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Home My WebLink About202-124Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250910 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 213-26T 50283202040000 225038 6/14/2025 AK E-LINE CBL MPU C-21 50029207530000 182081 7/8/2025 AK E-LINE Caliper MPU M-62 50029237440000 223006 6/23/2025 READ Caliper Survey PBU 01-13A 50029202700100 225052 8/17/2025 BAKER MRPM PBU 01-30A 50029216060100 225050 8/7/2025 BAKER MRPM PBU 07-24A 50029209450100 225045 8/3/2025 BAKER MRPM PBU N-12 50029205570000 181014 8/5/2025 BAKER SPN PBU PSI-09 50029230950000 202124 7/17/2025 HALLIBURTON WFL-TMD3D Please include current contact information if different from above. T40860 T40861 T40862 T40863 194-080 T40864 T40865 T40866 T40867PBU PSI-09 50029230950000 202124 7/17/2025 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.10 11:27:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-09 PRUDHOE BAY UNIT PSI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/08/2025 PSI-09 50-029-23095-00-00 202-124-0 N SPT 8034 2021240 2430 482 2707 2677 2667 0 0 0 0 OTHER P Guy Cook 7/22/2025 2 year MITT per C.O. 736. Header pressure at 2430. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-09 Inspection Date: Tubing OA Packer Depth 0 26 29 29IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250722131713 BBL Pumped:4 BBL Returned:3.8 Monday, September 8, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-09 PRUDHOE BAY UNIT PSI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 PSI-09 50-029-23095-00-00 202-124-0 W SPT 8034 2021240 2250 1900 1900 1902 1900 408 635 611 603 REQVAR P Guy Cook 7/5/2025 2 year MITIA to maximum injection pressure per AA AIO 4F.001. Header pressure was at 2250 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-09 Inspection Date: Tubing OA Packer Depth 815 2637 2440 2396IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250706164655 BBL Pumped:1.7 BBL Returned:1.7 Tuesday, August 5, 2025 Page 1 of 1           Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/24/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230824 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 14-6Y 50133205720000 207149 8/10/2023 YELLOW JACKET GPT/Plug/Perf KBU 14-6Y 50133205720000 207149 8/12/2023 YELLOW JACKET GPT/Plug/Perf KBU 14-6Y 50133205720000 207149 8/17/2023 YELLOW JACKET GPT/Plug/Perf KBU 22-06 50133205500000 205054 8/3/2023 YELLOW JACKET Gamma Ray KBU 22-06 50133205500000 205054 8/6/2023 YELLOW JACKET Gamma Ray KBU 22-06 50133205500000 205054 8/11/2023 YELLOW JACKET GPT/Plug/Perf MPU J-29A 50029236880100 221023 8/19/2023 READ Caliper Survey PBU S-42A 50029226620100 215055 8/11/2023 READ MAPP PBU PSI-09 50029230950000 202124 7/28/2023 HALLIBURTON WFL-TMD3D Please include current contact information if different from above. T37955 T37955 T37955 T37956 T37956 T37956 T37957 T37958 T37959 8/28/2023 PBU PSI-09 50029230950000 202124 7/28/2023 HALLIBURTON WFL-TMD3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.28 15:49:42 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:Brooks, Phoebe L (OGC); AOGCC Records (CED sponsored) Subject:FW: PSI-09_WFL-TMD3D_28JUL23_Report (PTD# 202124) Date:Monday, August 21, 2023 11:54:06 AM Attachments:image001.png PBU_PSI-09_WFL-TMD3D_28JUL23_Report.pdf From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, August 21, 2023 11:39 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: PSI-09_WFL-TMD3D_28JUL23_Report (PTD# 202124) Log results for PSI-09 (PTD# 202124) WFL ran 7/28/23. CO736 logging requirement. No flow detected. Let me know if you have any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Fanny Haroun <Fanny.Haroun@halliburton.com> Sent: Monday, July 31, 2023 12:02 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Nicholas Christian <Nicholas.Christian@halliburton.com>; Nicholas Sanders <Nicholas.Sanders@halliburton.com>; Chris Gullett <Christopher.Gullett@halliburton.com> Subject: [EXTERNAL] PBU_PSI-09_WFL-TMD3D_28JUL23_Report Dear all, Please find attached the analysis result for waterflow in PSI-09 well. The TMD3D Tool was run in oxygen activation impulse mode in the 7.625” and 7.0” tubing taking impulse tests at several station depths. The tool was run in normal configuration (generator positioned below the detectors) for water up flow detection. Impulse tests were done in 8 different depths: 6250, 6750, 7250, 7750, 8250, 8750, 9250, and 9750 ft MD. All the impulse tests show no detectable water moving upward at the station depths. Regards, Fanny Haroun Log Analyst 6900 Arctic Blvd Anchorage, AK 99518-2146 Email: fanny.haroun@halliburton.com Office: +1 907-275-2605 Mobile: +1 907-342-5550 This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Oxygen Activation Evaluation Water Flow Detection Company: Hilcorp North Slope, LLC. Well: PSI-09 Field: Prudhoe Bay Borough: North Slope State: Alaska API#: 50-029-23095-00 Geoscience & Production Center of Excellence, North America Analyst: Fanny Haroun Email: fanny.haroun@halliburton.com Phone: 907-342-5550 Logging Date: 07/28/2023 Report Date: 07/31/2023 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF Page 2 of 26 Table of Contents 1.0 EXECUTIVE SUMMARY ................................................................................................................... 3 2.0 WELL INFORMATION ...................................................................................................................... 4 3.0 TOOL STRING DIAGRAM ................................................................................................................ 5 4.0 WATER FLOW LOG EVALUATION ................................................................................................. 6 4.1 IMPULSE TESTS RESULT ............................................................................................................. 9 4.1.1 Impulse Test @ 6250 ft MD .................................................................................................. 9 4.1.2 Impulse Test @ 6750 ft MD ................................................................................................ 11 4.1.3 Impulse Test @ 7250 ft MD ................................................................................................ 13 4.1.4 Impulse Test @ 7750 ft MD ................................................................................................ 15 4.1.5 Impulse Test @ 8250 ft MD ................................................................................................ 17 4.1.6 Impulse Test @ 8750 ft MD ................................................................................................ 19 4.1.7 Impulse Test @ 9250 ft MD ................................................................................................ 21 4.1.8 Impulse Test @ 9750 ft MD ................................................................................................ 23 5.0 WARMBACK TEMPERATURE PLOT ............................................................................................ 25 Page 3 of 26 1.0 Executive Summary Well: PSI-09 Oxygen Activation Evaluation Survey date: 28-JUL-2023 Logging Objective Logging objective is to perform water flow log to determine water flow behind pipe. Conclusions The TMD3D Tool was run in oxygen activation impulse mode in the 7.625” and 7.0” tubing taking impulse tests at several station depths. The tool was run in normal configuration (generator positioned below the detectors) for water up flow detection. Impulse tests were done in 8 different depths: 6250, 6750, 7250, 7750, 8250, 8750, 9250, and 9750 ft MD. All the impulse tests show no detectable water moving upward at the station depths. Page 4 of 26 2.0 Well Information Page 5 of 26 3.0 Tool String Diagram Page 6 of 26 4.0 Water Flow Log Evaluation The TMD3D was run using stationary impulse tests across the zones of interest. Water flow can be detected by measuring gamma rays originating from activated oxygen within any water flowing past the neutron generator (activation) then moving past the detector section (decay). The fluid/water velocity is estimated from oxygen activation using impulse test data. The flow direction is determined by the position of the sensor relative to the neutron generator. The flow region, near or far, is derived by the ratio of Compton backscatter gamma rays compared to original gamma ray counts from activated oxygen. Lower Compton ratio indicates a flow region further from the tool i.e., behind the next string of pipe. Total oxygen activation will be a function of: • volume of water in the region of neutron cloud • flow velocity of water • tool speed • flow distance to detector • time exposure Below is a representation of the sequence of radioactive excitation and subsequent relaxation of Oxygen. Figure 1: Sequence events of oxygen activation The tool is configured in the normal mode with the neutron generator below the detector section. In the normal configuration, water will only be detected when moving up relative to the tool, in both the stationary impulse mode and continuous mode. Any oxygen activation detected by far and long detector should be from water flow upward. If there is water flow in the downward direction the GR sensor below the neutron generator will detect the activated oxygen. The near detector is not use for the calculation due to its proximity to the neutron generator. Page 7 of 26 Figure 2: Flow scenario related to TMD3D log tool Stationary Impulse Method This technique is a travel-time measurement and has the significant advantage of not requiring any calibration of the detectors. When the tool is stationary at a specified depth, the generator is turned on and allowed to stabilize. The count rate in each detector is then recorded for one or two minutes, at which time the generator is shut down. At some time later (depending on the fluid flow velocity and distance from the various detectors to the source), the count rate recorded in the detectors will drop to background level. The count rate will drop to zero in the spectral window encompassing the oxygen peak. The surface computer records the various detector count rates, steps down the generator, measures the time until the recorded count rates fall to one-half full value, and then computes a velocity from the travel time. The fluid velocity is the distance from the source to the detector divided by the time between the count-rate drop and the time when the generator was shut down. The procedure is completely automated. The spectral data can be processed to provide fluid velocity in one step because the count rate falls to zero after the activation passes. Processing the total gamma ray count rates requires two steps. The natural Page 8 of 26 background must be measured for approximately one minute after the drop to correct for the nonzero background activity. Fig. 3 is a graphical representation of the timing cycle used by the stationary impulse method. Figure 3: Stationary Impulse timing sequence The rate computation: Outer Casing ID = 6.875 or 6.276 inch (7.625 or 7.0” tubing), Inner Casing OD = 1.6 inch (the tool OD) Vavg = average water velocity Qw (bpd) = Vavg (ft/min) x 1.4 x (Outer CasingID2 (inch) – Inner CasingOD2 (inch)) Page 9 of 26 4.1 Impulse tests result 4.1.1 Impulse Test @ 6250 ft MD The impulse test at depth 6250 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 10 of 26 Page 11 of 26 4.1.2 Impulse Test @ 6750 ft MD The impulse test at depth 6750 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 12 of 26 Page 13 of 26 4.1.3 Impulse Test @ 7250 ft MD The impulse test at depth 7250 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 14 of 26 Page 15 of 26 4.1.4 Impulse Test @ 7750 ft MD The impulse test at depth 7750 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 16 of 26 Page 17 of 26 4.1.5 Impulse Test @ 8250 ft MD The impulse test at depth 8250 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 18 of 26 Page 19 of 26 4.1.6 Impulse Test @ 8750 ft MD The impulse test at depth 8750 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 20 of 26 Page 21 of 26 4.1.7 Impulse Test @ 9250 ft MD The impulse test at depth 9250 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during generator on and off. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 22 of 26 Page 23 of 26 4.1.8 Impulse Test @ 9750 ft MD The impulse test at depth 9750 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during generator on and off. The GR2 sensor below TMD3D tool shows different readings during generator on and off, due to active injection inside the wellbore. Page 24 of 26 Page 25 of 26 5.0 Warmback Temperature Plot Page 26 of 26 End of Report MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 15, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-09 PRUDHOE BAY UNIT PSI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2023 PSI-09 50-029-23095-00-00 202-124-0 N SPT 8034 2021240 2008 562 2706 2669 2662 0 0 0 0 OTHER P Sully Sullivan 7/26/2023 2 year test cycle mit-t per co 736 test psi 2430 per program 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-09 Inspection Date: Tubing OA Packer Depth 0 113 118 124IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230811152726 BBL Pumped:2 BBL Returned:2 Friday, September 15, 2023 Page 1 of 1          MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-09 PRUDHOE BAY UNIT PSI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 PSI-09 50-029-23095-00-00 202-124-0 W SPT 8034 2021240 2008 1926 1926 1924 1902 147 446 426 420 REQVAR P Guy Cook 7/22/2023 2 year MITIA per AIO AA 4F.001. Maximum applied pressure 2430 psi. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-09 Inspection Date: Tubing OA Packer Depth 252 2664 2522 2485IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230723142508 BBL Pumped:2.3 BBL Returned:2.3 Tuesday, September 12, 2023 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 2 year MITIA per AIO AA 4F.001. James B. Regg Digitally signed by James B. Regg Date: 2023.09.12 15:07:19 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 12, 2021 SUBJECT: Mechanical Integrity •bests Hilcorp North Slope, LLC PSI -09 PRUDHOE BAY UNIT PSI -09 Sre: Inspector Reviewed By: P.I. Supry T Comm Well Name PRUDHOE BAY UNIT PSI -09 API Well Number 50-029-23095-00-00 Inspector Name: Austin McLeod Permit Number: 202-124-0 Inspection Date: 7/25/2021 ' Insp Num• mitSAM210725160335 Rel Insp Num: Packer Depth Well PSI -09 Type Inj N TVD 8034 Tubing PTD 2021240 Type Test SPT 'Test psi 2008 IA BBL Pumped: 3.5 - BBL Returned: 3.1 OA Interval OTHER P/F P Notes: Retest. 2 year MITT per CO 736. Plug at 9755' MD. ✓ Pretest Initial 15 Min 30 Min 45 Min 60 Min 619 2707 " 2672 2658 ' 01 41 51- 48 Thursday, August 12, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, August 12, 2021 Jim Regg P.I. Supervisor Imo( SUBJECT: Mechanical Integrity Tests I Hilcorp North Slope, LLC PSI -09 FROM: Austin McLeod PRUDHOE BAY UNIT PSI -09 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry OTIL NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -09 API Well Number 50-029-23095-00-00 Inspector Name: Austin McLeod Permit Number: 202-124-0 Inspection Date: 7/24/2021 Insp Num: mitSAM210812105851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -09 - Type Inj N 'TVI) 8034 Tubing 2554 2712 _ 2661 _ 2634 ' PTD 2021240 Type Test sPT' Test psi 2008 IA 727 728683 655 BBL Pumped: 0.3 - BBL Returned: 4 - OA 360 345 320 305- Interval P/F F -OTHER Notes' 2 year MITT per CO 736. Plug at 9755' MD. First test (mitSAM210725201354) was a failure, credited non -stabilizing trend to thermal. Same results. Thursday, August 12, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: Thursday, August 12, 2021 >� Z r P.I. Supervisor � l l SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -09 FRONI: Austin McLeod PRUDHOE BAY UNIT PSI -09 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry �Rl_ NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -09 API Well Number 50-029-23095-00-00 Permit Number: 202-124-0 Insp Num: mitSAM210725201354 Rel Insp Num: Inspector Name: Austin McLeod Inspection Date: 7/24/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -09 PTD 2o212ao Type Inj N "TVD T 8034 560 2709 ' Type Test SPT Test psi 2008 IA 402 830 - 2615 255a 779 - 727 -�-- BBL Pumped: !, - - � 70 413 4.2 - BBL Returned: o OA 3— 386 --360 Intervali OTHER P/F F ✓ Notes: 2 year MITT per CO 736. Plug at 9755' MD. Prior to arriving warm fluid was loaded in tubing pre-test. Credited non -stabilizing trend to thermal. T 7 Thursday, August 12, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor lei � j -20' 6 f zez-1 FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT PSI -09 IInsp Num: mitSAM210725201354 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -09 PRUDHOE BAY UNIT PSI -09 Src: Inspector Reviewed By:: P.I. Supry �jgo — Comm API Well Number 50-029-23095-00-00 Inspector Name: Austin McLeod Permit Number: 202-124-0 Inspection Date: 7/24/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min �TVD Tubing: Psl-09 TYPe Inj N 8034 560 2709 2615 zssa - PTD -- 402 830 779 727_ BBL Pumped: 4 � Testi, sPT-'Test psi � z43o � �� 2o212ao YPe ,BBL Returned: 4 - OA 370 413 386. 360 P - - - - -- l -- -1---- - -- - - Interval REQvARP/F F Notes: 2 Year MITT. AIO No. 4F.001. Plug at 9755' MD. Test PSI=MAIP. Prior to arriving warm fluid was loaded in tubing pre-test. Credited non- stabi rz�ing trend to thermal. Test was bumped up at - 40 min. Held to -20 min with same results. Tuesday, July 27, 2021 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT PSI -09 Insp Num: mitSAM210725160335 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -09 PRUDHOE BAY UNIT PSI -09 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-23095-00-00 Inspector Name: Austin McLeod Permit Number: 202-124-0 Inspection Date: 7/25/2021 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min YP- J - PTD zPSI-09 Type Test - TVD 8034 - Tubing 619 2707 2672 2658 - I PSI 09 N Yp SPT �jest psi 2430 IA 0 41 51, 48 BBL Pumped BBL 3.5 Returned ' - - -- - = -- 3.1 - - OA 0 0 0 Interval. REQVAR P/F P Notes: Retesi 2 year MITT. AIO No. 4F.001. Plug at 9755' MD. Test PSI=MAIP Tuesday, July 27, 2021 Page 1 of I MEMORANDUM TO: Jim Regg"II II, JAL P.I. Supervisor l FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 15, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -09 PRUDHOE BAY UNIT PSI -09 Src: Inspector Reviewed By: P.I. Supry J'lSlf— Comm Well Name PRUDHOE BAY UNIT PSI -09 API Well Number 50-029-23095-00-00 Inspector Name: Brian Bixby Permit Number: 202-124-0 Inspection Date: 7/9/2021 Insp Num: mitBDB210709130606 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -09 Type Inj w VD 8034 Tubing 1615 1619 1619 1618 ' PTD 20202 1240 Type Test SPT dTCSt psi 2430 IA 50 2713 � � 2552 - � 2495 BBL Pumped: 1.6 BBL Returned: 1.6 OA 115 438 -i 417 - 407 Interval REQVAR IP/F P ,% Notes: MITIA as per AIO 4F.001 Thursday, July 15, 2021 Page 1 of I *®§§ � v- «/ .§ 2 ;$ :k 22 m & ` , - e ) / | - ' LL 2 z e ) /§ ( *®§§ � v- «/ 2 k k WELL LOG TRANSMITTAL #905839087 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: PSI -09 Run Date: 7/13/2019 2�21� 31303 October 3, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 PSI -09 Data in LAS format, Digital Log Image files 50-029-23095-00 RECEIVE® OCT 0 7 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou.xwh.BP.com Date: 0—/—D k02 Signed: 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUGREPORT OF SUNDRY WELL OPERATIONS U 2 9 Kfi3 1 0 Aerations Performed 10343 feet Plugs Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ feet Junk Suspend ❑ Pe P Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Operations shutdown ' ❑ Plug for Redrill ❑ Perforate New Pool ❑ Alter Casin ❑ ll Change Approved Program ❑ 2. Operetor Name: BP Exploration (Alaska), Inc Repair Well 0 4. Well Class Before Work Re-enter Susp Well ❑ Other: W Cement Squeeze 0 3. Adtlress: P.O. Box 196612 Anchorage, Development ❑ Exploratory p ry ❑ 5. Permit to Drill Number 202-124 AK 99519-6612 Stratigraphic ❑ 7. Property Designation (Lease Number): Service 0 6. API Number. 50-029-23095-00-00 ADL 028322 8 034631 e — 9 Logs (Lest logs antl submit Well Name and Number PBU PSI -09 electronic and printed data per 20AAC25 07n 11. Present Well Condition Summary Total Depth: measured 10343 feet Plugs true vertical 8635 feet Junk Effective Depth: measured 10300 feet Packer true vertical 8594 feet Packer 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL measured None feet measured 10154 feet measuretl 9713 feet true vertical 8035 feet Casing: Structure) Length: Size: MD: TVD: Buret: Collapse: Conductor 80 20" 35-115 35-115 1490 Surface 5553 13-3/8" 470 35 - 5586 35-4645 5020 Intermediate 9886 2260 9-5/8" 31-9920 31-8231 Production 6870 4760 Liner 1430 7" 8913-10343 7289-8635 7240 5410 Perforation Depth: Measured depth: 9980-10246 feet True vertical depth: 8269-8542 feet Tubing (size, grace, measured and true vertical depth) 7-5/8" 29.7# x 7" 26#, L-80 30-9768 30-8096 Packers and SSSV (type, measured and 7" Baker SABL-3 Packer 9713 true vertical depth) 8035 7" Cameo Ai Injection Valve 2162 12. Stimulation or cement squeeze summary: RIH and sting into retainer. C33 onfirm circulation antl load 10 Me of Surfactant Wash into the coil. Batch cement and mud push. Pump 9 bible of mud push followed by 54.2 bbls of cement into the annulus (59 pumped total) for a calculated cement top of 8442'. Unsting from retainer and reverse out cement remaining in coil while POOH. Circulate compressive d Powervis and KCI at max rate to Gear all lines. Wait on cement to reach 500 psi Intervals treated (measured): 6442' - 9670 - Treat ant 670'Treatment descriptions including volumes used an final pressure: 54.2 bb Final Pressures: OA = 25 psi, 1A= 315 psi, TBG = 1789 psi Is 14.82 ppg CemFit Heal, 13. Representative Daily Average Production or Injection Data Oil-Bblr cf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In Su 720 p bsequent to operation: Shut In 315 1789 14. Attachments: (requiree perID MC 25.07025.071,825.2fter work: Daily Report of Well Operations 0 Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ fter work: Printed and Electronic Fracture Stimulation Data Oil ❑Gas ❑WDSPL ❑ WIN) 0 WAG ❑ GIN) ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of m knowledge. Y 9 Sundry Number or N/A if C.O. Exempt: 319.234 Authorized Name: Smith, Travis T Contact Name: Smith, Travis T Authorized Title: Engine Contact Email: trevissmithl�bp.com Authorized Signatu Date: Contact Phone: +1 9075645412 Form 16404 Rebleed 04/ /✓��p i/f.4404/ RBDMS.I Submit Original Ony /�� /(J OYC J°i1J=/IT AUG 3 01019 '**WELL 0/1 ON Al (cement squeeze) RIGGED UP SWCP 4521 6/24/2019 ***WSR CONTINUED ON 6125/19*** ***WSR CONTINUED FROM 6124/19*** (cement squeeze) ct) PULLED 7" PRN PLUG FROM 9743' SLM / 9755' MD / 9753' ELM (plug bodEof 6/25/2019 TAGGED FILL W/ 3.50" CENT W/ BAILER AT 10,144' SLM 110,154' ELM (/ No sample) ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** **WELL S/I ON ARRIVAL*** (Cement Squeeze) RIG UP HES ELINE UNIT 4863 6/25/2019 ***JOB CONTINUED ON 26 -JUN -2019*** ***JOB CONTINUED FROM 25 -JUN -2019*** (Cement Squeeze) LOG SBHPS AS PER PROGRAM SET HES 7" FAS DRILL CBP a@ 9690' MID -ELEMENT (9689' top of plug). ill 1 11 llwl� 6/26/2019 ALL LOGS CORRELATED TO BASE TEMP/JEWELRY LOG DATED 29 -JULY -2002. *—JOB CONTINUED ON 27 -JUN -2018*** ****JOB CONTINUED FROM 26 -JUN -2019*** (Cement Squeeze) PUNCH TBG 91912", 4 Si 0 DEG PHASE GUN. CURRENTLY RIH W/ 7" HES FAS DRILL SVB COMPOSITE CEMENT RETAINER. 6/27/2019 ALL LOGS CORRELATED TO BASE TEMP/JEWELRY LOG DATED 29 -JULY -2002. ****JOB CONTINUED ON 27 -JUN -2019*** ***JOB CONTINUED FROM 27 -JUN -2019*** (Cement Squeeze) SET HES 7" FAS DRILL CEMENT RETAINER AT 9650' MID-ELMENT (9649'top of retainer). LRS PER ALL LOGS CORRELATED TO BASE TEMP/JEWELRY LOG DATED 29 -JULY -2002. 6/28/2019 ***WELL S/1 ONDEPARTURE*** CTU 9 2" 0.156WT 45.1 CV Objective: IA cement/post cement milling MIRU reverse out +MM bypass. Partial bop test on 7-1/16" bops. MU Cement stinger BHA for HES FasDril retainer. Displace coil to diesel before RIH. Replace choke trailer due to blockage and then diagnose backside MM. RIH and rig up SLB cementers. 7/3/2019 ...Continued on WSR 7-4-19... CTU #9 - 2" 0 Coil, 0.156wt 45.1 CV ***Cont. from WSR 7-3-19*** Objective: IA cemenVpost cement milling RIH and sting into retainer. Confirm circulation and load 10 bbls of Surfactant Wash into the coil. Batch cement and mud push. Pump 9 bbls of mud push followed by 54.21 of cement into the annulus (59 pumped total) for a calculated cement top of 6442'. Unsting from retainer andreverse ou cemen remaining in coil while POOH. Cvculate Powervis and KCI at max rate to clear all lines. Wait on cement to reach 500 psi compressive. 7/4/2019 ...continued on WSR 7-5-19... CTU #9 - 2" 0 Coil, 0.156wt 45.1 CV ***Cont. from WSR Objective: IA cement/post cement milling Continue standby for cement to reach 500 psi compressive strength 7/5/2019 ...In-------------- ro ress... CTU #9 - 2" 0 Coil, 0.156wt 45.1 CV ***Cont. from WSR 7-5-19*** Objective: IA cement/post cement milling 5.70" Continue standby for cement to reach 500 psi compressive strength. Make up Baker 2-7/8" motor with Mill and RIH. Mill Retainer and CBP. Unable to push CBP through lower RN nipple @ 9750'. POOH and bit is completely worn. Make up & RIH w/ Baker 3-1/8" venturi w/ 4.40" gauge ring. 7/6/2019 ...Job in Progress... Daily Report of Well Operations PBU PSI -09 CTU #9 - 2" 0 Coil, 0.156wt 45.1 CV ***Cont. from WSR 7-6-19*** Objective: IA cement/post cement milling RIH w/ Baker 3-1/8" Venturi wl 4.40" gauge ring. Made four venturi passes from top of plug @ 9759' up to V above. OOH and recovered -4 cups of blue plastic chips from -3" coated tubing. Make up Milling BHA with 5.65" 5 bladed mill and RIH. Mill CBP remnants at RN nipple push from tubing. Confirm injectivity by pumping additional 50 bbls at 7.5 bpm with 0 WHIP. Dry drift out tubing tail to confirm tubing clear. CBP remanats believed to be near SL tag of 10154' ELM. POOH. FP well. RDMO CTU. 'Job Complete' 7/7/2019 T/1/0=0/0/0 Temp= S/I (LRS Unit 70 assist SSL, TBG load and State Witnessed by Adam Earl MIT -T, MIT -IA) MIT -T to 2765 psi PASSED Pumped 5.4 bbls of 60* F diesel to achieve test pressure. 1st 15 min TBG lost 61 psi. 2nd 15 min TBG lost 23 psi. TBG lost 84 psi for a 30 min test. Bled back 5.4 bbls. MIT -IA PASSED to 2570 psi. Pumped 5.5 bbls of 60* F diesel to achieve test pressure. 1 st 15 min IA lost 124 psi. 2nd 15 min IA lost 40 psi. IA lost 164 psi for a 30 min test. AOGCC MIT -T PASSED to 2714 psi. Pumped 0.2 bbls of 60* F diesel to achieve test pressure. 1st 15 min I B(3 iost z2 psi. Znd 16 min I BU lost 11 psi. TBG lost 33 psi for a 30 min test. Bled back 3 bbls. AOGCC MIT -IA PASSED to 2651. Same test: MIT -IA to 2651 psi Failed according to BP criteria. Pumped 0.26 buls of 60* F Zliese o ac leve test pressure. 1st 15 min IA lost 57 psi. 2nd 15 min IA lost 32 psi. IA lost 89 psi for a 30 min test. Bled back 2 bbls. 7/12/2019 ***WSR continued on 07-13-19*** ***WELL S/I ON ARRIVAL SWCP 4518***(cement squeeze) DRIFT W/ 7" BRUSH & 4.65" G -RING TO RN -NIP @ 9755' MD. DRIFT W/ 5.87"G -RING & TAG RN -NIP @ 9728' SLM (9755' MD). SET 5.95" CAT STANDING VLV IN RN -NIP @ 9728'SUM (9755' MD). PASSING AOGCC WITNESS TBG & IA. 7/12/2019 ***CONTINUE WSR TO 7/13/19*** ***WSR continued from 07-12-19*** (LRS Unit 70 assist SSL, TBG load and State Witnessed MIT -T, MIT -IA) 7/13/2019 lContinue rig down from TxIA. Slickline in control of well upon LRS departure. FWHP's 790/250/0 ***CONTINUE WSR FROM 7/12/19 SWCP 4518***(cement squeeze) RAN HES SCMT LOG FROM 9713' SLM TO SURFACE BOG S PULLED 5.95" CAT STANDING VLV FROM 9728' SLM (9755' MD) 7/13/2019 ***WELL LEFT S/1 DSO NOTIFIED ON DEPARTURE*** T/I/O = 1715/532/0. Temp = 58°. AOGCC MIT -IA PASSED to 2707 psi, Max Pressure = 2900 psi, Target Pressure = 2700 psi (req Compliance). On SWI. tate witnessed by Austin McLeod. ITFL surface. Used 2.1 bbls of DSL to pressure up IAP from 532 psi to 2895 psi. IAP lost 156 psi in the 1st 15 minutes and 32 psi in the 2nd 15 minutes for a total loss of 188 psi in 30 minutes. Bled IAP to pre test pressure of 500 psi (2 bbls). Continued bleed to to 200 psi. Hung tags. Final WHPs = 1710/250/0. 7/28/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 12:00 T/l/O = 1650/250/20. Temp = 59*. WHP's. (Post MIT -IA). Well is on Inj. TP decreased 60 psi, no change in IAP, OAP increased 20 psi overnight. 7/29/2019 SV = C. WV, MV, SSV = 0. IA, OA = OTG. 20:17 ***JOB STARTED ON 07 -AUGUST -2019*** WELL FLOWING ON ARRIVAL. RIG UP ELINE. SHUT IN WING. TWO = 0/0/0. FLOWLINE ISSUE BEHIND NEIGHBORING WELL 10. RDMO. ELINE WILL RETURN TO LOG WFL AT LATER DATE. 8/7/2019 ***JOB COMPLETE ON 07 -AUGUST -2019*** Daily Report of Well Operations PBU PSI-09 ***WELL INJECTING ON ARRIVAL*** (SLB E-LINE WATERFLOW LOG) INITIAL T/1/0 = 0/0/0 PSI RIG UP, PT LUBRICATOR TO 350/3400 PSI RIH WITH WELL SI. LOG BASELINE PASS DOWN AT 60 FPM FROM SURFACE TO 97501. PUT WELL ON INJECTION AT 39000 BWPD AND LET STABILIZE. LOG STATION STOPS EVERY 500' FROM 9750' TO 6250'. NO UPWARD FLOW DETECTED BEHIND PIPE. SHUT IN INJECTION AND WAIT 1 HR. LOG 1 HR WARMBACK PASS UP FROM 9750' TO 6400' AT 60 FPM. LOG 2 HR WARMBACK PASS AT 60 FPM FROM 9750' TO 6400'. 8/9/2019 ***JOB CONTINUED ON 10-AUG-2019*** **'WELL S/I UPON ARRIVAL*** (cement squeeze) TAGGED 6" DB-NIPPLE W/ 6.05" GAUGE RING @ 2,138' SLM SET NEW DB-A1 INJECTION VALVE (HYS-426) IN SSSV NIPPLE @ 2,162' MD 8/10/2019 *'*WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS**' ***JOB CONTINUED FROM 9-AUG-2019'** (SLB E-LINE RST WATERFLOW LOG) LOGGING COMPLETED, POOH RDMO E-LINE FINAL T/1/0 = 0/0/0 PSI 8/10/2019 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE. READY FOR SLICKLINE*** TREE= 7-1/16"5K CJW 1ABLPEAD=13-58.5K FMC ACTUATOR= OKB. E LEV = 5055' BF. E LEV = 1927 KOP= 1400' Max Angle = 51' @ 5536' Datum MD= 10255' DatumTVD= 8500' SS zo' CONDUCTOR _#. _. 11) _ 116' 13-318' CSG, 666, L-80 BTC, D = 12.400' 6668' I CMT SHEATH, o=•570"(07107/19) I ITBG PUNCH, 4 8PF (06727/19)�PUNCH, 4 SPF (0627/19)--L_9666' -9670' Minimum ID = 5.770" @ 9756' 7" HES RN NIPPLE ID = 6.276' 9-58' CSG, 47#, L-80 BTRC-M, D = 8.681"9920' PERFORATION SUMMARY REF LOG: SM JEWELRY LOG 07/29/02 ANGLEATTOP PERF: 18' @ 9960' Note: Refer to Production DB for historical cert data PSI -09 SIZEISPF1 ELMD TT LOGGED 07/30/02 INTERVAL Opn/Sgz SHOT SOZ 3-38" 6 9960 -10030 O 11/19/02 0627119 CJWJMD PULLED PRN PLUG (062511 3-38" 6 10056-10076 O 11/19/02 3-38' 6 10088 - 10102 O 11/19/02 3-38' 6 10135 -10165 O 07/30/02 3-38" 6 10175 - 10186 O 07/30/02 3-38' 6 10196 - 10246 O 07/30/02 pBTD 10300' D =6276" 14 10345' SAFETY NOTES: WELL REQUIRES A SSSV ••' 42' - 9670' --j CMT IN IA (07/04/19) ' i irl /Qiet 7-518' X 7" XO, D = 6.276' r 966W 7" HES R NP, D = 5.963' �/ 9-58' X 7" BKR SABL-3 PKK D= 7' HES R NP, D = 5.963" 9763- 7669766' 9766' ELMD TT LOGGED 07/30/02 9613' 9-58'X7' BKRT�KSLV w/ZXP LTP, D=_" 0385/15 PJC REFORMAT PER TALLES JWJMD H, MILL RET 6 CBP 9697 9-518' X 7-BKR HMC LNR FGR. ID = ' DATE REV BY COMMENTS REV BY COMMENTS 0722102 NZ7E INITIAL COMPLETION MS/JMD B TBG PUNCH 0385/15 PJC REFORMAT PER TALLES JWJMD H, MILL RET 6 CBP 0323115 GJB/PJC PULL PRN PLUG =RETAINER,BP, M20"COND 0181/19 CJWJMD SET PRN PLUG(0128/19) 05/06/19 JNL EDRTO BF, 7' LNR DEPTHSDEPTH 0627119 CJWJMD PULLED PRN PLUG (062511 IFISH: MILLED 7' HES CBP 6 RETAINER (07107/19) PRUDHOE BAY UNIT WELL: PSP09 PERMIT No:'2021240 API No: 50-029-23095 Tl I N. RI 5E, 3876' NSL 8 4 BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggnry, DATE: Wednesday, July 31, 2019 P.I. Supervisor �� '{ al��I SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. PSI -09 FROM: Austin McLeod PRUDHOE BAY UNIT PSI -09 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Sup" NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -09 Insp Num: mitSAM190728110344 Rel Insp Num: API Well Number 50-029-23095-00-00 Permit Number: 202-124-0 Inspector Name: Austin McLeod Inspection Date: 7/28/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min PSI -09 �Typelnj W - TVD 8034 Tubing �;i5 In17151715212s• - 1715- PTD j 2040-tType Test PST 573 2895 2739- Test psi 2600 IA _ - 2)07 ' BBL Pumped: I 2.1 BBL Returned: 2 - OA i - 02 - 68 - 69 Interval OTHER — p/F I P Notes: MIT -IA. This well is under AND 4F.001(2 year), but SundryM 319.234 called for a test post LA cement squeeze. Test PSI reflects the MAIP. Wednesday, July 31, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Tuesday, July 23, 2019 2:36 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, G GPB FS2 Drillsites; Richards, Meredyth; Rupert, C. Ryan Cc: Regg, James B (CED); AK, GWO SR Eline WSL; AK, GWO SR Fullbore WSL; AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector PSI -09 (PTD# 2021240) passed MIT -T, MIT -IA post IA cement squeeze All, Injector PSI -09 (PTD # 2021240) was made Not Operable on 01/26/19 after it failed an AOGCC witnessed MIT -IA. On 03/13/19 Eline ran a leak detect log and discovered a production casing leak at 7,441 MD. On 07/04/19 Coil Tubing performed an IA cement squeeze in accordance with Approved Sundry 319-234. On 07/12/19 Fullbore performed a passing AOGCC witnessed MIT -T to 2,714 psi and passing MIT -IA to 2,651 psi. The well will now be classified as OPERABLE. Once the well is on stable injection, a state witnessed MIT -IA will be performed and E -line will perform a waterflow log. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, Janua 2019 11:46 AM To:'chris.wallace@alaska.gov is.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKO PSEOCSpecia lists@ bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2 Lead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2Field PTL@bp. > AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr<AKRESGPBEastWellsOptEngr@bp.com>, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AK CCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP. >; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Worthington,a <Jessica.Worthington@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO letions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllnt bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEnginee r@bp.com>; AK, GWO SUPT Well Int <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintf AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser. Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam G. Earl Petroleum Inspector Section: 15 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Mike Harris Casing/Tubing Data (depths are MD): Conductor: 20" _ O.D. Shoe@ Surface: 13 3/8" - O.D. Shoe@ Intermediate: NA O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 7' O.D. Shoe@ Tubing: 7 5/8" x 7" O.D. Tail@ Plugging Data: Test Data State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 12, 2019 SUBJECT: Plug Verification PBU PSI -09 BPXA PTD 2021240; Sundry 319-234 11N Range: 15E Meridian: Umait " NA Total Depth: 10343 ft MD Lease No.: ADL028322 Suspend: NA P&A: NA 115 Feet 5588 - Feet Feet 9920 " Feet 10343 - Feet 9768 — Feet Type Plug Casing Removal: Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ 0 Feet Csg Cut@ NA Feet Tbg Cut@ NA Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Annulus Packer 9713 ft MD 6441 ft MD' P OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 1 1265 1262 1260 IA 2740 2683 2651 P OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2747 2725 2714 - IA 681 696 697 P OA 0 0 0 Remarks: I traveled out to PBU PSI -09. BP rep. Mike Harris was on location. The well had a known Production casing leak (9 5/8") @ 7,741 ft MD. A cement job was completed that put a cement plug in the IA from the packer @ 9,713 ft MD up to a calculated 6,441 ft MD. This is what we would be pressure testing up against in the IA. The tubing had a plug set in a RN nipple @ 9,755 ft MD. This plug is what we would be testing up against for the tubing pressure test. Both tests passed. � rev. 11-28-18 2019-0712_Plug_Verification_PBU_PSI-09_ae THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU PSI -09 Permit to Drill Number: 202-124 Sundry Number: 319-234 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 64z�� Daniel T. Seamount, Jr. Commissioner DATED this 0— day of May, 2019. RBDMS�' MAY 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ECEIE MAY 08 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 21 Oper?9�(,on shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Ap�rw' i gram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other IA Cement Squeeze 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 202-124 ' 3. Address: P.O. Box 196612 Anchorage, AK 8. API Number 50-029-23095-00-00 , 99519-6612 Stretigrephic ❑ � Service 0 7. If perforating. S. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned Perforations require a spacing exception? Yes ❑ No 0 PBU PSI -09 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028322 & 034631 r PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10343 8635 9755 8074 9755 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 5553 13-3/8" 35-5588 65-4646 5020 2270 Intermediate 9889 9-5/8" 31-9920 31-8231 1 6870 1 4760 Production Liner 1430 7' 8913-10343 7289-8635 1 7240 1 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft). 1 9960-10246 8269 - 8542 75/8" 29.7# x 7" 26# L-80 30-9760 Packets and SSSV Type: 7' Baker SABL-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9713 / 8034 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: June 1, 2019 a 15. Well Status after proposed work: Oil ❑ WINJ 0 ' WDSPL ❑ Suspended ❑ 16. Verbal Approval. Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Smith, Travis T be deviated from without prior written approval. Contact Email: travis.smithlabp.com Authorized Name: Smith, Travis T Contact Phone: +1907 564 5412 Authorized Title: E Authorized Signature: Date: S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q-Z3y Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test O,� Location Clearance ❑ / Other. Van, a -A C't -6C Cc 7S46- I�EEP51,r4i e+�pSntq $-tam pMo /a�,3 4&4Z14-- X111 Azti Post w on IT 4c d? Yes No ❑ Spacing Exception Required? Yes ❑ No t$� Subsequent Form Required: 10 — ` /I I0 If AD BYTHE COMMISSIONER COMMISSION Date Approved by: J 6/ p6 61r' -211A Form 10403 Revised 04/2017 ORIGINAL RBDMS� / MAY 13 2019 /W ne69/10151" Submit Form and Approved application is valid for 12 months from the date of approval.Attachments in Duplicate AM'17 Z. �-0, SAO Engineers: Well: PSI -09 PSI -09 IA Cement Job Overview Travis Smith: 907-564-5412 Meredyth Richards: 907-564-4867 History: PSI -09 is one of seven Gas Cap Water Injection (GCWI) wells at PBU. Drilled in July 2002, PSI -09 was on injection nearly continuously for the last 17 years, over which time it provided more than 350MM BBL of seawater pressure support to the Ivishak reservoir. In December 2018, the well failed an AOGCC MIT -IA and therefore became non-operable. A subsequent leak detect log in March 2019 determined the leak source to be a production casing leak at 7441' MD. Given the high value and demonstrated recovery effectiveness of GCWI, coupled with a recent increase in available seawater volume at the Seawater Injection Plant, restoring the well to operability with an IA squeeze is important to Prudhoe's broader reservoir management strategy. Scope of Work: Repair production casing leak at 7441' MD with IA cement job. Return well to injection. Background Information: • Production casing leak: o Initially discovered with failing MIT -IA on 12/29/2018 o Acoustic LDL on 3/13/2019 found leak depth to be 7441' MD • Cretaceous stratigraphy at PSI -09: o Top of CM3: 8393' MD, 6818' TVD o Top of UG4: 6119' MD, 5004' TVD • SBHP on 5/1/2015 recorded pressure of 3749 psi equivalent at 8800' TVD datum, and temperature of 65 OF • 9-5/8" x 13-3/8" Outer Annulus has open shoe, and has never been pressure tested • TOC of the 9-5/8" casing is 7570' MD from USIT log on 7/18/2002 Overview Procedure: Slickline and Fullbore: 1. Pull 7" PRN plug from 9755' MD. 2. Collect SBHP survey. a 3. Run drift for CBP and cement retainer. 94,9 4. Set 7" CBP in the seal assembly of the PBR at�61 MD. 5. Fire tubing punch from 9661'-9665' MD, in the 9.78' pup joint above the PBR assembly. a. Fullbore: pumping down the tubing and taking returns through the IA, confirm circulating rates and pressure through tubing punch. b. Circulate tubing and IA to diesel. 6. Set cement retainer at 9654' MD, mid -joint in the 9.79' pup joint (second up from the PBR assembly). Coiled Tubing: 1. Sting into cement retainer and pressure test. Pumping down coil, establish returns up the IA and pump the following schedule (target TOC in the IA is 6441' MD): a. 5 bbl FW spacer b. 55 bbl Class G cement ✓ c. 5 bbl FW spacer d. CT volume of displacement 2. With 1 BBL of cement remaining in coil, disengage retainer and lay the last 1 BBL of cement on the retainer. Note pressures after un -stinging from retainer—do not bleed any pressure from IA. Ensure that retainer is holding pressure, and then circulate or reverse the cement off the retainer and POOH. 3. Wait for cement to gain 500 psi of compressive strength and RIH with milling BHA and junk mill. Mill the retainer, cement, and CBP from the 7" tubing. Mill/push the remainder of the CBP until it is out of the tubing tail. Slickline and Fullbore 1. Set PRN plug in RN nipple at 9755' MD. n 2. Log SCMT. —Ars-TI LS To A&ZGCle 3. AOGCC Witnessed MIT -T and MIT -IA to 2500 psi with any non -freezable fluid. Max applied pressure of 2750psi. 2` A-ne .eP Well Integrity Engineer 1. Add Biennial (every 2 years) MIT -Ts, MIT-IAs, and water -flow logs to AKIMS. TREE = 7-1116' 5K CNV WELLHEAD =13-518' 5K FMC ACTUATOR = ANGLE AT TOP PERF: 18' @ 9960' OKB. aEV = 50.55' BF. B -EV = 19.27' KOP= 1400' Max Angle = 51' @ 5536' Datum MD= 10255' Datum TVD= 8509 SS 120' CONDUCTOR —.#, __ D = _ _ " 13-3/8' CSG_ 68#. L-80 BTC D = 12 400' TBG, 29.7#, .0459 bpf, D = 6.875' 1-1 9947' Minimum ID = 5.770" @ 9755' 7" HES RN NIPPLE 17' TBG. 26#. L-80 TCA.0383 bpf. D= 6.276" I 19-58' CSG. 47#. L-80 BTRC-M. D = 8.681' I PERFORATION StIATMRY RE LOG: SNS JEWI3RY LOG 07/29/02 ANGLE AT TOP PERF: 18' @ 9960' Note: Refer to Production DB for historical pert data SIZE SPF KIEiVAL OpnISgz SHOT SQZ 3-318" 6 9960-10030 O 11/19/02 3-318" 6 10056-10076 O 11/19/02 3-3/8" 6 10088-10102 O 11/19/02 3-3/8" 6 10135 - 10165 O 07/30/02 3-3/8" 6 10175 - 10186 O 07/30/02 3-318' 6 10196 - 10246 O 07/30/02 PBTD 10300' 7' LNR, 26#, L-80 BTC -M, .0383 bpf, D = 6.276' 10346' PSI -09 SAFETY NOTES: WELL REQUIRES A SSSV ' ff -E� 13-3/8" TAM PORT COLLAR 2'16T 7-58' X 7- XO. D = 6276' 17-5/8- X 7" XO, D = 6.276' T HFS RNP D=5963' 974$' 7"HFS RNIP, D=5.963' 9766' 7" HES RN NP, D = 5.770" 9766' 7" PRN RUG (01/28119) 9788' T WLEG, D = 6.276' 9766' B -MD TT LOGGED 07/30/02 9813' 9-5/8" X 7" BKR TEBK SLV w 7ZXP LTP, 1) 4---982T REFORMAT PER TALLIES 9-5/8' X 7- BKR HMC LNR HGR, D = DATE REV BY C.OATEJTS DATE REV BY ODMMENTS 07122102 N27E INITIAL COMPLETION 03/05115 PJC REFORMAT PER TALLIES 07130/02 TMWKK FERFS & ELMD TF LOGGEr 03123115 GJB/ PJC PULL PRN PLUG 09IO2IO2 SVGrTP CHANGE KBE 01131119 CJWJMD SET PRN FLOG (01/28119) 11/19/02 CAO/KK ADPERFS 05/06119 JM- EDIT TO BF, 7" LNR DET/ -LS, 20" COND DB -n 02111111 MB/JND ADDED SSSV SAFETY NOTE 02127115 NLW/JM SEP PRN PLUG (02/20/15) PRIAHOE BAY UJfT Nt3L: PSI -09 PEMV No:`2021240 API No: 50-029-23095 1 SEC 15, T11 R R15E, 3876' NSL & 4351' NE BP Exploration (Alaska) Proposed Schematic TREE= 7-1116'5K CIN WELIEAD- 13-W 5K FIC ACTUATOR= _ OKB. B" = 50.55 BF. ELW = 2Z _.—_-- KOP= 1400 IvAn9k= 51'®5539 TAtu w= 10255 When TVD= 8500 SS L-80 Minimum ID = 5.770" @ 9755' IT TBG, 28/, L-6070.0383 bpf, D= 6276' H 9769• I PERFORATION SUMMARY FEE LOG: SWC JEWELRY LOG 0729'02 ANGLEAT TOPFE F: 16• @ 9960' Nab: Rater b Rnduckon OB for hebrical pert data SIZE SPFJ NIERVAL JOPVSW SI -10T SOZ 3-38'n10165 01/31119 CJN 030 O 11n982 338'0076 02711/11 MBIJf.D ADDED SAFETY NOTE O 11n982 0227/15 NLWAC SET PRN PLUG(02rMI5) 3-318'0102 O lIn9N2 3318'0165 O =3082 3-318•166 O 07rJW23.38•246 O 07MM FBTD LHR, 268, L-80 10345' PSI -09 I SAFETY NOTES: W B L REQUIRES A SSSV • X T XO, D= 6.276' 965W -17•F6 RHP. D=5.983• 9673• FBRD=e.zro• 97t3• ssa'xr BIwsA6L-3 9783' T 11FS R NP, D= 5.963• 9766• rHEBmw,D-5.T70 97� T md1 FLl1G (0128(19) 9766• 7- vZm D = 6.276' DATE REV BY I OOM,@BS DOTE I REV BY COMERS 072282 N27E INITIALCOMPLLTION 10=51151 PJC JREPORT TPER TALLIES 07/3402 TAWKK PHRF589.kDTT LOGGED 0323/15 GJfVP FUIRRN FT.US 0982/02 SVCJTP 09ANGEKBE 01/31119 CJN SErFTRf4R.l1G(0128/19) 11119102 CAO/W ASS 02711/11 MBIJf.D ADDED SAFETY NOTE 0227/15 NLWAC SET PRN PLUG(02rMI5) PTiIODE BAY LIMIT WELL P%09 R$66T Na: OZM240 AR Pb: 50-029-23095 SEC 15, T11µ RISE 387V NSL 84351' VAL BP Upbraban (Alaska) Notional Abandonment Schematic 417E FEV BY COM. NTS I DATE I REV BY Imketer7s 07122/02 N27E INT8ILCONPLEIION 03105115 PJC �4TPMTALLES 07x"2 TWW FEWS 8 ELMJ7T LOGO 0323175GW RLL PfN0.UG W" MUM SVCRP OUNGE KBE 07137/79 SET PRN RUG(0128119) 11119'02 CAOW ACPBFS 02/11/11 MB/JM Am® sssV SAFETY NOTE 0287115 w sEr PRN R.UG (0220115) PFI -C DEBAY I2ar WELL M09 FBW 170: 2021200 AP No: 50029-23095 MIR RI5E 3876 NSL 84351' VWL SP EKpbraUon (Alska) Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, January 26, 2019 11:46 AM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan; Smith, Travis T (CONOCOPHILLIPS); Worthington, Jessica Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector PSI -09 (PTD# 2021240) Failed MIT -IA All, Injector PSI -09 (PTD #2021240) was shut in and freeze protected on 12/29/18 after it was made Under Evaluation for failing an AOGCC MIT -IA. The well passed a PPPOT-T and PPPOT-IC on 01/21/19 confirming the leak is downhole. The well is now classified as NOT OPERABLE until barriers are restored. Slickline is scheduled to secure the well with a TTP then a future E -line Leak Detect Log will be performed once a unit is available. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GW40,Well Integrity Engineer Sent: Saturday, WcRmber 29, 2018 4:25 PM To: AK, OPS EOC Specia ' s <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.c >; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2Field PTL@bp.com>; AK -,-OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com K, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.co Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Nottingham, Derek rek.Nottingham@bp.com>; Ohms, Danielle H <Danielle.Ohms@bp.com>; Rupert, C. Ryan <Ryan.Rupe BP.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; Summers, Matthew <Matt .Summers@bp.com>; Worthington, Jessica <Jessica.Worthington@bp.com>;'chris.wallace@alaska.gov' <chris. Ilace@alaska.gov>; Atkinson, Tim <Tim.Atkinson@bp.com>; Fore, Glenn J <Glenn.Fore @bp.com> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.co AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProje WelllntegrityEngineer@bp.com AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; HibBe , Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t�G�t�� I I r 4I I �7 DATE: Monday, January 14, 2019 P.I. Supervisor (� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. PSI -09 FROM: Bob Noble PRUDHOE BAY UNIT PSI -09 Petroleum Inspector See: Inspector Reviewed Bye� P.I. Supry V„z— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -09 API Well Number 50-029-23095-00-00 Inspector Name: Bob Noble Permit Number: 202-124-0 Inspection Date: 12/29/2018 ' Insp Num: mi[RCN181229114843 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -09 Type Inj w. TVD- s0s4 Tubing 690 694 694- 694 PTD . zonzao (Type Test SPT Test psi 2008 IA 2 2540 570 - 784 " — -- BBL Pumped: 1.2 BBL Returned: o OA 6 100 - 10 J 6 Interval) REQVAR P/F F — Notes: AA 4F.001 requires 24 month MIT -IA to max injection pressure (1820). The T/V0+690/330/6 when 1 arrived. Ryan Holt said the IA can a gas cap and ask if they could bleed it off and I told them they could. After bleeding off the T/V0=690/2/6. They were going to test the IA at 2700 psi. At 2540 psi the pressure stopped increasing. A liquid leak rate of 1/4 bpm @ 2540 psi was established. The test was held 30 min to watch it bleed down. Monday, January 14, 2019 Page I of 1 . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,November 21,2016 Zp P.I.Supervisor �r/ rC(� 1/ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. PSI-09 FROM: Bob Noble PRUDHOE BAY UNIT PSI-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry<Tge— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI-09 API Well Number 50-029-23095-00-00 Inspector Name: Bob Noble Permit Number: 202-124-0 Inspection Date: 11/15/2016 Insp Num: mitRCN161115140607 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-09 Type Inj TVD 8034 . Tubing 637 635 , 1 637 - 637 - -- PTD 2021240 JType Test SPT Test psi 2800 ,. IA 200 2800 - 2778 - 2767 - ------- - --- Interval REQvAR P/F P ✓ OA 1 33 - 35 . 35- Notes: T x IA corn.2 year MIT to maximum anticIpated injestion pressure. Injection order no.4F.001 SCANNED 1:1 P` '' 2 I '. Monday,November 21,2016 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, March 28, 2015 3:10 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL; AK, OPS PCC EOC TL;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites;AK, OPS FS2 Field OTL; AK, OPS FS2 Field OTL; Farinez,Javier; Morrison, Spencer;Wallace, Chris D (DOA); Regg, James B (DOA); AK, OPS FS2 Field OTL Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: OPERABLE:Water Injector PSI-09 (PTD#2021240) Plug pulled post AA obtainal Attachments: image001 jpg; aio4f-001.pdf All, BP has received approval to operate Water Injector PSI-09 (PTD#202124)from the AOGCC.The well will now inject under AA AIO 4F-001 for slow tubing by inner annulus communication with the requirements of flagging all bleeds and a two year witnessed MIT-IA cycle.At this time,the well has been reclassified as Operable, and has been added to the monthly AOGCC Injector Report. Please use care when putting the well on injection as the annuli are fluid packed and susceptible to thermal effects. Thank you, Laurie Climer (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator �NN�� GwDooaIWei is SC �7 M Y Organizat:on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, February 17, 2015 1:03 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL;AK, OPS PCC EOC TL;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; AK, OPS FS2 Field OTL;AK, OPS FS2 Field OTL; Farinez,Javier; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: NOT OPERABLE:Injector PSI-09 (PTD#2021240)Inner Annulus Repressurization Attachments: image001 jpg; image002.png; PSI-09 Wellbore Schematic.pdf;Injector PSI-09 (PTD# 2021240) TIO Plot 02-15-15.docx All, Injector PSI-09(PTD#2021240) has exhibited signs of inner annulus repressurization.A passing MIT-IA was performed on December 09, 2014 to 2,500 psi. The well has been reclassified as Not Operable and needs to be shut in and freeze protected until further diagnostics have been completed.The well will be added to the Quarterly Not Operable Injector Report. Plan Forward: 1. Slickline: Set Tubing Tail Plug, MIT-T, LDL if fails A copy of the wellbore schematic,TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Kevin Parks (AItCI Batt' Latu is Chilli i BP Alaska-Well Integrity Coordinator GAGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well n -• •ordinator Sent: Monday, January 26, 2015 8:4 • To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Leas; • •PS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations e. - --ad; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells •• - u•r; G GPB FS2 Drillsites; AK, OPS FS2 Field OTL; AK, OPS FS2 Field OTL; Farinez, Javier; Morrison, Spencer; 'Regg, James B •9 ' (jim.regg@aalaska.gov)'; 'chris.wallace@alaska.gov' • • Injector PSI-09(PTD#2021240)TIO Plot 02-15-15 Wel o51la 3000 t—0 440 20 00 000 On CW .1.1514 11.2211 1'.1514 11%, `.14 1220'14 1:1` 1315 _1 _ 0 01'+1'. 02C-'5 i...41. PSI-09 (PTD #2021240) Injection Plot 02-15-15 1.a{ 1600 000 1.500 1400 300 1.200 -10.000 -60.000 10' • 1( 900 1 .•2.100 Q 0M on 700 100 -40000 file 000 -30000 ACC 2000 320 224 ,0000 11 IS 4 '11214 110014 100614 '11314 12214 12.77 14 0123'15 211015 C1 2.15 012115 013115 02,7.15 421415 • TREE= 7-1/16"5K CW WELLHEAD=13-5/8"5K FMC P S 1-0 9 SAr,fY NOTES: WELL REQUIRES A SSSV. ACTUATOR= KB.ELEV= 50.55' BF.ELEV= 22' KOP= 1400' Max Angle= 51 @ 5536' 959' H13-3/8"TAM PORT COLLAR I Datum MD= 10255' Datum TV D= 8500'SS 2161' —17-5/8"X 7"XO, ID=6.276" I 2162' J-1 7"CA MCO DB NIP, ID=6.000" 2164' —17-5/8"X 7"XO, ID=6.276" I 13-3/8"CSG,68#, L-80, ID=12.400" —I 5588' 7-5/8"TBG,29.7#,.0459 bpf,ID=6.875" —I 9647' I 9647' 1-17-5/8"X 7"XO, ID=6.276" 9659' -f7"HES R NIP, ID=5.963" Minimum ID = 5.770" @ 9755' 11rI 9673' J—IPBR,ID=6.270"I 7" HES RN NIPPLE 9713' —17"X 9-5/8"BKR SA BL-3 PKR, ID=6.0" I I 9743' —17"HES R NIP, ID=5.963" I I I 9755' I-17"HES RN NIP, ID=5.770" 7"TBG,26#,.0383 bpf, ID=6.276" —I 9768' I 9768' 1-17"WLEG, ID=6.276" 9766' —I ELMD TT LOGGED 07/30/02 PERFORATION SUMMARY REF LOG: SWS JEWELRY LOG 07/29/02 ANGLE AT TOP PERF: 18 @ 9960' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9960- 10030 0 11/19/02 3-3/8" 6 10056- 10076 0 11/19/02 3-3/8" 6 10088- 10102 0 11/19/02 3-3/8" 6 10135- 10165 0 07/30/02 3-3/8" 6 10175- 10186 O 07/30/02 3-3/8" 6 10196- 10246 O 07/30/02 $ 9827' (—{7"X 9-5/8"BKR ZXP LNR TOP PKR W/TIEBACK SLV 9-5/8"CSG,47#,L-80,ID=8.681" —1 9920' PBTD — 10300' 11111111 111111111111111 7"LNR,26#,L-80, .0383 bpf, ID=6.276" —I 10345' 144444481 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/22/02 DAC/KK ORIGINAL COMPLETION WELL: PSI-09 07/30/02 TMN/KK IPERFS&ELMD TT LOGGED PERMIT No:'2021240 09/02/02 SVC/TP CHANGE KBE API No: 50-029-23095 11/19/02 CAO/KK ADPERFS SEC 15,T11N,R15E,3876'NSL&4351'WEL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,January 26, 2015 8:47 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS PCC EOC IL;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites;AK, OPS FS2 Field OTL;AK, OPS FS2 Field OTL; Farinez,Javier; Morrison, Spencer; Regg, James B (DOA);Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: UNDER EVALUATION:Injector PSI-09 (PTD#2021240)TxIA diagnostics Attachments: image001jpg; PSI-09 TIO and Injection Plots 01-26-15.docx; PSI-09 Wellbore Schematic.pdf All, Water Injector PSI-09 (PTD#2021240) has begun exhibiting signs of tubing by inner annulus communication.A passing MIT-IA was executed December 09,2014 and a passing PPPOT-T performed the day prior. Per a conversation with the AOGCC,the well has been reclassified as Under Evaluation to further assess the well's mechanical condition with regards to potentially filing for an AA. Plan Forward: 1. DHD: Bleed inner annulus down, record BUR 2. WIE:Additional diagnostics as needed A copy of the wellbore schematic,TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate:Jack Disbrow) BP Alaska-Well Integrity Coordinator G�/�/ G!4saI4'J�IIS Y Y Organization SCANNED JAN 2 8 2015 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 ( ( 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. dOJ. - L:L Lþ. Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 RESCAN DIGITAL DATA ~iskettes, No. J 0 Other, No/Type: 0 Color Items: 0 Greyscale Items: 0 Poor Quality Originals: 0 Other: NOTES: BY: Helen ~- Project Proofing BY: Helen CMari_0 Scanning Preparation ~ x 30 = hD BY: Helen ~ Production Scanning D Rescan Needed 111111111111111111 OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: + 0 Other:: J ~ = TOTAL PAGES tz.. =i b~~~~t doe~~lf ro~~r /'e;t) 141f? 1. . 1111111111111111111 Stage 1 Page Count from Scanned File: 71f. (Count does include rover sheet) Page Count Matches Number in Scanning Preparation: BY: Helen (.,-f\Aaria ') If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: V YES Date:1. 3O/(Jff YES NO NO /s/ rn rJ Date: Is/ I , II I Î Date: Is/ Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 E JAN 2 4 Z01` Mr. Tom Maunder � �� f4 { Alaska Oil and Gas Conservation Commission JAN 333 West 7 Avenue 4 GIs Coos. C ; , - '4 arf Anchorage, Alaska 99501 Iflcrimg Subject: Corrosion Inhibitor Treatments of GPB PSI 4\C) t� Dear Mr. Maunder, s 1 , o 9 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB PSI 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, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal PSI -01 2021450 50029231040000 NA 1 NA 5.10 10/25/2010 PSI -05 2031390 50029231740000 NA 1 NA 5.95 10/24/2010 PSI -06 2020790 50029230820000 NA 12.3 NA 45.90 10/25/2010 PSI -07 2031480 50029231770000 NA 1.2 NA 6.80 10/24/2010 PSI -08 2021720 50029231140000 NA 1.3 NA 6.80 10/23/2010 4' 09 2021240 50029230954000 NA 1.8 NA 12.80 10/23/2010 ' PSI -10 2021590 50029231100000 NA 0.7 NA 3.40 10/23/2010 MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 To: Jim Regg P.1. Supervisor ~~ ~( Z~ (r J SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA)1NC PSI-09 FROM: Jeff Jones PRUDHOE BAY UNIT PSI-09 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~}a~-- Comm Well Name: PRUDHOE BAY UNIT PSI-09 Insp Num: mitJJ100721173517 Rel Insp Num: API Well Number: 50-029-23095-00-00 Permit Number: 202-124-o Inspector Name: Jeff Jones Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PSI-09 ~ yT p rie I j. W •~VD 8034 IA~ ~O 2400 ~ 2340 2365 ~ 2365 P.T.D zo212ao ~TypeTest SPT! Test psi zoo9 Op o 80 60 8o so ~ Interval 4YRTST p~F P ~ TUbing ~ 1660 1660 ~ 1660 1665 1660 ~ Notes: 3 BBLS methanol pumped. 1 well inspected; no exceptions noted. , `/ il,ir( .ir - Monday, July 26, 2010 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regglIDalaska.gov; phcebe.brooks~alaska.gov; tom.maurxler~ialaska.gov; dce.aogcc.prudhce.bayl@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP F~cploration (Alaska), Inc. Prudhoe Bay !PBU / PSI Pad 714110 Jerry Murphy Jeff Jones Packer Pretest Initial 15 Mn. 30 Min. Well PSI-06 T In'. W TVD 7,8 7 Tubi 1,820 1,810 1,810 1,810 Interval 4 P.T.D. 2020790 T test P Test 1968 550 2,610 2,585 2,585 P/F P Notes: MIT-IA to 2600 psi for 4 year UIC OA 180 360 360 360 Pum 3.1 bbls MEOH to achieve test Well PSI-08 T In'. W TVD 8,014 Tubi 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2021720 T test P Test 2003.5 Casi 675 2,610 2,590 2,585 P/F P Notes: MIT-IA to 2600 psi for 4 year UIC OA 250 500 500 500 Pum 2.9 bbls MEOH to achieve test Well PSI-09 T In'. W TVD 8,034 T 1,660 1,660 1,660 1,665 Interval 4 .T.D. 2021240 T test P Test 2008.5 0 2.400 2,340 2,365 P/F P Notes: MIT-IA to 2400 psi for 4 year UIC OA 0 80 60 80 Pum 3 bbls MEOH to ach~ve test 45 Min. Well T In'. TVD Tubi 1,660 Interval P.T.D. T test Test C 2,365 P/F Notes: Extended PSI-09 test for 15 minutes OA 80 Well PSI-10 T In'. W TVD 8,056' T 1,75D 1,750 1,760 1,760 Interval 4 P.T.D. 2021590 T test P Test 2014 Casi 0 2,500 2,485 2,480 P/F P Notes: MIT-IA to 2500 psi for 4 year UIC OA 0 250 250 250 Pumped 3.7 bbls MEOH to achieve test psi ~~ ~~-~ ~(7 ~~~~7 TYPE INJ Codes TYPE TEST Codes `/ (j 1 ~ INTERVAL Codes D =Drilling Waste M =Annulus Monitoring ~ ~~ '~ I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Irrtemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU PSI-06 OB 0910 07-04-10.x1s MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .-----, \ ~r!f¿'I' , I, í(Zf;/ DATE: Wednesday, July 05, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) fNC PSI-09 PRUDHOE BAY UNIT PSI-09 ~ \ ~lt ;1\)ð- FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By:_ P.I. Suprv ':"J3'f2- Comm Well Name: PRUDHOE BAY UNIT PSI-09 API Well Number 50-029-23095 -00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060701135354 Permit Number: 202-124-0 Inspection Date: 7/1/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I PSI-09 ¡Type Inj. i W TVD ! 8035 I IA 40 i 2195 2175 I 2175 I Test psi i 2195 ~TQA i I P.T. ¡ 2021240 ¡TypeTest i SPT 400 680 680 680 I I Interval 4YRTST P/F P -"// Tubing 1400 : 1400 1400 1400 i I ~ Notes 3 bbl's pumped, Good test. NON-CONFIDENTIAL '. '1('>' "\,¡ \',-"" t~:~1Ù~~ ,;5~t:\~_"J ç', -, C;;' t Wednesday, July 05, 2006 Page 1 of 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) \j ~ ~\'\\1 DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Sf ú-d. ) J \A0 ~ )-, API No. 50-029-23095-00-00 ~~_/ Permit to Drill - 2021240 Well Name/No. PRUDHOE BAY UNIT PSI-09 Operator BP EXPLORATION (ALASKA) INC MD 10343 ~ TVD 8635./' Completion Date 7/30/2002 ~ Completion Status 1WINJ Current Status 1WINJ ~-~----- REQUIRED INFORMATION DATA INFORMATION Mud Log No Samples No Directional Survey Yes -----~---~.- --.------ (data taken from Logs Portion of Master Well Data Maint) ~ Log Log Run Interval OH/ ~edia No Start Stop CH Received Comments ------.- Col 1 7200 9900 Case 8/30/2002 ~Blu 7310 10294 ~ 11/8/2002 0 10343 Open 8/23/2002 0 10343 Open 8/23/2002 56 10309 Case 2/11/2003 0 10343 Open 8/23/2002 MWD 2 Col 7284 10314 Open 8/9/2002 Best DT Final Result Anisotrophy Processing 5 Blu 9600 10246 Case 8/16/2002 Jewelry Log 56 10309 Case 2/11/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 6/13/2002. 7320 10346 ~"'- 11/8/2002 LDWG edit of relabeled DSllog 5 Blu 9600 1 0246 Case 12/10/2002 Jewelry Log 25 Blu 7310 10294 ~' 11/8/2002 Delta T comp 1 Blu ~ 10210 Case 8/16/2002 Static Bore Hole Pressure PSP 0 1 0343 Open 8/23/2002 MWD 7284 10314 Open 8/9/2002 5 Col 1 7200 9:00 -6ase---8f30t200Z--- Ù4í l¡ (Å j Q., \ WI., (<1 1,2,3 57 10343 Open 6/2/2003 ------.------- Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Ty~Med/Frmt -t:6g 9ig ~ 'Rpt Rpt Rpt ~ ~ c...EI:J D \..2Ó C ~ ~ ~ ~ó ~C Electr Dataset Number Name - --- ------ --------- Sonic Sonic .-Ðiféctional Survey Directional Survey LIS Verification Directional Survey <...sée Notes tÃ'êmperature '-'tf509 LIS Verification lA4290 See Notes ~~mperature ~c Pressure -9frãctional Survey tAó994 Sonic ..log CÐ1'nent [valuation (...;(D C Asc ~02 LIS Verification DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021240 Well Name/No. PRUDHOE BA V UNIT PSI-09 MD 10343 tD C Pdf ~ C Pdf C Pdf V ED C Pdf TVD 8635 Completion Date 7/30/2002 ~2002 Induction/Resistivity 12002 Induction/Resistivity 12002 Density 12002 Density ED C Pdf 12002 Neutron ..É.9-, C Pdf _~02 Neutron ~ ) Log ~ Temperature Spinner Gradiometer Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? v([E) Chips Received? V / N - Analysis Received? Comments: ~ Compliance Reviewed By: ~ Operator BP EXPLORATION (ALASKA) INC Completion Status 1WINJ Current Status 1WINJ 25 Final 200 10343 Open 6/2/2003 25 Final 200 8635 Open 6/2/2003 25 Final 200 10343 Open 6/2/2003 25 Final 200 8635 Open 6/2/2003 25 Final 200 10343 Open 6/2/2003 25 Final 200 8635 Open 6/2/2003 25 Blu 7700 10228 Case 7/23/2003 25 Blu 7700 10228 Case 7/23/2003 25 Blu 7700 10228 Case 7/23/2003 Sent Sample Set Number Comments Received Daily History Received? /~/N IG/N Formation Tops API No. 50-029-23095-00-00 UIC V ----------- MWD-ROP, DGR, EWR- MD MWD-DGR, EWR- TVD MWD-DGR, SLD, CNP-MD MWD-DGR, SLD, CNP- TVD MWD-DGR, SLD, CNP-MD MWD-DGR, SLD, CNp. TVD Temperature Warmback w/Spin ner/PFCS/G radio/PB MS ~ Temperature Warm back w/Spinner/PFCS/Gradio/PB MS Temperature Warmback w/Spinner/PFCS/Gradio/PB MS --------- ---------~ Date: d2 ~.~'-I== '\ dOd- -/~Ì-I Jd~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue~ Suite 100 ~chorage, Alaska 99501 May 21,2003 RE: MWD Formation Evaluation Logs: PSI-09, AK-MW-22104 PSI-09: Digital Log Images 50-029-23095-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~~;" ~~~ i'V JUN 02 ~~~ \Y\~ ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X 1404' FNL, 4351' FEL, Sec. 15, T11N, R15E, UM At top of productive interval 2446' FNL, 1410' FEL, Sec. 09, T11N, R15E, UM At effective depth 2358' FNL, 1456' FEL, Sec. 09, T11N, R15E, UM At total depth 2348' FNL, 1462' FEL, Sec. 09, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 708052,5966180) (asp's 705589, 5970351) (asp's 705540, 5970438) (asp's 705534, 5970448) 10343 feet 8635 feet Plugs (measured) Effective depth: measured 1 0299 feet Junk (measured) true vertical 8593 feet Casing Length Size Cemented Conductor 108' 20" 260 sx Arctic Set (aprox) Surface 5553' 13-3/8" 1329 sx AS III Lite, 601 sx Class 'G' Intermediate 9889' 9-5/8" 618 sx Class 'G' Liner 530' 7" 145 sx Class 'G' Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 51 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number PSI-09 9. Permit number / approval number 202-124 10. API number 50-029-23095-00 11. Field / Pool Prudhoe Bay Oil Pool RECEIVED DEC 1 9 2002 MeasureMllí\OU.& Gas9wJs~- ~ 143' Anchorage 143' 5588' 9920' 9813' - 10343' 4646' 8231' 8129' - 8635' Perforation depth: measured Open Perfs 9960'-10030',10056'-10076', 10088'-10102', 10135'-10165', 10175'-10186', Open Perfs (continued) 10196'-10246'. true vertical Open Perfs 8269'-8335',8360'-8379',8391'-8404', 8436'-8464', 8474'-8484', 8494'-8542' Tubing (size. grade, and measured depth) 7-5/8" 29.7# L-80 @ 2161' MD. 7-5/8" x 7" XO @ 2161'. 7" x 7-5/8" XO @ 2164'. 7-5/8" 29.7# L-80 @ 9647' MD. 7-5/8" x 7" XO @ 9647'. 7" 26# L-80 @ 9768'. Packers & SSSV (type & measured depth) 7" X 9-5/8" Baker SABL-3 Packer @ 9713' MD. 7" X 9-5/8" BKR ZXP LNR TOP PKR WI TIEBACK SLY @ 9827'. 7" Cameo DB NIP @ 2162'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl 109,916 108,395 16. Status of well classification as: Prior to well operation 11/16/2002 Subsequent to operation 11/28/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ....ð-d~~~ T~e: Techn""IAssistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 . Casing Pressure Tubing Pressure 2189 2100 Suspended - Service WATER INJECTION Date December 05. 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLtCA TE ~ .......:: 11/01/2002 11/02/2002 11/04/2002 11/18/2002 11/19/2002 12/02/2002 12/04/2002 ( ( PSI-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS INJECTIVITY TEST: AC-FLUID LEVEL INJECTIVITY TEST: AC-MITIA INJECTIVITY TEST: AC-MONITOR NEW WELL POST: PERFORATING NEW WELL POST: PERFORATING NEW WELL POST: SSSV C/O OR STROKE TESTEVENT --- Inj Press, psi: 1,986 Type: PW Vol: 104,864 EVENT SUMMARY 11/01/02 T/I/O = 1200/360/400, IA FL @ SURFACE POST INJECTION START-UP. 11/02/02 T/I/0=1160/380/380 MITIA TO 2060 PSI. PASSED (AOGCC WITNESSED, JEFF JONES). INITIAL IA FL AT SURFACE. MITIA LOST 0 PSI IN THE FIRST 15 MINUTES AND GAINED 5 PSI IN THE SECOND 15 MINUTES FOR A GAIN OF 5 PSI IN 30 MINUTES. PUMPED 4 BBLS OF 60/40 METHANOL DOWN IA. FINAL WHP's = 1160/340/380. 11/04/02 TIO= NA/250/250 (POST MITIA) 11/18/02 11/19/02 PERFORATE INTERVALS: 10088'-10102' ,100561-100761, AND 99851-100301. TAG BOTTOM AT 102401. PERF HSD GUNS - 3-3/8" PJ 3406 HMX - 6SPF - 60 DEG RANDOM. API SPECS WHEN SHOT IN 4.5" CASING: EHD = 0.45" & PEN = 38.6". WELL SHUT IN PRIOR TO RIH AND ON VAC AFTER FIRST TWO RUNS - WELLHEAD PRESSURE SLOWLY INCREASED TO 900 PSI AFTER INTERVAL 100101-10030' PERFED. NOT MUCH ADDITIONAL INCREASE AFTER 9985'- 10010' PERFS. STAND UNIT BACK FOR THE NIGHT. BACK IN THE MORNING TO SHOOT LAST 25' GUN. «< PAD OPERATOR TO BRING WELL ON INJ OVER NIGHT »> DAY TWO: PERFORATE LAST 25' INTERVAL. WELL ON INJECTION OVERNIGHT. SHUT IN TO RIH. TAG BOTTOM AT 10240'. PERF HSD GUNS - 3- 3/8" PJ 3406 HMX - 6SPF - 60 DEG RANDOM. API SPECS WHEN SHOT IN 4.5" CASING: EHD = 0.45" & PEN = 38.6". PERFORATE: 9960'-9985'. REFERENCE SLB JEWELRY LOG DATED 29-JUL Y -2002. ***PAD OPERATOR NOTIFIED TO POI*** 12/02/02 SET 7" A-1 CAMCO ISSSV W/ DB-6 LOCK @ 2141' SLM. (IP=950. OAL=49".) GOOD CLOSURE TEST. «< RETURNED WELL FOR INJECTION »> 12/04/02 TESTEVENT --- INJECTION PRESSURE, PSI: 1,986 TYPE: PW VOL: 104,864 BWPD. Page 1 PSI-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Fluids Pumped BBLS 2 3 4 9 DIESEL FOR SURFACE PRESSURE TEST (3 TESTS) METHANOL 60/40 METHANOL WATER TOTAL ADD PERFS 11/18 -19/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING 3-3/811 3406-PJ, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9960' - 10030' 10056' - 10076' 10088' - 10102' Page 2 12/09/02 ScblulD~epgep NO. 2586 . Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ Well Job# Log Description Color Date Blueline Sepia Prints CD 11/29/02 1 10/26/02 1 10/17/02 1 11/21/02 1 11/19/02 1 07/29/02 1 10/23/02 1 10/28/02 1 10/30/06 1 10/25/02 1 10/30/02 1 D.S.4-01 /70-0</d. D.S. 1-20 I'? d. - jI-J to A-12 1 ~1)'I/Î H-14A j 9<t -tlt~ PSI-06 aM-o - PSI-09 ~o d- I õ? L NK-42 } ~-) o~ R-14 I ;S.-Oò;). D.S.7-21 I. c3~ ()) Cj D.S. 2-30B ~ 00- fa (¡; D.S.9-39 J 11-0 J ~ PRODUCTION PROFILE LDL PRODUCTION PROFILE LDL SBHP SURVEY BASETEMP~EWELRYLOG PROD PROFILE/DEFT LDL LDL LDL INJECTION PROFILE ~ PLEASE ACKNOWLEDGE RECEIPT BY .SIGNINÂ~. ^E}~~ ONE COpy EACH TO: BP Exploration (Alaska) Inc. REvr:J V t:U Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: DEC 1 0 2002 Alaska Oii & Gas Cons. Commission AnCiîorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AnN, Beth ~ - Recél;~~~~-~ ~ ¿~ Ûbp~ Schlumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description PSI-09 ðJ:B4 22346 OH EDIT DSI (PDC) PSI-09 22346 DSI PSI-09 22346 DSI DEL TA-T COMP PSI-10 do~-15, 22423 OH EDIT BHC (PDC) PSI-10 J, 22423 SONIC LOG PSI-10 22423 SONIC LOG SSTVD Date 07/18/02 07/18/02 07/18/02 08/28/02 08/28/02 08/28/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~JL~ I> "t:. rVl::, () NOV 08 Date Delivered: :J;;¡TImi~s~on J1JaGta Œ'~ & G¡Y~ ÞiTi~!1~ij'{; Blueline 11/04/02 NO. 2528 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive~ GJ)oo~ ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 11/05/02, Put on Injection 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned IBI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3876' NSL, 4351' WEL, SEC. 15, T11N, R15E, UM At top of productive interval 2834' NSL, 1410' WEL, SEC. 09, T11 N, R 15E, UM At total depth 2933' NSL, 1462' WEL, SEC. 09, T11 N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 50.55' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/3/2002 7/17/2002 7/30/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10343 8635 FT 10299 8593 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, LWD, USIT, 23. CASING SIZE 34" X 20" 13-3/8" 9-518" 7" WT. PER FT. 91.51# 68# 47# 26# 27. Date First Production October 28, 2002 Date of Test Hours Tested 11/4/2002 Classification of Service Well Gas Cap Injection 7. Permit Number 202-124 8. API Number 50- 029-23095-00 9. Unit or Lease Name Prudhoe Bay Unit 302-330 10. Well Number PSI-09 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2162' MD 1900' (Approx.) Dipole Sonic CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 42" ,260 sx Arctic Set (Approx.) 35' 5588' 16" 1329 sx AS III Lite, 601 sx 'G' 31' 9920' 12-1/4" 618 sx Class 'G' 9813' 103431 8-1/2" 145 sx Class 'G' SIZE 7-518",29.7#, L-80 x 7", 26#, L-80 9768' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect wi 138 Bbls Diesel GRADE H-40 L-80 L-80 L-80 25. MD TVD 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 10135' - 10165' 8436' - 8464' 10175' - 10186' 8474' - 8484' 10196' - 10246' 8494' - 8542' 26. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL 26,792 WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 738 24-HoUR RATE OIL-BBL GAs-McF AMOUNT PULLED TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 9713' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit R!!e I V E D No core samples were taken. 28. Form 10-407 Rev. 07-01-80 ,p RBOMS BFt (;{ NOV 0 6 2002 AldSKa 01& Gas Ooos. Commission - Anchorage Submit In Duplicate 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 1 7300' 5868' West Sak 2 7954' 6420' West Sak 1 8166' 6611' Colville Mudstone 3 8389' 6814' Colville Mudstone 2 9203' 7555' Colville Mudstone 1 9317' 7660' HRZ 9749' 8068' Base HRZ IlCU I Zone 3 9959' 8268' Zone 2C 10026' 8332' Zone 1 10186' 8484' Kavik 10292 8586' 31. List of Attachments: 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RI~Ø'VED NOV 062002 AlasKa Off.' Gas Gons. Commission Anchorage Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~- Title Technical Assistant Date I ¡.. D5 ..Ó~ PSI-09 202-124 302-330 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner fI-.1A1 DATE: November 2, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPXA Petroleum Engineer ~ Q1yý\ PSI Pad r3Y \\\",07 PSI-01, 08, 09, 10 FROM: Jeff Jones Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. T.V.o. 8040 Tubing 900 900 900 900 Interval Test psi 2010 Casing 150 2090 2090 2085 P/F OA 200 450 450 450 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 70 deg. F Well PSI-01 Type Inj. S P.T.D. 202145y Type test P Well PSI-08 Type Inj. S TV.o. 8014 Tubing 1175 1340 1340 1350 Interval P.T.D. 202172'l'Type test P Test psi 2004 Casing 80 2110 2090 2110 P/F OA 220 420 420 420 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 72 deg. F Well PSI-09 Type Inj. S P.T.D. 202124~Type test P T.V.D. 8034 Tubing 1160 1000 1160 1150 Interval Test psi 2009 Casing 380 2060 2060 2065 P/F OA 380 560 560 560 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60140 methanol. S riser temp: 76 deg. F Pretest Initial 15 Min. 30 Min. 45 Min. Well PSI-10 Type Inj. S TV.o. 8056 Tubing 850 850 850 850 850 Interval P.T.D. 2021590 /Type test P Test psi 2014 Casing 0 2090 2085 2080 2080 P/F ~ OA 320 580 580 580 580 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 74 deg. F Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details November 2, 2002: I traveled to BPXA's PSI Pad inthe Prudhoe Bay Field to witness initial MIT's on water injection wells PSI-Ol, PSI-08, PSI-09 and PSI-lO. Roland Johnson was the BPXA representative today and he performed the tests in a safe and proficient manner. The pre-test pressures were observed for 15 minutes and found to be stable. The stàndard annulus pressure test was then performed, with all four wells passing the MIT. Well PSI-IO was monitored an additional 15 minutes to further demonstrate integrity and the casing pressure stabilized at 2080 PSI. The four well houses were inspected with no exceptions noted. Summary: I witnessed successful MIT's on BPXA's Prudhoe Bay Field water injection wells PSI-Ol, PSI-08, PSI-09 and PSI-IO. Four well house inspections; no exceptions noted. .1.T.'s performed:! Attachments: Number of Failures: Q Total Time during tests: 5 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU PSI 01,08,09,10 11-2-02 JJ.xls I E I E I E I E 11/4/2002 08/29/02 Scblumbepger NO. 2380 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ Well Job# Log Description Color Date Blueline Sepia Prints CD 07/30/02 1 07/18/02 2 W-25 I ~'6-1J J PSI-09 ðC"td.-1 ~'-1 22363 RST -SIGMA 22345 US IT ~ Date Delivered: REceiVED AUG 8 G2002 Alaaka on & Gas Cons Co .. Anchorag~ mml8SlOn Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ReœiVed~ c.. (h f -< ^ ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface r-ëGMP'LË.i¡â¡:Cl ",' ::t 3876' NSL, 4351' WEL, SEC. 15, T11N, R15E, UM l DP.TE ,f, :,1~., '., At top of productive interval t. í', '-3ð ,p~ ~aJ";~ 2834' NSL, 1410' WEL, SEC. 09, T11N, R15E, UM 2' v, E~~, ' J", ~. ,," " ~,:' ~ 2~~~~~k~~~~62' WEL, SEC. 09, T11 N, R15E, UM \ =;~~,~" " ~" : .. ,- H.- ...:,:~:' '). Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 50.55' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/3/2002 .. 7/17/2002 7/30/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10343 8635 FT 10299 8593 FT aYes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, LWD, US IT, 23. CASING SIZE 34" X 20" 13-3/8" 9-518" Classification of Service Well Water Injection 7. Permit Number 202-124 8. API Number 50- 029-23095-00 9. Unit or Lease Name Prudhoe Bay Unit 302-330 10. Well Number PSI-09 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2162' MD 1900' (Approx.) Dipole Sonic CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 42" ,260 sx Arctic Set (Approx.) 35' 5588' 16" 1329 sx AS III Lite, 601 sx 'G' 31' 9920' 12-1/4" 618 sx Class 'G' 9813' 10343' 8-1/2" 145 sx Class 'G' SIZE 7-5/8",29.7#, L-80 x 7",26#, L-80 9768' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect w/138 Bbls Diesel 7" WT. PER FT. 91.51# 68# 47# 26# GRADE H-40 L-80 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 10135' -10165' 8436' - 8464' 10175' - 10186' 8474' - 8484' 10196' - 10246' 8494' - 8542' 25. MD TVD 26. 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL AMOUNT PULLED TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 9713' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. r" ~ ~r:: ~ 28. No core samples were taken. E . ) UH 6. Cons, Commission 0 RIG I N A L RBOMS BFl Anc:o: 6 íID2Submit In Duplicate Form 10-407 Rev. 07-01-80 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 1 7300' 5868' West Sak 2 7954' 6420' West Sak 1 8166' 6611' Colville Mudstone 3 8389' 6814' Colville Mudstone 2 9203' 7555' Colville Mudstone 1 9317' 7660' HRZ 9749' 8068' Base HRZ I LCU I Zone 3 9959' 8268' Zone 2C 10026' 8332' Zone 1 10186' 8484' Kavik 10292 8586' 31. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~}J\Ì.t, ~ Title Technical Assistant PSI-09 202-124 302-330 Well Number Permit No. I Approval No. Date OR.~.oõt... Prepared By Name/Number: Terrie Hubb/e, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: PSI-09 Common Name: PSI-09 Test Date 7/9/2002 7/16/2002 FIT FIT Test Type Test Depth (TMD) 5,588.0 (ft) 9,920.0 (ft) BP Leak-Off Test Summary Test Depth (TVD) 4,645.0 (ft) 8,242.0 (ft) AMW 9.20 (ppg) 9.00 (ppg) Surface Pressure 700 (psi) 430 (psi) Leak Off Pressure (BHP) 2,920 (psi) 4,283 (psi) Page 1 of 1 EMW 12.10 (ppg) 10.00 (ppg) . .-... ...-.., Printed: 7/29/2002 4:46:26 PM ( BP Operations Summary Report Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PS 1-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Date From - To Hours Task Code NPT Phase Description. of Operations 7/1/2002 18:00 - 00:00 6.00 MOB P PRE Hold Pre-Job Safety Meeting - Rig Down And Move Nabors Rig 27E From PSI-06 - Move Pump Room Complex, Mud Pits, Motor Shed, Pipe Shed Units - Jack Up Sub Base - Pull Sub Base Off Well "Stop Operation" And Remove Trolly From Mono-Rail And Raise Beam In Order To Clear Production Tree Top Valve - Continue To Move Sub Base From PSI-06 Well - Spot Sub Base In Middle Of Pad And Blade Location Around PSI-09 7/2/2002 00:00 - 02:00 2.00 MOB P PRE Hold Pre-Job Safety Meeting - Set Matting Boards For Sub Base - Attempt To Spread And Lay Herculite 02:00 - 14:00 12.00 MOB N WAIT PRE Winds At 39 MPH To 45 MPH With Gusts To 63 MPH - Shut Down Operations - Wait On Weather To Proceed Safely 14:00 - 16:30 2.50 MOB P PRE Hold Pre-Job Safety Meeting With Nabors Crews And Peak Oilfield Haulers - Spread Herculite And Spot Sub Base Over PSI-09 Conductor 16:30 - 18:00 1.50 MOB P PRE Level Pad - Set Rig Mats For Lay Down Machine Section Of Pipe Shed And Spot Unit 18:00 - 20:00 2.00 MOB P PRE Level Pad - Spot Pit Complex - Slide Rig Mats And Herculite Under Same 20:00 - 21 :00 1.00 MOB P PRE Spot Motor Complex 21 :00 - 22:00 1.00 MOB P PRE Spot Pump Room And Rig Fuel Storage Tank - Spot Power Factor Corrector Trailor Next To Motor Complex 22:00 - 22:30 0.50 MOB P PRE Spot Cuttings Tank And Build Berm For Same 22:30 - 00:00 1.50 MOB P PRE Spot Cement Water Tank - Set Second Section Of Pipe Shed 7/3/2002 00:00 - 06:00 6.00 RIGU P PRE Hold Pre-Job Safety Meeting With Nabors Crew And Peak Oilfield Haulers - Spot Second Cement Water Tank - Set 2 Each Cement Silo's - Move Camp Generator Unit And Spot By Truck Shop - Move Camp To Edge Of Pad - Continue To Berm Up Around Rig - Spot Tioga Heater For Pipe Shed - Hook Up Utilities Misc. Lines And Electrical Cables In Rig. 06:00 - 08:00 2.00 BOPSURP SURF Pick Up Trash And Misc. Tools Around Rig And Pad *NOTE* Nabors Rig 27E Accepted For Well Work On PSI-09 At 06:00 Hours 08:00 - 15:30 7.50 BOPSUR P SURF Nipple Up 21 1/4" Diverter System - Install Riser And Flow Line - Hook Up 16" Knife Valve And Control Hoses - Install Díverter Line To Edge Of Pad - Install Otis Nipple Flange On PSI-06 - Take On Spud Mud 15:30 - 16:00 0.50 BOPSUR P SURF Hold Safety Meeting With GPB Drilling Manager (Tony Bunch) 16:00 - 17:30 1.50 BOPSUR P SURF Change Out Long Elevator Links For Short Set - Service Can-Rig Top Drive, Traveling Blocks, And Crown Sheaves 17:30 - 18:00 0.50 BOPSUR P SURF Pick Up And Rabbit 5" Drill Pipe And Stand Back In Mast 18:00 - 19:00 1.00 BOPSUR P SURF Function Test 21 1/4" Annular And 16" Knife Valve - Preform Accumulator Test - Test H2S And LEL Gas Detection Sensors - Calibrate Flow Show And Check PVT System. *NOTE* The Witness Of Function Testing The Diverter Was Waived By AOGCC Representíve Chuck Scheve 19:00 - 21 :00 2.00 BOPSUR P SURF Continue To Pick Up 5" Drill Pipe (For Top Hole Section) And Stand Back In Mast - Shear Spud Mud Thru Mud Pump While Picking Up Drill Pipe 21 :00 - 23:00 2.00 BOPSURP SURF Pick Up 16" Bit, Mud Motor, And String Stab - RIH Tag Ice At 48' - Pressure Test Mud Line At 1,500 Psi. - Break Circulation Printed: 7/29/2002 4:46:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' BP Operations Summary Report Page 2 of 8 PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Date From- To Hours Task Code NPT Phase Description of Operations 7/3/2002 21 :00 - 23:00 2.00 BOPSURP SURF Check For Surface Leaks 23:00 - 00:00 1.00 DRILL P SURF Pick Up Stand Of Weight Pipe - Drill Ice In 20" Conductor Pipe From 48' To 108' - Continue To Drill Ahead To 145' 7/4/2002 00:00 - 01 :00 1.00 DRILL P SURF Hold Pre-Job Safety Meeting - Drill Ahead From 145' To 200' 01 :00 - 03:00 2.00 DRILL P SURF Stand Back 2 Stands Of HWDP - Pick Up And Make Up MWD Tool- Orient Motor And MWD Tools - Pick Up (3) Flex Drill Collars - Surface Test MWD 03:00 - 07:30 4.50 DRILL P SURF Continue To Drill Ahead From 200' - Make Lift Sub Up In Steel Drill Collars And Jars On Lay Down Machine And Drill Down Singles To Kick Off Point - Directional Drill Ahead To 611' 07:30 - 08:30 1.00 DRILL N FLUD SURF Flow Line And Possom Belly Plugging Up Jet Same - Work To Get Circulation Rates Up With Out Running Over Top Of 20" Riser - Work To Get MWD Tool Turned On. 08:30 - 00:00 15.50 DRILL P SURF Directional Drill Ahead From 611' To 2,047' - Weight On Bit 1 OK To 50K With Pump Rate At 215 Strokes Or 915 GPM - Off Bottom Pump Pressure At 1800 Psi. & On Bottom Pump Pressure At 2150 Psi. - Top Drive RPM At 90 To 100 - Off Bottom Torque At 4K & On Bottom Torque At 8K - String Rotating Weight At 130K - With Pump On Drag Up At 140K And Drag Down At 120K 7/5/2002 00:00 - 06:30 6.50 DRILL P SURF Directional Drill Ahead From 2,047' To 2,796' - Weight On Bit 5K To 45K With Pump Rate At 215 Strokes Or 915 GPM - Off Bottom Pump Pressure At 1950 Psi. & On Bottom Pump Pressure At 2150 Psi. - Top Drive RPM At 100 To 110 - Off Bottom Torque At 6K & On Bottom Torque At 9K - String Rotating Weight At 140K - With Pump On Drag Up At 145K And Drag Down At 125K 06:30 - 07:30 1.00 DRILL P SURF Pump Weighted Sweep Around 07:30 - 09:00 1.50 DRILL P SURF Hold Pre-Job Safety Meeting - POH To Drill Collars (NO PROBLEMS) 09:00 - 09:30 0.50 DRILL P SURF Service Top Drive, Traveling Blocks, Crown Sheaves 09:30 - 11 :00 1.50 DRILL P SURF Hold Pre-Job Safety Meeting - RIH (NO PROBLEMS) To 2,702' - Wash Last Stand To Bottom At 2,796' 11 :00 - 00:00 13.00 DRILL P SURF Directional Drill Ahead From 2,796' To 4,482' ,. Weight On Bit 5K To 30K With Pump Rate At 215 Strokes Or 915 GPM - Off Bottom Pump Pressure At 2400 Psi. & On Bottom Pump Pressu re At 2650 Psi. - Top Drive RPM At 1 00 To 11 0 - Off Bottom Torque At 12K & On Bottom Torque At 15K - String Rotating Weight At 145K - With Pump On Drag Up At 175K And Drag Down At 125K 7/6/2002 00:00 - 14:00 14.00 DRILL P SURF Directional Drill Ahead From 4,482' To 5,608',. Weight On Bit 25K To 45K With Pump Rate At 215 Strokes Or 900 GPM - Off Bottom Pump Pressure At 2400 Psi. & On Bottom Pump Pressure At 2700 Psi. - Top Drive RPM At 100 - Off Bottom Torque At 12K & On Bottom Torque At 15K ,. String Rotating Weight At 160K - With Pump On Drag Up At 200K And Drag Down At 135K 14:00 -15:30 1.50 DRILL P SURF Pump Low / Hi Vis. Weighted Sweep At TD 15:30 - 20:00 4.50 DRILL P SURF Hold Pre-Job Safety Meeting - POH With 5" Drill Pipe & 5" HWDP Stand Back In Mast 20:00 - 22:00 2.00 DRILL P SURF Stand Back Jars, (2) Stands Of Steel Drill Collars, (1) Stand Of Flex Drill Collars - Hold Pre-Job Safety Meeting - Continue To POH Laying Down Sperry Sun MWD Tools & Mud Motor Printed: 7/29/2002 4:46:44 PM ( ( BP Operations Summary Report Page 3 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/6/2002 22:00 - 22:30 0.50 DRILL P SURF Clear Rig Floor And Wash Off Same 22:30 - 00:00 1.50 CASE P SURF Hold Pre-Job Safety Meeting - Remove Short Set Of Elevator Links - Remove Top Drive Clamp & Saver Sub - Hold Pre-Job Safety Meeting - Pick Up And Make Up GBR Franks Fill Up Tool 7/7/2002 00:00 - 02:00 2.00 CASE P SURF Hold Pre-Job Safety Meeting - Continue To Rig Up To Run 13 3/8" 681b. L-80 Casing - Change Out Chicksan Swivel Joint At Top Of Cement Line And Test Same To 2,000 Psi. - Rig Up GBR Franks Tool - Spacing Of Cups Incorrect Lay Down And Space Out Same - Pick Up Franks Tool. 02:00 - 03:00 1.00 CASE P SURF Pick Up Shoe Track And Float Equipment - Start Filling With Mud To Check Floats Wash Pipe Packing Leaking - Shut Down Operation 03:00 - 04:30 1.50 CASE N RREP SURF Hold Pre-Job Safety Meeting - Change Out Wash Pipe Cartridge And Test To 3,500 Psi. (Good Test) 04:30 - 16:30 12.00 CASE P SURF Continue To RIH With 136 Joints Of 13 3/8" 681b. L-80 Casing- Tight At 3,500' Break Circulation And Wash From 3,500' To 3,600' - RIH And Wash From 3,900' To 4,000' - Continue To RIH With Casing Per Program 16:30 - 20:00 3.50 CEMT P SURF Circulate And Condition Mud - Unable To Reciprocate Casing String At 550K 20:00 - 21 :30 1.50 CEMT P SURF Hold Pre-Job Safety Meeting With All Personal Regarding Upcoming Cement Job - Rig Down Franks Fill-Up Tool - Install Crossover And Dowell Schlumberger Cement Head - Make Up Circulating Lines - Circulate With Both Mud Pumps To Verify Operational 21 :30 - 00:00 2.50 CEMT P SURF Shut Down And Turn Over To Dowell- Pump 5 BBLS. CW-100 - Pressure Test Surface Equipment And Lines To 3,000 Psi. - Pump 5 BBLS. CW-100 - Shut Down And Drop Bottom Plug - Pump 65 BBLS. 10.2 PPG. Mud Push With Red Dye - Start Pumping 10.7 PPG Lead Cement At 6 BPM 7/8/2002 00:00 - 03:00 3.00 CEMT P SURF 00:00 To 03:00 - Continue To Pump Lead Cement - When CW-100 Turned Corner Lost Returns For Brief Period - Slow Pump Rate To 4 BPM Total Loses At 39 BBLS. Got Returns Back And Increased Pump Rate To 6 BPM - Continue To Pump 1019BBLS. Lead Slurry - Swap To Tail Slurry And Pump A Total Of 120.8 BBLS. 15.8 PPG Tail Cement - Shut Down And Drop Top Plug - Pump 10 BBLS. Behind Plug - Shut Down And Swap To Rig For Displacement - Pump Rate At 10 BPM With Full Returns - Slow Pump Rate T02 BPM At 1,100 Psi. - Bump Plug With 815 BBLS. 9.3 PPG Mud - Increase Printed: 7/29/2002 4:46:44 PM ( BP Operati.ons Summary Report Page 4 of 8 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-09 PSI-09 ORIG DRilLING NABORS NABORS 27ES Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Date From -To Hours Task Code NPT Phase Description of Operations 7/8/2002 00:00 - 03:00 3.00 CEMT P SURF Pressure To 1,600 Psi. - Bleed Pressure To 0 Psi. - Remove Cement Hose And Check Floats (OK) - Total Cement Volume To Surface 20 BBLS. - Cement In Place At 02:58 Hours. 03:00 - 05:00 2.00 CEMT P SURF Hold Pre-Job Safety Meeting - Wash Off Casing Tools And Rig Down Same - Clear Rig Floor - Back Out Landing Joint And Lay Down Same 05:00 - 08:00 3.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Nipple Down 16" Diverter Line And 21 1/4" Riser, Annular, And Diverter Spool - Remove From Cellar Area 08:00 - 09:30 1.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Nipple Up FMC Big Bore 5M Split Uni-Head - Test Metal To Metal Seal To 1,000 Psi. For Ten Minutes (Good Test) 09:30 - 14:00 4.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Install 13 5/8 5M BOP Stack And Nipple Up BOP And Related Equipment 14:00 - 16:30 2.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Install Lower Valve And Clamp On Can-Rig Top Drive - Install Short Set Bales And 5" Drill Pipe Elevators - Inspect Top Drive And Service 16:30 - 21 :30 5.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Install FMC Lower Test Plug And Rig Up To Test Bop - Witness Of BOP Test Waived By AOGCC Inspector Chuck Scheve - Test Annular At 250 Psi. Low And 3,500 Psi. High - Test Upper And Lower Pipe Rams, Blind Rams, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves, Manual And HeR Valves On The Choke And Kill Lines At 250 Psi. Low And 5,000 Psi. High - Test Pit PVT System And H2S And LEL Detectors - Perform Accumulator Test - Remove Test Plug - Install Long Bowl Protector 21 :30 - 23:00 1.50 DRILL P INT1 Preform Mast Inspection - Tighten Jam Nuts On Turnbuckles For Top Drive Torque Tube - Install Secondary Annulus Valve On FMC Split Uni-Head 23:00 - 00:00 1.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Pick Up And Make Up 12 1/4" Bit And BHA NO.2 - Orient MWD/LWD Tools And Initialize Same 7/9/2002 00:00 - 01 :00 1.00 DRILL P INT1 MU MWD and orient to motor. Upload to MWD. 01 :00 - 02:00 1.00 DRILL P INT1 Finish picking up BHA. Bring CBI's to rig floor and caliper. 02:00 - 06:30 4.50 DRILL P INT1 RIH picking up DP. Pick up 4 stands from derrick. RIH to 5400'. 06:30 - 08:00 1.50 DRILL P INT1 Break circulation. Test casing to 3,500 psi for 30 minutes. 08:00 - 11 :30 3.50 DRILL P INT1 RIH to 5,484'. Wash and ream to float collar at 5,496'. Drill float equipment and firm cement to shoe at 5,582'. Hung up coming out of shoe. Work pipe until everthing clear. Continue to drill rat hole to 5,608'. 11 :30 - 12:30 1.00 DRILL P INT1 Drill 20' of new formation from 5,608' to 5,628'. 12:30 - 13:30 1.00 DRILL P INT1 Pump sweep and circulate hole clean. 13:30 - 15:00 1.50 DRILL P INT1 RIU & Perform FIT test to 12.1 ppg EMW. Take ECD baseline rates & pressures 15:00 - 00:00 9.00 DRILL P INT1 Drill from 5,628' to 6,066'. AST=2.91, ART=4.39. 7/10/2002 00:00 - 13:00 13.00 DRILL P INT1 Drill from 6,066' to 7,050' with 850 gpm, ECD=9.7. 13:00 - 19:30 6.50 DRILL N RREP INT1 Leak from goose neck. Pull to shoe and repair goose neck. RIH. Hole in good shape. 19:30 - 00:00 4.50 DRILL P INT1 Drill from 7,050' to 7,225'. Daily drilling hours: AST=4.92, ART=6.58. 7/11/2002 00:00 - 00:00 24.00 DRILL P INT1 Drill from 7,225' to 8,200' continueing to drop angle as per Printed: 7/29/2002 4:46:44 PM ( Page 5 of 8 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES 14:30 - 16:00 1.50 CASE P 16:00 - 22:30 6.50 CASE P 22:30 - 00:00 1.50 CASE N 7/15/2002 00:00 - 05:00 5.00 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 12:00 6.00 CASE P 12:00 -14:00 2.00 CASE P 14:00 - 15:00 1.00 CASE P 15:00 - 17:00 2.00 CASE P Date 7/11/2002 7/12/2002 7/13/2002 7/14/2002 From - To Hours Task Code NPT Phase 00:00 - 00:00 24.00 DRILL P 00:00 - 18:00 18.00 DRILL P 18:00 - 19:30 1.50 DRILL P 19:30 - 00:00 4.50 DRILL P 00:00 - 02:30 2.50 DRILL P 02:30 - 04:30 2.00 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 12:00 6.00 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 00:00 11.00 DRILL P 00:00 - 00:30 0.50 DRILL P 00:30 - 03:00 2.50 DRILL P 03:00 - 08:30 5.50 DRILL P 08:30 - 09:00 0.50 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 11 :30 1.50 DRILL P 11 :30 - 12:00 0.50 DRILL P 12:00 -14:30 2.50 CASE P INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 RREP INT1 INT1 INT1 INT1 INT1 INT1 INT1 17:00 - 18:30 1.50 CASE P INT1 18:30 - 20:30 2.00 CASE P INT1 20:30 - 22:00 1.50 CASE P INT1 22:00 - 00:00 2.00 CASE P INT1 7/16/2002 00:00 - 04:00 4.00 CASE P INT1 04:00 - 05:00 1.00 CASE P INT1 05:00 - 06:30 1.50 DRILL P INT1 06:30 - 08:00 1.50 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P PROD1 10:00 - 11 :00 1.00 DRILL P PROD1 Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Description of Operations directional plan. ART=3.03, AST=12.67. Drill from 8,200' to 9,346'. AST=5.08, ART=7.42. Change swab in #2 pump. Circulate and condition mud to 10.3 ppg at 77 spm. Unable to obtain higher rate due to background gas. Weight up mud to 10.3 ppg. Necessary to circulate at 77 spm due to background gas ( 3500U). Monitor well Short trip from 9,346' to 13 3/8" shoe at 5,588'. Hole in good shape. RIH to 9,346'. Drill from 9,346' to 9,542'. Change swab on #1 pump. Drill from 9,542' to 9,918'. Daily drilling hours: ART=14.1, AST=O. Drill from 9,918' to intermediate TD at 9,932'. Circulate sweep surface to surface. Spot 95 bbls lubricant pill. Observe well. Well static. POH to BHA. Stand back HWDP, drilling jar, and DCs. Down load MWD. LD MWD, AGS, pony collar, and motor. Clear floor. Pull wear bushing. Install test plug. Change top rams to 9 5/8". Test doors to 3,000 psi. Make dummy run with landing joint. RD elevators and change bails. RU casing equipment. Run 9 5/8", 47#, L-80, BTCM casing to 3,284'. Work on goose neck. Change O-ring. Run 9 5/8", 47#, L-80, BTCM casing to 5,560'. Break circulation. Stage up rate to 7 bpm. Circulate one casing volume. Run casing to 9,920'. Necessary to wash second to last joint down. Land casing. Circulate and condition mud. Fluid level stable, no losses. LD Franks fillup tool. RU cement head. Perform cement job. Pump 10 bbls CW-100. Test lines to 3,500 psi. Pump 10 bbls CW-100, 50 bbls 12.0 ppg mud push spacer, drop bottom plug, pump 133 bbls 15.8 ppg class G cement with latex, pump all @ 6 BPM. drop top plug chase w/ 10 bbls of water, switch to rig pumps and displace cement w/ 710 Bbls. mud @ 11 BPM. Slow to 3 BPM & Bump plug w/ 1500 psi. CIP 17:00 hrs.Check Floats - OK. RD cementers and casing equipment. LD landing joint. Install packoff and test to 5,000 psi for 10 minutes. Change top rams back to 4 1/2" X 7" variables. Test BOPE to 250 / 4,000 psi as per BP policy and AOGCC regulations. Witness of test waived by John Crisp of AOGCC. Continue testing BOPE. Clear floor and RD testing equipment. LD 8" DCs and jar. PU 8 1/2" BHA. Upload MWD. Load RA source. Surface test MWD. PU jar out of pipe shed. Run 11 joints of HWDP. PU 21 joints Printed: 7/29/2002 4:46:44 PM BP Operations Summary Report Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/16/2002 10:00 - 11 :00 1.00 DRILL P PROD1 of DP from shed. 11 :00 - 16:30 5.50 DRILL P PROD1 RIH to 9,681'. 16:30 - 17:00 0.50 DRILL P PROD1 CBU for casing test. 17:00 - 18:30 1.50 DRILL P PROD1 Pressure test casing to 3,500 psi for 30 minutes. 18:30 - 19:00 0.50 DRILL P PROD1 Wash and ream to top of float collar. 19:00 - 20:00 1.00 DRILL N RREP PROD1 Work on top drive. 20:00 - 21 :30 1.50 DRILL P PROD1 Drill cement and float at 9,836'. Drill cement to 9,895'. 21 :30 - 22:30 1.00 DRILL P PROD1 Displace old mud with 9.0 ppg Baradril-N. 22:30 - 23:30 1.00 DRILL P PROD1 Drill cement and shoe track. Clean out rat hole to 9,932'. 23:30 - 00:00 0.50 DRILL P PROD1 Drill new formation from 9,932' to 9,963'. 7/17/2002 00:00 - 00:30 0.50 DRILL P PROD1 Circulate and condition mud to 9.0 ppg in and out. 00:30 - 01 :00 0.50 DRILL P PROD1 Perform FIT test to 10.0 ppg EMW. 01 :00 - 08:30 7.50 DRILL P PROD1 Drill from 9,951' to 10,328'. 08:30 - 10:30 2.00 DRILL P PROD1 Circulate and condition mud. 10:30 - 11 :00 0.50 DRILL N HMAN PROD1 Short trip from 10,328' to 10,025'. MAD pass from 10,025' to 9,823'. 11 :00 - 11 :30 0.50 DRILL P PROD1 RIH. 11 :30 - 13:00 1.50 DRILL P PROD1 Pump sweep and circulate hole clean. 13:00 -14:00 1.00 DRILL P PROD1 Drill from 10,328' to 10,343'. 14:00 - 15:30 1.50 DRILL P PROD1 CBU. Spot liner running pill. 15:30 - 20:30 5.00 DRILL P PROD1 POH. SLM. 20:30 - 23:00 2.50 DRILL P PROD1 LD BHA. Remove RA source and download MWD. 23:00 - 00:00 1.00 EVAL P PROD1 RU eline. 7/18/2002 00:00 - 04:00 4.00 EVAL P PROD1 RIH with USIT on eline. Log from 9,900' to 7,300' WLM. POH. 04:00 - 04:30 0.50 EVAL P PROD1 LD USIT. 04:30 - 08:30 4.00 EVAL N SFAL PROD1 MU dipole sonic tool. Trouble shoot and fix ground connect failure in the logging head and telemetry problem relating to DSI/GPIT combo. 08:30 - 19:30 11.00 EVAL P PROD1 RIH and log with dipole sonic. 19:30 - 20:30 1.00 EVAL P PROD1 RD wireline. 20:30 - 00:00 3.50 CASE P PROD1 PJSM. RU to run 7" liner. Make up float equipment and check floats. Run 7", 26#, L-80, BTCM liner. MU HMC liner hanger and ZXP liner top packer. 7/19/2002 00:00 - 10:00 10.00 CASE P PROD1 RIH with 7" liner on 5" DP at 1.5 minutes per stand. Fill every 10 stands. 10:00 - 10:30 0.50 CASE P PROD1 Circulate at 9 5/8" shoe. 10:30 - 11 :30 1.00 CASE P PROD1 RU cement head on 5" DP pup joint and lay down same. 11 :30 - 12:00 0.50 CASE P PROD1 RIH and tag up at 10,343'. 12:00 - 14:00 2.00 CASE P PROD1 Circulate and condition mud at 5 bpm, 500 psi. PU=225K, SO=185K. Install cement head. Held PJSM with crews and cementers while circulating. 14:00 - 15:30 1.50 CASE P PROD1 Pressure test cement lines to 4.000 psi with water. Pump 30 bbls CW-100, 30 bbls 10.0 ppg mud push spacer, 31 bbls 15.8 ppg class G cement w/ latex, drop DP wiper dart, displace cement with 184 bbl of 9.1 ppg mud with cement pump. Bump plug and set liner hanger with 3,500 psi. Slack off to ensure hanger is set. Bleed pressure to zero and check floats, OK. Rotate 15 turns to the right to release from hanger. 15:30 - 16:00 0.50 CASE P PROD1 Pressure up to 1000 psi and unsting, circulate at 10 bpm for 50 bbls. Pick up to expose setting lugs on rotating dog sub. Reduce rate to 2 bpm, rotate, slack off and set ZXP liner top packer with 75,000 Ibs down weight. 16:00 - 17:30 1.50 CASE P PROD1 Circulate. Recovered 8 bbl cement. LD cement head and Printed: 7/29/2002 4:46:44 PM ( BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES Date From - To Hours Task Code NPT Phase 7/19/2002 16:00 - 17:30 1.50 CASE P 17:30 - 21 :00 3.50 CASE P 21 :00 - 22:30 1.50 CASE P 22:30 - 23:30 1.00 CASE P 23:30 - 00:00 0.50 CASE P 00:00 - 02:30 2.50 CASE P 02:30 - 06:00 3.50 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 10:30 2.50 CASE P PROD1 PROD1 PROD1 PROD1 PROD1 7/20/2002 PROD1 PROD1 PROD1 PROD1 PROD1 10:30 - 11 :00 0.50 CASE P 11 :00 - 12:00 1.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 18:00 5.50 CASE P 18:00 - 20:00 2.00 CASE P 20:00 - 22:00 2.00 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 1.00 CASE P 7/21/2002 00:00 - 15:00 15.00 CASE P 15:00 - 18:00 3.00 CASE P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 18:00 - 21 :30 3.50 CASE P PROD1 21 :30 - 23:00 1.50 CASE P PROD1 23:00 - 00:00 1.00 CASE P PROD1 7/22/2002 00:00 - 01 :00 1.00 CASE P PROD1 01 :00 - 02:00 1.00 CASE P PROD1 Page 7 of 8 Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Description of Operations lines. POH. Slip and cut drilling line. LD liner running tool and TD head. Change elevators and handling equipment. PU casing scrapers and XOs. PU 7" casing scraper, 15 joints of 31/2" HWDP and 95/8" casing scraper. RIH w/ 5" DP from derrick. Tag up on 7" landing collar at 10,253'. Circulate and clean hole at 420 gpm. PJSM with crews and Peak drivers on displacement to seawater. Displace to seawater at 435 gpm. Pump 50 bbl caustic wash, 50 bbls dirt magnet, 25 bbl high vis sweep followed by 1.5 times hole volume of seawater. Final NTU=58. RU to test casing. PJSM. Test 7" liner, liner top packer and 9 5/8" casing to 4,000 psi for 30 minutes. RD test equipment. POH and stand back 29 stands of 5" DP in derrick. Continue to POH and LD DP and casing scrapers. Pull wear bushing, set test plug. Change top rams to 7 5/8" and test door seals. Change bails, RU to run 7" tail pipe assembly. PU 7 5/8" casing equipment. Run 7" tail pipe, 7 x 9 5/8" Baker SABL-3 packer, PBR, and R nipple. RU 7 5/8" casing equipment and run 75/8", L-80, 29.7#, STL plastic coated tubing, Continue to run 7 5/8", 29.7#, L-80, STL internal plastic coated tubing. Space out. Drop ball / rod. Set packer. Increase pressure in 500 psi increments. PBR sheared at 2,200 psi while setting packer. Test tubing to 2,500 psi for 15 minutes. Test annulus to 1000 psi for 15 minutes. Confirm top of PBR by going back down and stinging in while pumping 1 bpm. RU and reverse circulate 126 bbls of inhibited sea water. RU Little Red hot oil unit. Pressure test lines to 3,500 psi. Reverse circulate 138 bbls of diesel. U-tube diesel into tubing to freeze protect to 2000'. Land tubing hanger with 5" drill pipe and cross over. Run in lock down screws. WLEG at 9767'. RN no-go nipple at 9755'. R Nipple at 7943'. SABL-3 Packer at (top) 9713', elements at 9728'. PBR (top) at 9673', R Nipple at 9659'. DB Nipple at 2162'. Top ofT' liner at 9813'. 7" float collar at 10257' RD U-tube lines and pressure test injection line from rig pump to cellar. RU and Pressure test 7 5/8" tubing to 4,000 psi for 30 minutes. Bleed tubing pressure to 2,500 psi. Pressure test 75/8" x 9 5/8" annulus to 4,000 psi for 30 minutes. Witness of pressure Printed: 7/29/2002 4:46:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP Operations Summary Report PSI-09 PSI-09 ORIG DRILLING NABORS NABORS 27ES From -To Hours Task Code NPT Phase 7/22/2002 01 :00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 06:30 06:30 - 10:30 10:30 - 14:00 14:00 - 16:00 1.00 CASE 1.00 CASE 1.00 CASE 2.50 CASE 4.00 CASE 3.50 CASE 2.00 CASE P P p P P N P PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 Page 8 of 8 Start: 7/2/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 7/3/2002 End: Description of Operations testing waived by John Spaulding of AOGCC. RD testing equipment and set TWC. Blow down high pressure line and change pipe rams. ND BOPE. NU tree. Attempt to test tree. Trouble shoot and repair test pump. RU DSM and change out TWC. Test tree to 5,000 psi with hot oil pump truck. Release rig at 16:00 hrs. Printed: 7/29/2002 4:46:44 PM (' Well: Field: API: Permit: PSI-09 Prudhoe Bay Unit 50-029-23095-00 202-124 Rig Accept: 07/03/02 Rig Spud: 07/03/02 Rig Release: 07/22/02 Drilling Rig: Nabors 27E POST RIG WORK 07/28/02 PULL B&R, 4-1/2" RHC- M & 7" NIPPLE REDUCER. RIH WI 3-3/8" DMY GUN I TEL I SB. UNABLE TO LOCATE EOT. TAG PBTD @ 10,218' SLM. SAMPLE OF SAND IN BAILER. RDMO. WELL TO REMAIN SHUT IN. 07/29/02 LOG DOWN TEMPERATURE SURVEY AND REPEAT PASS AT 40 FPM FROM 9650 FT TO TD @ 10247' ELM. LU JEWELRY PASS FROM TD TO 9600'. ELMD FOR WLEG IS 9766'. WELL SHUT IN - PERF IN THE AM. 07/30/02 PERFORATE: 10196-10246/10175-10186/10135-10165 IN FOUR RUNS WI 33/8" PJ, 6 SPF, 60 DEG PHASE, -- 38.6 PEN, .45" ENT HOLE. ALL SHOTS FIRED. WELL ON VAC AFTER EACH RUN. TAKE SBHPS IMMEDIATELY AFTER PERFORATING @ 10160' MD (8460' SS) FOR 15 MINUTES. PRESSURE AT THAT DEPTH DROPPING FROM 3386.6 PSI TO 3382.2 PSI. NOTIFY PAD OPER OF STATUS - WELL SHUT IN. 08/02102 PUMP INJECTIVITY TEST. 08/04/02 PUMP INJECTIVITY TEST. ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well PSI-09 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 19-Aug-02 0.00' MD I M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUt, ? .,. ')01\1) ...... c........J L v, AlaMaOi/& Gaseons. Commisøto Anchorage n CìQ¿)~/~ North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI slot I PSI-09 Job No. AKZZ22104, Surveyed: 17 July, 2002 SURVEY REPORT 13 August, 2002 Your Ref: API 500292309500 Surface Coordinates: 5966179.63 N, 708052.62 E (70018' 39.4389" N, 1480 18' 50.1224" W) Kelly Bushing: 50. 55ft above Mean Sea Level spel'I'Y-SUI! Q Af L ";1.1\1. rs.-- > s erR v I c: S.? A Halliburton Company Survey Ref: svy11237 Sperry-Sun Drilling Services .. Survey Report for PSI-09 Your Ref: API 500292309500 Job No. A KZZ221 04, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -50.55 0.00 0.00 N 0.00 E 5966179.63 N 708052.62 E 0.00 AK-6 BP _IFR-AK 115.00 0.020 198.430 64.45 115.00 0.02 S 0.01 W 5966179.61 N 708052.61 E 0.017 -0.01 210.92 0.120 20.870 160.37 210.92 0.06 N 0.02 E 5966179.69 N 708052.64 E 0.146 0.04 305.42 0.080 150.080 254.87 305.42 0.09 N 0.09 E 5966179.73 N 708052.71 E 0.192 0.04 424.90 0.120 314.410 374.35 424.90 0.11 N 0.04E 5966179.74 N 708052.66 E 0.166 0.07 507.64 0.300 85.990 457.09 507.64 0.19 N 0.20 E 5966179.82 N 708052.81 E 0.471 0.07 596.76 1.690 341 .480 546.20 596.75 1.45 N 0.01 E 5966181.08 N 708052.59 E 2.007 1.26 658.15 2.810 345.630 607.54 658.09 3.76 N 0.65W 5966183.37 N 708051.87 E 1.842 3.61 752.96 3.440 343.690 702.21 752.76 8.75 N 2.02W 5966188.32 N 708050.36 E 0.674 8.64 847.72 3.840 328.380 796.78 847.33 14.18 N 4.48 W 5966193.68 N 708047.74 E 1.105 14.59 941.37 4.900 324.890 890.15 940.70 20.12 N 8.43 W 5966199.51 N 708043.64 E 1.166 21.70 1035.22 6.190 336.540 983.57 1034.12 28.04 N 12.75 W 5966207.31 N 708039.10 E 1.818 30.72 1128.78 8.530 346.900 1076.35 1126.90 39.43 N 16.33 W 5966218.59 N 708035.20 E 2.866 42.43 1223.88 9.800 343.840 1170.24 1220.79 54.07 N 20.18 W 5966233.12 N 708030.95 E 1 .430 57.13 1255.43 10.240 340.330 1201.31 1251.86 59.29 N 21.87 W 5966238.29 N 708029.11 E 2.385 62.52 1316.69 10.280 333.960 1261.59 1312.14 69.33 N 26.11 W 5966248.21 N 708024.60 E 1.852 73.36 1348.27 10.600 331 .130 1292.65 1343.20 74.40 N 28.75 W 5966253.21 N 708021.82 E 1.914 79.08 ~. 1410.58 12.340 327.780 1353.71 1404.26 85.06 N 35.06 W 5966263.68 N 708015.21 E 2.989 91.45 1503.67 14.800 325.810 1444.20 1494.75 103.31 N 47.05 W 5966281.60 N 708002.73 E 2.688 113.22 1598.53 14.830 326.810 1535.90 1586.45 123.49 N 60.50 W 5966301.40 N 707988.72 E 0.271 137.38 1691.99 14.080 327.960 1626.40 1676.95 143.14 N 73.08 W 5966320.69 N 707975.60 E 0.859 160.65 1787.48 14.090 326.880 1719.02 1769.57 162.72 N 85.60 W 5966339.92 N 707962.55 E 0.275 183.84 1878.23 13.070 327.080 1807.23 1857.78 180.58 N 97.21 W 5966357.45 N 707950.45 E 1.125 205.08 1971.35 13.410 330.430 1897.88 1948.43 198.82 N 108.26 W 5966375.37 N 707938.89 E 0.901 226.38 2068.29 15.010 333.400 1991.85 2042.40 219.82 N 119.43 W 5966396.06 N 707927.15 E 1.813 250.17 2163.23 15.860 334.480 2083.37 2133.92 242.52 N 130.52 W 5966418.44 N 707915.43 E 0.945 275.41 2257.19 17.640 336.590 2173.34 2223.89 267.17 N 141.71 W 5966442.77 N 707903.56 E 2.002 302.41 2349.32 19.680 336.020 2260.62 2311.17 294.16 N 153.56 W 5966469.42 N 707890.97 E 2.223 331 .77 2442.76 21.330 336.420 2348.14 2398.69 324.11 N 166.76 W 5966499.00 N 707876.95 E 1.772 364.38 2536.23 23.380 336.820 2434.58 2485.13 356.74 N 180.86 W 5966531.23 N 707861.95 E 2.199 399.78 ______n_.u___~--- --------~-----------~_.~-._---- - --------_.~ 13 August, 2002 - 14:54 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services .' Survey Report for PSI-09 Your Ref: API 500292309500 Job No. AKZZ221 04, Surveyed: 17 July, 2002 BPXA North Slope Alaska lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (1t) (1t) (ft) (ft) (1t) (ft) (1t) (°/1 OOft) 2630.27 27,120 335.250 2519,62 2570.17 393.38 N 197.18 W 5966567.39 N 707844,62 E 4,040 439,75 2723.98 31 .490 332.620 2601,32 2651.87 434.53 N 217.39 W 5966607,97 N 707823,27 E 4,860 485,56 2818,05 34,370 332.110 2680,27 2730.82 479.82 N 241.12 W 5966652,59 N 707798,30 E 3,076 536,68 2911,52 37,310 332.670 2756,03 2806.58 528.32 N 266.47 W 5966700,36 N 707771,62 E 3,165 591,39 3003.85 39,270 333.140 2828,50 2879.05 579.25 N 292.52 W 5966750.55 N 707744,16 E 2,146 648,58 3097.54 39,640 332.770 2900,84 2951.39 632.28 N 319.59 W 5966802.81 N 707715.63 E 0.468 708,09 3188.40 40,320 331 ,500 2970.46 3021.01 683,88 N 346.88 W 5966853.64 N 707686.93 E 1,169 766.47 3284.92 43,120 330.920 3042.50 3093.05 740.16 N 377.82 W 5966909.04 N 707654.44 E 2,928 830.69 3378.48 44,010 330.310 3110,29 3160.84 796.35 N 409.46 W 5966964.33 N 707621.25 E 1.052 895.16 3471.21 45,040 330.620 3176.40 3226.95 852,92 N 441,51 W 5967019.99 N 707587,65 E 1,135 960,18 3560.52 44,000 332.540 3240,08 3290.63 907,98 N 471.32 W 5967074.21 N 707556,33 E 1.905 1022,79 3660.57 45,860 332.000 3310.91 3361.46 970,52 N 504,20 W 5967135.81 N 707521,72 E 1.898 1093.44 3752.91 47,240 332.380 3374.41 3424.96 1029,82 N 535.47 W 5967194,21 N 707488,82 E 1.524 1160.47 3843.04 48,140 331.590 3435.08 3485.63 1088,65 N 566,78 W 5967252.16 N 707455,89 E 1.190 1227,11 3935.01 46.510 332,570 3497.42 3547.97 1148.39 N 598.45 W 5967311,00 N 707422,59 E 1.938 1294,72 4032.41 46,580 332,220 3564.41 3614.96 1211.05 N 631,21 W 5967372,73 N 707388,10 E 0.271 1365.41 4128.82 47.970 331,240 3629.82 3680.37 1273.42 N 664,76 W 5967434.14 N 707352,84 E 1,624 1436,23 4218,85 48,650 331,380 3689.70 3740.25 1332.40 N 697.03 W 5967492,20 N 707318,94 E 0,764 1503.46 ~ 4309,96 48,650 331,830 3749.90 3800.45 1392.56 N 729.56 W 5967551.45 N 707284,76 E 0,371 1571,86 4403.93 47,820 331 .430 3812.49 3863.04 1454.24 N 762.86 W 5967612,17 N 707249,76 E 0,939 1641,95 4501.46 47,380 332,070 3878.25 3928.80 1517.68 N 796.95 W 5967674.65 N 707213.93 E 0.662 1713.97 4598,27 47,990 331,740 3943.42 3993,97 1580,83 N 830.67 W 5967736.84 N 707178.48 E 0.679 1785,55 4693,18 48.490 332.490 4006.64 4057.19 1643.40 N 863.78 W 5967798.47 N 707143.65 E 0.791 1856,34 4787.43 48,860 329,660 4068.88 4119.43 1705.34 N 898.01 W 5967859.44 N 707107,71 E 2,289 1927,10 4882.37 47,930 329,550 4131.92 4182.47 1766.57 N 933.92 W 5967919.65 N 707070,11 E 0,983 1998,06 4977.54 48.230 329,580 4195.50 4246.05 1827.63 N 969.80 W 5967979.69 N 707032,56 E 0.316 2068,84 5070.49 47,790 329,330 4257.68 4308,23 1887.13 N 1004.91 W 5968038.19 N 706995,82 E 0.514 2137.89 5165.63 48,070 329,250 4321.43 4371,98 1947.85 N 1040.97 W 5968097.89 N 706958,08 E 0.301 2208.47 5258.43 48.450 329.160 4383.21 4433.76 2007.33 N 1076.42 W 5968156.37 N 706921,00 E 0.416 2277,66 5353.60 49,390 329.780 4445,75 4496,30 2069.12 N 1112.86 W 5968217.13 N 706882,86 E 1,103 2349,36 - ----------.--------- ~--- -------- ----.------- --- ----------~-----~------- -- - 13 August, 2002 - 14:54 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services ~.' Survey Report for PSI-09 Your Ref: API 500292309500 Job No. AKZZ22104, Surveyed: 17 July, 2002 BPXA North Slope Alaska lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5444.82 50.430 330.010 4504.49 4555.04 2129.50 N 1147.87 W 5968276.51 N 706846.20 E 1.156 2419.12 5535.90 51.020 330.470 4562.15 4612.70 2190.70 N 1182.86 W 5968336.72 N 706809.52 E 0.757 2489.62 5590.61 50.660 330.400 4596.70 4647.25 2227.60 N 1203.79 W 5968373.03 N 706787.57 E 0.665 2532.03 5684.91 50.760 329.740 4656.42 4706.97 2290.85 N 1240.21 W 5968435.24 N 706749.42 E 0.552 2605.00 5781.75 47.880 329.150 4719.53 4770.08 2354.09 N 1277.53 W 5968497.42 N 706710.36 E 3.010 2678.39 5875.27 46.400 329.250 4783.14 4833.69 2412.97 N 1312.63 W 5968555.31 N 706673.64 E 1.584 2746.89 5972.98 46.390 330.060 4850.53 4901.08 2474.03 N 1348.38 W 5968615.35 N 706636.22 E 0.600 2817.61 6070.43 44.580 329.710 4918.85 4969.40 2534.14 N 1383.24 W 5968674.47 N 706599.71 E 1.875 2887.07 6164.16 43.090 329.660 4986.46 5037.01 2590.18 N 1416.00 W 5968729.58 N 706565.40 E 1.590 2951.96 6259.75 43.250 330.850 5056.18 5106.73 2646.96 N 1448.45 W 5968785.44 N 706531 .40 E 0.868 3017.34 6353.36 43.800 331.570 5124.05 5174.60 2703.45 N 1479.49 W 5968841.06 N 706498.80 E 0.791 3081.81 6450.50 43.940 332.170 5194.08 5244.63 2762.82 N 1511.23 W 5968899.52 N 706465.43 E 0.452 3149.13 6543.78 44.990 332.010 5260.65 5311.20 2820.56 N 1541.82 W 5968956.39 N 706433.25 E 1.132 3214.46 6637.68 43.970 332.340 5327.65 5378.20 2878.74 N 1572.53 W 5969013.70 N 706400.94 E 1.114 3280.24 6730.83 42.880 332.870 5395.30 5445.85 2935.59 N 1601.99 W 5969069.71 N 706369.91 E 1.234 3344.26 6825.27 43.120 332.950 5464.37 5514.92 2992.93 N 1631.32W 5969126.22 N 706339.01 E 0.261 3408.64 6919.16 44.100 332.470 5532.35 5582.90 3050.48 N 1661.02 W 5969182.93 N 706307.73 E 1.102 3473.38 7012.87 45.150 332.910 5599.05 5649.60 3108.97 N 1691.21 W 5969240.56 N 706275.92 E 1.168 3539.19 .~ 7104.62 42.310 331.190 5665.34 5715.89 3165.00 N 1720.91 W 5969295.74 N 706244.68 E 3.355 3602.60 7201.56 38.590 330.950 5739.10 5789.65 3220.04 N 1751.33 W 5969349.91 N 706212.75 E 3.841 3665.48 7294.83 36.090 331.030 5813.25 5863.80 3269.51 N 1778.76 W 5969398.60 N 706183.96 E 2.681 3722.05 7387.54 36.340 331 .490 5888.04 5938.59 3317.54 N 1805.10 W 5969445.88 N 706156.30 E 0.398 3776.82 7480.59 34.220 331.930 5964.00 6014.55 3364.85 N 1830.57 W 5969492.48 N 706129.53 E 2.295 3830.56 7573.61 32.230 330.810 6041.81 6092.36 3409.59 N 1854.98 W 5969536.52 N 706103.89 E 2.239 3881.52 7666.63 31 .180 329.920 6120.95 6171.50 3452.09 N 1879.15 W 5969578.33 N 706078.55 E 1.236 3930.40 7757.17 30.590 329.190 6198.65 6249.20 3492.15 N 1902.70 W 5969617.73 N 706053.91 E 0.772 3976.85 7851.65 29.260 328.790 6280.53 6331.08 3532.55 N 1926.97 W 5969657.44 N 706028.52 E 1 .423 4023.95 7945.56 29.41 0 329.030 6362.40 6412.95 3571.95 N 1950.73 W 5969696.17 N 706003.68 E 0.203 4069.91 8038.48 25.550 328.600 6444.82 6495.37 3608.63 N 1972.92 W 5969732.22 N 705980.48 E 4.160 4112.74 8133.85 23.730 328.710 6531.50 6582.05 3642.59 N 1993.60 W 5969765.59 N 705958.87 E 1.909 4152.45 U~--~._---~--~--------- ~ -- ---------~-_.------------~ 13 August, 2002 - 14:54 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services .' Survey Report for PSI-09 Your Ref: API 500292309500 Job No. A KZZ221 04, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (1t) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8228.50 24.060 328.400 6618.04 6668.59 3675.29 N 2013.61 W 5969797.73 N 705937.97 E 0.373 4190.75 8321.74 24.860 328.740 6702.91 6753.46 3708.24 N 2033.74 W 5969830.10 N 705916.93 E 0.871 4229.31 8414.76 25.740 328.480 6787.01 6837.56 3742.17 N 2054.44 W 5969863.45 N 705895.29 E 0.954 4269.02 8509.84 25.520 329.420 6872.73 6923.28 3777.40 N 2075.66 W 5969898.08 N 705873.11 E 0.486 4310.11 8602.65 24.700 330.000 6956.77 7007.32 3811.41 N 2095.52 W 5969931.52 N 705852.31 E 0.922 4349.47 8696.69 25.310 330.060 7042.00 7092.55 3845.84 N 2115.38 W 5969965.39 N 705831.51 E 0.649 4389.21 8791.50 26.210 329.610 7127.38 7177.93 3881.47 N 2136.09 W 5970000.43 N 705809.82 E 0.971 4430.40 8882.76 23.320 329.070 7210.24 7260.79 3914.35 N 2155.57 W 5970032.76 N 705789.43 E 3.176 4468.60 8980.81 23.100 329.230 7300.36 7350.91 3947.53 N 2175.39 W 5970065.37 N 705768.71 E 0.233 4507.22 9075.09 23.580 328.730 7386.92 7437.47 3979.54 N 2194.64 W 5970096.84 N 705748.58 E 0.551 4544.54 9164.79 24.320 328.220 7468.90 7519.45 4010.57 N 2213.68 W 5970127.34 N 705728.68 E 0.857 4580.90 9260.79 22.620 327.800 7556.95 7607.50 4043.00 N 2233.93 W 5970159.19 N 705707.54 E 1.779 4619.07 9353.84 19.780 328.610 7643.70 7694.25 4071.59 N 2251.67 W 5970187.28 N 705689.02 E 3.068 4652.66 9446.25 18.950 328.800 7730.88 7781.43 4097.77 N 2267.58 W 5970213.01 N 705672.38 E 0.901 4683.27 9541.84 18.510 328.740 7821.41 7871.96 4124.02 N 2283.50 W 5970238.80 N 705655.74 E 0.461 4713.94 9637.38 18.500 329.200 7912.01 7962.56 4150.00 N 2299.13 W 5970264.34 N 705639.40 E 0.153 4744.23 9729.68 18.320 330.510 7999.58 8050.13 4175.21 N 2313.77 W 5970289.13 N 705624.07 E 0.489 4773.37 9823.88 18.420 331.090 8088.98 8139.53 4201 .12 N 2328.25 W 5970314.64 N 705608.87 E 0.221 4803.06 ~ 9841.35 18.430 331.340 8105.56 8156.11 4205.96 N 2330.91 W 5970319.40 N 705606.08 E 0.456 4808.58 9981.44 18.160 332.870 8238.57 8289.12 4244.82 N 2351.49 W 5970357.68 N 705584.44 E 0.393 4852.55 10074.12 17.480 331.990 8326.80 8377.35 4269.97 N 2364.61 W 5970382.45 N 705570.62 E 0.789 4880.90 10168.03 16.570 331.980 8416.59 8467.14 4294.24 N 2377.52 W 5970406.35 N 705557.04 E 0.969 4908.40 10263.55 15.870 331 .430 8508.31 8558.86 4317.73 N 2390.17W 5970429.49 N 705543.75 E 0.750 4935.08 10279.94 15.800 331.580 8524.08 8574.63 4321.66 N 2392.30 W 5970433.36 N 705541.51 E 0.495 4939.55 10343.00 15.800 331.580 8584.76 8635.31 4336.77 N 2400.47 W 5970448.23 N 705532.92 E 0.000 4956.72 Projected Survey -_._--~- ~ -------_.~-- ~---~~--------- -----_.-----_._~~- -- 13 August, 2002 - 14:54 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PS/-09 Your Ref: AP/500292309500 Job No. AKZZ22104, Surveyed: 17 July, 2002 . North Slope Alaska BPXA lisburne PSI (East Dock) All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI slot I. Northings and Eastings are relative to PSI slot I. -~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI slot I and calculated along an Azimuth of 331.350° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10343.00ft., The Bottom Hole Displacement is 4956.79ft., in the Direction of 331.035° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10343.00 8635.31 4336.77 N 2400.47 W Projected Survey Survey tool program for PS/-09 ~ From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 10343.00 8635.31 AK-6 BP _IFR-AK ------~-._--~---- ---~------ -~--- -~-~-'-------~'--------------_._---~-------------- - ------ 13 August, 2002 - 14:54 Page 6 of 6 DrillQuest 2.00.08.005 ~Od- /01 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well PSI-09 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~;/ !(~ ? '; L?OO2 /- ¡.... '..¡ ..... \.... AlaskaOil&GasCOns.Commisfon AnChorage North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI slot I PSI-09 MWD Job No. AKMW22104, Surveyed: 17 July, 2002 SURVEY REPORT 13 August, 2002 Your Ref: API 500292309500 Surface Coordinates: 5966179.63 N, 708052.62 E (70018' 39.4389" N, 148018' 50.1224" W) Kelly Bushing: 50.55ft above Mean Sea Level .~ S~t=I""'''''\I-5UI! D ÃrCCl~rG'!¡ínæ R \Ii ë:-E;..!:! A Halliburton Company Survey Ref: svy11273 Sperry-Sun Drilling Services . Survey Report for PSI-09 MWD Your Ref: API 500292309500 Job No. AKMW22104, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (1t) (ft) (ft) (ft) (ft) (ft) (1t) (°/1 OOft) 0.00 0.000 0.000 -50.55 0.00 0.00 N 0.00 E 5966179.63 N 708052.62 E 0.00 MWD Magnetic 115.00 0.020 198.430 64.45 115.00 0.02 S 0.01 W 5966179.61 N 708052.61 E 0.017 -0.01 210.92 0.120 21.200 160.37 210.92 0.06 N 0.02 E 5966179.69 N 708052.64 E 0.146 0.04 305.42 0.080 150.200 254.87 305.42 0.09 N 0.09 E 5966179.73 N 708052.71 E 0.192 0.04 424.90 0.120 314.320 374.35 424.90 0.11 N 0.05 E 5966179.74 N 708052.66 E 0.166 0.07 507.64 0.300 85.890 457.09 507.64 0.18 N 0.20E 5966179.82 N 708052.81 E 0.471 0.07 596.76 1.690 341 .350 546.20 596.75 1 .45 N 0.01E 5966181.08 N 708052.59 E 2.007 1.26 658.15 2.810 345.550 607.54 658.09 3.76 N 0.65W 5966183.37 N 708051.86 E 1.843 3.61 752.96 3.440 343.630 702.21 752.76 8.74 N 2.03W 5966188.31 N 708050.34 E 0.674 8.65 847.72 3.840 328.230 796.78 847.33 14.17 N 4.51 W 5966193.67 N 708047.72 E 1.110 14.59 941.37 4.900 324.540 890.15 940.70 20.09 N 8.48 W 5966199.48 N 708043.59 E 1.170 21.70 1035.22 6.190 336.920 983.57 1034.12 28.01 N 12.79 W 5966207.28 N 708039.06 E 1.867 30.71 1128.78 8.530 347.200 1076.35 1126.90 39.42 N 16.30 W 5966218.58 N 708035.23 E 2.860 42.41 1223.88 9.800 343.950 1170.24 1220.79 54.08 N 20.10 W 5966233.13 N 708031.03 E 1 .442 57.09 1255.43 10.240 340.520 1201.31 1251.86 59.30 N 21.78 W 5966238.30 N 708029.20 E 2.350 62.48 1316.69 10.280 334.280 1261.59 1312.14 69.36 N 25.97 W 5966248.24 N 708024.74 E 1.815 73.32 1348.27 10.600 331.390 1292.65 1343.20 74.45 N 28.58 W 5966253.26 N 708021.99 E 1.943 79.04 ~.. 1410.58 12.340 327.780 1353.71 1404.26 85.11 N 34.88 W 5966263.74 N 708015.40 E 3.019 91.41 1503.67 14.800 326.150 1444.20 1494.75 103.41 N 46.81 W 5966281.70 N 708002.97 E 2.674 113.19 1598.53 14.830 327.200 1535.90 1586.45 123.67 N 60.13 W 5966301.59 N 707989.09 E 0.285 137.36 1691.99 14.080 328.250 1626.40 1676.95 143.39 N 72.59 W 5966320.96 N 707976.08 E 0.850 160.64 1787.48 14.090 326.880 1719.02 1769.57 163.00 N 85.06 W 5966340.22 N 707963.08 E 0.349 183.83 1878.23 13.070 327.580 1807.23 1857.78 180.92 N 96.59 W 5966357.80 N 707951.05 E 1.138 205.08 1971.35 13.410 330.930 1897.88 1948.43 199.25 N 107.48 W 5966375.82 N 707939.66 E 0.901 226.38 2068.29 15.010 333.750 1991.85 2042.40 220.33 N 118.50 W 5966396.59 N 707928.06 E 1.798 250.17 2163.23 15.860 334.990 2083.37 2133.92 243.11 N 129.42 W 5966419.06 N 707916.51 E 0.960 275.40 2257.19 17.640 337.670 2173.34 2223.89 267.92 N 140.26 W 5966443.56 N 707904.99 E 2.065 302.37 2349.32 19.680 336.660 2260.62 2311.17 295.08 N 151.71W 5966470.39 N 707892.79 E 2.242 331.69 2442.76 21.330 336.400 2348.14 2398.69 325.10 N 164.75 W 5966500.04 N 707878.93 E 1.769 364.29 2536.23 23.380 337.040 2434.58 2485.13 357.76 N 178.79 W 5966532.30 N 707863.99 E 2.209 399.68 -~~-----_._~- ---~-----_._---- 13 August, 2002 - 14:56 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI-09 MWD Your Ref: API 500292309500 Job No. AKMW22104, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 2630.27 27.120 335.450 2519.62 2570.17 394.45 N 194.98 W 5966568.53 N 707846.79 E 4.042 439.64 2723.98 31.490 332.420 2601.32 2651.87 435.59 N 215.20 W 5966609.09 N 707825.44 E 4.923 485.44 2818.05 34.370 332.940 2680.27 2730.82 481.03 N 238.66 W 5966653.86 N 707800.73 E 3.076 536.56 2911.52 37.310 333.410 2756.03 2806.58 529.86 N 263.34 W 5966701.99 N 707774.70 E 3.159 591.25 3003.85 39.270 334.000 2828.50 2879.05 581.15 N 288.68 W 5966752.56 N 707747.95 E 2.159 648.41 3097.54 39.640 333.440 2900.84 2951.39 634.54 N 315.04 W 5966805.19 N 707720.12 E 0.548 707.90 3188.40 40.320 331.820 2970.46 3021.01 686.37 N 341.88 W 5966856.27 N 707691.85 E 1.368 766.26 3284.92 43.120 331.020 3042.50 3093.05 742.77 N 372.62 W 5966911.79 N 707659.56 E 2.953 830.48 3378.48 44.010 330.430 3110.29 3160.84 799.01 N 404.15 W 5966967.14 N 707626.49 E 1.046 894.96 3471.21 45.040 330.710 3176.40 3226.95 855.64 N 436.10 W 5967022.86 N 707592.98 E 1.131 959.97 3560.52 44.000 332.630 3240.08 3290.63 910.75 N 465.82 W 5967077.13 N 707561.74 E 1.905 1022.59 3660.57 45.860 332.980 3310.91 3361.46 973.60 N 498.11 W 5967139.06 N 707527.73 E 1.875 1093.22 3752.91 47.240 334.120 3374.42 3424.97 1033.62 N 527.96 W 5967198.23 N 707496.23 E 1.743 1160.20 3843.04 48.140 333.460 3435.09 3485.64 1093.42 N 557.40 W 5967257.18 N 707465.14 E 1.136 1226.79 3935.01 46.510 334.660 3497.43 3547.98 1154.21 N 586.99 W 5967317.14 N 707433.88 E 2.015 1294.33 4032.41 46.580 333.980 3564.42 3614.97 1217.93 N 617.62 W 5967379.98 N 707401.49 E 0.512 1364.94 4128.82 47.970 332.860 3629.83 3680.38 1281.26 N 649.32 W 5967442.41 N 707368.05 E 1.675 1435.71 .~ 4218.85 48.650 332.760 3689.71 3740.26 1341.07N 680.04 W 5967501.34 N 707335.69 E 0.760 1502.92 4309.96 48.650 332.670 3749.90 3800.45 1401.85 N 711.39 W 5967561.23 N 707302.66 E 0.074 1571.30 4403.93 47.820 332.070 3812.49 3863.04 1463.95 N 743.90 W 5967622.41 N 707268.45 E 1.003 1641.38 4501.46 47.380 333.330 3878.26 3928.81 1527.94 N 776.93 W 5967685.46 N 707233.66 E 1.055 1713.38 4598.27 47.990 332.610 3943.43 3993.98 1591.71 N 809.46 W 5967748.30 N 707199.37 E 0.836 1784.93 4693.18 48.490 332.980 4006.64 4057.19 1654.67 N 841.83 W 5967810.35 N 707165.27 E 0.602 1855.71 4787.43 48.860 331.540 4068.88 4119.43 1717.31 N 874.78 W 5967872.05 N 707130.60 E 1.213 1926.47 4882.37 47.930 330.070 4131.92 4182.47 1779.29 N 909.40 W 5967933.04 N 707094.28 E 1.517 1997.46 4977.54 48.230 331.530 4195.50 4246.05 1841.10 N 943.94 W 5967993.87 N 707058.04 E 1.184 2068.26 5070.49 47.790 329.350 4257.69 4308.24 1901.19 N 978.01 W 5968052.99 N 707022.31 E 1.806 2137.33 5165.63 48.070 328.040 4321.44 4371.99 1961.53 N 1014.71 W 5968112.29 N 706983.96 E 1.064 2207.88 5258.43 48.450 328.850 4383.22 4433.77 2020.53 N 1050.95 W 5968170.27 N 706946.10 E 0.769 2277.03 5353.60 49.390 330.640 4445.76 4496.31 2082.50 N 1087.08 W 5968231.21 N 706908.26 E 1.728 2348.74 -----~------------_._~-_._-- --~---_.~-- ~-----.~----~- 13 August, 2002 - 14:56 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI-09 MWD Your Ref: API 500292309500 Job No. AKMW22104, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Easti ngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/1 OOft) 5444.82 50.430 331.570 4504.51 4555.06 2143.60 N 1120.80W 5968291.35 N 706872.87 E 1.381 2418.52 5535.90 51.020 330.960 4562.17 4612.72 2205.42 N 1154.70 W 5968352.21 N 706837.27 E 0.830 2489.03 5590.61 50.660 330.400 4596.71 4647.26 2242.41 N 1175.47 W 5968388.61 N 706815.48 E 1.031 2531 .44 5684.91 50.760 330.290 4656.43 4706.98 2305.83 N 1211.58 W 5968451.01 N 706777.63 E 0.139 2604.42 5781.75 47.880 329.930 4719.55 4770.10 2369.50 N 1248.17 W 5968513.64 N 706739.29 E 2.987 2677.83 5875.27 46.400 329.730 4783.16 4833.71 2428.76 N 1282.62 W 5968571.93 N 706703.21 E 1.590 2746.36 5972.98 46.390 331.240 4850.55 4901.10 2490.33 N 1317.47 W 5968632.50 N 706666.66 E 1.119 2817.10 6070.43 44.580 331 .400 4918.87 4969.42 2551.29 N 1350.82 W 5968692.52 N 706631.64 E 1.861 2886.58 6164.16 43.090 329.660 4986.48 5037.03 2607.81 N 1382.74 W 5968748.13 N 706598.16 E 2.044 2951.49 6259.75 43.250 331.330 5056.20 5106.75 2664.72 N 1414.95 W 5968804.13 N 706564.39 E 1.207 3016.87 6353.36 43.800 331.570 5124.07 5174.62 2721.35 N 1445.76 W 5968859.88 N 706532.02 E 0.613 3081.34 6450.50 43.940 332.070 5194.10 5244.65 2780.69 N 1477.55 W 5968918.32 N 706498.60 E 0.385 3148.66 6543.78 44.990 332.390 5260.67 5311.22 2838.50 N 1507.99 W 5968975.27 N 706466.57 E 1.151 3213.99 6637.68 43.970 332.570 5327.67 5378.22 2896.85 N 1538.39 W 5969032.75 N 706434.57 E 1.095 3279.77 6730.83 42.880 333.430 5395.32 5445.87 2953.90 N 1567.46 W 5969088.97 N 706403.92 E 1.331 3343.77 6825.27 43.120 333.150 5464.39 5514.94 3011 .43 N 1596.41 W 5969145.68 N 706373.39 E 0.325 3408.14 6919.16 44.100 332.740 5532.37 5582.92 3069.11 N 1625.87 W 5969202.51 N 706342.35 E 1.086 3472.88 7012.87 45.150 333.590 5599.07 5649.62 3127.84 N 1655.58 W 5969260.41 N 706311.02 E 1.289 3538.67 7104.62 42.310 331 .850 5665.36 5715.91 3184.21 N 1684.62 W 5969315.95 N 706280.43 E 3.361 3602.06 7201.56 38.590 331 .830 5739.12 5789.67 3239.65 N 1714.30 W 5969370.55 N 706249.23 E 3.837 3664.94 7294.83 36.090 331 .400 5813.26 5863.81 3289.42 N 1741.19 W 5969419.55 N 706220.97 E 2.695 3721.51 7387.54 36.340 331 .520 5888.06 5938.61 3337.54 N 1767.36 W 5969466.93 N 706193.48 E 0.280 3776.28 7480.59 34.220 331.900 5964.02 6014.57 3384.86 N 1792.83 W 5969513.52 N 706166.70 E 2.291 3830.02 7573.61 32.230 330.810 6041.83 6092.38 3429.59 N 1817.25 W 5969557.56 N 706141.05 E 2.234 3880.98 7666.63 31 .180 329.880 6120.97 6171.52 3472.08 N 1841 .43 W 5969599.36 N 706115.70 E 1.245 3929.86 7757.17 30.590 329.330 6198.67 6249.22 3512.17 N 1864.94 W 5969638.78 N 706091.09 E 0.722 3976.32 7851.65 29.260 329.560 6280.55 6331.10 3552.75 N 1888.90 W 5969678.69 N 706066.01 E 1.413 4023.42 7945.56 29.410 329.280 6362.42 6412.97 3592.36 N 1912.31 W 5969717.63 N 706041.52 E 0.216 4069.40 8038.48 25.550 328.870 6444.84 6495.39 3629.14 N 1934.33 W 5969753.79 N 706018.49 E 4.159 4112.24 8133.85 23.730 329.250 6531.52 6582.07 3663.24 N 1954.78 W 5969787.31 N 705997.10 E 1.916 4151 .97 ~'--'~-----~---- ----_._---~~ -----~-----~-----~--------------_.- - --------------_.---- - 13 August, 2002 - 14:56 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services .' Survey Report for PSI-09 MWD Your Ref: API 500292309500 Job No. AKMW22104, Surveyed: 17 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8228.50 4190.29 ~, 24.060 330.260 6618.06 6668.61 3696.36 N 1974.09 W 5969819.88 N 705976.88 E 0.555 8321.74 24.860 329.590 6702.93 6753.48 3729.77 N 1993.44 W 5969852.74 N 705956.62 E 0.908 4228.88 8414.76 25.740 328.410 6787.03 6837.58 3763.84 N 2013.92 W 5969886.23 N 705935.20 E 1.090 4268.60 8509.84 25.520 329.730 6872.75 6923.30 3799.11 N 2035.06 W 5969920.90 N 705913.09 E 0.644 4309.69 8602.65 24.700 329.500 6956.79 7007.34 3833.09 N 2054.98 W 5969954.31 N 705892.24 E 0.890 4349.06 8696.69 25.310 329.400 7042.02 7092.57 3867.32 N 2075.18 W 5969987.97 N 705871.09 E 0.650 4388.79 8791.50 26.210 329.510 7127.40 7177.95 3902.81 N 2096.12 W 5970022.87 N 705849.18 E 0.951 4429.97 8882.76 23.320 329.140 7210.26 7260.81 3935.69 N 2115.62 W 5970055.19 N 705828.78 E 3.171 4468.17 8980.81 23.100 329.060 7300.38 7350.93 3968.84 N 2135.46 W 5970087.79 N 705808.03 E 0.227 4506.78 9075.09 23.580 329.100 7386.94 7437.49 4000.89 N 2154.65 W 5970119.29 N 705787.95 E 0.509 4544.10 9164.79 24.320 328.510 7468.92 7519.47 4032.03 N 2173.51 W 5970149.90 N 705768.23 E 0.867 4580.48 9260.79 22.620 327.950 7556.97 7607.52 4064.54 N 2193.64 W 5970181.84 N 705747.22 E 1.786 4618.65 9353.84 19.780 328.350 7643.72 7694.27 4093.12 N 2211 .40 W 5970209.91 N 705728.67 E 3.056 4652.25 9446.25 18.950 328.700 7730.90 7781.45 4119.25N 2227.40 W 5970235.59 N 705711.95 E 0.907 4682.85 9541 .84 18.510 328.910 7821.43 7871.98 4145.50 N 2243.30 W 5970261.39 N 705695.33 E 0.466 4713.52 9637.38 18.500 329.400 7912.03 7962.58 4171.54 N 2258.85 W 5970286.99 N 705679.07 E 0.163 4743.82 9729.68 18.320 330.830 7999.60 8050.15 4196.81 N 2273.37 W 5970311.85 N 705663.85 E 0.527 4772.96 9823.88 18.420 331 .430 8089.00 8139.55 4222.81 N 2287.70 W 5970337.44 N 705648.80 E 0.227 4802.64 ~ 9841.35 18.430 331.780 8105.58 8156.13 4227.66 N 2290.33 W 5970342.22 N 705646.04 E 0.636 4808.17 9981.44 18.160 333.150 8238.59 8289.14 4266.65 N 2310.66 W 5970380.63 N 705624.64 E 0.362 4852.13 10074.12 17.480 332.040 8326.82 8377.37 4291.83 N 2323.71 W 5970405.44 N 705610.90 E 0.820 4880.48 10168.03 16.570 331.980 8416.61 8467.16 4316.11 N 2336.61 W 5970429.35 N 705597.33 E 0.969 4907.98 10263.55 15.870 331.000 8508.33 8558.88 4339.56 N 2349.34 W 5970452.44 N 705583.95 E 0.787 4934.66 10279.94 15.800 331.670 8524.10 8574.65 4343.48 N 2351.49 W 5970456.30 N 705581.70 E 1.194 4939.13 10343.00 15.800 331.670 8584.78 8635.33 4358.60 N 2359.64 W 5970471.18 N 705573.13 E 0.000 4956.30 Projected Survey -_._.-----~-----~--- ~-~----------------- -- -----~_._-~----~-- ----._~-------_.- .--------- 13 August, 2002 - 14:56 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI-09 MWD Your Ref: API 500292309500 Job No. AKMW221 04, Surveyed: 17 July, 2002 ,j)' North Slope Alaska BPXA Lisburne PSI (East Dock) All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI slot I. Northings and Eastings are relative to PSI slot I. .~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI slot I and calculated along an Azimuth of 331.350° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10343.00ft., The Bottom Hole Displacement is 4956.34ft., in the Direction of 331.570° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10343.00 8635.33 4358.60 N 2359.64 W Projected Survey Survey tool program for PSI-09 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 10343.00 8635.33 MWD Magnetic ------ -------------~-_._----_.~--~ - ---------..------------------.----- - ------_w .-- ---- 13 August, 2002 - 14:56 Page 6 of 6 DrillQuest 2.00.08.005 Shared Services Drilling ~. '" ,..,. doa-Iav Handover Form To Drilling: Well: PSI-09 To Production: XXXXX AFE Number: PBZ4P1923 Well Information Pre Rig Work Cost: $ API Number: 50-029-23095 SITP: 0 Production Csg Pressure: 0 Surface Csg Pressure: 0 BHP: Depth:8635 (TVD) Freeze Protection Fluid: Weight: Diesel 6.8 ~p~ w~tp-r 8.5 Date: 7/22/2002 Date:7/22/2002 Date: 7/22/2002 Date: 7/22/2002 Frz Prot? Depth: 0-2200 ??00-10?57 Amount: 138 bbl 144 hhl Surface x Int. Annulus: Inj. Well: Yes Inj. Well: yes yes Annulus: Annulus: Tubing: Tubing: Tree Type: Inlay Top of Fill or Junk: BPV Installed (Yes/No): Yes Dummy GLV's (Yes/No): No New Casing String Installed During this Workover (Yes/No): Wellbore Fluids Fluid Type: Weight: nie~el 6.8 ~e~w~ter 8.5 nie~el 6.8 ~e~w~ter 8.5 Downhole Information PBTD: 10257 Last TD tag Date: 7/20/2002 Downhole Plugs (Yes/No): SSSV and Insert (Yes/No): Yes No Yes SPF: Depth: O-??OO 1 : ??00-9767 2: O-??OO 3: ??00-9767 4: Perf Intervals From: Fluid Loss During Workover Fluid Type: Weight: Amounts (bbls): To: Perfs Squeezed: . Nn * General Information wøu~was--dri!IAd~tft-un-1n~4~.c-A--7-1! -linAr-ftJnwiJhtqp- ::!!tuAA121;andÞndina- ~nnar ilt 1n9~71. Thl\ w~1I waA ~nmpl~t~d with 7 ~/A11 tuhi~a frnm Allrfa~~ with W. Fn at Q7R71 II th~ PKR at Q79A1. Th~ tubinv and annuluA w~r~ t~At~d tn 4nnn pAi. Th~ 7 ~/A" X Q !!?alA" annulllA iA fr~~~~ prnt~~t~d tn 9~nnl with di~A~1 and tr~at~d A~a wat~r tn Q7R71. * Fish (attach diagram of fish), tight spots, leaks, etc. Attach Tubing and Completion Detail Forms. Completion Equipment MfgrJType/Size/Dummy or Orifice/Latch SSSV: Land Nipple: GLM: GLM: GLM: GLM: GLM: GLM: GLM: GLM: GLM: GLM: GLM: GLM: X Nipple: Sldg Sleeve: PBR/SBR: Packer: X Nipple: WLEG: Blast Ring Packer: X Nipple: NoGo Nipple: Shear Sub: WLEG: C~mco nR Nipple for i~ection v~lve Top (md) ft ?163 R NIPP. F 6.?76 In 9659 PRR RAKFR T' X 9 5/8" ~AR. -3 pkr with '0' PRR R NIPP. F. 5.963 In RN Nn Gn NIPP. F. 5.77" In 9669 97?8 9744 9755 W. FG 7" 9767 Drlg Rep: nllnr.~n Fp-r~lI~nn Title: nrillin~ ~llPp-rvi~nr Revised: 10/25/95 by SRW Datp-: 7/??/?OO? Production Rep: Titlp-: PI= Date: ( TREE = 7 -1/16" 5K CIVIl WELLHEAD = 13-518" 5K FMC ACTl.IÞ. TOR= KB. B.EV = BF. B.EV = KOP= Wax Angle = Datum M) = Datum lVD = 52' 22' 1400' 51 @ 5536' 10255' 8500' SS 113-318" CSG, 68#, L-80, ID = 12.400" H 5588' 17-518" lEG, 29.7#, .0459 bpf, ID = 6.875" H 9647' Minimum ID = 5.770" @ 9755' 7" HES RN NIPPLE 17" TBG, 26#, .0383 bpf, ID = 6.276" H 9768' PffiFORA TION SUM~ RY RB= LOG: SWS JEWELRY LOG 07/29/02 ANGLEA TTOP PffiF: 17 @ 10135' /'.bte: Refer to A'oduction DB for hislorical perf dam SIZE SFF INTffiVAL Opn/Sqz DATE 3-318" 6 10135-10165 0 07/30/02 3-318" 6 10175- 10186 0 07/30/02 3-318" 6 10196 - 10246 0 07/30/02 ( I SAÆ1YNOTES: PSI-09 J. .1.-; 959' H 13-318" TAM PORT COLLAR I \. -'----- I 2161' H7-5/8"X 7" XO, D =6.276"1 r ""\-. ~ 2162' H7"CAMCO œ NP, D =6.000" 1 .. j 2164' H 7 -5/B" X 7" XO. ID = 6,276" I ~ ~ J l g f g 19-5/8" CSG, 47#, L-80, ID =8.681" H 9920' ¡--' ~ I P8TD H 10300' I ~.. T'LNR,26#,L-80,.0383bpf,ID=6.276" H 10345' ~ DA TE REV BY COMv1ENTS 07/22/02 DAC/KK 0 RIG INA L COMPLETON 07/30/02 TrvN/KK IPffiFS & B.M TT LOGGED DATE REV BY 1 9647' H7-518" X7"XO, ID= 6.276" I t 9659' H 7" I-ES R NIP, D = 5.963" I I 9673' H FeR, ID = 6.270" 1 & 9713' H7"X9-5/8"BKRSABL-3PKR,D=6.0" I 9743' H 7" HES R NIP, ID = 5.963" I 9755' H 7" HES RN NP, ID = 5.770" I 9768' H 7" WLEG, ID = 6.276" I 9766' 1-1 B.MD TT LOGGED 07/30/02 I &) 9827' H7" X 9-5/8" BKR ZXP LNR TOP R<R W / TIEBA CK SL V ~ COMM:NTS PRUDHOE BAY UNIT WELL: FSI-09 PffiMT /'.b: 2021240 A R No: 50-029-23095 3876' NSL, 4351'WEL, SEC. 15, T11, R15E BP Exploration (Alaska) Schlumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~~ Well PSI-09 ~...lat..J P-23 J 't~... /J ;¡ K-07C /qq - In'1 D.S.17-22d(')-O¡q GNI-03 Jq7"'J~Cf D-28AL 1 1'17... 014 K-03A I q q-oo R K-12A ~o -ó} Oï K-09B I f../Î-O~4> PSI-09~()õ- Ja'-l - BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Color Date Blueline Sepia Prints CD 07/29/02 1 08/02/02 1 08/03/02 1 08/04/02 1 07/28/02 1 08/03/02 1 08/02/02 1 08/04/02 1 08/05/02 1 07/30/02 1 Job# Log Description BASETEMP~EWELRYLOG LEAK DETECTION LOG STATIC SURVEY STATIC SURVEY SHUT-IN TEMP SURVEY STATIC SURVEY STATIC SURVEY STATIC SURVEY STATIC PRESS SURVEY SBHP LOG RECEIVED AUG 1 6 2002 Alaska Qii & Gas Cons. Commission Anchorage 08/15/02 NO. 2319 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 :~~i~&W~ 08105/02 Scblumbepger NO. 2287 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ Well Job # Log Description Color Date Blueline Sepia Prints CD 05/07/02 07/18/02 2 06/21/02 2 H-36A aoo...Qd 5 PSI-09 d[)Õ)- Jd'-J PSI-06 ~~- 0 ï ~ 22254 MCNL 22325 PROCESSED DSI 22320 USIT ~'" BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received~ ,(~ OOO~ Date Delivered: AUG 0 9 2002 Alaska Oil & GèI5 Cons. Commission Anchorage ( ,Hubble, Terrie L From: Sent: To: Cc: Subject: Quay, Walter (Natchiq) Monday, July 22, 2002 10:45 AM Hubble, Terrie L; Robertson, Brian B Tirpack, Robert B FW: PSI-09 Packer to Injected Zone Distance Walter, This confirms AOGCC's verbal approval of your proposed completion of well PSI-09 outlined below. All other permit stipulations apply. Please submit a detailed Form 10-403 as required. Winton Aubert AOGCC 793-1231 "Quay, Walter (Natchiq)" wrote: > Winton, > With our present Ops, with 9-5/8" set, the 7" liner is presently being > run(planning for a 107' of overlap), the preliminary space outs from the > injected zone to the packer will exceed the 200' limit as per 20 AAC 25.412 > (b). The tallys and measurements are subject to some change, with the 7" > liner actually being landed and set, along with the space out and make up of > the tail pipe and setting of the packer, etc. but the present operations > project the packer to injected zone distance as less than 250'. . My latest > estimate of this distance is 220' from packer to injection zone./The USIT > has been run and shows good isolation through the HRZ. > > I would request your approval of this different packer placement distance, > exceeding the 200' limit, but less than 250' from packer to injected zone. > > Walter Quay > quaywd@bp.com > (907)564-4178 > (907)440-8632 - Cell 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL IJ Suspend IJ Plugging IJ Time Extension IJ Perforate IJ Repair Well IJ Pull Tubing IJ Variance IJ Other IJ Operation Shutdown IJ Re-Enter Suspended Well IJ Stimulate . .. ( 1. Type of Request: IJ Abandon / IJ Alter Casing II Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic 1m Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3876' NSL, 4351" WEL, SEC. 15, T11N, R15E, UM At top of productive interval 2827' NSL, 1374' WEL, SEC. 09, T11N, R15E, UM At effective depth (As Planned) At total depth 2946' NSL, 1439' WEL, SEC. 09, T11 N, R15E, UM (As Planned 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10343 feet 8636 feet 10299 feet 8621 feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented 108' 5588' 9920' 530' 34" X 20" 13-3/8" 9-518" 7" 260 sx Arcticset (Approx.) 1329 sx AS III Lite, 601 sx 'G' 618 sx Class 'G' 145 sx Class IG' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 7-5/8",29.7#, L-80 to 97671 Alaska Oil & CommissuJ! Anchorage 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended Packers and SSSV (type and measured depth) 9-7/8" Baker 'SABL-3' packer at 9728" 13. Attachments 1m Description Summary of Proposal 14. Estimated date for commencing operation July 19, 2002 16. If proposal was verbally approved / Winton Aubert 7/19/2002 Name of approver Date Approved Contact Engineer Name/Number: Walter Quay, 564-4178 17. I hereby certify that the foregoi~9 is .true and correct to the best of my knowledge Signed B. R b rtso "'..(1~.'.' . :l..~ Title Senior Drilling Engineer rlan 0 en'. J ~,~I Service Water Injection ~G¡t 1/l~/OL- ..J ç II-¡,~(~ . Y)(}J 7/¿3 6. Datum Elevation (DF or KB) Plan KB = 52.1 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /" PSI.09 9. Permit Number 202-124 10. API Number 50- 029-23095-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool MD TVD 108' 5588' 9922' 9813' - 10343' 108' 4647' 8265' 8151' - 8636' ECE I F ~"JII,I rUI ')? "002. y =- L....~ L 1.i 0 BOP Sketch Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test '-- Subsequent form required 10- L/ 0 7 Approved by order of the Commission Form 10-403 Rev. 06/15/88 0f1gtn~ ~fl~(' 1 N A L C8n~ny ~'~.JfLJ , .. \ . Date Approval No. 30 Z- :3 ;3C) M4 ~/~þ{w--. ( Commissioner Date /f &3 b~ Submit In +~Pli~te .. ." ~~~-O9 Completion 7-5/8",29.7#, ST-L, IPC, Injection Tubing (wIT' accessories) 7" x 5.963" HES R Nipple 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG u ~ ~ 7" x 9-5/8" Baker HMC Liner Hanger, ZXP Liner Top packer, and tieback sleeve 9-5/8 Casing+l- 8263' TVD; 9,922' MD TSAD - Est. Top Perf. Date 07 -22-02 Rev By woo ~ Comments / I Z _._--_u~ l XOver #4-Seal Assembly: 7 -5/8" STL Box X 7" TCII Pin Â 97'8' 9767' /' 9813' 99.'2' .. 9959' 7", 26#, L-80, BTC-M Injection Liner @ +/- 8643' TVD: 10,343' MD PROJECT: GCWI WELL: PSI-09 API NO: GPB Rotary Drilling Re: PSI-09 Packer to Injected Zone Distance ( Subject: Re: PSI-09 Packer to Injected Zone Distance Date: Fri, 19 Ju12002 09:47:19 -0800 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: "Quay, Walter (Natchiq)" <QuayWD@BP.com> Walter, This confirms AOGCC's verbal approval of your proposed completion of well PSI-09 outlined below. All other permit stipulations apply. Please submit a detailed Form 10-403 as required. Winton Aubert AOGCC 793-1231 "Quay, Walter (Natchiq)" wrote: > Winton, > With our present Ops, with 9-5/8" set, the 7" liner is presently being > run (planning for a 107' of overlap), the preliminary space outs from the > injected zone to the packer will exceed the 200' limit as per 20 AAC 25.412 > (b). The tallys and measurements are subject to some change, with the 7" > liner actually being landed and set, along with the space out and make up of > the tail pipe and setting of the packer, etc. but the present operations > project the packer to injected zone distance as less than 250'. My latest > estimate of this distance is 220' from packer to injection zone. The USIT > has been run and shows good isolation through the HRZ. > > I would request your approval of this different packer placement distance, > exceeding the 200' limit, but less than 250' from packer to injected zone. > > Wal ter Quay > quaywd@bp.com > (907)564-4178 > (907)440-8632 - Cell PSI-09 7" Liner Lap Subject: PSI-09 7" Liner Lap Date: Mon, 8 Jul2002 14:25:05 -0500 From: "Quay, Walter (Natchiq)" <QuayWD@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Robertson, Brian B" <RobertBB@BP.com>, "Tirpack, Robert B" <firpacRB@BP.com>, "Crane, Lowell R" <CraneLR@BP.com> Winton, The liner lap and completion for the well, PSI-09, will have a slight change from the drilling permit: The liner lap will be shortened from 150' to 50' The 7-5/8" X 7" completion string will be located 50' above the 7" liner tie-back sleeve. These changes are made based upon operational problems encountered in running and setting the first packer in PSI-06. Based upon the PSI-06 operations, the plan is to locate the WLEG above the 7" liner tie-back. To maintain easy WL access to the liner, we would like to be either located in the tie-back or -50' above the tieback as opted for in this well. This 50' added to the previously planned for 150' liner lap would already place the packer at the 200' distance from perfs... adding the WLEG and tailpipe assembly up to the packer, will put this packer over 200' above the perforation. Please contact me if you have any questions regarding this matter Walter Quay quaywd@bp.com (907)564-4178 (907)440-8632 - Cell ~. ¡r'!Æ^ 0' 1. [ ill! l'i¡ I~¡.' fi:\ n ¡7IA'. ((ù flj.7 íA. \ ,i U 'J !? ¡ ~ I f\ \ II f L \ "''' ¡ [\ / [j \ J j Lb U J J ~l\ U-J [¡-1j @ U\} lrJ AI/A~KA. OIL AND GAS CONSERVATION COltDlISSION Brian Robertson BP Exploration (Alaska), Inc. Drilling Department PO Box 196612 Anchorage Alaska 99519 Re: Pennitto Drill 202-124 Dear Mr. Robertson: July 1, 2002 TONY KNOWLES, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Last week the Commission approved the above-referenced application for pennit to drill. The approval letter inadvertently included two sentences from a template generally used for exploratory wells. Please disregard the following requirement that was included in the approval letters: "A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use." We apologize for any inconvenience this may have caused you. Sincerely, ~c~~ Chair @~. fK\~æ.i r=[:'~ Æ\r @@r.~ fK\ @ ~ lrU~ 1. 0 U u-Ù lLlJìJ @ ~~U1\ AI4A~1iA OIL AND GAS CONSERVATION COMMISSION .I I I I í / í / TONY KNOWLES, GOVERNOR Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit PSI -09 BP Exploration (Alaska), Inc. Permit No: 202-124 Surface Location: 3876' NSL, 4351' WEL, Sec. 15, TIIN, RI5E, UM Bottomhole Location: 2946' NSL, 1439' WEL, Sec. 09, TllN, RI5E, UM Dear Mr. Roberson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned.. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ca11U11Vy ~. /~ V r-/ Cammy ({jechsli Tayl~r IS- Chair BY ORDER OF THE COMMISSION DATED thisJjj£day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 42" 16" 12-1/4" 8-112" ('. STATE OF ALASKA, ALASKA," .f- AND GAS CONSERVATION COMJ- -'ION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil B Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KB = 52.1 Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 034631 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / PSI-09 9. Approximate spud date 06/24/02 // Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10279' MD I 8641' TVD " 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 41 0 Maximum surface 3000 psig, At total depth (TVD) 8641' / 3864 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 73' 73' Surface Surface 5299' 4563' Surface Surface 9876' 8263' 9726' 8120' 10279' 8641' V-IGA- bll)/"2- Y b(t~ 1 a. Type of work B Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3876' NSL, 4351' WEL, SEC. 15, T11N, R15E, UM At top of productive interval 2827' NSL, 1374' WEL, SEC. 09, T11N, R15E, UM At total depth 2946' NSL, 1439' WEL, SEC. 09, T11N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028322,2946' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 800' MD M~ximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 34" x 20" 91.51 # H-40 Welded 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-M 7" 26# L -80 BTC-M 11. Type Bond (See 20 MC 25.025) Number 2S100302630-277 Lenath 80' 5299' 9876' 553' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 1158 sx AS III Lite, 598 sx 'G' 431 sx Class 'G' 146 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED JUN 1 2 2002 Perforation depth: measured true vertical Alaska Oil & Gas Cons. GommisSlor¡ Anchorage B Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Walter Quay, 564-4178 Prepared By Name/Number: Terrie Hubble, 564-4628 21. ~~:~:y c:~~:::::e fore Oi~~~{;~i¡;~: e best eOf :n~:;~~~t:: Engineer 2ðO ~ Permit Number LI API Number 3 0 J\pp íO~ )0:" See cover letter 2.0.2.. - /2. 7' 50- () ¿, - 2- 0 I'S (f lvr 0\ for otherreQuirements Conditions of Approval: Samples Required 0 Yes M No Mud Log 'Hequiréd 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes 9 No Directional Survey Required J3 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Tesf BOPE ~ t¡Ot!Jf) f1St'~ ML:TCa.cAd evfl\-t'l~{£1 to &1 ~ð~NJd. 0nglnal Signed By by ordEM of ~i q~ Approved By Cammy OAdasli T~IOf 0, .., R.,orr" miSS. ¡one. r" ., 'the commission Date I ~ ~ Form 10-401 Rev. 12-01-85 , r"\ I G 11\1 A L mit n Triplicate 20. Attachments K".ell Name: PSI-09 ( I Drill and Complete Summary I Type of Well (producer or injector): 1 Injector - Water / Surface Location: (As Built) Target Location: Bottom Hole Location: x = 708,053 / Y = 5,966,180 1404' FNL, 929' FVVL, Sec. 15,T11N,R15E X = 705,625 / Y = 5,970,345 2453'FNL,3906'FVVL,Sec.9,T11N,R15E X = 705,556 / Y = 5,970,463 2333'FNL,3840'FVVL,Sec.09,T11N,R15E 1 AFE Number: 1 PBD4P1923 I I MD: 1 10,279' 1 / 1 TVD: 18,641' 1 I Estimated Start Date: I 06/24/02 1 I I Operatina days to complete: I 21.7 1 I Ria: I Nabors 27e 11 KB: 134.5' I 1 Ground Elevation: 117.6' I 1 KB Elevation: 1 52.1' 1 1 1 I Well Desian (conventional, slim hole, etc.): I Big Bore 1 Objective: I High rate water injection into Ivishak Gas Cap, Zones 4 through 1 Formation Markers (wp05) Tops MD TVDss Comments Base PF 1,883' -1820 8.6 ppg SV4 3870' -3438 8.6 ppg SV3 4414' -3847 8.6 ppg SV2 4682' -4049 8.6 ppg SV1 5192' -4433 8.6 ppg UG4 5882' -4952 8.6 ppg UG3 6602' -5494 8.6 ppg UG1 7055' -5835 8.6 ppg VVest Sak 2 7755' ,.6364 8.6 ppg VVest Sak 1 8001' -6557 8.6 ppg CM3 8238' -6750 8.6 ppg CM2 8972' -7380 8.6 ppg CM1 9242' -7623 8.6 ppg THRZ 9684' -8032 8.6 ppg BHRZ/LCU 9876' -8213 8.6 ppg TZ4 NA 7.5 ppg; HC Bearing TZ3 9876' -8213 7.5 ppg; HC Bearing TZ2 9941' -8274 7.5 ppg; HC Bearing BSAD 10214' -8324 7.5 ppg; HC Bearing TD 10279' -8591 7.5 ppg; TLSB N/ A -8641 8.6 ppg; HC Bearing Surface TD Criteria: Based on -100' TVD below SV1 Top. Intermediate TD Criteria: Casing to be set above BHRzrrZ4 transition. TD Criteria: Based on 50' TVD above TLSB. / / PSI-09 Drilling Permit.doc Page 1 CasinQITubinQ ProQram ( Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 42" Insulated 20" 91.51 # H-40 Welded 80' GL -73' 173' (34" 00) 16" 13-3/8" 68# L-80 BTC -5299' GL 5299' I 4563' / 12-1/4" 9-518" 47# L-80 BTC-M -9876' GL 9,876' I 8,263' 8-1/2" 7" 26# L-80 BTC-M -553' 9726' I 8,120' 10,279' I 8,641 ' TUbing 7-5/8" 29.7# L-80 STL -9276' GL 9276' I 8,120' Directional KOP: I 800' MO Maximum Hole Angle: Close Approach Well: -410 In intermediate section from 2800' to 7500' PSI-09 passes BP Clo~ Approach guidelines. The nearest well is East Bay State-1 which is -328' well-to-well at surface and PSI-06 which has a planned wellpath -92' Ctr-Ctr at 525'. Survey Program: Standard MWO Surveys from surface to TO. *Refer to the attached, approved Sperry directional program - wp05 Mud Program 16" Surface Hole I Freshwater Spud Mud From Surface to -80' TVO below top SV1 Interval Density Viscosity (ppg) (seconds) Initial to Base PF 8.8 - 9.5 200-300 Base PF to Top SV sands 9.0 - 9.5 / 100-150 Top SV sand to Interval TO 9.5 max'¡ 75-150 *Refer to the attached Baroid mud program for details 12-1/4" Intermediate Hole I LSND From Surface Casing Shoe to BHRZ Interval Density Plastic Viscosity YP (ppg) (cp) (lb/10ote) Initial to THRZ 9.0-9.5/ 10-15 25-30 THRZ to BHRZ 10.0 10-15 20-30 *Refer to the attached Baroid mud program for details 8-1/2" Production Hole I BARADRILn From Intermediate Casing Shoe to TO Interval Density Plastic Viscosity YP (ppg) / (cp) (lb/100ft2) Ivishak 8.8-9.0 10-15 17-25 *Refer to the attached Baroid mud program for details PSI-09 Drilling Permit.doc YP tauo API FL pH (lb/100fe) (lb/100ft2) (mls/30min) 50-70 >8 15-"-20 8.5-9.5 30-45 >6 4-10 8.5-9~5 20-35 >6 4-10 8.5 -9.5 tauo (lb/100ft2) 4-7 4-7 10' Gel API HTH P FL (mls/30min) 6-10 4-61<12.0 pH LGS 0/0 vol <5 <5 10 10 8.5-9.5 8.5-9.5 tauo (lb/100ft2) 3-5 10' Gel API HTH P FL (mls/30min) 4-6<12.0 pH 8.5-9.5 LGS 0/0 vol <5 10 Page 2 Integrity Testing ( The 13-3/8" surface casing point is expected to provide a fracture gradient of 12.5 to 13.5 ppg EMW. Fracture gradient information from offset are shown below: Well Name Formation TVDss Frac Gradient, PPG East State Bay-1 SV-4? 2745' TVDss 12.1 ppg EMW L2-32 SV-4 3589' TVDss 12.5 ppg EMW / L3-01 SV-3 4009' TVDss 13.8 ppg EMW L3-0S SV-3 4032' TVDss 12.5 ppg EMW PSI-06 SV-1 4576' TVD 13.4 ppg EMW Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. Below are the planned integrity test points. Test Point Depth Surface Casing Shoe 20' minimum below shoe Intermediate Casing Shoe 20' minimum below shoe Test Type FIT FIT EMW 12.0 ppg for -103 bbl kick tolerance ../ 10.0 ppg Well Evaluation Proaram ~ 16" Surface: Drilling: Open Hole: Cased Hole: Coring: Sampling: 12-1/4" Intermediate: Drilling: Open Hole: Cased Hole: Coring: Sampling: MWD / GR None None None Gas Detection - Entire Interval / MWD / GR / Res - Realtime from 500' above BHRZ to section TD None USIT None Cuttings Samples and Gas Detection - from 500' above BHRZ to section TD ..-- / 8-1/2" Production: Drilling: MWD / GR / NEU / LWD **- Realtime over entire interval Open Hole: None Cased Hole: None Coring: None Sampling: Cuttings Samples and Gas Detection - Entire Interval If PEX with DiPole sonic log was successfully run in PSI-06, then the PSI-09 productino will be drilled with GR/RES/NEW LWD. It the PEX was not successful in PSI-06 and the USIT shows good cement in PSI-09, the production hole will be logged with the GR only, and the WL PEX will be run in PSI-09. PSI-09 Drilling Permit.doc / Page 3 Cement Program (../ The following surface casing cement calculations are based upon a single stage job. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. In - the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of ./ the upcoming remedial cement work for possible witness of cement to surface. Casing Size 113-3/8" Surface I Basis: Lead: Open hole volume + 350% excess in permafrost; 50% excess below permafrost. Lead TOC: To Surface. Tail: Open hole volume + 500/0 excess + 82' shoe track volume. Tail TOC: 1000' MD above 13-3/8" shoe (-4298' MD) Fluid Sequence & Volumes: Pre 10 bbls CW100 at 8.3 ppg Flush Spacer Lead 75 bbls MudPUSH ViscosJfied Spacer weighted to 10.2 ppg 1150 bbl I 5039/fe I 1158 sks of Dowell ArticSET III-Lite at 10.7 ppg and 4.44 cf/sk, B~T 450 I BHCT 520, IT = 6.0 hrs 124 ~I I 696 fe I 598 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk, BHST 900 I BHCT 860, TT = 4 hrs *See Attached Dowell Cement Program for Details Tail Casing Size 19-5/8" Intermediate Basis: Lead: None Tail: Open hole volume + 50% excess + 82' shoe track volume Tail TOC: 1000' above 9-5/8" shoe (-8,876 MD) Fluid Sequence & Volumes: Pre 10 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 50 bbls MudPUSH Viscosified Spacer weighted to 11.5 ppg None / 90 bbl 1503 fQ431 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.16 cf/sk, BHST 1700 I BHCT 1310, TT = Batch Mix + 4.0 hrs *See Attached Dowell Cement Program for Details Liner Size I 7" Production Basis: Lead: None Tail: Open hole volume + 50% Excess + 82' shoe track + 150' liner lap + 200' of 9-5/8" x 5" DP annulus volume. Tail TOC: -9,526 MD (' TVD).- Liner top. Fluid Sequence & Volumes: Pre 30 bbls CW100 at 8.3 ppg Flush Spacer Lead Tail 30 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None ,( 30 bbl I 170 f~1 146 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.16 cf/sk, BHST 1810 I BHCT 1370, TT = Batch Mix + 3.5 hrs *See Attached Dowell Cement Program for Details PSI-09 Drilling Permit doc Page 4 Well Control ( Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 13-3/8" Casing Test pressure Intermediate Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test pressure Production Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingl7" Liner Test Planned completion fluids 20", 2M Diverter (Hydril - MSP) 2041 psi (8.6 ppg @ 4563' TVD) 1585 psi N/A Function test 3500 psi surface pressure I 13-3/8", 5M, 3 Gates with Annular (Hydril- GL) 3695 psi (8.6 ppg @ 8263' TV D) 2869 psi (.10~.Si/ft. g s gradient to surface) 103 bbls " '. don Ð \J GÆ- Rams test to ." si!250 psi. Annular test t 2 0 psi/250 psi 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3864 psi (8.6 ppg @ 8641' TVD) 3000 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 4,000psi/250 psi. Annular test to 2,500 psi/250 psi 4000 psi surface pressure /' 8.4 ppg Seawater / 6.8 ppg Diesel Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Drill and Complete Procedure Summary PSI-09 Drilling Permit.doc Page 5 (' (' Pre-Ria Work: 1 . The 20" insulated conductor is installed and the FMC landing ring for the FMC Big Bore wellhead on the 20" conductor and the 4" side outlet valves on the conductor pipe for surface cementing operations are in place. RiQ Operations: 1. Move Nabors 27e from PSI-06 toYSI-09 2. Nipple up and function test diverter system. P 5" ~P to drill surface hole and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR and ir ionally drill surface hole to approximately 5299' MD / 4563' TVD. The actual surface hole TD wj!U>e +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 13-3/8", 68# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface durin9:~imary cementing operations. 5. ND diverter system and NU casing 1 tubing head. NU BOPE and test to¡(3S0ð psi. 6. MU 12-1/4" drilling assembly with MWD/GR/Res and RIH to float collat/~est the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.0 ppg LSND drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. 8. Drill ahead as per directional plan and mud program. 9. Increase mud weight to 10.0 ppg prior to entering the HRZ. Short trip as required. 10. TD the 12-1/4" interval in the BHRZ. Get as close to the BHRZlTZ3 as possible without penetrating TZ3. 11. Run and cement the 9-5/8",47# intermediate casing to 1000' above the top of the shoe. Displace cement with 1 0.0 ppg mud. Freeze protect the 13-3/8" X 9-518" annulus to 2200' MD. / 12. OPTION: If cement job went poorly or is suspect, RU E-line. RIH with USIT. Log bottom 1000' MD of wellbore. Determine bond quality and TOC. POH. Otherwise continue with program. / 13. MU 8-1/2" drilling assembly with MWD/GR and RIH to float collar. Test the 9-5/8" casing to 35.00 psi for 30 minutes. 14. Drill out shoe joints and 20' of new formation. Formation Integrity Test will be the 10.0 ppg MW in the hole. Displace hole over to 9.0 ppg BARADRILn fluid. 15. Drill ahead as per directional plan to proposed TD at 10,279' MD 1 8641' TVD. The actual TD of the well will extend +1-60' TVD below the BSAD, but no deeper than 50' TVD above the TLSB. Short trip as required and condition hole for running the 7" liner. 16. RU E-Line. Make two possible logging runs: 1) If USIT was not run before, log bottom 1000' of 9-5/8" casing. Determine bond quality and TOC. 2) If PEX and sonic was not run in PSI-06, Log 8-1/2" open hole and 500' into 9-5/8" casing with PEX and Sonic. 17. Make open hole clean-out if necess~. 18. Run and cement the 7", 26# liner. The liner will extend up into the 9-5/8" casing -150' MD and will be fully cemented to the liner top. Displace cement with mud. POOH with drillpipe. 19. RIH with 6-1/8" bit, a scraper for the 7",26# liner, and a scraper for 9-5/8",47# casing. Clean out to PBTD. Displace hole over to ~awater. 20. Testwellbore to 4000 psi for 30 minutes. POH laying down drill pipe. 21. Run 7-5/8", IPC, Flush-joint, injection string with tailpipe. 22. Sting into 7" tie back sleeve. Set packer. 23. Shear out of PBR. PU and space out. Make up tubing hanger. 24. Circulate Freeze protection. Allow diesel to U- Tube in annulus. 25. Land Tubing hanger/sting back into PBR../ 26. Pressure test tubing and annulus to 4000 psi for 30 mins. 27. Set BPV. ND BOPE. NU tree. 28. Test tree to 5000 psi, Secure well. RDMO. Post-Ria Work: 1. Clean-up location as required. 2. R/U wireline. Recover ball and rod. 3. Perforate and stimulate Ivishak intervals as required. 4. Put on Injection. PSI-09 Drilling Permit.doc Page 6 ( ( Job 1: MIRU Hazards and Contingencies - ).> The rig move will involve no surface close approach hazards with adjacent wells. The PSI-09 well will be drilled from an existing pad with only two other wells on the location: East Bay State #1, an exploration well drilled in 11/74, and PSI-06 drilled in 6/02. EBS#1 was DST'd in the Lisburne and then suspended. Later on, EBS#1 was used as an Ivishak pressure monitoring well and then suspended again. The well is currently T A'd with cement plugs covering the Lisburne and Ivishak. ).> H2S is not expected during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, AOGCC has declared PSI-09 as ,~n H2S well. Standard Operating Procedures for H2S precautions are to be followed at all times. /,p Job 2: Drill Surface Hole Hazards and Contingencies ).> No fault crossing are expected in the surface interval. ).> There are no close approach issues along the PSI-09 well path. The nearest well is East Bay State-1 which is -328' well-to-well at surface and PSI-06 which has a planned wellpath -92' Ctr-Ctr at 525'. ).> Gas hydrates are not expected in this area. ~ Two offset wells on the West Beach pad have experienced deeper gravel beds below the Permafrost. Maintain adequate viscosity. PSI-06 did not have significant problems with these gravels. ).> Abnormally pressured shallow gas zones have NOT been observed in offset wells and is not expected at PSI-09. ).> Hole cleaning will be challenging in the 16" hole with 5" DP. Maintain adequate viscosity and high flow rates. Short trip as required. ~~-"",,,,,,,,,,,,,,,,,><~.,,",,,~,;,,,,,,,,,,,,><,,,~,,,'''~''''''''''',*,'''',,,,",,''''''.'.'~ '''''~'MW«_",~'ß,'',;(;.,;.;.;.;,~~'K<'IJf.~'tfJ.'tf.,'I'.~~,w....... Job 3: Install 13-3/8" Surface CasinQ Hazards and Contingencies ).> It is critical that cement is circulated to surface for well integrity. 3500/0 excess cement through the permafrost zone (and 50% excess below the permafrost) is planned. As contingency, a port collar will be (' run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. I ).> Cementing practices on the surface casing should meet the below criteria. 1. Pipe reciprocation during cement displacement 2. Cement - Top of lead to surface 3. Cement - Top of tail >1000' MDabove shoe using 500/0 excess. 4. Casing Shoe Set approximately -80'TVD below SV-1 sand. .;,:,,~~':' Job 4: Drill Intermediate/Production Hole Hazards and Contingencies ).> Fault crossings are not expected along the PSI-09 well path in the intermediate hole. ).> Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. PSI-09 Drilling Permit doc Page 7 ~ The directional plan has ( In built to minimize directional work and ( Jent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. ~ Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. ~ The kick tolerance for the 12-1/4" open hole section would be 121 bbls assuming a kick while at the section TD (-9,876' MD / 8,263' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. ~ Picking the 9-5/8" casing point is critical. Every attempt should be made to hit just above the HRZ/Zone 3 (" transition. The planned TD pick is in the lower HRZ. If Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 3 (7.5 ppg). Control drilling (constant parameters) will be required. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. :fnr'~:~-~I_I. _m~"'. ./mflllm.rm _mm^_,;,',;,"I~ : .tt. ... _tIlY"W",Y>ty, Job 6: Install 9-5/8" Intermediate/Production CasinQ Hazards and Contingencies ~ Differential sticking is a concern across the Ugnu and West Sak sand intervals. Communicate individual responsibilities to all members of rig team and review connection / tripping practices to minimize the time the pipe is left stationary. ~ Verify the floats are holding prior to continuing cementing operations. If floats are not holding, hold pressure and wait on cement. ~ Make every attempt to minimize the amount of HRZ left open below the 9-5/8" shoe. The HRZ could present problems while drilling the Ivishak with a 9.0 ppg mud or during subsequent liner running operations. --..........;~.~t'1- .1- -:"*,::':"YN""""'.'__m_,---~' ...It.. "',--~~::_W"',~.¡N'n--,'V.......w- -""^lI*!'f'~:"""^""-~"--',~--" . -'{'IW:"~-,.",~,.v._' U""'-,,,,,,,,,,,,,,,,,,,,,-,,,,,,,,,/>.",,' "'~":"')I:ltl,nlnl!I-'~:ltlltl,,..:tll.:~~..¡(~ Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-09 wellpath in the production hole. ~ Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore presJure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. ~ Drilling Close Approach: All offset wells pass BP Close Approach guidelines. ~ Gas Cap Drilling: High potential for swabbed gas kicks. ~ Hole Instability due to exposed HRZ: Recommended practices for drilling the HRZ in this area at 20° hold angle, call for a 10.0 ppg minimum mud weight. Due to the low reservoir pressure of the Ivishak, this section will be drilled with 9.0 ppg mud. Therefore, the potential exsists for any exposed HRZ to start causing hole problems. "':"'~,""',~~'^'.""::--", ~~........~~.¡."v.,-"""""-,,,','I'-'.~',',~,,:, PSI -09 Drilling Permit.doc Page 8 Job 9: Install 7" Production ( . .er Hazards and Contingencies ~ Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. ~ Hole instability, ledges across open HRZ interval. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ( Job 12: Run Completion HazardsandConüngencres ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. ~ The injection tubing will be large diameter, internally coated, and have flush joint connections. This job will be non-routine. Ensure all personnel are briefed of the potential hazards. Review all aspects of the operation with all rig team members prior to starting the job. ~ Ensure personnel are clear of rig floor during packer setting and when shearing out of the PBR. There will be the potential for a sudden release of stored energy with the string to jump at surface. ~ Freeze protection operations will also be non-routine without a RP Shear valve in the injection string. Freeze protection will be done through the BOP stack and choke manifold. Take extra precaution to avoid spills. Ensure all lines are blown down to vac truck. ~ Ensure MSD sheets are available for completion fluid additives. .ro^'".;,-,,,~,,,",~"~''''''--''-'+'','',....~^,,'AW,''..,,-''N......- ""....,,,.,~."h'" ""~"""""=:~""''''''''.''~'''''ðo;. Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Non-routine freeze protect operations may leave diesel in BOPE, choke manifold, and associated .Iines. Take extra precaution to avoid spills. Ensure all lines are blown down to vac truck. ~."'~"""m"",:,, ----_ov....... ..v... """"-~1:W~':x......m_m""n~_nn__--_. 1-'_a_i,I''''':.:''~::::::W''''_m'''''''..~'n''m','~-'^'''''"'o/àl.»~*»x._wx::""'..~u'mn-"'.........."''::'::~W' amaa:""--~""'_WIo__...~...'nm_m--"".. :""-""""""»'^""""""""'_',--'_mn,--,..nÛ., ''''''~:=U!_'~,.,:_.,,=::=:-'I- -~=:::: PSI-09 Drilling Permit.doc Page 9 ( PSI-09 ,Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates are not expected in this area. Gravel beds below the Permafrost may be present. . Intermediate Hole Section: . Fault crossings are not expected along the PSI-09 wellpath in the intermediate hole. . Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. . The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. . Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. . The kick tolerance for the 12-1/4" open hole section would be 103 bbls assuming a kick while at the section TD (-9,876' MD / 8263' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. . Picking the 9-5/8" casing point is critical. Every attempt should be made to hit just above the HRZ/Zone 3 transition. If Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 4 (7.5 ppg). Production Hole Section: . Gas cap drilling: High potential for swabbed gas kicks. Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Exposed HRZ has the potential for tight hole and sloughing. Monitor cuttings for excessive shale returns. The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. . . . HYDROGEN SULFIDE - H2S . H2S is not expected during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, The AOGCC has designated PSI-09 as a H2S well. Standard Operating Procedures for H2S precautions will be followed at all times. CONSULT THE PSI PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION PSI -09 Drilling Permit.doc Page 10 100.000 bbls/day @ 2700 psi injection pressure Xaver #1-Tbg Hanger: 7" NSCC Box X 7-5/8" STL Pin 20" x 34" Insulated Conductor @ +/- 80-' 7" x 9-5/8" Baker HMC Liner Hanger, ZXP Liner Top packer, and tieback sleeve 9-5/8",47#, L-80, BTC-M Intermediate Casing @+/- 8263' TVD; 9,876' MD PC-09 Completion Desi<J: Tree: 6-3/8" bore x 7-1/6" 5K, 625 Inlay, CIW H Wellhead: 13-5/8", 5K, Big Bore FMC 7" Camco 6.00" DB Nipple with I njection Valve at -2200' 7-5/8",29.7#, ST-L, IPC, Injection Tubing (w/T' accessories) 7" x 5.963" HES R Nipple 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG u Note: All tailpipe and accessories to be TCII 13-3/8" TAM Port Collar @ +/- 1000' MD Xaver #2&3-lnjection Valve: 7 -5/8" STL Box X 7" TCII Pin 7" TCII Box X 7-5/8" STL Pin 13-3/8",68#, L-80, BTC Surface Casing @ +/- 4563' TVD; 5,299' MD Xaver #4-Seal Assembly: 7 -5/8" STL Box X 7" TCII Pin 7", 26#, L-80, BTC-M Injection Liner @ +/- 8641' TVD: 10,279' MD Date 4-11-02 Rev By RBT Comments Update for PSI-09 materials order PROJECT: GCWI WELL: PSI-09 API NO: GPB Rotary Drilling 101111 ,.,-' " ----I ~c- i EnJDlr 175'llll'I\ID,17511'TVD I .-' ¡ : i..' $1.In [)Ir _1¡llill' I 'It.." ~~. MD, 1')5I1TVD ¡ ~ B l'~nnJln"l ~lIil( . 1{)," I i .....1- i . ." - EIIJ D" ~~.I 1 ~. 1\10. ~ 707 ,,~' TVD i ~.r- 2800-- ---+-----...-----. .--- i _111(11)" I i I ¡ "i i ~ 5600- ===. -----.1...- .._........ ....-...... --- i .... ¡ , i ! I ! 1400 :? ;t: 0 0 :! ..c: i5. 4200 Ö OJ u '€ > 2 f-< 7000 kip COMPANY DETAILS SURVEY PROGRAM Depth Fm Depth To SurveylPIan REFERENCE INFORMATION l'lan: PSI 9 wp05 (1'51 9/1'Ian )'SI 9) BP Amoco Tool Co-ordinale (NIE) Reference: Well Cenlre: PSI 9. True North Vertical (TVD) Reference: RKB Est 50.00 Section (VS) Reference: Slot. PSI I (O.OON.O.OOE) Measured Depth Reference: RKB Est 50.00 Calculation Method: Minimwn Curvature Date: Dale: 3/26/2002 CfC'atcd By: Ken Allen Checked: Dale: Calcu1ation Method: Minimmn Cwvature Enor System: ISCWSA Scan Metbod: Trov Cyhnder North Error Surface: E1Iiptical + Casing Wamin~ Method: Rules Based 30.00 1000.00 Planned PSI 9 wp05 VI 1000.00 10278.72 Planned PSI 9 wp05 VI CB-GYRO.SS MWD+IFR+MS Reviewed: WELL DETAILS Name +NI-S +EI.W IAlngitudc Slot Northing Easting Latitude C}----__4- PSI 9 132.13 295.40 5966179.63 708052.63 70'18'39.439N 148'18'50.122W I'SI I All TVD depths are ssTVD pillS 50' for RKBE. TARGET DETAILS Name 1VD +NI-S +EI-W Northing Easting Shape PSI 9 TI 8263.00 4231.24 .231 1.41 5970345.00 705625.00 Point PSI 9 polygon BH 8641.00 4446.83 .2473.71 5970556.00 705456.80 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 2 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 3 1200.00 4.00 331.35 1199.68 12.25 -6.69 1.00 331.35 13.96 4 1759.01 15.18 331.35 1750.00 93.85 -51.27 2.00 0.00 106.94 5 1966.24 15.18 331.35 1950.00 141.47 -77.29 0.00 0.00 161.20 6 2833.20 41.19 331.35 2707.62 497.74 -271.92 """'3.00 0.01 567.18 7 7564.93 41.19 331.35 6268.44 3232.39 -1765.75 0.00 0.00 3683.24 '-" 8 9683.84 20.00 331.35 8082.00 4173.43 -2279.83 1.00 -180.00 4755.54 9 9876.46 20.00 331.35 8263.00 4231.24 -2311.41 0.00 0.00 4821.42 PSI9TI 10 10278.72 20.00 331.35 8641.00 4351. 98 -2377.38 0.00 0.00 4959.00 CASINO DETAILS 'I.lrl DII IfllJO' XIIII' I\ID. xIIl)'TVD $1J.n Dlr ~iI(lI' I~IJIJ'MD. 11')9 hx'T\'D I -t- $\'-1 -1111/11 '- 4563.00 5298.69 13 3/8" 8263.00 9876.46 9 5/8" 8641.00 10278.72 7" 13.375 9.625 7.000 No. TVD MD Name Size -SV.I - SV~ FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1"''-'.00 1883.35 B.Pennafrost '»( k 2 .\);X.OO 3870.19 SV4 ~; ¡/SF ',< :=}r" 3 .IV/7.00 4413.69 SV3 4 "'''''''.00 4682.11 SV2 5 ,J 11< 1.00 5192.38 SVI 6 .""111'.:'.00 5882.05 U04 7 'dJ.OO 6602.27 UG3 ;/ 'y . 8 .~;';K'.OO 7055.40 UOI 9 ,.J I J.OO 7755.62 WS2 ~~:;t:;/, 10 ,.,...7.00 8000.74 WSI II ,.S' "',00 8238.25 CM3 12 7J ¡".OO 8972.10 CM2 13 'ir, i 1.00 9241.95 CMI ~. /1):'(;::",':,"""~ 14 1<"":.00 9683.84 THRZ 15 )':" '.00 9876.46 BHRZ/CUrrZ3/TCGL /~ 16 ~ ¡: J..OO 9941.37 TZ2C/BCOL 17 II 17J.00 9994.58 TZ2B/23SB I /','~ ~ 18 11'1<1.00 10214.86 BSAD t " ;;;; - ~ 5uuu \~ SVI / 113iS" --+ I.llì-l "111111 ~ í . . .~.. . -. ..- .........-+---". ..:.-:::.. _~.llì_1 i ~ 701111 - UGI ! I ! ã i ¡ ! --- -.î - -' - ----------- - ---~-~~'~~SI - - .. ------ -: :-:.----.. -.------...--.......-..-..--.. -.--' .- ............. .......: -~:=-:..:~~-:I~_: .~-(~ 1.1 ! " i i t ¡ i Î ; -CM2 j -þoUl!' ." 1 I ~CMI j ¡'" End Dir : 9683.84' MD, 8082' TVD - j- ..1- z:C THRZ ¡ ¡ 1.\\' . BHRZ/CUrrZ3rrCOL -0. '-"-"_~"---"m'''__- "':::-I'--"':~--:"__o."""':.-----.".:-....... ::::... ::-t-- TZ2C/BCOL ¡ :1' TZ2B/23SB 1 BSAD I i Depth: 10278.72' MD, 8641' TVD I I ¡ 28uu '¡2uu Vertical Section at 331.35° [1400ft/in] - $1.!rI [I'r 1/1110': 7564.93' MD, 6268.44'TVD ¡ i I ! I ! ~ i ! 8400 "'::,c_~, =-:, ..C. -,C- - ...t- c ! I ¡ I-Iuu I 5600 I 7000 bp COMPANY DETAILS BP Amoco Co-ordinate (NIE) Reference: Wen Centre: PSI 9. Tme North Vertical (TVD) Reference: RKB Est 50.00 Section (VS) Reference: Slot - PSI I (O.OON,O.OOE) Meas~aPc::k~o~e~=~ ~~m~ ~~~ REFERENCE INFORMATION Calculation Method: Minimwn Cwvature ElTOr System: ISCWSA Scan Method: T rav Cylinder North Error Surface: Elliptical + Casing Wamin~ Method: Rules Based CASING DETAILS No. TVD MD 4800- I 2 3 4563.00 5298.69 133/8" 8263.00 9876.46 9 5/8" 8641.00 10278.72 7" Total Depth: 10278.72' MD, 8641' TVD PSI 9 BH PSI 9 TI End Dir : 9683.84' MD, 8082' TVD SURVEY PROGRAM Depth Fm Depth To SurveylPlan 30.00 1000.00 Planned: PSI 9 wp05 VI 1000.00 10278.72 Planned: PSI 9 wp05 VI Tool CB-GYRO-SS MWD+IFR+MS Created By: Ken Nlen Checked: Reviewed: WELL DETAILS Name +NI.s +Fl-W Northing Easting Latitude 708052.63 70'18'.19.439N 148'18'50,122W PSI 1 Name Size PSI 9 132.13 295.40 5966179.63 13.375 9.625 7.000 TARGET DETAILS Plan: "SI 9 wp05 (I'SI 9/I'lan I'SI 9) Longitude 5101 Dale: 3/26/2002 Date: Date: Name TVD +NI.s .Fl-W Northing EIL"ling Shupe PSI 9 TI 8263,00 4231.24 -2311.4 I 5970345.00 705625.00 Point PSI 9 polygon BII 8641.00 4446.83 -2473.7 I 5970556.00 705456.80 Polygon PSI 9 BII 8641.00 4351.98 -2377.38 5970463.86 705555.72 I'oint SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target I 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 2 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 3 1200.00 4.00 331.35 1199.68 12.25 -6.69 1.00 331.35 13.96 4 1759.01 15.18 331.35 1750.00 93.85 -51.27 2.00 0.00 106.94 5 1966.24 15.18 331.35 1950.00 141.47 -77.29 0.00 0.00 161.20 6 2833.20 41.19 331.35 2707.62 497.74 -271.92 3.00 0.0] 567.18 ,~ 7 7564.93 41.19 33].35 6268.44 3232.39 -1765.75 0.00 0.00 3683.24 8 9683.84 20.00 33].35 8082.00 4173.43 -2279.83 1.00 -180.00 4755.54 9 9876.46 20.00 331.35 8263.00 4231.24 -231 ].41 0.00 0.00 482].42 PSI 9 T] ]0 10278.72 20.00 331.35 8641. 00 4351.98 -2377.38 0.00 0,00 4959.00 Dir 1/100': 7564.93' MD, 6268.44'TVD :s ~ <=> <=> ~ 1600 800 FORMATION TOP DETAILS No. TVDPath MDPath Formation ~i 1~1=[~ ,1//1 ~/ \vkJ, .". ~~Jæ \'BJ -I~"-,,(l..' ..' ..,!/0;(),"'" ':"'§<."~>riß<" ' '., ~;> ;;2)//::""'" ,..., I / /", ", ~ ,,/ // .~~df ,.,Q' ~ , ~ ,(1 ~ .,Q ...'" ~ ~ I 2 3 4 5 6 7 8 9 10 11 12 13 14 ]5 16 17 ]8 1870.00 3488.00 3897.00 4099.00 4483.00 5002.00 5544.00 5885.00 6414.00 6607.00 6800.00 7430.00 7673.00 8082.00 8263.00 8324.00 8374.00 8581.00 End Dir : 2833.2' MD, 2707.62' TVD -800 W est( - )/East( +) [800ft/in] : 1966.24' MD, 1950'TVD : 1759.0 I' MD, 1750' TVD ]200' MD, I I 99.68'TVD : 800' MD, 800'TVD I t 800 -2600 -2500 -2400 W est( - )/East( +) [200ft/in] I"¡~ i.35 I:.,¡ 711.]9 oJ I i.69 oJ'.;;:.11 , "':.38 .';o'~.05 r.r.II~.27 '71> '~.40 ') )-".62 )<'0111'.74 )¡~ IX.25 );., 7:.]0 I,~ J 1.95 I,.... 1.84 1,)(7r..46 I"'-J 1.37 1""'-1.58 ]I'.' 1-1.86 -2300 B.PermafTost SV4 SV3 SV2 SVI VG4 VG3 VGI WS2 WSI CM3 CM2 CMI THRZ BHRZ/CU'TZ3rrCGL TZ2C/BCGL TZ2B/23SB BSAD ~, 3 440å§ . 0 t!. +' :;:: . 1:: 430~ , '7' :;:: :; 0 r/J 4200 -2200 -2100 BP Planning Report - Geographic Company: BPArnõCo Fi~ld: Usbume Site: Ea.st . Dock (PSI) Well: PSI 9 W~lIpath: Plan PSI 9 Date:3I26!2002 Tillie: 17:21:18 Co-ordinat~{N;E)R~fe..ence:Well:PSI.9,TrueNorth Vertical (TVD) Reference: RKBEst 50.0 Section (VS) ~eference: Well(0.00N,0.00E,331.35Azi) Plan: PSI 9 wp05 Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: East Dock (PSI) Site Position: Northing: 5966039.39 ft Latitude: 70 18 38.139 N From: Map Easting: 707761.01 ft Longitude: 148 18 58.739 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 20.00 ft Grid Convergence: 1.59 deg Well: PSI 9 Slot Name: PSI! Surface Position: +N/-S 132.13 ft Northing: 5966179.63 ft Latitude: 70 18 39.439 N +E/- W 295.40 ft Easting : 708052.63 ft Longitude: 148 18 50.122 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 132.13 ft Northing: 5966179.63 ft Latitude: 70 18 39.439 N +E/-W 295.40 ft Easting: 708052.63 ft Longitude: 148 18 50.122 W Measured Depth: 30.00 ft Indination: 0.00 deg Vertical Depth: 30.00 ft Azimuth: 0.00 deg Wellpath: Plan PSI 9 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: RKB Est Height 50.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/30/2001 Declination: 26.80 deg Field Strength: 57516 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 331.35 Plan: PSI 9 wp05 Date Composed: 3/26/2002 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information -tE/.;W DLS Build Turn TFO. ft (jég!100ft deg!1POft . deg/1()M dfi)g 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 0.00 1200.00 4.00 331.35 1199.68 12.25 -6.69 1.00 1.00 0.00 331.35 1759.01 15.18 331.35 1750.00 93.85 -51.27 2.00 2.00 0.00 0.00 1966.24 15.18 331.35 1950.00 141.47 -77.29 0.00 0.00 0.00 0.00 2833.20 41.19 331.35 2707.62 497.74 -271.92 3.00 3.00 0.00 0.01 7564.93 41.19 331.35 6268.44 3232.39 -1765.75 0.00 0.00 0.00 0.00 9683.84 20.00 331.35 8082.00 4173.43 -2279.83 1.00 -1.00 0.00 -180.00 9876.46 20.00 331.35 8263.00 4231.24 -2311.41 0.00 0.00 0.00 0.00 PSI 9 T1 10278.72 20.00 331.35 8641.00 4351.98 -2377.38 0.00 0.00 0.00 0.00 Section 1: Start DLS Build Turn TFO q~911()Mqfi)f/10M deg/10OO deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP Planning Report - Geographic Company: BPAmoco Date: <3/26/2002 Time: 17:2t:18 Field: Usbume Co-ordinate(NE}.Reference:.Well:.'PSI.9,.True North Site: East Dock (PSI) Vertical (TVD) Reference: RKBEst 50.0 Well: PSI 9 Section (VS) Reference: Well(0.00N,O.00E,331.35Azi) Wellpath: Plan PSI 9 Plan: PSI9Wp05 Section 2: Start VS DLS Build Turn TFO ft ft deg/10OO deg/10OO deg/10OO deg 900.00 1.00 331.35 899.99 0.77 -0.42 0.87 1.00 1.00 0.00 0.00 1000.00 2.00 331.35 999.96 3.06 -1.67 3.49 1.00 1.00 0.00 0.00 1100.00 3.00 331.35 1099.86 6.89 -3.76 7.85 1.00 1.00 0.00 0.00 1200.00 4.00 331.35 1199.68 12.25 -6.69 13.96 1.00 1.00 0.00 0.00 Section 3: Start MD Incl Azhn TVD +N/-S +E/~W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1000 deg/1 000 . dëg/1 000 deg 1300.00 6.00 331.35 1299.29 19.90 -10.87 22.67 2.00 2.00 0.00 0.00 1400.00 8.00 331.35 1398.54 30.59 -16.71 34.86 2.00 2.00 0.00 0.00 1500.00 10.00 331.35 1497.30 44.32 -24.21 50.50 2.00 2.00 0.00 0.00 1600.00 12.00 331.35 1595.46 61.06 -33.36 69.58 2.00 2.00 0.00 0.00 1700.00 14.00 331.35 1692.89 80.80 -44.15 92.07 2.00 2.00 0.00 0.00 1759.01 15.18 331.35 1750.00 93.85 -51.27 106.94 2.00 2.00 0.00 0.00 Section 4: Start MD loci Azim TVD +N/.:.S +E/-W VS DLS Build Turn TFO ft dëg . dég ft ft ft ft . ~ég{100ft dég/10Qft'd~g/1()()ft deg 1800.00 15.18 331.35 1789.56 103.27 -56.42 117.67 0.00 0.00 0.00 180.00 1900.00 15.18 331.35 1886.07 126.25 -68.97 143.86 0.00 0.00 0.00 180.00 1966.24 15.18 331.35 1950.00 141.47 -77.29 161.20 0.00 0.00 0.00 180.00 Section 5: Start MD loci Azhn VS DLS Build Turn TFO ft dég (jëg ft dëg/1 OOftdeg/~O()ft dëg/1000 dM 2000.00 16.19 331.35 1982.50 149.48 -81.67 170.33 3.00 3.00 0.00 0.01 2100.00 19.19 331.35 2077.76 176.14 -96.24 200.72 3.00 3.00 0.00 0.01 2200.00 22.19 331.35 2171.30 207.15 -113.18 236.05 3.00 3.00 0.00 0.00 2300.00 25.19 331.35 2262.86 242.41 -132.44 276.23 3.00 3.00 0.00 0.00 2400.00 28.19 331.35 2352.19 281.83 -153.97 321.15 3.00 3.00 0.00 0.00 2500.00 31.19 331.35 2439.05 325.30 -177.72 370.68 3.00 3.00 0.00 0.00 2600.00 34.19 331.35 2523.20 372.69 -203.61 424.68 3.00 3.00 0.00 0.00 2700.00 37.19 331.35 2604.40 423.89 -231.58 483.02 3.00 3.00 0.00 0.00 2800.00 40.19 331.35 2682.45 478.75 -261.54 545.53 3.00 3.00 0.00 0.00 2833.20 41.19 331.35 2707.62 497.74 -271.92 567.18 3.00 3.00 0.00 0.00 Section 6: Start DLS Build Turn TFO deg/100ft deg/10OO deg/10OO deg 2900.00 41.19 331.35 2757.89 536.35 -293.01 611.16 0.00 0.00 0.00 180.00 3000.00 41.19 331.35 2833.14 594.14 -324.58 677.02 0.00 0.00 0.00 180.00 3100.00 41.19 331.35 2908.40 651.94 -356.15 742.87 0.00 0.00 0.00 180.00 3200.00 41.19 331.35 2983.65 709.73 -387.72 808.73 0.00 0.00 0.00 180.00 3300.00 41.19 331.35 3058.91 767.52 -419.29 874.58 0.00 0.00 0.00 180.00 3400.00 41.19 331.35 3134.16 825.32 -450.86 940.44 0.00 0.00 0.00 180.00 3500.00 41.19 331.35 3209.41 883.11 -482.43 1006.29 0.00 0.00 0.00 180.00 3600.00 41.19 331.35 3284.67 940.90 -514.00 1072.15 0.00 0.00 0.00 180.00 3700.00 41.19 331.35 3359.92 998.70 -545.57 1138.00 0.00 0.00 0.00 180.00 3800.00 41.19 331.35 3435.18 1056.49 -577.14 1203.86 0.00 0.00 0.00 180.00 3900.00 41.19 331.35 3510.43 1114.29 -608.71 1269.71 0.00 0.00 0.00 180.00 4000.00 41.19 331.35 3585.68 1172.08 -640.28 1335.56 0.00 0.00 0.00 180.00 4100.00 41.19 331.35 3660.94 1229.87 -671.85 1401.42 0.00 0.00 0.00 180.00 4200.00 41.19 331.35 3736.19 1287.67 -703.42 1467.27 0.00 0.00 0.00 180.00 4300.00 41.19 331.35 3811.45 1345.46 -734.99 1533.13 0.00 0.00 0.00 180.00 4400.00 41.19 331.35 3886.70 1403.26 -766.56 1598.98 0.00 0.00 0.00 180.00 4500.00 41.19 331.35 3961.95 1461.05 -798.13 1664.84 0.00 0.00 0.00 180.00 4600.00 41.19 331.35 4037.21 1518.84 -829.70 1730.69 0.00 0.00 0.00 180.00 4700.00 41.19 331.35 4112.46 1576.64 -861.28 1796.55 0.00 0.00 0.00 180.00 4800.00 41.19 331.35 4187.72 1634.43 -892.85 1862.40 0.00 0.00 0.00 180.00 4900.00 41.19 331.35 4262.97 1692.23 -924.42 1928.26 0.00 0.00 0.00 180.00 BP ( Planning Report - Geographic Company: BPAmoco Date: ..... . 3/26/2002 Time: 17:21:18 Field: Usbume Co--ordinate(l'fE)Reference:Well:PSI9., True North Site: East Dock (PSI) Vertical (TYD) Reference: RKB Est 50.0 Well: PSI 9 Section(VS) Reference: Well (0.00N,0.00E,331.35Azi) Wellpath: Plan PSI 9 Plån: PSI 9 wp05 Section 6: Start 5000.00 41.19 331.35 4338.22 1750.02 -955.99 1994.11 0.00 0.00 0.00 180.00 5100.00 41.19 331.35 4413.48 1807.81 -987.56 2059.97 0.00 0.00 0.00 180.00 5200.00 41.19 331.35 4488.73 1865.61 -1019.13 2125.82 0.00 0.00 0.00 180.00 5300.00 41.19 331.35 4563.99 1923.40 -1050.70 2191.67 0.00 0.00 0.00 180.00 5400.00 41.19 331.35 4639.24 1981.19 -1082.27 2257.53 0.00 0.00 0.00 180.00 5500.00 41.19 331.35 4714.49 2038.99 -1113.84 2323.38 0.00 0.00 0.00 180.00 5600.00 41.19 331.35 4789.75 2096.78 -1145.41 2389.24 0.00 0.00 0.00 180.00 5700.00 41.19 331.35 4865.00 2154.58 -1176.98 2455.09 0.00 0.00 0.00 180.00 5800.00 41.19 331.35 4940.26 2212.37 -1208.55 2520.95 0.00 0.00 0.00 180.00 5900.00 41.19 331.35 5015.51 2270.16 -1240.12 2586.80 0.00 0.00 0.00 180.00 6000.00 41.19 331.35 5090.77 2327.96 -1271.69 2652.66 0.00 0.00 0.00 180.00 6100.00 41.19 331.35 5166.02 2385.75 -1303.26 2718.51 0.00 0.00 0.00 180.00 6200.00 41.19 331.35 5241.27 2443.55 -1334.83 2784.37 0.00 0.00 0.00 180.00 6300.00 41.19 331.35 5316.53 2501.34 -1366.40 2850.22 0.00 0.00 0.00 180.00 6400.00 41.19 331.35 5391.78 2559.13 -1397.97 2916.07 0.00 0.00 0.00 180.00 6500.00 41.19 331.35 5467.04 2616.93 -1429.54 2981.93 0.00 0.00 0.00 180.00 6600.00 41.19 331.35 5542.29 2674.72 -1461.11 3047.78 0.00 0.00 0.00 180.00 6700.00 41.19 331.35 5617.54 2732.51 -1492.68 3113.64 0.00 0.00 0.00 180.00 6800.00 41.19 331.35 5692.80 2790.31 -1524.25 3179.49 0.00 0.00 0.00 180.00 6900.00 41.19 331.35 5768.05 2848.10 -1555.83 3245.35 0.00 0.00 0.00 180.00 7000.00 41.19 331.35 5843.31 2905.90 -1587.40 3311.20 0.00 0.00 0.00 180.00 7100.00 41.19 331.35 5918.56 2963.69 -1618.97 3377.06 0.00 0.00 0.00 180.00 7200.00 41.19 331.35 5993.81 3021.48 -1650.54 3442.91 0.00 0.00 0.00 180.00 7300.00 41.19 331.35 6069.07 3079.28 -1682.11 3508.77 0.00 0.00 0.00 180.00 7400.00 41.19 331.35 6144.32 3137.07 -1713.68 3574.62 0.00 0.00 0.00 180.00 7500.00 41.19 331.35 6219.58 3194.87 -1745.25 3640.47 0.00 0.00 0.00 180.00 7564.93 41.19 331.35 6268.44 3232.39 -1765.75 3683.24 0.00 0.00 0.00 180.00 Section 7: Start l\ID Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/10OO deg/10OO deg/10OO deg 7600.00 40.84 331.35 6294.90 3252.59 -1776.78 3706.25 1.00 -1.00 0.00 -180.00 7700.00 39.84 331.35 6371.12 3309.39 -1807.81 3770.98 1.00 -1.00 0.00 -180.00 7800.00 38.84 331.35 6448.46 3365.02 -1838.20 3834.37 1.00 -1.00 0.00 -180.00 7900.00 37.84 331.35 6526.90 3419.46 -1867.94 3896.40 1.00 -1.00 0.00 -180.00 8000.00 36.84 331.35 6606.40 3472.69 -1897.01 3957.05 1.00 -1.00 0.00 -180.00 8100.00 35.84 331.35 6686.96 3524.69 -1925.42 4016.30 1.00 -1.00 0.00 -180.00 8200.00 34.84 331.35 6768.53 3575.45 -1953.15 4074.14 1.00 -1.00 0.00 -180.00 8300.00 33.84 331.35 6851.10 3624.95 -1980.19 4130.55 1.00 -1.00 0.00 -180.00 8400.00 32.84 331.35 6934.64 3673.18 -2006.54 4185.51 1.00 -1.00 0.00 -180.00 8500.00 31.84 331.35 7019.13 3720.13 -2032.18 4239.00 1.00 -1.00 0.00 -180.00 8600.00 30.84 331.35 7104.54 3765.77 -2057.12 4291.01 1.00 -1.00 0.00 -180.00 8700.00 29.84 331.35 7190.85 3810.09 -2081.33 4341.52 1.00 -1.00 0.00 -180.00 8800.00 28.84 331.35 7278.02 3853.09 -2104.82 4390.51 1.00 -1.00 0.00 -179.99 8900.00 27.84 331.35 7366.04 3894.75 -2127.58 4437.98 1.00 -1.00 0.00 -179.99 9000.00 26.84 331.35 7454.87 3935.05 -2149.60 4483.90 1.00 -1.00 0.00 -179.99 9100.00 25.84 331.35 7544.48 3973.99 -2170.87 4528.27 1.00 -1.00 0.00 -179.99 9200.00 24.84 331.35 7634.86 4011 .54 -2191.38 4571.07 1.00 -1.00 0.00 -179.99 9300.00 23.84 331.35 7725.97 4047.71 -2211.14 4612.28 1.00 -1.00 0.00 -179.99 9400.00 22.84 331.35 7817.79 4082.48 -2230.14 4651.89 1.00 -1.00 0.00 -179.99 9500.00 21.84 331.35 7910.29 4115.83 -2248.36 4689.90 1.00 -1.00 0.00 -179.99 9600.00 20.84 331.35 8003.43 4147.76 -2265.80 4726.29 1.00 -1.00 0.00 -179.99 9683.84 20.00 331.35 8082.00 4173.43 -2279.83 4755.54 1.00 -1.00 0.00 -179.99 Section 8: Start l\ID Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/10OO deg/10OO deg/10OO deg 9700.00 20.00 331.35 8097.19 4178.28 -2282.48 4761.07 0.00 0.00 0.00 0.00 9800.00 20.00 331.35 8191.15 4208.30 -2298.88 4795.27 0.00 0.00 0.00 0.00 9876.46 20.00 331.35 8263.00 4231.24 -2311.41 4821.42 0.00 0.00 0.00 0.00 BP ( Planning Report - Geographic Date: .3/26/2002 Time: 17:21 :18 Page: 4 Co--ordinate(N'E),Referençe: Well:pSI9,,..rue Nqrth Vertiçal (TVD) Referençe: RKBEst50.0 Sedion (VS) Referençe: Well (0.00N,0.00E,331.35Azi) Plån: PSI 9 wp05 Sedion 9: Start 9900.00 20.00 331.35 8285.12 4238.31 -2315.28 4829.47 0.00 0.00 0.00 0.00 10000.00 20.00 331.35 8379.09 4268.32 -2331.67 4863.67 0.00 0.00 0.00 0.00 10100.00 20.00 331.35 8473.06 4298.34 -2348.07 4897.87 0.00 0.00 0.00 0.00 10200.00 20.00 331.35 8567.03 4328.35 -2364.47 4932.08 0.00 0.00 0.00 0.00 10278.72 20.00 331.35 8641.00 4351.98 -2377.38 4959.00 0.00 0.00 0.00 0.00 Survey Map Map <.;..;.. . Loögitude -> Inçl +E/"W Northing Eästing Deg. Min. .... See deg ft ft ft 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 500.00 0.00 0.00 500.00 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 600.00 0.00 0.00 600.00 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 700.00 0.00 0.00 700.00 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 800.00 0.00 0.00 800.00 0.00 0.00 5966179.63 708052.63 70 18 39.439 N 148 18 50.122 W 900.00 1.00 331.35 899.99 0.77 -0.42 5966180.38 708052.19 70 18 39.446 N 148 18 50.134 W 1000.00 2.00 331.35 999.96 3.06 -1.67 5966182.65 708050.87 70 18 39.469 N 148 18 50.171 W 1100.00 3.00 331.35 1099.86 6.89 -3.76 5966186.41 708048.68 70 18 39.507 N 148 18 50.232 W 1200.00 4.00 331.35 1199.68 12.25 -6.69 5966191.69 708045.60 70 18 39.559 N 148 18 50.317 W 1300.00 6.00 331.35 1299.29 19.90 -10.87 5966199.22 708041.21 70 18 39.635 N 148 18 50.439 W 1400.00 8.00 331.35 1398.54 30.59 -16.71 5966209.74 708035.08 70 18 39.740 N 148 18 50.610 W 1500.00 10.00 331.35 1497.30 44.32 -24.21 5966223.26 708027.20 70 18 39.875 N 148 18 50.828 W 1600.00 12.00 331.35 1595.46 61.06 -33.36 5966239.74 708017.59 70 18 40.039 N 148 18 51.095 W 1700.00 14.00 331.35 1692.89 80.80 -44.15 5966259.17 708006.26 70 18 40.234 N 148 18 51.410 W 1759.01 15.18 331.35 1750.00 93.85 -51.27 5966272.02 707998.78 70 18 40.362 N 148 18 51.618 W 1800.00 15.18 331.35 1789.56 103.27 -56.42 5966281.29 707993.37 70 18 40.454 N 148 18 51.768 W 1900.00 15.18 331.35 1886.07 126.25 -68.97 5966303.91 707980.19 70 18 40.680 N 148 18 52.134 W 1966.24 15.18 331.35 1950.00 141.47 -77.29 5966318.89 707971.45 70 18 40.830 N 148 18 52.377 W 2000.00 16.19 331.35 1982.50 149.48 -81.67 5966326.78 707966.86 70 18 40.909 N 148 18 52.504 W 2100.00 19.19 331.35 2077.76 176.14 -96.24 5966353.03 707951.56 70 18 41.171 N 148 18 52.929 W 2200.00 22.19 331.35 2171.30 207.15 -113.18 5966383.56 707933.76 70 18 41.476 N 148 18 53.423 W 2300.00 25.19 331.35 2262.86 242.41 -132.44 5966418.27 707913.53 70 18 41.823 N 148 18 53.985 W 2400.00 28.19 331.35 2352.19 281.83 -153.97 5966457.07 707890.92 70 18 42.211 N 148 18 54.613 W 2500.00 31.19 331.35 2439.05 325.30 -177.72 5966499.86 707865.98 70 18 42.638 N 148 18 55.306 W 2600.00 34.19 331.35 2523.20 372.69 -203.61 5966546.52 707838.79 70 18 43.104 N 148 18 56.061 W 2700.00 37.19 331.35 2604.40 423.89 -231.58 5966596.92 707809.41 70 18 43.608 N 148 18 56.877 W 2800.00 40.19 331.35 2682.45 478.75 -261.54 5966650.92 707777.94 70 18 44.147 N 148 18 57.751 W 2833.20 41.19 331.35 2707.62 497.74 -271.92 5966669.62 707767.04 70 18 44.334 N 148 18 58.054 W 2900.00 41.19 331.35 2757.89 536.35 -293.01 5966707.63 707744.89 70 18 44.714 N 148 18 58.669 W 3000.00 41.19 331.35 2833.14 594.14 -324.58 5966764.52 707711.73 70 18 45.282 N 148 18 59.590 W 3100.00 41.19 331.35 2908.40 651.94 -356.15 5966821.42 707678.58 70 18 45.851 N 148 19 0.511 W 3200.00 41.19 331.35 2983.65 709.73 -387.72 5966878.31 707645.42 70 18 46.419 N 148 19 1.432 W 3300.00 41.19 331.35 3058.91 767.52 -419.29 5966935.20 707612.26 70 18 46.987 N 148 19 2.353 W 3400.00 41.19 331.35 3134.16 825.32 -450.86 5966992.10 707579.10 70 18 47.556 N 148 19 3.274 W 3500.00 41.19 331.35 3209.41 883.11 -482.43 5967048.99 707545.94 70 18 48.124 N 148 19 4.196 W 3600.00 41.19 331.35 3284.67 940.90 -514.00 5967105.89 707512.79 70 18 48.692 N 148 19 5.117 W 3700.00 41.19 331.35 3359.92 998.70 -545.57 5967162.78 707479.63 70 18 49.261 N 148 19 6.038 W 3800.00 41.19 331.35 3435.18 1056.49 -577.14 5967219.67 707446.47 70 18 49.829 N 148 19 6.959 W 3900.00 41.19 331.35 3510.43 1114.29 -608.71 5967276.57 707413.31 70 18 50.398 N 148 19 7.880 W 4000.00 41.19 331.35 3585.68 1172.08 -640.28 5967333.46 707380.16 70 18 50.966 N 148 19 8.801 W 4100.00 41.19 331.35 3660.94 1229.87 -671.85 5967390.36 707347.00 70 18 51.534 N 148 19 9.722 W BP Planning Report - Geographic ( Company: BPArnoco Field: Usbume Site: East Dock (PSI) Well: PSI 9 Wellpath: Plan PSI 9 Date: > 3/26/2002 TÍlne: 17:21: 18 Co-ordinate(NE) Reference: Well: PSI 9, True North Vertical (TVD) Reference: RKBEst50.0 Section (VS) Reference: Well (0.00N,0.00E,331.35Azi) Plan: PSI9wp05 Page: 5 Survey 4200.00 41.19 331.35 3736.19 1287.67 -703.42 5967447.25 707313.84 70 18 52.103 N 148 19 10.643 W 4300.00 41.19 331.35 3811.45 1345.46 -734.99 5967504.15 707280.68 70 18 52.671 N 148 19 11.565 W 4400.00 41.19 331.35 3886.70 1403.26 -766.56 5967561.04 707247.52 70 18 53.239 N 148 19 12.486 W 4500.00 41.19 331.35 3961.95 1461.05 -798.13 5967617.93 707214.37 70 18 53.808 N 148 19 13.407 W 4600.00 41.19 331.35 4037.21 1518.84 -829.70 5967674.83 707181.21 70 18 54.376 N 148 19 14.328 W 4700.00 41.19 331.35 4112.46 1576.64 -861.28 5967731.72 707148.05 70 18 54.945 N 148 19 15.250 W 4800.00 41.19 331.35 4187.72 1634.43 -892.85 5967788.62 707114.89 70 18 55.513 N 148 19 16.171 W 4900.00 41.19 331.35 4262.97 1692.23 -924.42 5967845.51 707081.73 70 18 56.081 N 148 19 17.092 W 5000.00 41.19 331.35 4338.22 1750.02 -955.99 5967902.40 707048.58 70 18 56.650 N 148 19 18.013 W 5100.00 41.19 331.35 4413.48 1807.81 -987.56 5967959.30 707015.42 70 18 57.218 N 148 19 18.935 W 5200.00 41.19 331.35 4488.73 1865.61 -1019.13 5968016.19 706982.26 70 18 57.786 N 148 19 19.856 W 5300.00 41.19 331.35 4563.99 1923.40 -1050.70 5968073.09 706949.10 70 18 58.355 N 148 19 20.777 W 5400.00 41.19 331.35 4639.24 1981.19 -1082.27 5968129.98 706915.95 70 18 58.923 N 148 19 21.699 W 5500.00 41.19 331.35 4714.49 2038.99 -1113.84 5968186.87 706882.79 70 18 59.491 N 148 19 22.620 W 5600.00 41.19 331.35 4789.75 2096.78 -1145.41 5968243.77 706849.63 70 19 0.060 N 148 19 23.541 W 5700.00 41.19 331.35 4865.00 2154.58 -1176.98 5968300.66 706816.47 70 19 0.628 N 148 19 24.463 W 5800.00 41.19 331.35 4940.26 2212.37 -1208.55 5968357.56 706783.31 70 19 1.196 N 148 19 25.384 W 5900.00 41.19 331.35 5015.51 2270.16 -1240.12 5968414.45 706750.16 70 19 1.765 N 148 19 26.306 W 6000.00 41.19 331.35 5090.77 2327.96 -1271.69 5968471.35 706717.00 70 19 2.333 N 148 19 27.227 W 6100.00 41.19 331.35 5166.02 2385.75 -1303.26 5968528.24 706683.84 70 19 2.901 N 148 19 28.148 W 6200.00 41.19 331.35 5241.27 2443.55 -1334.83 5968585.13 706650.68 70 19 3.470 N 148 19 29.070 W 6300.00 41.19 331.35 5316.53 2501.34 -1366.40 5968642.03 706617.53 70 19 4.038 N 148 19 29.991 W 6400.00 41.19 331.35 5391.78 2559.13 -1397.97 5968698.92 706584.37 70 19 4.606 N 148 19 30.913 W 6500.00 41.19 331.35 5467.04 2616.93 -1429.54 5968755.82 706551.21 70 19 5.175 N 148 19 31.834 W 6600.00 41.19 331.35 5542.29 2674.72 -1461.11 5968812.71 706518.05 70 19 5.743 N 148 19 32.756 W 6700.00 41.19 331.35 5617.54 2732.51 -1492.68 5968869.60 706484.89 70 19 6.312 N 14819 33.677 W 6800.00 41.19 331.35 5692.80 2790.31 -1524.25 5968926.50 706451.74 70 19 6.880 N 148 19 34.599 W 6900.00 41.19 331.35 5768.05 2848.10 -1555.83 5968983.39 706418.58 70 19 7.448 N 148 19 35.521 W 7000.00 41.19 331.35 5843.31 2905.90 -1587.40 5969040.29 706385.42 70 19 8.017 N 148 19 36.442 W 7100.00 41.19 331.35 5918.56 2963.69 -1618.97 5969097.18 706352.26 70 19 8.585 N 148 19 37.364 W 7200.00 41.19 331.35 5993.81 3021.48 -1650.54 5969154.07 706319.10 70 19 9.153 N 148 19 38.285 W 7300.00 41.19 331.35 6069.07 3079.28 -1682.11 5969210.97 706285.95 70 19 9.722 N 148 19 39.207 W 7400.00 41.19 331.35 6144.32 3137.07 -1713.68 5969267.86 706252.79 70 19 10.290 N 148 19 40.128 W 7500.00 41.19 331.35 6219.58 3194.87 -1745.25 5969324.76 706219.63 70 19 10.858 N 148 19 41.050 W 7564.93 41.19 331.35 6268.44 3232.39 -1765.75 5969361.70 706198.10 70 19 11.227 N 148 19 41.649 W 7600.00 40.84 331.35 6294.90 3252.59 -1776.78 5969381.58 706186.51 70 19 11.426 N 148 19 41.971 W 7700.00 39.84 331.35 6371.12 3309.39 -1807.81 5969437.50 706153.92 70 19 11.984 N 148 19 42.877 W 7800.00 38.84 331.35 6448.46 3365.02 -1838.20 5969492.27 706122.01 70 19 12.531 N 148 19 43.764 W 7900.00 37.84 331.35 6526.90 3419.46 -1867.94 5969545.86 706090.77 70 19 13.067 N 148 19 44.632 W 8000.00 36.84 331.35 6606.40 3472.69 -1897.01 5969598.26 706060.24 70 19 13.590 N 148 19 45.481 W 8100.00 35.84 331.35 6686.96 3524.69 -1925.42 5969649.45 706030.40 70 19 14.102 N 148 19 46.310 W 8200.00 34.84 331.35 6768.53 3575.45 -1953.15 5969699.42 706001.28 70 19 14.601 N 148 19 47.120 W 8300.00 33.84 331.35 6851.10 3624.95 -1980.19 5969748.15 705972.88 70 19 15.087 N 148 19 47.909 W 8400.00 32.84 331.35 6934.64 3673.18 ~2006.54 5969795.63 705945.20 70 19 15.562 N 148 19 48.679 W 8500.00 31.84 331.35 7019.13 3720.13 -2032.18 5969841.84 705918.27 70 19 16.023 N 148 19 49.427 W 8600.00 30.84 331.35 7104.54 3765.77 -2057.12 5969886.77 705892.08 70 19 16.472 N 148 19 50.155 W 8700.00 29.84 331.35 7190.85 3810.09 -2081.33 5969930.41 705866.65 70 19 16.908 N 148 19 50.862 W 8800.00 28.84 331.35 7278.02 3853.09 -2104.82 5969972.74 705841.98 70 19 17.331 N 148 19 51.548 W 8900.00 27.84 331.35 7366.04 3894.75 -2127.58 5970013.75 705818.08 70 19 17.741 N 148 19 52.213 W 9000.00 26.84 331.35 7454.87 3935.05 -2149.60 5970053.42 705794.95 70 19 18.137 N 148 19 52.856 W 9100.00 25.84 331.35 7544.48 3973.99 -2170.87 5970091.75 705772.61 70 19 18.520 N 148 19 53.477 W 9200.00 24.84 331.35 7634.86 4011.54 -2191.38 5970128.72 705751.06 70 19 18.889 N 148 19 54.076 W BP Planning Report - Geographic . Company: BP<Amoco Field: Usbume Site: East.Dock (PSI) Well: PSI 9 Wellpath: Plan PSI 9 Date: ....3/26/2002 Time: 17:21:18 Co-ordinate(NE) .Reference:.Well:PSI9, True North Vertical (TVD)Reference: RKB Est 50,0 Section (VS) Reference: vvel[(0,00N.0,00E.331.35Azi) Plan: PSI 9 wp05 Page: 6 Survey Map Map <-:'""Latitude--->: <-Longitude i--> Incl Azim TVD +N/-S +E/-W Northing Easting DegMin........Sec Deg Min See deg deg ft ft ft ft ft 9300.00 23.84 331.35 7725.97 4047.71 -2211.14 5970164.32 705730.31 70 19 19.245 N 148 19 54.653 W 9400.00 22.84 331.35 7817.79 4082.48 -2230.14 5970198.55 705710.36 70 19 19.587 N 148 19 55.207 W 9500.00 21.84 331.35 7910,29 4115,83 -2248.36 5970231,38 705691.23 70 19 19.914 N 148 19 55.739 W 9600.00 20.84 331.35 8003.43 4147.76 -2265.80 5970262,82 705672.90 70 19 20.228 N 148 19 56.249 W 9683.84 20,00 331.35 8082.00 4173.43 -2279.83 5970288,09 705658,17 70 19 20.481 N 148 19 56,658 W 9700.00 20,00 331.35 8097.19 4178.28 -2282.48 5970292,86 705655,39 70 19 20.529 N 148 19 56.736 W 9800,00 20.00 331,35 8191.15 4208,30 -2298.88 5970322.41 705638.17 70 19 20.824 N 148 19 57.215 W 9876.46 20.00 331.35 8263,00 4231 .24 -2311.41 5970345.00 705625.00 70 19 21.049 N 148 19 57,581 W 9900.00 20,00 331,35 8285,12 4238,31 -2315,28 5970351.96 705620,95 70 19 21,119N 148 19 57,693 W 10000,00 20,00 331.35 8379,09 4268,32 -2331.67 5970381.50 705603.72 70 19 21.414 N 148 19 58,172 W 10100,00 20.00 331.35 8473.06 4298.34 -2348,07 5970411.05 705586,50 70 19 21.709 N 148 19 58.651 W 10200.00 20.00 331.35 8567.03 4328,35 -2364.47 5970440.60 705569.28 70 19 22,004 N 148 19 59.130 W 10278.72 20,00 331,35 8641.00 4351,98 -2377,38 5970463.86 705555,72 70 19 22,237 N 148 19 59.507 W I.OCA}"ED WITHIN PROTRACTED SEC. 15, T. 11. N.. R. 15 EO) UMIAT MERID¡AN. ALASKA WE\...\... .. A.S.P.' PLANT GEODETIC GÈÒDETIC CELLAR' SECTION NO. COO~DNA TES COORDINA TES POSITION(DM~) POSITION(P.DD) BOX ELEV. OFFSETS Y;;:;5,966,097.64 N-=10.000.00 70.18'38_694" 70.31 Ö7483" :S.80Q' FSL PSI~1 x= 7.97,827.02 E= 4:,909.96 }48.18'56.767.':^ 148.3157694" 17.6' 4.579. FEL Y=5.966,148.95 Nõõ:10,OOO.17 70'18'39.160" 70.3108778' 3,848' FS~ PSI-6 x= 7071.~6 7.83 E= 5,059,83 148"18'52.619" J48.314.61677" 17.6' 4.436' FEL Y= 5.966.179.51 N:::: 9."999.86 iO'18'39.438;;' 70.3109550' :5 87é'- FSI- PSI-9 x= 708,05.2.69 E= 5,150.02 148"18';50.120" 148.3139222" 17.4' 4.351' FEL. .' Apr-14-2002 16:48 l From-MCC WING 6 +907-659-5065 ( þ/ // . // /" PRUDHOE BAY... :';/// // .' ..' ooo._~ ..' ...' ...-......~..-............. .' . // .' c 0 b § -'" :;: 'Q < éF -" c.5 a.. It -N - I WF1INJECTION / WELL FACILITY (EAST DOCK WEST PAD) -1 ~ c.o 0"> I I ( ø (/) i7i li1 :z; CL CL 0.. ¡::: -+ + + V) x ...... . '" " ... 0.. u m M ~ ~ ~ <:> NOTE S: 1. DATI:: OF SURvEY: APRIl.. 12, 2002. 2. REFERENCE FIELD 800K: PB02-04 PAGES. 29-.30. 3. COORDINATES ARE ALASKA STATE PLANE. ZONE-4 NAD27. 4-. GEODETIC COORDINAìES ARE NAD-27. 5. EAST DOCK FACII-ITY AVERAGE SCALE FACTOR IS 0.999949103. 6. t-IORIZONTAL CONTROL ESTASI-ISt-IED BY GPS STATIC 08SERVATIONS BASED ON ORrLLSITE OPERA TOR MONUMENT "05-11 A". 7. ELEVATIONS ARE ARCa Mt...LW BASED ON DRILLSITE 11 OPERA TOR MONUMENT "05-11 A", I'J i (]\ .(!. ~ .- ß .., " <II g, ~ 0 '.1 L ~ .z .8 .. " ',. Ç;. .... 0 :: "- co '" ~ c;> ~ '--l~o_~ei1J . ...-- ~]-- W -... . ----- ~ mææill(bo J.£ LCM ~.......r.~t- """ "oVIU :.~,,~ 41'1t .,.('S( ~"",..¡J ",--, 11 t CHK. MC....""",c.., ............ ,,"~J '~CÄI.f¡ ,-", 120' ~- . '- [)Ò/"'W~I. JACaaS c,,¡"r,ifõ- ..- ALliSON -¡11\rC -- 3/27/02 O~~~3~ EO 02-00 . .:t .~--_.. TO--,.- '" " ~. ~ - 1å a 4/1 ~/O~ f~EO FOR Nf'OÓ/J..!"'TI~ ~ NO. D-'lTC R:EVlS,Or. ..0" NO. T-855 P.002/002 F-958 J'RlJDHO[; BAt >'-- PROJECT AREA ¿ '. , .~ - on . b~.þ.\ ~.~ , ~'J LISBURNE'" "\ DR!I-\... SITE 3 . . 2:?'" 0 I VICINITY MAP N.T.S. 21 LEG~N D 4- AS-BUILT CONDUCTOR . ËXtSTING CONDUCTOR SURV!;YOR'S CERTIFICATE I HEREBY CERTIFY THAT AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF AI..ASKA AND THAT THIS PLAT REPRESENTS A SuRVEY MADE BY ME OR UNDER MY DIRECT SuPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 12, 2002. Obp GPB EAST DOCK WFI PAD AS-BUILT CONDUCTORS WELLS PSI-1. PSI-B, & PSI-9 ~'It:n 1 OF 1 '.... ~, H 206921 \"',,-,, . . ' ~.. DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS ,( OS/23/02 CK052302D Permit To Drill Fee ", Pls call Terrie Hubble X4628 ?S1 ~D1 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX' 196612 ANCHORAGE, ALASKA 99519-6612 DATE CHECK NO. OS/28/02 H206921 VENDOR DISCOUNT NET $100.00 H RECEI'lED JUN 'j 2 2002 Alaska Oil & Gm~ Gone. ConHll¡&G:O: ,AnchoraQe $100.00 No. H 208921 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 PAY B .,.,f?"",'",'," r.:,-",'"',,",, ',' 'l'" ,1m" ,dill) ,¡I'''¡' f"'j¡ ¡.II, ;:..' :"-,' -- _..f":" f ,I t 1 'f'li" .If'. -ti' .,.' . .""':: . ~~,:.J.. 'III' till. .".... ""U" ',"" DATE AMOUNT *****$100.00****** -- ***May 28,2002*** TO THE ORDER OF A1.àskanöil& Gás CbnservationCommisssion ,333 W7th}\ve, ste 100 AnChdragèi AK99501 /18 2 0 b 9 2 ./18 I: 0 L. . 2 0 ~ a 9 5 I: 0 0 a L. L. . 9 118 NOTVALlD AFTER 120 DAYS Ç(~r¿0:~~ CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA TION INJECTION ~ INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJlU CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) ß'ft f,'...,e. /Afi~/.~ ANNULAR DISPOSAL INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SPACING EXCEPTION PS1- 09' "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Please note that an disposal of fluids generated. . . Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY B P )¿ WELL NAME fJ8C¡ f'I) J -I} 9 FIELD & POOL b~/QO INITCLASS I-,..A..J)A/! ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . .. . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . A~ I2~J~7 12. Permit can be issued without administrative approval.. . . . . ~ ~..:)7"2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . .. . 15. Surface casing protects all known USOWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . .-. . 23. If diverter required, does it meet regulations. . . . . . . . . . 24, Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to t/-OOO psig. 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . .. ]1/& N 31. Data presented on potential overpressure zones. . . . . . . Y N ' A ) ./.Î 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / V I (/"'1 ~.fR "","D'!~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N /~ ~ Yc.JZ., 34. Contact name/phone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. '. to surface; (C) will not impair mechanical integrity of the well used for disposa' Y N (0) will not damage producing formation or impair recovery fro Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: C MMISSION: RP~A--- JDH ~ COT J pI. WGA vJ{:¡/r DTS D6/1'} 1°<-, p? ø;Þ/- VJ.~ (pli~/o'¿. GEOLOGY APPR DATE /þ #d?- G:\geology\permits\checklist. doc PROGRAM: Exp - Dev - Redrll - Serv X- Wellbore seg - Ann. disposal para req - GEOL AREA (19 ò UNIT# 1/ be (' ('j ON/OFF SHORE <l ~ ?\N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~.. ~ <;<1" ¡( 'W" ¡6) 73 I ~~ Ackt~ Q..¡LCR<;~ yaP u ~~ tJ4w.. UE ~ ~ ::p s" 00 if~.' ft.uv¡; ~) 1< ,d- <toc9o t' t/ ' ~~ ,/l~ / A r- /.( *I-!"¡-- Îr->rr.c)Gr D (J~J -r:-f V ) /l./, /1, Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special'effort has been made to chronologically. . organize this category of information. ~f ) ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 05 09:09:57 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/02/05 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS aBJ Y Ie") 1/50 '1 ;¿ (J;¿ - I), <I Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/02/05 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD / MAD. . LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA PSI-09 500292309500 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 05-FEB-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22104 J. BOBBITT B. DECKER MWDRUN 3 AK-MW-22104 T. GALVIN B. DECKER MWDRUN 2 AK-MW-22104 J. BOBBITT B. DECKER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 15 11N 15E 3876 4351 MSL 0) 50.50 17.30 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 20.000 114.0 12.250 13.375 5588.0 ) ) 3 RD STRING PRODUCTION STRING 8.500 9.625 9920.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ PRESSURE WHILE DRILLING (PWD)¡ AND AT-BIT INCLINATION (ABI) 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ COMPENSATED NEUTRON POROSITY (CNP) ¡ AND STABILIZED LITHO-DENSITY (SLD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN PSI-09 ON 18 JULY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 12 NOVEMBER 2002. 7. MWD RUNS 1 - 3 REPRESENT WELL PSI-09 WITH API#: 50-029-23095-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10343'MD/8635'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 9.05 PPG MUD SALINITY: 15,000 PPM CHLORIDES FORMATION WATER SALINITY: 50,000 PPM CHLORIDES ) ) FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.... ........ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/05 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NCNT FCNT NPHI PEF RHOB DRHO $ 1 clipped curves¡ all bit runs merged. .5000 START DEPTH 56.0 113.5 5564.5 5564.5 5564.5 5564.5 5564.5 9800.5 9800.5 9801.0 9809.5 9925.0 9925.0 STOP DEPTH 10309.0 10346.5 10302.5 10302.5 10302.5 10302.5 10302.5 10262.0 10262.0 10262.0 10271.0 10271.0 10271.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 56.0 7242.0 7363.0 7395.5 7418.5 7430.5 7447.0 7450.5 7481.0 7483.5 7493.0 7498.0 7512.0 7517.5 7538.0 7557.0 7584.5 7587.5 7597.5 7630.0 7638.0 7645.0 7655.5 7696.5 GR DEPTH 57.0 7243.0 7364.0 7396.5 7416.5 7430.5 7447.0 7450.5 7480.5 7483.0 7492.0 7497.0 7512.0 7517.5 7538.5 7556.0 7583.0 7587.0 7597.0 7629.0 7637.5 7645.5 7655.0 7695.0 ) ) 7705.5 7704.0 7719.0 7719.0 7726.0 7726.5 7743.0 7743.5 7783.0 7781.5 7802.5 7802.0 7804.0 7803.5 7810.0 7809.5 7834.0 7833.0 7844.5 7842.0 7852.5 7851.0 7874.5 7872.5 7885.0 7882.5 7894.5 7894.0 7905.5 7905.0 7909.0 7908.5 7931.0 7929.5 7959.0 7958.0 7970.0 7970.5 7980.0 7978.5 8010.5 8010.5 8017.0 8015.0 8022.0 8021.0 8044.5 8043.5 8056.0 8055.0 8061.5 8060.5 8091.0 8090.0 8098.0 8097.0 8130.5 8129.5 8157.5 8157.5 8167.5 8166.5 8194.5 8193.5 8205.5 8205.0 8213.0 8211.5 8220.5 8219.0 8255.5 8254.0 8264.0 8262.5 8275.0 8273.0 8315.5 8313.5 8324.0 8320.0 8334.0 8330.5 8349.5 8347.5 8370.0 8367.0 8406.0 8402.5 8434.0 8430.5 8447.5 8443.0 8531.0 8525.0 8543.0 8538.5 8554.5 8551.0 8570.0 8565.0 8610.5 8607.0 8626.0 8623.0 8630.5 8627.5 8643.0 8639.0 8653.5 8646.5 8683.5 8678.0 8704.0 8698.5 8712.5 8707.5 8722.5 8718.0 8756.0 8752.0 8775.5 8769.5 8855.5 8851.0 8970.0 8965.0 8978.5 8972.5 9004.5 8997.5 ) ) 9068.0 9062.0 9100.5 9092.5 9110.0 9103.5 9165.5 9158.0 9178.5 9173.5 9201.5 9196.0 9207.5 9202.0 9226.0 9221.5 9283.5 9277.5 9309.0 9300.0 9320.5 9312.0 9334.5 9325.0 9341.5 9333.0 9351.5 9342.5 9357.0 9348.0 9370.0 9361.5 9387.5 9377.0 9397.5 9388.0 9415.5 9406.5 9440.0 9430.5 9452.0 9443.0 9460.5 9451.5 9470.5 9462.0 9481.5 9472.0 9503.5 9494.0 9525.5 9516.0 9530.0 9521.0 9537.5 9528.0 9546.0 9536.5 9579.0 9570.5 9609.0 9600.0 9627.0 9617.5 9664.5 9654.0 9671.0 9661.0 9679.5 9668.5 9690.0 9679.5 9697.5 9687.0 9710.5 9700.5 9718.5 9708.5 9731.0 9720.5 9742.0 9731.0 9758.0 9747.0 9761.0 9750.5 9768.5 9757.5 9774.5 9764.0 9791.5 9781.0 9799.0 9788.5 9812.0 9801.0 9817.0 9805.0 9821.5 9810.0 9842.0 9830.0 9861.5 9850.5 9865.5 9854.0 9871.5 9861.0 9873.5 9863.0 9876.5 9865.5 9881.5 9874.0 9892.5 9884.5 9895.5 9887.0 9901.0 9892.5 9907.5 9899.5 9913.5 9908.5 9922.0 9917.0 9923.0 9919.0 9929.0 9925.5 ) ) 9934.5 9942.0 9947.5 9951.5 9953.9 9954.0 9970.0 9977.5 10014.0 10027.5 10042.0 10049.5 10059.5 10063.0 10069.5 10076.5 10085.0 10104.5 10111.0 10118.0 10122.0 10129.0 10137.5 10142.0 10162.0 10167.0 10184.5 10189.5 10193.5 10196.0 10201.0 10203.5 10210.5 10232.5 10236.5 10242.0 10251.0 10346.5 $ 9931.0 9938.0 9943.5 9947.5 9948.5 9951.0 9965.5 9972.0 10009.0 10022.0 10039.0 10047.0 10056.0 10060.5 10066.5 10073.0 10082.0 10098.0 10103.0 10112.5 10116.5 10124.0 10132.5 10137.0 10156.5 10161.5 10177.5 10184.0 10188.5 10192.0 10197.5 10199.0 10208.0 10229.0 10233.5 10238.0 10247.5 10343.0 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 57.0 2 5608.0 3 9932.0 MERGE BASE 5608.0 9932.0 10343.0 # 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. ..0 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 56 10346.5 5201.25 20582 56 10346.5 ROP MWD FT/H 0.19 963.91 160.826 20467 113.5 10346.5 GR MWD API 13.04 389.22 70.3355 20507 56 10309 RPX MWD OHMM 0.23 1722.02 5.42262 9477 5564.5 10302.5 RPS MWD OHMM 0.33 1722.04 7.69673 9477 5564.5 10302.5 RPM MWD OHMM 0.38 1815.04 10.7838 9477 5564.5 10302.5 RPD MWD OHMM 0.64 2000 19.676 9477 5564.5 10302.5 FET MWD HOUR 0.31 74.69 3.27301 9477 5564.5 10302.5 NPHI MWD PU-S 8.8 110.74 31.8969 923 9801 10262 FCNT MWD CNTS 409.12 1579.28 807.424 924 9800.5 10262 NCNT MWD CNTS 2210.72 4274.96 3122.01 924 9800.5 10262 RHOB MWD G/CM 1.95 2.81 2.29154 693 9925 10271 DRHO MWD G/CM -0.12 0.76 0.037316 693 9925 10271 PEF MWD BARN 1.45 14.33 4.86604 924 9809.5 10271 First Reading For Entire File......... .56 Last Reading For Entire File. ... ...... .10346.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....03/02/05 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...... .03/02/05 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 2 header data for each bit run in separate files. 1 ) DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ .5000 START DEPTH 57.0 114.5 STOP DEPTH 5549.5 5608.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL 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 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record. .... ....... . Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units. . . . . . . . . . . . . . . . . . . . . . . ) 06-JUL-02 Insite 66.37 Memory 5608.0 56.0 5608.0 .0 51.0 TOOL NUMBER 142827 16.000 .0 Spud Mud 9.20 320.0 8.8 600 11.6 .000 .000 .000 .000 .0 95.0 .0 .0 ) ) Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 57 5608 2832.5 11103 57 5608 ROP MWD010 FT/H 2.92 963.91 201.31 10988 114.5 5608 GR MWD010 API 13.04 111.86 51.4111 10986 57 5549.5 First Reading For Entire File........ ..57 Last Reading For Entire File.......... .5608 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation..... ..03/02/05 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. ... ...03/02/05 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 RPX FET RPD RPM RPS ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 5550.0 5565.5 5565.5 5565.5 5565.5 5565.5 5608.5 STOP DEPTH 9871.0 9863.5 9863.5 9863.5 9863.5 9863.5 9932.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 14-JUL-02 VERSION: Insite ) DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point.. ........... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 66.37 Memory 9932.0 5608.0 9932.0 18.3 51.0 TOOL NUMBER 014179 63122 12.250 5588.0 LSND 9.30 55.0 9.1 400 11.0 1.600 .880 1.600 1.600 72.0 136.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5550 9932 7741 8765 5550 9932 ROP MWD020 FT/H 0.19 495.89 115.127 8648 5608.5 9932 GR MWD020 API 21.87 323.43 93.5879 8643 5550 9871 RPX MWD020 OHMM 0.91 300.5 2.88488 8597 5565.5 9863.5 RPS MWD020 OHMM 0.86 879.67 3.10126 8597 5565.5 9863.5 RPM MWD020 OHMM 0.85 944.75 3.35316 8597 5565.5 9863.5 RPD MWD020 OHMM 0.89 1918.08 5.19039 8597 5565.5 9863.5 FET MWD020 HOUR 0.31 74.69 2.4221 8597 5565.5 9863.5 First Reading For Entire File........ ..5550 Last Reading For Entire File......... ..9932 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/05 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...... .03/02/05 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 FCNT NCNT NPHI PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9790.0 9790.0 9790.5 9798.5 9864.0 9864.0 9864.0 9864.0 9864.0 9871.5 9921.0 9921.0 9932.5 STOP DEPTH 10258.5 10258.5 10258.5 10267.5 10299.0 10299.0 10299.0 10299.0 10299.0 10305.5 10267.5 10267.5 10343.0 ) # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # 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... ..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 ) 17-JUL-02 Insite 66.37 Memory 10343.0 9932.0 10343.0 15.8 18.2 TOOL NUMBER 124725 160816 078940 067985 8.500 9920.0 BARADRIL-N 9.05 56.0 8.5 15000 4.0 .330 .180 .330 .350 63.0 122.0 63.0 63.0 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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9790 10343 10066.5 1107 9790 10343 ROP MWD030 FT/H 12.35 467.7 98.4613 822 9932.5 10343 GR MWD030 API 22.12 389.22 79.5909 869 9871.5 10305.5 RPX MWD030 OHMM 0.23 1722.02 30.0894 871 9864 10299 RPS MWD030 OHMM 0.33 1722.04 52.2588 871 9864 10299 RPM MWD030 OHMM 0.38 1815.04 82.7214 871 9864 10299 RPD MWD030 OHMM 0.46 2000 173.034 871 9864 10299 FET MWD030 HOUR 0.5653 73.8705 12.7671 871 9864 10299 NPHI MWD030 PU-S 8.8 110.74 32.3391 937 9790.5 10258.5 FCNT MWD030 CNTS 409.12 1579.28 801.475 938 9790 10258.5 NCNT MWD030 CNTS 2210.72 4274.96 3111.65 938 9790 10258.5 RHOB MWD030 G/CM 1.95 2.81 2.29349 694 9921 10267.5 DRHO MWD030 G/CM -0.12 0.76 0.0376081 694 9921 10267.5 PEF MWD030 BARN 1.45 14.33 4.97196 939 9798.5 10267.5 First Reading For Entire File......... .9790 Last Reading For Entire File.. ....... ..10343 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation... ... .03/02/05 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name....... ... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 02 / 0 5 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name....... ... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 /02 / 05 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN ) ) Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File