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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. Some people who received this message don't often get email from lmoore@hilcorp.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Luke Moore - (C) Cc:Regg, James B (OGC) Subject:RE: S-102 Initial BOPE test Date:Tuesday, January 23, 2024 2:18:55 PM Attachments:Nabors CDRAC 12-13-23 Revised.xlsx Luke, Attached is a revised report removing the CH Misc “FP” (based on the quantity “0”). Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Luke Moore - (C) <lmoore@hilcorp.com> Sent: Friday, December 15, 2023 2:02 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS - CTD DSM <AlaskaNS-CTD-DSM@hilcorp.com> Subject: S-102 Initial BOPE test All- Please see the attached 10-424 Form for well S-102 Thanks Luke Moore 3%86 37' revised removing the CH Misc “FP” 907-670-3097 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CDR2AC DATE: 12/13/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2001290 Sundry #323-366 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:2321 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2.0"P Trip Tank PP Annular Preventer 1 7 1/16" GK P Pit Level Indicators PP #1 Rams 1 Blind / Shears P Flow Indicator PP #2 Rams 1 2.0" Pipe / Slip P Meth Gas Detector PP #3 Rams 1 2-3/8" Pipe / Slip FP H2S Gas Detector PP #4 Rams 1 2.0" Pipe / Slip FP MS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2-1/16"P Pressure After Closure (psi)2200 P Check Valve 0NA200 psi Attained (sec)18 P BOP Misc 2 2.0" Piper FP Full Pressure Attained (sec)58 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 2200 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 4 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 2 P Inside Reel valves 1P #3 Rams 2 P #4 Rams 2 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:14.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/11/2023 17:11 Waived By Test Start Date/Time:12/13/2023 7:00 (date) (time)Witness Test Finish Date/Time:12/13/2023 21:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors 2'' lower pipe slip rams and 2-3/8'' lower pipe slip rams Fail / Pass. CO both sets of lower pipe slip rams. Retested and had lower 2-3/8'' DS Door Seal Fail due to getting pinched CO pipe / slip ram. Replaced and passed test. TV2 valve was leaking CO TV2 with new valve and passed test. Fail / Pass. N.Wheeler / W.Williams Hilcorp North Slope, LLC Kavanagh/Moore PBU S-102 Test Pressure (psi): Nathan.wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022) 2023-1213_BOP_Nabors_CDRAC_PBU_S-102 9 9 9 9999 9 9 9 9 9 9 9 9 -5HJJ FP FP FP 2'' lower pipe slip rams 2-3/8'' lower pipe slip rams Fail DS Door Seal Fail TV2 valve was leaking 643 sx AS Lite, 510 sx Class G, 150 sx AS Lite By Grace Christianson at 11:11 am, Jan 17, 2024 Abandoned 12/15/2023 JSB RBDMS JSB 012924 xG DSR-2/13/24 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.15 11:02:34 -09'00' Torin Roschinger (4662)Drilling Manager 01/15/24 Monty M Myers ACTIVITYDATE SUMMARY 6/22/2023 T/I/O= 766/968/268 (HOT OIL TBG WASH) Pumped 141 bbls of 190* Crude down TBG. Pumped 20 bbls of 190* Crude down FL. Pad Op notified of well status upon departure.Valve Positions - SV/WV/SSV= Closed, MV/AL= Open, IA/OA= OTG. FWHPs= -14/955/386 7/23/2023 TFS UNIT 3 Assist Slick Line *******Job Canceled***** 7/27/2023 ****WELL FLOWING UPON ARRIVAL**** (CTD) RAN 3.80" G. RING TO PARAFFIN AT 1,494' SLM RAN 2.25" G. RING TO 2,884' SLM (unable to work deeper) RAN 2-7/8" BRUSH & 1.90" G. RING TO 8,000' SLM (75 bbls hot diesel pumped) RAN 2-7/8" BRUSH & 2.25" G. RING TO 4,500' SLM RAN 3-1/2" BRUSH & 2.65" G. RING TO 8,000' SLM RAN 4-1/2" BRUSH & 3.25" G. RING TO 3,090' SLM (unable to work deeper. 16 bbls hot diesel pumped) RAN LOOSE 4-1/2" BRUSH & 2.83" G. RING TO 8,000' SLM RAN LOOSE 4-1/2" BRUSH & 3.25" G. RING TO 8,000' SLM (worked tight spots from 3,100' - 4,100'. 14 bbls hot diesel pumped) RAN 4-1/2" BRUSH & 3.80" G. RING TO X-NIP AT 11,351' MD (worked tight spots from 3,200' - 4,700'. 25 bbls hot diesel pumped) RAN 4-1/2" BRUSH & 3.65" G. RING TO XO AT 11,446' MD ***CONTINUE ON 7/28/23 WSR*** 7/28/2023 T/I/O= 868/861/272 LRS Unit 72 Assist Slickline. Pumped 154 bbls 1% KCL to load the IA followed by 44 bbls diesel down the IA for freeze protect. MIT-IA to 2750 psi. ***FAIL*** Pumped 44 bbls dsl and 6 bbl crude down IA to take pressure to 2750 for 2 failing MIT-IA's. On the 2nd test. 2nd test failed after 22 mins. (SEE LOG). ***Job Cont to 07/29/2023 WSR*** 7/28/2023 ***CONTINUED FROM 7/27/23 WSR*** (CTD) SET 4-1/2" WHIDDON AT 11,421' MD PULLED BK-OGLV AT ST# 1 (11,136' md) PULLED BK-LGLV AT ST# 3 (9,052' md) & ST# 4 (5,830' md) SET BK-DGLV AT ST# 4 (5,830' md), ST# 3 (9,052' md) LRS LOADED IA W/ 150 BBLS KCL & 44 BBLS DIESEL SET BK-DGLV AT ST# 1 (11,136' md) LRS PERFORMED FAILING MIT-IA MULTIPLE TIMES (suspect gas migrating) PULLED EMPTY 4-1/2" WHIDDON AT 11,421' MD DRIFT W/ 20' x 2.70" DUMMY WHIPSTOCK TO DEVIATION AT 11,664' SLM CURRENTLY BLEEDING GAS OFF IA ***CONTINUE ON 7/29/23 WSR*** 7/29/2023 ***Job Cont from 07-28-2023 WSR*** MIT-IA to 2613 psi ***PASS*** Max Applied = 2750 psi Target = 2500 psi Pumped 27.8 bbls crude down IA to take pressure to 2753 psi. IA lost 106 psi in the 1st 15 mins and 34 psi in 2nd 15 mins for a total loss of 140 psi in 30 min test. Bled IA to 100 psi and got back ~3 bbls. Pad Op notified of well stats per LRS departure. SV,WV= C SSV,MV=O IA,OA=OTG **Tag hung on IA 7/29/2023 ***CONTINUED FROM 7/28/23 WSR*** (CTD) BLEED GAS OFF IA. HAND OFF TO LRS FOR MIT-IA ***LRS IN CONROL OF WELL ON DEPARTURE*** 8/5/2023 T/I/O 1150/200/225 Temp S/I (TFS unit 4 assist SL with TBG Load) Pumped 200 bbls of crude down TBG to Load well. *********WSR Continued on 8/6/2023*********** Daily Report of Well Operations PBU S-102 Daily Report of Well Operations PBU S-102 8/5/2023 ****WELL S/I ON ARRIVAL****(Ctd) SET 4 1/2" WHIDDON CATCHER ON XN AT 11,421' MD TB LOADED TBG w/ 200BBLS CRUDE. ***CONTINUED ON 8/6/23 WSR*** 8/6/2023 *********WSR continued from 8-5-2023********* (TFS unit 4 assist SL with TBG load) Pumped 17 bbls of crude down TBG to assist SL get to depth. Well left in SL control Final WHPS 0/0/278 8/6/2023 ***CONTINUED FROM 8/5/23 WSR*** (Ctd) PULLED BK-DMY GLV FROM ST. # 1 @ 11,136' MD PULLED BK-DMY GLV FROM ST. # 3 @ 9,052' MD PULLED BK-DMY GLV FROM ST. # 4 @ 5,830' MD SET BK-DOME GLV IN ST. # 4 @ 5,830' MD SET BK-DOME GLV IN ST. # 3 @ 9,052' MD SET BK-SO GLV IN ST. #1 @ 11,136' MD PULLED 4-1/2" WHIDDON FROM 11,405' SLM(empty) ****WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS**** 8/11/2023 T/I/O= 653/866/270 (CTD) HOT OIL TBG WASH - Pumped 1 bbls of 50/50 and 141 bbls of 190* Crude down TBG. Pumped 20 bbls of 190* Crude down FL. FWHP=0/892/374. Apon departchure Wing, SSV, Swab left closed. TC, IA, OA, Master left open. DSO notified apon Departchure. 9/4/2023 Hot Oil Treatment (HOT OIL TBG WASH) Pumped 3 bbls 60/40 meth and 142 bbls 180* Crude into the TBG. Pumped 20 bbls 180* Crude down FL. SV/WV = C, SSV/MV/AL = O, IA/OA = OTG. Pad op notified upon LRS departure. 9/16/2023 T/I/O = 717/844/260. Temp - SI. Assist SL. Pumped 191 bbls 190* Crude into TBG for Brush and Flush. *** Job continued to 09-17-2023 *** 9/16/2023 *** WELL FLOWING ON ARRIVAL *** RUN VARIOUS SIZE G-RINGS & BLB FROM 2.25" TO 3.72" WHILE PUMPING HOT CRUDE TO CLEAN PARRAFFIN FROM TUBING (194 TOTAL BBLS PUMPED) *** CONTINUE ON 9/17/2023 *** 9/17/2023 *** Job continued from 09-16-2023 *** Assist SL. Pumped 191 bbls 190* Crude into TBG (2 day total of 282 bbls 190* Crude) for Brush and Flush. SL in control of well upon departure. FWHP's = 130/861/352 9/17/2023 *** CONTINUE FROM 9/16/2023 *** BRUSH & FLUSH W/ 3.76" & 3.80" GAUGE RINGS TAG XN @ 11,421' MD W/ 3.80" G-RING ( 88 BBLS PUMPED......282 TOTAL BBLS PUMPED FOR ENTIRE JOB) *** WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS *** 11/7/2023 T/I/O=640/1000/240 (HOT TBG FLUSH) Pump into TBG w/ 3 bbls 60/40, 141 bbls 190* Crude. DSO to POP FWHP=0/950/330 11/16/2023 T/I/O=750/850/250 Assist S/L ( Load & Test TBG ) Freeze protect flowline with 5 bbls 60/40. Pump 260 bbls 180* crude down Tbg for brush & flush. FWHPs=0/871/373 Daily Report of Well Operations PBU S-102 11/16/2023 ***WELL FLOWING ON ARRIVAL*** ATTEMPT TO SET CATCHER, ENCOUNTER PARAFFIN RAN 4-1/2'' BRUSH, 3.50'' G. RING, WORK THROUGH TIGH SPOTS FROM 2750' - 3800' SLM RAN 4-1/2'' BRUSH, 3.70'' G. RING, DRIFT TO X NIP @ 11446' MD RAN 4-1/2'' BRUSH, 3.80'' G. RING, WORK THROUGH TIGHT SPOTS FROM 2750' - 6000' SLM, DRIFT TO XN NIP @ 11421' MD SET CATCHER ON XN NIP @ 11421' MD ***WSR CONT. 11-17-2023*** 11/17/2023 T/I/O=600/700/250 TFS unit#3 (Assist Slickline). Pumped 254 bbls of crude down the TBG to load for an MIT-T *Job continues to 11-18-23* 11/17/2023 ***WSR CONT. FROM 11-16-2023*** PULLED BK-SOV FROM STA# 1 @ 11136' MD PULLED BK-GLV FROM STA# 3 @ 9052' MD PULLED BK-GLV FROM ST#4 @ 5830'MD SET BK-DGLV IN ST#4 @ 5830'MD SET BK-DGLV IN ST #3 @ 9052'MD SET BK-DGLV IN ST#1 @ 11136'MD PULLED WHIDDON CATCHER FROM XN-NIP @ 11421'MD SET 3.81'' PX PLUG IN X NIP @ 11351' MD ***WSR CONT. 11-18-2023*** 11/18/2023 ***WSR CONT. FROM 11-17-2023*** MIT-T (Pass) PULL 3.81'' PX PLUG @ 11351' MD ***WELL S/I ON DEPARTURE*** 11/18/2023 *Job continues from 11-17-23* (Assist Slickline MIT-T) TFS U3. Pumped 2 bbls of crude down the TBG to attempt an MIT-T map @ 2500 psi. *PASS* reached test pressure at 2517 psi. First 15 minutes TBG lost 117 psi. Second 15 minutes TBG lost 41 psi. *PASS* bled back 1.8 bbls of crude to take TBG down to 200 psi for slickline to pull plug. Well left in control of slickline upon departure 11/20/2023 LRS CTU #1 - 1.50" Blue Coil Job Objective: Pre-rig whipstock drift. Travel to location, MIRU CTU. Complete weekly BOP test. Make up FCO/log BHA with a 2.40" GR/CCL carrier and a 2.75" DJN. RIH dry drift down to PBTD, log up, POOH. +16' correction. Corrected PBTD 12,680.82'. M/U whipstock drift. RIH ...Continued to WSR on 11/21/23..... 11/21/2023 LRS CTU #1 - 1.50" Blue Coil Job Objective: Pre-rig whipstock drift. Continue RIH w/whipstock drift. Correct depth at flag. RIH, drift to PBTD at 12,676 corrected CTMD. POOH, Cap well with 38bbls diesel. RDMO ***Job Complete*** 6.30.2023 By Grace Christianson at 10:24 am, Jun 30, 2023 323-366 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.06.30 09:35:21 -08'00' Monty M Myers MDG 7/17/2023 10-407 DSR-7/6/23 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(I) approved for alternate plug placement with fully cemented liner on upcoming CTD sidetrack MGR18JUL23GCW 07/19/2023 JLC 7/19/2023 07/20/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.20 00:10:43 -05'00' RBDMS JSB 072023 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: June 28, 2023 Re: S-102 Sundry Request Sundry approval is requested to set a whipstock and mill a window in the S-102 wellbore as part of the drilling and completion of the proposed S-102A CTD lateral. Proposed plan: A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE, and kill the well. The rig will set the 3-1/2" whipstock. A single string 2.80" window + 10' of formation will be milled. The well will kick off drilling in the Kuparuk C and continue drilling the upper Kuparuk C to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated and frac'd at the toe post rig. This completion will completely isolate and abandon the parent Kuparuk perfs.This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work 1. SL Dummy GLMs. Set and pull plug for MIT 2. C Drift for 3-1/2” Whipstock 3. F MIT 4. V Pre-CTD Tree and gravel work Rig Work 1 MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,321 psi). 2 Set Whipstock and Mill 2.80” Window. 3 Drill production lateral: 3.25" OH, ~2530' (10 deg DLS planned). 4 Run 2-3/8" 13Cr liner 5 Pump primary cement job: 23 bbls, 15.3 ppg Class G, TOC at TOL*. 6 Freeze protect well to a min 2,200' TVD. 7 Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. V: Valve & tree work 2. S: SBHPS, set LTP* (if necessary). Set live GLVs. 3. C: Post rig perforate (~1000’) and RPM. 4. T: Portable test separator flowback. .This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). @ 12,640' MD -mgr MIT-IA to 2500 psi. -mgr per Ciolkosz email 7-17-23 11:16 Sundry 323-366 Hazards: x S Pad is an H2S pad. H2S reading on S-27B: 140 ppm on 01/10/2012. o Max H2S recorded on S-102: 78 ppm. Reservoir Pressure: x The reservoir pressure is expected to be 3000 psi at 6799’ TVDSS (8.6 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2321 psi. x A min EMW of 8.4 ppg for this well will be 30 psi under-balance to the reservoir. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 S-102 S-102 S-102 A 15,170' - 2-3/8" LNR 4.7#, L80, HYD511, ID=1.995" 3-1/2" Whipstock - 12640' 11475' - 2.70" DPLY SLV Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip RECEIVED S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C SSION REPORT OF SUNDRY WELL OPERATIONS APR 1 1 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations .• y Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-129 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 -•°- AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22972-00-00 7. Property Designation(Lease Number): ADL 028256 8. Well Name and Number: PBU S-102 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL 11.Present Well Condition Summary: Total Depth: measured 13488 feet Plugs measured 12675 feet true vertical 6787 feet Junk measured None feet Effective Depth: measured 12675 feet Packer measured 11316,11524 feet true vertical 6687 feet Packer true vertical 6611.6701 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 29-108 29-108 1490 470 Surface 4788 10-3/4" 29-4816 29-3315 3580 2090 Intermediate 11690 7" 27-11717 27-6762 8160 7020 Production Liner 1557 4-1/2" 11543-13100 6708-6749 8430 7500 Perforation Depth: Measured depth: 11660-12549 feet SCANNED True vertical depth: 6746-6754 feet 1�� Tubing(size,grade,measured and true vertical depth) 4-112"12.6#x 3-112"9.3#,13Cr85/13Cr80 23-12720 23-6750 Packers and SSSV(type,measured and 4-1/2"12.6#L-80 11520-11559 6700-6714 true vertical depth) 4-1/2"HES TNT Pkr,4-1/2"BKR S-3 Pkr 11316,11524 6611,6701 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 208 457 221 1166 210 Subsequent to operation: 305 236 280 1179 208 • 14.Attachments:(required per 20 AAC 25.070.25.071,5 25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A • Authorized Name: Youngmun,Alex Contact Name: Youngmun,Alex Authorized Title: OA,Kupparuk&/�Scchhrader Bluff PE Louie Contact Email: younak@BP.com Authorized Signature: ""I,I'"°J✓' Date: Contact Phone: +1 907 564 4864 Form 10-404 Revised 04/2017 / tri_�//4�y Z//"/1 b RBDMS P 1 3 2018 Submit Original Only �J (13 K 7.7/1 M • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) April 11, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU S-102, PTD #200-129. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • Daily Report of Well Operations PBU S-102 ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL***(Perforating) BRUSHED DOWN TO 7000'SLM (4220'TVD)WITH 2-7/8" BL-BRUSH 1.90"G-RING. LRS PUMPED 60 BBLS OF HOT CRUDE. BRUSHED DOWN TO 8000'SLM (4650'TVD)WITH LOOSE 3 1/2" BL-BRUSH 2.50" G-RING. LRS PUMPED 35 BBLS OF HOT CRUDE. 3/12/2018 ***CONT ON 3-13-18 WSR*** T/I/0=760/1000/225 Assist S-Line w/Brush &Flush. Pumped into Tbg. w/40 bbls 180*Crude, 20 bbls 180*Diesel, Pumped 36 bbls hot crude while SLine brushed. Pumped 36 bbls crude down Tbg to push SLine down hole. Pumped 22 bbls 60/40 meth down Tbg to pump SLine down hole***Job 3/13/2018 Cont to 03-14-2018 WSR*** ***Continued from 03-12-18 WSR*** Assist Slickline w/B&F. Pumped 53 bbls(148 bbls total)of 180* crude down TBG while Slickline brushed. S-line on well on dep wing shut swab shut ssv shut 3/13/2018 master open casing valves open to gauges AL shut Final WHp's=70/655/231 ***CONT FROM 3-12-18 WSR*** BRUSHED DOWN TO 8,500' SLM WITH STIFF 3-1/2" BRUSH, 2.73" G-RING, LRS PUMPED 25 BBLS OF HOT CRUDE. BRUSHED DOWN TO 7,000' SLM WITH LOOSE 4-1/2" BRUSH, 3.0"G-RING. BRUSHED DOWN TO 3,307' SLM WITH TIGHT 4-1/2" BRUSH, 3.80" G-RING, LRS PUMPED 18 BBLS OF HOT CRUDE. BRUSHED DOWN TO 3,38'SLM WITH TIGHT 4-1/2" BRUSH, 3.25" G-RING. BRUSHED DOWN TO 6,500' SLM w/3-1/2" BRUSH, 3.80" SCRATCHER, 3.25" G-RING. BRUSHED DOWN TO 6,500'SLM w/4-1/2" BRUSH, 3.50"G-RING. BRUSHED DOWN TO 8,500'SLM w/4-1/2" BRUSH, 3.80"G-RING. LRS PUMPED 80 BBLS HOT CRUDE, 20 BBLS HOT DIESEL. RAN 30'x 2-1/2" DUMMY PERF GUNS (2.77" MAX OD OMEGA DRIFT). STOPPED DUE TO DEV AT 11,670'SLM WITH LRS PUMPING. RAN 30'x 2-1/2" DUMMY PERF GUNS (2.77" MAX OD OMEGA DRIFT)**WITH 10' OF ROLLER STEM**AND ALOT OF WORKING TLS. STOPPED DUE TO DEV AT 11,723' SLM WITH LRS PUMPING. 3/13/2018 ***CONT ON 3-14-18 WSR*** ***CONT FROM 3-13-18 WSR*** RAN 20' OF 2 1/2" DMY GUNS (2.77" MAX OD OMEGA DRIFT)WITH ROLLER STEM. STOP DUE TO DEV(150FPM)W/O WORKING TLS @ 11,663' SLM. UNABLE TO GET DEEPER. ***WELL LEFT S.I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** ***DRIFTED TO 3000'W/3.70"x 20' DMY WHIPSTOCK FOR SUBSIDENCE 3/14/2018 SURVEILLANCE*** ***WELL S/I ON ARRIVAL***(SLB ELINE PERF IN PROGRESS) S/B FOR SRT TO CLEAN OPERATIONS SPILL ON PAD. INITIAL T/I/O =700/950/200. MIRU, LPT/HPT= PASS. RIH W/2.5"X 30' POWERJET OMEGA GUNS, 6 SPF, 60 DEG PHASE. OAL= 57', OAW= 540 LBS, MAX SWELL IN LIQUID=2.78". 3/14/2018 ***JOB CONTINUED ON 15-MARCH-2018*** ***Job Cont from 03-13-2018 WSR*** Pumped 6 bbls (28 bbls total)60/40 meth down Tbg to pump down SLine. Pumped 7 bbls 60/40 meth down FL for FP. Pressured up FL to 1500 psi. SLine 3/14/2018 incontrol of well per LRS departure. FWHP's=250/980/220 IA,OA=OTG Assist EL as directed (PERFORATING) Spot equipment, SB for E-Line to rig up. **WSR continued 3/14/2018 on 3-15-18** • • Daily Report of Well Operations PBU S-102 ***JOB CONTINUED FROM 14-MARCH-2018*** CONTINUE RIH W/2.5"X 30' POWERJET OMEGA GUNS, 6 SPF, 60 DEG PHASE. OAL=57', OAW= 540 LBS, MAX SWELL IN LIQUID=2.78". PERFORATE 11684'- 11714', GOOD INDICATION OF SHOT. RUN 2: RIH W/2.5"X 26' POWERJET OMEGA GUNS, 6 SPF, 60 DEG PHASE. OAL= 52', OAW=490 LBS, MAX SWELL IN LIQUID = 2.78". PERFORATE 11658'- 11684'. GOOD INDICATION OF SHOT, POOH, RDMO. ALL LOGS CORRELATED TO SLB MEMORY TEMPERATURE LOG DATED 4-AUG-2012 WELL LEFT S/I ON DEPARTURE. FINAL T/I/O =710/950/200 3/15/2018 ***JOB COMPLETE 15-MARCH-2018*** Fluids Summary Bbls Type 22 Diesel 260 Crude 40 60/40 Methanol TREE 4-1116'aw • WELLHEAD= FMC silly NOTE'S-- WELL ANGLE>Tr @ 12972""`CHROME TBG""CAtJTIOPt 2 SWS RADIOACTIVE SOURCES P&A'd ACTUATOR- LEO IB.�1 64 2' S -102 10/04/00 W I RED CMT TO PB 8017'MD/4655'TVD. 1)8564' MD/4882'TVD-2.0 CURIE CS-137. 2)8531'M1/486T TVD- KOP= 1400 _ 1 4.0 CURIEAM-241"IF S-102 IS ROTARY STd,DO NOT RE Max Angle= 93" ?, 12497' 20"CXNDUCTOR 109• ENTH2 WELL BELOW S-102 PSI DEPTH BEFORE CALLING Datum MD= 11724' 91.5#,H-40, _ US.NUCLEAR REG COMM&AK DEPT OF O&G** Datum IVO= 6700'SS ID=19.124" 2206' —{4-112 HE S X NP D=3.813* 10-3/4'TAM FORT COLLAR --I 982' ' 1 GAS LFT MANDRELS r PORT COLLAR H 2185' ST MD TVD DEV TYPE VLV LATCH FORT DATE 10-3/4'CSG,45.5#,K-55-BTC.0=9.95" --I 4816' 4 5830 3740 67 KBG-4-5 DOME BK 16 12/22/12 LI 3 9052 5247 53 KBG-4-5 DOLE BK 16 1222/12 7"PORT COLLAR H 6992' = 2 10429 6084 54 KBG-4-5 DMY BK 0 10/27/11 1 11136 6505 53 KBG-4-5 SO BK 22 12/22/12 4-1/2"MJPG-C GAUGE MANDREL,D=3.958_ —{ 11212* a ' •J 11287' --14-1/7 HES X NP,D=3.813" Minimum ID =2.972" @ 11446' 4-1/2"X 3-1/2" XO g, z� 11316' --17"X 4-1/2"FES TNT PKR D=3.856' li 11361' H4-1/2"FEES X 11P,D=3.813" 11421' H4-1/2"HES XN NIP,D=3.725" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, --I 11441' }---- .0152 bpf,0=3.958" 11446' H4-1/2.X 3-1/2"XO,D=2.972" 14-1/2-TBG STUB(09/20/11) H{ 11620' I---- 11624' 7"X 4-1/2"BKR S-3 PKR,D=3.875" 11643' —17.40'TIEBACK SLV,0=5.25" I TOP OF 4-1/2'LNR —I 11643' 11647' --14-1/2"1-ES X NP D=3.813' 3 11660' _I-1 T X 5"BKR LTP,D=4.406 4-12-TBG,12.8#,L-80 BT, --{ 11559' 11657' H 7"X 4-1/2"BKR HMC HGR,D=3.938' j .0152 bpf,D=3.958" 11559' H4-1/2*WLEG,D=4.00' 11553' --I ELMD TT LOGGED 12/12/00 7"CSG,29#,L-80 BTC-M, H 11717' 10,_ -11660 —I EST TOC .0371 bpf,D=6.182' l k PE2FORATION SUMMARY \A i , .s REF LOG: SPE4RY MWD DGR-EWR ON 10/19/00 F ■ ANGLE AT TOP PERF: 73"r, 11660' I F' Note:Refer to Aoduction DB for historical perf data I 11 SEE SPF INTERVAL 1 Opn/Sgz DATE R 12264' H FES TY PE H CEMENTER, MILLED TO 3.80"(10/8/03) SEE FACIE 2 FOR PERFORATION DATA6 • ✓ �4, 12267' —14-1/2'BKR CTC EXTERNAL PKR,D=3.875' 1 I I 1 ►.� .. MID 2003 CID TOF DMA OUT WITH 3-3/16"X2-7/8" 12675' 4 LW FBTD IS AT 14968'MD.2011 R/A)ISOLATED C I D LA IERAL BY C734_NTTIG 3-1/7 CONCENTRICLNR I, 0 13 PLACE ABOVE CTD LW.TOP /' U 1 3-12"TBG,9.3#,13CR-80 an_ H 12690' p 'l 0087 bpf,D=2.972' 1.��-- 12676'1-H3-1/2"BKR CBP(07/25/12) r ,�1►I+.+e1 4-12'LNR 12.6#,L-80 BT H 13100' Rlr�♦+ 12720' j—I3 1/2'HALF 11E�aFlOE;D=3.00' 41 .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY CO/MEWS AURORA 1141 10/24/00 COMPLETION 01/29/18 AY/JMD EDITS TO PERF IF0&CMT WELL: S-102 11/05103 TAI MTLP CTD SIDETRACK(L1) 03/15/18 AY/JMD EMS TO NOTES&FBTD PERMIT No:"2001290 10/31/11 D-16 RWO 03/21/18 MS/JMD ADP ES(03/15/18) AR No: 50-029-22972-00 01/12/12 DB/PJC FINAL DRLG CORRECTIONS SFC 35,T12N,R12E 828'FAL&781'FWL 11/19/12 JA/JMD ( TT/P E SQZ 1227/12 JAR/JMD GLV C/O(12/22/12) BP E3rploratlon(Alaska) • • S -102 = L a I I z I I I U PERFORATION SUMIAARY RE=LOG: SPERRY MWD DGR-e R ON 10/19/00 ANGLE AT TOP PERF: 73"n 1166(Y ' 1 Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ S-102 2-7/8" 6 11660-11680 S 08/11/11 08/16/12 2-1/2" 6 11660-11716 0 03/15/18 3-3/8" 6 11680-11700 S 01/21/01 08/16/12 2-7/8" 6 11690-11710 S 12/22/06 08/16/12 3-3/8" 6 11716-11736 S 01/21/01 08/16/12 2-1/2" 6 11720-11745 0 10/06/12 2" 6 12308-12318 S 08/01/12 08/02/12 2-1/7 6 12524-12549 0 08/17/12 2" 6 12550-12575 S 08/04/12 08/16/12 5-10211 2-7/8" SLID 13284-14384 AB 11/02/03 2-7/8" SLID 14475-14935 AB 11/02/03 1,. Ie fir, ! p Grfr •:i' #• DATE REV BY O0114M34TS DATE REV BY COMIIABNfS AURORA UNIT 10/24/00 COMPLETION 01/29/18 AY/AD EDITS TO PERF INFO&CMT WELL: S-102 11/05/03 TMNTLPCTD SIDETRACK(L1) 03/15/18 AY/A/D EDITS TO NOTES 8PBTD PERMIT No:It001290 10/31/11 D-16 MO 03/21/18 MS/JVD ADFE RFS(03/15/18) API No: 50-029-22972-00 01/12/12 DB/PJC ANAL DRLG CORRECTIONS SEC 35,T12N,R12E,828'FNL&781'FWL 11/19/12 JA/JMJ CMT/PERF SQZ 12/27/12 JAR/AID GLV C/O(12/22/12) BP Exploration(Alaska) REEIVE° STATE OF ALASKA • NOV 2 ® 2012 AASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGGC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac IS Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WelrJ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 200-129-0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22972 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: - ADL0028256 " AURA S -102 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: Total Depth measured 13488 feet Plugs measured 12675 feet true vertical 6787.46 feet Junk measured None feet Effective Depth measured 11111 feet Packer measured See Attachment feet true vertical 6490.14 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 4791 10 -3/4" 45.5# K -55 27 - 4818 27 - 3315.34 • "M$` 2090 Intermediate None None None None None None Production 11693 7" 29# L -80 26 - 11719 26 - 6762.84 8160 7020 Liner 1557 4 -1/2" 12.6# L -80 11543 - 13100 6708.24 - 6749.3 8430 7500 Perforation depth Measured depth See Attachment feet L � True Vertical depth See Attachment feet SCANNED MAR • Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): CIBP Set @ 12675'; Sqz Perfs: 12308'- 12318', Cmt Sqz: 11660'- 13488'; Sqz Perfs: 12550'- 12575', Cmt Sqz: 12550'- 12575', Frac Perfs: 12524'- 12549', Second Frac Perfs: 12524'- 15549',11720'- 11745'. Treatment descriptions including volumes used and final pressure: First Cmt Sqz: 70.1 Bbls LARC Cement, 3124 psi; Second Cmt Sqz: 53.5 Bbls LARC Cement, 5900 psi; First Frac Stim: 782 Bbls 25# Lin Gel, 872 Bbls Yf125FlexD, 47 Bbls LVT -200 Mineral Oil, 106,260 Ibs 20/40 Carbolite Propant, 4040 psi; Second Frac Stim: 546 Bbls 25# Lin Gel, 732 Bbls YF125 FIexD X -Link Gel, 55 Bbls LVT -200 Mineral Oil, 104,756 Ibs 20/40 Carbolite Propant, 3012 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 166 5411 1575 255 Subsequent to operation: 1006 1377 1411 1733 455 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development IMI - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . U Gas U WDSPLIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry Printed Name Garry Catron Title PDC PE Signature N a4017:414t / v `- Phone 564 -4424 Date 11/20/2012 1Z. -14.12 /� / Z rn 2 - Form 10 -404 Revised 10/2012 i Submit Original Only • 0 fp Packers and SSV's Attachment ADL0028256 SW Name Type MD TVD Depscription S -102 PACKER 11316 6546.48 4 -1/2" HES TNT Perm Packer S -102 PACKER 11524 6637.25 4 -1/2" Baker S -3 Perm Packer S -102 PACKER 11543 6644.04 4 -1/2" Baker ZXP Packer S -102 PACKER 12266 6701.36 4.5" Baker CTC Packer Perforation Attachment ADL0028256 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base S -102 8/16/2012 SQZ 11660 11680 6746.01 6751.77 S -102 8/16/2012 SQZ 11680 11700 6751.77 6757.51 S -102 10/6/2012 SQZ 11716 11720 6762.01 6763.11 S -102 10/6/2012 APF 11720 11736 6763.11 6767.29 S -102 10/6/2012 APF 11736 11745 6767.29 6769.36 S -102 8/16/2012 SQZ 12308 12312 6764.25 6764.12 S -102 8/16/2012 SQZ 12312 12318 6764.12 6763.92 • S -102 8/17/2012 SQZ 12318 12524 6763.92 6755.22 S -102 8/17/2012 APF 12524 12549 6755.22 6754.47 S -102 8/17/2012 SQZ 12549 12550 6754.47 6754.44 S -102 8/16/2012 SQZ 12550 12575 6754.44 6753.7 S -102 8/4/2012 SQZ 12575 12675 6753.7 6750.9 S -102 7/26/2012 BPS 12675 13100 6750.9 6749.3 S -102 7/26/2012 BPS 13100 13488 6749.3 6787.46 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER • PER PERF SPR SAND PLUG REMOVED RPF REPERF ■ Casing / Tubing Attachment ADL0028256 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 29 - 109 29 - 109 1490 470 LINER 1557 4 -1/2" 12.6# L -80 11543 - 13100 6708.24 - 6749.3 8430 7500 PRODUCTION 11693 7" 29# L -80 26 - 11719 26 - 6762.84 8160 7020 SURFACE 4791 10 -3/4" 45.5# K -55 27 - 4818 27 - 3315.34 3580 2090 TUBING 12698 4 -1/2" 12.6# 13Cr80 22 - 12720 22 - 6749.97 8430 7500 TUBING 39 4 -1/2" 12.6# L -80 11520 - 11559 6700.02 - 6713.92 8430 7500 • • s Daily Report of Well Operations ADL0028256 RAN 4 -1/2" BLB & 3.805" G. RING & PUSH DEBRIS FROM 2245' SLM TO 3710' SLM. UNABLE TO PUSH FURTHER MADE MULTIPLE BAITED 3.70" WIRE GRAB RUNS. RECOVER 1 COMPOSITE BRIDGE PLUG ELEMENT FROM 11,218' SLM ALSO RECOVER AN 1/8 OF A CUP OF METAL DEBRIS INSIDE THE 4 -1/2" BAIT SUB RAN 10' 3.50" PUMP BAILER W/ 3.60" FINGER BASKET BTM TO 4 -1/2" x 3 -1/2" XO @ 11,431' SLM / 11,446 MD ABLE TO RECOVER 1/2 CUP OF VARIOUS SMALL PIECES OF METAL & SOME PIECES OF PLASTIC 6/19/2012 * * *CONT ON 06/20/12 WSR * ** * * *CONT FROM 06/19/12 WSR * ** (fracturing) RAN 5' OF 3.50" PUMP BAILER W/ 3.60" FINGER BASKET TO XO @ 11,431' SLM / 11,446' MD. (nothing recovered) RAN 2.77" SWAGE, 2.69" CENT & 2.67" MAGNET TO 11486' SLM. (recovered 1" piece of metal) RAN 3 -1/2" GR, 3 -1/2" BAIT SUB, 2.60" 3 -PRONG WIRE GRAB TO 11498' SLM (nothing recovered). RAN 10' x 2.50" P. BAILER W/ FINGER BASKET BTM, WORK TO DEV @ 11648' SLM (recovered 3 pieces of metal). ATTEMPT TO SET 4 -1/2" WHIDDON CATCHER, ENCOUNTERED DEBRIS AT MULTIPLE DEPTHS. RAN 3.75" JUNK BASKET TO XN @ 11412' SLM, (recovered 2 pieces of metal)) SET 4 -1/2" WHIDDON CATCHER SUB ON XN @ 11404' SLM 6/20/2012 ** *CONT. ON 06/21/12 WSR * ** * * *CONT. FROM 06/20/12 WSR * ** (fracturing) PULLED BK -OGLV FROM ST #3 @ 9047' SLM /9058' MD PULLED BK -LGLV FROM ST#4 @ 5821' SLM/5836' MD SET BK -DGLV IN STA#4 @ 5821' SLM/5836' MD. LOAD IA W/ 190 BBLS CRUDE W/ LRS. SET BK -DGLV IN STA #3 @ 9047' SLM /9058' MD. LRS MIT -IA TO 2500 PSI (PASSED). PULL 4 -1/2" WHIDDON CATCHER FROM 11,404' SLM (recovered piece of metal) 6/21/2012 ** *WELL TURNED OVER TO DSO * ** T /I /O= 1820/1823/40 Temp =S /I Assist slickline w/ Load & MIT -IA PASSED to 2500 psi. (Pre- frac) Pumped 5 bbls of neat meth and 190 bbls of 90* F crude to load IA. SSL set DV in station #3. Pumped 1.8 bbls of crude to reach test pressure. IA lost 79 psi. in the 1st 15 min. and 17 psi. in the 2nd 15 min. for a total loss of 96 psi.in a 30 min. test. Bled back - 6/21/2012 3 bbls to Final WHP= 2086/200/48. SSL on well at departure. • • Daily Report of Well Operations ADL0028256 CTU #9 1.75" Coil Tubing - Job Scope = Drift/Log, CIBP, Drift/Log, CIBP, Perf, Cement MIRU, RIH w/ BOT MHA, PDS memory gamma ray /ccl tools inside 2.2" carrier w/ a 2.7" drift nozzle on the bottom. Tagged the liner top at 12731' ctm. Attempted multiple ways to get through with no luck. Pumped down the coil, no luck. Started to load well and had freezing issues. Pumped down the coil up the backside to warm and load the well. turned around once the well was loaded and pumped down the backside a hole volume and attempted to get into the liner top. No luck. Stopped at 12713' ctm and logged up at 40 fpm. stopped at 12541' ctm to paint a flag on the coil. logged up at 40 fpm. stopped at 12200' ctm and flagged pipe. logged up to 11000' ctm. POOH. Downloaded tool at 7/24/2012 surface. Good gama ray but no CCL. « <Job continued on 7/25/2012 »> CTU #9 1,75" CT. Job Scope: Frac Prep RIH w/ 2.35" JSN and Memory GR /CCL. Tag liner top at 12,731'CTM. Unable to enter 3- 3/16" liner. Log memory GR /CCL up from 12,731' to 11,000'CTM at 40 fpm. Paint flags. POOH. Good log data. Tie GR /CCL into MWD ref log. Attempt to RIH w/ CIBP. POOH w/ CIBP after observing weight bobbles. Hookup to read downhole BHP /BHT. RIH w/ 2.78" CIBP drfit. Position nozzle at 11,000'CTM and perform step rate injectivity test w/ 1% KCI at 1, 3, & 5 bpm in 5 min intervals (see detail in Log). Tag at 12,727'CTM. Repaint flags. POOH. Pull up into lubricator and perform step rate injectivity test w/ 1% 7/25/2012 KCI at 1, 3, & 5 bpm in 5 min intervals (see detail in Log). CTU #9 1,75" CT. Job Scope: Frac Prep / RIH w / 3.5" baker CIBP Set 3.5" CIBP at 12675' Pressure tested plug to 3032 psi for 10 mins and lost 13 psi. 7/26/2012 Found bad spots in pipe below min starting at 9700' to 9000' from .074 to .063 for min. CTU #9 w / 1.75" ct : Job objective Perforate ./ cement squeeze. Perform BOP test «< 7/31/2012 Continue WSR on 8/1/12 »> CTU #9 w / 1.75" ct : Job objective Perforate ./ cement squeeze. Completed weekly BOP test. Tied in from CIBP and shot 2.0" 6spf guns from 12308' - 12318' corr.CTMD. Performed inj. test and squeezed LARC cement. Inj rates: static BHP= 3343psi, @1 bpm BHP= 3393psi, @2bpm BHP= 3475psi. Park coil at 12250' and line up and squeeze 55 bbls cement behind liner. Observe - 300psi increase in WHP while pumping. Well drinking while laying in cement (see log for details). 4 bbls of cement laid in. Allow cement to thicken and attempt bump up BHP 200psi. Pressure bleeds down <5 min. «< Continue 8/1/2012 WSR from 7/31/12 »> CTU #3 w/1.75" ct. Job Objective: Perforate /Cement Squeeze /Perforate. « <Job continued from 8/1/12 AWGRS »> Allow cement to thicken but could only build 30 psi squeeze pressure. Clean out from 10600 - 12666' cmtd and POOH at 80% while washing jewelry and maintaining constant BHP from downhole gage. Freeze protect from 2500'. Wait on cement to gain 500psi compressive strength. MIT -T to 1000 psi, lost 417psi in 15 min (see log for details). Begin MU Drift/GR -CCL BHA. 8/2/2012 « <Job continued on 8/3/12 WSR »> CTU #3 w/ 1.75" ct. Job Objective: Dr ft/GR- CCL /Perforate /Temp Log. « <Job continued from 8/2/12 WSR »> MU Drift/GR -CCL BHA w/2.80" JSN. Tag at 12200' cmtd. Attempt to work past. POOH to pick up motor and mill. RIH w / motor & parabolic 2.81" mill. Tagged cement © 12200' Milled to 12315' no more motor work PUH chasing sweep RBIH shut down pump at 12280' drift to CIBP @ 12675'. POOH. Injectivity test: 0.5bpm @ 1250psi and 0.65bpm @ 1480psi (see log for details). MU perforating BHA. 8/3/2012 « <Job in progress. Continued on 8/4/12 WSR »> • I Daily Report of Well Operations ADL0028256 CTU #3 w /1.75 Job Objective: Perforate/Temperature Log. «< Continued from 8/3/12 WSR »> MU Perforating BHA: 25'x2.50" 2506 PJ Omega, 6spf, 60 deg phasing, 12gm. Top shot 12550' Bottom shot 12575' POOH At surface confirmed guns fired.RIH w / sib logging tools.Run base line temp pass. Perform stop counts 12200' / 12500' & flag at 12665'. Pump 260 bbls of 80* KCI. Injectivity Test: 1 bpm @ 2057psi, 3bpm @ 2350 3.5bpm @ 2400psi. Log temp passes: baseline, 1 & 3 hr warmbacks up /down at 60fpm. Begin logging 5 hr warmback pass. 8/4/2012 « <Job in progress. Continued on 8/5/12 WSR »> CTU #9 1.75" Coil Tubing. Job Scope: Cement Squeeze (Frac Prep) MIRU, Perform weekly BOP test. RIH w/ 2.1" BDN. SBHP = 3342. RIH to 11,000'CTM. Perform injectivity test: 0.5 bpm stabilized at WHP 1500 psi, BHP 4333 psi, BHT 130 *F. 1 bpm stabilized at WHP 1950 psi, BHP 4780 psi, BHT 124 *F. Tag CIBP at 12,650'CTM. Correct to ELMD. PU 50' and flag coil (red /white). Verify field cement lab test. Continue 8/15/2012 fluid pack. « <Job in Progress »> CTU #9 1.75" Coil Tubing. Job Scope: Cement Squeeze (Frac Prep) Continue batch mixing cement. Batch mixed cement field test complete, verify within specs. Position nozzle at 12,625' ELM. Come online down CT bullheading 5 bbls FW followed by 15.8 ppg LARC cement into formation. Lay in 3.2 bbls of cement into tubing to 12,250' ELM. Down squeeze bbls 11.1 bbls of cement into formation before exceeding 2500 psi at 0.5 bpm. Lay in coil volume of cement (39.2 bbls) into tubing while maintaining >500 psi overbalance. PUH to safety at 8,300'ELM. Perform hesitation squeeze in 500 psi increments up to 5900 psi squeezing 3 additional bbls behind pipe. 14 total bbls of n dropped cement behind pipe. See Log for detail BHP data. Swapped to biozan and d opp ball, conaminated down to a tag @ 12672' reciped up, down, and chased out of hole. Stand by for cement to get compressive strength 8/16/2012 « <Job Continued on 8/17/2012 »> CTU #9 1.75" Coil Tubing. Job Scope: Cement Squeeze / Mill / Perf / Log (Frac Prep) « <Continued from 08/16/12 »> Wait for cement to reach 500 psi compressive strength. Pressure tested cement sqz to 500 psi over, lost 30 psi over 30 min. Cement sqz holding. RIH w/ 2.8" BOT Junk Milling assembly. Tagged @ 12653'CTM. Did not see any obstructions. POOH. RIH w/ 25'x 2.5" PowerJet Omega pert guns. Verify cement reached 2000 psi compressive strength. Tag CIBP at 12,653'CTM. Correct depth to 12,673.8'ELMD. Paint red /blue flag at 12,664'ELMD. PU 125' above CIBP and perforate interval 12,524- 12,549'ELMD. Begin 8/17/2012 POOH. « <Job in Progress »> CTU #9 1.75" Coil Tubing. Job Scope: Cement Squeeze / Mill / Pert / Log (Frac Prep) « <Continued from 08/17/12 >» PUH to 11,300'ELM in 4.5" tubing. Perform injectivity test w/ 50/50 meth water: 1 bpm @ 2201 psi, BHP 5095 psi. 2 bpm @ 2248 psi, BHP unavailable. 3 bpm @ 2461 psi, BHP 5208 psi. WHP builds toward max P of 2500 psi, SD pump and POOH. Injectivity meets objective. RIH w/ IPROF to flag. Stop at 11300' ctm and circ methanol out of the well. Pump 1% KCL down the backside of the coil, Perform stop counts at 12200', 12500' and 12619' ctm. Freeze protect well with 38 bbls of 50/50 methanol. Shut pump down and perform warm back passes at 0,1,3,5 hour intervals. POOH. Good data. RD. « <Job 8/18/2012 Complete »> • • Daily Report of Well Operations Y p P ADL0028256 T /I /0= 50011800/50 SI Injectivity TestJMJT IA PASSED to 4000 psi (FRAC) Lead in with 35 bbls neat meth. Pump 190 bbls 1% kcl to load. Injectivity tests at 1 bpm= 1800 -2000 psi, 3 bpm= 2200 -2400 psi, 5 bpm =2400 for total 296 bbls 1% kcl. Freeze protect tbg with 38 bbls diesel. Pump 4.2 bbls diesel down IA to MIT IAP lost 152 psi 1st 15 min, 53 psi 2nd 15 min. FWHP's= 860/500/110 Tags hung, pad op notified. SV, WV =S /I SSV, 9/1/2012 MV =O IA, OA =OTG AL =S /I T /I /O =SI Assist SLB (FRACTURING) Hold backside pressure while SLB fracs. Pumped 3.5 bbls to load IA.RDMO. FRac crew on well departure. IA closed and flagged. OA open 10/1/2012 to gauges. Operator notified of departure. SLB Frac: Job Scope: Fracture Treatment - Kuparuk C Sands: Pump breakdown, scour, data frac, and fracture treatment. NWBF from step down test = 1000 psi. Pump scour stage, and repeat step down. NWBF after scour = 600 psi. Datafrac analysis showed frac gradient = 0.67 psi /ft, ISIP = 1934 psi, Pc = 1647 psi, Tc = 16.8 min, eff = 0.52, FL = 0.0025. Pump frac at 25 bpm using YF125FIexD gel system: Pad stage of 60 Bbls, 1 PPA Flat stage in 60 bbls, ramp 1 PPA - 4 PPA in 80 bbls, ramp 4 PPA - 8 PPA in 130 bbls, pump 8 and 9 ppa flat stages in 80 bbls each, and 10 ppa flat stage in 130 bbls. Flush volumes of 61 bbls 25# XL gel, 61 bbls 25# non -XL gel, and 47 Bbls mineral oil. Seven bbls of mineral oil in surface lines, and 40 bbls in the well, placing freeze protect at 2630'. Pnet for frac = 550 psi. Pumped a total of 106,260 lbs of 20/40 Carbolite propant, of which 98,233 lbs were placed behind pipe with 5,324 lbs left in liner. Propant top estimated at 11392' (based on vertical wellbore calcs), but could be higher due to 10/1/2012 horizontal liner. ** *Job Complete * ** CTU #3 - 1.75" Coil Job Scope: FCO, contingent plug set, perf. Performed BOP test, chain inspection, and changed packoff. Begin RU. 10/4/2012 ** *Job continued on 10/5/12. * ** CTU #3 - 1.75" Coil Job Scope: FCO, contingent plug set, pert. Cut 100' of coil off. MU 2.25" BDN to reverse circulate. RIH and tag fill at 11181'. PUH to 9500' and circ out mineral oil and XL gel.Reverse circulate from 11181' to 11801'. PUH to 11000' perform MIT -T to 4000 psi looked good. PUH to 9000' pump gel pill down coil chase out of hole at 80% maintaining 700 psi at the choke. Tag at surface pump another gel sweeep and a drift ball. Unstab & recover ball at surface. MU PDS GR /CCL logging toolstring and RIH. 10/5/2012 ** *Job continued on 10/6/12 * ** CTU #3 - 1.75" Coil Job Scope: FCO, Jewelry log, perf. ** *Continued from WSR 10/5/12. * ** RIH w/ PDS GR /CCL logging toolstring. Tag down at 11804'. Log GR /CCL up at 40fpm from 11300 - 11804'. Flag pipe at 11619.3'. POOH. At surface, PDS identified the data couldn't be retrieved. Begin RU PDS logging toolstring for 2nd run. RIH w/ PDS GR /CCL logging toolstring. Log from 11300' to 11800' at 40 fpm. Flag pipe white /red at 11621.5. POOH at surface good data. RU perf guns RIH with 25' of 2506 PJO, HMX perf guns. Tie - in using PDS GR /CCL dated July 24, 2012. Shoot perfs from 11720 - 11745'. PUH to 11350' and perform injectivity test at 1, 3, and 5 bpm. (Results: 1bpm @ 1900psi, 3bpm @ 2200psi, 5bpm @ 2290psi.) Freeze protected well w/ 42bbls of 50/50 methanol. POOH. Confirmed guns fired at surface and recovered ball. RDMO. Notified grease crew and pad op that AL valve is slowly leaking by. 10/6/2012 ** *Job complete. * ** 10/14/2012 Heat frac tanks to 105* for upcoming frac job. ** *WSR continued on 10- 15 -12 * ** 10/14/2012 Heat frac tanks to 105* for upcoming frac job. 10/15/2012 ** *WSR continued from 10- 14 -12 * ** Heat frac tanks to 105* for upcoming job. 10/15/2012 Temp = S/I Assist Frac * *Job Postponed ** • • Daily Report of Well Operations ADL0028256 SLB Frac: Job Scope: Fracture Treatment - Kuparuk C Sands: Pump breakdown, scour, data frac, and fracture treatment. After break down decision was made to pump scour stage. NWBF after scour = 350 psi. Datafrac analysis showed frac gradient = 0.68 psi /ft, ISIP = 1785 psi, Pc = 1642 psi, Tc = 36.8 min, eff = 0.65, FL = 0.001 Pump frac at 25 bpm using YF125FIexD gel system: Pad stage of 40 bbls, 1 PPA Flat stage in 80 bbls, ramp 1 PPA - 4 PPA in 80 bbls, ramp 4 PPA - 8 PPA in 130 bbls, pump 8 and 9 ppa flat stages in 80 bbls each, and 10 ppa flat stage in 103 bbls. Flush volumes of 58 bbls 25# XL gel, 58 bbls 25# linear gel, and 46 bbls LVT -200 mineral oil. Seven bbls of mineral oil in surface lines, and 48 bbls in the well, placing freeze protect at 3154'. Pnet for frac = 320 psi. Pumped a total of 104,756 lbs of 20/40 Carbolite propant, of which 102,854 lbs were placed behind pipe with 120 lbs in 4 1/2 tubing and 1782 lbs left in 3 1/2" liner. Propant top estimated at 11422 ' (based on vertical wellbore calcs), but could be higher due to 10/16/2012 horizontal liner. ** *Job Complete* ** CT -8 1 3/4" Cont'd from 10 -17 -12 WSR Scope of Work: Post frac fill clean out. CT Tractor broken down, waiting on repairs. Dolly onto spare tractor. MIRU. Pumped 1.25" ball thru reel, had large pieces of Gaggregate in nozzle at end of last job. Recovered ball. MU 1.75" BDN w/ 1/2" ball on seat, BHA OAL 8.94'. RIH 10/18/2012 « <IN PROGRESS »> CT -8 1 3/4" Cont'd from 10 -18 -12 WSR Scope of Work: Post frac fill clean out. Cont. RIH w /wash noz assembly. Tagged TOF @ 11027' CTD. Circ'd out well bore. Washing prop from 11027'. Clean out to 11675' with 10 bbl power vis sweeps. Circ bottoms up. Inspect pipe damage. Close pipe and slip rams. Bleed down above pipe rams. Push /pull 10k over neutral wt. Perform chain inspection. Clean gripper blocks & inspect. Prep to POOH for further inspection. PU to pipe marks inspect/paint not bad. Hot water plant still down. 10/19/2012 «< Job in progress. »> CT -8 1 3/4" Cont'd from 10 -19 -12 WSR Scope of Work: Post frac fill clean out. Cont. POOH after gripper block C/O & inspection. Work on G- blocks on back deck. RIH w/ same 1.95" BDN w/ 1/2" ball on seat. Dry tag fill @ 11763'. Re -start FCO from 11675' w/ 10 bbl power vis sweeps. 10/20/2012 «<JOB IN PROGRESS »> CT -8 1 3/4" Cont'd from 10 -20 -12 WSR Scope of Work: Post frac fill clean out. Cont. POOH chasing out Gel sweeps. FP CT & well to 2500' w/ 50/50 meth. Well C/O to 12669' CTD. Well appeared to be flowing -.5 BPM 40 psi choke FO. Short flow due to possible loss of FP in tbg. 10/21/2012 « «JOB COMPLETE »> ASRC Test Unit1 Inlet Well S -102 Outlet Well S -200 10/21/2012 ** *RIG UP * ** Continue on WSR 10- 22 -12 * ** CT -8 1 3/4" Cont'd from 10 -20 -12 WSR Scope of Work: Post frac fill clean out. Cont. POOH chasing out Gel sweeps. FP CT & well to 2500' w/ 50/50 meth. Well C/O to 12669' CTD. Well appeared to be flowing -.5 BPM 40 psi choke FO. Short flow due to possible loss of FP in tbg. 10/21 /2012 « «JOB COMPLETE »> • • Daily Report of Well Operations ADL0028256 T /I /0= 675/1550/0 temp =S /I Assist SL w/ Hydrate Thaw Pumped 4.5 bbls neat meth down TBG. TBG pressured up to 2900 psi. Monitored pressure 20 min. TBGP fell from 2900 psi to 2732 psi. SL RIH to tag ice. Pumped up Tbg to 2500 w/ 10* neat while SLine pounded on ice. Pressured up Tbg to 3000 psi and hold for 15 mins. Bled pressure Tbg pressure to 500 psi. Bumped up Tbg pressure to 3000 psi and held for 15 mins. Bled Tbg 10/22/2012 to 500 psi. SLine in control of well per LRS departure. FWHP's= 500/1600/0 CV's =OTG ASRC Test Unit1 ** *Continue from WSR 10- 21 -12 * ** Inlet Well S -102 Outlet Well S -200 10/22/2012 ** *RIG UP * ** Continue on WSR 10- 23 -12 * ** ***WELL SHUT IN PRIOR TO ARRIVAL*** STAND BY FOR REMOVAL OF FLOW BACK SUB RAN INTO ICE PLUG W/4 1/2" WHIDDEN CATCHER SUB @ 1435'SLM RAN 3" SAMPLE BAILER TO 1506'SLM - RECOVERED ICE AND HYDRATES LRS PUMPED 4.5 BBLS OF METHANOL & TBG LOCKED UP TO 2800# RAN 2.25" CENT. & 1 -3/4" S. BAILER TO 1,582' SLM & PUSHED ICE PLUG TO 2,347' SLM LRS PRESSURED UP TO 3000# ON TBG TO ATTEMPT TO PUSH DOWN ICE PLUG ** *NOTE: ICE PLUG IN HOLE AT 2,347' SLM * ** ** *WELL LEFT SHUT -IN ON DEPARTURE, PAD OP NOTIFIED * ** 10/22/2012 ASRC Test Unit1 ** *Continue from WSR 1 22 -12 * ** Inlet Well S -102 Outlet Well S -200. P /T, S/B for generic gaslift design. ** *Continue on 10/23/2012 WSR 10- 24 -12 * ** Cl U #9 w/1.75" ct. Job Objective: I haw Ice /Hydrate Plug. 10/23/2012 MU Ice thaw BHA w/ 2.25" down jet nozzle. CTU #9 w/1.75" ct. Job Objective: Thaw Ice /Hydrate Plug. MU Ice thaw BHA w/ 2.25" down jet nozzle. Ran in hole to 8000' circulated 60/40 methanol 10/23/2012 @ 80% pulling OOH. RDMO «< Job complete »> T /I /0= 600/467/23. Assist SSL w/ Hydrate thaw (Fracturing) Pumped 6.7 bbls meth down Tbg to hold pressure above obstruction in attempt to clear Tbg with SSL. ** *WSR 10/24/2012 Continued * ** ASRC Test Unit1 * ** Continue from WSR 10 -23 -12 * ** Inlet Well S -102 Outlet Well S -200. S/B for eneric gaslift design. desi 9 9 9 10/24/2012 DRIL Complete ** *Continue on WSR 10- 25 -12 * ** ** *WSR Continued * ** Assist slickline with Tbg plug (Fracturing) Pumped 11 bbls neat methanol down tbg to pressure up to 1500 psi, while SSL worked baler. (See Log) SSL 10/25/2012 still in control of well on LRS departure. FWHP= 1340/694/21 ASRC Test Unit1 ** *Continue from WSR 10- 24 -12 * ** Inlet Well S -102 Outlet Well S -200. S/B for generic gaslift design, Rig up, PT. ** *Continue 10/25/2012 on WSR 10- 26 -12 * ** ASRC Test Unit1 ** *Continue from WSR 10- 25 -12 * ** Inlet Well S -102 Outlet Well S -200. Rig up, PT. Flow Well, S/B for CTU ** *Continue on 10/26/2012 WSR 10- 27 -12 * ** ASRC Test Unit1 ** *Continue from WSR 10- 26 -12 * ** 10/27/2012 Inlet Well S -102 Outlet Well S -200. S/B for CTU ** *Continue on WSR 10- 28 -12 * ** 10/28/2012 CTU #9 w/1.75" ct. Job Objective: N2 lift. MIRU «< Job in progress »> ASRC Test Unit1 ** *Continue from WSR 10- 27 -12 * ** 10/28/2012 Inlet Well S -102 Outlet Well S -200. S/B for CTU ** *Continue on WSR 10- 29 -12 * ** s I Daily Report of Well Operations ADL0028256 ASRC Test Unit1 ** *Continue from WSR 10- 28 -12 * ** 10/29/2012 Inlet Well S -102 Outlet Well S -200. Assist CTU ** *Continue on WSR 10- 30 -12 * ** CTU #9 w/1.75" CT. Job Objective: N2 lift. MIRU. RIH w/ 2" JSN maintaining a N2 rate of 300 scfm. Park nozzle at 1000'CTM, unload liquid from tubulars to nozzle. BHP drops from 2900 to 2600 psi. RIH at 30 fpm to 2000'CTM, park CT and unload liquid. BHP drops from 2600 to 2300 psi. Increase rate to 10/29/2012 400 scfm. RIH at 30 fpm to 3000'CTM, park, and unload. « <In Progress »> CTU #9 w/1.75" CT. Job Objective: N2 lift. « <Continued from 10/29/12 WSR »> RIH at 30 fpm to 3018'CTM, park, and unload tubulars at 400 scfm. BHP drops to 2120 psi. RIH to 4000'CTM, park, and unload liquid. Lose BHP data transmission. Circ P stabilizes. RIH to 5000'CTM, park, unload liquid. Increase rate to 500 scfm. Circ P stabilized. RIH to 6000'CTM, park, unload liquid. RIH to 7000'CTM at 30 fpm, park, and unload. Went 8500' while pumping N2 the well quit giving up fluid, Shut N2 pump down bled coil down and dry tagged @ 11000'. PUH and retag 100' shallower at 10,900'CTM. PUH and ordered PowerVis for FCO. Performed nitrified cleanout from 10,900'CTM 10/30/2012 through top set of perfs at 11,720'- 11,745'ELM. Well has inflow. « <In Progress »> ASRC Test Unit1 ** *Continue from WSR 10- 29 -12 * ** 10/30/2012 Inlet Well S -102 Outlet Well S -200. Assist CTU ** *Continue on WSR 10- 31 -12 * ** CTU #9 w/1.75" CT. Job Objective: N2 lift. RIH at 30 fpm to 3018'CTM, park, and unload tubulars at 400 scfm. BHP drops to 2120 psi. RIH to 4000'CTM, park, and unload liquid. Lose BHP data transmission. Circ P stabilizes. RIH to 5000'CTM, park, unload liquid. Increase rate to 500 scfm. Circ P stabilized. RIH to 6000'CTM, park, unload liquid. RIH to 7000'CTM at 30 fpm, park, and unload. Perform FCO Recip across gas lift stations w / powervis. Freeze protect well 10/31/2012 from 2900' 2500'TVD w / 45 bbls Methanol. RDMO ** *WELL SHU 1 IN ON ARRIVAL * ** (fracturing) RAN WHIDDON C -SUB, S.D @ 5749' SLM, WORKED TOOLS TO 5756' SLM (FRAC SAND IN GS) 10/31/2012 ** *JOB CONTINUED ON 11/1/12 WSR * ** ASRC Test Unit1 ** *Continue from WSR 10- 30 -12 * ** 10/31/2012 Inlet Well S -102 Outlet Well S -200. S/B for Slick Line ** *Continue on WSR 11- 01 -12 * ** CTU #9 1.75" Coil Tubing Wait for well to stabilize before leaving location. Well flowing. 11/1/2012 « <Job complete »> ASRC Test Unit1 ** *Continue from WSR 10- 31 -12 * ** Inlet Well S -102 Outlet Well S -200. S/B for Slick Line to set GLV's POP Well 11/1/2012 ** *Continue on WSR 11- 02 -12 * ** ASRC Test Unit1 ** *Continue from WSR 11- 01 -12 * ** Inlet Well S -102 Outlet Well S -200. S/B for Slick Line to set GLV's POP Well, flow well to production. 11/2/2012 ** *Continue on WSR 11- 03 -12 * ** • • Daily Report of Well Operations ADL0028256 ASRC Test Unit1 ** *Continue from WSR 11- 02 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to flow well to production. 11/3/2012 ** *Continue on WSR 11- 04 -12 * ** ASRC Test Unit1 ** *Continue from WSR 11- 03 -12 * ** Inlet Well S -102 Outlet Well S -200. Continuued to flow well to production. Well died off. S/I S -102. SB for Slickline to install GLV's. 11/4/2012 ** *Continue on WSR 11- 05 -12 * ** * ** *WELL SHUT IN ON ARRIVAL * * ** (fracturing) RIG UP SLICKLINE SWCP UNIT # 10 ASRC PUMPING ATTEMPT TO FREEZE PROTECT TUBING W/ 60/40 11/4/2012 * ** *JOB CON'T ON 11/5/12 * * ** * ** *JOB CON'T 11/4/12 * ** *(fracturing) SET WHIDDON CATCHER SUB @ 11,000' SLM PULLED STA #3 BK -DGLV © 5810' SLM /5830' MD & STA #4 BK -DGLV © 9028' SLM /9052' MD SET STA #3 BK -LGLV @ 5810' SLM /5830' MD 11/5/2012 * ** *JOB CON'T ON 11/6/12 * * ** ASRC Test Unit1 ** *Continue from WSR 11- 04 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to SB for Slickline to install GLV's and AL. 11/5/2012 ** *Continue on WSR 11- 06 -12 * ** ASRC Test Unit1 ** *Continue from WSR 11- 05 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to SB for Slickline to install GLV's and AL. 11/6/2012 ** *Continue on WSR 11- 07 -12 * ** * ** *JOB CON'T FROM 11 /5 /12 * * * *(fractunng) MADE MULTIPLE ATTEMPTS TO SET BK -OGLV IN STA #3 @ 9052' MD. SET STA #3 BK -OGLV @ 9032' SLM /9052' MD 11/6/2012 * ** *JOB CON'T ON 11/7/12 * * ** ASRC Test Unit1 ** *Continue from WSR 11- 06 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to SB for Slickline to install GLV's and AL. Bring well on. 11/7/2012 ** *Continue on WSR 11- 08 -12 * ** * ** *JOB CON'T FROM 11 /6 /12 * * * *(fracturing)(gly do) PULLED 4 1/2" WHIDDON CATCHER SUB @ 11,000' SLM * ** *WELL LEFT S/I & PAD -OP NOTIFIED UPON DEPARTURE * * ** 11/7/2012 * *NOTE:WELL TESTING UNIT # 1 IN CONTROL OF WELL AT TIME OF DEPARTURE ** ASRC Test Unit1 ** *Continue from WSR 11- 07 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to Bring well on. SB for gas lift on pad. Continue bring on well. 11/8/2012 ** *Continue on WSR 11- 09 -12 * ** ASRC Test Unit1 ** *Continue from WSR 11- 07 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to Bring well on. SB for gas lift on pad. Continue bring on well. 11/8/2012 ** *Continue on WSR 11- 09 -12 * ** ASRC Test Unit1 ** *Continue from WSR 11- 08 -12 * ** Inlet Well S -102 Outlet Well S -200. Continue to Bring well on. FOC. Stabilize for test. 11/9/2012 ** *Continue on WSR 11- 10 -12 * ** • • Daily Report of Well Operations ADL0028256 ASRC Test Unit1 ** *Continue from WSR 11- 09 -12 * ** Inlet Well S -102 Outlet Well S -200. FOC. Stabilize for test. 3 hr purge and 8 hr piggyback Test w/ WPS. 11/10/2012 ** *Continue on WSR 11- 11 -12 * ** ASRC TEST Unit #1. Post Frac Flowback and Test. Inlet well S -102. Outlet well 5-200. ** *Continued from WSR 11/10/12 * ** 11/11/2012 Continued RD. Travel to Peak wash bay for vessel clean out. ** *Job complete @ 23:59 * ** TREE= 4 -1/16" CJW WHIHEAD = MC SAFETY I�f ES: WELL ANGLE > 70° @ 12972' *** CHROME S-102 TBG "** CAUTION: 2 SWS RADIOACTIVE SOURCES P&A'd ACTUATOR= ' " 10!04100 WI RED CMT TO PB 8017' MD /4655' TVD. 1)8564' Ks. t3EV = 64 2' L1 MD/4882' TVD -2.0 CURIE CS -137. 2) 8531' MD /486T TVD -4.0 BE ELEV = I CURIE AM - 241** DO NOT RE -ENTER WELL BELOW PB DEPTH KOP= 1400' BEFORE CALLING U.S. NUCLEAR REG COMMISSION & AK Max Angle = 93° @ 12497' 20" CONDUCTOR, 109' DEPT OF O&G "" Datum MD= 11724' 91.5#, 1-1-40, DMum 1VD = 6700' SS D = '19.124' 1 2206' -14-1/2" I-ES X MP, D = 3.813" 110 -3/4" TAM PORT COLLAR H 987 GAS LIFT MANDRELS Jr PORT COLLAR 2185' 1 H ST-M-01 TVD DEV _ TYPE VLV LATCH PORT DATE 4 5830 3740 67 KBG -4.5 DMY BK 0 06/21/12 1 10 -3/4" CSG, 45.5#, K- 55 -BTC, D = 9.95" 4816' 3 9052 5247 53 KBG -4-5 DMY BK 0 06/21/12 1 7" PORT DOLLAR H 6992' 2 10429 6084 54 KBG -4-5 DMY BK 0 10/27/11 1 11136 6505 53 KBG -4-5 DMY , BK 0 10/27/11 14-1/2" NDPG -C GAUGE MANDREL, D = 3.958" H 11212' 11287' - 1H4- 1/2"HESX P1 D =3.813' 1 Minimum ID = 2.377" @ 13272' . 3-3/16" X 2 -7/8" XO gi4 11316' -17" X 41/2' WS TNT PKR, D = 3.856" 11351' 1 14-1/2" HES X NP, D = 3.813" 41/2" 7BG, 12.6#, 13CR -85 VAM TOP, --1 11447' 1 11421' -14-1/2" I-ES XN NP, D = 3.725° 0152 bpf, D = 3.958" 11446' - 1 . 4-1/2" X 3-1/2" XO, BD= 2.972" 14-1/2" TBG STUB (09/20/11) H 11520' O M ∎ M I 11524' --17" X 41/2" BKR S-3 PKR, D = 3.875" 11543' H7.40' TIEBACK SLV, D = 525" 1 TOP OF 4-1/2" LN2 H 11543' 11547" 4112" HES X NP D = 3.813" 4-1/2" TBG, 12.6#, L-80 ET, -1 11558 11550' --17' 5' BKR LIP, D = 4.406" 0152 bpf, D = 3.958" i 11557' H7" X 4-1/2" BKR HMC HGR, D = 3.938" 1 11559' H4-1/2" WLEG, D = 4.00' 1 7" CSG, 29#, L- 80 -BTC-M( H 11717' I 11553' H ELMD TT LOGGED 12/12/00 I .0371 bpf, D = 6.182" I 3 1/2" TBG, 9.3#,13CR -80 STL -{ 12690' 122 H � TY FE H CEMENTER, MLLED TO 3.80" (1018/03) 0087 bpf, D = 2.972" 0 B 1226T --141 /2"BKR CTC EXTERNAL PKR, D = 3.875" 4-1/2° WHIPSTOCK (10/26/03) -1 12827' a� ■ w/ RA TAG @ 12836' r j 12676' H3-1/2^ BKR CBP (07/25/12) I 4-112" SLID LhFi, 12.6#, L -80 BT, 13100' ►��� �Q 12720' --13 -112" HALF MULESHOE, D = 3.00" 1 .0152 bpf, 0= 3.958" ► fi t ♦ t �4 4 . , 4 ! 12737' -13-1/2" BKR DEPLOY SLV, 0= 3.00" 1 PERFORATION SUMMARY . i 12740' 1 3.112" x 3 -3116" XO, D = 2.786" 1 REF LOG: PDS JEWELRY LOG ON 12111/00 .ii� i ANGLE AT TOP PEW: 73" © 11660' ' Nonseii,� L.--- t MLLOUT WINDOW (S - 102L1) 12827' - 12833' Note: Refer to Production DB for historical pert data \ a '!' '/ SIZE SPF NTERVAL (OprdSgz DATE - 1. � / I I 13272' - -3116" X 2 -7/8 X0, D= 2.377" SEE PAGE 2 FOR R32FORATION DATA � . 1' I I I I Ier J 14430' H2 WFD CBP (12 -22o6) 13 -3/16" LM , 6.2#, L -80 T, .0076 bpf D= 2.805" H 13272' l � 1 ? ? -FISH - KO TOOL SPRNGS 11/19/03 1 TO, 1 PBTD 1H 14935' 1 ? ? --13 BP ELEMENTS (03/14/04 2 -7/8" LNR, 6.16#, L -80 STL, .0058 bpf, D= 2.441" 14968' ►' 1 14980' - TD DATE REV BY COM ENTS DATE REV BY COM4134TS AURORA UNIT 10/24/00 COMPLETION 08/08/12 .11/ PJC SET PLUG (07126/12) WELL: S -102 L1 11/05/03 TMNITLP CTD SIDETRACK (L1) 08/09/12 LLY PJC CMT SQZ/ PERF (08/07/12) PERK Nb: 2001290 , 2031560 10131/11 0-16 RWO 08/23/12 JJUJMD CMT SOZJ PERE (08/16- 17/12) AR No: 50 -029- 22972 -00, (60) 11/13/11 PJC DRLG DRAFT CORRECTIONS 10/24 /12 TTR/JMD ADPERF (10/06/12) SEC 35, T12N, R12E, 828' FN- & 781' FWL 01/12/12 DB/PJC FINAL DRLG CORRECTIONS _ Bp Exploration (Alaska) 06/22/12 LEGPJC GLV GO (06/21/12) • • S -102 L1 1 � 1 -4 S PBRFORA1ION SUMMARY REF LOG: PDS JEYELRY LOG ON 12/11/00 ANGLE AT TOP PERF: 73° @ 11660' 1 Note: Refer to Production DB for historical pert data 11 SIZE SPF NYTBVAL Opn/Sgz SHOT SQZ 5-102 2 -7/8° 6 11660- 11680 0 08/11/11 3-3/8" 6 11680 - 11700 0 01/21/01 2 -7/8" 6 11690 -11710 0 12/22/06 3-3/8" 6 11716 - 11736 0 01/21/01 4 • 2 -1/2° 6 11720 - 11745 0 10/06/12 2" 6 12308 - 12318 S 08/01/12 08/02/12 • • 2 -1/2" 6 12524 - 12549 0 08/17/12 2" 6 12550 - 12575 S 08/04/12 08/16/12 S -102L1 ► asi 2 -7/8" SLID 13284 - 14384 0 11/02/03 ►� r ( 2 -7/8" SLID 14475 - 14935 C 11/02/03 — 4 ►♦ a. lemur Bpi♦ F, I I I DATE REV BY COMBOS DATE REV BY COMMITS AURORA UNIT 10/24/00 COMPLETION 08/08/12 JJU PJC SET PLUG (07/26/12) WELL: S -102 L1 11/05/03 TMNITLP CTD SIDETRACK (11) 08/09/12 LLV PJC CMT SQZ/ PERF (08/07 /12) PERMIT No: 2001290 , 2031560 10/31111 D-16 RWO 08/23/12 JJL/JM) CMT S07/ PEFF (08/16 - 17/12) API No: 50- 029- 22972 -00, (60) 11/13/11 PJC DRLG DRAFT CORRECTIONS 10/24/12 TTRJJM) ADPERF (10/06112) SEC 35, T12N, R12E, 828' FM,.. & 781' FINE 01/12/12 DB/PJC F1t4AL DRLG CORRECTIONS 06/22/12 LECJPJC GLV 00 (06/21/12) BP Exploration (Alaska) DATE: 5-Nov-12 Stephanie Pacillo TRANS#: 6192 Data Delivery Services Technician ,.. k a na K Bender Schlumberger Oilfield Services -1. --zi Natural Resources Technician II WIRELINE -'-') Alaska Oil & Gas Conservation C01 a, Alaska 2525 Gambell St, Ste. 400 -- -');,G.; Vc,• ..---- Avo, Sulte IOC Ancherac;c: Anchorage, AK 99503 lit: Office: (907) 273-1770 k4011; ,,' : - - SERVId ' OH RESERV CNL MECH. LOG DESCRIPTION •- NAME ORDER # . MST. 1* POST _ ijIST , :LOPLGED- PRINTS PRINTS 15-30B BCRC-00208 X MEMORY PPROF 05-SEP-202 1 1 CD S-102 C5XI-00029 X MEMORY IPROF 18-Aug-12 1 1 CD • MPE-23 C600-00055 X MEMORY IPROF 7-Oct-12 1 1 CD MPL-15 C600-00035 X MEMORY IPROF 9-Aug-12 1 1 CD MPC-05A AMPSURVEEL X SCMT 1-Oct-12 1 1 CD 01-02 CBTY-00004 X LEAK DETECTION LOG 5-Oct-12 1 1 CD G-08A CBAF-00009 X LEAK DETECTION LOG 27-Sep-12 1 1 CD 09-05A APBNRWOSEL X FLOSCAN IMAGER 16-Oct-12 1 1 CD W-15A BZ2J-00023 X . MEMORY GAS LIFT SURVEY 10-Aug-12 1 1 CD MPI-18 BCRC-00204 X MEMORY IPROF 30-Aug-12 1 1 CD 13-05 CBAF-00008 X LEAK DETECTION LOG 23-Sep-12 1 1 CD 13-08A BBSK-00139 X LEAK DETECTION LOG 26-Sep-12 1 1 CD V-225 BSM4-00035 X IPROF RST W/ WFL 26-Aug-12 1 1 CD I • Please return a sign -d copy to: Please return a signed copy to: BP PDC LR2-1 0 % M3 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd SCP R Anchorage AK 99503 N Anchorage AK 99508 ' , - „ ,- 8 :_, . . . • 3 _D‘ ..... .•s■ ■ • - .._„..1.. ' . DATE: 28- Sep -12 Stephanie Pacillo TRANS #: 6067 Data Delivery Services Technician - z / Makana K Bender Schlumherger Oilfield Services -. \ *'i Natural Resources Technician If WIRELINE Alaska Oil & Gas Conservation Conr"us ,tor 2525Garnbel9 St, Ste. 400 .: a 3 71 . r: :, Su ITC: I ( lcA r',C1 "v.,! -Sno F.i: - c Anchorage, AK 99503 W: Office: (907) 273 -1770 :t, li . R IC ,::, OH ; :' E . V CN - MEci - , LPG - DESCRIPTION ' DATE ' : B /W COLOR BCD ; NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS R -01 BCRC -00203 X MEMORY LEAK DETECTION 9- Aug -12 1 1 CD V -122 BINC -00101 X DRIFT SURVEY 25- May -12 1 1 CD III MPB -05A C600 -00037 X MEMORY IPROF 11- Aug -12 1 1 CD G -10C C600 -00029 X PPROF / IPROF w CNL -BORAX 17- Jul -12 1 1 CD ` K -10C BAUJ -00138 X MEMORY PPROF w GHOST 29- Jun -12 1 1 CD S -102 COT4 -00047 X MEMORY TEMPERATURE LOG 4- Aug -12 1 1 CD 1- 35/0 -25 BG4H -00114 X XFLOW CHECK 20- Feb -12 1 1 CD 15 -05B C600 -00038 X MEMORY PPROF 16- Aug -12 1 1 CD 15 -34A BG4H -00129 X XFLOW CHECK w IBP RECORD 13- Aug -12 1 1 CD B -05C C5XI -00023 X MEMORY CEMENT BOND LOG 09 -AUG -212 1 1 CD M -23 BBSK -00133 X CROSSFLOW LOG 17- Aug -12 1 1 CD A -28 C4W7 -00011 X PPROF 4- May -12 1 1 CD C-42A C1UB -00024 X SLIM CEMENT MAPPING TOOL 4- Aug -12 1 1 CD H -36A C5XI -00024 X MEMORY PPROF GHOST 9- Aug -12 1 1 CD 2- 58/S -09 BZ81 -00034 X LEAK DETECTION LOG 15- Aug -12 1 1 CD W -211 BZ81 -00032 X PPROF W GHOST DEFT 12- Aug -12 1 1 CD • X X Please return a signed copy to: ��p� N� APR 2��3 Please return a signed copy to: BP PDC LR2 -1 SCANNED DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 f TATE OF ALASKA ALASKA OIL ANff CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory - 200 - 129 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 - 029 - 22972 - 00 - 00 7. Property Designation: ,,4'I1^ t) I to- 8. Well Name and Number: ADL 028257&13282.5.7 „Z 8,j 6, - PBU S -102 9. Field / Pool(s): Prudhoe Bay Field / Aurora Pool 10. Present well condition summary Total depth: measured 13488' feet Plugs (measured) 12827' feet true vertical 6787' feet Junk (measured) None feet Effective depth: measured 13100' feet Packer: (measured) 11316' & 11524' feet true vertical 6749' feet Packer: (true vertical) 6611' & 6701' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 109' 109' 1490 470 Surface 4789' 10 -3/4" 4816' 3314' 3580 2090 Intermediate 11693' 7" 11719' 6763' 8160 7020 Production Liner 1557' 4 -1/2" 11543' - 13100' 6708' - 6749' 8430 7500 Add Perforation Depth MD Depth 11660' - 11680' Perforation Depth: Measured Depth: Slotted Section: 12312' - 13099' True Vertical Depth: 6746' - 6752' & 6764' - 6749' . Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# x 3-1/2", 9.3# 13Cr85 / 13Cr80 1 2720' 6750' & 4 -1/2 ", 12.6# & L -80 1 - 11559' 6700' - 6714' Packers and SSSV (type, measured and true vertical depth): 7" x 4 - 1/2" HES 'TNT' packer 11316' 6611' 7" x 4 -1/2" Baker 'S -3' packer 11524' 6701' 11. Stimulation or cement squeeze summary: ����� Intervals treated (measured): Treatment description including volumes used and final pressure: DR' 0 I. Air Aska Oil & Gas Cons. Commission A CChj � 0 � V 12. Representative Daily Average Production or Injection a Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory - Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ •"' =∎ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564 -5683 N/A Printed Name Terrie Hubble Title Drilling Technologist 1 Prepared By Name /Number: Signatur / `f`- 0 / Phone 564 - 4628 Date 12/01 hi Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 V` + • DMS DEC 0 2 ZO a.L.i / ?/,, / S ubmit Original Only • • North America - ALASKA - BP 'z,, Page 1 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/16/2011 18:00 - 00:00 6.00 RIGD P PRE RIG DOWN LOCATION AND PREP TO DERRICK DOWN AND PULL OFF WELL S -102 LOCATION IS NOT READY FOR RIG HIGH WINDS SO WE ARE WAITING TO DERRICK DOWN AS THERE IS NO NEED AT THIS TIME 10/17/2011 00:00 - 04:00 4.00 MOB P PRE WAIT ON PAD PREP OF S -102, CONTINUE TO R/D AND PREP TO MOVE 04:00 - 04:30 0.50 MOB P PRE HIGH WINDS HAVE DIED DOWN LAY DERRICK OVER AND SECURE ON DERRICK STAND 04:30 - 08:30 4.00 MOB P PRE CONTINUE R/D LOCATION AND PREP TO MOVE OFF S-09i - PERFORM WORK ORDERS 08:30 - 10:00 1.50 MOB P PRE MOVE RIG OFF WELL S -09i AND SPOT ON PAD AND STAND DOWN 09:15 TOWN ENGINEER SEAN MCLAUGHLIN CALLED TO NOTIFY US TO STAND DOWN OPERATIONS UNTIL FURTHER NOTICE DUE TO NORDIC 1 INCIDENT 10:00 - 11:00 1.00 MOB N WAIT PRE SAFETY MEETING / ROUND TABLE DISCUSSION WITH NIGHT CREW 11:00 - 12:00 1.00 MOB P PRE SAFETY MEETING / ROUND TABLE DISCUSSION WITH DAY CREW 12:00 - 14:00 2.00 MOB P PRE FIELD SAFETY SHUT DOWN - CONTINUE TO CLEAN RIG AND WORK ON WORK ORDERS 14:00 - 15:00 1.00 MOB P PRE PJSM REMOVE BOP FROM CELLAR AND INSTALL ON BOP MOBILE CRADLE 15:00 - 16:00 1.00 MOB P PRE PJSM INSTALL REAR BOOSTERS 16:00 - 00:00 8.00 MOB P PRE FIELD SAFETY SHUT DOWN CONT. WORK ORDERS AND CLEANING 10/18/2011 00:00 - 06:00 6.00 MOB PRE SAFETY STAND DOWN FOR NORDIC 1 INCIDENT, WAIT ON CLEARANCE TO MOVE RIG, RIG MAINTENANCE AND CLEANING 06:00 - 12:00 6.00 MOB PRE SAFETY STAND DOWN, WAIT ON CLEARANCE TO MOVE RIG, WORK ORDERS AND GENERAL RIG MAINTENANCE "UNINTERRUPTED POWER SUPPLY" QUADCO SYSTEM INSTALLED. 12:00 - 00:00 12.00 MOB PRE CONTINUE TO STAND DOWN - HARDLINE INSPECTION BY SCS AND RIG CREW OF RETURNED HARDLINE POST RE- CERTIFICATION - GENERAL HOUSEKEEPING AROUND RIG - PLYWOOD AND HERCULITE INSTALLED IN CELLAR OF S -102 10/19/2011 00:00 - 06:00 6.00 MOB PRE SAFETY STAND DOWN FOR NORDIC 1 INCIDENT, WAIT ON CLEARANCE TO MOVE RIG. - CONTINUE MINOR MAINTENANCE WHILE WAITING ON ORDERS Printed 11/14/2011 1:58:56PM North ,erica - ALASKA - BP Page 2 of 15 • Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 12:00 6.00 MOB PRE COMPLETE ALL WORK ORDERS DUE IN SYSTEM EXCEPT THOSE REQUIRING THE DERRICK TO BE UP. 12:00 - 00:00 12.00 MOB PRE CONTINUE TO STAND DOWN - GENERAL HOUSEKEEPING AROUND RIG 10/20/2011 00:00 - 10:00 10.00 MOB N WAIT PRE SAFETY STAND DOWN FOR NORDIC 1 INCIDENT, WAIT ON CLEARANCE TO MOVE RIG. - CONTINUE MINOR MAINTENANCE WHILE WAITING ON ORDERS 24 HOUR NOTICE TO AOGCC FOR INITIAL BOP TEST -BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS AT 08:15 10:00 - 11:00 1.00 MOB P PRE RECEIVED OK TO PROCEED WITH RIG MOVE ON S -PAD, FROM SOUTH PAD TO NORTH PAD. -CALL OUT DOYON DRILLING SUPT -PREP MOVING SYSTEM FOR MOVE. -1/2 TO 3/4 OF A GALLON MOP WATER LEAKED ON TO THE PAD. ALL NOTIFICATIONS MADE. CLASSIFIED AS A NON - EVENT. 11:00 - 12:00 1.00 MOB P PRE CREW CHANGE -PJSM ON RIG MOVE. ALSO HELD RISK ASSESSMENT MEETING ON SOP (DRILLING / WORKOVER SURFACE CLOSE PROXIMITY) -WITH ADW HSE REP, PAD OPERATOR, 2 BP WSL'S, TOOLPUSHER AND DRILLER. - DISCUSSED: 'WELLS INSIDE THE RIG FOOT PRINT" AND "BACK OVER WELLS ". - ACTION ITEMS: -1) PAD OPERATOR TO REPOSITION THE IA VALVE GAUGE FOR MORE CLEARANCE. -2) ORDER LIGHT STAND FOR SPOTTING OVER IN THE DARK. -3) TEST MOVING SYSTEM ESD PRIOR TO BACKING OVER. -4) REQUIRES TOOLPUSHER / TOURPUSHER AND WSL PRESENT. -5) ESD IS REQUIRED AT DRILLER STATION IF A WELL IS PLACED IN SERVICE. 12:00 - 16:00 4.00 MOB P PRE MOVE OFF SOUTH S -PAD -14:00 HRS AT THE 'Y' AND BACK DOWN TO SHORT PAD. -15:00 FIRS MAKE 'R' TURN ON TO RESERVE PIT ROAD. -15:30 HRS MAKE SECOND 'R' TURN ON RESERVE PIT ROAD. -16:00 HRS ON NORTH S -PAD. 16:00 - 17:30 1.50 MOB P PRE PJSM - REMOVE FRONT AND REAR BOOSTER WHEELS. 17:30 - 18:30 1.00 MOB P PRE INSTALL BOPS IN CELLAR - CALLIBRATE GAS DETECTORS - FUNTION TEST ESD SWITCH Printed 11/14/2011 1:58:56PM North iprica - ALASKA - BP z Page 3 of 15 Operation Summary Report , Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 20:30 2.00 MOB P PRE SPOT OVER S -102 - ADJUST CELLAR DOORS FOR 15' WELL SPACING AND EQUIMENT ON ADJACENT WELLS -TP AND BP WSLS PRESENT 20:30 - 22:30 2.00 RIGU P PRE SHIM RIG -IA PRESSURE = 0 PSI -SPOT CUTTING BOX, MUD #2 MODULE AND MOTOR MODULE. 22:30 - 00:00 1.50 RIGU P PRE PJSM -RAISE DERRICK -RIG UP RIG FLOOR 10/21/2011 00:00 - 02:00 2.00 RIGU P PRE CONTINUE TO RIG UP RIG FLOOR AND MUD MANIFOLD EQUIPMENT - BRIDLE DOWN 02:00 - 02:30 0.50 RIGU P PRE H2S /RIG EVAC DRILL -HELD AAR WITH CREW AND WSLS -AAR FINDINGS: PERSONAL H2S MONITORS NEEDED FOR LOADER OPERATOR AND ANY GROUPS WORKING OUTSIDE, DISCUSSED ALTERNATIVE MUSTER AREA IF NORMAL MUSTER AREAS AREN'T STAGED YET 02:30 - 05:00 2.50 RIGU P PRE RU CIRCULATING LINES AND TEST TO 3500 PSI -RU DOUBLE ANNULUS VALVE AND 2" LINE FOR OA BLEED TO SLOP TANK -BRING ON440 BBLS OF BRINE INTO PITS, FLUID WEIGHT 9.75 PPG 05:00 - 07:00 2.00 RIGU P PRE PJSM -RIG UP AND TEST DSM LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH -PULL BPV AND R/D DSM LUBRICATOR. -AFTER PULLING BPV TUBING, IA AND OA PRESSURES ALL 0 PSI **ACCEPT RIG AT 06:00** 07:00 - 08:00 1.00 CLEAN P DECOMP PJSM, RU TO CIRCULATE AND PRESSURE TEST LINE TO 3500 PSI. -8.2 BBLS BRINE TO FILL FLUID LINES AND GAS BUSTER. 08:00 - 10:30 2.50 CLEAN P DECOMP PJSM DISPLACE FREEZE PROTECT OUT OF WELL. - SUMP 20 BBLS BRINE DOWN THE IA AT 3 BPM / 320 PSI. - CIRCULATE 431 BBLS DOWN THE TBG AT 5 BPM / 800 PSI. - MONITOR WELL FOR 10 MINUTES, NO FLOW. 10:30 - 12:00 1.50 BOPSUR P DECOMP PJSM - RIG MU AND TEST DSM LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH. -SET TWC AND R/D DSM LUBRICATOR. 12:00 - 13:00 1.00 BOPSUR P DECOMP TEST TWC FROM BELOW TO 1000 PSI - TEST TWC FROM ABOVE TO 250 LOW, 3500 PSI - BOTH TEST CHARTED FOR 10 MINUTES. -R/D DSM LUBRICATOR. Printed 11/14/2011 1:58:56PM North giorica - ALASKA - BP Page 4 of 15 Operation Summary Report . Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 13:30 0.50 BOPSUR P DECOMP CALL TOWN RWO ENGINEER, - DISCUSSED OA TEST. -RU AND PRESSURE TEST THE OA TO 2000 PSI, -TEST HELD 1590 PSI FOR 10 MINUTES. 13:30 - 14:30 1.00 BOPSUR P DECOMP DSM DEACTIVATE SSV ELECTRIC MOTOR -R/D ALL CIRCULATING LINES. -FMC WELL HEAD REP PREPARE THE ADAPTER FOR REMOVAL. 14:30 - 17:30 3.00 BOPSUR P DECOMP PJSM N/D TREE AND ADAPTER FLANGE. -CLEAN OUT HANGER AND CHECK NSTC X/O THREADS FOR PULLING HANGER • -7.75 TURNS TO MAKE -UP 17:30 - 18:30 1.00 BOPSUR P DECOMP PJSM FOR BOP NIPPLE UP -RIG UP CONTINUOUS FEED LOOP TO IA 18:30 - 00:00 5.50 BOPSUR P DECOMP NU BOPE -LOAD AND STRAP DRILL PIPE IN PIPE SHED 10/22/2011 00:00 - 08:00 8.00 BOPSUR P DECOMP TESTING 13 -5/8" BOPE TEST BOPE PER , WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 3500 Pe PSI HIGH. - HYDRILL TESTED TO 250 PSI LOW AND 3,500 J,e- PSI HIGH -TEST USING 4 1/2" AND 2 7/8" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT -AK -10-45 -AOGCC STATE INSPECTOR BOB NOBLE WAIVED STATES RIGHT OF WITNESS. ACCUMULATOR DRAW DOWN TEST: - 2900 PSI DRAW DOWN TO 2050 PSI. - 200 PSI INCREASE IN 17 SECONDS. - FULL PRESSURE IN 69 SECONDS. - 6 N2 BOTTLES @ 2100 PSI. - ANNULAR= 19 SECONDS. -BLIND RAMS = 8 SECONDS. -PIPE RAMS = 14 SECONDS. NO FAILURES 08:00 - 08:30 0.50 BOPSUR P DECOMP R/D TEST EQUIPMENT -BLOW DOWN CHOKE LINES. 08:30 - 09:00 0.50 BOPSUR P DECOMP PU / RU DUTCH SYSTEM AND DSM LUBRICATOR. 09:00 - 09:30 0.50 BOPSUR P DECOMP TEST LUBRICATOR TO 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. -DSM PULLED TWC 09:30 - 10:00 0.50 BOPSUR P DECOMP R/D LUBRICATOR AND DUTCH SYSTEM. 10:00 - 12:00 2.00 PULL N WSEQ DECOMP 4" DP ELEVATORS NOT OPERATING PROPERLY. BRING NEW ELEVATORS TO FLOOR AND R/U SAME. 12:00 - 15:00 3.00 PULL P DECOMP BACK OUT LDS, PULL HANGER TO RIG 1/ FLOOR. PULL HANGER OFF SEAT AT 11 OK, �C PULL FREE AT 21 OK, PICK UP WT =130K, R/U CIRC LINES 15:00 - 16:00 1.00 PULL P DECOMP CIRCULATE B/U THROUGH CHOKE, 7 BPM 1550 PSI, R/D CIRC LINES Printed 11/14/2011 1:58:56PM North , rica - ALASKA - BP Page 5 of 15 Operation Summary Report . . Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 16:30 0.50 PULL P DECOMP MONITOR WELL 10 MINUTES, R/U CASING EQUIP 16:30 - 00:00 7.50 PULL P DECOMP POOH AND UD 4 -1/2 ", 12.6 LB-FT, L80 BTC TUBING FROM 11,520' TO 6,064' 10/23/2011 00:00 - 06:00 6.00 PULL P DECOMP POOH AND UD 4 1/2 12.6# L80 BTC TUBING FROM 6064 TO SURFACE -275 TOTAL JOINTS, 4 GLM'S, TWO "X" NIPPLES, 3 PUPS. - JET -CUT WAS MADE IN THE TOP COLLAR OF THE PACKER. - RECOVERED 2" OF THE PACKER ASSEMBLY TOP. - 1" DIA. HOLE 2' BELOW COLLAR ON TOP 9' PUP JT OF GLM #1 AT 11387 06:00 - 07:30 1.50 PULL P DECOMP RD TBG HANDLING EQUIPMENT -LOAD AND STRAP 2 7/8" HT -PAC DP AND 3 1/4" DC, INTO THE PIPE SHED. -STRAP AND TALLY PIPE. 07:30 - 08:00 0.50 CLEAN P DECOMP IItST.AL WEAR RING ID = 7" 08:00 - 10:30 2.50 CLEAN P DECOMP P/U AND M/U 3.75" MILL, BIT SUB, 3 EA 3- 3/4" DC, 40 EA 2 7/8" DP, XO, XO, 7" CSG SCRAPER, BIT SUB, PUMP OUT SUB, XO SUB = 1368.81 -PUMP A D.P. VOLUME TO CLEAR BHA, 2 BPM / 220 PSI. 10:30 - 00:00 13.50 PULL P DECOMP PJSM P/U DP. -P /U 4" 15.5# DP FROM PIPE SHED 1X1. - CONTINUOUS HOLE FILL WITH NO GAINS OR LOSSES. 10/24/2011 00:00 - 00:30 0.50 PULL P DECOMP CONTINUE TO CIRCULATE DP VOLUME. 3 -BPM, 970 -PSI 00:30 - 01:30 1.00 PULL P DECOMP PJSM, CONT. RIH W /DP 1X1 FROM 9,899' TO 10,436' PUW 160K, DW 105. 01:30 - 03:30 2.00 WHSUR P DECOMP PJSM, M/U STORM PACKER, RIH AND SET PACKER JUST BELOW SURFACF AT 95'. MILL DEPTH 10,531' -TEST FROM TOP, 1,000 -PSI, 10 MINUTES V Gr CHARTED (TEST GOOD) - TESTED BARRIERS: 2 7/8" CBP AT 14,430' MD AND 7" STORM PACKER AT 95' MD 03:30 - 04:00 0.50 WHSUR P DECOMP P/U RUNNING TOOL & PULL WEAR RING. 04:00 - 06:00 2.00 WHSUR P DECOMP N/D BOPE AND TUBING SPOOL. 06:00 - 10:00 4.00 WHSUR P DECOMP ATTEMPT TO PULL PACK OFF, UNSUCCESSFUL, CONSULT WITH CONSULT WITH RWO ENGINEER, RWO SUPERINTENDENT, FMC TECH AND RIG TEAM, DEVELOP PLAN FORWARD. - DECIDE TO LEAVE OLD PACK -OFF IN WELL HEAD AND INSTALL NEW "REDUCER BUSHING ", RILDS AND TORQUE 10:00 - 12:30 2.50 WHSUR P DECOMP N/U NEW FMC TUBING SPOOL, INSTALL DOUBLE ANNULUS VALVES / 12:30 - 14:30 2.00 WHSUB P DECOMP TEST FMC 7" CASING PACK -OFF, 3500 -PSI ✓ FOR 30- MINUTES, CHARTED, (TEST GOOD) 14:30 - 16:30 2.00 WHSUR P DECOMP PJSM, N/U BOPE Printed 11/14/2011 1:58:56PM North Orioa - ALASKA - BP Page 6 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 17:30 1.00 WHSUR P DECOMP PJSM, INSTALL TEST PLUG, R/U TEST EQUIPMENT -TEST TUBING SPOOL AND BOP FLANGE BREAK, 3,500 -PSI, 5- MINUTES CHARTED, (TEST GOOD) -R/D TEST EQUIPMENT 17:30 - 22:00 4.50 WHSUR N WSEQ DECOMP UNABLE TO PULL TEST PLUG FROM TUBING SPOOL, CONSULT WITH RWO ENGINEER, RWO SUPERINTENDENT, FMC TECH AND RIG TEAM, DEVELOP PLAN FORWARD. 22:00 - 00:00 2.00 WHSUR N WSEQ DECOMP PJSM, N/D BOPE. 10/25/2011 00:00 - 01:00 1.00 WHSUR N WSEQ DECOMP PJSM, WD REMOVE STUDS ON TUBING SPOOL, ATTEMPT TO PULL SPOOL WITH 25K, UNSUCCESSFUL VISUALLY INSPECT TEST PLUG AND SPOOL FOR OBSTRUCTIONS, 01:00 - 02:00 1.00 WHSUR N WSEQ DECOMP PJSM, RE- INSTALL STUDS ON TUBING SPOOL AND BOP, MVU LANDING JT TO TEST PLUG, TEST PLUG PULLED FREE WITH 40K, INSPECT TEST -PLUG, INDICATION THAT LOWER NECK OF TEST PLUG HAD STABBED INTO THE I.D. OF 7 ", 29# CSG, APPROXIMATELY 1 -1/2" 02:00 - 03:00 1.00 WHSUR N WSEQ DECOMP REMOVE BOP, INSPECT TUBING SPOOL, DRIFT 7" CSG AT WELLHEAD WITH 6.059" DRIFT, DRY RUN NEW TEST PLUG PRIOR TO INSTALLATION OF BOPE. 03:00 - 04:00 1.00 WHSUR N WSEQ DECOMP N/U TUBING SPOOL - TEST PACK -OFF VOID, 3,500 -PSI, 30- MINUTES, CHARTED (TEST GOOD) 04:00 - 05:30 1.50 BOPSUR N WSEQ DECOMP PJSM - N/U BOP, INSTALL TEST PLUG 05:30 - 06:00 0.50 BOPSUR N WSEQ DECOMP - TEST BOP FLANGE BREAK 250 -PSI LOW, Q 3,500 -PSI HIGH, 5- MINUTES EACH, CHARTED V (TEST GOOD) PULL TEST PLUG 06:00 - 06:30 0.50 BOPSUR P DECOMP SET WEAR RING 06:30 - 07:30 1.00 DHB P DECOMP PJSM - DISCUSS ANTICIPATED TRAPPED PSI. RELEASE STORM - PACKER MONITOR FOR PRESSURE, (NO PRESSURE OBSERVED) PULL STORM - PACKER TO FLOOR - UD STORM - PACKER 07:30 - 08:30 1.00 CLEAN P DECOMP CIRC. BOTTOMS UP AT 10,436' - 4 BPM, PSI 920 08:30 - 10:00 1.50 CLEAN P DECOMP P/U DP FROM PIPE -SHED. RIH F/ 10,436 T/ 11,321' PER PROGRAM MAKE ADDITIONAL SCRAPES AT 11,384' AREA, 4 -TOTAL PASSES (NO ISSUES) - CONTINUE RIH TO 11,510' - PUW 185K, DW 107K 10:00 - 10:30 0.50 CLEAN P DECOMP POOH RACK DP IN DERRICK F/ 11,510' T/ 10,373' 10:30 - 11:30 1.00 CLEAN P DECOMP P/U DP FROM PIPESHED RIH WITH SAME F/ 10,373 T/ 11,510 11:30 - 17:30 6.00 CLEAN P DECOMP WHILE CIRC. 3 -BPM, 1,750 -PSI, LOAD AND PREP 4 -1/2" TUBING INTO PIPESHED - PUW 170K, DW 111K Printed 11/14/2011 1:58:56PM North carica - ALASKA - BP Page 7 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:00 1.50 CLEAN P DECOMP PJSM- EST. PARAMETERS AT 11,585' IN PREPARATION TO MILL CBP. - RIH F/ 11,510', TAG TUBING STUMP AT 11,514' - TAG CBP AT 11,528' D{- - PUW 165K, DW 112K, RW 132K, TRQ 7.5K - PUMP 20 -BBL HI-VIS SWEEP, 5- BPM, 2,390 -PSI - SPR'S 11,585' 9.8 -PPG #1 MP, 30 -SPM, 920 -PSI #1 MP, 40 -SPM, 1,290-PSI #2 MP, 30 -SPM, 940 -PSI #2 MP, 40 -SPM, 1,670 -PSI 19:00 - 20:00 1.00 CLEAN P DECOMP MILL THROUGH CBP AT 11,528' (CBP MILLED 19:37 HRS) RETURN FLOW 23% WHILE MILLING FLOW RETURN REDUCED TO 12 -19% ONCE CBP MILLED. -4 BPM, PSI 1,740 - WOB 5K, TRQ 7.5K, 40 RPM. - POOH TO ABOVE TUBING 4 -1/2 TUBING STUB T/ 11,510' 20:00 - 21:00 1.00 CLEAN P DECOMP 11,510' SHUT ANNULAR PREVENTER. BULLHEAD 50 -BBLS OF 9.8 -PPG BRINE - 7 BPM, PSI 690 - SHUT DOWN PUMP, RECORD PRESSURE - SIDP 100 -PSI, SICP 100 -PSI - MONITOR WELL FOR FLOW THROUGH BLEEDER ON CHOKE - 8 -BBLS RETURNED THROUGH CHOKE. SHUT IN MONITOR PRESSURE. - SIDP 50 -PSI, SICP 50 -PSI 21:00 - 00:00 3.00 CLEAN P DECOMP CBU THROUGH CHOKE. AT B/U NO INDICATIONS OF GAS OR CONTAMINATED FLUID. 5 -BPM, PSI 1,670 - DYNAMIC LOSS RATE 90 -BPH - TOTAL LOSS 117 -BBL - SHUT DOWN MONITOR WELL TO CLOSED CHOKE. PERFORM EXHALE TEST PER ADW RP FOR WELLBORE BREATHING TO VERIFY SUSPECTED FORMATION CHARGE. - SIDP 50 -PSI, SICP 60 -PSI - BLEED 10 -BBL T/ TRIP TANK. SHUT IN, MONITOR, RECORD PSI, SIDP 40 -PSI, SICP 40 -PSI - REPEAT PROCESS IN 10 -BBL INCREMENT. NO REDUCTION IN SIDPP 40 -PSI, SICP 40 -PSI - CONSULT RWO ENG. RIG TEAM ON PLAN FORWARD. MONITOR PRESSURES. - NO INCREASE OF SIDP 50 -PSI, SICP 50 -PSI - MW IN 9.8, MW OUT 9.8 10/26/2011 00:00 - 03:30 3.50 CLEAN P DECOMP WELL SHUT IN CONTINUE TO MONITOR s! PRESSURES AT 11,510' ,�_ - CONSULT AND DISCUSS OPTIONS WITH J RWO ENG. TEAM LEAD AND WELLS MANAGER. - MONITOR PRESSURES. SITP 50 -PSI, SICP 50 -PSI - NO INCREASE OF SIDP OR ,DP. - MW IN 9.8, MW OUT 9.8 ✓ Printed 11/14/2011 1:58:56PM North *Ilea - ALASKA - BP Page 8 of 15 Operation Summary.,Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 13:30 10.00 CLEAN P DECOMP MOBILIZE AND PREPARE TO WEIGHT UP FROM 9.8 -PPG TO 10.4 -PPG - SITP 50 -PSI, SICP 50 -PSI - HAVE 409 BBLS OF 10.2 PPG IN THE PITS AND THREE TRUCKS WITH 10.2 PPG ON LOCATION - RECIEVED OPS NOTE # 1 PLAN FORWARD FROM RWO ENGINEER 13:30 - 14:30 1.00 CLEAN P DECOMP VERIFY WITH TOWN FOR APPROVAL TO BEGIN CIRCULATING 10.2 KWF - VERIFY WITH RWO TEAM LEAD AND WELLS MANAGER. - DISCUSS CHANGE TO THE OPS NOTE # 1 REV 2 PLAN FORWARD WITH THE ENGINEER 14:30 - 15:00 0.50 CLEAN P DECOMP PJSM WITH CREW FOR NEW PLAN FORWARD & WELL KILL OPERATION / - DISCUSSION ON FLUIDS MANAGMENT PLAN (/ - REVIEWED DDI PROCEDURE FOR WELL KILL OPERATIONS **GAVE 24 HOUR NOTIFICATION FOR WEEKLY BOPE TESTING ** - JOHN CRISP CALLED BACK AND ASKED FOR AN UPDATE IN THE MORNING. 15:00 - 16:00 1.00 CLEAN P DECOMP PUMPED DP VOLUME OF 116 BBLS OF 10.2 PPG SODIUM BROMIDE, TAKING THE 9.75 PPG RETURNS OUT TO THE SLOP TANK - HELD 50 PSI ON THE CHOKE DURING CIRCULATION. - 3 BPM @ 550 -650 PSI - SHUT IN AND MONITORED THE WELL FOR 10 MIN, DP PRESSURE GUAGE READING 0 - LOST — 15 BBLS DURING THE CIRCULATION 16:00 - 20:00 4.00 CLEAN P DECOMP STARTED PUMPING A BOTTOMS UP WITH THE 10.2 PPG BRINE - TAKING RETURNS TO THE SLOP TANK - HELD 40 -PSI ON THE CHOKE - PUMPED 2.5 - 4 BPM WITH 400 -750 PSI. - 10.2 -PPG KWF AT SURFACE WITH A TOTAL OF 670 -BBL PUMPED. - DYNAMIC LOSS RATE 180 -BPH - 19:30 HRS WELL SHUT IN. MONITOR PRESSURES. - SIDP 0 -PSI, SICP 0 -PSI - TOTAL BRINE LOST TO WELL SINCE COMPOSITE BRIDGE PLUG MILLED. 423 -BBL Printed 11/14/2011 1:58:56PM North , rIca - ALASKA - BP Page 9 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:00 1.00 CLEAN P DECOMP WELL SHUT IN, CONTINUE TO MONITOR PRESSURES AT 11,510' - SICP 0 -PSI, SITP 0 -PSI * *CONSULT WITH WELLS MANAGER, TEAM LEAD, RWO ENG AND RWO SUPT** - WSL'S GRANTED AUTHORIZATION TO OPEN WELL AND PROCEED WITH OPERATIONS - OPEN WELL. WELL TAKING FLUID, - EST. STATIC LOSS RATE OF 80 -BPH. - PER PROCEDURE ADDENDUM, FILL AT 60 -BPH. - HOLD PJSM WITH RIG TEAM ON FLUID MANAGEMENT AND WELL OPERATIONS. - BLOW DOWN TOP - DRIVE, CHOKE AND GAS - BUSTER 21:00 - 00:00 3.00 CLEAN P DECOMP RIH FROM 11,510' TO 12,730' - PUW 160K, DW 117K - SCRAPE PACKER SETTING DEPTH FROM 11,340' TO 11,365' - CONTINUE TO FILL 60 -BPH 12,730' - PJSM FOR POOH WITH DP. - MW IN 10.2 -PPG, MW OUT 10.2 -PPG - STATIC LOSS RATE 76 -BPH 10/27/2011 00:00 - 00:30 0.50 CLEAN P DECOMP POOH FROM 12,730' TO 11,510' - PUW 170K, DW 110K - FILL HOLE AT 60 -BPH - STATIC LOSS RATE 76 -BPH 00:30 - 01:30 1.00 CLEAN P DECOMP PJSM - CUT AND SLIP DRILLING LINE - FILL HOLE AT 60 -BPH 01:30 - 04:00 2.50 CLEAN P DECOMP POOH UD JNTS DP TO PIPE -SHED FROM 11,510 TO 8,856' - FILL HOLE AT 60 -BPH 04:00 - 05:00 1.00 CLEAN N RREP 8,855.98 DECOMP REPLACE FRAYING CABLE ON SKATE. 05:00 - 14:00 9.00 CLEAN P DECOMP CONTINUE POOH UD 4" 14# DP FROM 8,856' TO 1368' - LAYING DOWN SNGLES TO THE PIPE SHED AOGCC CALLED BACK AND WAIVED THE RIGHT TO WITNESS FOR OUR WEEKLY BOPE TESTING. 14:00 - 16:00 2.00 CLEAN P DECOMP MONITOR WELL FOR FLOW BEFORE PULLING BHA THRU THE STACK - BREAK AND LAY DOWN 2 -7/8" HT PAC AND 3 -3/4" MILLING ASSEMBLY 16:00 - 18:30 2.50 BOPSUR P DECOMP CLEAN AND CLEAR RIG FLOOR - PULL WEAR RING - RU CONTINUOUS HOLE FILL LINE TO BE USED DURING BOP TESTING - RU BOPE TESTING EQUIPMENT 18:30 - 19:30 1.00 BOPSUR P DECOMP PJSM- INSTALL TEST PLUG - GREASE CHOKE MANIFOLD VALVES R - FILL BOPE AND TEST EQUIPMENT WITH H20. - RU TO TEST BOPE Printed 11/14/2011 1:58:56PM • North rica - ALASKA - BP Page 10 of 15 Operation Summary,Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 BOPSUR P DECOMP TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. - RAMS TESTED TO 250 -PSI LOW AND 3500 -PSI HIGH. - HYDRILL TESTED TO 250 -PSI LOW AND 3,500 -PSI HIGH - TEST USING 4 -1/2" AND 3 -1/2" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN EACH TEST. ALL TEST WITNESSED BY BP WSL / DDI TP. VV/ - ALL TEST FOLLOW TESTING CRITERIA 1S DOCUMENTED IN CRT- AK -10 -45 1 - AOGCC STATE INSPECTOR JOHN CRISP WAIVED WITNESS. ACCUMULATOR DRAW DOWN TEST: - 2900 PSI DRAW DOWN TO 1600 PSI. - 200 PSI INCREASE IN 22 SECONDS. - FULL PRESSURE IN 103 SECONDS. - 6 N2 BOTTLES @ 2100 PSI. ** NO FAILURES ** 10/28/2011 00:00 - 01:00 1.00 BOPSUR P DECOMP CONTINUE TESTING 13 -5/8" BOPE. TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. ACCUMULATOR DRAW DOWN TEST: - 2900 PSI DRAW DOWN TO 1600 PSI. - 200 PSI INCREASE IN 22 SECONDS. - FULL PRESSURE IN 103 SECONDS. - 6 N2 BOTTLES @ 2100 PSI. 01:00 - 01:30 0.50 BOPSUR P DECOMP RD BOP TEST EQUIPMENT. BLOW DOWN LINES AND CHOKE MANIFOLD. 01:30 - 04:00 2.50 RUNCOM P RUNCMP R113-1/2" TUBING RUNNING EQUIPMENT AND SLB I -WIRE SPOOLER, 04:00 - 07:00 3.00 RUNCOM P RUNCMP PJSM- PU 3 -1/2 ", 9.3#, 13CR -80 ST -L TAILPIPE ASSEMBLY - RIH WITH TUBING PER PROGRAM WITH 40 JNTS, 1222.41' - TORQUE TURN SERVICES & SINGLE JOINT COMPENSATOR FOR PREMIUM CONNECTIONS - USE "JET LUBE SEAL GUARD" THREAD COMPOUND - CONTINUOUS HOLE FILL AT 60 BPH 07:00 - 21:00 14.00 RUNCOM P RUNCMP RUN 4 -1/2" 12.6# VAM TOP WITH 7" BY 4 -1/2" HES TNT PACKER. - RIH TO 1,403' PU HES TNT PACKER, VERIFY PACKER S/N AND VISUAL INTEGRITY - RIH TO 1,507' PU SLB NDPG -C GUAGE MANDREL AND CONNECT I -WIRE. - CONTINUE RIH WITH 4 -1/2" 12.6# VAM TOP 13CR -85, USING TORQUE TURN SERVICES AND SINGLE JOINT COMPENSATOR. - TRQ EACH JOINT TO 4,440 FT /LBS - BAKER -LOC ALL 4 -1/2" CONNECTIONS BELOW THE PACKER - VERIFY THE I -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JOINTS. - CONTINUOUS HOLE FILL STILL AT 60 BPH. Printed 11/14/2011 1:58:56PM Northrica - ALASKA - BP • Page 11 of 15 • Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 21:30 0.50 RUNCOM P RUNCMP D -1 DRILL (KICK WHILE TRIPPING) WITH C -CREW - TABLE TOP DISCUSSION WITH RIG PERSONNEL - DISCUSS MULTIPLE SCENARIO BASED SITUATIONS AND GRADUATED COMPLEXITY OF THE DRILL. - DISCUSS POTENTIAL HAZARDS OF THE I -WIRE AND EXTRA PERSONNEL ON THE RIG. - REVIEW CREW MEMBERS ROLL AND RESPONSIBILITY DURING WELL CONTROL EVENTS. 21:30 - 00:00 2.50 RUNCOM P RUNCMP CONTINUE TO RUN 4 -1/2" 12.6# VAM TOP COMPLETION. FROM 6,503' TO 7,908' - UTILIZE TORQUE TURN SERVICES AND SINGLE JOINT COMPENSATOR. - VERIFY THE I -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JOINTS. - USE "JET LUBE SEAL GUARD" THREAD COMPOUND - PUW 110K, DW 84K ** LOSSES LAST 24 HRS 1,361 -BBLS ** ** LOSS AVERAGE 57 -BPH ** 10/29/2011 00:00 - 01:30 1.50 RUNCOM P RUNCMP CONTINUE TO RUN 4 -1/2" 12.6# VAM TOP COMPLETION. FROM 7,908' TO 8,450' - UTILIZE TORQUE TURN SERVICES TRQ TO 4,440 FT /LBS - UTILIZE SINGLE JOINT COMPENSATOR. - VERIFY THE 1 -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 10 JOINTS. - USE "JET LUBE SEAL GUARD" THREAD COMPOUND 01:30 - 02:30 1.00 RUNCOM N RREP RUNCMP 01:30 HRS 5- GALLONS OF 10.2 PPG BRINE LEAKED FROM AIR -BOOT ON THE DRILLING NIPPLE/ RISER. ALL FLUID CONFINED TO RIG AND WITHIN CONTAINMENT. - NOTIFY PROPER AUTHORITIES, PER LEVEL "0" NOTIFICATION LIST. - NOTIFICATION GIVEN TO #5700, SENIOR WSL, OPS SUPERINTENDENT, S -PAD OPERATOR, GC2 FACILITY AND HSE. - MITIGATE AND REPAIR LEAKING AIR -BOOT. DISCUSS SPILL PREVENTION WITH RIG TEAM. - TRACTION IR PENDING MONITOR STATIC LOSS TO WELL WHILE REPAIRING. - STATIC LOSS OF 57- BBL/HR 02:30 - 08:30 6.00 RUNCOM P RUNCMP CONTINUE TO RUN 4 -1/2" 12.6# VAM TOP COMPLETION. ' - TIH FROM 8,450' TO 11,510' JUST ABOVE THE 4 -1/2" STUB AND PACKER. - 135K PUW , 97K SOW - RIH & TAG STUB AT 11,521' TUBING MEASUREMENT. Printed 11/14/2011 1:58:56PM North.rica - ALASKA - BP Page 12 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 14:00 5.50 RUNCOM P RUNCMP ATTEMPT TO GUIDE THE 3 -1/2" HALF MULE SHOE INTO THE THE 4 -1/2" STUB AT 11,521' - PU & SLACK OFF SEVERAL TIMES, MAX 5K DOWN WEIGHT. - RIG DOWN SINGLE JOINT COMPENSATOR AND MU TIW WITH VAM TOP X0. - MAKE UP TIW AND AND TOP DRIVE - PUMP 3 -4 BPM WITH 150 -250 PSI , WHILE ATTEMPTING TO GUIDE THE MULE SHOE INTO THE 4-1/2" STUB. FAILED SEVERAL ATTEMPTS. - CONTACTED RWO ENGINEER AND SUPT TO DISCUSS PLAN FORWARD. - PLAN FORWARD IS TO PULL SLACK IN THE I -WIRE AND IMPUT 3 ROTATIONS IN THE PIPE IN AN ATTEMPT TO ROLL THE MULE SHOE INTO THE 4 -1/2" STUB. - CONTINUOUS HOLE FILL MAINTAINED AT 40 -45 BPH. 14:00 - 14:30 0.50 RUNCOM P RUNCMP HELD A TABLE TOP PJSM TO DISCUSS WHAT WERE GOING TO ATTEMPT. - PULLED SLACK IN THE I -WIRE , PUT 3 FULL TURNS IN THE 4 -1/2" TUBING. - HELD 2K DOWN WEIGHT AND RECIPROCATED THE PIPE UP AND DOWN. - THE MULE SHOE FINALLY ROLLED INTO THE 4 -1/2" STUB. - SLB PERFORMED A CONTINUITY TEST AND EVERYTHING CHECKED OUT GOOD. 14:30 - 15:30 1.00 RUNCOM P RUNCMP PJSM TO RE -GROUP AFTER THE CHANGE IN SCOPE, DISCUSSED RUNNING THE LONG TAILPIPE ASSEMBLY INTO THE 4 -1/2" LINER. - MAKE UP THE SINGLE JOINT COMPENSATOR AND TUBING RUNNING EQPT. - STATIC LOSS RATE — 40 BPH 15:30 - 17:00 1.50 RUNCOM P RUNCMP CONTINUE TO RUN4 -1/2" 12.6# VAM TOP COMPLETION. ' - RIH FROM 11,521' TOP OF LINER TO 12,720' - CONTINUOUS HOLE FILL MAINTAINED AT 40 BPH. 17:00 - 19:00 2.00 RUNCOM N RREP RUNCMP RIG MISPLACED ORIGINAL CROSSOVER FOR JOB, M/U TIW VALVE AND CROSSOVERS 19:00 - 19:30 0.50 RUNCOM P RUNCMP PU TCII LANDING JOINT, MAKE UP CROSS OVERS AND TIW VALVE. - MAKE UP FMC, 13 -5/8" X 4 -1/2" TCII TUBING HANGER 19:30 - 20:30 1.00 RUNCOM P RUNCMP TERMINATE I -WIRE - FMC TEST HANGER TO 5,000 -PSI FOR 10- MINUTES 20:30 - 21:00 0.50 RUNCOM P RUNCMP LAND HANGER, VERIFY RKB MFASIJRFMFNTS - RUN IN LDS AND L/D LANDING JNT. - 12,720' PUW 140K, DW 100K ** CLAMPS RAN ** FULL CLAMPS= 175 1/2 CLAMPS= 9 TOTAL CLAMP =184 Printed 11/14/2011 1:58:56PM North firioa - ALASKA - BP Page 13 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 23:00 2.00 RUNCOM P RUNCMP PJSM- PIT LINES TO 4,000 PSI. - PUMP 200 -BBLS. 10.2 -PPG BRINE WITH CORROSION INHIBITOR. - 3 -BPM , 960 -PSI 23:00 - 23:30 0.50 RUNCOM P RUNCMP P/U AND INSTALL LANDING JNT, DROP BALL AND ROD WITH ROLLERS TO SEAT IN RHC. - L/D LDG JNT - BLOW DOWN LINES, ATTEMPT TO OBTAIN LOW PRESSURE TEST ON TBG. 23:30 - 00:00 0.50 RUNCOM P RUNCMP TROUBLESHOOT AND ISOLATE LEAKING VALVES ON SQUEEZE MANIFOLD IN CELLAR. - CHANGE TWO HALLIBURTON PLUG VALVES TOTAL. ** TOTAL 24 -HR LOSS TO WELL 749 - BBL*" 10/30/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP CONTINUE TO CHANGE OUT HALLIBURTON VALVES ON SQUEEZE MANIFOLD. - PT LINES AND VALVES TO 4,000 -PSI; TEST GOOD 00:30 - 02:00 1.50 RUNCOM P RUNCMP ATTEMPT LOW PT ON TBG. NO GOOD, - DETERMINE BALL AND ROD LEAKING PAST RHC. - CONSULT RWO ENG. GET APPROVAL TO SET PACKER PER PROGRAM. 02:00 - 03:00 1.00 RUNCOM P RUNCMP PRESSURE UP ON THE TUBING, PUMPING DOWN THE KILL LINE. - OBSERVE PACKER SET AT 1,950 -PSI. - CONTINUE TO PRESSURE TO 3,500 -PSI. CHART TEST 30 -MIN. - TBG 20 -PSI OVERALL PRESSURE LOSS OVER 30 -MIN - 20 -PSI FIRST 15 -MIN. - 0 -PSI LOST LAST 15 -MIN. TEST PASSED CRT- AK -10 -45 CRITERIA * - BLEED TUBING DOWN TO 1,500 -PSI 03:00 - 04:00 1.00 RUNCOM P RUNCMP PRESSURE TO 4,000 -PSI ON 4 -1/2" X 7" IA FOR 30 -MIN CHARTED - OVERALL PRESSURE LOSS OF 90 -PSI - 90 -PSI FIRST 15 -MIN - 0 -PSI LOST LAST 15 -MIN. - TEST PASSED CRT -AK -10-45 CRITERIA - VERIFY THE COMPETENCY OF THE PRESSURE TEST WITH OPERATION MANAGER AND RWO ENG. GRANTED APPROVAL TO PROCEED. SHEAR DCK VALVE - CIRCULATE DOWN TBG 2 -BPM, 720 -PSI - CIRCULATE DOWN IA 2 -BPM, 690 -PSI VERIFICATION OF ABILITY TO PUMP BOTH WAYS 04:00 - 05:30 1.50 RUNCOM P RUNCMP FMC REP DRY ROD IN THE 4" H STYLE TWC, - PRESSURE TEST FROM BELOW TO 1,000 -PSI. TEST 3,500 -PSI FROM ABOVE. 10 -MIN ON EACH TEST. 05:30 - 08:30 3.00 RUNCOM P RUNCMP ND 13 -5/8" 5K HYDRILL BOPE - CLEAN & CLEAR CELLAR. - BARRIERS ARE THE BALL ON ROD SEAT , KWF & 4" TESTED (H STYLE TWC Printed 11/14/2011 1:58:56PM • North erica - ALASKA - BP Page 14 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 13:00 4.50 RUNCOM P RUNCMP PJSM FOR NU OF TREE - NU 13 -5/8" 5K X 4- 1/16" ADAPTER FLANGE AND DRY HOLE TEE - SLB TESTING CONTINUITY - FMC REP TESTING HANGER VOID AND SEAL TO 250 PSI LOW AND 5000 PSI FOR 30 CHARTED MIN. - CONTINUITY TEST (FAILED) - REMOVE ADAPTER FLANGE TO INSPECT I -WIRE - WAS DISCOVERED THAT THE I -WIRE WAS DAMAGED WHEN THE ADAPTER FLANGE WAS MADE UP. SLB WAS ABLE TO USE SOME SLACK IN THE I -WIRE TO REPAIR IT AND TERMINATE IT THRU THE ADAPTER FLANGE. 13:00 - 13:30 0.50 RUNCOM N WSEQ RUNCMP FMC REP RE- TESTING HANGER VOID AND SEAL TO 250 PSI LOW AND 5000 PSI FOR 30 CHARTED MIN. 13:30 - 14:30 1.00 RUNCOM P RUNCMP PJSM FOR - NU DRY HOLE TREE - PRESSURE TEST TREE TO 5,000 -PSI FOR 5 CHARTED MINUTES. 14:30 - 16:30 2.00 RUNCOM P RUNCMP RU DSM LUBRICATOR - PRESSURE TEST 250 -PSI LOW, 3,500 -PSI HIGH FOR 5- CHARTED MINUTES. - PULL TWC WITH DSM LUBRICATOR 16:30 - 17:30 1.00 RUNCOM P RUNCMP RU LITTLE RED HOT OIL TO FREEZE PROTECT 17:30 - 20:30 3.00 RUNCOM P RUNCMP PREP RIG FOR UD DERRICK AND MOVE TO L -205 WHILE LITTLE RED STAGING DIESEL ** 18:45 HRS. FIRE REPORTED AT MOBILE PAD, VEHICLE FIRE. TRUCK WAS A CHM2H. INFORM PROPER AUTHORITIES. CMH2H HANDLING TRACTION. IR # 3979649 ** 20:30 - 22:00 1.50 RUNCOM P RUNCMP PJSM- FOR FREEZE PROTECT - PRESSURE TEST LINES TO 250 -PSI LOW, 3,500 -PSI HIGH - PUMP 81 -BBLS HEATED DIESEL DOWN IA - CIRCULATE FREEZE 2 -BPM, ICP 880 -PSI, FCP 1,300 -PSI 22:00 - 23:30 1.50 RUNCOM P RUNCMP LINE UP AND ALLOW DIESEL TO U -TUBE, FREEZE PROTECTING TUBING AND ANNULUS TO 2,200' -MD - IA PRESSURE STABILIZED AT 230 -PSI 23:30 - 00:00 0.50 RUNCOM P RUNCMP BLOW DOWN LINES, RU DSM LUBRICATOR TO INSTALL BPV. 10/31/2011 00:00 - 01:00 1.00 WHSUR P RUNCMP RU DSM LUBRICATOR - PRESSURE TEST LUBRICATOR TO 250 -PSI LOW, 3,500 -PSI HIGH FOR 5- CHARTED MINUTES 01:00 - 02:00 1.00 WHSUR P RUNCMP SET 'H' BPV WITH LUBRICATOR IN TUBING HANGER - TEST BPV WITH LRS FROM BELOW TO 1,000 -PSI FOR 10- CHARTED MIN. TEST GOOD - IA 270 -PSI, TBG 50 -PSI 02:00 - 03:00 1.00 WHSUR P RUNCMP BLOW DOWN CIRC. LINES. - RD LRS, - RD DSM LUBRICATOR Printed 11/14/2011 1:58:56PM North Orica - ALASKA - BP Page 15 of 15 Operation Summary Report Common Well Name: S -102 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2011 End Date: X4- 00V44 -E (4,700,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: 9/14/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292297200 Active Datum: S -102 @64.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:00 1.00 WHSUR P RUNCMP CLEAN AND CLEAR CELLAR - SECURE TREE - RD MUD MANIFOLD ** RIG RELEASED FROM S -102 10/31/2011 00:01 HRS. ** ** REFER TO L -205 FOR ADDITIONAL DETAILS ** Printed 11/14/2011 1:58:56PM TREE = . 4 CIW SAFETY NOTES: W ELL AWE > 70° @ 12972' * ** , WELLHEAD = F MC 102 CHROME TBG * ** CAUTI 2 SWS RADIOACTIVE i PJC DRAFT ACTUATOR = LEO SOURCES P&A'd d 10/04/00 w/ RED CMT TO PB 8017 MD KB. ELEV = 64.2' /4655' TVD. 1) 8564' MD/4882' TVD -2.0 CURIE CS -137. BF. ELEV = 1 2) 8531' MD/4867' TVD -4.0 CURIE AM - 241 ** DO NOT j KOP = 1400' 20" CONDUCTOR, J 110' RE -ENTER WELL BELOW PB DEPTH BEFORE CALLING Max Angle = 93° @ 00' S S I - - U.S. NUCLEAR REG COMMISSION & AK DEPT OF O &G ** ' Datum MD = 1172 91.5 #, H-40, Y Datum TVD = 6700' SS ID = 19.124" ' ' L 2206' 1-14-1/2" HES X NIP, ID = 3.813" I : 110 -3/4" TAM PORT COLLAR H 982' GAS LIFT MANDRELS 17" PORT COLLAR H 2185' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 1 10 -3/4" CSG, 45.5 #, K- 55 -BTC, ID = 9.95" H 4816' 4 5830 3740 67 KBG -2 -LS DOME INT 16 11/20/03 I7" PORT COLLAR H 6992' 1---= L 3 9052 5247 53 KBG -2 -LS DOME INT 16 11/20/03 2 10429 6084 54 KBG -2 -LS DMY INT 0 04/15/10 I4 -1/2" NDPG -C GAUGE MANDREL, ID = 3.958" H 11212' 1-1 1 11136 6505 53 KBG 2 LS EMPTY INT - 08/13/11 1 1 1 11287' H 4- 112 "HESX NIP, ID = 3.813" Minimum ID = 2.377" @ 13272' S • 3- 3/16" X 2-7/8" XO g'I 11316' 1-17" X 4 -1/2" HES TNT PKR, ID = 3.856" I 1 III 11351' 1-14-1/2" HES X NIP, ID = 3.813" , 11421' H4-1/2" HES XN NIP, ID = 3.725" E 4 -1/2" TBG, 12.6 #, 13CR -85 VAM TOP, -1 11447 I- \ / I , .0152 bpf, ID = 3.958" 11446' H 4 -1/2" X 3 -1/2" XO, ID = 2.972" I I4 -1/2" TBG STUB (09/20/11) 1-1 11520' ∎M 11524' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 11543' H 7.40' TIEBACK SLV, ID = 5.25" I !TOP OF 4 -1/2" LNR 1-1 11543' I 11547' I--I4 -1/2" HES X NIP, ID = 3.813" I 4-1/2" TBG, 12.6 #, L -80 IBT, I 11558' 11550' 1-17' X 5" BKR LTP, ID = 4.406" I .0152 bpf, ID = 3.958" 11557' H 7" X 4 -1/2" BKR HMC HGR, ID = 3.938" I 7" CSG, 29 #, L-80-BTC-M, 11717' 11559' IH 4 -1/2" WLEG, ID= 4.00" I .0371 bpf, ID = 6.182" 11553' H ELMD TT LOGGED 12/12/00 I 3 -1/2" TBG, 9.3 #, 13CR -80 STL -1 12690' I - ft .0087 bpf, ID = 2.972" \ 4 -1/2" WHIPSTOCK (10/26/03) -1 12827' • D "-.......-1 12264' H HES TYPE H CEMENTER, MILLED TO 3.80" (10 /8/03) 1 w/ RA TAG @ 12836' I . 1 1 12267' H 4 -1 /2 "BKR CTC EXTERNAL PKR, ID = 3.875" 4 -1/2" SLTD LNR, 12.6 #, L -80 IBT, -12827 I I .0152 bpf, ID = 3.958 I 12720' I- I3 -1/2" HALF MULESHOE, ID = 3.00" I ► ■ PERFORATION SUMMARY r � ■ 12737' H 3 -1/2" BKR DEPLOY SLV, ID = 3.00" I 40 • REF LOG: PDS JEWELRY LOG ON 12/11/00 � 12740' - I3 -1/2" x 3- 3/16" XO, ID = 2.786" ( ANGLE AT TOP PERF: 73° @ 11660' Note: Refer to Production DB for historical perf data MILLOUT WINDOW (S- 102L1) 12827' - 12833' SIZE 1 SPF 1 INTERVAL 1 Opn /Sqz 1 DATE SEE PAGE 2 FOR PERFORATION DATA 1 I 13272' H 3- 3/16" X 2 -7/8 XO, ID = 2.377" I I 0---1 14430' I- 12-7/8" WFD CIBP (12- 2206) 1 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf ID = 2.805" I 13272' I� 1 7 7 H FISH - KO TOOL SPRINGS 11/19/03 I PBTD H 14935' ? ? -I3 IBP ELEMENTS (03/14/04 I 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" I 14968' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 10/24/00 COMPLETION WELL: S -102L1 11/05/03 TMN/TLP CTD SIDETRACK (L1) PERMff No: 2001290 , 2031560 10/31/11 D-16 RWO API No: 50- 029 - 22972 -01.60 11/13/11 PJC DRLG DRAFT CORRECTIONS SEC 35, T12N, R12E, 828' FNL & 781' FWL ' { . BP Exploration (Alaska) OPERABLE: S -102 (PTD #2001290) Passing MiiIA post rig workover Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, November 13, 2011 10:36 PM z rt f 1f To: AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Schultz, Kirsten L; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Walker, Greg (D &C); Olson, Andrew Subject: OPERABLE: S -102 (PTD #2001290) Passing MIT -IA post rig workover Attachments: S- 102.pdf; S -102 TIO 11- 13- 11.doc All, Producer S -102 (PTD #2001290) passed an MIT -IA to 4000 psi on 10/31/11 after a rig workover was completed to repair TxIA communication by swapping out the tubing and running a new packer. The passing test confirms two competent barriers and the well is reclassified as Operable. Attached are wellbore schematic and TIO plot for reference. «S- 102.pdf» «S -102 TIO 11- 13- 11.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells NO4t4Y ' . - = U Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 11/15/2011 f . PBU S -102 PTD #2001290 11/13/2011 TIO Pressures Plot welt Una j 1 I 4) b 3.000 i --0— TIN • — IA i 2.000 OA MA + OOOA —On I t.noo A ; INNINNiiiiiiii . , , 1 �7 1 . .. _ _. . • 1 00 /13111 00 /20 /7t O8/27 /11 09/03/I1 09 110/ll O$ /17 /11 O5/24 /11 10101 /11 10/00 /11 � t0 / % tl • 10/22/11 10125 /11 ti /1t 11/ 12/11 ' 1110 TREE"" . 4 CIW SAFETY NOTES: WELL 111V > 70° @ 12972' *** WELLHEAD = FMC ACTUATOR = PJC DRAFT P- 1 02 CHROME TOG*** CAUTI SWS RADIOACTIVE - KB. ELEV = - 64.2' Ll SOURCES P&A'd 10/04/00 w/ RED CMT TO PB 8017' MD /4655' ND. 1) 8564' MD/4882' ND -2.0 CURIE CS-137. BF. ELEV = - II 2) 8531' MD/4867' TVD -4.0 CURIE AM - 241 ** DO NOT WOP = Taiiii' Max Angle = @ 1249T 20" CONDUCTOR, --1 110' RE-ENTER WELL BELOW PB DEPTH BEFORE CALLING ..... ... , U.S. NUCLEAR REG COMMISSION & AK DEPT OF O&G ** Datum MD = 11724' 91.5#, H-40, T _ Datum TV D= 6700' SS ID = 19.124" I 1 , I 2206' H4-1/2" HES X NIP, ID = 3.813" [10-3/4" TAM PORT COLLAR I-1 982' GAS LIFT MANDRELS [7" PORT COLLAR H 2185' 11/)' 111 ST MD ND DEV TYPE VLV LATCH PORT DATE 1 10-3/4" CSG, 45.5#, K-55-BTC, ID = 9.95" f-i , 4816' 4 5830 3740 67 KBG-2-LS DOME INT 16 11/20/03 L - 3 9052 5247 53 KBG-2-LS DOME INT 16 11/20/03 17" PORT COLLAR I-1 6992' I---= L - 2 10429 6084 54 KBG-2-LS DMY INT 0 04/15/10 1 11136 6505 53 KBG-2-LS EMPTY INT - 08/13/11 14-1/2" NDPG-C GAUGE MANDREL, ID = 3.958" H 11212' 1--411 1 1 , 11287' I-I4-1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.377" @ 13272' .2K 3-3/16" X 2-7/8" XO 1 1 1316' I-I X 4-1/2" HES TNT PKR, ID = 3.856" I Ill 'i 1 1351' H4-1/2" HES X NIP, ID = 3.813" I II 1 1421' H4-1/2" HES XN NIP, ID = 3.725" I 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, -I 11447' -..,„.......1 .0152 bpf, ID = 3.958" 11446' H 4- 1 / 2" X 3-1/2" XO, ID = 2.972" I 14-1/2" TBG STUB (09/20/11) H 11520' 1 2 d 2K- 11524' H 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 11543' I-I 7.40' TIEBACK SLV, ID"" 5.25" 1 TOP OF 4-1/2" LNR I-I 11543' I L a I 11547' H 4- 1 / 2" HES X NIP, D = 3.813" 1 4-1/2" TBG, 12.6#, L-80 IBT, --I 11558' : : 11550' I-I 7' X 5" BKR LTP, ID = 4.406" I .0152 bpf, ID = 3.958" 1 1 1557' H7" X 4-1/2" BKR HMC HGR, ID = 3.938" I 7" CSG, 29#, L-80-BTC-M, H 11717' 11559' H 4-1/2" WLEG, ID = 4.00" I .0371 bpf, ID = 6.182" , I 11553' I-I ELMD TT LOGGED 12/12/00 I 3-1/2" TBG, 9.3#, 13CR-80 STL --1 12690' I a _ .0087 bpf, ID = 2.972" ...... „...A 12264' 1--I HES TYPE H CEMENTER, MILLED TO 3.80" (10/8/03) I 4-1/2" WHIPSTOCK (10/26/03) ---1 12827' • 0 WI RA TAG @ 12836' 12267' J-I4-1/2"BKR CTC EXTERNAL PKR, ID = 3.875" I 4-1/2" SLTD LNR, 12.6#, L-80 IBT, -12827 l N i .0152 bpf, ID = 3.958" . i 1 12720' I-13-1/2" HALF MULESHOE, ID = 3.00" I . •. 12737' 1-13-1/2" BKR DEPLOY SLV, ID = 3.00" PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 12/11/00 40 to 12740' I-13-1/2" x 3-3/16" XO, ID = 2.786" 1 ANGLE AT TOP PERE: 73° @ 11660' ■ Note: Refer to Production DB for historical perf data MILLOUT WINDOW (S-102L1) 12827' - 12833' SIZE I SPF I INTERVAL I Opn/Sqz j DATE , SEE PAGE 2 FOR PERFORATION DATA ( s'---'------ 13272' H 3-3/16" X 2-7/8 X0, ID = 2.377" I I I I I I 0---1 14430' 1-12-7/8" WFD CIBP (12-2206) I 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf ID = 2.805" 1--1 13272' I I ? ? I-I FISH - KO TOOL SPRINGS 11/19/03 1 I PBTD I-I 14935' 1Q-------- ? ? H 3 IBP ELEMENTS (03/14/04 I 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I 14968' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 10/24/00 COMPLETION WELL: S-102L1 11/05/03 TM N/TLP CTD SIDETRACK (L1) PERMIT No: 2001290 , 2031560 10/31/11 0-16 RWO API No: 50-029-22972-01.60 11/13/11 PJC DRLG DRAFT CORRECTIONS SEC 35, T12N, R12E, 828' FNL & 781' FWL _ BP Exploration (Alaska) 1-102 • L VIIMEM OWE I 1 1 I I I ■ . L PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 12/11/00 ANGLE AT TOP PERF: 73° @ 11660' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 11660 - 11680 0 08/11/11 3 -3/8" 6 11680 - 11700 0 01/21/01 2 -7/8" 6 11690 - 11710 0 12/22/06 1 1 3 -3/8" 6 11716 - 11736 0 01/21/01 SLTD LNR 13284 - 14384 0 1 /02/03 SLTD LNR 14475 - 14935 C; 11/02/03 # � • • II II 1 DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 10/24/00 COMPLETION WELL: S -102L1 11/05/03 TMN/TLP GTD SIDETRACK (L1) PERMIT No: 2001290 , 2031560 10/31/11 D-16 RWO API No: 50 -029- 22972 -01.60 11/13/11 PJC DRLG DRAFT CORRECTIONS SEC 35, T12N, R12E, 828' FNL & 781' FWL BP Exploration (Alaska) • Page 1 of 1 Schwartz, Guy L (DOA) S- r `a Z From: Crisp, John H (DOA) V) 2- Sent: Wednesday, October 26, 2011 11:24 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: Secondary Well control usage Just got a call from John Rall (filling in for BPX Drilling Superintendents) PBU S -102 workover. Drilled /6/2,0( plug above production perrs & then bullheaded 50 bbls 9.8 brine into production zone. Opened up & well flow — shut in with 100 psi both sides. They will send in well control equipment usage report. Annular preventer used for this work, no rams above mud cross — BPX policy. Seems as if they are going to weight up from 9.8 to 10.2 ppg for workover fluids. Fluid loss to formation reported while CBU after bullhead has occurred. Rall stated any extreme changes would be reported to AOGCC immediately. Good luck to them. 12/2/2011 BOPE usage report: Doyon Rig 16: S -102 Wo1ver • Page 1 of 1 Regg, James B (DOA) From: Rall, John R [RalIJR2 @BP.com] Sent: Wednesday, October 26, 2011 11:38 AM it y To: DOA AOGCC Prudhoe Bay PIT Z0d _/ Z'( Cc: Daniel, Ryan; Kilfoyle, Jeffery A; McMullen, John C; Reem, David C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Schultz, Mikel; Willingham, James M; AK, D &C Rig 16 Well Site Leader Subject: BOPE usage report: Doyon Rig 16: S -102 Workover Attachments: 10 -26 -2011 BOPE usage S- 102.doc «10 -26 -2011 BOPE usage S- 102.doc» John Rall Wells Operations Superintendent Office: 659 -4618 Cell: 907 - 980 -2589 11/4/2011 . • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. I0'1 I Field Superintendent Name: John Rall Wellsite Leader Name:Anthony Knowles /Rick Dolfi Contact Number: 659 -4618 Contact Number: 659 -4177 Traction Number: Pending Well Location & Name: S -Pad Well 102 Permit To Drill (PTD) Number: 200 -1290 Date and Time of Incident: 10/25/2011 , 20:00 Original Scope of Work: Milled through composite bridge plug at 11,528'. POOH to above the tubing stub at 11,510'. Shut in annular preventer, bullhead 50 -bbls of 9.8 -ppg brine, 7 BPM, 690 -psi. Shut down the pump, SIDPP 100 -psi SICP 100 -psi. Operational Description Leading up to Well Control Event: Monitor well for flow through bleeder on choke, 8 -bbls retu Shut in and monitor pressure, SIDPP 50 -psi, SICP 50 -psi. CBU through the choke, at bottoms up no indication of gas or contamim fluid. 5 -bpm, 1,670 -psi, dynamic loss rate 90 -bph. Total loss 117 -bbl. Shut down monitor well through a closed choke. Bleed 10 -bbl. Shut in and monitor SIDPP 40 -psi, SICP 40 -psi. Repeat the process in 10 -bbl increments total fluid bled off 38- bbls. No reduction in SIDPP 40 -psi, SICP 40 -psi. Shut in and monitor pressure, prepare to weight up. Well is currently shut in with SIDPP -40 psi and SICP 50 psi BOPE Used and Reason: The Annular Element is closed. Because the well is shut in with SIDPP of 40 psi an( SICP Of 50 psi Is a BOPE Test Required after use ( Yes / No): If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Is to weight up from 9.8 ppg brine to a 10.2 ppg brine. Two 290 -bbl vac trucs with 10.4 -ppg fluid en route. Dry products to weight up the active pit system en route. Additional Comments: We will do a complete BOPE test when we are out of the hole. This will suffice for the re -test of the equipment we used for shut in and for our weekly test due on Fri 28 of Oct. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.prudhoe.bav(�alaska.gov Email CC List BP WSL RWO Supt Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer- Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC August 2, 2010 HRE 1 STATE OF ALASKA • ' ALASKADAND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ -- 200 -1290 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 22972 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: _ ADLO- 028256 S -102 10. Field /Pool(s): PRUDHOE BAY FIELD / AURORA OIL POOL 11. Present Well Condition Summary: Total Depth measured 13488 feet Plugs (measured) 12827 (WHIP) feet true vertical 6787.46 feet Junk (measured) None feet Effective Depth measured 12827 feet Packer (measured) 11524 11543 12266 feet true vertical 6748.38 feet (true vertical) 6701 6708 6766 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 29 - 109 29 - 109 1490 470 Surface 4791' 10 -3/4" 45.5# K -55 27 - 4818 27 - 3315 3580 2090 Production 11693' 7" 29# L -80 26 - 11719 26 - 6763 8160 7020 Liner 1557' 4 -1/2" 12.6# L -80 11543 - 13100 6708 - 6749 8430 7500 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - = st� +r - True Vertical depth: :_ ,'r 0 , ';,' li ' t AUG ' L U Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 11559 23 - 6714 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 11524 6701 4 -1/2" Baker ZXP Packer 11543 6708 4.5" Baker CTC Packer - ":' a 6766 K� 4 12. Stimulation or cement squeeze summary: AUG 2 9 2'n Intervals treated (measured): sumassion Treatment descriptions including volumes used and final pressure: MO' 8 0? ' & G8$ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 159 2640 118 205 Subsequent to operation: 14. Attachments: 15. Well Class after work: _ Copies of Logs and Surveys Run Exploratory Development eg Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil f Ei Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - •e Lastufk* 1 Title Petrotechnical Data Technologist Signature �1] - Phone 564 -4091 Date 8/29/2011 - RBDM AUG 29 1� 1.30. It Form 10 -404 Revised 10/2010 /OA Submit Original Only S -102 200 -129 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 5-102 10/24/00 SL 12,312. 13,100. 6,764.12 6,749.3 S -102 1/21/01 APF 11,680. 11,700. 6,751.77 6,757.51 S -102 1/21/01 APF 11,716. 11,736. 6,762.01 6,767.29 S -102 1/21/01 OH 13,100. 13,488. 6,749.3 6,787.46 S -102 7/8/01 FIL 11,843. 13,100. 6,776.34 6,749.3 1 S -102 10/7/03 FCO 11,843. 11,850. 6,776.34 6,776.12 ,8 27. 13 488. 6 748.38 6 787.46 S -102 10/26/03 BPS 12 S -102 12/22/06 APF 11,690. 11,710. 6,754.65 6,760.33 S -102 12/22/06 APF 11,660. 11,680. 6,746.01 6,751.77 S -102 10/3/08 BPS 12,200. 12,827. 6,767.33 6,748.38 S -102 4/15/10 BPS 11,542. 12,200. 6,707.88 6,767.33 S -102 8/2/11 BPP 11,542. 12,200. 6,707.88 6,767.33 • S -102 8/6/11 BPP 11,220. 12,827. 6,555.61 6,748.38 S -102 8/7/11 APF 11,660. 11,680. 6,746.01 6,751.77 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • S -102 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AcT 8/7/2011 `. CTU #9 1.75 "CT Objective: Pull WRP, AdPerf « <Cont from 8/6/11>>> RIH w/ PDS memory GR/CCL in 2.2" carrier and 3.40" DJN. Tag 3.5" liner top at s 12,743'CTM. Log GR/CCL from 12,743' to 11,347'CTM at 40 fpm. Paint flag at '11,800'CTM. POOH. Confirmed good data. RIH w / CBF firing head & gun 2 7/8" x j 20' HSD - PJ02906 - HMX 6 SPF gun. Shot perfs at 11660' to 11680',. Freeze protect i ;well w / 38 bbls of 50/50 methanol. At surface confirmed guns fired ball has been I recovered. RDMO « <Job Complete »> FLUIDS PUMPED BBLS 60 1% KCL 60 TOTAL KB. ELEV = 64.2' 1 0 z * SAFETY * ON S RADIOACTIVE SOURCES P &A'd KOP = 1400' L 1 & L2 OP = 10/04/00 w/ RED CMT TO PB 8017' MD /4655' TVD. 1) Max Angle = 94° @ 13653' 8564' MD/4882' TVD -2.0 CURIE CS -137. 2) 8531' Datum MD = 11724' I 1 MD/4867' TVD -4.0 CURIE AM - 241 ** DO NOT RE- Datum TVD = 6700' SS ENTER WELL BELOW PB DEPTH BEFORE CALLING U.S. 120" CONDUCTOR, 91.5 #, H - 40, ID = 19.124" I 110' NUCLEAR REG COMMISSION & AK DEPT OF O &G ** 10 -314" TAM PORT COLLAR H 982' 2515' 1-14 -112" HES X NIP, ID = 3.813" J 17" PORT COLLAR 1-1 2185' 1 GAS LIFT MANDRELS 10 -3/4" CSG, 45.5 #, K -55 -BTC, ID = 9.95" 1-1 4816' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 5783 3721 65 KBG -2 -LS DOME INT 16 11/20/03 I7" PORT COLLAR I — I 6992' 1--= 3 9818 5715 52 KBG -2 -LS DOME INT 16 11/20/03 MP 2 11161 6520 53 KBG -2 -LS DMY INT 0 04/15/10 1 11395 6648 64 KBG -2 -LS EMPTY INT - 08/13/11 Minimum ID = 2.377" @ 13272' 3-3/16" X 2 -7/8" XO 11503' H4 -1/2" HES X NIP, ID = 3.813" I � ��� 11524' I — 1 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I (TOP OF 4 -1/2" LNR 1-1 11543' I I 11543' 1— I7.40' TIEBACK SLV, ID = 5.25" 11547' I— I4 -1/2" HES X NIP, ID = 3.813 ", il 11550' H7' X 5" BKR LNR TOP PKR, ID = 4.406" I 4 -1/2" TBG, 12.6 #, L -80 BTC-M, 11558' 1 .0152 bpf, ID = 3.958" 11557' 1 X 4-1/2" BKR HMC HGR, ID = 3.938" I y i 11559' H4-1/2" WLEG, ID = 4.00" I 1 11553' 1 — I ELMD TT LOGGED 12/12/00 I 7" CSG, 29 #, L- 80- BTC -M, — 11717' I - 4 , .0371 bpf, ID= 6.182" , 12264' I — HES TYPE H CEMENTER * MILLED TO 3.80" (10/08/03) • • I4 -1/2" WHIPSTOCK (10/26/03) H 12827' ∎, .7, 12267' j — I4 - 1/2 "BKR CTC EXTERNAL PKR, ID = 3.875" ( 1 I IRA PIP TAG I—I 12836' N I �. 12737' H3 -1/2" BKR DEPLOY SLV, ID = 3.00" I PERFORATION SUMMARY *A I 12740' H3-1/2" x 3-3/16" XO, ID = 2.786" I REF LOG: PDS JEWELRY LOG ON 12/11/00 • � ANGLE AT TOP PERF: 73° @ 11660' `..� �b�. O MILLOUT WINDOW (S-102L 1) 12827' - 12833' Note: Refer to Production DB for historical pert data ���� ( ) SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 11660 - 11680 0 08/11/11 i 1 1 13272' H3-3/16" x 2-7 / 8 x 0, ID = 2.377" I 3 -3/8" 6 11680 - 11700 O 01/21!01 I 1 1 14430' — I2 -7/8" WFD CIBP (12 -2206) 3 2 -718" 6 11690 - 11710 O 12/22/06 • ����� 3 -3/8" 6 11716 - 11736 O 01/21/01 � � � N • • ? ? -I FISH - KO TOOL SPRINGS 11/19/03 SLTD LNR 13284 - 14384 0 11/02/03 ' ∎!*• • ■• SLTD LNR 14475 - 14935 C 11/02/03 ? ? —I3 IBP ELEMENTS (03/14/04 1 • • • • 14935 ' I 1 4-1/2" SLTD LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 1 13100' ♦ PBTD I3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf ID = 2.805" 3—I 13272' I 12 -7/8" LNR, 6.1611, L -80 STL, .0058 bpf, ID = 2.441" I 14968' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 10/24/00 COMPLETION 08/14/11 CDJ/ PJC PULL PLUGS (8/2/11) WELL: S- 102L1& 12 11/05/03 TMN/TLP CTD SIDETRACK (L1) 08/14/11 JJL/ PJC REPERF (8 /11/11) PERMIT No: 2001290 , 2031560 10/18/08 RRK /PJC SET WRP (10 /03/08) 08/15/11 GJB/ PJC GLV C/O (8 /13/11) API No: 50- 029 - 22972 -01.60 02/04/10 PJP /PJC DRAWING CORRECTIONS SEC 35, T12N, R12E, 827' FNL & 780' FWL 04/22/10 CJN/SV GLV C/0 & SET I 1 P(04/15/10' 04/08/11 RCT /PJC PULL/ RESET PX (04/02/11) BP Exploration (Alaska) UNDER EVALUATION: 5-102 (PTD #2001290) Sustained IA Casing Pressure - TxIA comet Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] `P~l ~~~~'~~ Sent: Wednesday, March 24, 2010 3:41 PM ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Phillips, Patti J; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-102 (PTD #2001290) Sustained IA Casing Pressure - TxIA comet Attachments: S-102 TIO Plot 03-24-10.doc; S-102.pdf All, Producer S-102 (PTD #2001290) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to SSV/2020/0 on 0. TIFL ailed on 03/22/10 confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while work is conducted to attempt to restore integrity. A TIO plot and wellbore schematic have been included for reference. «S-102 TIO Plot 03-24-10.doc» «S-102.pdf» Please let me know if there are any questions. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 3/25/2010 PBU 5-102 PTD 2001290 3/24/2010 TIO Pressures Plot Well= S-102 ~.n~n 3,00E 2.000 1,000 -#- T bg -F IA -~ OA OOA OOOA On 12/25/09 01102110 01 /09110 01 ~'1 611 0 01 12311 0 01(30110 0210G110 02113x'10 02!20!1 0 0212711 0 0310011 0 0311 311 0 03!20!10 KB. ELEV = 64.2' BF. ELEV = ..u ~~. . . KOP- -".~`.9- ~_ _ 1400' IViax Angle = __. __ 94- (a7 13e53` _ Datum MD = i 1 !24` Datum TVD = 6700' 5S S-102L1 SAFETY NOTES: W ELL ANGLE , 70° @ 12972'. *** CAUTION: 2 SWS RADIOACTIVE SOURCES P&A'd 10!04!00 w! RED CMT TO PB 8017' MD /d655' ND. 1) 8564' MDl4882' ND -2.0 CURIE CS-137. 2) 8531' MDI4867' ND -4.0 CURIE AM - 241 ** DO NOT RE- ENTER WELL BELOW PB DEPTH BEFORE CALLING U.S. NUCLEAR REG COMMISSION & AK DEPT OF O&G ** 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" ~-~ 110' 10-314" TAM PORT COLLAR 982' 7" PORT COLLA ~ 2185' J 10-3/4" CSG, 45.5#, K-55-BTC, ID = 9.95" 4816' 7" PORT COLLA~ 6992' Minimum ID = 2.377" @ 13272' 3-3/18" X 2-7/8" XO TOP OF 4-112" LNR 11543' 4-1/2" TBG; 12.6#, L-80 BTGM, 11558' .0152 bpf, ID = 3.958" 7" CSG, 29#, L-80-BTGM. 11717' .0371 bpf, ID = 6,182" 3.69" WRP(10/03/O8) 12198' 4-112" WHIPSTOCK (10126!03) 12827' RA PIP TAG 12836' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 12/11/00 ANGLE AT TOP PERF: 73° @ 11660' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8'" 6 11660 - 11680 O 12!22/06 3-3/8" 6 11680 - 1 i 700 O 01!21101 2-718" 6 11690 - 11710 O 12122/06 3-318" 6 11716 - 11736 O 01121 /01 SLID LNR 13284 - 14384 C 11(02103 SLTD LNR 14475 - 14935 C 11!02/03 2515' ]-~4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD 7VD DEV TYPE VLV LATCH PORT DATE 4 5783 3721 65 KBG-2-LS DOME INT 16 11/20/03 3 9818 5715 52 KBG-2-LS DOME INT 16 11/20/03 2 11161 6520 53 KBG-2-LS S!O INT 24 11!20/03 1 11395 6648 64 KBG-2-LS *DMY INT 0 09118/03 `S I H ~F 1 = UMY FW 5 CX I h_NUCU F't~Ci UN I UF' 24 k5 I M 5 I H (:KS 11503° ~-~ 4-1 /2" HES X NIP, ID = 3.813" 11524' ~-~ 7" X 4-112" BKR S-3 PKR, ID = 3.875" 11543' 7.40' TIEBACK SLV, ID = 5.25" 4-112" HES X NIP, ID = 3.813" 7' X 5" BKR LNR TOP PKR, ID = 4.406" 7" X 4-112" BKR HMC HGR, ID = 3.938" 11559' - j 4-112" W LEG, ID = 4.00" 11553° ELMD TT LOGGED 12/12(00 12~2~ HES TYPE H CEMENTER ' MILLED TO 3.80" (10!08/03) 14-1/2'BKR CTC EXTERNAL PKR, ID = 3.875" I 3-112" BKR DEPLOY SLV, ID = 3.00" 12740' ~-~ 3-112" x 3-3116" XO, ID = 2.786" MILLOUT WINDOW {S-102L1) 12827 - 12833' ~ I \ ~ 13272' ~-'~ 3-3(16" X 2-718 XO, ID = 2.377" 1~ '_" --- I I ~ 14430' 2-718" WFD CIBP (12-2206) ~ ~ ? ? FISH - KO TOOL SPRINGS 11119/03 ~ ~ ? ? - 3 IBP ELEMENTS (03114!04 ~ ~ ~` ` ' 4-1/2" SLTD LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 13100' ~ 14935 PBTD 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf ID = 2.805" 13272' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 14968' DATE REV BY COMMENTS DATE REV BY COMMENTS 10124/00 COMPLETION 01!10107 JY/ PJC L1 CTD CORRECTIONS 11/05/03 TM WTL CTD SIDETRACK {L1} 10/1810$ RRK/PJC SET WRP (10!03108) 11/19!03 KSBITLP LOST 2 SPRINGS IN TBG (?) 11/20/03 JBNIlTLP GLV CIO 11/15/06 JLP/PJC FISH CORRECTION (03114/04) 12/22/06 DMS/PAG SET CIBP, ADPERFS AURORA UNfT WELL: S-102L1 PERMff No: 2031560 API No: 50-029-22972-01 SEC 35, T12N, R12E, 827' FNL & 7$0' FWL BP Exploration (Alaska} 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA _ ALAS . OIL AND GAS CONSERVATION COMM,.::>N REPORT OF SUNDRY WELL OPERATIONS D D o //Ø /-;? ¢.,,~ JAN 2 3 Z007 Alaska Oil & Gas Cons. Commissio P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P / Stratigraphic Stimulate D Other D WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 200-1290 J 3. Address: Exploratory Service 6. API Number: 50-029-22972-00-00·" 9. Well Name and Number: 64.2 KB I S-102 ( 10. Field/Pool(s): PRUDHOE BAY Field/ AURORA OIL Pool I 8. Property Designation: ADLO-028256 I 11. Present Well Condition Summary: Total Depth measured true vertical 13488/ 6788 } feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 13100 feet true vertical 6749 feet Casing Length Size MD TVD Burst Conductor 80' 20" 91.5# H-40 29' - 109' 29' - 109' 1490 Surface 4789' 10-3/4" 45.5# K-55 27' - 4816' 27' - 3315' 5210 Production 11655' 7" 29# L-80 26' - 11719' 26' - 6763' 8160 Liner 1557' 4-1/2" 12.6# L-80 11543' - 13100' 6708' - 6749' 8430 Collapse 470 2480 7020 7500 SCANNED JAN 2 5 2007 Perforation depth: Measured depth: 11660' - 13100' True Vertical depth: 6745' - 6810' - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 23' - 11559' Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 4.5" Baker CTC Packer o 11524 11543 12266 o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 37 389 0 44 484 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P' Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 19 28 Tubing pressure 418 214 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x Contact Gary Preble WINJ WDSPL Title Data Engineer Signature Phone 564-4944 Date 1/17/2007 Form 10-404 Revised 04/200D R 2 9 2007 kV)r) Submit Original Only . . S-102 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/20/2006 CTU #5 ***Job Scope Set CIBP/Add Perfs*** Standy by on rig up ...Continue job on 12/21/2006... 12/21/2006 CTU #5 ***Job Scope Set CIBP/Add Perfs*** Sim Ops discussion with WSL on Rig 7ES in relation to spacing between CTU 5 and Rig camp. The spacing is in with 2006 ASH RIH w. SWS logging tools in 2.2" carrier - Set down at 14490' - Log up at 60 fpm to 10300' - paint flags at 14400' and 11610'- POH verify log data ..., +14' correction, RIH w. 2 7/8" CIBP ...Continue job on 12/22/2006... 12/22/2006 #5 Job Scope set Perfs ***Contiue job from 1 RIH w. 2 7/8" CIBP set @ 14430' center of element. Add Perfs w. 2 7/8" PJ Omega, HMX 6 SPF 60* Phasing under balanced, 1st gun shot at 11690'-11710', good surface indication of gun fired with well flowing at 290 WHP- POH- Gun had partial detonation splitting case and 31 out of 124 shots mis-fired - MU/RIH with gun #2 and perf interval 11660' - 11680' - good surface indication gun fired with well flowing at 400 WHP - POH - all shots fired. RD CTU and left well flowing. *** Job complete*** FLUIDS PUMPED BBLS 136 60/40 METHANOL 98 DIESEL 234 TOTAL F:\LaserFiche\CvrPgs _I nserts\M icrofi I m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,....-.. ,~.Ir'!"'¡·'· ¡:~~., I . ". ~;! ." .... Þ;;.,.. \~" ¡" ) ) ~ r-.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~ 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool 0 4. Current Well Class: Perforate 0 WaiverD Stimulate ŒI Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-1290 OtherD Name: BP Exploration (Alaska), Inc. Development Œ] Stratigraphic D 9. Well Name and Number: S-102 10. FieldlPool(s): Prudhoe Bay Field / Aurora Oil Pool ExploratoryD ServiceD 6. API Number 50-029-22972-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.20 8. Property Designation: ADL-o028256 11. Present Well Condition Summary: Total Depth measured 13488 feet true vertical 6787.5 feet Effective Depth measured 13100 feet true vertical 6749.3 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 109 29.0 - 109.0 1490 470 Liner 1557 4-1/2" 12.6# L-80 11543 - 13100 6708.2 - 6749.3 8430 7500 Production 11693 7" 29# L-80 26 - 11719 26.0 - 6762.8 8160 7020 Surface 3 10-3/4" 45.5# L-80 27 30 27.0 - 30.0 5210 2480 Surface 952 10-3/4" 45.5# K-55 30 982 30.0 - 981.2 3580 2090 Surface 3 10-3/4" 45.5# L-80 982 985 981.2 - 984.2 5210 2480 Surface 3745 10-3/4" 45.5# K-55 985 . 4730 984.2 - 3276.8 3580 2090 Surface 2 10-3/4" 45.5# L-80 4730 - 4732 3276.8 - 3277.6 5210 2480 Surface 83 10-3/4" 45.5# K-55 4732 . 4815 3277.6 - 3314.0 3580 2090 Surface 3 10-3/4" 45.5# L-80 4815 - 4818 3314.0 - 3315.3 5210 2480 Measured depth: 11680 -11700,11716 -11736,12312 -13100 True vertical depth: 6751.77 - 6757.51,6762.01 - 6767.29, 6764.12 - 6749.3 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 23 11559 RECEIVED APR 1 4 2004 A\aska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 4.5" Baker CTC Packer @ 11524 @ 11543 @ 12266 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11680' -11736' Treatment descriptions including volumes used and final pressure: 75 Bbls 15% DAD Acid @ 3540 psig Representative Dailv Averaae Production or Iniection Data Gas-Me! Water-Bbl Casing Pressure 1.6 3925 1530 13 817 2.9 4405 1480 Tubing Pressure 276 377 Prior to well operation: Subsequent to operation: Oil-Bbl 777 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development 00 ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron ::;::,:ome GjJ :; ~ Form 10-404 Revised 12/2003 0 ~ I GIN A Choo' 564';;' BFL Date 4/12/04 APR 1 4 200~ ~ ",......, ~ S-102L1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/13/04 PUMP 150BBLS HOT CRUDE DOWN TBG FOR CTU. 03/13/04 MEM PPROF, SET IBP, ACID. CTU #9. CONTINUED FROM 3/12/04 WSR. MU AND RIH WITH 3 3/8" IBP. PUMP 150 BBLS HOT CRUDE DOWN TUBING. POSITION COE AT 11900', PUMP BALL TO SEAT, WAIT 3 HRS FOR TEMPERATURE STABILIZATION. SET IBP @ 14955', PUT WELL IN TEST AND POOH. LAY DOWN RUNNING TOOLS, MU PULLING TOOLS AND WAIT FOR WELL TO STABILIZE. FINAL RATE 280 BOPD, 0 BWPD, 0.7 MMSCF/D, AL 2.4 MMSCF/D. RIH W/SURE CATCH AND FLUID PACK WELL WITH FILTERED 1 % KCL. PERFORMED INJECTIVITY TEST W 60/40 DOWN COIL WHILE PARKED AT 11,600': INJECTIVITY: 1.5 BPM @ WHP 738 PSI. ACIDIZE PERF INTERVAL 11680' - 11736' W/ 75 BBLS 15% DAD, OVERFLUSH WITH 75 BBLS HOT DIESEL. PULL IBP AND POOH. NOTIFY PCC AND PAD OP. PUT WELL BOL. 03/14/04 CTU #9: MEM PPROF, SET IBP, ACID. CONTINUED FROM 3/13/04 WSR. POOH WITH IBP. RECOVERED IBP, BUT MISSING ALL 3 RUBBER ELEMENTS. PAD OP PUT WELL BOL. RDMO LEFT WELL FLOWING. FLUIDS PUMPED BBLS 141 169 150 77 75 612 60/40 Methonal 1 % KCL Crude 15% DAD Acid Hot Diesel TOTAL Page 1 ~ .' .~ 1"'""\ TREE = 4-1/16" - 5M erN OiROME W8..LI"EAD = 13-518" - 5M FWC SH AGrUATOR = BAKER KB. ELEV = 64.2' BE ELEV = KOP= Max Angle = Datum MD = DatumTVD = 8-1 02L 1 SAÆTY NOTES: CAUTION: 2 SWS RADIOACTIVE SOURCES P&A'd 10104/00 WI REDCMTTO PB8017'MD 14655'TVD. 1) 8564' MDI4882'TVD-2.0 CURlEC5-137. 2) 8531' MDl4867' TVD-4.0 CURIE AM - 241 ** DO NOT RE8IITER W B.L BB.OW P B DEPTH BEFORE CALUNG U.s. NUCLEAR REGULATORY COM MISSION & AK DEPT OF O&G ** 1400' 94 @ 13653' 11513' 6700' 55 4816' ~ [¡] = ---I 2185' 2515' H7" PORT COLLAR H4-1/2"XLANDNGNIP,ID=3.813" 1 - 10-3I4"CSG, 45.5#, K-55-BTC, ID =9.95" H 6 GAS LIFT MAN!:R8..S ST M) TVD DBI lYPE VLV LATOi FORf DATE 4 5783 3722 66 KBG-2-LS DOME INT 16 11/20/03 3 9819 5914 52 KBG-2-LS DOME INT 16 11/20/03 2 11161 6521 53 KBG-2-LS SlO INT 24 11/20/03 1 11395 6648 64 KBG-2-LS *DMY INT 09/18/03 *STA TON # 1 = DMY HAS EXT8'JDED A<G ON TOP & B1M STAO<S Minimum ID = 2.377"@ 13272" SLOTTED LINER [] - - I 6992' H7" FORf OOLLA R 1 ÆRFORA TION SUMMARY - - REF LOG: PDS JEN8..RY LOG ON 12/11/00 . I 11503' H4-1/2" x LANDING NIP, ID = 3.813" 1 ANGLE AT TOP ÆRF: 73 @ 11680' - IIbte: Refer to Production DB for historical perf dam Z Z 11524' H7" X4-1/2"BAKERS-3 A<R,/D =3.875" SIZE SPF INTER\! AL Opn/Sqz DATE 3-318" 6 11680-11700 0 01/21/01 8' ~ 11543' ~BAKER 5" X 7" LNR TOP PKR I 3-318" 6 11716 - 11736 0 01/21/01 . . W/Llf\ER liE-BACK SLEEVE SL TO LNR 13284 - 14383 0 11/02/03 SL TO LNR 14475-14935 0 11/02/03 . I 1154T H4-1/2" X LANDING NIp, ID = 3.813" 1 1 - 17" CSG, 29#, L-80-BTC-M, ID = 6.182" H 11717' - ~ ~. 11557' HBAKER 5" X 7" HMC HYDRAULIC I ILf\R HGR. ID = 3.938" H4-1/2" WLB3 HELM) TT LOGGED 12/12/00 1 11558' ~ 14-112" TOO, 12.6#, L-BO BTC-M, H .0152bpf,ID=3.958" I' 14-1/2"LNR,12.6#,L-80,.0152bpf,ID=3.958" I TOPOF4-1/2"SLTDLNR H 12312' I 11558' 11553' 81 12264' HHð.LLIBLRTONESTYÆHCe.1ENTER I 1* MILLED TO 3.80" DURING PRE-RIG WORK 1226T H4-1/2"BAKERCTCPKR, D =3.875" 1 1273T H3-1/2" BAKERDER..OYMENTSLV, D=3.000" I ITOPOFWHPSTOO< H 12827' I ~ I I I I I I I 13272' H3-3I16" X 2-718 XO 1 1 BOTTOM OF 4-1/2" SL TD LNR H 13100' 1 :: I PBTOH 13100' I j I '<\, ŒJi 13488' I ~'\ A " ':/ ? ? 13-3/16" LNR, 6.2#, L-80, .00764 bpf ID = 2.805" H 13272' I '~~, 2-7/8"SLTOLNR,6.16#,L-80,.00549bpf,D=2.377" H 14968' ~~ H2 SPRINGS LOST FROM I IGL KlCKOVER TOOL 11/19/03 14935' ~ DATE REV BY COMMENTS 7/4/1982 ORIGINAL COMPLETION 10/06/91 DSMC LAST WORK OVER 10/24/00 LAST COMPLETION 11/05/03 TM IflLP CTD SIŒTRACK 11/19/03 KSBlTLP LOST 2 SPRINGS IN TBG (?) 11/20/03 £M'TLP GLV C/O DUE RBI BY OOMMENTS AURORA um W8..L: S-1 02L 1 ÆRMITNo: 2031560 A PI No: 50-029-22972-00 SEC 35, T12N, R12E, 827' FNL & 780' FWL BP Exploration (Alaska) Permit to Drill 2001290 DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UN AURO S-102 Operator BP EXPLORATION (ALASKA) INC MD 13488 'rVD 6787 Completion Dat 10/24/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22972-00-00 UIC N · _ REQUIRED INFORMATION Mud Log N.__~o Sample N.._g_o Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Received Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH I Type Media Fmt Name Scale Media No Start Stop CH 818 13405 ~~2/22/2001 818 8635~f'-"Geseb~u~.J22/2001 ~GR/ROP/Res 2/5 ~ ~ I FINAL 874 8688 .C,H'~21/2001 ~T~/D GR/ROP/Res 2/5"~" ~ ~ .FINAL 874 8688 -F~10~""2/21/2001 9826-'''''~ FINAL 2/22/2001 LIS Verification FINAL 2/22/2001 9837/.-'''''~ FINAL 2/22/2001 LIS Verification FINAL 2/22/2001 LDWG LIS Listing 818 13405 CH 1/9/2001 LDWG LIS Listing 818 13405 1/9/2001 a3R/Res TVD 2/5 FINAL 874 13488 ~ ~1/9/2001 LDWG LIS 1/9/2001 JewelryLog FINAL 11295 11778 ~q4~,~1/3/2001 Dataset Number Comments 09837 -8~'8-13405 09826 ~18-8635 ~I~1 10291 '"~-1295-11778 874-8688 BL, Sepia 874-8688 BL, Sepia 9826"~LIS Verification Digital Data LIS~erification Paper Copy 9837/~LIS Verification Digital Data LIS Verification Paper Copy 818-13405 Digital Data 818-13405 Paper Report 874-13488 BL, Sepia 874-13488 BL, Sepia 874-12488 BL, Sepia 818-8635 Digital Data Lis Verification 11295-11778 Digital Data Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Permit to Drill 2001290 MD 13488 TVD Well Cored? Y / N Chips Received? Y / N Analysis Y / N R ~.r.~.iv~.d ? DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. PRUDHOE BAY UN AURO S-102 Operator BP EXPLORATION (ALASKA) INC 6787 Completion Dat 10/24/2000 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? Y / N Formation Tops '~/N APl No. 50-029-22972-00-00 UIC N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X(FRAC) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory_ Stratigraphic._ Service_ 4. Location of well at surface 827' FNL, 4499' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 4623' FNL, 4449' FEL, Sec. 22, T12N, R12E, UM At effective depth (asp's 618929, 5980656) (asp°s 613583, 5987337) At total depth 3191' FNL, 296' FEL, Sec. 21, T12N, R12E, UM (asp°s 612433, 5988751) 12. Present well condition summary Total depth: measured true vertical 13488 feet Plugs (measured) 6787 feet Effective depth: measured true vertical 11520 feet Junk (measured) 6700 feet Casing Length Conductor 109' Surface 4752' Production 11655' Liner 1557' Size Cemented 20" 260 Sx AS 10-3/4" 643 Sx AS Litelll, 510 Sx Class G, & 150 Sx AS Lite 7" 627 Sx Class G 4-1/2" 57 Sx Class G (solid & slotted line 6. Datum elevation (DF or KB feet) RKB 64.2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-102 9. Permit number / approval number 200-129 / approv # 301-145 signed 6/1/01 10. APl number 50-029-22972 11. Field / Pool Prudhoe Bay Field/Aurora Pool (undefined) Abandoned WRP located @ 11772' MD. Measured Depth True Vertical Depth 109' 109' 4816' 3186' 11719' 6634' 13100' 6621' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 11680'- 11700'; 11716'- 11736'; (Isolated below WRP is the Slotted liner interval f/12312' - 13099'). 6623'- 6629'; 6634' - 6639'; (Isolated below WRP is the Slotted liner interval f/6764' - 6749'). 4-1/2", 12.6#, L-80 Tbg @ 11559' MD. RECEIVED AUG 1 2.001 Alaska 0il & Gas Cons. Commission 7" X 4-1/2" Baker S-3 Packer @ 11524' MD; 4-1/2" X 7" Baker ZXP Liner Top Packe~,{~Clllel~a~MD. 4-1/2" X Landing Nipple @ 2515' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl 444 2988 0 1119 2171 36O Casing Pressure Tubing Pressure 300 398 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _X 16. Status of well classification as: Oil ~X Gas _ Suspended _ Service 17. I hereby, certifv that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Aurora Petroleum Engineer James Young Form 10-404 Rev 06/15/88 ORIGINAL. Date Auqust 9, 2001 Prepared by Paul Rauf 564.5799 SUBMIT IN DUPLICATI'~ S-102 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date Event Summary 7/07/2001 - 7/0812001: 7/11/2001 - 7/1312001: 7/1712001: MIRU CTU. PT'd equip. RIH w/CT & performed Hot Oil Treatment to 5850'. POOH. RIH w/ CT & FCO'd to 12300'. POOH w/CT. RIH w/WRP (wireline retrievable plug) & set it @ 11800' (fishing neck @ 11790') to isolate the horizontal slotted liner interval from: 12312' - 13099' MD (Kuparuk C Sand) Reference Log: Sperry MWD EWR 10/25/2000. POOH w/setting tool. FP'd well. RD CTU. Ran Petrodat Static Survey w/stops @ 11297' & 11517'. Ave Temp @ 6600' TVD = 2671 psi & 138° F. Dummied GLV's. MITIA to 3500 psi - passed. MIRU Dowell FRAC Unit. PT'd equip. Performed a FB Hydraulic Fracture Treatment using 20/40 mesh ceramic proppant through the target perforations listed below: 11680' - 11700' MD (Kuparuk C Sand) 11716' - 11736' MD (Kuparuk C Sand) Pumped: (a) 236 bbls 20# Gelled Pre-Pad @ 40 bpm, followed by shutdown. ISIP = 1236 psi. (b) 50 bbls 40# Crosslinked Gelled Pad @ 30 bpm, followed by (c) 75 bbls 1 ppg Scour Stage @ 30 bpm, followed by (d) 233 bbls Flush w/20# Liner Gel @ 30 bpm, followed by (e) Shutdown. ISIP @ 1390 psi. (f) 75 bbls 40# Crosslinked Gelled Pad @ 30 bpm, followed by (g) 230 bbls Flush w/20# Liner Gel @ 30 bpm, followed by (h) Shutdown. ISIP @ 1470 psi. Resumed pumpin.q Datafrac Treatment: (i) 50 bbls 40# Crosslinked Gel @ 30 bpm, followed by (j) 180 bbls 20# Linear Gel Flush @ 30 bpm, followed by (k) Shutdown. ISIP = 1684 psi. Resumed Additional Pad/Scour Treatment: (I) 100 bbls 50# Crosslinked Gel @ 20 bpm, followed by (m) 50 bbls 50# Crosslinked Gel w/1 ppg Scour Stage @ 20 bpm, followed by (n) 50 bbls 50# Crosslinked Gel @ 20 bpm, followed by (o) 25 bbls 50# Crosslinked Gel w/1 ppg Scour Stage @ 20 bpm, followed by (p) 50 bbls 50# Crosslinked Gel @ 20 bpm, followed by (q) 25 bbls 50# Crosslinked Gel w/1 ppg Scour Stage @ 20 bpm, followed by (r) 230 bbls Flush w/20# Liner Gel @ 20 bpm, followed by (s) Shutdown. ISIP = 1607 psi. Page 1 S-102 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date Event Summary 7/19/2001: 7/20/2001: 7/21/2001: 7/22/2001: 7/24/2001: 7/25/2001: 7/26/2001 - 7/29/2001: Resumed pumpin,q Frac Treatment: (t) 20 bbls 40# Crosslinked Pad @ 25 bpm, followed by (u) 450 bbls Crosslinked Slurry @ 25 bpm w/proppant stages @ 1-10 ppg, followed by (v) 174 bbls Flush @ 25 bpm, followed by (w) Shutdown. Placed a grand total of 92849 lbs of proppant into FM. Max proppant concentration placed was 10 ppg. Did not achieve tip screenout. Estimated 1024 lbs of proppant left in wellbore. RD Dowell FRAC equip. MIRU CTU. PT'd BOPE. RIH w/CT. Tagged TOS @ 11168' CTM. Performed FCO to the top of WRP located @ 11784'. RIH w/ Overshot but unable to get beyond 8442'. POOH. RIH w/Collet Overshot while pumping nitrified liquid. Tagged WRP @ 11772'. Circ'd BTM's up & latched plug. PUH w/plug. POOH - did not recover WRP. RD CTU. Decided to leave WRP in the 4-1/2" liner. MIRU SLU. PT'd equip. RIH & attempted to run live GLV's but was unable to get deeper than 3275'. POOH. RD SLU. MIRU CTU. PT'd equip. RIH to 3067' & reversed out Frac Sand using combo of Gelled Diesel & Slick Water. Reversed out Frac Sand to 11520'. POOH. FP'd well. RD CTU. Pulled dummy GLV's. Installed live GLV's. Placed well BOL & performed a representative welltest. Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ (FRAC) Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface ~ ~r ~ 827, FNL, 4499' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 4623' FNL, 4449' FEL, Sec. 22, T12N, R12E, UM At effective depth At total depth 3191' FNL, 296' FEL, Sec. 21, T12N, R12E, UM 5. Type of Well: Development ._X Exploratory _ Stratigraphic _ Service__ (asp's 618929, 5980656) (asp's 613583, 5987337) (asp's 612433, 5988751) 6. Datum elevation (DF or KB feet) RKB 64.2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-102 9. Permit number / approval number 200-129 ~ 10. APl number ~ 50-029-22972 11. Field / Pool Prudhoe Bay Field/Aurora Pool (undefined) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 109' 20" Surface 4752' 10-3/4" Production 11655' 7" Liner 1557' 4-1/2" 13488 6787 13488 6787 feet ~' Plugs (measured) feet ~' feet Junk (measured) feet Cemented Measured Depth True vertical Depth 260 Sx AS 109' 109' 643 Sx AS Litelll. 510 Sx Class 4816' 3186' G, & 150 SxAS Lite 627 Sx Class G 1 1719' 6634' 57 Sx Class G (solid & slotted liner) 13100' 6621' Perforation depth: measured 11680'-11700';11716'-11736'; Slotted liner interval f/12312'- 13099'. R E C El\/E [) true vertical 6623' - 6629'; 6634' - 6639'; Slotted liner interval f/6764' - 6749'. Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 11559' MD. ':~,lasi(a ('.)ii &..:., ,:,..:, (;:,"~s. 5ommissior' Am:borage Packers & SSSV (type & measured depth) 7" X 4-1/2" Baker S-3 Packer @ 11524' MD; 4-1/2" X 7" Baker ZXP Liner Top Packer @ 11543' MD. 4-1/2" X Landing Nipple @ 2515' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch_ 15. Status of well classification as: 14. Estimated date for commencing operation June 4, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ X Gas __ Suspended _ Service 17. I hereby certi~t the, ~origoing is true and correct to the best of my knowledge. Signed ~' I ~VI '~~ Title: Aurora Petroleum Engineer Jim Youn~l I ~. ', FOR COMMISSION USE ONLY Questions? Call Jim Young O 564-5754. Date Prepared by Paul Rauf 564-5799 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance ~ Integrity Test _ Subsequent form required 10- ~'[~ Mechanical Approved by order of the Commission ORIGINAL Commissioner Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp May 31, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 RECEIVED ,-.iU;"J 0 'i LAJU ~ Dear Tom: RE: Sundry_ Notice for S-102 Hydraulic Fracture Treatment Alaska Oil & Gas Co~*,.s. Commission A.~chorage BP requests approval for Hydraulic Fracture Treatment for the Kuparuk C Sand interval. The procedure includes the following major steps: Category IOR Ste' Description S 800 I ' Set SPG in ~LM#1. DGLV's. Load & MITIA. C 800 2 Drift to 13100'. Set ClBP at 11800' (HAW). O 800 3 Pump Datafrac &Frac S 800 4 Drift & tag. Set 3/8" OGLV in top GLM. C 800 5 Perform unberbalanced FCO, mill ClBP. S 800 6 APC frac flowback. Shut-in for 24 hr PBU. $ 800 7 Pull sidepocket gauge, Run LGLV's (deep design) Max, Deviation: Deviatoin at Tbgtail: Last Tag TD: Latest Welltest: Reference Log: BHT & BHP: 93° @ 12496' md Perf Deviation: 72-°@ 11600' Minimum ID: HAW Last Downhole Op: 600 BOPD, 3MMCFD. Latest H2S value: Sperry Sun MWD EWR 10/25/00 147° F & 2916 psia @ 6765' TVD (11503' MD) Perfs open for Frac (40'): .!..,!Z!.....8.: ................. - ..!..!......7.,.3,.8.: ................. .6..S..P...f.....e.....6.0..°. .................................. .3:.3../.,.8.,'.'.......P..,j......(,.o,......3..~:'.....,.,E..,.H....,D..) ............... .!..,!...,.6....8.....o..1 ................. - ..!....!..7....o...,o.,1 .................. .6...s.,,p...f..~....6..o...°. .................................. ,.3.-Y...8.iL,.P...J......(O..,....3..$,5.,.E...,.H.....D..) ............... 76-o @ 11738' 3.813" LGLVs <10 ppm The frac operation will include pre and post-frac CTU work to set/retrieve a bridge plug to isolate the horizontal slotted liner section, an SRT to determine parting pressure, MiniFRAC to determine fluid efficiency and the main frae. The frae will consist of pumping __.67,000 pounds 20/40 Carbo-lite proppant. The objectives are of the frae treatment are: 1 ) Bypass completion skin from the well (+8 skin measured with PBU). 2) Limit downward height growth to <100' tvd (C1 thief/aquifer at -6850' TYD). Page 1 3) Place 3 psf proppant out to >50'. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or by email at Youngj3@bp.com. Jim Young Aurora Petroleum Engineer Page 2 TREE =-4-1116" - 5M CIW CHROME WELLHEAD-- 13-518" - 5M FMC SH ACTUATOR= BAKER KB. B. EV = 64.2' BF. B_EV = KOP = 1400' Max Angle = 93° @ 12,497' Oat~m MD ~ ................. Datum TVD= 6764' I 10-314" CSG, 45.5#, K-55-BTC, ID = 9.95" H 4816' ~ S-102 SAFETY NOTES: 2185' 2515' H7" PORT COLLAR I H4-1/2" ~(' LAI~DING NIPPLE, D =3.813" GAS LFT MANDRELS Minimum ID = 3.75"@ 12,264' HALLIBURTON ES CEMENTER CAUTION: TWO SCHLUMBERGER RADIOACTIVE SOURCES WERE P & A'D ON 10-4-00 W/RED CEMENT TO A PLUGBACK DEPTH OF 8017' MD/4655' TVD. #1 8564' MDI4882' TVD - 2.0 CURIE CS-137 #2 8531' MDI4867' TVD - 4.0 CURIE AM - 241 DO NOT RE-ENTER WELL BELOW PLUGBACK DEPTH BEFORE CONTACTING THE U.S. NUCLEAR REGULATORY COM MISSION AND ALASKA DEPARTMENT OF OIL & GAS 4-11Z' TBG, 12.6#, L-80 BTC-tvt ~ 11558' 0.01522 bpf, D = 3.958" 6992' 11503' 11524' 11543' 11547' 11557' 11558' 11553' 7" PORTCOLLAR I Id4-1/Z' 'X' LANDING NIPPLE ID = 3.813" H.7" X 4-11Z' BAKBR S-3 PK~ ID= 3.875" W/LINERTIE-BACK SLEEVE I H4-112" 'X' LANDING NIPR. E, ID= 3.813" I BAKER5"X7"'HMC' HYDRAULIC LNR HANGER, ID = 3.938" H4-11Z' VVLEG I I 7" CSG, 29#, L-80-BTC-M, ID = 6.182" H 1171 T 4-1/2" IBTLNR, 12.6~, L-80, .0152 bpf, ID= 3.958" RERFORATDN SUtv~ARY REF LO~ PDS JEWELRY LOG 12/11100 ANGLEATTOPPERF: 73° @ 11,680' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11,680-11,700 O 01121101 3-3/8" 6 11,716-11,736 O 01/2t/01 ITOPOF 4-1/2" SLOTTEDLNR H 12312' IBO'ITOMOF4-1/2"SLO'ITEDLI~R ~/. 13100' 13488' I I I I I 12264' 12267' HALLIBURTON ES TYPE H CEIVENTER * MLLED OUTTO 3.75" DURING COMR. ETION H4-1/2,,x 6-3/4" ECP, ID: 3.875" I DATE ~ BY COMIVENTS PRUDHOE BAY UNIT 7/4/1982 ORIGINAL COlVPLETION WB.L: S-102 10/06/91 DSMC LASTWORK OVER PERMIT No: 82-0950 03/08/01 SIS-MH CONVEh[~ ~-u TO CANVAS APl No: 50-029-20765-00 03/12/01 SIS-MD RNAL Sec. 35, T12N, T12E 03/16/01 CH/TP CORRECTIONS BP Exploration (Alas ka) STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 827' FNL, 4499' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 4623' FNL, 4449' FEL, Sec. 22, T12N, R12E, UM At effective depth At total depth 3191' FNL, 296' FEL, Sec. 21, T12N, R12E, UM 5. Type of Well: Development _X Exploratory_ Stratigraphic._ Service__ (asp's 618929, 5980656) (asp's 613583, 5987337) (asp's 612433, 5988751) 6. Datum elevation (DF or KB feet) RKB 64.2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-102 9. Permit number / approval number 200-129 10. APl number 50-029-22972 11. Field / Pool Prudhoe Bay Field / Aurora Pool (undefined) 12. Present well condition summary Total depth: measured true vertical 13488 feet Plugs (measured) 6787 feet Effective depth: measured true vertical 13488 feet Junk (measured) 6787 feet Casing , Length Conductor 109' Surface 4752' Production 11655' Liner 1557' Size Cemented Measured Depth 20" 260 sx AS 109' 10-3/4" 543 Sx AS Litelll, 510 Sx Class 4816' G, & 150 Sx AS Lite 7" 627 Sx Class G 11719' 4-1/2" 57 sx Class G (solid & slotted 13100' liner) Perforation depth: measured 11680' - 11700'; 11716' - 11736'; Slotted liner interval f/12312' - 13099'. true vertical 6623' - 6629'; 6634' - 6639'; Slotted liner interval f/6764' - 6749'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 11559' MD. True vertical Depth 109' 3186' 6634' 6621' RECEIVED MAt? 0 1 2001 Alaska Oil & Gas Cons." ts ior'omm-s-n Anchorage Packers & SSSV (type & measured depth) 7" X 4-1/2" Baker S-3 Packer O 11524' MD; 4-1/2" X 7" Baker ZXP Liner Top Packer O 11543' MD. 4-1/2" X Landing Nipple {~ 2515' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 321 Representative Daily Avera,qe Production or Injection Data Gas-Md Water-Bbl 6981 0 596 6339 0 Casing Pressure Tubing Pressure 304 291 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~,/~"~/~ Title: Aurora Petroleum Engineer Jim Young ~ Form 10-404 Rev 06/15/88 · Date 2/28/2001 Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE'~ S-102 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 1/18/2001: 1/19/2001: 1/21/2001: RIH w/dummy gun & drifted to 11370' SLM. Unable to get further due to Parafins. RIH w/LIB to 11755' (HAW) - past yesterday's obstruction. POOH w/LIB (small piece of Aluminum embedded in outer face of LIB). RIH w/dummy gun until stopped by deviation @ 11730' SLM. MIRU ELU. PT'd equip to 3000 psi. Pumped 100 bbls of Hot Diesel/Xylene Treatment. RIH w/perforating guns & did tie-in. Shot 40' of add perforations @' 11680' - 11700' MD 11716' - 11736' MD Used 3-3/8" carriers & all shots @ 6 SPF. POOH w/guns - ASF. RD ELU. Placed well BOL & obtained well test data. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Page I S-102 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 1/1812001: 1/1912001: 1121/2001: RIH w/dummy gun & drifted to 11370' SLM. Unable to get further due to Parafins. RIH w/LIB to 11755' (HAW) - past yesterday's obstruction. POOH w/LIB (small piece of Aluminum embedded in outer face of LIB). RIH w/dummy gun until stopped by deviation @ 11730' SLM. MIRU ELU. PT'd equip to 3000 psi. Pumped 100 bbls of Hot Diesel/Xylene Treatment. RIH w/perforating guns & did tie-in. Shot 40' of add perforations @: 11680'-11700' MD 11716'-11736'MD Used 3-3/8" carriers & all shots @ 6 SPF. POOH w/guns - ASF. RD ELU. Placed well BOL & obtained well test data. 0 Alaska Oil & Gas Cons. Commission Anchorage Page 1 To.' WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 02, 2001 MWD Formation Evaluation Logs · S-102 PB1, AK-MM-00184 S-102 PBI: 2" x 5" MD Resistivity & Gamma Ray Logs · 50-029-22972-70 o~0~-/o~ 2" x 5" TVD Resistivity & Gamma Ray Logs · 50-029-22972-70 1 Blueline~' 1 Rolled Sepia .~' 1 Blueline 1 Rolled Sepia '/ PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING A COPY TRANSMITTAL LETTER TO THE ATTEN'~ON OF: Sperry-Sun Drilling Services Arm: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF Date:c~-Itkt) ~ · , ' STATE OF ALASKA ALASK .iL AND GAS CONSERVATION COM ,,_,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-129 300-260 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22972-00 4. Location of well at surface .-' ...................... '~OCAT~" 9. Unit or Lease Name 4452' NSL, 4499' WEE, SEC 35, T12N, R12E, UM ~ At top of productive interval ,,.,.....~:. t ¥ ' Prudhoe Bay Unit 672' NSL, 4428' WEE, SEC 22, T12N, R12E, UM :!:/~'~--~'-/-~J= 'i" i~v'l At total depth ' · ............ ' ~ [1~' 10. Well Number '~ :..~'~ i.~ S-102 2105' NSL, 273' WEE, SEC 21, T12N, R12E, UM ~ ........ i. 'J~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease' Designation and Sedal No. Prudhoe Bay Field / Aurora Pool KBE = 64.2' ADL 028256 (Undefined) 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore .10. Nc. of Completions 9/14/2000 10/18/2000 10/24/2000 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 13488 6787 FTI 13488 6787 FTI [] Yes [] NoI (Nipple) 2515' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD / GR, MWD / GR / RES / NEU / DEN / PWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 29' 109' 30" 260 SX Arctic Set (Approx.) 10-3/4" 45.5# K-55 27' 4816' 13-1/2" 643 sx Arcticset Lite 3~ 510 sx Cle$s 'G' Top Job: 150 sx AS Lite 7" 29# L-80 26' 11719' 9-7/8" 827 sx ClaSs 'G' 4-1/2" 12,6# ' L-80 11543' 13100'. 6-1/8" 57 sx Class 'G' (Solid & Slotted Liner. 24. PerfOrations pp. en tq P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and m~erva~, s~ze and number} SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 11559' 11524' MD TVD MD TVD 12312' - 13099' 6764' - 6749' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 72 Bbls of Diesel 27. PRODUCTION TEST ~n I C"I k l ^ I Date First Production Method of Operation (Flowing, gas lift, etc.) U ~ ~ U I I ~ ~ L- December 18, 2000 Gas Injection, Shut-In Date of Test Hours Tested PRODUCTION FOR CIE'BeE GAs'MCF WATER-BeE CHOKE S~ZE I GAS-O~L RATio 12/22/2000 4 TEST PERIOD 458 5,499 0 176I 12,005 Flow Tubing CaSing Pressure CALCULATED OIL-BeE GAs-MCF WATER-BeE OIL GRAWTY'API (CORR) Press. 24-HOUR RATE ~8. CORE DATA Brief description of lithology, porosity, fractures, aPparent dips and presence of °il, gas or water. Submit core chips. None RECEIVED JAN ; 001 Form 10-407 Rev. 07-01-80 Alaska Oil & Gas Cons. Commission Anchorage Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Ugnu 5346' 3532' Schradder Bluff 8272' 4782' West Sak 8508' 4920' Kuparuk 11657' 6745' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~'~'~_.~ ~ Title TechnicalAssistant Date ~1°~.~"~)/ S-102 200-129 300-260 Prepared By Name/Nurnbec Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. . ~NSTRUCTIONS 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. ITEM27: Method of Operation: Flowing, GasLift, Rod Pump, Hydraulic Pump, Submersible,~t~~~~n, Shut-ln, Other-explain. ITEM 28: If no cores taken, indicate 'none'. JAN 001 Form 10-407 Rev. 07-01-80 Alaska Oil & Gas Cons. Commission Anchorage :. : ':"i ' · : . .,.~ ., .,,.. , .... · , :,, ,., , .. ,,, ,, . . · ,;,{, ,., .,,,, ,: ...;:;;:: ..:.:.,,:, .,,, . . , ,,, . . · . ~".. '"..." '~'"'~.'~ ' '~.." :'"'..' ...' " ' ' ' '....." '::..:::. .,:'. "'~' ." .:'.;.::.":~::':.:.:.":.""~..,:."/i: :.:'..':~ :":.~'.,:" :":'~i:". i;:' ': :"~':'":~Le';ik. ,~,,Off, :..~est,'. SUmmary, ,. : . . · .., ,. , · Legal Name: S-102 Common Name: S-102 "Test. Date . .'".~;esl;.'Type,;.:., '.i.' .... '.i:'"......Te~{:Ei~Pth.'.(TaD);" ".:i::i TestilD.epth,.(TVO).;: ... ...'," AMW. " Surface Pressure Leak Off Pressure (BHP) EMW 9/22/2000 LOT 4,833.0 (fi) 3,321.0 (fi) 9.60 (ppg) 910 (psi) 2,566 (psi) 14.87 (ppg) 10/15/2000 FIT 11,717.0 (fi) 8,765.0 (fi) 10.40 (ppg) 775 (psi) 4,430 (psi) 12.61 (ppg) Printed: 1119/2000 10:12:03 AM BP EXPLORATION Page I of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 9/14/2000 00:00 - 07:00 7.00 RIGU SURF Accepted rig at 0000 hours 9/14/00. Nippled up 21 inch Hydril diverter, lines and drilling nipple. Filled pits and mixed spud mud. Loaded pipe shed with 5" DP. 07:00 - 09:30 2.50 RIGU SURF Clear rig floor, install pipe handling equipment and rig up to pick up DP. 09:30 - 10:30 1.00 RIGU SURF Pick up DP and stand in derrick. 10:30 - 11:30 1.00 RIGU TREE SURF Rig cellar doors and windwalls would not close due to proximity to Christmas tree wing valves and LDS on S-100i. Assisted DSM in removing wing, etc. to close doors. 11:30 - 17:30 6.00 RIGU SURF Finished picking up DP and HWDP and standing in derrick. Strapped mud tanks and confirmed PVT function and calibration. 17:30- 18:00 0.50 DRILL SURF Load floor with BHA components. 18:00 - 18:30 0.50 DRILL SURF Function tested diverter BOP and held diverter drill. 18:30 - 19:00 0.50 DRILL SURF Held pro-spud meeting and safety meeting with all involved personned. 19:00 - 20:30 1.50 DRILL SURF Made up spud BHA. 20:30 - 21:00 0.50 DRILL SURF Filled conductor hole with spud mud, checked system for leaks and prep to drill. 21:00 - 21:30 0.50 DRILL SURF Spudded at 2100 hours and drilled to 133 ft. 21:30 - 23:00 1.50 DRILL SURF Rigged up SWS with Gyro Data survey tools. Run, repeat and confirm gyro directional survey results. 23:00 - 00:00 1.00 DRILL SURF Drilled by sliding to 163 ft. 9/15/2000 00:00 - 16:00 16.00 DRILL 'SURF Drill and slide to 874 ft. running gyro surveys on Schlumberger line. AST-5 hrs. ART-5.5 hrs. 16:00- 16:30 0.50 DRILL SURF Circulate 16:30 - 17:00 0.50 DRILL SURF POOH 17:00 - 18:00 1.00 DRILL SURF Change bit. Lay down jars. Clear floor. 18:00 - 19:30 1.50 DRILL SURF Slip and cut drill line. Service top drive. 19:30 - 22:00 2.50 DRILL SURF Make up BHA with MWD and new jars. Trip in hole. '22:00 - 23:00 1.00 DRILL SURF Gyro survey and MDW survey for comparison. 23:00 - 00:00 1.00 DRILL SURF Drill by sliding to 900 fi. with 280 deg tool set. AST-0.5 hr. 9/16/2000 00:00 - 03:30 3.50 DRILL SURF Drilled to 1048 ft. Assembly not building angle or turn. 03:30- 04:00 0.50 DRILL SURF CBU. 04:00 - 05:00 1.00 DRILL SURF POOH to PDM. 05:00 - 06:00 1.00 DRILL SURF Adjusted PDM bend to 2.12 degrees. 06:00 - 06:30 0.50 DRILL SURF RIH. No fill. Function PVT equipment. 06:30 - 00:00 17.50 DRILL SURF Drill with PDM to 1660 ft. Function PVT equipment. 9/17/2000 00:00 - 00:00 24.00 DRILL SURF Directionally drill with PDM from 1660 ft. to 2676 ft. AST-8.25 hrs.; ART-7.25 hrs. 9/18/2000 00:00 - 01:30 1.50 DRILL SURF Directionally drilled f/2676 ft, to 2771 ft. AST - 0.75 hr. ART - 0.25 hr. 01:30 - 02:30 1.00 DRILL SURF Circulate bottoms up. 02:30 - 04:30 2.00 DRILL SURF POOH working tight spots f/2772 ft. t/2000 ft. Had 25K-35K overpulls. No tite spots in permafrost above 1900 ft. 04:30 - 06:00 1.50 DRILL SURF Change PDM bend to 1.5 degrees. Run new bit. 06:00 - 06:30 0.50 DRILL SURF Service top drive. 06:30 - 07:00 0.50 DRILL SURF Orient PDM and MWD. RIH w/collars. 07:00 - 09:00 2.00 DRILL SURF RIH w/bit to 2000 ft. w/no problems. Filled pipe and worked tite hole f/ 2000 ft. t/TD. Had 40 ft. fill. CBU at 600 gpm w/50 rpm rotaty. No excessive cuttings. 09:00 - 00:00 15.00 DRILL SURF Directionally drill f/2771 ft. t/3585 ft. 9/19/2000 00:00 - 16:00 16.00 DRILL SURF Directionally drilled 13 1/2" hole to 4833 ft. AST - 1.75 hrs. ART - 9.75 hrs. Functioned PVT. 16:00 - 17:30 1.50 DRILL SURF CBU at 650 gpm, 80 rpm rotary, 90 ft. pipe stroke. Pumped hi-vis sweep surface to surface. Normal cuttings return. Functioned PVT. 17:30 - 20:15 2.75 DRILL SURF Made wiper trip up to 880 ft. Worked tite hole at 4100', 3795'-3780', Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 2 of 12 Operations Summar Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 9/19/2000 17:30 - 20:15 2.75 DRILL SURF 3484'-3424' w/swabbing. Back reamed 3411'-3301'. Worked tite hole intervals 3190'-3180', 2760'-2740' and 1775'. Hole took proper fill. 20:15 - 22:45 2.501 DRILL SURF RIH to complete wiper trip. Worked tite hole at 2460', 2750', 2900'-3000'. Stacked out at 3443' numerous times. Stacked out at 3721' and worked hole. Finished in hole to bottom. No fill. 22:45 - 00:00 1.25 DRILL SURF Filled DP, broke circulation and pumped hi vis, Barafiber sweep surface to surface. 9~20~2000 00:00 - 00:30 0.50 DRILL SURF Finished circ. sweep surface to surface. 00:30 - 02:00 1.50 DRILL SURF POOH for wiper trip to 3470 ft. Back reamed from 3470 ft. to 3200 ft. 02:00 - 02:30 0.50 DRILL SURF RIH to complete wiper trip. Washed and reamed to TD with no fill. 02:30 - 04:30 2.00 DRILL SURF Circulated hi vis sweep and conditioned mud with 4% Lubetex pill in interval 2433 ft. to 4833 ft. TD. 04:30 - 07:30 3.00 DRILL SURF Dropped ESS instrument and POOH taking check directional shots at 4802', 4710' and 4150'. SLM DP - no correction. 07:30 - 10:30 3.00 DRILL SURF Stood HWDP and laid down 8" directional tools (MWD, NMDC, & PDM). Cleared floor and loaded out tools. Function PVT. 10:30 - 13:30 3.00 CASE SURF Rigged up Nabors casing tools and Franks fillup tool. 13:30 - 14:00 0.50 CASE SURF Held PJSM with all crews. 14:00 - 14:30 0.50 CASE SURF Picked up shoe joints, made up and tested for circulation and float. 14:30 - 23:00 8.50 CASE SURF RIH picking up 10 3~4" casing. Had to bump casing shoe thru hole ~irregularity at 2706 ft. Otherwise, casing ran smoothly. Washed down last two joints at 3.3 bpm w/340 psi. 23:00 - 23:30 0.50 CASE SURF Made up casing hanger and landing joint. 23:30 - 00:00 0.50 CASE SURF Worked casing hanger stuck in diverter BOP. 9/21/2000 00:00 - 00:30 0.50 CASE SURF Casing hanger profile hung in diverter recess. Worked free and pipe partially stuck. Worked pipe free and landed casing at 4817 ft. 00:30 - 03:30 3.00 CEMT SURF Circulated and conditioned mud to run casing. Held PJSM with Nabors, Peak, Dowell, Baroid, PES personnel. 03:30 - 07:30 4.00 CEMT SURF Rigged up Dowell and tested lines to 3500 psi. Pumped 10 FW, dropped bottom plug, 10 FW, 75 D45 spacer ~ 10.4 ppg, 666 sx (525 bbls) Articset III, 510 sx (106 bbls) Class G cement (~ 15.8 ppg. Dropped top plug and pumped 5 FW. Displaced cement at maximum rate of 8.0 bpm and average rate of 5.7 bpm. Final pressure 1036 psi. PLUG DID NOT BUMP! Bled pressure and floats held. Had 226 barrels (286 sx) good cement returns. Cement stood in conductor casing. 07:30 - 09:30 2.00 CEMT SURF Rigged down casing handling equipment. RD cementing head. Laid down landing joint. Clear rig floor and load out tools. 09:30 - 12:00 2.50 BOPSUF SURF Nipple down 20" diverter. 12:00 - 14:00 2.00 ~ WHSUI; INT1 Installed 13 5/8" 5000 psi FMC Split Speed casing head with 13 5/8" 5000 psi tubing head as spacer spool. Tested to 1000 psi. 14:00 - 21:00 7.00 BOPSUF INT1 Nippled up BOPE. 21:00 - 00:00 3.00 BOPSUF INT1 Installed test plug. Began testing BOPE, choke and kill lines, standpipe, choke manifold, pipe and blind rams and annular preventer to 250 psi Iow pressure and 3500 psi high pressure per BPAmoco requirements. Witness of test waived by Lou Grimaldi, AOGCC agent. 9~22~2000 00:00 - 01:30 1.50 BOPSUF INT1 Finished testing BOPs to 250/3500 psi per BPAmoco and AOGCC requirements. Witness of test waived by Lou Grimaldi, AOGCC agent. Pulled BOP test plug. 01:30 - 02:00 0.50 BOPSUF INT1 Insrtall wear ring 02:00 - 06:00 4.00 DRILL INT1 Make up 9 7~8" drillimg assembly. Load MWD 06:00 - 10:00 4.00 DRILL INT1 Pick up 5" drill pipe in singles and RIH to 4552'. Test MWD. 10:00 - 11:30 1.50 DRILL INT1 POOH and stand 5" drill pipe in derrick. Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 3 of 12 Operations Summar Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 , Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 9/22/2000 11:30 - 12:30 1.00 DRILL INT1 Slip and cut drilling line 12:30 - 13:00 0.50 DRILL INT1 Service rig and top drive 13:00 - 13:30 0.50 DRILL INT1 RIH to 4290' 13:30- 15:00 1.50 DRILL INT1 Held stripping in drill. 15:00 - 17:00 2.00 DRILL INT1 RIH to 4557'. Wash to 4708' and tag cement. 17:00 - 17:30 0.50 DRILL INT1 Drill cement from 4708' to 4730'. 17:30 - 20:00 2.50 DRILL INT1 Pressure test casing to 2800 psi for 30 minutes. Pressure drop 50 psi ~n 30 minutes. 20:00 - 22:00 2.00 DRILL INT1 Drill cememt and float equipment and 20' of new hole to 4853' 22:00 - 22:30 0.50 DRILL INT1 Circulate and condition mud 22:30 - 23:30 1.00 DRILL INT1 Perform LOT. EMW 14.87 ppg. 910 psi with 9.6 ppg mud. 23:30 - 00:00 0.50 DRILL INT1 Circulate and change out spud mud for 10.5 ppg LSND mud. 9/23/2000 00:00 - 03:00 3.00 DRILL INT1 Circulate and change out spud mud to LSND mud. 03:00 - 03:30 0.50 DRILL INT1 Change mode on MWD. 03:30 - 04:30 1.00 DRILL INT1 Drill 9 718" directional hole from 4853' to 4932'. Shaker screens blinding. Unable to circulate above 500 gpm. Loosing mud over the shakers. 04:30 - 05:00 0.50 DRILL INT1 POOH to casing shoe. 05:00 - 06:00 1.00 DRILL INT1 Circulate and condition mud. Add 1% condent to reduce screen blinding. Change shaker screens to 24/50. 06:00 - 06:30 0.50 DRILL INT1 RIH to bottom. 06:30 - 13:30 7.00 DRILL ' INT1 Drill 9 7/8" directional hole from 4932' to 5530'. Shaker screens blinding and loosing mud over the shakers. 13:30- 15:00 1.50 DRILL COND INT1 Circulate and condition mud. 15:00 - 16:00 1.00 DRILL INT1 Drill 9 7/8" directional hole from 5530' to 5617'. ROP > 120 FPH with little weight on bit. Loosing mud over shakers. Unable to circulate with more than 500 gpm. 16:00- 18:00 2.00 DRILL CLN INT1 POOH to casing shoe. Work pipe and back ream from 5617' to shoe. 18:00 - 18:30 0.50 DRILL COND INT1 Circulate and condition mud. Add 1% drill-n-slide to mud. Change shaker screens to 110/84. Increase circulation rate to 600 gpm. 18:30- 19:00 0.50 DRILL COND INT1 RIH to 5617'. OK. 19:00 - 00:00 5.00 DRILL INT1 Drill 9 718" directional hole from 5617' to 5869' Slide and rotate to hold angle and direction. 9/24/2000 00:00 - 00:00 24.00 DRILL INT1 !Drill 9 7/8" directional hole. Rotate and slide to maintain angle and direction. 9/25/2000 00:00 - 15:00 15.00 DRILL INT1 i Drill 9 7/8" directional hole from 7655' to 8688'. Rotate and slide to start dropping angle. 15:00 - 00:00 9.00 DRILL FORM INT1 Work stuck pipe with bit at 8629'. After sliding last 45' of stand and picking up back reaming to make a connection the pipe became stuck at 8629'. Full circulation, no rotation and no pipe movement up or down. Immediately start jaring down and applying torqure to the string. Work pipe while waiting on "SFT" spotting fluid from Baroid mud plant. 9/26/2000 '00:00 - 02:00 2.00 DRILL FORM INT1 Work stuck pipe. Jarring down and appyling torque to string. Circulate slowly and reduce mud weight to 10.1 ppg. 02:00- 03:00 1.00 DRILL FORM INT1 Pump 50 bbl "SFT" spotting pill at 10.3 ppg down drill pipe. Spot 15 bbl outside around BHA and leave 35 bbl inside pipe. 03:00 - 23:00 20.00 DRILL FORM INT1 Work stuck pipe. Jarring down and up and applying torque to string. Max over pull on up jarring 80,000 lbs. Pump 2 bbl SFT pill out to annulus every hour while jarring. No progress 23:00 - 00:00 1.00 DRILL FORM INT1 Circulate SFT pill out of the hole. 9/27/2000 00:00 - 03:00 3.00 DRILL FORM INT1 Circulate SFT spotting pill out of system. Hold PJSM with crews and service companies involved. Test lines from hot oil unit to rig floor to Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 4 of 12 Operations Summar Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG 'Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 9/27~2000 00:00 - 03:00 3.00 DRILL FORM INT1 3000 psi. Hot oil unit pump 107 bbl crude oil down drill pipe at 6 BPM. Displace oil with rig pumps at 14 BPM. When oil was around BHA jarred down and torqued string. With 50 bbl displacement left for oil to be at surface, closed annular preventer., Observed 40 psi on annulas. Displaced oil to surface through choke with 200 psi back pressure at 3 BPM. Opened drill pipe to atmosphere, opened choke and allowed fluids to "U" tube. Annulus flowed back 7 bbl and well was static. 03:00 - 06:30 3.50 DRILL FORM INT1 Working stuck pipe. Jarring down and torquing string with reduced hydrostatic on well. No progress. 06:30 - 10:00 3.50 DRILL ~FORM INT1 Circulate crude oil out of well through choke and pump to frac tank. Open annular and circulate and condition mud at 14 BPM with 2400 psi. 10:00 - 12:00 2.00 DRILL FORM INT1 Work 4 turns of left hand torque down drill pipe. 12:00 - 15:30 3.50 DRILL FORM INT1 Rig up Schlumberger and run CCL and string shot. Have to pump tools down. Fired shot at 8478' top of bottom flex collar under the jars. POOH with tools and hang in derrick. 15:30 - 16:00 0.50 DRILL FORM INT1 Connect top drive and work left hand torque (15,000 fi/lb) down string. No back off. 16:00 - 19:30 3.50 DRILL FORM INT1 Rig up Schlumberger and run CCL and string shot. Have to pump tools down. Fired shot at 8447' top of middle flex collar under the jars. POOH with tools and hang in derrick. 19:30 - 21:00 1.50 DRILL FORM INT1 Connect top drive and work left hand torque (15,000 fi/lb) down string. No back off. 21:00 - 00:00 3.00 DRILL FORM INT1 Rig up Schlumberger and run CCL and string shot. Have to pump tools down. Fired second shot at 8447' top of middle flex collar under the jars. POOH with tools and hang in derrick. 9/28/2000 00:00 - 01:30 1.50 DRILL FORM INT1 Connect top drive and work 6 3/4 turns left hand torque (17,000 fi/lb) down string after string shot at 8447'. No back off. 01:30 - 14:30 13.00 DRILL FORM ~INT1 Rig up Schlumberger side entry sub and swivel. RIH with free point indicator. Tool failure, change out free point indicator tool. Took several free point readings at depths between 8360' and 8490'. Pipe 100% free down to top of jars, some indication of free pipe below jars in flex joints but to a much lesser degree. POH and hang tools in derrick. 14:30 - 16:00 1.50 DRILL FORM INT1 Work pipe. Jarring and working torque down string while preparing string shot. 16:00 - 17:30 1.50 DRILL FORM INT1 RIH with Schlumberger string shot to 8417'. Connection below jars. Tools went to bottom without pumping as mud was heated up to 95? F during the day while circulating slowly. 17:30 - 19:30 2.00 DRILL FORM INT1 Circulate. Spot 25 bbls "SFT" spotting pill around BHA. 19:30 - 21:00 1.50 DRILL FORM INT1 Work torque down string, 8 314 left hand turns into string (19000 fi/bi) Fire string shot at 8416' at bottom of jars. No immediate indication of back off. 21:00 - 22:00 1.00 DRILL FORM INT1 POH with Schlumberger tools and hang in derrick. Left in hole, 2 centralizers and one 3' section of string shot rod. 22:00 - 23:00 1.00 DRILL FORM INT1 Work pipe and torque string to left attempt to back off. No success. 23:00 - 00:00 1.00 DRILL FORM INT1 RIH with Schlumberger string shot to attempt back off at 8387' 9~29~2000 00:00 - 01:00 1.00 DRILL FORM INT1 RIH with Schlumberger string shot to attempt back off at 8386'. Not necessary to pump tools down. SFT pill in place around BHA. 01:00 - 03:30 2.50 DRILL FORM INT1 Work 8 1/2 left hand turns (19000 fi/lb) into pipe and work down. Fired string shot at 8386', top of jars. Good indication of back off. 03:30 - 05:00 1.50 DRILL FORM INT1 POH Schlumberger wire line tools and rig down logging unit. 05:00 - 08:30 3.50 DRILL FORM INT1 POH with 5" drill pipe and HWDP an dstand in derrick. Top of fish 8386'. Box of jars looking up. 08:30 - 11:00 2.50 DRILL FORM INT1 Pick up 4 joints of 8 1/8" wash-over pipe with 9 5/8" OD shoe, Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 5 of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 9/29/2000 08:30 - 11:00 2.50 DRILL FORM INT1 wash-over safety joint, bumper jar and oil jar on 21 joints HWDP. See remarks page for details. 11:00 - 11:30 0.50 DRILL FORM INT1 Service rig and top drive. NOTE: AOGCC representative John Crisp waived BOP test scheduled for today due to fishing job. 11:30 - 14:30 3.00 DRILL FORM INT1 Slip and cut driling line. 14:30 - 18:00 3.50 DRILL FORM INT1 RIH 5" drill pipe, break, re-dope and re-torque each connection. Held up at 5662'. 18:00 - 20:30 2.50 DRILL FORM INT1 Wash and ream several spots from 5662' to 6400'. 20:30 - 23:00 2.50 DRILL FORM INT1 RIH to 8319'. Break circulation. 23:00 - 00:00 1.00 DRILL FORM INT1 Wash and ream from 8319' to 8226'. 9~30/2000 00:00 - 02:30 2.50 DRILL FORM INT1 Wash and ream to top of fish at 8386'. Work wash pipe over fish and wash over to 8513'. Large pieces of coal over shakers. 02:30 - 04:30 2.00, DRILL FORM INT1 Circulate and condition mud. Spot 25 bbl SFT pill around fish. 04:30 - 09:00 4.50 DRILL FORM INT1 POH with wash over pipe. Tight hole from 8320' to8230', 20K over pull. POH stand back 5" drill pie. 09:00 - 11:00 2.00 DRILL FORM INT1 POH lay down 9 its HWDP, 4 jts wash over pipe and tools. 11:00 - 15:00 4.00 DRILL FORM INT1 RIH with fishing BH^ with screw in sub. See remarks page for details. Run in to 7500', break circulation. Run in to 8330'. 15:00 - 16:00 1.00 DRILL FORM INT1 Circulate bottums up at 200 SPM with 1430 psi. Clean up shakers. Fill drill pipe with 1007 F mud before stop circulating. 16:00 - 22:00 6.00 DRILL FORM INT1 Screw into fish at 8386'. Work torque down string. Jar up 375,000 and down to 90,000. Circulate 500 GPM 1430 psi while jarring. No i progress. .22:00 - 00:00 2.00 DRILL FORM INT1 Rig up Schlumberger side entry sub and swivel for string shot. PJSM. 10/1/2000 :00:00 - 02:30 2.50 DRILL FORM INT1 RIH with Schlumberger string shot with 7 strands of primer cord to 8479'. 02:30 - 04:00 1.50 DRILL FORM INT1 Work 8 3/4 left hand turns into string. Spot 25 bbl SFT pill around fish. String machanicaly backed off at screw in sub at top of jars. Confirm with CCL. 04:00 - 05:30 1.50 DRILL FORM INT1 POH with wire line tools. Rig down side entry sub and swivel, leave sheaves in derrick. 05:30 - 06:30 1.00 DRILL FORM INT1 Engage fish at screw in sub and work 30,000 ft/Ibs right hand torque down string. 06:30 - 07:30 1.00 DRILL FORM INT1 Rig up Schlumberger side entry sub and swivel. RIH with string shot to 8479'. 07:30 - 09:30 2.00 DRILL FORM INT1 Work 8 1/2 left hand turns into string. Fire string shot at 8479' at top of bottom flex collar. Good indication of back off. 09:30 - 11:00 1.50 DRILL FORM INT1 POH with wire line tools. Rig down side entry sub, swivrl and sheves and logging unit. 11:00 - 15:30 4.50 DRILL FORM INT1 POH stand back 5" drill pipe. Recovered drilling jars and 2 jts flex collars. Top of fish 8479' 15:30 - 18:30 3.00 DRILL FORM INT1 RIH with fishing BHA with screw in sub to casing shoe. See remarks page for BH^ deatils. 18:30 - 20:00 1.50 DRILL FORM INT1 Slip and cut drilling line, service top drive and inspect brakes. 20:00 - 21:30 1.50 DRILL FORM INT1 RIH to 8464' 21:30 - 22:30 1.00 DRILL FORM INT1 Circulate and condition mud at 580 GPM with 1450 psi. 22:30 - 00:00 1.50 DRILL FORM INT1 Engage fish at 8479°. Jar on fish up and down, 400,000 max pull. No progress. 1012/2000 00:00 - 07:00 7.00 DRILL FORM INT1 Jarring up and down on fish. Max over pull 400,000 lbs. No progress. 07:00 - 09:30 2.50 DRILL FORM INT1 Rig up Schlumberger side entry sub and swivel. RIH with 6 strands string shot to 8479'. 09:30 - 15:00 5.50 DRILL FORM INT1 Work left hand torque down drill pipe. Made uncontrolled back off. Printed: 1119/2000 10:12:11 AM BP EXPLORATION Page 6 of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 10/2/2000 09:30 - 15:00 5.50 DRILL FORM INT1 Pulled wire line into drill pipe as precaution. Made up string to 25,000 ft/Ibs torque. Work 6 left hand turns into string and work down. Fired string shot at 8479'. Obtained back off. Run wire line back in to confirm back off with CCL. 15:00 - 16:30 1.50 DRILL FORM INT1 POH with wire line. Rig down side entry sub, swivel and logging unit. 18:30 - 20:30 4.00 DRILL FORM INT1 POH stand 5" drill pipe in derrick. Test choke manifold to 250 psi and 3500 psi on trip out. 20:30 - 21:30 1.00 DRILL FORM INT1 Lay down Baker fishing tools and clean up rig floor. 21:30 - 22:30 1.00 DRILL FORM INT1 Service top drive. Inspect derrick and drawworks 22:30 - 23:30 1.00 DRILL FORM INT1 Function test BOP rams and both hydraulic valves. Blow down lines. Met AOGCC requirements for weekly BOP test. 23:30 - 00:00 0.50 DRILL FORM INT1 Make up 9" wash over pipe with 9 3/4" shoe and tools. See remarks page for BHA details. 10/3/2000 00:00 - 01:30 1.50 DRILL FORM INT1 Make up 3 joints of 9" wash over pipe with 9 3/4" shoe and tools. 01:30 - 10:00 8.50 DRILL FORM INT1 RIH with washover pipe. Work through tight spot at 5600'. Work pipe , through and circulate from 6870' to 6900'. Partial loss of circulation. 10:00 - 11:00 1,00 DRILL FORM INT1 Circulate at a reduced rate, regain full circulation. Total losses 30 bbl. ' 11:00 - 13:00 2.00 DRILL FORM INT1 RIH washing down every stand from 6900' to top of fish at 8479'. 13:00- 14:00 1.00 DRILL FORM INT1 Circulate and condition mud. 14:00 - 19:00 5.00 DRILL FORM INT1 Wash over fish at 8479'. Wash down with no rotation to 8518' taking weight, 55,000 lbs. Wash down with rotation, 55 RPM with 3,000 to 5,000 weight on bit with torque fluctuating between 16K and 23K. Wash last 12' with no ratation to 8564' top of stabiliser on MWD. 19:00 - 19:30 0.50 DRILL FORM INT1 Circulate and spot 25 bbl SFT pill around washed over section of BHA. 19:30 - 00:00 4.50 DRILL FORM INT1 POH slowly to shoe to avoid swabbing. Check for flow at shoe. Stand back 5" drill pipe and HWDP. 10/4/2000 00:00 - 01:00 1.00 DRILL FORM INT1 POH and lay down 9" washover pipe and tools. 01:00 - 02:00 1.00 DRILL FORM INT1 Make up fishing/jarring BHA with screw in sub. 02:00 - 05:00 3.00 DRILL FORM INT1 RIH to top of fish at 8479'. 05:00 - 06:00 1.00 DRILL 'FORM INT1 Circulate bottoms up wash top of fish. 06:00 - 10:00 4.00: DRILL , FORM INT1 Jar down and work pipe with torque for first hour and a half. Work pipe up and down. No progress. 10:00 - 11:00 1.00 DRILL 'FORM INT1 Rig up Schlumberger side entry sub and swivel. PJSM. RIH with string shot to 8479' 11:00 - 15:00 4.00 DRILL FORM INT1 Work 4 1/2 left hand turns down drill pipe. Fire string shot. Work pipe and obtain back off. Pick up 10' 15:00 - 16:30 1.50 DRILL FORM INT1 Log down with CCL to confirm back off. POH with wireline. Rig down side entry sub and swivel, and logging unit. 16:30 - 20:00 3.50 DRILL FORM INT1 POH stand back 5" drill pipe and HWDP. 20:00 - 22:00 2.00 DRILL FORM INT1 POH lay down fishing/jarring BHA. Left screw in sub in hole. Top of fish 8476' 22:00 - 00:00 2.00 DRILL FORM INT1 RIH 5" drill pipe with mule shoe. 10/5/2000 00:00 - 01:30 1.50 DRILL FORM INT1 RIH with 5" drill pipe to top of fish at 8476' 01:30 - 02:30 1.00 DRILL FORM INT1 Circulate to clear drill pipe. 02:30 - 03:00 0.50 DRILL FORM INT1 Rig up cement lines. PJSM. Test lines to 3000 psi. 03:00 - 04:00 1.00 DRILL FORM INT1 Mix (Batch mix) and pump 62 bbl class "G" cement at 17.0 ppg. Pump 37 bbl of neat slurry followed by 25 bbl of slurry with red dye. Displaced with rig pumps. Cement in place at 03:45. Top of plug calculated at 7976' 04:00 - 04:30 0.50 DRILL FORM INT1 POH 8 stands slowly to 7224'. 04:30 - 06:30 2.00 DRILL FORM INT1 Reverse circulate. No cement returns. Some contaminated mud Printed: 1119/2000 10:12:11 AM BP EXPLORATION Page 7 of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: N^BORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 1015/2000 04:30 - 06:30 2.00 DRILL FORM INT1 returned, bump 93 bbl. Open annular preventor and circulate. 06:30 - 09:00 2.50 DRILL FORM INT1 POH to shoe. Break, re-dope and re-torque all drill pipe connections. 09:00 - 10:30 1.50 DRILL FORM INT1 i Slip and cut 91' drilling line. Service and inspect top drive. 10:30 - 14:30 4.00 DRILL FORM INT1 POH. Break, re-dope and re-torque all drill pipe connections. 14:30 - 15:00 0.50 DRILL INT1 Pull wear bushing. 15:00 - 17:30 2.50 DRILL INT1 Test BOP, all safety valves on rig floor and top drive safety valves to 250 psi Iow and 3500 psi high. Witnessed by Lou Grimaldi o fAOGCC. 17:30 - 18:00 0.50 DRILL NT1 Install wear bushing. 18:00 - 19:00 1.00 DRILL FORM INT1 Change hydraulic cylinder on top drive link tilt. 19:00 - 22:00 3.00 DRILL FORM INT1 Pick up drilling BHA with new bit. Load MWD. 22:00 - 00:00 2.00 DRILL FORM INT1 RIH to casing shoe. Circulate and check MWD. 1016/2000 00:00 - 01:30 1.50. DRILL FORM INT1 RIH. Check MWD at 7009'. RIH to 7602' 01:30 - 04:00 2.50 DRILL FORM NT1 Wash to 7950'. Start drilling firm cement at 8017' 04:00 - 04:30 0.50 DRILL INT1 Circulate and condition mud. 04:30 - 00:00 19.50 DRILL INT1 Drill from 8017'. Time drill with tool face on Iow side and sliding to start side track. Slide and rotate to maintai hole angle and direction. 10/7/2000 00:00 - 06:00 6.00 DRILL INT1 Drill from 8185' to 8374'. Make 500 bbl new mud dilution to system. AST = 3 hr. ART = 1 hr. PU =240K. SO =95K. ROT -- 137K @ 550 gpm & 2000 psi. Control ROP while rotating to less than 60 FPH for hole stability. Erratic torque and drag on slides. Stalled and no .longer able to slide. Worked parameters and still not sliding. Pumped sweep wi no change. 06:00 - 07:30 1.50 DRILL FILL INT1 Short trip to 7950' and back to bottom. Pu -- 225K. SO = 100K after trip. 07:30 -. 12:30 5.00 DRILL INT1 Drill to 8560. Torque reduced but still difficult to slide. Sweep hole and start Lub-tex mud treatment. Sliding improved. Increase rotating time and ROP while rotating to controled at 100 FPH. PU = 225K. SO = 95K. ROT = 137K. {~ 70 RPM w/19 K fflb torque. 2300 psi ~ 600 GPM. ~12:30 - 00:00 11.50 DRILL INT1 Drill 8560' to 9217'. Torque gradualy increased to 20,000 fi/lbs. Increase mud weight to 10.4 ppg. 10/8/2000 00:00 - 04:00 4.00 DRILL INT1 Drill from 9217' to 9405'. Torque increasing to 24,000 fi/lbs. ART 2 1/2. AST 1. 04:00 - 05:00 1.00 DRILL INT1 Circulate Hi-Vis pill around with lubricants. 05:00 - 07:00 2.00 DRILL INT1 Wiper trip 15 stands to 8015' top of kick off point. PU -- 250K, SO = 95K. off bottom. SO -- 225K in old hole. 07:00 - 17:00 10.00 DRILL INT1 Drill from 9405' to 9975'. Adding lubricant to mud system Torque up to .26000 ftlb. Troque responding to lubricant but building slowly. Electrical fire in Mud pump #1, stop pump. 17:00 - 17:30 0.50 DRILL INT1 Rig repairs. Mud pump #1 down. Trouble shoot electrical problem. i Circulate slowly with #2 pump. 17:30 - 20:15 2.75 DRILL ClRC INT1 POH to 6300' while repairing #1 mud pump. 20:15 - 21:00 0.75 DRILL INT1 POH to casing shoe. 21:00 - 21:30 0.50 DRILL CIRC INT1 Circulate and check mud pump #1. 21:30 - 23:00 1.50 DRILL INT1 RIH from casing shoe to 3600' 23:00 - 00:00 1.00 DRILL ClRC INT1 RIH from 3600' to 9975' 10/9/2000 00:00 - 00:30 0.50 DRILL INT1 RIH to 9975'. Wash last 90' to bottom as precaution. Trip OK. 00:30 - 00:00 23.50 DRILL INT1 Drill from 9975' to 11,174'. Torque rediced to 17,000 fi/lbs with addition of Baro-Trol to the mud. WOB 2K-10K. 3300 psi. 625 GPM. ART 16.5. AST0. 10/10/2000 00:00 - 00:30 0.50 DRILL INT1 Drill tangent at 527. to 11250'. PU = 225K. SO = 130K ROT = 163K. WOB = 9 - 12 K. Torque = 18K ftlb @ 80 rpm. 3050 psi @ 625 gpm. Printed: 1119/2000 10:12:11 AM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: S-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: N^BORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date 'From-To Hours Task Sub Code Phase Description of Operations 10/10/2000 00:30 - 01:30 1.00 DRILL INT1 Circulate hi-vis sweep while reciprocate and rotate. 01:30 - 02:30 1.00! DRILL INT1 Survey, Pump dry job and short trip to 9950'. PU = 250K. 02:30 - 03:30 1.00 DRILL INT1 RIH. No exess drag or fill. 03:30 - 17:30 14.00 DRILL INT1 Drill and build angle to 73? from 11250' to 11712°. PU = 225K. SO = 130K ROT = 163K. WOB = 10 - 12 K. Torque -- 18K ftlb (~ 80 rpm. 3300 psi @ 625 gpm. ART = 4. AST = 7.5 17:30 - 19:45 2.25 DRILL INT1 Circulate bottom up for geololigic sample. 19:45-20:15 0.50 DRILL INT1 Drill from 11712' to 11727'. PU-- 225K. SO= 130K ROT= 168K. WOB = 5 - 10 K. Torque --' 16K ftlb ~ 80 rpm. 3400 psi (~ 625 gpm. AST -- 112 20:15 - 21:30 1.25 DRILL INT1 Circulate bottom up for geololigic sample. 21:30 - 23:30 2.00 DRILL INT1 Wiper trip 10 stands to 10,800'. Normal drag, no fill. 23:30 - 00:00 0.50 DRILL INT1 Circulate hi-vis sweep and spot pill on bottom for casing job. 10/11/2000 00:00 - 01:00 1.00 DRILL INT1 Spot 100 bbl casing running pill at TD. Pump dry job. 01:00 - 07:00 6.00 DRILL INT1 POOH to 4800" laying down DP. No excess drag. 07:00 - 08:00 1.00 DRILL INT1 Slip and cut Drilling line 08:00 - 12:00 4.00 DRILL INT1 POOH and LD DP and HWDP 12:00 - 16:00 4.00 DRILL INT1 POOH and LD BHA 16:00 - 16:30 0.50 CASE INT1 Pull wear bushing. 16:30 - 19:00 2.50 CASE i lNT1 Change out top rams to 7". Test doors to 250 psi and 3500 psi for 10 minutes. 19:00 - 21:00 2.00 CASE INT1 Rig up to run 7" casing. Install Franks Fill Up/Circulating Tool and Air Slips/Elevators. Hold PJSM with crew and third party contractors. 21:00 - 00:00 3.00 CASE INT1 Run 7" 29~ L-80 casing. Check Floats, thread lock shoetrack. 10/12/2000 00:00 - 03:00 3.00 CASE INT1 Run 55 jts 7" 29.0 # 1-80 MBTC casing to 2300'. 03:00 - 04:00 1.00 CASE INT1 CBU mud cold and thick. Vis 300 sec.declined to 120 sec. 04:00 - 06:00 2.00 CASE INT1 RIH to joint # 111 at 4550'~vl full returns. RIH tojt 113 at 4630' and had sudden complete loss of retums. 06:00 - 08:00 2.00 CASE CIRC INT1 Work pumps to attempt to regain circ. Fillup tool BPV requires 300 psi. to open. Therefore circ at 1.5 & 400psi to 2.5 bpm & 540 psi w/no returns. Work pipe to break mud gell strength wi no change. NU circ swedge and circulate at 0.75 bpm and 370 psi w/no returns. Hole standing full when static. Hole swabbing on upstroke. Total loss to hole = 137 bbl. 08:00 - 12:00 4.00 CASE ClRC INT1 Build mud volume, evaluate design of casing and cement and bring additional stage collar and centralizers to rig. 12:00 - 13:00 1.00 CASE INT1 PUjt. #114 W centralizer, Port collar and Jr# 115w/centralizer. 13:00 - 13:30 0.50 CASE INT1 Take on mud from truck. 13:30 - 21:00 7.50 CASE INT1 Run 7" casing centralizing every other jt. to jt # 165. Continue RIH to 8680'. No mud returns. PU -- 250 K SO = 78 K. Hole becoming sticky and drag increasing once past 8680'. Continue RIH to 9530'. PU = 290K# SO = 80 K# 21:00 - 21:30 0.50 CASE INT1 Make up second Tam Port Collar w/centralizers above and below. Casing stuck after 5 min. on slips. Work pipe to PU = 450 K# and SO = 50 K#. Pulled loose. 21:30 - 00:00 2.50 CASE INT1 Run 7" casing to jt # 283. Pick up 20' pup joint and attempt to wash down. Final PU -- 370 K PU = 102K No returns and pipe stuck with shoe at 11717'. Total of 600 bbl mud lost while running casing and attempting to circulate. 10113/2000 00:00 - 04:30 4.50 CASE INT1 Lay down 7" X 20' pup joint. Rig down fill-up tool. Rig up cementing head and lines. Mix 10.2 ppg mud volume for displacing cement. Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 9 of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG ,Rig Name: N^BORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 10/13/2000 00:00 - 04:30 4.50 CASE INT1 PJSM. Test cement lines. 04:30 - 07:30 3.00 CASE INT1 Mix and pump 312 sx (155 bbl) class "G" cement at 11.54 ppg as lead followed by 319 sx (66 bbl) "G" cement at 15.8 ppg as tail. Displace with 422 bbls mud with rig pumps. Plug did not bump. Top of cement calculated at 7500'. 07:30 - 16:00 8.50 CASE INT1 Pick up BOP, split stack at casing head and tubing head flanges. Install FMC C-21 casing slips and land 7" casing with 60,000 lbs tension. Cut casing, remove cut off section. Install primary pack off assembly, make final cut on casing and install tubing head with secondary pack off pre-installed. Test pack off to 4500 psi. OK. 16:00 - 19:30 3.50 CASE INT1 Nipple up BOP. Change rams to 2 7~8" X 5" variable. 19:30 - 20:30 1.00 CASE INT1 Inject fresh water down 7" x 10 3/4" annulus with 3 BPM at 1100 psi with rig pumps. 20:30 - 22:30 2.00. CASE INT1 Rig up top drive with 4" equipment. 22:30 - 23:30 1.00 CASE INT1 Rig up to test BOP. PJSM with rig crew and third party contractor 3ersonnel. 23:30 - 00:00 0.50 CASE INT1 Rig up Schlumberger cement lines to well head 7" x 10 3~4" annulus and test to 3000 psi. 10/14/2000 00:00 - 03:30 3.50 CASE INT1 Test BOP to 250 psi and 350 psi for 5 and 10 minutes. AOGCC rep Joe Spalding waived witness of test. Pumped top cement job of 150 sx (118 bbl) Arcticset lite at 10.7 ppg while testing BOP. See remarks and cementing report for details 03:30 - 07:00 3.50 DRILL PROD1 Make up BHA with 6" bit. Load and test MWD, adjust bent housing on motor to 1.837. 07:00 - 20:00 13.00 DRILL PROD1 Pick up 4" drill pipe. Pull 30 stands and stand in derrick. Continue picking up drill pipe and RIH with BHA. 20:00 - 20:30 0.50 DRILL PROD1 Service top drive and repair hydraulic leak. 20:30 - 00:00 3.50 DRILL PROD1 Pick up 4" drill pipe and RIH. Tag up at 11484'. Connect top drive. ( Top of cement 147 ft high ). 10/1512000 00:00 - 03:00 · 3.00 DRILL PROD1 Drill Medium Hard Cement from 11,484 ft ( 147 ft high ) to 11,631 ft. 60 fi- 80 fi/hr. 03:00 - 04:00 1.00 DRILL PROD1 Circulate Bottoms up ~ 245 GPM/2300 psi. Conduct Reservoir Meeting while Circulating. ;04:00 - 05:00 1.00 CASE PROD1 :Test 7" Casing to 500~3500 psi for 5/30 mins. 5.2 bbls Pumped. 105:00 - 07:30 2.50 DRILL PROD1 : Drill Remainder of Shoetrack @ 60-80 fi/hr and clean out rathole ~11,727 ft. Work thru 7" shoe several times 07:30 - 09:00 1.50 DRILL PROD1 I Displace hole to 10.4 ppg Mud system @ 245 GPM/2500 psi. 09:00 - 11:00 2.00 DRILL PROD1 Slide Drill 6" hole for 20 ft of new formation to 11,747 ft. AST= 1.5 I hours. AST 1 112 ART 0 11:00 - 12:30 1.50 DRILL PROD1 Circulate bottoms up for FIT 12:30 - 13:15 0.75 DRILL PROD1 Conduct FIT to 12.6 ppg EMW. 780 psi surface pressure w/ 10.4 ppg Mud weight. 7" Shoe @ 11,717 ft MD/6795 ft TVD. 0.9 bbls pumped/returned. 13:15 - 00:00 10.75 DRILL PROD1 Drill 6" directional hole from 11747' to 11941'. Rotate and slide. AST 4 1/2 ART 3 1/2 WOB 12 klbs. No drag, no losses. P/U weight 170 klbs, S/O 103 klbs. 10/16/2000 00:00 - 00:00 24.00 DRILL PROD1 Drill 6" directional hole from 11941' to 12749'. Rotate and slide. AST 3 ART 12 WOB 15 klbs. No drag, no losses. P/U weight 164 klbs, S/O 102 klbs. Drilling break at 12440' flow check. Adding Lube-Tex lubricant to help with torque. Pumping 25 bbl Hi-vis weighted sweeps every 400'. 10/17/2000 00:00 - 07:30 7.50 DRILL PROD1 Drill 6" directional hole from 12794' to 13144'. Rotate and slide. AST 1 1/2 ART 7 1/4. WOB 15 klbs. No drag, no losses. P/U weight 165 Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 10 of 12 Operations Summar Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 10117/2000 00:00 - 07:30 7.50 DRILL PROD1 klbs, S/O 98 klbs. Pumping 25 bbl Hi-vis weighted sweeps every 400'. Sudden ROP drop at 13144' 07:30 - 08:30 1.00 DRILL PROD1 Circulate bottom up for sample- HRZ in sample. Preare to drop angle. 08:30 - 00:00 15.50 DRILL PROD1 Drill 6" directional hole from 13144' to 13402'. Rotate and slide. Drop angle in stages down to 82 degrees once a geological fault had been established to look for sand on the down throw side AST 1 3/4 ART 6 3/4. WOB 15 klbs. No drag, no losses. P/U weight 165 klbs, S/O 95 klbs. Changed out 85% of mud in system with new mud at 13250'. 10/18/2000 00:00 - 07:30 7.50 DRILL PROD1 Rotate ahead 6" hole thru HRZ to find sand on downthrow side of fault @ 20-10 ft/hr. All Drilling parameters steady until 13,484- indications of Formation change. P/U 165 klbs, S/O 95 klbs. ART= 7.5 hrs 07:30 - 10:00 2.50 DRILL TGHT PROD1 P/U after motor stalled- Stuck pipe -free same and slowly backream experiencing stalling/packing off and overpulls to get above HRZ to 13,095'. Loosing fluid @ 30-60 bls/hr into HRZ- Vary all parameters to get above shale. 10:00 - 12:00 2.00 DRILL PROD1 Work and reciprocate pipe while sweeping hole clean @ 235 GPM/ 2800 psi. Excessive HRZ cavings on bottoms up. No luther fluid losses. All parameters steady. 12:00 - 13:30 1.50 DRILL PROD1 POOH to 7" shoe @11,717 ft- hole good. 13:30 - 15:30 2.00 DRILL PROD1 Service Top Drive/Drawworks and cut drill line. 15:30 - 16:30 1.00 DRILL PROD1 RIH, precautionary wash down last two stands to 13,100' staging up pumps gradually to 235 GPM/2800 psi 16:30 - 19:30 3.00 DRILL PROD1 Sweep hole clean. Some HRZ cavings from bottoms up. Circulate ~ shakers clean. Spot Liner running pill. 19:30 - 21:00 1.50 DRILL PROD1 'FC. POH to 12,189' and drop ESS, take survey shots and pull to 7" shoe @ 11,717'. Hole i good shape. 21:00 - 21:30 0.50 DRILL PROD1 Flowcheck @ shoe. Drop 2.375" hollow rabbit. 21:30 - 00:00 2.50 DRILL PROD1 POOH. Note: 90 bbls Lost downhole as result of packing off. 10/19/2000 00:00 - 03:00 3.00 DRILL I PROD1 POOH 4" drillpipe and L/D 23 joints of HWDP. Recover ESS and rabbit. 03:00 - 05:00 2.00 DRILL PROD1 L/D BHA. Flush same. Download LWD. Inspect bit. Clear rigfloor. '05:00 - 06:30 1.50 CASE COMP R/U to run 4.1/2" Bonzai Liner. PJSM. '06:30 - 09:30 3.00 CASE COMP Run 20 joints 4.1/2" Slotted liner, Landing collar, Pup Joint, CTC packer, ES cementer, 17 joints solid 4.1/2", Pup Joint, Baker HMC hanger and Baker ZXP Packer. Change to Drillpipe handling elevators. No downhole losses. 09:30 - 23:00 13.50 CASE COMP RIH on 4" drillpipe to 11,671 ft. Running slow due to fiowback up drilpipe. No downhole losses. 23:00 - 00:00 1.00 CASE COMP M/U cement head and stand back. Circulate drillpipe and liner volume @ 2.8 BPM/775 psi Note: JORPS not satisfied. ESS hung up in dogleg- no satisfactory survey. 10/20/2000 00:00 - 03:00 3.00 CASE COMP cont. RIH w/41/2" Liner on 4" DP fr. 11670' to 13075'. No Drag. Hole Slick. 03:00 - 09:30 6.50 CASE COMP Pu Cmt. Hd. on single RIH to 13100'. Circ. Btms. up. Drop 1st. dart. Test lines w/Rig pump to 3500 psi. Pump dart to 1st wiper plug and latch in Idng. cir. Had to pres. up to 3000 psi 3 times to set HMC. Cont. prgrm. ECPclosed w/.1 bbl. Switch to Dowell and open ES type H cementer. Pump spacer, 11.5 bbls Cmt and drop plug as per prgm. Printed: 11/912000 10:12:11 AM BP EXPLORATION Page 11 of 12 Operations Summa Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: N^BORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 10/20/2000 03:00 - 09:30 6.50 CASE COMP Displ. CMT w/Rig. Note '. rig pumps proved 99 to 100% efficient. Land Dart, Close cementer, release & set Hgr. circ clean. No downhole losses. 09:30 - 14:30 5.00 CASE COMP POH w/4" DP LD 62 Jts, LD Running Tool- everything OK. 14:30 - 19:00 4.50 CASE COMP Test BOPE 250/3500 psi. AOGCC- John Crisp witnesssed. 19:00 - 19:30 0.50 CASE COMP Pressure test 7" Csg to 500 / 3000 psi 19:30 - 23:00 3.50 CASE COMP M/U Tam Shifting Tool, RIH to 2100' 23:00 - 00:00 1.00 CASE COMP Drop ball, set pkr, test to 1000psi-Ok. Open PC. Circ. dn DP and up 7"X 10 3/4" ann. w/135 bbls mud @5 bbl/min and 333psi 10/2112000 00:00 - 05:30 5.50 CASE COMP Reverse Circulate Hot Oil Freeze Protect ~ 2.5 BPM. Observe Oil @ Surface after only 90 bbls Pumped ( = 1500 ft in annulus). Circulate out Oil and attempt to clean up annulus @ higher rate= 9 BPM/800 psi. Loose seal on Tam Tool. Attempt to reset- No Go 05:30 - 08:00 2.50 CASE PROP COMP POOH to inspect Tool. Cups OK. Ball seat OK. Replace cups and ensure all seals intact. 08:00 - 09:30 1.50 CASE PROP COMP RIH and reset Tool and test to 1000 psi OK-Open Port. 09:30 - 14:00 4.50 CASE COMP Circulate annulus @ 6 BPM/500 psi. Reverse circulate Hot Oil ~ 1 BPM. Observe breakthrough ~ 93 bbls. ( =1500 ff if account for drillpipe volume or 1800 ft if breakhrough came straight up drillpipe 14:00 - 15:00 1.00 CASE COMP ,Test Casing to 500 psi/3500 psi for 30 minutes. 4.2 bbls Pumped/ Returned. 15:00 - 18:00 3.00 CLEAN COMP M/U BHA RIH 1900' Test Motor 90 gpm @ 535psi 18:00 - 00:00 6.00 CLEAN COMP Cont. RIH on 4" DP Break circ. every 3500' RIH to 11526' 10/22/2000 00:00 - 02:30 2.50 CLEAN COMP RIH with 3.75" Flat Mill cleanout assembly and tag TOC @ 12,264 ft. 02:30 - 16:00 13.50 CLEAN COMP Drill Plugs and cement from 12,264 ft to 12, 314 ft. Very slow progress getting through plugs with constant stallouts on Motor. Rotate @ 20 RPM/8000 fi/lbs. Up weight 200 Klbs, down 120 klbs, Rotate Weight @ 132 klbs. 16:00 - 16:30 0.50 CLEAN COMP RIH to Shoe ~ 13100". 16:30 - 21:00 4.50 CLEAN COMP Break circ. pump 100 bbl. 10.2 ppg brine. Drop vinyl PBL ball. Chase wi 40 bbl HI-VIS sweep & cont. pumping 10.2 ppg. brine, observe Ball seat,cont.to pump brine @ 9.5 bbl/min w! 2900 psi. 21:00 - 22:30 1.50 CLEAN COMP Clean flowlines, shakers and pits in order to keep filtered brine clean 22:30 - 00:00 1.50 CLEAN COMP Cont. circ. wi clean 10.2 ppg brine. 45 NTU final in and out. 10/23/2000 00:00 - 01:30 1.50 CLEAN COMP Circulate closing steel ball down and close PBL.Flowcheck. 10.2 ppg BRine ~ 45 NTU in well. No downhole losses. 01:30 - 04:00 2.50 CLEAN COMP POOH standing back 70 stands of 4" DP for Rig Move to S-105. 04:00 - 05:30 1.50 CLEAN COMP Slip and cut Drill line. Service Top Drive. 05:30 - 12:30 7.00 CLEAN COMP POH laying down 159 joints of 4" drillpipe, 42 joints of 2.7~8" pipe and Milling assembly. Clear rigflor. Pull Wear ring. 12:30 - 13:30 1.00 RUNCO~ COMP PJU Tubing Handling Equipment and hold PJSM. 13:30 - 00:00 10.50 RUNCO~ COMP RIH w/completion string 10/24/2000 00:00 - 02:30 2.50 RUNCO~ COMP Cont. RIH wi 4.5" Tbg. compl, assy. 02:30 - 04:30 2.00 RUNCO~ COMP Tagged Baker Pkr at 11550' on down stroke ( 90K slack off wt). pulled up 2', marked pulled up and spaced out Hanger. Drained stack and verified hanger will set fully. Pull Hgr. above mud X. 04:30 - 09:00 4.50 RUNCOt COMP Displace tbg and annulus with heated filtered 10.2 ppg brine. 09:00 - 12:00 3.00 RUNCO~ COMP Land Hanger in Tubing HeadDrop ball rod for RHC plug. Set pkr. Test tbg.to 3500 psi.for thirty min.Test annulus to 3500 psi.- 30 min. Shear RP. Bleed to 0. 12:00 - 12:30 0.50 RUNCO~ COMP Set TWC, pressure test to 1000 psi Printed: 11/9/2000 10:12:11 AM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 8-102 Common Well Name: S-102 Spud Date: 9/14/2000 Event Name: DRILL+COMPLETE Start: 9/14/2000 End: 10/24/2000 Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG ~Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 10/24/2000 :12:00- 12:30 0.50 RUNCOI~ COMP 12:30 - 14:00 1.50 RUNCOI~ COMP R/D Lines, N/D BOP & Set Back 14:00 - 18:00 4.00 RUNCOI~I COMP N/U Adaptor flange and Tree, Test both to 5000 psi. PJU lubricator-test- pull TWC. 18:00 - 20:00 2.00 RUNCOI~I COMP PJSM - Rig up HOT Oilers Test lines to 2500 psi. Displace 72 bbls. diesel down annulus. Allow oil to "U" tube into tubing, left 275 psi on tbg. 20:00 - 21:00 1.00 RUNCO~ COMP PJU lubricator, test. set BPV in tubing head PJD lubricator. Secure well. RIG 9 ES RELEASED FROM WELL S -102 AT 2100 HRS., 24 OCTOBER 2000 Printed: 111912000 10:12:11 AM North Slope*Alaska Alaska State Plane 4 PBU_ WOA S Pad S-102 mwd Surveyed: 18 October, 2000 SURVEY REPORT 10/27/2000 14:30:09 PM Your Ref: API-500272297200 Surface Coordinates: 5980655.13 N, 618929.96 E (70° 21' 20.8844" N, 149° 02' 02.9105" W) Kelly Bushing: 64.20ft above Mean Sea Level 13 I '{~ Survey Ref: svy10545 Sperry-Sun Drilling Services Survey Report for S-102 mwd Your Ref: API-500272297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7983.42 64.700 321.240 4576.54 4640.74 8017.00 64.700 321.240 4590.89 4655.09 8022.83 64.680 321.860 4593.39 4657.59 8054.42 63.910 320.810 4607.09 4671.29 8087.04 61.670 322.240 4622.00 4686.20 8119.23 59.710 321.300 4637.76 4701.96 8150.33 58.960 321.720 4653.62 4717.82 8214.28 58.480 321.340 4686.83 4751.03 8308.29 55.480 321.020 4738.05 4802.25 8339.63 55.220 322.180 4755.87 4820.07 8369.03 54.340 320.680 4772.83 4837.03 8399.89 54.150 321.410 4790.86 4855.06 8461.29 52.940 322.500 4827.34 4891.54 8493.11 53.130 321.930 4846.48 4910.68 8588.00 53.340 321.980 4903.27 4967.47 8678.92 53.360 322.370 4957.54 5021.74 8774.16 52.530 323.880 5014.94 5079.14 8868.11 52.920 324.030 5071.83 5136.03 8960.85 52.930 324.180 5127.74 5191.94 9056.34 53.170 324.590 5185.15 5249.35 9149.40 53.320 324.890 5240.83 5305.03 9243.63 52.400 323.900 5297.72 5361.92 9336.99 51.960 323.490 5354.97 5419.17 9430.48 51.850 323.830 5412.65 5476.85 9522.85 52.050 323.010 5469.58 5533.78 4418.51N 3375.88W 5985019.49N 615484.35 E 4442.19 N 3394.89W 5985042.86 N 615464.97E 4446.32 N 3398.17W 5985046.94 N 615461.63 E 4468.54 N 3415.95W 5985068.88 N 615443.50 E 4491.25 N 3434.00W 5985091.29 N 615425.09 E 4513.30 N 3451.37W 5985113.06 N 615407.37E 4534.23 N 3468.02W 5985133.74 N 615390.40 E 4577.02N 3502.02W 5985175.98 N 615355.72 E 4638.43 N 3551.42W 5985236.60 N 615305.35 E 4658.64 N 3567.44W 5985256.55 N 615289.01 E 4677.42N 3582.41W 5985275.08 N 615273.74 E 4696.89 N 3598.15W 5985294.31 N 615257.69 E 4735.78 N 3628.59W 5985332.71N 615226.64 E 4755.87N 3644.17W 5985352.55 N 615210.75 E 4815.74N 3691.02W 5985411.66 N 615162.96 E 4873.36 N 3735.75W 5985468.56 N 615117.31E 4934.15 N 3781.36W 5985528.63 N 615070.74 E 4994.60 N 3825.35W 5985588.37N 615025.80 E 5054.54 N 3868.73W 5985647.61N 614981.47E 5116.58 N 3913.17W 5985708.94 N 614936.05 E 5177.46 N 3956.21W 5985769.13 N 614892.05 E 5238.53 N 3999.94W 5985829.50 N 614847.36 E 5297.96 N 4043.61W 5985888.23 N 614802.76 E 5357.23 N 4087.20W 5985946.80 N 614758.22 E 5415.64 N 4130.55W 5986004.51N 614713.95 E Dogleg Rate (°/lOOft). 0.000 9.620 3.861 7.896 6.600 2.677 0.906 3.204 3.156 5.131 2.016 2.434 1.551 0.225 0.345 1.536 0.434 0.129 0.425 0.304 1.286 0.585 0.309 0.732 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 556o.41 5590.77 5596.04 5624.50 5653.50 5681.57 5708.32 5762.97 5841.77 5867.55 5891.57 5916.61 5965.99 5991.41 6067.43 614o.37 6216.37 6291.09 6365.04 6441.3o 6515.78 6590.84 6664.57 6738.12 6810.84 Tie-on Survey Window Point Continued... 10/27/2000 14:30:10 PM -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 mwd Your Ref: API-500272297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 9616.83 52.150 323.850 5527.32 9712.33 52.260 322.660 5585.84 9806.30 52.050 320.990 5643.50 9898.75 52.040 321.290 5700.36 9993.36 52.220 320.610 5758.44 10085.87 52.730 320.960 5814.79 10178.64 53.060 320.530 5870.75 10266.89 53.420 321.060 5923.57 10360.22 53.540 319.770 5979.11 10454.30 53.640 320.270 6034.95 10545.42 53.640 320.880 6088.97 10640.10 53.560 320.980 6145.16 10735.17 53.650 320.960 6201.57 10826.73 53.460 320.570 6255.96 10923.19 53.180 320.670 6313.58 11016.18 53.290 321.950 6369.24 11108.53 53.210 321.970 6424.49 11198.86 52.970 321.340 6478.74 11252.49 53.570 321.530 6510.82 11297.05 56.640 321.270 6536.30 11328.18 59.130 322.380 6552.85 11358.41 61.810 321.380 6567.75 11390.28 63.860 322.430 6582.30 11452.86 64.460 323.240 6609.58 11482.85 66.770 322.490 6621.96 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (fi) 5591.52 5475.20 N 4174.74W 5986063.36 N 614668.83 E 5650.04 5535.67 N 4219;88W 5986123.10 N 614622.73 E 5707.70 5594.00 N 4265.74W 5986180.70 N 614575.95 E 5764.56 5650.76 N 4311.48W 5986236.73 N 614529.32E 5822.64 5708.76 N 4358.53W 5986293.98 N 614481.35 E 5878.99 5765.60 N 4404.91W 5986350.08 N 614434.07E 5934.95 5822.89 N 4451.73W 5986406.62 N 614386.35 E 5987.77 5877.68 N 4496.42W 5986460.69 N 614340.79 E 6043.31 5935.48N 4544.21W 5986517.72 N 614292.09 E 6099.15 5993.50 N 4592.86W 5986574.96 N 614242.53 E 6153.17 6050.18 N 4639.46W 5986630.89 N 614195.03 E 6209.36 6109.35 N 4687.49W 5986689.29 N 614146.07 E 6265.77 6168.79 N 4735.68W 5986747.96 N 614096.94 E 6320.16 6225.84 N 4782.27W 5986804.27 N 614049.45E 6377.78 6285.64 N 4631.35W 5986863.28 N 613999.43 E 6433.44 6343.78 N 4877.92W 5986920.67 N 613951.95 E 6488.69 6402.06 N 4923.51W 5986978.22 N 613905.43E 6542.94 6458.71N 4968.32W 5987034.15 N 613859.73 E 6575.02 6492.31N 4995.12W 5987067.32 N 613832.40 E 6600.50 6520.87 N 5017.92W 5987095.52 N 613809.15 E 6617.05 6541.60 N 5034.21W 5987115.98 N 613792.53 E 6631.95 6562.29 N 5050.45W 5987136.41N 613775.97E 6646.50 6584.60 N 5067.94W 5987158.45 N 613758.13 E 6673.78 6629.49N 5101.96W 5987202.78 N 613723.39 E 6686.16 6651.26 N 5118.45W 5987224.29 N 613706.56 E Dogleg Rate (°/lOOft) 0.713 0.991 1.421 0.256 0.598 0.628 0.513 0.631 1.118 0.441 0.539 0.120 0.096 0.401 0.302 1.109 0.088 0.618 1.154 6.906 8.550 9.321 · 7.069 1.509 8.032 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 6884.98 6960.43 7034.63 7107.51 7182.18 7255.52 7329.49 7400.17 7475.13 7550.79 7624.14 7700.33 7776.84 7850.47 7927.80 8002.28 8076.28 8148.50 8191.48 8228.02 8254.38 8280.68 8309.03 8365.35 8392.66 Continued... 10/27/2000 14:30:11 PM - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 mwd Your Reft AP1-$00272297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-See Depth (ft) Vertical Locel Coordinetes Global Coordinates Depth Northings Eaetings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11513.46 68.930 322.500 6633.50 6697.70 11577.35 69.390 323.130 6656.23 6720.43 11611.68 71.950 321.820 6667.59 6731.79 11640.01 73.210 322.830 6676.07 6740.27 11692.22 73.300 322.110 6691.12 6755.32 11722.02 74.010 321.700 6699.50 6763.70 11752.58 78.420 321.290 6706.78 6770.98 11782.89 85.070 322.910 6711.13 6775.33 11813.65 89.750 323.230 6712.52 6776.72 11845.52 91.780 323.420 6712.10 6776.30 11879.51 92.030 323.580 6710.97 6775.17 11905.96 91.780 323.280 6710.09 6774.29 11939.16 91.480 322.460 6709.14 6773.34 11968.28 91.230 321.600 6708.45 6772.65 11998.06 91.230 321.690 6707.81 6772.01 12031.09 91.050 321.000 6707.16 6771.36 12060.92 90.860 320.420 6706.66 6770.86 12092.17 90.860 319.930 6706.19 6770.39 12124.31 91.720 319.340 6705.47 6769.67 12164.91 91.850 319.470 6704.20 6768.40 12217.33 91.420 319.100 6702.71 6766.91 12309.90 91.910 320.280 6700.02 6764.22 12404.84 92.090 320.180 6696.70 6760.90 12496.80 93.390 321.190 6692.31 6756.51 12527.53 91.720 322.920 6690.94 6755.14 6673.75 N 5135.71W 5987246.51N 613688.95 E 6721.32 N 5171.80W 5987293.50 N 613652.11E 6747.01N 5191.53W 5987318.87 N 613631.97E 6768.40 N 5208.05W 5987340.00 N 613615.11E 6808.05 N 5238.51W 5987379.16 N 613584.03 E 6830.55 N 5256.15W 5987401.38 N 613566.03 E 6853.77 N 5274.62W 5987424.30 N 613547.19 E 6877.43 N 5293.03W 5987447.66 N 613528.41E 6901.99 N 5311.49W 5987471.92 N 613509.56 E 6927.55 N 5330.52W 5987497.18 N 613490.13 E 6954.85 N 5350.73W 5987524.16 N 613469.49 E 6976.08 N 5366.48W 5987545.14 N 613453.40 E 7002.54 N 5386.51W 5987571.27 N 613432.95 E 7025.49 N 5404.42 W 5987593.94 N 613414.68 E 7048.84 N ' 5422.90 W 5987616.99 N 613395.84 E 7074.63 N 5443.53 W 5987642.45 N 613374.80 E 7097.71N 5462.41W 5987665.23 N 613355.55 E 7121.71N 5482.43W 5987688.90 N 613335.16 E 7146.19 N 5503.24W 5987713.05 N 613313.97 E 7177.00 N 5529.64W 5987743.44 N 613287.07 E 7216.72 N 5563.82W 5987782.61N 613252.27 E 7287.28 N 5623.68W 5987852.21N 613191.30 E 7360.21N 5684.38W 5987924.17 N 613129.45 E 7431.27 N 5742.57W 5987994.30 N 613070.13 E 7455.48 N 5761.45W 5988018.20 N 613050.88 E Dogleg Rate (°/lOOft) 7.057 1.169 8.281 5.599 1.332 2.724 14.489 22.568 15.250 6.397 0.873 1.476 2.629 3.075 0.302 2.159 2.046 1.568 3.245 0.453 1.082 1.380 0.217 1.789 7.821 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 8421.Ol 8480.72 8513.11 854o.14 859o.13 8618.73 8648.40 8678.38 8709.09 8740.95 8774.91 88Ol.34 8834.53 8863.64 8893.41 8926.43 8956.24 8987.47 9o19.57 9o6o.lo 9112.43 9204.87 9299.70 9391.52 9422.22 Continued... 10/27/2000 14:30:11 PM - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 mwd Your Ref: API-500272297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (fi) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 12590.60 91.660 321.900 6689.08 6753.2~i 7505.43 N 5799.90 W 12636.44 91.660 321.770 6687.75 6751.95 7541.46 N 5828.22 W 12683.46 91.290 321.780 6686.54 6750.74 7578.38 N 5857.30 W 12728.66 90.980 322.020 6685.64 6749.84 7613.95 N 5885.19 W 12777.19 90.920 321.910 6684.84 6749.04 7652.17 N 5915.08 W 12869.83 90.180 321.690 6683.95 6748.15 7724.96 N 5972.37 W 12963.14 . 89.690 321.700 6664.06 6748.26 7798.19 N 6030.21 W 13055.56 89.380 320.510 6664.81 6749.01 7870.11 N 6088.24 W 13128.20 90.060 320.330 6685.16 6749.36 7926.10 N 6134.52 W 13150.67 89.320 321.620 6685.28 6749.48 7943.55 N 6148.67 W 13183.68 86.980 322.830 6686.35 6750.55 7969.63 N 6168.87 W 13243.42 85.750 323.650 6690.14 6754.34 8017.39 N 6204.55 W 13277.02 85.440 324.710 6692.72 6756.92 8044.56 N 6224.16 W 13308.50 81.720 324.940 6696.24 6760.44 8070.12 N 6242.18 W 13336.91 81.660 325.280 6700.34 6764.54 8093.18 N 6258.26 W 13367.54 81.220 324.910 6704.90 6769.10 8118.02 N 6275.59 W 13488.00 81.220 324.910 6723.29 6787.49 8215.43 N 6344.03 W 5988067.54 N 613011.63 E 5988103.11 N 612982.75 E 5988139.57 N 612953.08 E 5988174.69 N 612924.64 E 5988212.42 N 612894.14 E 5988284.30 N 612835.70 E 5988356.60 N 612776.71 E 5988427.59 N 612717.55 E 5988482.84 N 612670.38 E 5988500.07 N 612655.96 E 5988525.82 N 612635.34 E 5988573.01 N 612598.91 E 5988599.86 N 612578.87 E 5988625.13 N 612560.45 E 5988647.94 N 612544.01 E 5988672.50 N 612526.28 E 5988768.81 N 612456.31 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-102, Northings and Eastings are relative to S-102. Dogleg Rate (°/lOOft) 1.619 0.283 0.787 0.867 0.258 0.833 - 0.525 1.331 0.968 6.618 7.979 2.473 3.278 11.839 1.203 1.868 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 9485.26 9531.08 9578.08 9623.27 9671.79 9764.43 9857.73 9950.13 10022.73 10045.20 10078.19 10137.80 10171.28 10202.52 10230.60 10260.85 10379.76 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-102 and calculated along an Azimuth of 322.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13488.00ft., The Bottom Hole Displacement is 10379.79ft., in the Direction of 322.324° (True). Continued... 10/27/2000 14:30:12 PM - $- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 mwd Your Ref: API-500272297200 Surveyed: 18 October, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad _.~..~ Comments Measured Depth (ft) 7983.42 8017.00 13488.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4640.74 4418.51 N 3375.88 W 4655.09 4442.19 N 3394.89 W 6787.49 8215.43 N 6344.03 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (fi) 0.00 0.00 852.00 851.25 To Measured Vertical Depth Depth (fi) (fi) 852.00 851.25 13488.00 6787.49 Survey Tool Description AK-1 BP_HG MWD Magnetic 10/27/2000 14:30:13 PM - 6 - DrillQuest 1.05.05 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-102 Surveyed: 18 October, 2000 SURVEY REPORT 10/27/2000 13:55:11 PM Your Ref: API.500292297200 Surface Coordinates: 5980655.13 N, 618929.96 E (70° 21' 20.8844" N, Kelly Bushing: 64.20ft above Mean Sea Level 149° 02' 02.9105" W) Survey Ref: svy10543 Sperry-Sun Drilling Services Survey Report for S-102 Your Ref: API-500292297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eaetings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7983.42 64.700 321.560 4576.52 4640.72 8017.00 64.700 321.560 4590.87 4655.07 8022.83 64.680 321.730 4593.36 4657.56 8054.42 63.910 320.740 4607.06 4671.26 8087.04 61.670 321.990 4621.98 4686.18 8119.23 59.710 320.880 4637.73 4701.93 8150.33 58.960 321.150 4653.59 4717.79 8214.28 58.480 321.310 4686.80 4751.00 8308.29 55.480 321.310 4738.02 4802.22 8339.63 55.220 322.200 4755.84 4820.04 8369.03 54.340 320.710 4772.80 4837.00 8399.89 54.150 321.290 4790.83 4855.03 8461.29 52.940 322.440 4827.31 4891.51 8493.11 53.130 321.750 4846.45 4910.65 8588.00 53.340 321.770 4903.24 4967.44 8678.92 53.360 322.130 4957.51 5021.71 8774.16 52.530 323.670 5014.91 5079.11 8868.11 52.920 323.820 5071.81 5136.01 8960.85 52.930 323.990 5127.71 5191.91 9056.34 53.170 324.450 5185.12 5249.32 9149.40 53.320 324.650 5240.80 5305.00 9243.63 52.400 323.460 5297.70 5361.90 9336.99 51.960 323.440 5354.94 5419.14 9430.48 51.850 323.720 5412.62 5476.82 9522.85 52.050 322.940 5469.56 5533.76 4404.74N 3393.94W 4428.52 N 3412.82W 4432.65 N 3416.09W 4454.84 N 3433.91W 4477.50 N 3452.02W 4499.45 N 3469.52W 4520.24 N 3486.35W 4562.85 N 3520.57W 4624~37 N 3569.84W 4644.62N 3585.80W 4663.41N 3600.76W 4682.87 N 3616.52W 4721.71N 3647.02W 4741.77 N' 3662.64W 4801.47N 3709.69W 4858.92 N 3754.65W 4919.53 N 3800.50W 4979.82 N 3844.71W 5039.60 N 3888.30W 5101.51N 3932.92W 5162.25 N 3976.16W 5223.07N 4020.25W 5282.31N 4064.17W 5341.52 N 4107.85W 5399.86 N 4151.29W Dogleg Rate (°/lOOft) Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 5985005.43 N 615466.52 E 5560.60 5985028.91N 615447.27 E 0.000 5590.95 5985032.99 N 615443.93 E 2.658 5596.22 5985054.90 N 615425.76E 3.730 5624.68 5985077.26 N 615407.29 E 7.666 5653.69 5985098~3 N 615389.45 E 6.791 5681.75 5985119.45 N 615372.29 E 2.525 5708.50 5985161.52 N 615337.40E 0.780 5763.14 5985222.25 N 615287.16 E 3.191 '5841.95 5985242.24 N 615270.88 E 2.479 5867.73 5985260.78 N 615255.62E 5.109 5891.75 5985279.99 N 615239.55 E 1.645 5916.78 5985318.34 N 615208.44E 2.480 5966.17 5985338.15 N 615192.50 E 1.833 5991.59 5985397.10 N 615144.51 E 0.222 6067.60 5985453.82 N 615098.64 E 0.318 6140.55 5985513.70 N 615051.84E 1.557 6216.54 5985573.28 N 615006.68 E 0.434 6291.28 5985632.37 N 614962.14 E 0.147 6365.24 5985693.56 N 614916.55 E 0.460 6441.50 5985753.61N 614872.34 E 0.236 6516.00 5985813.71N 614827.30 E 1.402 6591.07 5985872.25 N 614782.44E 0.472 6664.80 5985930.76 N 614737.83 E 0.263 6738.36 5985988.40 N 614693.46 E 0.699 6811.08 Comment Tie-on Survey Window Point Continued... 10/27/2000 13:55:14 PM -2- DrillOuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 Your Ref: API-500292297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9616.83 52.150 323.770 5527.29 5591.49 9712.33 52.260 322.320 5585.81 5650.01 9806.30 52.050 320.730 5643.47 5707.67 9898.75 52.040 321.120 5700.33 5764.53 9993.36 52.220 320.390 5758.41 5822.61 10085.87 52.730 321.040 5814.76 5878.96 10178.64 53.060 320.610 5870.72 5934.92 10266.89 53.420 320.990 5923.54 5987.74 10360.22 53.540 320.170 5979.08 6043.28 10454.30 53.640 320.640 6034.92 6099.12 10545.42 53.640 320.230 6088.94 6153.14 10640.10 53.560 320.470 6145.13 6209.33 10735.17 53.650 320.730 6201.54 6265.74 10826.73 53.460 320.800 6255.93 6320.13 10923.19 53.180 320.880 6313.55 6377.75 11016.18 53.290 321.070 6369.21 6433.41 11108.53 53.210 321.110 6424.46 6488.66 11198.86 52.970 322.170 6478.71 6542.91 11252.49 53.570 322.450 6510.79 6574.99 11297.05 56.640 322.280 6536.27 6600.47 11328.18 59.130 322.440 6552.82 6617.02 11358.41 61.810 320.910 6567.72 6631.92 11390.28 63.860 322.260 6582.27 6646.47 11452.86 64.460 323.370 6609.55 6673.75 11482.85 66.770 322.710 6621.93 6686.13 5459.36 N 4195.55 W 5986047.19 N 614648.26 E 5519.66 N 4240.92 W 5986106.76 N 614601.95 E 5577.75 N 4287.08 W 5986164.12 N 614554.86 E 5634.34 N 4333.03 W 5986219.97 N 614508.02 E 5692.18 N 4380.28 W 5986277.05 N 614459.86 E 5748.97 N 4426.74 W 5986333.10_N 614412.51 E 5806.32 N 4473.47 W 5986389.70 N 614364.87 E 5861.11 N 4518.16 W 5986443.78 N 614319.32 E 5919.05 N 4565.79 W 5986500.95 N 614270.78 E 5977.40 N 4614.04 W 5986558.52 N 614221.60 E 6033.97 N 4660.78 W 5986614.34 N 614173.97 E 6092.64 N 4709.41 W 5986672.24 N 614124.42 E 6151.78 N 4757.98 W 5986730.59 N 614074.91 E 6208.82 N 4804.57 W 5986786.90 N 614027.43 E 6268,81 N 4853.42 W 5986846.10 N 613977.63 E 6326.68 N 4900.33 W 5986903.22 N 613929.81 E 6384.26 N 4946.80 W 5986960.05 N 613882.43 E 6440.89 N 4991.63 W 5987015.96 N 613836.71 E 6474.90 N 5017.90 W 5987049.56 N 613809.89 E 6503.84 N 5040.22 W 5987078.14 N 613787.12 E 6524.72 N 5056.32 W 5987098.76 N 613770.69 E 6545.35 N 5072.63 W 5987119.12 N 613754.05 E 6567.57 N 5090.25 W 5987141.06 N 613736.09 E 6612.44 N 5124.29 W 5987185.38 N 613701.34 E 6634.26 N 5140.71 W 5987206.94 N 613684.57 E Dogleg Rate (°llOOft) O.7O5 1.205 1.355 0.333 0.638 0.784 0.513 0.534 0.718 0.416 0.362 0.221 0.240 0.216 0.298 0.202 0.093 0.975 1.194 6.897 8.011 9.899 7.455 1.862 7.959 Alaska State Plane 4 PBU_WOA S.Pad Vertical Section (ft) Comment 6885.22 6960.68 7034.87 7107.75 7182.41 7255.75 7329.72 7400.40 7475.37 7551.05 7624.39 7700.56 7777.06 7850.69 7928.03 8002.50 8076.48 8148.70 8191.69 8228.23 8254.60 8280.89 8309.24 8365.56 8392.87 Continued... 10/27/2000 13:55:14 PM -3- DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for S-102 Your Ref: AP1~500292297200 Surveyed: 18 October, 2000 .. Vertical Local Coordinates Global Coordinates Depth Northings Eaatings Northings Eastings (ft) (fi) (ft) (fi) (ft) 11513.46 68.930 322.730 6633.47 6697.67 11577.35 69,390 323,150 6656.20 6720.40 11611.68 71.950 322.300 6667.56 6731.76 11640.01 73,210 323,400 6676.04 6740.24 11692.22 73.300 323.280 6691.09 6755.29 11722,02 74.010 323.150 6699.47 6763.67 11752.58 78,420 323.030 6706.75 6770.95 11782.89 85.070 322.900 6711.10 6775.30 11813.65 89.750 323.080 6712.49 6776.69 11845.52 91.780 323.290 6712.07 6776.27 11879.51 92.030 323,390 6710.94 6775.14 11905.96 91.780 323.070 6710.06 6774.26 11939.16 91.480 322.180 6709.11 6773.31 11968.28 91.230 321.480 6708.42 6772.62 11998.06 91.230 321.430 6707~8 6771.98 12031.09 91.050 320.860 6707.13 6771.33 12060.92 90.860 320.320 6706.63 6770.83 12092.17 90.860 319.970 6706.16 6770.36 12124.31 91.720 319,270 6705.44 6769.64 12164.91 91.850 319.390 6704.17 6768.37 12217.33 91.420 319.100 6702.68 6766.88 12309,90 91.910 320.390 6699.99 6764.19 12404.84 92,090 319.990 6696.67 6760.87 12496.80 93.390 321.010 6692.28 6756A8 12527.53 91,720 322.740 6690.91 6755.11 6656.82 N 5157.88W 5987229.22 N 613667.05 E 6704.47N 5193.86W 5987276.30 N 613630.31E 6730.24 N 5213.48W 5987301~6 N 613610.29 E 6751.79 N 5229.81W 5987323.04 N 613593.62 E 6791.89 N 5259.66W 5987362.67 N 613563.14 E 6814.79 N 5276.78W 5987385.29 N 613545.65 E 6838.52 N 5294.60W 5987408.73 N 613527.46 E 6862.45N 5312.66W 5987432.37N 613509.03 E 6886.98 N 5331.15W 5987456.61N 613490.15 E 6912.49 N 5350.24W 5987481.81N 613470.65 E 6939.74 N 5370.53W 5987508.74 N 613449.94 E 6960.92N 5386.35W 5987529.66 N 613433.78 E 6987.29 N 5406.50W 5987555.71N 613413.22 E 7010.18 N 5424.49W 5987578.31N 613394.86 E 7033.47N 5443.04W 5987601.30 N 613375.94 E 7059.18 N 5463.76W 5987626.68 N 613354.82 E 7082.23 N 5482.69W 5987649.42 N 613335.52 E 7106.21N 5502.72W 5987673.09 N 613315,12 E 7130.69 N 5523.53W 5987697.23 N 613293.92E 7161.47 N 5549.98W 5987727.59 N 613266.99 E 7201.16 N 5564.19 W 5987766.73 N 613232.15 E 7271.78 N 5643.98 W 5987836.39 N 613171,25 E 7344.66 N 5704.73 W 5987908.30 N 613109.35 E 7415.54 N 5763.15W 5987978.24 N 613049.81E 7439.69 N 5782.10W 5988002.08 N 613030.48E Dogleg Rate (°/lOOft) 7.057 0,946 7,814 5,788 0.280 2,419 14.436 21.944 15.226 6.404 0.792 1.535 2.828 2.552 0.168 1.809 1.919 1,120 3.450 0.436 0.989 1.490 0.462 1.796 7.821 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) comment 8421.22 8480.92 8513.32 8540.34 8590.33 8618.92 8648.59 8678.57 8709.28 8741.14 8775.11 8801.54 8834.72 8863.84 8893.61 8926.62 8956.44 8987.66 9019.76 9060.29 9112.62 9205.06 9299.89 9391.70 9422.40 Continued... 10/27/2000 13:55:15 PM - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 Your Ref: API.500292297200 Surveyed: 18 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Easflngs (~t) (ft) (~t) (~t) (ft) Global Coordinates Northings Eastings (ft) (ft) 12590.60 91.660 321.680 6689.05 6753.25 7489.51 N 5820.73 W 12636.44 91.660 321.560 6687.72 6751.92 7525.42 N 5849.18 W 12683.46 91.290 321.620 6686.51 6750.71 7562.26 N 5878.38 W 12728.66 90.980 321.830 6685.61 6749.81 7597.73 N 5906.38 W 12777.19 90.920 321.690 6684.81 6749.01 7635.84 N 5936.41 W 12869.83 90.180 321.350 6683.92 6748.12 7708.36 N 5994.05 W 12963.14 89.690 321.390 6684.03 6748.23 7781.25 N 6052.30 W 13055.56 89.380 320.390 6684.78 6748.98 7852.96 N 6110.60 W 13128.20 90.060 320.230 6685.13 6749.33 7908~86 N 6156.99 W 13150.67 89.320 321.620 6685.25 6749.45 7926.30 N 6171.15 W 13183.68 86.980 322.830 6686.32 6750.52 7952.38 N 6191.36 W 13243.42 85.750 323.450 6690.11 6754.31 8000.08 N 6227.13 W 13277.02 85.440 324.470 6692.69 6756.89 8027.17 N 6246.84 W 13308.50 81.720 324.710 6696.21 6760.41 8052.66 N 6264.96 W 13336.91 81.660 325.070 6700.31 6764.51 8075.66 N 6281.13 W 13367.54 81.220 324.810 6704.87 6769.07 8100.45 N 6298.53 W 13488.00 81.220 324.810 6723.26 6787.46 8197.74 N 6367.13 W 5988051.28 N 612991.06 E 5988086.75 N 612962.04 E 5988123.11 N 612932.26 E 5988158.14 N 612903.71 E 5988195.77 N 612873.07 E 5988267.36 N 612814.29 E 5988339.32 N 612754.88 E 5986410.09 N 612695.46 E 5988465.25 N 612648.19 E 5988482.46 N 612633.75 E 5988508.21 N 612613.13 E 5988555.34 N 612576.61 E 5988582.11 N 612556.47 E 5988607.31 N 612537.95 E 5988630.05 N 612521.42 E 5988654.56 N 612503.63 E 5988750.75 N 612433.49 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-102. Northings and Eastings are relative to S-102. Dogleg Rate (°/100fi) 1.683 0.262 0.797 0.828 0.314 O.879 0.527 1.133 0.962 7.008 7.979 2.305 3.164 11.841 1.272 1.664 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 9485.44 9531.26 9578.26 9623.45 9671.97 9764.60 9857.90 9950.29 10022.89 1 o045.35 1 o078.34 10137.95 10171.44 10202.69 10230.77 lO261.02 10379.95 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-102 and calculated along an Azimuth of 322.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13488.00ft., The Bottom Hole Displacement is 10379.95ft., in the Direction of 322.164° (True). Continued... 10/27/2000 13:55:16 PM - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 Your Ref: API-500292297200 Surveyed: 18 October, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Meaeured Station Coordinetes Depth TVD Northlnge Eestings (~t) (~t) (~t) (ft) 7983.42 4640.72 4404.74 N 3393.94 W 8017.00 4655.07 4428.52 N 3412.82 W 13488.00 6787.46 8197.74 N 6367.13 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Meaeured Vertical Depth Depth (~t) (fi) 0,00 0.00 852.00 851.25 To Meaeured Vertical Depth Depth (fi) (ft) 852.00 851.25 13488.00 6787.46 Survey Tool Description AK-1 BP_HG AK-6 BP_IFR-AK 10/27/2000 13:55:17 PM - 6 - Dri/IQuest 1.05.05 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-102 pbl Surveyed: 25 September, 2000 SURVEY REPORT 27 October, 2000 Your Ref: API-500292297270 Surface Coordinates: 5980655.13 N, 618929.96 E (70° 21' 20.8844" N, Kelly Bushing: 64.20ft above Mean Sea Level 149° 02' 02.9105" W) 0 Survey Reft svy10539 Sperry-Sun Drilling Services Survey Report for S-102 pb 1 Your Ref: AP1-$00292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth 0.00 0.000 0.000 -64.20 82.00 0.200 325.000 17.80 173.00 0.600 339.500 108.80 266.00 1.300 341.800 201.78 356.00 2.500 11.800 291.73 449.00 3.100 30.000 384.63 544.00 3.300 44.600 479.48 635.00 3.000 54.200 570.34 729.00 3.100 71.500 664.21 822.00 2.900 73.000 757.08 852.00 2.490 65.850 787.05 945.51 1.750 54.240 880.50 1041.28 1.790 2.090 976.23 1135.52 5.590 330.540 1070.26 1230.00 7.280 328.320 1164.14 1321.99 8.660 324.920 1255.24 1416.14 10.890 318.760 1348.02 1511.15 17.870 313.560 1440.00 1543.19 18.020 314.190 1470.48 1637.04 19.140 317.220 1559.44 1732.54 22.680 318.900 1648.64 1763.10 24.070 318.870 1676.69 1795.05 25.970 318.940 1705.64 1889.26 29.620 320.540 1788.97 1981.67 29.230 321.870 1869.46 Vertical Local Coordinates . Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 82.00 173.00 265.98 355.93 448.83 543.68 634.54 728.41 821.28 851.25 944.70 1040.43 1134.46 1228.34 1319.44 1412.22 1504.20 1534.68 1623.64 1712.84 1740.89 1769.84 1853.17 1933.66 0.00 N 0.00 E 0.12 N 0.08 W 0.69 N 0.34 W 2.15 N 0.84 W 5.O4 N 0.76 W 9.21 N 0.91 E 13.38 N 4.12 E 16.64 N 7.89 E 18.88 N 12.29 E 20.37 N 16.93 E 20.86 N 18.25 E 22.52 N 21.26 E 24.87 N 22.50 E 30.34 N 20.30 E 39.44 N 14.89 E 50.07 N 7.85 E 62.56 N 2.09 W 79.38 N 18.59W _ 86.22 N - 25.70W 107.63N 46.56W 133.00 N 69.31W 142.14 N 77.28W 152.32 N 86.16W 185.86 N 114.52W 221.24 N 142.96W Dogleg Rate (°/lOOft) Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 5980655.13 N 618929.96 E 0.00 5980655.25 N 618929.88 E 0.244 0.14 5980655.82 N 618929.61 E 0.450 0.76 5980657.27 N 618929.09 E 0.754 2.22 5980660.16 N 618929.12 E 1.689 4.45 5980664.35 N 618930.73 E 1.145 6.71 5980668.57 N 618933.87E 0.881 8.05 5980671.89 N 618937.58 E 0.666 8.31 5980674.20 N 618941.95 E 0.981 7.38 5980675.76 N 618946.56 E 0.231 5.72 5980676.27 N 618947.88 E 1.765 5.29 5980677.99 N 618950.86 E 0.911 4.76 5980680.35 N 618952.07 E 1.625 5.86 5980685.79 N 618949.77 E 4.426 11.53 5980694.80 N 618944.22 E 1.808 22.04 5980705.32 N 618937.01E 1.585 34.75 5980717.65 N 618926.88 E 2.613 50,71 5980734.20 N 618910.11 E 7.464 74.11 5980740.93 N 618902.89 E 0.766 83.88 5980762.01N 618881.69 E 1.575 113.58 5980787.02 N 618858.55 E 3.759 147.57 5980796.02 N 618850.43 E 4.549 159.68 5980806.06 N 618841.39 E 5.948 173.17 5980839.15 N 618812.51 E 3.954 217.05 5980874.07N 618783.50 E 0.823 262.44 Comment Gyro Data surveys from 82' - 822' MD AK-6 BP_IFR-AK Continued... 27 October, 2000- 21:46 - 2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pb 1 Your Reh APi-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Mea8ured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth ' Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 2075.34 32.990 324.890 1949.65 2013.85 2169.68 36.710 325.310 2027.05 2091.25 2264.19 39.960 325.410 2101.18 2165.38 2296.60 41.280 324.970 2125.78 2189.98 2325.22 42.830 324.230 2147.03 2211.23 2355.96 44.780 323.100 2169.21 2233.41 2386.87 46.980 323.130 2190.73 2254.93 2418.88 49.220 323.190 2212.10 2276.30 2449.46 50.960 323.410 2231.72 2295.92 2480.57 52.300 321.870 2251.03 2315.23 2511.75 53.860 322.380 2269.76 2333.96 2544.66 55.680 322.270 2288.75 2352.95 2575.78 57.390 322.070 2305.91 2370.11 2605.62 57.890 322.150 2321.88 2386.08 2637,72 58.940 322.520 2338.69 2402.89 2670.62 60.660 323.250 2355.24 2419.44 2700.85 62.690 323.690 2369.58 2433.78 2732.46 63.650 324.550 2383.85 2448.05 2825.58 61.950 325.390 2426.41 2490.61 2919.02 63.220 321.580 2469.45 2533.65 3012.65 65.780 319.840 2509.76 2573.96 3105.67 66.370 319.230 2547.48 2611.68 3199.83 64.670 319.200 2586.50 2650.70 3294.90 65.400 319.240 2626.62 2690.82 3384.97 69.120 319.010 2661.43. 2725.63 260.11N 171.76W 5980912.48 N ' 618754.09 E 30~32N 202.59W 5980956.19 N 618722.56 E 352.54N 235.91W 5981003.88 N 618688,48 E 369.87N 247.95W 5981021.01N 618676.16 E 385.49N 259.06W 5981036.46 N 618664,81E 402.63 N 271.67W 5981053.40 N 618651.93 E 420.38 N 284.99W 5981070.93 N 618638,33 E 439.44N 299.27W 5981089.77 N 618623.75 E 458.25 N 313.29W 5981108.35 N 618609.43E 477.63N 328.09W 5981127.49 N 618594.33 E 497.31N 343.39W 5981146.93 N 618578.71 E 518.59N 359.82W 5981167.94 N 618561.95 E 539.09 N 375.75W 5981188.19 N 618545.70 E 558.98 N 391.23W 5981207.83 N 618529.91 E 580.63 N 407.93W 5981229.21N 618512.86 E 603.30 N 425.09W 5981251.61N 618495.35 E 624.68 N 440.93W 5981272.74 N 618479.17 E 647.54N 457.46W 5981295.33 N 618462.28 E 715.35 N 505.00W 5981362.38 N 618413.67E 781.99 N 554.36W 5981428.22 N 618363.26 E 847.38 N 607.87W 5981492.75 N 618308.71 E 912.06 N 663.06W 5981556.55 N 618252.51E 976.95 N 719.03W 5981620.54 N 618195.51E 1042.21N 775.33W 5981684.90 N 618138.19 E 1105.01N 829.68W 5981746.83 N 618082.84 E Dogleg Rate (°/lOOft) 4.345 3.951 3.439 4.168 5.686 6.835 7.118 6.999 5.717 5.798 5.171 5.537 5.521 1.691 3.415 5,569 6.836 3.888 1.994 3.866 3.208 0.873 1.806 0.769 4.137 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 310.80 364.63 423.15 444.23 463.38 484.65 506.83 530.65 554.11 578.49 603.42 630.30 656.26 681.47 708.81 737.24 763.85 792.04 874.76 957.66 1042.13 1127.06 1212.64 1298.71 1381.64 Continued... · 27 October, 2000- 21:46 -3- DrillQuest 1.05.0'5 Sperry-Sun Drilling Services Survey Report for $-102 pb I Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (fi) (ft) (fi) (ft) (ft) (ft) 3482.72 67.880 320.030 2697.26 3573.64 66.630 320.660 2732.41 3665.72 67.580 321.000 2768.23 3757.74 66.980 321.500 2803.77 3851.54 65.880 321.870 2841.28 3942.88 65.860 321.900 2878.62 4035.01 66.020 322.130 2916.18 4129.20 65.670 322.880 2954.73 4221.00 65.120 322.860 2992.95 4314.50 65.190 323.210 3032.23 4409.48 64.760 324.020 3072.41 4503.05 63.820 322.800 3113.00 4595.01 63.830 322.030 3153.57 4687.62 64.220 321.390 3194.13 4763.09 64.300 321.920 3226.91 4794.66 63.470 322.470 3240.80 4885.48 65.330 323.030 3280.04 4979.79 64.820 323.160 3319.79 5071.69 66.920 323.160 3357.36 5164.14 66.660 323.620 3393.79 5258.72 66.070 323.010 3431.71 5352.69 65.810 322.520 3470.02 5446.77 66.000 322.810 3508.43 5539.82 64.240 322.360 3547.57 5634.11 62.800 323.280 3589.62 2761.46 1174.18 N 888.72W 2796.61 1238.74N 942.23W 2832.43 1304.50 N 995.81W 2867.97 1370.69 N 1048.94W 2905.48 1438.15 N 1102.24W 2942.82 1503.73 N 1153.69W 2980.38 1570.04 N 1205.47W 3018.93 1638.22 N 1257.78W 3057.15 1704.77 N 1308.16W 3096.43 1772.56 N 1359.18W 3136.61 1841.84 N 1410.23W 3177.20 1909.54 N 1460.48W 3217.77 1974.94 N 1510.82W 3258.33 2040.28 N 1562.41W 3291.11 2093.60 N 1604.58W 3305.00 2115.99 N 1621.96W 3344.24 2181.19 N 1671.53 W 3383.99 2249.58 N 1722.89 W 3421.56 2316.70 N 1773.17 W 3457.99 2384.90 N 1823.85W 3495.91 2454.38 N 1875.61W 3534.22 2522.70 N 1927.53W 3572.63 2590.98 N 1979.61W 3611.77 2658.03 N 2030.90W 3653.82 2725.27 N 2081.90W .. 5981815.06 N 618022.71E 5981878.75 N 617968.18 E 5981943.65 N 617913.57 E 5982009.00 N 617859.40 E 5982075.60 N 617805.03 E 5982140.36 N 617752.54 E 5982205.83 N 617699.72 E 5982273.18 N 617646.33 E 5982338.92 N 617594.90 E 5982405.89 N 617542.81 E 5982474.35 N 617490.66 E 5982541.24 N 617439.35 E 5982605.83 N 617387.98 E 5982670.35 N 617335.36 E 5982722.99 N 617292.34 E 5982745.11N 617274.61 E 5982809.51N 617224.01E 5982877.07N 617171.57 E 5982943.38 N 617120.23 E 5983010.77 N 617068.48 E 5983079.43 N 617015.62 E 5983146.91N 616962.63 E 5983214.36 N 616909.46 E 5983280.58 N 616857.12 E 5983347.00 N 616805.05 E Dogleg Rate (°/lOOft) 1.597 1.516 1.086 0.822 1.227 0.037 0.287 0.816 0.599 0.348 0.896 1.546 0.752 0.751 0.641 3.059 2.122 0.555 2.285 0.537 0.859 0.551 0.346 1.942 1.759 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) Comment 1472.49 1556.29 1641.09 1725.96 1811.93 1895.29 1979.41 2065.35 2148.81 2233.65 2319.69 2403.97 2486.5O 2569.75 2637.73 2666.07 2747.97 2833.49 2917.34 3002.29 3088.92 3174.72 3260.60 3345.01 3429.40 Continued... 27 October, 2000 - 21:46 - 4 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (fi) Incl. Azlm. Sub-Sea Depth (ft) 5728.26 62.590 322.990 3632,81 5823.31 66.670 322.800 3673,52 5916.76 66.190 323,350 3710,89 6010.89 66.440 323,600 3748,70 6105.54 66.310 321.110 3786,64 6197.32 65.820 322,490 3823.88 6286.16 66.190 321,520 3860.00 6382.86 64.530 322.430 3900.32 6476.48 63,680 323.180 3941.21 6571.04 65.270 322.460 3981.95 6666.37 65.470 323.080 4021.68 6760.10 65,730 323.060 4060.40 6854.05 65.870 323.160 4098.91 6947.53 66,110 322.670 4136.95 7042.76 66,560 322.990 4175.17 7137.09 64.300 320.900 4214.40 7231.56 64.470 320.020 4255,24 7327.99 64.960 320.430 4296.43 7419.16 65.030 320,360 4334,96 7514.99 65,320 320.700 4375,20 7609.40 65.660 321.140 4414.36 7702.65 63.660 320.050 4454.27 7795.83 63.880 320.890 4495.46 7889.86 ~4.510 322,180 4536.39 7983.42 64.700 321.560 4576,52 Sperry-Sun Drilling Services Survey Report for S-102 pb I Your Ref: AP1-$00292297270 Surveyed: 25 September, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) (ft) 3697.01 2792.20 N 2132.09W 3737.72 2860.68 N 2183.89W 3775.09 2929.15 N 2235.35W 3812.90 2998.42'N 2286,66W 3850.84 3067.08 N 2339.61W 3888.08 3133.00 N 2391.49W 3924.20 3196.96 N 2441.45W 3964.52 3266.19 N 2495,60W 4005.41 3333.28 N 2546.51W 4046.15 3401.26 N 2598.08W 4085.88 3470.26 N 2650.51W 4124.60 3538.49 N 2701.80W 4163.11 3607.03 N 2753.24W 4201.15 3675.14 N 2804.73W 4239,37 3744.65 N 2857.42W 4278,60 3812.20 N 2910.29W 4319.44 3877.89 N 2964.52W 4360,63 3944.90 N 3020.30W 4399.16 4008.56 N 3072.97W 4439.40' 4075.70 N 3128.26W 4478.56 4142.39 N 3182.41W 4518.47 4207.50 N 3235.90W 4559.66 4271.97N 3289.10W 4600.59 4338.25 N 3341.76W 4640.72 4404.74N 3393.94W 5983413.13 N 616753.81 E 5983480.78 N 616700.93 E 5983548.42 N 616648.39 E 5983616~7 N 616595.99 E 5983684.68 N 616541.95 E 5983749.77 N 616489.03 E 5983812.93 N 616438.06 E 5983881.29 N 616382.82E 5983947.56 N 616330.85 E 5984014.71N 616278.21E 5984082.87N 616224.69 E 5984150.28 N 616172.33 E 5984217.99 N 616119.81E 5984285.28 N 616067.24 E 5984353.94 N 616013.45E 5984420.64 N 615959.52 E 5984485.47N 615904.25 E 5984551.59 N 615847.41E 5984614.40 N 615793.74 E 5984680.66 N 615737.39 E 5984746.47N 615682.19 E 5984810.73 N 615627.67E 5984874.35 N 615573.45 E 5984939.78 N 615519.75 E 5985005.43N 615466.52 E Dogleg Rate (°/lOOff) 0.353 4.296 0.745 0.360 2.414 1.474 1.081 1.918 1.159 1.816 0.627 0.278 0.178 0.543 0.564 3.130 0.859 0.637 0.104 0.442 0.556 2.391 0.842 1.405 0.632 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 3513.04 3598.90 3684.55 3770.73 3857.43 3941.32 4022.48 4110.37 4194.58 4279.90 4366.56 4451.90 4537.59 4622.97 4710.19 4795.96 4881.11 4968.25 5050.83 5137.77 5223.65 5307.89 5391.43 5476.08 5560.60 Continued... 27 October, 2000- 21:46 -$- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pb 1 Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 8076.49 65.110 321.500 4615.99 4680.19 4470.73 N 3446.38 W 5985070.58 N 615413.04 E 8173.09 65.690 320.850 4656.20 4720.40 4539.15 N 3501.44 W 5985138.12 N 615356.90 E 8267.40 66.130 320.250 4694.70 4758.90 4605.63 N 3556.15 W 5985203.73 N 615301.14 E 8361.47 66.800 321.450 4732.26 4796.46 4672.52 N 3610.60 W 5985269.74 N 615245.64 E 8454.61 65.310 320.800 4770.06 4834.26 4738.79 N 3664.02 W 5985335.15 N 615191.17 E 8547.71 63.900 320.240 4809.99 4874.19 4803.70 N 3717.49 W 8688.00 63.900 320.240 4871.71 4935.91 4900.55 N 3798.06 W 5985399.21 N 615136.68 E 5986494.76 N 615054.57 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-102 WPS. Northings and Eastings are relative to S-102 WPS. Dogleg Rate (°llOOft) 0.444 0.857 0.745 1.369 1.722 1.609 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5644.88 5732.69 5818.75 5904.97 5990.08 6074.14 6200.05 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-102 and calculated along an Azimuth of 322.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8688.00ft., The Bottom Hole Displacement is 6200.05ft., in the Direction of 322.223° (True). Continued... 27 October, 2000 - 21:46 - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pbl Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad '-~. _~omments Measured Depth (fi) 82.00 8688.00 Station Coordinates TVD Northlngs Eaetinga (~t) (ft) (fi) 82.00 0.12 N 0.08 W 4935.91 4900.55 N 3798.06 W Comment Gyro Data surveys from 82' - 822' MD Projected Survey Survey tool program From Measured Vertical Depth Depth (~t) (ti) 0.00 0.00 852.00 851.25 To Measured Vertical Depth Depth (tt) (ft) 852.00 851.25 8688.00 4935.91 Survey Tool Description AK-1 BP_HG AK-6 BP_IFR-AK 27 October, 2000- 21:46 - 7- DrillQuest 1.05.05 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-102 pbl MWD Surveyed: 25 September, 2000 SURVEY REPORT 27 October, 2000 Your Ref: API-500292297270 Surface Coordinates: 5980655.13 N, 618929.96 E (70° 21' 20.8844" N, Kelly Bushing: 64.20ft above Mean Sea Level 149° 02' 02.9105" W) Survey Ref: svy10541 Sperry-Sun Drilling Services Survey Report for S- 102 pb I MWD Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -64.20 82.00 0.200 325.000 17.80 173.00 0.600 339.500 108.80 266.00 1.300 341.800 201.78 356.00 2.500 11.800 291.73 449.00 3.100 30.000 384.63 544.00 3.300 44.600 479.48 635.00 3.000 54.200 570.34 729.00 3.100 71.500 664.21 822.00 2.900 73.000 757.08 852.00 2.490 66.750 787.05 945.51 1.750 54.220 880.50 1041.28 1.790 1.790 976.23 1135.52 5.590 329.740 1070.26 1230.00 7.280 327.450 1164.14 1321.99 8,660 325.110 1255.24 1416.14 10.890 319.050 1348.02 1511.15 17.870 313.720 1440.00 1543.19 18.020 314.470 1470.48 1637.04 19.140 317.480 1559.44 1732.54 22.680 319.460 1648.64 1763.10 24.070 318.560 1676.69 1795.05 25.970 318.460 1705.64 1889.26 29.620 319.780 1788.97 1981.67 29.230 321.230 1869.46' Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00E 82.00 0.12 N 0.08W 173.00 0.69 N 0.34W 265.98 2.15 N 0.84 W 355.93 5.04 N 0~6 W 448.83 9.21 N 0.91 E 543.68 13.38 N 4.12 E 634.54 16.64 N 7.89 E 728.41 18.88 N 12.29 E 821.28 20.37 N 16.9~E 851.25 20.85 N 18.25 E 944.70 22.48 N 21.28 E 1040.43 24.83 N 22,51E 1134.46 30.27 N 20.24 E 1228.34 39.29 N' 14.70 E 1319.44 49.89 N 7.61E 1412.22 62.42N 2.28W 1504.20 79.29 N 18.72W 1534.68 86.16 N 25.81W 1623.64 107.67N 46.57W 1712,84 133.21N 69.12W 1740.89 142.36 N 77.08W 1769.84 152.48 N 86.03W 1853.17 185.71N 114.75W 1933.66 220.74N 143.62W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 5980655.13 N 618929.96 E 0.00 5980655.25 N 618929.88 E 0.244 0,14 5980655.82 N 618929,61 E 0.450 0,76 5980657.27 N 618929.09 E 0.754 2,22 5980660.16 N 618929.12 E 1.689 4,45 5980664.35 N 618930.73 E 1.145 6.71 5980668.57N 618933.87E 0.881 8.05 5980671.89 N 618937.58 E 0.666 8.31 5980674.20 N 618941.95 E 0.981 7.38 5980675.76 N 618946.56 E 0.231 5.72 5980676.26 N 618947,88 E 1.680 5.28 5980677.95N 618950,88 E 0.929 4.72 5980680.32N 618952.07E 1.633 5.82 5980685.72N 618949.72 E 4.437 11.51 5980694.65 N 618944.04E 1.809 22.04 5980705.13 N 618936.77 E 1.541 34.76 5980717.51N 618926.69 E 2.605 50.72 5980734.12 N 618909.99 E 7.470 74.13 5980740.87N 618902.79 E 0.860 83.90 5980762.05 N 618881.69 E 1.571 113.62 5980787.23 N 618858.73 E 3.779 147.62 5980796.25 N 618850.63 E 4.696 159.73 5980806.23 N 618841.52E 5.948 173.21 5980839.00 N 618812.28 E 3.929 217.07 5980873.56 N 618782.85 E 0,879 262.45 Comment Gyro Data surveys from 82' - 822' MD MWD Magnetic Continued,,. 27 October, 2000- 21:57 -2- DriilQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pb I MWD Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2075.34 32.990 324.900 1949.65 2013.85 2169.68 36.710 323.160 2027.06 2091.26 2264.19 39.960 325.700 2101.19 2165.39 2296.60 41.280 325.090 2125.79 2189.99 2325.22 42.830 324.470 2147.04 2211.24 2355.96 44.780 323.200 2169.22 2233.42 2386.87 46.980 324.330 2190.74 2254.94 2418.88 49.220 324.420 2212.11 2276.31 2449.46 50.960 324.840 2231.73 2295.93 2480.57 52.300 323.580 2251.04 2315.24 2511.75 53.860 323.650 2269.77 2333.97 2544.66 55.680 323.220 2288.76 2352.96 2575.78 57.390 322.950 2305.92 2370.12 2605.62 57.890 323.210 2321.89 2386.09 2637.72 58.940 323.250 2338.70 2402.90 2670.62 60.660 324.060 2355.25 2419.45 2700.85 62.690 324.270 2369.59 2433.79 2732.46 63.650 324.580 2383.86 2448.06 2825.58 61.950 325.630 2426.42 2490.62 2919.02 63.220 322.110 2469.46 2533.66 3012.65 65.780 320.700 2509.76 2573.96 3105.67 66.370 319.220 2547.49 2611.69 3199.83 64.670 319.880 2586.50 2650.70 3294.90 65.400 319.520 2626.63 2690.83 3384.97 69.120 319.240 2661.44 2725.64 Local Coordinates Northinga Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 259.45N 172.62W 5980911.81N 618753.24E 303.05 N 204.31W 5980954.90 N 618720.87 E 350.74 N 238.36W 5981002.05 N 618686.06 E 368.11N 250.34W 5981019.22 N 618673.80 E 383.77 N 261.40W 5981034.70 N 618662.50 E 400.94 N 273.96W 5981051.68 N 618649.67E 418.84N 287.07W 5981069.36 N 618636.28 E 438.21N 300.95W 5981088.51N 618622.09 E 457.34 N 314.52W 5981107.42N 618608.21E 477.12 N 328.79W 5981126.97 N 618593.64 E 497.19 N 343.58W 5981146.80 N 618578.53 E 518.78 N 359.59W 5981168.13 N 618562.18 E 539.53 N 375.18W 5981188.64 N 618546.26 E 559.68 N 390.33W 5981208.55 N 618530.80 E 581.59 N 408.69W 5981230.19 N 618514.08 E 604.49N '423.54W 5981252.82 N 618496.87E 626.06 N 439.12W 5981274.14 N 618480.95 E 649.00 N 455.53W 5981296.82 N 618464.18 E 716.93N 502.91W 5981363.98 N 618415.73 E 783.90N 551.82W 5981430.17 N 618365.76E 849.93 N 604~54W 5981495.36 N 618312.00 E 915.03N 65~24W 5981559.57N 618256.28 E 980.23 N 714.84W 5981623.89 N 618199.65 E 1045.96 N 770.58W 5981688.73 N 618142.87E 1109.00 N 824.66W 5981750.90 N 618087.80 E Dogleg Rate (°/lOOft) 4.494 4.081 3.821 4.253 5.6O7 6.958 7.586 7.001 5.787 5.351 5.006 5.632 5.542 1.830 3.273 5.644 6.743 3.161 2.083 3.609 3.053 1.587 1.915 0.841 4.140 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 310.81 364.68 423.23 444.30 463.45 484.72 506.90 530.71 554.14 578.52 603.43 630.31 656.27 681.47 708.81 737.23 763.83 792.01 874.72 957.61 1042.11 1127.06 1212.66 1298.77 1381.72 Continued... 27 October, 2000 - 21:57 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pb I MWD Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 3482.72 67.880 320.400 2697.27 2761.47 3573.64 66.630 321.610 2732.42 2796.62 3665.72 67.580 322.050 2768.24 2832.44 3757.74 66.980 322.300 2803.78 2867.98 3851.54 65.880 322.170 2841.29 2905.49 3942.88 65.860 319.750 2878.64 2942.84 4035.01 66.020 320.010 2916.20 2980.40 4129.20 65.670 321.530 2954.74 3018.94 4221.00 65.120 322.260 2992.96 3057.16 4314.50 65.190 322.910 3032.25 3096.45 4409.48 64.760 324.910 3072.43 3136.63 4503.05 63.820 323.590 3113.02 3177.22 4595.01 63.830 321.980 3153.59 3217.79 4687.62 64.220 320.870 3194.15 3258.35 4763.09 64.300 321.990 3226.93 3291.13 4794.66 63.470 322.290 3240.83 3305.03 4885.48 65.330 323.150 3280.07 3344.27 4979.79 64.820 323.240 3319.81 3384.01 5071.69 66.920 323.780 3357.38 3421.58 5164.14 66.660 324.810 3393.81 3458.01 5258.72 66.070 323.960 3431.73 3495.93 5352.69 65.810 322.960 3470.04 3534.24 5446.77 66.000 323.020 3508.45 3572.65 5539.82 64.240 322.700 3547.60 3611.80 5634.11 62.800 323.630 3589.64 3653.84 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1178.48 N 883.34W 5981819.44N 618028.03 E 1243.65 N 936.10W 5981883.76 N 617974.23 E 1310.34 N 988.52W 5981949.61-N 617920.76 E 1377.38 N 1040.57W 5982015.82N 617867.65 E 1445.34N 1093.22W 5982082.94 N 617813.93 E 1510.08 N 1145.72W 5982146.83 N 617760.41 E 1574.41N 1199.93W 5982210.30 N 617705.18 E 1640.98 N 1254.29W 5982275.99 N 617649.78 E 1706.66 N 1305.79W 5982340.84 N 617597.24E 1774.05 N 1357.34W 5982407.40 N 617544.62 E 1843.59 N 1408.04W 5982476.13 N 617492.83 E 1912.01 N 1457.29W 5982543.76 N 617442.50 E 1977.73 N 1507.20W 5982608.68 N 617391.55 E 2042.82N 1559.11W 5982672.94 N 617338.61 E 2095.97N 1601.50W 5982725.41N 617295.39 E 2118.35 N 1618.89W 5982747.51N 617277.64 E 2183.51N 1668.50W 5982811.88 N 617227.01E 2251.99 N 1719.74W 5982879.54 N 617174.69 E 2319.42N 1769.61W 5982946.16 N 617123.75 E 2388.41N 1819.19W 5983014.36 N 617073.08 E 2458.85 N 1869.65W 5983083.99 N 617021.51E 2527.79 N 1920.74W 5983152.11N 616969.34 E 2596.37N 1972.43W 5983219.86 N 616916.56 E 2663.66 N 2023.40W 5983286.33 N 616864.53 E 2731.21N 2073.99W 5983353.07N 616812.87E Dogleg Rate (°/lOOff) 1.682 1.843 1.122 0.699 1.180 2.418 0.311 1.519 0.939 0.635 1.961 1.620 1.571 1.157 1.341 2.764 2.219 0.548 2.347 1.062 1.033 1.010 0.210 1.917 1.764 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 1472.59 1556.42 1641.24 1726.12 1812.o9 1895.42 1979.48 2065.39 2148.85 2233.70 2319.72 2403.97 2486.49 2569.73 2637.71 2666.05 2747.95 2833.46 2917.3o 3oo2.21 3088.80 3174,58 3260.45 3344.86 3429.24 Continued... 27 October, 2000 - 21:57 - 4 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for S-102 pbl MWD Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Depth (ft) Incl. AzJm. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eaatlngs Northings Eastings (ft) (ft) (ft) (ft) (ft) 5728.26 62.590 323.320 3632.83 3697.03 5823.31 66.670 323.290 3673.55 3737.75 5916.76 66.190 323.850 3710.92 3775.12 6010.89 66.440 324.040 3748.73 3812.93 6105.54 66.310 321.530 3786.66 3850.86 6197.32 65.820 322.550 3823.90 3888.10 6286.16 66.190 321.480 3860.03 3924.23 6382.86 64.530 322.410 3900.34 3964.54 6476.48 63.680 323.280 3941.23 4005.43 6571.04 65.270 322.310 3981.98 4046.18 6666.37 65.470 324.330 4021.71 4085.91 6760.10 65.730 323.440 4060.43 4124.63 6854.05 65.870 323.490 4098.94 4163.14 6947.53 66.110 323.170 4136.98 4201.18 7042.76 66.560 322,790 4175.20 4239.40 7137.09 64.300 320.740 4214.43 4278.63 7231.56 64.470 319,860 4255.27 4319.47 7327.99 64.960 320.490 4296.46 4360.66 7419.16 65.030 320.660 4334.99 4399.19 7514.99 65.320 321.050 4375.23 4439.43 7609.40 65.660 322.470 4414.39 4478.59 7702.65 63.660 321.290 4454.30 4518.50 7795.83 63.880 322.020 4495.49 4559.69 7889.86 64.510 322.320 4536.42 4600.62 7983.42 64.700 321.240 4576.54 4640.74 2798.43 N 2123.79W 5983419.49 N 616762.01E 2867.28 N 2175.10W 5983487.52 N 616709.62 E 2936.20 N 2225.96W 5983555.62 N 616657.67 E 3005.89 N 2276.70W 5983624.49 N 616605.83 E 3074.94 N 2329.14W 5983692.71N 616552.30 E 3141.08 N 2380.74W 5983758.02 N 616499,66 E 3205.05 N 2430.69W 5983821.18 N 616448,70 E 3274.25 N 2484.87W 5983889.52N 616393.42E 3341.37N 2535.74W 5983955.82 N 616341.50 E 3409.33 N 2587.33W 5984022.95 N 616288,83-E 3478.82 N 2639.09W 5984091.62 N 616235.97 E 3547.78 N 2689.40W 5984159.76 N 616184.57E 3616.63 N 2740.42W 5984227.80 N 616132.47E 3685.12 N 2791.42W 5984295.47N 616080.39 E 3754.76 N 2843.93W 5984364.27 N 616026.78 E 3822.15 N 2897.01W 5984430.80 N 615972.64 E 3887.69 N 2951.42W 5984495.47N .615917.19 E 3954.65 N 3007.26W 5984561.54 N 615860.30 E 4018.47N 3059.73W 5984624.52 N 615806.82 E 4085.93 N 3114.64W 5984691.09 N 615750.85 E 4153.40 N 3167.80W 5984757.71N 615696.62 E 4219.70 N 3219.82W 5984823.18 N 615643.55 E 4285.25 N 3271.68W 5984887.90 N 615590.66 E 4352.11N 3323.59W 5984953.93 N 615537.69 E 4418.51N 3375.88W 5985019.49 N 615484.35 E Dogleg Rate (°/100fi) 0.368 4.293 0.752 0.324 2.433 1.148 1.177 1.926 1.234 1.919 1.938 0.908 0.157 0.405 0.597 3.106 0.859 0.779 0.186 0.478 1.415 2.431. 0.741 0.729 1.062 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 3512.88 3598.73 3684.36 3770.52 3857.22 3941.11 4022.27 4110.16 4194.37 4279.69 4366.33 4451.65 4537.32 4622.70 4709.91 4795.68 4880.82 4967.96 5050.55 5137.50 5223.40 5307.67 5391.25 5475.90 5560.41 Continued... 27 October, 2000 - 21:57 - 5 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for S-102 pb I MWD Your Ref: AP1-$00292297270 Surveyed: 25 September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (fi) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 8076.49 65.110 320.960 4616.02 4680.22 4484.11 N 3428.81 W 8173.09 65.690 320.100 4656.23 4720.43 4551.91 N 3484.65 W 8267.40 66.130 320.290 4694.72 4758.92 4618.05 N 3539.76 W 8361.47 66.800 319.090 4732.29 4796.49 4683.81 N 3595.56 W 8454.61 65.310 320.760 4770.09 4834.29 4748.94 N 3650.36 W 8547.71 63.900 320.230 4810.02 4874.22 4813.83 N 3703.86 W 8688.00 63.900 320.230 4871.74 4935.94 4910.67 N 3784.45 W 5985084.24 N 615430.39 E 5985151.14 N 615373.49 E 5985216.40 N 615317.33 E 5985281.27 N 615260.50 E 5985345.52 N 615204.67 E 5985409.55 N 615150.15 E 5985505.10 N 615068.03 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-102 WPS. Northings and Eastings are relative to $-102 WPS. Dogleg Rate (°/lOOft) 0.518 1.008 0.501 1.369 2.290 1.599 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5644.68 5732.48 5818.52 5904.68 5989.73 6073.79 6199.70 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-102 and calculated along an Azimuth of 322.200° (True). - ~.~.~ Based upon Minimum Curvature type calculations, at a Measured Depth of 8688.00ft., The Bottom Hole Displacement is 6199.73ft., in the Direction of 322.380° (True). Continued... 27 October, 2000 - 21:57 - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-102 pb I MWD Your Ref: API-500292297270 Surveyed: 25 September, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad '~'-'Comments Measured Depth 82.00 8688.00 Station Coordinates TVD Northinge Eaetings (ft) (ft) 82.00 0.12 N 0.08 W 4935.94 4910.67 N 3784.45 W Comment Gym Data surveys from 82'.- 822' MD Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) 0.00 0.00 852.00 851.25 To Measured Vertical Depth Depth (ft) (ft) 852.00 851.25 8688.00 4935.94 Survey Tool Description AK-1 BP_HG MWD Magnetic 27 October, 2000.21:57 - 7- DrillQuest 1.05.05 WELL LOG TRANSMITTAL To: State of Alaska January 04, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs S-102 PB1, AK-MM-00184 1 LDWG formatted Disc with verification listing. API#: 50-029-22972-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUR_NING A COPY OF TRANSMITTAL LETTER TO TI-IE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Tectmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 I Signe~ To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 December 05, 2000 MWD Formation Evaluation Logs ' S-102, AK-MM-00184 S-102: ~" x 5" MD Resistivity & Gamma Ray Logs ' 50-029-22972-00 /1,T" x 5" TVD Resistivity & Gamma Ray Logs · 50-029-22972-00 ex 5" MD Neutron & Density Logs: 50-029-22972-00 2" x 5" TVD Neutron & Density Logs' 50-029-22972-00 ~1 Blueline "i/Rolled Sepia vi Blueline ,1/ Rolled Sepia ~ Blueline ti/Rolled Sepia N/A PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSMITTAL LETYER TO THE ATFENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF Date:~] Sign~ WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 16, 2000 RE: MWD Formation Evaluation Logs S-102, AK-MM-00184 c~t~-/~' 1 LDWG formatted Disc with verification listing. API#: 50-029-22972-00 PLEASE ACKNOWLEDGE RECEIVF BY SIGNING AND RETURNING A COPY OF THE TRANSMITFAL LETI'ER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissionerq-U~,,~~' THRU: Blair Wondzell P.I. Supervisor FROM: John Cris? ~0~-'~ Petroleum Inspector NON- CONFIDENTIAL DATE: October 20, 2000 SUBJECT: Blowout Preventer Test Nabors 9ES BPX S Pad S-102 200-129 Prudhoe Bay Field Operator Rep.: Gavin Kidd Contractor Rep.: Bill Bixby Op. phone: 659-4831 Rig phone: 659 4806 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 3500 Annular: 3500 Choke: 3500 TEST DATA MISC. INSPECTIONS: FLOOR VALVES: MUD SYSTEM: Visual Alarm PIF PIF Quantity P/F Trip Tank OK OK Location' Gen. : Good Sign: Yes Upper Kelly 1 P Pit Level Indicators OK OK Housekeeping: Good Rig cond: Good Lower Kelly 1 P Flow Indicator OK OK PTD On Location Yes Hazard: Yes, Ball Type 1 P Meth Gas Detector Tested Tested '- Standing Order: Yes -- Inside BOP 1 P H2S Gas Detector Tested Tested ' BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5~8" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 2 718x5" P Quantity PIF System Pressure 3050 LOwer Pipe Rams 1 2 7/8x 5" P No. Valves 14 P After Closure 1700 " Blind Rams 1 13 5~8" P Man. Chokes 1 Functioned 200 psi Attained 24 sec. Choke Ln. Valves 1 3" P Hyd. Chokes 1 Functioned Full Pressure 2 min. 03 sec. HCR Valves 2 3" P Blind Covers (All Stations): Yes Kill Line Valves 1 3" P N2 Bottles (avg): 6 btls. 2000 ave. Check Valve Test's Details Individual valves in the choke manifold were tested before my arrival. I witnessed a full body test on choke manifold & witnessed Hyd. Choke & Manual chokes functioned. BOP test was conducted a day before thc 7 day test date to avoid a request for extension to finish well. Rig 9ES has always shown that compliance to State regulations is a priority. priority. Bill Bixby, Nabors Rep. & Gavin Kidd BP Rep. both were on Rig floor to make sure all testing was conducted to State, Contractor, & Operators regulations & satisfaction. Driller on tour & his crew conducted test in very safe & efficient manner. Rig & Location are in great shape. Total Test Time: 4 hours Number of failures: 0_. cc: Attatchments: none BOP Nabors 9ES 10-20-00jc.xls STATE OF ALASKA ALASK '" '_ AND GAS CONSERVATION COM '" ~I-r'LICATION FOR SUNDRY APPROVAI~' '~ION 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4452' NSL, 4499' WEL, SEC 35, T12N, R12E, UM At top of productive interval 1253' NSL, 4907' WEL, SEC 22, T12N, R12E, UM (As Planned) At effective depth At total depth 2587' NSL, 874' WEL, SEC 21, T12N, R12E, UM (~ Planned) [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) Plan RKB = 64.2' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-102 9. Permit Number 200-129 10. APl Number 50- 029-22972-00 11. Field and Pool Prudhoe Bay Field / Aurora Pool (Undefined) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11941 feet 6775 feet 11941 feet 6775 feet Length Size 110' 4790' 11679' 20" 10-3/4" 7" Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Plugs (measured) Junk (measured) Cemented MD 260 sx Arcticset (Approx.) 110' 643 sx Articset Lite 3, 510 sx Class 'G' 4816' 631 sx Class 'G' 11717' Pumped Top Job for 10-3/4" Casing: 149 sx AS Lite TVD 110' 3315' 6767' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation October 13, 2000 proposal was verbally approved~~/~ 1 6. If Tom Maunder ~ ~' Name of approver Contact Engineer Name/Number: Allen Sherlftt, 564-5204 10/13/2000 Date Approved Status of well classifications as: [] Oil [] Gas [] Suspended Service Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and~rrect to the best of my knowledge Signed ........ ~ _ /t_. Title Senior Drilling Engineer ~'. ~,!..,.,'....,,: ,:.i,.u,~J..',~;, ..:,...~., ...',,;,,, ;~ !r b J',':~'~;....:.,,:..~.~,~.~.:.:,,.'i.,.,'...,, ',~:'::;,,! i, ,' ~;~l~!i:, j',l~,~,': ~,~1,0'~', Conditions of Approval: Notify Commission so representative may witness Plug integrity Mechanical ~,~Test ubsequen rm re ' d 10- 'i'~1~"~ Approved by order of the Commisqfj~ejF~ ~~~'- ' Form 10-403 Rev. 06/15/88 .. Submit In Tri~31icate e - hared rv[ces ' rill,ng BP -Exploration / Phillips Petroleum Due to lost circulation while running the 7" intermediate casing in S-102, the casing and cementing procedure will be modified to ensure isolation at the top of the Kuparuk reservoir and at the Ugnu sands. A second port collar will be placed in the 7" at +_7000 MD and the lead cement will be reduced to ensure the cement in the annulus does not reach the port collar as a contingency in case it is required to cement above the Ugnu. In the event that bullheading down the 7" x 10 3A,, annulus is possible after pumping the lead and tail cement, the port collar will not be used and 2200 annular feet of cement will be placed above the Ugnu by bullheading and displacing with mud. Procedure: 1. Add a second port collar to the 7" intermediate string to be positioned at _+7000' MD. 2. Cement as per the drilling program (with reduced lead cement volume) with: · 312 sx (155 bbls) 11.5 ppg class G cement at 2.79 cuft/sk yield LEAD · 319 sx (66 bbls) 15.8 ppg class G cement at 1.16 cuft/sk yield TAIL 3. Bullhead cement via 10 3~" by 7" casing annulus as follows: · Pump 234 bbls water pre-flush 8.3 ppg. (-4800' annular volume to displace drilling mud.) · Pump 24 bbls 10.2 ppg mud spacer. (-500' annular volume spacer between 8.3 ppg water and 10.7ppg cement.) · Pump 118 bbls 10.7 ppg Arcticset Cement (2200' column cement from 3500' MD to 5700' MD.) · Displace with 170 bbls of 10.2 ppg mud, (-3500' column) Cement: Dowell Arcticset Wt = 10.7 pp YId = 4.44 ft%k TOC = BOC = -3500' MD - (-1318' inside 10 s,4" surface casing.) -5700' MD - (-354' below top of Ugnu.) Final EMW equal to 10.3 ppg at 6417' MD (fault). · The 6.8 ppg Diesel freeze protect would leave the cement column in an under-balance'condition. 4. PU 4" DP with TAM Port collar running tool and RIH to port collar at -2200' MD. Freeze protect 7" x 10- 3/4" annulus. POOH. Re: S-~ ~'2 7" casing cement prog. ¢ Subject: Re: S-102 7" casing cement prog. Date: Fri, 13 Oct 2000 15:11:08-0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Stone, Dan M (ARCO)" <StoneDM~BP.com> Dan, Monday will be fine. Tom "Stone, Dan M (ARCO)" wrote: Tom, would Monday suffice for submittal of Sundry notice? I assume since the cement design has changed a sundry is required. We got the casing to within 10' of bottom last night and pumped the first stage to put cement from the shoe at 11717' to about 7500'. Got good differential indication that we were lifting cement as planned which would show that the loss zone is in the Ugnu/Schrader somewhere. We won't have the down squeeze job done until tomorrow, hence my reasoning to get you a sundry next week with the complete actual data. Sound OK? Thanks Dan Stone ..... Original Message ..... From: Tom Maunder [mai/to:tom maunder~,admin, state, ak. us/ Sent: Friday, October 13, 2000 8:47 AM To: Sherritt, Allen (ARCO) Cc: Dan Stone; Blair Wondzell Subject: Re: S-102 7" casing cement prog. Allen, Thanks for the heads up. I think you guys have pretty well looked at your options and have a couple of paths forward. Your goal is to get cement across the Ugnu, which is the requirement. We hope, as you do, that the cementing goal can > be > accomplished with the least application of money. Good luck. > Tom > "Sherritt, Allen (ARCO)" ~ote: >> Tom, >> > > S- 102; Permit #200-129 >> > > As per our conversation, the followfng is an outline of our forward plan > to > > cement the 7" intermediate casing string. >> > > Loss situation: Loosing returns to fault @ 6417' IVD Ugnu 3 zone. Hole > will > > stay full under static conditions. ECD while circulating or tripping in > the > > hole causes loss to fault. 1 of 3 10/17/00 3:32 PM - Re: S-1'02 7" casing cement prog. > Option 1: > > Run 7" to bottonl filling hole with 11.4ppg mud as needed. Break circulation > and establish returns. > Initial assumption, we are loosing fluid to the fault in the UG3 formation > 6417' MD. Once the shoe is pass that depth, losses should diminish and or > stop. If this is the case, circulation and returns should be obtained with · casing on bottom. The rig v~ll proceed with the original, (as permitted) cement program. Bringing cement 500' above Ugnu in a single stage job. If rig maintains full returns during job, then continue on with original well plan. If returns are partial and/or lost, rig will down squeeze via the annulus · with 2200' of lO. 7ppg Arcticset cement, 500' 10.0 ppg mud spacer, and 2200' · of diesel freeze protect. The BOC @ -4900' It/D, TOC @ -2700' MD. The EIVIVV of · the fluid column will be reduced to '-8. 7 ppg. The oement will stay in · place above the 11.4 open hole mud system. (Losses should not be a problem · with this EMW, as the hole will stay full with 11.4 ppg mud.) Option 2: Run 7" to bottom and break circulation. If loss is continuing, the cement program will be reduced to bring TOC to 7500' IVD, (500' below TAM port collar set at 7002' MD.) See faxed copy of proposed contingency plan. As above, a down squeeze will be attempt to put cement in place above the · Ugnu. If the down squeeze is unsuccessful, the TAM port collar will be used · to perform a second stage cement job across the Ugnu. By performing the down squeeze as a contingency over the 2 stage, the TAM port collars do not need to be functioned, eliminating the risk of leak paths in the intermediate string. Additionally, the down squeeze can be performed off the critical path of the ongoing operatiom4 allowing the primary cement to cure and potentially stop the losses across the Ugnu. I have faxed a copy of this, along with a drawing outlining "Option 2". Again, if returns are established, the original cement program will be followed. If you have any questions give me a shout. Thanks Allen Sherritt ADW Operations Drilling Engineer 2 of 3 10/17/00 3:32 PM 'Ri: S-102 7" casing cement prog. > > 56#-520# > > 240-8070 >> > > <<$-102 7 o~ment prog. CNV>> >> >> > > Nane: S-102 7 cement prog. CNV > > S-102 7 oement prog. CNV Type: unspecified type > (application/octet-stream) > > En©ding: base64 Tom Maunder <tom maunder~..admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Consentation Commission ............................................ :....:....: .:..:::. :.~.:: ::::: ::::: ::: :::: :: 3 of 3 10/'17/00 3:32 PM Re: S-102 7" casing cement prog. Subject: Re: S-102 7" casing cement prog. Date: Fri, 13 Oct 2000 08:46:57 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Sherritt, Allen (ARCO)" <SherriJ~@BP.com> CC: Dan Stone <stonedm@bp.com>, Blair Wondzell <blair_wondzell@admin.state.ak. us> Allen, Thanks for the heads up. I think you guys have pretty well looked at your options and have a couple of paths forward. Your goal is to get cement across the Ugnu, which is the requirement. We hope, as you do, that the cementing goal can be accomplished with the least application of money. Good luck. Tom "Sherritt, Allen (ARCO)" wrote: > Tom, > S- 102; Permit #200-129 > > As per our conversation, the following is an outline of our forward plan to > cement the 7" intermediate casing string. > > >. > .> > > Loss situation: Loosing returns to fault @ 6417' IVD Ugnu 3 zone. Hole will stay full under static conditions. ECD while circulating or tripping in the hole causes loss to fault. Option 1: Run 7" to botton3 filling hole with 11.4ppg mud as needed. Break circulation and establish returns. Initial assumption, we are loosing fluid to the fault in the UG3 forrmtion @ 6417' MD. Once the shoe is pass that depth, losses should diminish and or stop. If this is the case, circulation and returns should be obtained with casing on bottom. The rig will proceed with the original, (as permitted) cement program. Bringing cement 500' above Ugnu in a single stage job. If rig maintains full retums during job, then continue on with original well plan. If returns are partial and/or lost, rig will down squeeze via the annulus with 2200' of 10. 7 ppg Arcticset cement, 500' 10.0 ppg mud spacer, and 2200' of diesel freeze protect. The BOC @ -4900'/VD, TOC @ -2700' MD. The EMW of the fluid column will be reduced to -8. 7 ppg. The oement will stay in place above the 11.4 open hole mud system. (Losses should not be a problem with this EMW, as the hole will stay full with 11.4 ppg mud.) Option 2: Run 7" to bottom and break circulation. If loss is continuing, the cement program will be reduced to bring TOC to 7500' MD, (500' below TAM port collar set at 7002' MD.) See faxed copy of proposed contingency plan. As above, a down squeeze will be attempt to put cement in place above the 1 of 2 10/13/00 10:25 AM Re: S-102 7" casing cement prog. > Ugnu. If the down squeeze is unsuccessful, the TAM port co#ar will be used > to perform a second stage cement job across the Ugnu. > By performing the down squeeze as a contingency over the 2 stage, the TAM > port collars do not need to be functioned, eliminating the risk of leak > paths in the intermediate string. Additionally, the down squeeze can be > performed off the critical path of the ongoing operation~ allowing the > primary cement to cure and potentially stop the losses across the Ugnu. > > I have faxed a copy of this, along with a draying outlining "Option 2". > Again, if returns are established, the original cement program will be > fo/lowed. > If you have any questions give me a shout. > Thanks > > Allen Sherritt > ADW Operations Drilling Engineer > 564-5204 > 240-8070 > > <<S-102 7 cement prog. CNV>> Nane: S-102 7 cement prog. CNV S- 102 7 cement prog. CNV Type: unspecified type (application/octet-stream) Eno)ding: base64 Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 10/13/00 10:25 AM 10/12/00 17:36 FAX 907 564, 5193 BP E~.P~OI~TI ON BP milSKI BmI.UIG & llmUS TO: COMPANY: DATE: · .. "'> AOGCC .. I~001 FROM: PHONE: FAX: . (907)564- ,, PHONE: _ (907)$6 .4- '"'~, ,~ ~l?~F,'{;':~j~:i'!:~%'l~ii~'"'"'~)(,)' ll)I~;, ~' '~ "11'I ~)- ','~ ~"~"~' "' "~ ~ ' ,'J ' ~, ,, '"' '"";~ ,,, ~; ..... ,-, '"~,~ ....., , ,'-~,,, Number of attachments not including fax cover: 10/12/00 17'36 FAX 907 564 5~93 · . BP EXPLORATION Sh,,,erritt, Allen IARCO, I To: CC: Subject: Tom Maunder (E-mail) Anthony Bunch (E-mail); Dan Stone (E-mail) S-102 7" casing cement prog. * AOGCC ~ 002 I I I Tom, S-102; Permit#200-129 As per our conversation, the following is an outline of our forward plan to cement the 7" intermediate casing string. Loss situation: Loosing returns to fault @ 6417' MD Ugnu 3 zone. Hole will stay full under static conditions. ECD while circulating or tripping in the hole causes loss to fault. Option 1: Run 7" to bottom, filling hole with 11.4ppg mud as needed. Break circulation and establish returns. Initial assumption, we are loosing fluid to the fault in the UG3 formation @ 6417' MD, Once th6 shoe is pass that depth, losses should deminish and or stop. If this is the case, circulation and returns should be obtained with casing on bottom. The rig will proceed with the original, (as permitted) cement program. Bringing cement 500' above Ugnu in a single stage job. If rfg maintains full returns during job, then continue on with original well plan. If returns are partial and/or lost, rig will down squeeze via the annulus with 2200' of 10.7 ppg Arcticset cement, 500' 10.0 ppg mud spacer, and 2200' of diesel freeze protect. The BOC O -4.900' MD, TOC @ -2700' MD. The EMW of the fluid column will be reduoed to ~8,7 ppg. The cement will stay in place above the 11.4 open hole mud system. (Losses should not be a problem with this EMW, as the hole will stay full with 1 l.~t ppg mud.) Option 2: Run 7" to bottom and break circulation. If loss is COl~tinuing, the cement program will be reduced to bfing. TOC to 7500' MD, (500' below TAM port collar set at 7002' MD.) See faxed copy of proposed contingenoy plan. As above, a down squeeze will be attempt to put cement tn place above the Ugnu. If the down squeeze is unsuccessful, the TAM port collar will be Used to perform a second stage cement job across the Ugnu. By performing the down squeeze as a contingency over the 2 stage, the TAM port collars do not need to be functioned, eliminating the risk of leak paths in the intermediate string. Additionally, the down squeeze can be performed off the critical path of the ongoing operations, allowing the primary cement to cure and potentially stop the losses across the L/gnu. I have faxed a copy of this, along with a drawing outlining "Option 2". Again, if returns are established, the original cement program will be followed. If you have any questions give me a shout. Thanks Allen Sheriff ADWOperafions Drilling Engineer 564-5204 240-8070 10/12/00 17:37 FAX 90? 564 5193 BP EXPLORATION -* AOGCC ~003 ... S-102 Secondary Cement Program Assuming Limited Returns with 7" at TD. TRi;F-.: 4-1116 ' - SM CIW C~rom~/I IV i Cellar Elevation = $5.7' : *' ~'~ !~I Nebo~ SEe RKB = 64.2' WELLHEAD 13 516 5M FMCSH /~-j r ~l/i ~ 2,200' Diesel I'reeze for protection 6.8 ppg. 7" slips will be used to hang intermediate ~~ .--- 2,700' MD. TOC Arc§c Set 10.7 ppg cmt. 0-314 ~ ,~.i:~ [~.!!~[ ~ Bullhead ¢=emen[ down annulus, puffing a 2200' cerner~t =~lumn in place ,~~ :l,~,l~l,~i!ii~il [l~'!i~k above Ugnu formation. Displace cement with 500' mud sp~cer and [4S~ 8' MD [ll~?~ 2200' o~' diesel freeze prote~-t. In place.' EMW -- 8.? ppg, Hole is staying ~i~!!iiI ~?,~ full with 11.4 ppg under stati= =ondltlons. / ! ~5,346 MD - Top of Ihe UG4A - Oil bearing Ugnu sands. 11.4 PPg LSND mud In I {3p~J't hole. I ~ , -~ J '~'"'" 6417 MD - Fault in the UG;~. Loss ~ zone. Base of =11 bearing Ugnu I & sands. ~ T ~ 7002' MD -7" TAM Port Cellar- for2 Stage contingency job. ~ 1 ?.500' MD - 3157' Extended Blend 11.5 ppg cml i1 / ~ 10,657, MD - 1000' Cl=ss "G" 15,5 PI~J cml 7', 26 ff~fl, 1.80, BTC-Mod i~/'-" 11,657' MD - Top of Kupan~k form=fion. Date Rev By. ~.0mments , _ AURORA 10-11-00 JAS 7" cement program ~, WELL: S-102 , APl NO; 50-029-22972.00 . ,,,, Shared Services Drilling MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO.' Dan Seamount ~~ Chairman DATE: October 5, 2000 THRU: BlairWondzell ~~ P.I. Supervisor ! ¢)(~o0 FROM: Lou Gdmaldi Loc~ ~.. Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 9ES BPX S pad S 102 200 1290 Prudhoe Bay Field/Unit Operator Rep.: Contractor Rep.: Keith Spoales Op. phone: Op. E-Mail: Rig phone: Rig E-Mail: Test Pressures Rams: Annular: Choke: TEST DATA MISC, INSPECTIONS: FLOOR VALVES: MUD SYSTEM: Visual Alarm P/F P/F Quantity P/F Trip Tank P P Location Gen.: P Sign: P Upper Kelly 1 P Pit Level Indicators P P Housekeeping: P Rig cond: P Lower Kelly 1 P Flow Indicator P P PTD On Location ' P Hazard: P Ball Type 1 P Meth Gas Detector P P Standing Order: P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 4 '1/2x7 'P Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 3 112x6 P No. Valves 15 P After Closure 1650 P Blind Rams 1 P Man. Chokes 1 P 200 psi Attained :39 P Choke Ln. Valves 1 3 1/8 P Hyd. Chokes 1 P Full Pressure 2:3 P HCR Valves 2 3 1/8 P Blind Covers (All Stations): P Kill Line Valves 1 3 118 P N2 Bottles (avg): P Check Valve 0 Test's Details The rig was still coming out of the hole when T arrived. ! made a short tour of thc rig and surrounding area. Once started, thc test went we, i] with ail BOP equipment functioning properly and ho]ding its pressure test. The rig is in good shape and seems to be maintained well. Kcith Spoales (Toolpusher) was 'on hand during todays test and insured his rig was tested properly. Thc rig is situated on thc satellite pad portion of S pad which was neat and ordcr]y. Total Test Time: 3 112 Number of failures: _0 Attatchments: None cc: Shared Services Drilling ~.e,. i~'ermit #200-129 S-102 P&A and sidetrack around fish Subject: Re: Permit #200-129 S-102 P&A and sidetrack around fish Date: Thu, 05 Oct 2000 16:00:53 -0800 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Sherritt, Allen (ARCO)" <SherriJA~BP.com> CC: Dan Seamount <Dan_Seamount~admin.state.ak.us> '~e:C) -!/Z9 .__ Allen, Thanks for the information. This is as we discussed. side-track around junk", no other paper work is needed. problems. Sincerely, Blair Wondzell, 10/5/00. Since this is now "a Sorry about the "Sherritt, Allen (ARCO)" wrote: Mr. Wondzell, Please find attached the information you requested regarding, Permit #200-129 well S-102, P&A operations. If you need anything else please give me a shout ...... <<P&A ltr AOGCC. doc>> Allen Sherritt Name: P&A l tr AOGCC. doc P&A ltr AOGCC.doc Type: Microsoft Word Document Encoding: base64 (appl ica tion/msword) Iofl 10/5/00 4:01 PM To: Blair Wondzell, AOGCC Date: October 5, 2000 From: Allen Sherritt Subject: P&A and sidetrack operations on Aurora S-102 Permit #200-129 Mr. Wondzell, As per our conversation on 10-4-00, the following is a brief description and details of the stuck pipe and P&A operations on S-102, (Permi~ 200-129.) On 9-25-00 at 1500 hrs, rig Nabors 9ES became stuck -58 feet off bottom while pulling out of the hole to make a connection. The BHA contained both neutron and density sources. Multiple wash over runs and jarring attempts were made to free fish, however, they proved to be unsuccessful. The events of the fishing operations and P&A plan, where communicated to the NRC. The NRC has approved our abandonment procedures, stipulating the requirement of 200' MD of "red" cement above fish. The rig will pump an additional 300' MD of 17.0 ppg "neat" class G over and above the 200' MD of 17.0 ppg "red" cement on top of fish. This will provide a 500' MD 17.0 ppg cement plug above fish. Wellbore details: TD hole = Bottom of Fish = Top of Fish = Top of Cement = Hole inc @ TD = Hole Azi @ TD = Current Formation = Current hole size = Surface casing = Surface Casing depth = LOT @ surface Shoe = 8688' MD / 4938' TVD 8629' MD / 4911' TVD 8476' MD / 4843' TVD 7976' MD / 4637' TVD 64 degs 320 degs West Sak 2 9 7/8" 10 3/4" 4816' MD 14.9 ppg Source information: Neutron = Density = 4.0 curie Am-241 Be @ -8528' MD 2.0 curie Cs-137 @ -8568'MD A "low side" sidetrack will be performed at ~7976' MD, 500' MD above fish. Once around fish, the current directional plan and BHL/Targets will be followed. If there is any other additional information or questions you may have, don't hesitate to call. Sincerely, Allen Sherritt ADW Engineer 564-5204 ALASKA OIL AND GAS CONSERVATION CO~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ge~ Prudhoe Bay Unit S-102 BP Exploration (Alaska) Inc. Permit No: 200-129 Sur Loc: 4452'NSL, 4499'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 2587'NSL, 674'WEL, Sec. 21, T12N, R12E, UM Dear Mr. Stone: 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 required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ( ~~D_aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ ~ 7~ day of August, 2000' dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .' ALASKA{'4' . AND GAS CONSERVATION COM~' ~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill J lb. Type of well Re-Entry [] Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas [][] StratigraphiCsingle Zone Test [][] MultipleDevel°pmentzone Oil I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.2' Prudhoe BaY Field / 3. Address 6. Property Designation~z~,,~,~;~ ,J~ool P.O. Box 196612, Anchorage, Alaska 99519-6612 oZ~:,~-f,~ ~. ADL 028256 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O MC 25.O25) 4452' NSL, 4499' WEL, SEC 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1253' NSL, 4907' WEL, SEC 22, T12N, R12E, UM S-102 Number 2S100302630-277 At total depth 9. Approximate spud date 2587' NSL, 674' WEL, SEC 21, T12N, R12E, UM 09-04-00 Amount $200,000.00 12. Distance to nearest property line J13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028258, 2587' MDI 15' away from S-100 at sulface 2240 13932' MD / 6829' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 97 ° Maximum surface 2761 psig, At total depth (TVD) 6735' / 3435' psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin.cl Weiaht Grade Couplin,q Len,qth MD TVD MD TVD (include sta.qe data) 30" 20" 91.5# H-40 WLD 80' Surface Surface 110' 110' _~60 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC 5153' Surface Surface 5153' 3261' 9-7/8" 7" 26# L-80 BTC-M 11326' Surface Surface 11326' 6808' 6-1/8" 4-1/2" 12.6# L-80 BTC-M 995' 11176' 6705' 12171' 6705' 6-1/8" 4-1/2" 12.6# L-80 Slotted 1761' 12171' 6821' 13932' 6829' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ~,'~ ..... .,-~., '~ ' *' Production .-. Liner ooo ORIGINAL A~k~ 0;,; & Gas "', ~,, '" ..... , i ' Perforation depth: measured .Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherfltt, 564-5204 Prepared By Name/Numbec TerSe Hubble, 564-4628 21. I hereby certify that the foregoing is true and c~,,~ct to the best of my knowledge J / ~ Signed Dan Stone ~--~-------"~.,... ~'W, .;~ Title Senior Ddlling Engineer Date ~>//~-~ APl Number Apprpval D.ate See cover letter Permit ~..../,~_~:~ 50--' Or) for other requirements Conditions of Approval: Samples Required [] Yes J~ No Mud Log I~equirec'l [] Yes ~"No Hydrogen Sulfide Measures [] Yes ~l"No Directional Survey Required ,l~i~'Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3500 psi forCTU Other: '~SO~ ~.\ by order of Approved By ORIGINAL~ _ SIGNr:D_ ~- ~y Commissioner the commission Date ~/~ ~/~ Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit ?n Triplicate ( Summary of Drillin.q Hazards POST THIS NOTICE IN THE DOGHOUSE High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Mud weights in excess of 10.4 ppg can be expected. The surface holes on S-100i and S-101 were drilled with 9.6 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. Lost circulation is a possibility across a large fault between 2100' and 2600' MD. BE prepared with LCM and adequate surface volume. S-100i and S-101 did not encounter loss circulation while crossing the faults in the surface and intermediate sections. S-102's directional plan crosses the faults at a more oblique angle, increasing the risk of loss circulation. Pipe sticking tendency is possible if the HRZ shale gives problems. S-100i and S-101i HRZ conditions where normal, back reaming at connections and good hole cleaning practices contributed to the good hole conditions. The 7" intermediate casing strings on S-100 and S-101 went to bottom without any difficulty. The Ugnu interval on S-100i and S-101 contained hydrocarbons. Triple combo LWD tools were used to mad pass the interval. Cement will need to be brought minimum 500 feet above the Ugnu formation. pad is not a designated H2S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 2.0 Aurora S-1021 Hazards and Contingencies Page 1 of 1 ]Well Name: IS-102 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: Target Location: Kuparuk Bottom Hole Location: X = 618,929.96 Y = 5,980,655.13 4452' NSL 4499' WEL S35 T12N R12E X = 613,115.00 Y = 5,987,927.00 1253' NSL 4907' WEL S22, T12N, R12E X = 612,046.00 2587' NSL Y = 5,989,245.00 Umiat Umiat 674' WEL S21, T12N, R12E Umiat I AFE Number: 13A0094 I Estimated Start Date: 19-4-00 I MD: 113,932' I I TVD: 16829' I Rig: I Nabors 9ES I Operating days to complete: 132.2 I BF/MS: 135.7' I I RKB: 164.2' I Well Design (conventional, slimhole, etc.): I Horizontal Slimhole with Solid/Slotted Liner I Objective: I Kuparuk Formation Mud Program: 13-1/2" Surface Hole (0-5153'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.5 300 75 15-20 25 NC Interval TD 9.5-9.7 100-75 25 20-30 12 NC 9-7/8" Intermediate Hole (5153' - 11,326'): LSND Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 42-53 10-25 10-15 9.0-9.5 6cc <9 shoe to 7" to to by HRZ csg point 11.2 <5 6-1/8" Production Hole (11,326' - 13,932') Baradriln Interval Density ~iscosity YP ' PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.4 40-55 22-28 12-20 8.5-9.0 <6 <10 Hole S-102 Permit to Drill Page 1 Directional: KOP: 1300' Maximum Hole Angle: Close Approach Wells: 97° at 11600' MD - production hole Surface - 15' wellhead spacing with S-100 to -300' MD Gyro will be used for initial surveys and kick-off. Logging Program: Surface Intermediate Hole Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 2117 1800 SV3 / T5 3952 2650 SV1 / T3 5053 3150 K15 5339 3280 Ugnu top (UG4A) 5780 3480 8.98 ppg EMW (pore pressure = 1625) Ugnu (UG1) 8121 4573 8.96 ppg EMW (pore pressure = 2130) West Sak (WS2) 8493 4810 8.64 ppg EMW (pore pressure = 2160) West Sak (WS1) 8683 4940 8.8O ppg EMW (pore pressure = 2260) Base West Sak 9129 5244 Top upper HRZ 10773 6365 Trad. Top HRZ 11076 6572 HRZ Base 11289 6717 Kuparuk C4B 11315 6735 Top Target 9.9 EMW (pore pressure = 3435) Kuparuk C4A 11328 6744 Kuparuk C3B 11367 6768 Kuparuk C3A 11426 6797 Base Target Interval Kuparuk C2 6852 Not Penetrated Kuparuk C1 6876 Not Penetrated Kuparuk B, LCU 6895 Not Penetrated Kuparuk A 7027 Not Penetrated Miluveach 7066 Not Penetrated TD 13932 6763 TD Horizontal S-102 Permit to Drill Page 2 ( ( Casinc/Tubing Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 110/110 13-1/2" 10-3/4" 45.5# L-80 BTC 5153' GL 5153'/3261' 9-7/8" 7" 26# L-80 BTC-M 11326' G1 11326'/6808' 6-1/8" 4-1/2" 12.6# L-80 BTC-M -995' 11176'/6705' 12171'/6705' 6-1/8" 4-1/2" 12.6# L-80 Slotted -1761' 12171'/6821' 13932'/6829' Tubing 3-1/2" 9.3# 13-Cr Fox -11176' GL 11176'/6617' Cement Calculations: The following cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Cement volumes will be as follows: Lead - as noted for 1st stage. Tail - as noted below for 1st stage. Casin(. Basis: Size 110 3~4" Surface - lS' Stage I Lead: Based on 2117' of annulus in the permafrost @ 200% excess and 2536' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -4653' MD (2968' TVDss). Lead 630 bbl / 3537 ft~ / 797 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 50 bbl/281 ft~ / 242 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casin(, Basis: Size 17" Intermediate - 1s' Stage I Lead: 500' above Ugnu 4 formation and 30% excess Lead TOC: 5280' MD ITotal Cement Volume: Tail: Based on TOC 500' above top of Kuparuk River formation and 50% excess + 80' shoe track. Tail TOC: 10,815' MD, 6394' ss TVD Lead 1 340 bbls / 1909 ftc/684 sks of Dowell Extended blend at 1 11.5 ppg and 2.79 cf/sk. Tail 34 bbls / 191 ftc/165 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size 14'1/2''Solid section.Pr°ducti°n' 1s~ Stage Basis: Lead: Solid 4 ~" Liner will be run to -12,171' MD, (845') with 150' liner lap, 200' above liner top and 80' shoe track, plus 30% excess in open hole. Lead TOC: - 11,176' MD, top of 4 1~,, liner Tail: N/A ITotal Cement Volume: Lead 38 bbls / 213 ftc/184 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Tail None S-102 Permit to Drill Page 3 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. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- - Maximum anticipated BHP: · Maximum surface pressure: 3435 psi @ 6735' TVDss - Kuparuk Target Top 2761 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 10.3 ppg KCI/NaCI/NaBr Brine / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · S-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad has been 60 ppm (S-37, 12/2/98) DRILLING CLOSE APPROACH: There are no close approach issues while drilling this well, except for surface proximity to S-100 and S-101. S-102 is 15' from S-100 at surface to KOP of 300' MD. A gyro will be run while drilling surface hole until S-102 is kicked-off and away from magnetic interference. SURFACE HOLE SECTION: · Directional control was an issue in the S-100 surface hole. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · The surface hole interval on S-Pad has been relatively problem free on most wells to date. Only one well (S-22, 1990) is recorded with lost circulation problems. S-22 experienced lost circulation while drilling and cementing both. · Some tight hole has been noted while running casing, in particular with the larger 13- 3/8" casing in 16" holes. · The S-102 well will cross a fault in very shallow unconsolidated sediments where there is little mechanical or fluid contrast between sediments in and outside the fault zone. The S-102 well is expected to cross this fault between 2100' and 2600' MD. This fault has been encountered in virtually all S-pad wells with no directly attributed incidents reported. · Heavy clays are reported in the 2000-3000' TVD area of S-pad. S-102 Permit to Drill Page 4 · Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- 40 required 9.3 ppg mud to drill this interval. INTERMEDIATE HOLE SECTION: · The major north-south oriented fault, which bisects Aurora Field occurs between S- Pad and the target polygon, and will parallel much of the S-102 trajectory. At Kuparuk depth, this fault has approximately 175' of down-to-the-west displacement and is located approximately 1700' to 2000' east of the BHS. This fault extends upward toward the surface where its displacement diminishes and its imaging on seismic data also diminishes. It could occur in a zone up to 750' wide, and may be made up of one or more fault strands. This fault presents a fluid loss hazard, and a possible ~qeo- steering hazard. It is planned that the S-102 well cross this fault in very shallow unconsolidated sediments where there is little mechanical or fluid contrast between sediments in and outside the fault zone. The S-102 well is expected to cross this fault between 2100' and 2600' MD. · Numerous faults of varying orientations and displacements occur east of the above major north-south fault. These faults have a complex pattern and are not well imaged seismically. They occur in the northwest quadrant of Drillsite S, and many of these faults have been crossed en route to Sag River-lvishak targets. These faults potentially pose hazards for fluid loss, gas cut mud, borehole ledges, or tight formation. · Gas cut mud occurred in a relatively nearby well (S-03) at 5713' TVD. Mud weight was increased from 10.1 ppg to 10.3 ppg to handle the problem. Other wells wells experienced gas cut mud in the Ugnu between 3674' TVD and 4040' TVD, these wells were not drilled in the direction of the S-102 target. · A relatively high angle through the HRZ in this well will require a higher mud weight and attentive drilling practices to ensure wellbore stability. · The kick tolerance for the 9-7/8" open hole section would be 128 bbls assuming an influx from the Sag River interval at -11,326' MD. This is a worst case scenario based on a 9.9 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.4 ppg mud in the hole. Rig will perform LOT after drilling 20ft of new formation. Actual: S-100 FIT = 12.5 ppg; S-101 LOT = 14.6 ppg PRODUCTION SECTION: · A small fault with 15'-20' of down-to-the south displacement will occur in the horiz, section approx. 420' after the BHS point. It carries a moderate geo-steering risk to stay in zone, but should not pose a significant LC risk. · Two small faults occur 325' to the west of the BHS point, and 325' south of the BHS point. These have 20' to 35' of displacement. They constrain the width of the target polygon. As long as the wellbore stays within the polygon, these faults will not be encountered. · A significant fault with 20' to 40' of down-to-the-east displacement occurs approx. 400' beyond and west of the EHS point. The well should reach TD before reaching this fault. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 13,932' MD. This is a worst case scenario based on a 9.9 ppg pore pressure, a minimum fracture gradient of 12.5 ppg at the 7" casing shoe, and 10.5 ppg mud in the hole. Rig will perform FIT to 12.5 ppg after drilling 20ft of new formation. Actual: S- 100 FIT = 12.5; S-101 will be performing a LOT after drilling out intermediate casing. S-102 Permit to Drill Page 5 Disposal: · No annular injection in this well. · Cuffings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. DRILL AND COMPLETE PROCEDURE SUMMARY Pm-Rig Work: The 20" conductor has already been set for this well. 1. Weld an FMC landing ring for the FMC Big Bore Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. Operations: MIRU Nabors 9ES. Nipple up and function test 16" diverter system. PU 5" DP as required and stand back in derrick. MU 13-1/2" drilling assembly and drill surface hole to approximately 5153' MD / 3261' TVD. The actual surface hole TD will be +/-100' MD below the SV1 sand. 4. Run and cement the 10 %", 45.5# surface casing back to surface. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 9 7/8" drilling assembly and RIH to float collar. Test the 10 3,4" casing to 3000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a LOT. 8. Drill per directional plan to top of Kuparuk and TD intermediate section at 11326' MD (6808' TVD). 9. POOH, lay down 5" DP. 10. Run 7" 26#/ft intermediate casing to TD and cement to -6035' above top of the Kuparuk formation, (cover Ugnu formation), set on emergency slips. 11. RIH w/6-1/8" drilling assembly on 4" DP. Test casing to 3000 psi for 30 minutes. 12. Drill out 7" shoe and change mud over to 10.3 ppg LSND. Drill 20' new hole and perform FIT to 1.0 ppg over the mud weight. 13. Drill ahead to planned TD at approximately 13,932' MD / 6829' TVDbkb. POOH. 14. MAD pass with Neu/Den/Res LWD as required. Spot liner running pill in open hole. 15. Run 4 Y2" combination solid/slotted production liner. 16. Cement 4 Y2" solid liner from -12171' MD to top of 4 ~" liner @-11,176' MD / 6705' TVD. 17. RIH w/2 7/8" workstring and cleanout to TD of slotted liner. Displace 4-1/2" slotted liner with enzyme breaker. POOH to top of liner and displace well to clean 10.3 ppg brine. POOH. 18. Run 3-1/2", 9.3# 13-Cr completion string. See attached completion schematic for details. Set production packer and test tubing and annulus to 3500 psi. 19. Install two-way check. Nipple down.the BOPE. Nipple up and test the tree to 5000 psi. Pull two-way check and shear the RP valve in the top GLM. 20. Freeze protect the well to -2000' TVDss. Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 8/28/2OOO Allen Sherritt Alaska Drilling and Wells 564-5204 sherrija@BP.com S-102 Permit to Drill ~,~a,a. ka Oi'i a Gas C.~'~s. Oo~.imissior~_ AncI~0ra(le Page 6 TREE: 4-1/16" - 5M ClW Chrome WELLHEAD: 13 518' - §M FMC SH 7" slips will be used to hang intermediate casing. S-102 Proposed Completion Cellar Elevation = 35.7' Nabors 9ES RKB = 64.2' 10-3/4", 45.5 #Iff, L-80, BTC 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I ~2500' MD I 3-1/2" Camco Gas Lift Mandrels with handling pups installed. , GAS LIFT MANDRELS ,..[ .... ~ ' ......... I~1~ ................ -~'i~ ................... -~i~,;--~r-yl~'(; ........... TBD TBD TBD TBD 1" RP Shear 1" DV 1" DV 1 - 1/2" DV 3-1/2" 9.2# 13Cr-80, Fox Tubing 7", 26 #/ft, L80, BTC-Mod 4-1/2" 12.6 #/ft, L-80, BTC-Mod Solid Liner 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer with crossover pups to 3-1/2" 3-1/2" 'XN' Landing Nipple with 2.813" seal bore and 2.75" No-Go ID. 3-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I1 i176' MD I BAKER 5" x 7" Liner Tie Back Sleeve I ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" x6-3/4" ECPJ 12,171' MD I · " 4-1/2" 12.6 #Iff, L-80, BmC-Uod I 13,932' MD J Slotted Liner .~.-"" .... Plug Back DepthI 1 Date Rev By Comments 6/8/00 JAS Proposed Completion 8/16/00 JA$ Revised Proposed Completion AURORA WELL' S-102 APl NO' 50-029-????? Shared Services Drilling i Shared Services Drilling S-102 Wp 10 I DrillQuest' __ 1250 2500 3750 5000 o ~ 6250 .-- /Begin Dir @ 1.5°/100ft: 300.00ft MD, 300.00ft TVD /Increase in Dir Rate @ 2.500°/100ft· 500.00ft MD, 499.91ft TVD /Increase in Dir Rate @ 3.000°/100ft: 700.00ft MD, 698.92ft TVD 7ncrease in Dir Rate @ 3.500°/100ft: 900.00ft MD, 895.16ft TVD End Dir: 2100.00ft MD, 1856.28ft TVD · 2355.55ft MD, 1991.10ft TVD SV3tT5 - 2715.70 TVD 10 3/4" Casing (100' MD Below SV1) 5152.96 MD . .3.2_6.1:.10...T~.. ......................... - ................ SVIff3 - 3215.70 TVD .............................................. UG4A/KI5 (Firzt Coal) - 3345.70 TVD UC-4A/Top Ugntt - 3545.70 TVD I WM: S-1(32 I I-I~iz~nlal Cored'roles: I Re~. Gl~al Cm~dinatas: 598~655.13 N, 618829.g6 E [ R~. Sltuct~e Rem:2t7.17 S, 10~9.~2 E I I~ I~=~Oon: 65.7~R m Meea Sea Level 65.7~1t ah3te S~uclm'e Ra~mnce I ~ Re~ence: Tree ~ [ Unib: Feel .............................................................................................................. 0 Scale: linch = 1250ft Proposal Data for S-102 Wp10 Vertical Origin · S-102 WPS Horizontal Origin:S-102 WPS Measurement Units:ft North Reference: True North Dogleg severity: Degrees per 100fi Vertical SeclJon Azimulh: 322.201 ° Vertical SeclJon Description: S-102 WPS Vertical Secl~on Origin: 0.00 N,0.00 E Measured Incl. Azlm. Vertical Northings Eastlngs Vertical Dogleg Depth Depth Section Rate 0.00 0.000 0.910 0.00 0.0{) N 0.(X) E 0.0{) 300.00 0.000 0.910 300.00 0.(X) N 0.0{) E 0.0{) 0.0{X) 500.00 3.000 322.310 499.91 4.14 N 3.20 W 5.23 I..~X) 700.00 8.000 322.310 698.92 19.31 N 14.92 W 24.40 2.50{} ~00.00 14.000 322.310 895.16 49.49 N 38.24 W 62.54 3.0{X) 2100.00 56.000 322.310 1856.28 582.04 N 449.~) W 735.52 3.500 2200.00 56.000 322.310 1912.20 647.64 N 500.38 W 818.43 0.0{X} 2355.55 63.000 322.310 1991.10 753.64 N 582.28 W 952.38 4.50{} 5163.10 63.000 322.310 3265.70 2733.18 N 2111.7(} W3453.91 (}.0{)0 7674.16 63.000 322.310 4405.70 4503.67 N 3479.62 W 5691.28 0.(]00 8474.16 47.000 322.310 4863.07 5020.56 N 3878.98 W 6344.48 2.0{)0 11325.53 47.000 322.310 6807.70 6670.76 N 5153.95 W E429.83 0.{XX) 11335.53 47.000 322.310 6814.52 6676.55 N 5158.43 W E43'/.14 0.{X)O 11600.31 97.305 321.728 6893.09 6868.77 N 530S.74 W 8681.16 19.00{} 12170.65 97.:305321.728 6820.56 7312.~0 N 5659.14 W 9246.85 0.0{X) 12234.91 89.595 321.865 6816.70 7363.27 N 5~)8.78 W 9310.95 12.00{} 13931.98 89.595 321.865 6g2&70 8698.011 N 6746.72 W 110{}7.940.0{X} mi IJnils: ft S-lO2 Pol)~on ~lU~ Poinl Bomlda~ point ~ S-10Z TI B/~/00 En~)' Poird ~102 'r2 8~00Enl~- Poim S-10213 8~0 Enlty P~im S-102 Wp01 TIEn~- Poim S-102 WpO112 F..nl~y Poim in Dir @ 2.000°/100ff· 7~74.15ft MD, 4405.70ft TVD Dir' 8474.1~t MD, 4853.07ff TVD ............. 'O~'[~.[,;~it;; iO~'- ;i&ig'7'o' ~i " W$11$chrad~r O~ - $00~, 10 SIngle Well Target Data for 5-102 Cee~gmd$ Point TVI)rkb 'rVDsI NMthlngl Eamtlr~ ASP Y ~sP X TatUM $-!02 T3 819/00 6828. ?0 8698.08 N, 6746.72 If~ ..................... T,'I' lit1-, II~X. . ~t.o).7o 7 11325.53 MD .......................... 6807.70 TVD ......... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........ ::..=:::: ............................................................................... .,..,:., ~ .,.::: :. !: ...: ! ............... .: ....................... ,.%/,8~ X1,819J~0 ............... -" b'~.8, ~'.0 .'t 1~ ...................... ..................................................................................................................... '~St)~: ~O'~ .................. 7,~;, ~7 N ¢~on ,n w ., ',.', .',, .'.;,. ,'. '. , I I I I I I Oo//.o~ ~,, ~,~.o'o w I ' I 4 ha' Liner ~ 13931 98 3 1250 2500 3750 5000 6250 7500 8750 10000 sa2e ~o ............. ' .......... "' Vertical Section Section Azimuth: 321.291 ° (Grid North) sper',r, j-sunI A IL~JJJl~'el~'~ CI~%IP,L%N Shared Services Drilling S-102 Wp 10 I DriHQuestTM Scale: linch = 1500ft Eastings -6000 -4500 -3000 -1500 0 CmTent Well Properties S. I(~ Rel. (~1 CO,halOs: .6~60655.13 N. 618~.96 E ROI. Sb'ucluro Rolm'once: 21 ?. 17 S 1000.9~ E Rd. GeograiYnical Co~rdinales: 70' 21' 20.8844' N. 149' OZ 02.910~- W ~ EIo~l~on: 65.701{ aborn Mean Sea Lmel 65.70lt aix~e Slmcl~e Roferon,a Units: Feel 9000 41/2" Liner 13931.98 k4 6828.70 TV 7500 6000 3000 I I I I _ S'!02 Polygon _ ~, 5-102 T3 8/9/00 er ~,,~----- 6828. 70 TVD ~ ~ N, 6746.72 W _ \'~,_\ End Dir: 12234.91ft MD, 6816.70ft TVD egin Dir @ 12.000°/100ft: 12170.65ft MD, 6820.56ft TVD - S.lO2~ s/9/oo/ ~End Dir: 11600.31ft MD, 6893.09ft TVD 6816.70~ ~-,~B~in Dir ~ 19.000°/100ft: 11335.53ft MD, 6814.52ft TVD 7363.27N, 5~8.78 W ~ 7" ~ing / '~ 11~5.~ MD ~ ~ 6807.70 ~ S-l~T~9/O0/ ~o.~ _ 6807.70 T~ / ~ 6677.62 N, 5159.60 W ~ ~find ~ir: 8474.~ff M~, 48~.07ff TVD ~ ~B~in Dir ~ 2.000°/l~ft: _ ~7674.16ft MD, 4405.7~t TVD S~ Wag Tar~ D~a f~ ~102 ~.~ -- Mo~m~ Un~,: , ~ 10 ~4" C~ing I -- ' Co~ln.. ~-- 5152 ~ MD TI~II Point ~D~ TVDal No~lng. EaaUng. ~fl Y ~P X Ta~ ~ ~oed "d ~ ~tm Nam ~pi Shape ~M ~v...v , vu (~(~I6N ~3,~dW 5~7434.~N 613378,~E ~ ~-I(~T3~l I~Po~ (~28.~67(~1.~ ~,~N 6746,~2W ~892&~,~N612~.~E P~ ~ -- ~-102W~ITI ~P~ 6762,~(~7,~ 73~%27N 5~8,~W 598~27.~N6131IS.~B p~ :~ .... .... ~'~ End Dir' 2355 55ft ~D, ~0{~ ~ End Dir: 21~.0~t MD, 1B562~t TV~~.. Incr~se inDir Rate ~ 3.500°/10~t: 9~f~~it_~V_~ ~ Incre~e in Dir Rate ~ 3 0~°/10~t: 70~t ~8.92ft-TV~ N Incr~e in DirRate ~ ~.500°/10~t: 500.~ff ~99.91ft TV~~ B~in Dir ~ 1.5°/1~t: 3~.~ft MD. ~ TV~ I I I I -c:4500 o Z 1500 O II ~ o -6000 -4500 -3000 -1500 0 Scale:linch = 1500ff Eastings Referenceis True No~h 9OOO 75O0 6000 4500 3000 1500 SperrY'Sun Drilling Sei ices Proposal Data - S- 102 - S- 102 Wp 10 i MD Delta Inclin. Azimuth TVD Delta Northings Eastings Dogleg Toolface (ft) MD (ft) (°) (°) (fi) TVD (fi) (fi) (ft) (°/100ft) (°) I 0.00 0.000 0.000 0.00 0.00 0.00I 2 300.00 300.00 0,000 0.0O0 300.00. 3O0.00 0.00 0.00 0.000 0.O00 3 500.00 200.00 3.000 322.310 499.91 199.91 4.14N 3.20W 1.500 322.310 '~-- 700,00 200.001 8,000 322.310 698.92 199.02 19.31N 14,92W 2.5oo1~ o.ooo' 9°0.O0 6.000 5 200.00 14.000 322.310 895.16 196.24 49,49 Ni 38,24 W 3.000i 6' 2100,00 1200.00: 56.000 322.310 1856.28 961.12 582.04 N 449,69 W 3.500' 0.000! 7 22O0.O0 100.00 56.000 322.310 1912.20 55.92 C047.64N. 5O0.38W 0.000 ~).000! 8' 2355.55 155.56 63.000 322.310 1991.10 78.90 753~64 N 582.28 W 4.500 0.000 9' 5163.10 2807.54; 63.O00 322.310 3265.70 1274.60 2733.18N 2i11.70W 0.000 0.0001 10' 7674.16 2511.07 63.000 322.310 4405.70 1140.00 4503.67N 3479,62W 0.000 0.000 11; 8474116 800,00 47.000' 322,310 4863.07 457;37 5020.56N 3878.98W 2.000 180.000 ,.. 12' 1.1325:53 2851:37 47.000 322.310 6807.70 ':i944:63 667-(~:76N 5~53.95:W 0.000 o.000i ] 13 11335;53' 10.00 47~000 322~310,~ 68!4.52 ' :14 i i'1~,3i!~'.~264~78 1 97,305 / 32L728 6893,09 78~57- .6868~fi~ 53~&74w: 19.000:.-359,251. :~: : ~: !~. :: ..:: i~..~: ~:: :::: :-':. !,-~ :¥. f t ::~:: ~ : ~ "L.-: ~i-~' : '::~1:~;~ ~ : ~: i :-::;i .~ ~ ; : ~ :: ::~:: ;~1.5:~:: 12170,6~ :~ ~34: .:97,~5:32!~728 ~ :~20,56::~., ~72~52_-.. 73~2~90:N~:c~:5~9:14~: ~ : 0,~0 ~ ~ :~0.~0: i-i~ :t ~,~a~'~;,~! ;h%.~ol;::89.s9sl: ,-:~.~051 j8~8.,01 ~.~ ~C::~,~°°j 8090.08 Ni 6740.72 W .? ::-:o:~or ~ ?:~ 0.~i 14 August, 2000- 14:42 - 1 - DrillQuest North Slope Alaska Alaska State Plane 4 PBU WOA S Pad~ sho~ wp~o - .... PROPOSAL '~, ~R~oRT ~,o~. ,='"N;[:.~ ~oo =,' =o...~'' N, Kelly above Mean Sea Level 149° 02' 02.9105" W) Proposal Ref: pro9920 North Slope Alaska Measured Depth Incl. Azim. 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 1.500 322.310 500.00 3.000 322.310 600.00 5.500 322.310 700.00 8.000 322.310 800.00 11.000 322.310 900.00 14.000 322.310 Sub-Sea Depth (ft) -65.70 34.30 134.30 234.30 334.29 434.21 533.93 633.22 731.84 829.46 Sperry-Sun Drilling Services Vertical Depth (ft) 0.00 100.00 200.00 300.00 399.99 499.91 599.63 698.92 797.54 895.16 Proposal Report for S- 102 Wp 10 1000.00 17.500 322.310 925.69 991.39 1100.00 21.000 322.310 1020.09 1085.79 1200.00 24.500 322.310 1112.29 1177.99 1300.00 28.000 322.310 1201.96 1267.66 1400.00 31.500 322.310 1288.77 1354.47 1500.00 35.000 322.310 1372.39 1438.09 1600.00 38.500 322.310 1452.50 1518.20 1700.00 42.000 322.310 1528.81 1594.51 1800.00 45.500 322.310 1601.04 1666.74 1900.00 49.000 322.310 1668.91 1734.61 2000.00 52.500 322.310 1732.17 1797.87 2100.00 56.000 322.310 1790.58 1856.28 2116.84 56.000 322.310 1800.00 1865.70 2200.00 56.000 322.310 1846.50 1912.20 2300.00 60.500 322.310 1899.11 1964.81 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (,) (ft) (ft) (ft) (°/lOOft) 0.00 N 0.00 E 5980655~ 618929.96 E 0.00 N 0.00 E 59806~.~ 618020.96 E 0.000 0.00 N 0.00 E 598~55.1~ 618929.96 E 0.000 0.00 N 0.00 E 5~1]i~55.13 N~618929.96 E 0.000 1.04 N 0.80 W 5 N 618929.14 E 1.500 4.14 N 3.20 W"%' .'. ...... 6~ 2 N 618926.69 E 1.500 10.01 N ~ W'"~;8~665.01 N 618922.07 E 2.500 19.31 N ~~ .... 5980674.20 N 618914.74 E 2.500 32.37 N..',,. ~01___ W'~ 5980687.09 N 618904.44 E 3.000 49.49..,,~"i:?'i':"!';;'.;:=i!'=i, '...." 31~ W 5980704.01 N 618890.94 E 3.000 70.97 N' ,,,,, ,,,, ,,: ,,""i' :i,;,,' 54.83 W 97.05 N ~' 74.98 W 127.65 N 98.62 W 162.64 N 125.66 W 201.90 N 156.00 W 245.29 N 189.51 W 292.63 N 226.09 W 343.75 N 265.59 W 398.46 N 307.86 W 456.56 N 352.75 W 517.83 N 400.08 W 582.04 N 449.69 W 593.09 N 458.23 W 647.64 N 500.38 W . 714.92 N 552.36 W Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 0.00 0.00 0.00 0.00 1.31 5.23 12.65 24.40 40.90 62.54 5980725.22 N 618874.01 E 3.500 89.68 5980750.98 N 618853.44 E 3.500 122.65 5980781.20 N 618829.32 E 3.500 161.31 5980815.76 N 618801.73 E 3.500 205.53 5980854.53 N 618770.78 E 3.500 255.15 5980897.38 N 618736.58 E 3.500 309.97 5980944.13 N 618699.25 E 3.500 369.79 5980994.62 N 618658.95 E 3.500 434.39 5981048.65 N 618615.82 E 3.500 503.53 5981106.03 N 618570.01 E 3.500 576.95 5981166.54 N 618521.70 E 3.500 654.38 5981229.96 N 618471.08 E 3.500 735.52 5981240.87 N 618462.37 E 0.000 749.49 5981294.75 N 618419.36 E 0.000 818.43 5981361.19 N 618366.32 E 4.500 903.44 Comment BeQ_ in Dir @ 1.5°/100ft: 300.00ft MD, 300.00ft TVD Increase in Dir Rate@ 2.500°/100ft: 500.00ft MD, 499.91ft TVD Increase in Dir Rate @ 3.000°/100ft: 700.00ft MD, 698.92ft TVD Increase in Dir Rate @ 3.500°/100ft: 900.00ft MD, 895.16ft TVD End Dir' 2100.00ft MD, 1856.28ft TVD B Perm Bec3_ in Dir @ 4.500°/100ft: 2200.00ft MD, 1912.20ft TVD Continued... 14 August, 2000 - 14:45 - 2 - DrillQuest 1.05.058 North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 2355.55 63.000 322.310 1925.40 1991.10 2400.00 63.000 322.310 1945.58 2011.28 2500.00 63.000 322.310 1990.98 2056.68 2600.00 63.000 322.310 2036.38 2102.08 2700.00 63.000 322.310 2081.78 2147.48 2800.00 63.000 322.310 2127.18 2192.88 2900.00 63.000 322.310 2172.58 2238.28 3000.00 63.000 322.310 2217.97 2283.67 3100.00 63.000 322.310 2263.37 2329.07 3200.00 63.000 322.310 2308.77 2374.47 3300.00 63.000 322.310 2354.17 2419.87 3400.00 63.000 322.310 2399.57 2465.27 3500.00 63.000 322.310 2444.97 2510.67 3600.00 63.000 322.310 2490.37 2556.07 3700.00 63.000 322.310 2535.77 2601.47 3800.00 63.000 322.310 2581.17 2646.87 3900.00 63.000 322.310 2626.57 2692.27 3951.62 63.000 322.310 2650.00 2715.70 4000.00 63.000 322.310 2671.96 2737.66 4100.00 63.000 322.310 2717.36 2783.06 4200.00 63.000 322.310 2762.76 2828.46 4300.00 63.000 322.310 2808.16 2873.86 4400.00 63.000 322.310 2853.56 2919.26 4500.00 63.000 322.310 2898.96 2964.66 4600.00 63.000 322.310 2944.36 3010.06 Proposal Report for S- 102 Wp 10 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (fi) (fl) (ft) (ft) (°/lOOft) 784.98 N 606.49 W 5981.~ 618311.08 E 0.000 855.49 N 660.97 W ~ ~5~0.02'~ 618255.50 E 0.000 996.50 N 769.92 W ~28N 618144.32 E 0.000 1067.01 N 824.39~....=Wii'!::i":: ..... ..._ _~598=~1~8'.92 N 618088.73 E 0.000 1137.52 N 878.87 Wi':i;iil;i:: :'::i!':S';'.:'~981778.55 N 618033.14 E 0.000 1208.03 N 933,34 Ws;i~:S:'.'......."i'i'"5§8~848.19 N 617977.56 E 0.000 1278.53 N ~~. W ~5981917.82 N 617921.97 E 0.000 1349.04 N ~~5981987.45 N 617866.38 E 0.000 1419.55_.,_N'"~ ....... ...., ,T~....~.....~x VV~ 5982057.09 N 617810.79 E 0.000 1490.0,6:,,~,,i,':?? ' I,, '~".:::?::1:~., ~,~-1"5!";:25 W 5982126.72 N 617755.20 E 0.000 1560.5~,':~:'~ '"';7!;:205'72 W 5982196.36 N 617699.62 E 0.000 1631.07N.!::~:'.!.I.. .... 41.260.20 W 5982265.99 N 617644.03 E 0.000 1701.58 N'?.i~7i314.67 W 5982335.62 N 617588.44 E 0.000 1772.09 N 1369.15 W 5982405.26 N 617532.85 E 0.000 1842.59 N 1423.62 W 5982474.89 N 617477.26 E 0.000 1878.99 N 1451.74 W 5982510.84 N 617448.57 E 0.000 1913.10 N 1478.10 W 5982544.53 N 617421.68 E 0.000 1983.61 N 1532.57 W 5982614.16 N 617366.09 E 0.000 2054.12 N 1587.05 W 5982683.79 N 617310.50 E 0.000 2124.63 N 1641.53 W 5982753.43 N 617254.91 E 0.000 2195.13 N 1696.00 W 5982823.06 N 617199.32 E 0.000 2265.64 N 1750.48 W 5982892.70 N 617143.74 E 0.000 2336.15 N 1804.95 W 5982962.33 N 617088.15 E 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) 952.38 991.98 1081.08 1170.18 1259.28 1348.38 1437.48 1526.58 1615.68 1704.78 1793.88 1882.98 1972.08 2061.18 2150.28 2239.38 2328.48 2374.48 2417.58 2506.69 2595.79 2684.89 2773.99 2863.09 2952.19 Comment End Dir: 2355.55ft MD, 1991.10ft TVD SV3/T5 Continued... 14 August, 2000-14:45 - 3 - DrillQuest 1.05.058 North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 4700.00 63.000 322.310 2989.76 3055.46 4800.00 63.000 322.310 3035.16 3100.86 4900.00 63.000 322.310 3080.56 3146.26 5000.00 63.000 322.310 3125.96 3191.66 5052.96 63.000 322.310 3150.00 3215.70 5100.00 63.000 322.310 3171.35 3237.05 5152.96 63.000 322.310 3195.40 3261.10 5163.10 63.000 322.310 3200.00 3265.70 5200.00 63.000 322.310 3216.75 3282.45 5300.00 63.000 322.310 3262.15 3327.85 5339.31 63.000 322.310 3280.00 3345.70 5400.00 63.000 322.310 3307.55 3373.25 5500.00 63.000 322.310 3352.95 3418.65 5600.00 63.000 322.310 3398.35 3464.05 5700.00 63.000 322.310 3443.75 3509.45 5779.85 63.000 322.310 3480.00 3545.70 5800.00 63.000 322.310 3489.15 3554.85 5900.00 63.000 322.310 3534.55 3600.25 6000.00 63.000 322.310 3579.95 3645.65 6100.00 63.000 322.310 3625.34 3691.04 6200.00 63.000 322.310 3670.74 3736.44 6300.00 63.000 322.310 3716.14 3781.84 6400.00 63.000 322.310 3761.54 3827.24 6500.00 63.000 322.310 3806.94 3872.64 6600.00 63.000 322.310 3852.34 3918.04 6700.00 63.000 322.310 3897.74 3963.44 6800.00 63.000 322.310 3943.14 4008.84 6900.00 63.000 322.310 3988.54 4054.24 7000.00 63.000 322.310 4033.94 4099.64 7100.00 63.000 322.310 4079.34 4145.04 Proposal Report for S- 102 Wp 10 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2406.66 N 1859.43 W 5983031~ 617032.56 E 2477.16 N 1913.90 W 59831~ 616976.97 E 2547.67 N 1968.38 W 598.~[~.2~ 616921.38 E 2618.18 N 2022.85 W ~4~87 N~ 616865.79 E 2655.52 N 2051.71 W ~5 N ~: 616836.35 E 2688.69 N 2077.33 W .... 5g'8~'~10.50 N 616810.21 E 2726.03 N 2106.18 W' ??'::'!:i ': 5..9.83:~:'38 N 616780.77 E 2733.18 N 2111.70 W;~.;:=;!i~', "'"' ,,598.,3,354.44 N 616775.13 E 2759.19 N 2_~W ~983380.13 N 616754.62 E 2829.70 N ~~5983449.77 N 616699.03 E 2857.42 N '~0~ 5983477.14 N 616677.18 E 5983519.40 N 616643.44 E 5983589.04 N 616587.85 E 5983658.67 N 616532.27 E 3111.73 N::'~'~:,:i,,~,,: ..... :,'i!:!~04.18 W 5983728.30 N 616476.68 E 3168.03 N '-~ 2447.68~ W 5983783.91 N 616432.29 E 3182.24 N 2458.66 W 5983797.94 N 616421.09 E 3252.75 N 2513.13 W 5983867.57 N 616365.50 E 3323.26 N 2567.61 W 5983937.20 N 616309.91 E 3393.76 N 2622.09 W 5984006.84 N 616254.33 E 3464.27 N 2676.56 W 5984076.47 N 616198.74 E 3534.78 N 2731.04 W 5984146.11 N 616143.15 E 3605.29 N 2785.51 W 5984215.74 N 616087.56 E 3675.80 N 2839.99 W 5984285.37 N 616031.97 E 3746.30 N 2894.46 W 5984355.01 N 615976.39 E 3816.81 N 2948.94 W 5984424.64 N 615920.80 E 3887.32 N 3003.41 W 5984494.28 N 615865.21 E 3957.83 N 3057.89 W 5984563.91 N 615809.62 E 4028.33 N 3112.37 W 5984633.54 N 615754.03 E 4098.84 N 3166.84 W 5984703.18 N 615698.45 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~) 3041.29 3130.39 3219.49 3308.59 3355.78 3397.69 3444.88 3453.91 3486.79 3575.89 3610.92 3664.99 3754.09 3843.19 3932.29 4003.44 4021.39 4110.49 4199.59 4288.70 4377.80 4466.90 4556.00 4645.10 4734.20 4823.30 4912.40 5001.50 5090.60 5179.70 Comment SV1/T3 10 3/4" Casing UG4A/K15 (First Coal) UG4A/Top Ugnu Continued... 14 August, 2000 - 14:45 - 4 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 7200.00 63.000 322.310 4124.73 4190.43 7300.00 63.000 322.310 4170.13 4235.83 7400.00 63.000 322.310 4215.53 4281.23 7500.00 63.000 322.310 4260.93 4326.63 7600.00 63.000 322.310 4306.33 4372.03 7674.16 63.000 322.310 4340.00 4405.70 7700.00 62.483 322.310 4351.83 4417.53 7800.00 60.483 322.310 4399.57 4465.27 7900.00 58.483 322.310 4450.35 4516.05 8000.00 56.483 322.310 4504.10 4569.80 8100.00 54.483 322.310 4560.76 4626.46 8120.96 54.064 322.310 4573.00 4638.70 8200.00 52.483 322.310 4620.27 4685.97 8300.00 50.483 322.310 4682.54 4748.24 8400.00 48.483 322.310 4747.50 4813.20 8474.16 47.000 322.310 4797.37 4863.07 8492.68 47.000 322.310 4810.00 4875.70 8500.00 47.000 322.310 4814.99 4880.69 8600.00 47.000 322.310 4883.19 4948.89 8683.30 47.000 322.310 4940.00 5005.70 8700.00 47.000 322.310 4951.39 5017.09 8800.00 47.000 322.310 5019.59 5085.29 8900.00 47.000 322.310 5087.79 5153.49 9000.00 47.000 322.310 5155.99 5221.69 9100.00 47.000 322.310 5224.19 5289.89 Proposal Report for S- 102 Wp 10 Local Coordinates Northings Eastings (ft) (ft) 4169.35 N 3221.32 W 4239.86 N 3275.79 W 4310.36 N 3330.27 W 4380.87 N 3384.74 W 4451.38 N 3439.22 W 4503.67 N 3479.62 W. .... 4521.85 N 4591.37 N 4659.54 N 4726.27 N Global Coordinates Northings Eastings (ft) fit) 5984772.~ 615642.86 E 59848~ 615587.27 E 598_~.08~ 615531.68 E ~81.71 N'~ 615476.09 E 5 N ~ 615420.50 E 9 N 615379.28 E 615364.95 E 615310.13 E 615256.39 E 615203.79 E 615152.38 E 615141.77 E 615102.25 E 615053.43 E 615006.01 E 614971.76 E 614963.32 E 614959.98 E 614914.35 E 614876.34 E 3547.38 W':[;;,]! i;i',.:.,, ,...,::'.:';;:'~§8~1'89.61 N ...... ,,3~5 W '~5985256.93 N .,.'..i":i:ii,..3.'651..~.iW... ~5985322.83 N 4791.46 N, ,,,,, :,,,,,,,,, W''''~,' 5985387.22 N 4804.93:,,!~?:''''''~' "'.::L';:ii.!: W 5985400.52 N """i: .!~751"i"1'i W5985450.03 N 4916.97'::'N..:'.i,'.!;,~'.:~ ...... ,..ii~798.94 W 5985511.17 N 4977.13 N'"' 'V:;~845.42 W 5985570.58 N 5020.56 N 3878.98 W 5985813.48 N 5031.28 N 3887.26 W 5985824.06 N 5035.51 N 3890.53 W 5985628.24 N 5093.39 N 3935.25 W 5985685.40 N 5141.59 N 3972.49 W 5985733.01 N 5151.26 N 3979.96 W 5985742.56 N 614868.72 E 5209.14 N 4024.68 W 5985799.71 N 614823.09 E 5267.01 N 4069.39 W 5985856.87 N 614777.46 E 5324.88 N 4114.10 W 5985914.03 N 614731.84 E 5382.76 N 4158.82 W 5985971.18 N 614686.21 E Dogleg Rate (°/lOOft) o.ooo o.ooo o.ooo o.ooo o.ooo 0.003 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 5268.80 5357.90 5447.00 5536.10 5625.20 5691.28 5714.25 5802.11 5888.26 5972.58 6054.97 6071.98 6135.33 6213.57 6289.59 6344.48 6358.02 6363.37 6436.51 6497.43 6509.64 6582.78 6655.91 6729.05 6802.18 Comment Beoin Dir @ 2.000°/100ft: 7674.16ft MD, 4405.70ft TVD UG1/$chrader MA End Dir: 8474.16ft MD, 4863.07ft TVD WS2/Top West Sak/Schrader NA WS1/$chrader OA Continued... 14 August, 2000 - 14:45 - 5 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9129.05 47.000 322.310 5244.00 5309.70 9200.00 47.000 322.310 5292.39 5358.09 9300.00 47.000 322.310 5360.59 5426.29 9400.00 47.000 322.310 5428.79 5494.49 9500.00 47.000 322.310 5496.99 5562.69 9600.00 47.000 322.310 5565.19 5630.89 9700.00 47.000 322.310 5633.39 5699.09 9800.00 47.000 322.310 5701.59 5767.29 9900.00 47.000 322.310 5769.79 5835.49 10000.00 47.000 322.310 5837.99 5903.69 10100.00 47.000 322.310 5906.19 5971.89 10200.00 47.000 322.310 5974.39 6040.09 10300.00 47.000 322.310 6042.59 6108.29 10400.00 47.000 322.310 6110.79 6176.49 10500.00 47.000 322.310 6178.99 6244.69 10600.00 47.000 322.310 6247.19 6312.89 10700.00 47.000 322.310 6315.39 6381.09 10772.74 47.000 322.310 6365.00 6430.70 10800.00 47.000 322.310 6383.59 6449.29 10900.00 47.000 322.310 6451.79 6517.49 11000.00 47.000 322.310 6519.99 6585.69 11076.26 47.000 322.310 6572.00 6637.70 11100.00 47.000 322.310 6588.19 6653.89 11200.00 47.000 322.310 6856.39 6722.09 11288.87 47.000 322.310 6717.00 6782.70 Proposal Report for S- 102 Wp 10 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5399.57 N 4171.81 W 598598~ 614672.96 E 5556.38 N 4292.96 W ~61~5-~'~' ~N '~ 614549.33 E 5614.25 N 4337.68 W ~~.81'"~ ~ N 614503.70 E 5672.13 N 4382.39 W.:.! ii;:,;'... '.. ....... . 598~2~.,97 N 614458.07 E 5730.00 N 4427.11~' :'"'W.?!i"i. :'" ;:,:!:, :,!~9863t14'.13' -"- N 614412.44 E 5787.88 N 44,~, 82 W'";:i;il, i:, ,:?;',., ~,,,,"i,: i':,'!~'{h~71.28 N 614366.82 E 5845.75 N 4¢','j6'ii~ W ";i¥;.~ 5986428.44 N 614321.19 E 5903.62 N ,, :;'"'i::'"~'561.25,",W,, '~-~5986465.60 N 614275.56 E 5961.50 N ,,,, :v:,,;,, "'"'";~5'i'96"'"~"'"" --'W`ii~'i:'`:`''' 5986542.75 N 614229.93 E 6019.37,:h'~? "',";:,::,"?':46'~bi,88 W 5986599.91 N 614184.31 E 6077.257~ .... :i'!',i;~95'i~§9 W 5986657.07 N 614138.68 E 6135.1~i:'N":':'!",:, ..... i~;J40.11 w 5986714.22 N 614093.05 E ,,., ..~....'~. 5986771.38 614047.42 E 6192.99 ."':i~'784.82 W N 6250.87 N 4829.54 W 5986828.54 N 614001.79 E 6308.74 N 4874.25 W 5986865.69 N 613956.17 E 6350.84 N 4906.78 W 5986927.27 N 613922.98 E 6366.61 N 4918.97 W 5986942.85 N 613910.54 E 6424.49 N 4963.68 W 5987000.01 N 613864.91 E 6482.36 N 5008.39 W 5987057.16 N 613819,28 E 6526.50 N 5042.50 W 5987100.75 N 613784.49 E 6540.24 N 5053.11 W 5987114.32 N 613773.66 E 6598.11 N 5097.82 W 5987171.48 N 613728.03 E 6649.55 N 5137.56 W 5987222.28 N 613687.48 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) 6823.43 6875.32 6948.45 7021.59 7094.72 7167.86 7240.99 7314.13 7387.26 7460.40 7533.54 7606.67 7679.81 7752.94 7826.08 7899.21 7972.35 8025.55 8045.48 8118.62 8191.75 8247.53 8264.89 8338.02 8403.02 Comment B WestSak/Base Schrader Obf Top Upper HRZ Top Trad HRZ BHRZ Continued... 14 August, 2000 - 14:45 - 6 - DrillQuest 1.05.058 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) 11300.00 47.000 322.310 6724.59 6790.29 11315.27 47.000 322.310 6735.00 6800.70 11325.53 47.000 322.310 6742.00 6807.70 11328.46 47.000 322.310 6744.00 6809.70 11335.53 47.000 322.310 6748.82 6814.52 11400.00 59.249 322.125 6787.43 6853.13 11500.00 78.248 321.913 6823.51 6889.21 11600.00 97.247 321.729 6827.43 6893.13 11600.31 97.305 321.728 6827.39 6893.09 11700.00 97.305 321.728 6814.71 6880.41 11800.00 97.305 321.728 6802.00 6867.70 11900.00 97.305 321.728 6789.28 6854.98 12000.00 97.305 321.728 6776.56 6842.26 12100.00 97.305 321.728 6763.85 6829.55 12170.65 97.305 321.728 6754.86 6820.56 12200.00 93.784 321.791 6752.03 6817.73 12234.91 89.595 321.865 6751.00 6816.70 12300.00 89.595 321.865 6751.46 6817.16 12400.00 89.595 321.865 6752.17 6817.87 12500.00 89.595 321.865 6752.87 6818.57 Proposal Report for S- 102 Wp 10 12600.00 89.595 321.865 6753.58 6819.28 12700.00 89.595 321.865 6754.29 6819.99 12800.00 89.595 321.865 6755.00 6820.70 12900.00 89.595 321.865 6755.70 6821.40 13000.00 89.595 321.865 6756.41 6822.11 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (fi) (fi) (fi) (fi) (~100ff) 6655.98 N 5142.54W 5987228~ 613682.40 E 0.000 6664.82 N 5149.37W 59872~~ 613675.43 E 0.000 6670.76N 5153.95W 598~.2~ 613670.75E 0.000 6672.46N 5155.27W ~4~.90N'~613669.41E 0.000 6676.55 N 5158.43W .~4 N ~ 613666.19 E 0.000 6717.22N 5189.97W~;'iii.!!,,:.'..,,,..~.. 59~2~9,.11N 613634.01E 19.000 6790.34 N 5247.07~:'ii,i;':".?'.i';'.'i'.::i~9~3~!i'.32 N 613575.75 E 19.000 6868.53N 530J~.55W".i!ii~'iii"::.,,,~(.:.]~'~4'38.52N 613513.03 E 19.000 6868.77 N ~_~J~W~5987438.75 N 613512.84 E 19.000 6946.40 N ~ ~?"5987515.40 N 613450.37 E 0.000 7024.27 N'::i;i:.i;'i:':':i:'i,:.;:...~;~. 543'~'~2 W 5987592.29 N 613387.70 E 0.000 7102..1.~!ii:~: ....... "i.;'i?'i!~92i:8'~ W5987669.17 N 613325.04 E 0.000 o.ooo 7257.88 N":J!ii=ii:"i::i::.; h,,... '::;:,!ii=5615.73 W 5987822.95 N 613199.71 E 0.000 7312.90 N '~"5659.14W 5987877.26 N 613155.44 E 0.000 7335.84 N 5677.22W 5987899.92 N 613137.00 E 12.000 7363.27 N 5698.78W 5987927.00 N 613115.00 E 12.000 7414.46 N 5738.97W 5987977.55 N 613074.00 E 0.000 7493.12 N 5800.72W 5988055.21N 613011.01E 0.000 7571.77 N 5862.47W 5988132.88 N 612948.02E 0.000 7650.42N 5924.22W 5988210.54 N 612885.03 E 0.000 7729.08 N 5985.97W 5988288.20 N 612822.04 E 0.000 7807.73N 6047.72W 5988365.87 N 612759.05 E 0.000 7886.39 N 6109.47W 5988443.53 N 612696.05 E 0.000 7965.04 N 6171.22W 598852~.19 N 612633.06 E 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~) 8411.16 8422.32 8429.83 8431.98 8437.14 8488.62 8581.39 8680.85 8681.16 8780.04 8879.22 8978.41 9077.59 9176.78 9246.85 9276.06 9310.95 9376.03 9476.03 9576.02 9676.02 9776.02 9876.01 9976.01 10076.00 Comment Top Kup/C4B 7" Casing Kup C4A Be~_ in Dir @ 19.000°/100ft: 11335.53ft MD, 6814.52ft TVD End Dir: 11600.31ft MD, 6893.09ft TVD Becl_ in Dir @ 12.000°/100ft: 12170.65ft MD, 6820.56ft TVD End Dir: 12234.91ft MD, 6816.70ft TVD Taraet - S-102 T2 8/9/00, Geological Continued... 14 August, 2000-14:45 - 7- Dr#/Quest 1.05.058 Sperry-Sun Drilling Services Proposal Report for $- 102 Wp 10 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 13100.00 89.595 321.865 6757.12 6822.82 13200.00 89.595 321.865 6757.82 6823.52 13300.00 89.595 321.865 6758.53 6824.23 13400.00 89.595 321.865 6759.24 6824.94 13500.00 89.595 321.865 6759.95 6825.65 13600.00 89.595 321.865 6760.65 6826.35 13700.00 89.595 321.865 6761.36 6827.06 13800.00 89.595 321.865 6762.07 6827.77 13900.00 89.595 321.865 6762.77 6828.47 13931.98 89.595 321.865 6763.00 6828.70 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (°/100ft) 8043.69 N 6232.97 W 5988598~ 612570.07 E 0.000 8122.35 N 6294.72 W 59886~. 612507.08 E 0.000 8201.00 N 6356.47 W 59.8~.18~ 612444.09 E 0.000 8279.65 N 6418.22 W ,~,9831~.85 N'~ 612381.10 E 0.000 8358.31 N 6479.97W ~8~1 N ~' 612318.11 E 0.000 ..... 8436.96 N 6541.72 W... 5988'9,.87.17 N 612255.12 E 0.000 8515.62 N 6603.47 W.:="ii~:i"i~i';..;....59890'6~84 N 612192.13 E 0.000 8594.27 N 6665.22 W!??;' .' ";: '}~9891,4~.50 N 612129.13 E 0.000 8672.92 N 6726~r97 W ',i'/: :.:'":'."::5989220.16 N 612066.14 E 0.000 8698.08 N .... .';6746'~;~ W "": ..... 5989245.00 N 612046.00 E 0.000 All data is in feet unless otherwise stated. Directions and coordinates":~.'~..rela{i'Ve to True North. Vertical depths are relative to S-102 WPS. Northings and Eastings are"¥~lativ.e'""{o s-102 wPs. Alaska State Plane 4 PBU_WOA S Pad Ve~ical Section (~) 10176.00 10275.99 10375.99 10475.99 10575.98 10675.98 10775.97 10875.97 10975.96 11007.94 Comment Total Deoth: 13931.98ft MD, 6828.70ft TVD 4 1/2" Liner Taraet - S-102 T3 8/9/00, Geological The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-102 WPS and calculated along an Azimuth of 322.201 o (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13931.98ft., The Bottom Hole Displacement is 11007.94ft., in the Direction of 322.201 o (True). Continued... 14 August, 2000 - 14:45 - 8 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for $- 102 Wp 10 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured S t a t i o n Depth TVD Northings (ft) (ft) (ft) 300.00 300.00 0.00 N 500.00 499.91 4.14 N 700.00 698.92 19.31 N 900.00 895.16 49.49 N 2100.00 1856.28 582.04 N 2200.00 1912.20 647.65 N 2355.55 1991.10 753.64 N 7674.16 4405.70 4503.67 N 8474.16 4863.07 5020.56 N 11335.53 6814.52 6676.55 N 11600.31 6893.09 6868.77 N 12170.65 6820.56 7312.90 N 12234.91 6816.70 7363.27 N 13931.98 6828.70 8698.08 N Coordinates Eastings (ft) 0.00 E 3.20 W 14.92 W 38.24 W 449.70 W 500.38 W 582.28 W 3479.62 W 3878.98 W 5158.43 W 5308.74 W 5659.14 W 5698.78 W 6746.72 W Comment Begin Dir @ 1.5°/100ft: 300.00ft MD?~O0~OOftT~ Increase in Dir Rate @ 2.500°/100ilf!::i;ii::50.0~0ft MD, 4~99.91ft TVD Increase in Dir Rate @ 3.000°/100ft~'~'00ft MD, 698.92ft TVD Increase in Dir Rate @ 3.5~{.1.(~0ft: 900~ft MD, 895.16ft TVD End Dir: 2100.00ft MD, 185~i:~i:.~VD Begin Dir @ 4.500~/j00ft' ~'~i~i00ft ~'g, 1912.20ft TVD End Dir' 2355.1 .10ft,.TVD Begin Dir @ MD, 4405.70ft TVD End Dir: 8474.11~t.ii~'~'' 486~:'.'07ft TVD Begin ~.~ii;?@ "'~l:..~i;q0O ./.~=.Q0ft: 11335.53ft MD, 6814.52ft TVD End D~r;i..'.;;.;,!:,..1600.3.1.it,~D, 6893.09ft TVD Begin d'i'r;:;ii~";..,12:~b/lOOft: 12170.65ft MD, 6820.56ft TVD End Dir: l~lft MD, 6816.70ft TVD Total Depth · 13931.98ft MD, 6828.70ft TVD Continued... 14 August, 2000 - 14:45 - 9- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S- 102 Wp 10 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 2116.84 1865.70 1800.00 3951.62 2715.70 2650.00 5052.96 3215.70 3150.00 5339.31 3345.70 3280.00 5779.85 3545.70 3480.00 8120.96 4638.70 4573.00 8492.68 4875.70 4810.00 8683.30 5005.70 4940.00 9129.05 5309.70 5244.00 10772.74 6430.70 6365.00 11076.26 6637.70 6572.00 11288.87 6782.70 6717.00 11315.27 6800.70 6735.00 11328.48 6809.70 6744.00 Northings Eastings Formation Name ~ (ft) (ft) ~~.~'~'~ 593.09 N 458.23 W B Perm ~ ~ -~- 1878.99 N 1 451.74 W SV3/T5 2655.52 N 2051.71 W SV1/T3 2657.42 N 2207.70 W UG4A/K15 (,F!?St,Coal) "",, ;: ',' .... 3168.03 N 2447.68 W UG4A/Top b'O~''.''I ',',?;!"", ........ "':,,"" 4804.93 N 3712.38 W UG 1/S'chrade?'~ ?'" ' '" 5031.28 N 3887.26 W W,,!,~'~i;~Vest"S!~Schrader NA 5141.59 N 3972.49 W "W"~,,,1,/,Sb~:i~ad~¥,,,0~'' 5399.57 N 4171.81~W ~?~ak/l~'~e Schrader Obf 4906.78 ,.z 6526.50 N 5042.50~ '~~ T~Frac~ HRZ 6649.55 N 5137.56 W ~Z 6664.82 N 5149.37 W '~op Kup/C4B 6672.46 N 5155.27 W Kup C4^ Continued... 14 August, 2000- 14:45 - 10- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S- 102 Wp 10 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> To Measured Depth (ft) 5152.96 11325.53 13931.98 Targets associated with this wellpath Target Name S-102 Polygon S-102 T1 8/9/00 Vertical Depth (ft) 3261.10 6807.70 6828.70 Casing Detail 10 3/4" Casing 7" Casing 4 1/2" Liner Mean Sea Level/Gj~al..C~dinates: G eog raphic'~ordinates: Target Boundary Point #1 #2 #4 Mean Sea Level/Global Coordinates #1 #2 #4 Geographical Coordinates #1 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 65.70 8972.66 N 6718.36 W 0.00 5989520.00 N 612070.00 E 70" 22' 49,1072" N 149° 05' 19.5564" W 65.70 8972.66 N 6718.36 W 65,70 7015.58 N 5217.24 W 65.70 6866.16 N 5443,64 W 65.70 8788.16 N 7003.32 W 0.00 5989520.00 N 612070.00 E 0.00 5987587,00 N 613602,00 E 0.00 5987434.00 N 613378.00 E 0.00 5989331.00 N 611788.00 E 70° 22' 49.1072" N 149° 05' 19.5564" W 70° 22' 29.8697" N 149° 04' 35,5788" W 70° 22' 28.3984" N 149° 04' 42,2007" W 70° 22' 47.2899" N 149° 05' 27,8923" W 6807.70 6677.62 N 5159.60 W 6742.00 5987250.00 N 613665.00 E 70" 22' 26,5460" N 149° 04' 33.8853" W Target Target Shape Type Polygon Geological · ._ ~..:.;~ .~. ,:.,~.- : ...... z;-'--,.'. '.,:~"'~' ~; . :' ~. · ;.: .-~ .; ~ - .~ ~ -. ~11;~ ~'" r-~,'~ . ., , . . . . l-~.~i.-~,-.,~.~.~ Point Geologic~ 14 August, 2000- 14:45 - 11 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for $- 102 Wp 10 North Slope Alaska Target Name S-102 T2 8/9/00 S-102 T3 8/9/00 S-102 Wp01 T1 S-102 Wp01 T2 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: G~ographical Coordinates: ~,, ~:' ;'i':.ii i,.::" :i.i !.::;I .6762.'701:i'"" Mean Sea Level/Global Coordinates:"=;:'i~i::!':,' "':'""6~97':00''' G~graphical Coordinates: ..... i.'.??' ..?[i :i;!';,:!:; ' :'.,..,~0779 70 Mean Sea Lovel/Globa[C'~id~tes:':I:L~ 6714.00 ,, ~'"~'~ ,,: :1~",: ;,,~"i~,,,,, ',,:i,,~;,,,~'',',',!,,,,,, Geogr.aPh,cal::~rdmates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6816.70 ~ 7363,27 N 5698.78W 6751.00~ 5987927.00 N 613115.00 E 2' 33.2860" N 149° 04' 49.6776" W 6~0 ~. ~ 8698.08 N 6746.72 W ~j~3.~ ~989245.00 N 612046.00 E ~ 70° 22' 46.4062" N 149° 05' 20.3794"W 7363.27 N 5698.78 W 5987927.00 N 613115.00 E 70° 22' 33.2860" N 149° 04' 49,6776" W 8698.08 N 6746.72 W 5989245.00 N 612046,00 E 70° 22' 46.4082" N 149° 05' 20.3794" W Alaska State Plane 4 PBU_WOA S Pad Target Target Shape Type Point Geological Point Geological Point Geological Point Geological 14 August, 2000- 14:45 - 12- DrillQuest 1.05.05a H 1 72569 DATE ! CHECK NO. ~0:!.72569 VENOOR AL/~ .~KASTAT 10 DATE INVOICE'/CREDIT MEMO DESCRIPTION G~ DISCOUNT NET __ ,, )1~0200 :KOSO200M 100. O0 100. O0 HANDLTI4(~ I'NST: TERR [E X462B CHECK I$ II PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 100. OO 1 OO. OO AI'TA~HED , . ,~..O0'i:::;:',;:i~.~IRCUP 1' N~'::i":':.!fiR i;'V~i:i:::'' :,: ~.? ANCHORAOE AK 99501 .. . . ': :.': ........ ':" .I~.',,I:.ION~.I;.:'.~ITY:B'.~K "ii'.J:: ::':': ~: 'i:.::"::'..:...:.;!' . ~.CEVELAND, O'Hio '..'.':'m .:''m :: mlm: m .' '!:i::i.i:::ii:' ';:..:iiii;;:~ga~C.'~?'.?i'', ~.?,.:?, 4'1~ , ,.,..'., . . , :.,.j~i.. ',:~. ,.,, ,:, ,., ." .. .. ?.:"."~' DATE :;,:::.i!!::?!' S::}':~:'~.?!)?"::' :~"'.?: i..fi:j~i!:}}~OUNT ': '.'. ~ I $too. oo ].'. ,,. WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ 4;/'~/'~.~ INIT CLASS WELL NAME ~. -//'~Z.PROGRAM: exp, dev / ~::::~ i/ /D/f-..--' GEOL AREA ,~IC:)/~ -- ADMINISTRATION 1. Permit fee attached. 2. Lease number appro~ri~t' .~i ~ ~-~/~"~".~. ~.; ~t~. ~ .~./ 3. Unique well name and.number..~,,_.,~: .............. 4. Well located in a defined poo~ .............. 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 ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14; 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. DATE 26. ~'~3~? 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to fie-in long string to surf csg ..... . .... CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... ' Adequate wellbore separation proposed ............. If diverter required, does it meet regulations ........ '.. Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet'.regulafion ................ BOPE press rating appropriate; test to , 3~'Ot;~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. redrll . serv wellbore seg ann. disposal para req. UNIT# ,/"~//~ ~-~) ON/OFF SHORE GEOLOGY 30. " 31. '32. Permit can be issued wlo.hydrogen sulfide measures ..... '. Y~.~_ ~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones .......... '."'..j~/Y N Seabed condition survey (if.off-shore) .......... .~,~'. Y N Contact name/phone for weekly progress reports [exl31~ratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y 'N APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N ' to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and .. (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC, LAnnular COMMISSION: Comments/Instructions: Z -4 c:~nsoffice\wordian~iana~checklist (rev. 02/17100) ,,. ) 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 sim.plify finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Nov 14 09:36:06 2000 Reel Header Service name ............. LISTPE Date ..................... 00/11/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/11/14 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'.. JOB NUMBER.: LOGGING'ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-00184 S. HUIBAN W. STAFFORD JOB NUMBER: ,LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION .SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION'(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 4 AK-MM-00184 S.HUIBAN S.LEWIS ., S-102 500292297200, . . BP Exploration (Alaska) Inc. Sperry Sun ' ' 1.3'NOV- 00 ' ,', MWD RUN' 2 AK-MM-00184 S.,'HUIBAN. W.,STAFFORD . MWD'RUN 3 AK-MM-00184 J~. SACK D. FERGUSON J. SACK G. KIDD 35 12N 12E 4452 4499 .00 28.52 GROUND LEVEL: WELL CASING RECORD 35.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 13.500 10.750 4817.0 9.875 7.000 11717.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 3 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP - RECORDED MODE), AND STABILIZED LITHO- .DENSITY (SLD - RECORDED MODE). THIS TOOL STRING IS LOST IN HOLE. ONLY REALTIME DATA IS PRESENTED. 3. MWD RUN 4 IS DIRECTIONAL WITH DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THIS RUN KICKS OFF FROM S-102 PB1 AT 8017'MD, 6765'TVD. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO- DENSITY (SLD). 5. DEPTH SHIFTING/CORRECTION IS WAIVED PER THE PHONE CONVERSATION BETWEEN J. COPEN OF BP EXPLORATION (ALASKA), INC. AND R KALISH OF SPERRY-SUN DRILLING SERVICES ON 11/09/00. 6. MWD RUNS 1-5 REPRESENT WELL S-102 WITH APIg: 50-029-22972-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13488'MD, 6787'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 RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.00" MUD WEIGHT: 10.3 - 10.6 PPG MUD SALINITY: 166000 PPM CHLORIDES FORMATION WATER SALINITY: 50000 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 ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP RPX RPD FET RPX RPM NPHI FCNT PEF NCNT DRHO RHOB $ START DEPTH 818.5 874.0 4807.0 4807.0 4807.0 8017.5 8017 5 11707 0 11707 0 11707 0 11707 0 11717 0 11717 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE STOP DEPTH 13405.0 13488.0 13412.5 13412.5 13412.5 13412.5 13412 5 13376 5 13376 5 13392 5 13376 5 13392 5 13392.5 EQUIVALENT UNSHIFTED DEPTH PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 818.5 MWD 2 2771.0 MWD 3 4833.0 MWD 4 8017.0 MWD 5 11727.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 2771.0 4833.0 8017.0 11727.0 13488.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD A?I 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU- 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 I ' 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 818.5 13488 ROP MWD FT/H 0 371 GR MWD API 7.64 417.62 RPX MWD OHMM 0.05 251.05 RPS MWD OHMM 0.06 2000 RPM MWD OHMM 0.64 2000 RPD MWD OHMM 0.1 2000 FET MWD HOUR 0.37 269.98 NPHI MWD ?U- 15.22 46.28 FCNT MWD CNTS 121.1 985.4 NCNT MWD CNTS 11667.8 35111.4 RHOB MWD G/CM 1.478 3.006 DRHO MWD G/CM -0.27 0.49 PEF MWD BARN 1.64 12.85 Mean Nsam 7153.25 25340 96.0696 25229 83.449 25174 5.20533 10749 10.7766 17170 10.6 10749 16.5014 17170 2.1069 17170 26.0131 334,0 492.118 3340 25228.9 3340 2.37669 3352 0.0374934 3352 2.37212 3372 First Reading 818.5 874 818.5 8017.5 4807 8017.5 4807 4807 11707 11707 11707 11717 11717 11707 Last Reading 13488 13488 13405 13412.5 13412.5 13412.5 13412.5 13412.5 13376.5 13376.5 13376.5 13392.5 13392.5 13392.5 First Reading For Entire File .......... 818.5 Last Reading For Entire File ........... 13488 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 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 ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 818.5 2714.5 ROP 874.0 2771.0 $ # LOG HEADER DATA DATE LOGGED: 18-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 2771.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ~0 MAXIMUM ANGLE: 62.7 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): TOOL NUMBER PB01530CGV8 13.500 SPUD 9.20 240.0 9.5 8OO 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined' Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 13.2 .000 .000 .000 .000 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 .0 76.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 818.5 2771 1794.75 3906 ROP MWD010 FT/H 2.3 245 76.2598 3795 GR MWD010 API 22.82 117.32 63.2251 3793 First Reading 818.5 874 818.5 Last Reading 2771 2771 2714.5 First Reading For Entire File .......... 818.5 Last Reading For Entire File ........... 2771 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 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 ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2716.0 ROP 2771.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO 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): STOP DEPTH 4777.0 4833.0 19-SEP-00 Insite 5.46 MEMORY 4833.0 62.0 96.1 TOOL NUMBER ?B01530CGV8 13.500 SPUD 9.50 160.0 9.2 8OO 5.6 .000 .000 .000 .000 .0 80.0 .0 .0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ...................... 60 .liN 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 DE?T FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT. FT 2716 4833 3774.5 4235 ROP MWD020 FT/H 6.9 281.6 127.957 4124 GR MWD020 API 30.3 118.28 72.7637 4123 First Reading 2716 2771.5 2716 Last Reading 4833 4833 4777 First Reading For Entire File .......... 2716 Last Reading For Entire File ........... 4833 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 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 ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4777.5 8017.0 RPS 4807.0 8017.0 RPD 4807.0 8017.0 FET 4807.0 8017.0 ROP 4833.5 8017.0 $ 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 EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 25-SEP-00 Insite 65.41 Real-Time 8017.0 62.6 66.8 TOOL NUMBER PB1680HGR66 PB1680HGR66 PB1680HGR66 PB1680HGR66 9.875 4817.0 LSND 10.50 52.0 8.9 6OO 3.6 2.200 1.345 1.700 3.400 64.0 109.0 60.0 68.0 Frame Spacing ..................... 60 .liN 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 MWD030 FT/H 4 1 68 4 2 RPS MWD030 OHMM 4 1 68 8 3 RPD MWD030 OHMM 4 1 68 12 4 FET MWD030 HOUR 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 Name Service Unit Min Max Mean Nsam DEPT FT 4777.5 8017 6397.25 6480 ROP MWD030 FT/H 0 371 137.75 6368 RPS MWD030 OHMM 0.1 2000 17.4715 6421 RPD MWD030 OHMM 0.1 2000 28.399 6421 FET MWD030 HOUR 0.42 84.63 1.86805 6421 GR MWD030 API 7.64 118.43 65.4156 6480 First Reading 4777.5 4833.5 4807 4807 4807 4777.5 Last Reading 8017 8017 8017 8017 8017 8017 First Reading For Entire File ' 4777.5 Last Reading For Entire File ........... 8017 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ........ 00/11/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8017.5 11727.0 FET 8017.5 11685.5 RPD 8017.5 RPM 8017.5 RPS 8017.5 RPX 8017.5 GR 8017.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11685.5 11685.5 11685.5 11685.5 11677.0 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 10-OCT-00 Insite 65.41 MEMORY 11727.0 52.0 73.3 TOOL,NUMBER PB01680HRG6 PB01680HRG6 9.875 4817.0 LSND 11.40 38.0 8.6 700 3.2 2.400 1.269 1.350 1.800 65.0 129.0 65.0 64.0 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit Min DEPT FT 8017.5 ROP MWD040 FT/H 4.3 GR MWD040 API 16.41 RPX MWD040 OHMM 1.2 RPS MWD040 OHMM 1.16 R?M MWD040 OHMM 1.11 RPD MWD040 OHMM 1.12 FET MWD040 HOUR 0.37 Max 11727 241.1 417 62 28 45 29 94 33 57 3O 07 269 98 Mean Nsam 9872.25 7420 74.8213 7420' 107.611 7320 3.86432 7337 4.0156 7337 4.21826 7337 4.31453 7337 1.3267 7337 First Reading 8017.5 8017.5 8017.5 8017.5 8017.5 8017.5 8017.5 8017.5 Last Reading 11727 11727 11677 11685.5 11685.5 11685.5 11685.5 11685.5 First Reading For Entire File .......... 8017.5 Last Reading For Entire File ........... 11727 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11677.5 13405.0 RPS 11707.0 13412.5 RPX 11707.0 13412.5 RPM 11707.0 13412.5 FET 11707.0 13412.5 NPHI 11707.0 13376.5 FCNT 11707.0 13376.5 FCNT 11707.0 13376.5 PEF 11707.0 13392.5 RPX 11707.0 13412.5 RHOB 11717.0 13392.5 DRHO 11717.0 13392.5 ROP 11727 . 5 13488 . 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 EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD 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: $ 18-OCT-00 Insite 65.44 MEMORY 13488.0 73.3 93.4 TOOL NUMBER PB01692H4 PB01692H4 PB01692H4 PB01692H4 6.000 11717.0 BaraDrill-N 10.40 50.0 8.6 165000 3.2 .060 .036 .060 .060 75.0 129.6 75.0 75.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 N?HI MWD050 PU-S 4 1 68 FCNT MWD050 CNTS 4 1 68 NCNT MWD050 CNTS 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 1 68 ?EF MWD050 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 11677.5 13488 ROP MWD050 FT/H 0 205.7 GR MWD050 API 36.13 354.1 RPX MWD050 OHMM 0.05 251.05 RPS MWD050 OHMM 0.06 1363.3 RPM MWD050 OHMM 0.64 2000 RPD MWD050 OHMM 3.07 1983.58 FET MWD050 HOUR 0.96 118.06 NPHI MWD050 PU-S 15.22 46.28 FCNT MWD050 CNTS 121.1 985.4 NCNT MWD050 CNTS 11667.8 35111.4 RHOB MWD050 G/CM 1.478 3.006 DRHO MWD050 G/CM -0.27 0.49 PEF, MWD050 BARN 1.64 12.85 Mean 12582.8 49.4811 101.027 8.08897 12.7163 24.3229 20.3176 4.23411 26.0131 492.118 25228.9 2.37669 0.0374934 2.37212' Nsam 3622 3522 3456 3412 3412 3412 3412 3412 3340 3340 3340 3352 3352, 3372 First Reading 11677.5 11727.5 11677.5 11707 11707 11707 11707 11707 11707 11707 11707 11717 11717 11707 Last Reading 13488 13488 13405 13412.5 13412.5 13412.5 13412.5 13412.5 13376.5 13376.5 13376.5 13392.5 13392.5 13392.5 First Reading For Entire File ..... ~ .... 11677.5 Last Reading For Entire File ........... 13488 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/11/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/11/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Jan 04 10:48:34 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/04 Origin ................... STS Reel Name ................ UNKI~OWN, Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/01/04 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: OPER3ITOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-00184 S. HUIBAN W. STAFFORD S-102 PB1 500292297270 BP Exploration (Alaska) Inc. Sperry Sun 03-JAN-01 MWD RUN '2 AK-MM-00184 S. HUIBAN W. STAFFORD MWD RUN 3 AK-MM-00184 J. SACK D. FERGUSON 35 12N 12E 4452 4499 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 64.20 35.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 80.0 13.500 9.875 10.750 4817.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 3 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP - RECORDED MODE), AND STABILIZED LITHO- DENSITY (SLD - RECORDED MODE). THIS TOOL STRING IS LOST IN HOLE. ONLY REAL TIME DGR-EWR4 DATA IS PRESENTED. WELL S-102 KICKS OFF FROM THIS WELLBORE AT 8017'MD, 4655'TVD. 5. DEPTH SHIFTING/CORRECTION IS WAIVED PER THE PHONE CONVERSATION BETWEEN J. COPEN OF BP EXPLORATION (ALASKA), 'INC. AND R KALISH OF SPERRY-SUN DRILLING SERVICES ON 11/o9/oo. 6. MWD RUNS 1-3 REPRESENT WELL S-102 PB1 WITH API#: 50-029-22972-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8688'MD, 4936'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 RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 818.5 8635.0 ROP 874.0 8687.5 RPS 4807.0 8614.5 RPD 4807.0 8614.5 FET 4807.0 8614.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 818.5 2771.0 2 2771.0 4833.0 3 4833.0 8687.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 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 GR MWD API 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 4 8 12 16 20 Name Service Unit Min Max DEPT FT 818.5 8687.5 ROP MWD FT/H 0 371 GR MWD API 7.64 118.43 RPS MWD OHMM 0.1 2000 RPD MWD OHMM 0.1 2000 FET MWD HOUR 0.42 84.63 Mean Nsam 4753 15739 118.415 15628 65.2145 15634 15.1376 7616 24.3688 7616 1.75024 7616 First Reading 818.5 874 818.5 4807 4807 4807 Last Reading 8687.5 8687.5 8635 8614.5 8614.5 8614.5 First Reading For Entire File .......... 818.5 Last Reading For Entire File ........... 8687.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/04 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..., .... 01/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 818.5 ROP 874.0 $ STOP DEPTH 2714.5 2771.0 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ............ Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 18-SEP-00 Insite 5.46 Memory 2771.0 .0 62.7 TOOL NUMBER PB01530CGV8 13.500 80.0 SPUD 9.20 240.0 9.5 800 13.2 .000 .000 .000 .000 .0 76.5 .0 .0 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 818.5 2771 1794.75 3906 ROP MWD010 FT/H 2.3 245 76.2598 3795 GR MWD010 API 22.82 117.32 63.2251 3793 First Reading 818.5 874 818.5 Last Reading 2771 2771 2714.5 First Reading For Entire File .......... 818.5 Last Reading For Entire File ........... 2771 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/04 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 ....... 01/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2716.0 4777.0 ROP 2771.5 4833.0 $ 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ...................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... 19-SEP-00 Insite 5.46 Memory 4833.0 62.0 96.1 TOOL NUMBER PB01530CGV8 13.500 80.0 SPUD 9.50 160.0 9.2 8OO 5~6 .000 .000 .000 .000 .0 80.0 .0 .0 Datum Specification Block sub-type...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 Name Service Unit Min Max Mean Nsam DEPT FT 2716 4833 3774.5 4235 ROP MWD020 FT/H 6.9 281.6 127.957 4124 GR MWD020 API 30.3 118.28 72.7637 4123 First Reading 2716 2771.5 2716 Last Reading 4833 4833 4777 First Reading For Entire File .......... 2716 Last Reading For Entire File ........... 4833 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/04 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 ........ 01/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB,003 Comment Record FILE HEADER FILE NUMBER: 4 R3%W MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4777.5 RPS 4807.0 RPD 4807.0 FET 4807.0 ROP 4833.5 STOP DEPTH 8635.0 8614.5 8614.5 8614.5 8687.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CNP COMPENSATED NEUTRON $ 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 .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet 25-SEP-00 Insite 65.41 Real-Time 8688.0 62.6 66.8 TOOL NUMBER PB1680HGR66 PB1680HGR66 PB1680HGR66 PB1680HGR66 9.875 4817.0 LSND 10.50 52.0 8.9 600 3.6 2.200 1.345 1.700 3.400 64.0 109.0 60.0 68.0 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPS MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 Name Service Unit Min Max DEPT FT 4777.5 8687.5 ROP MWD030 FT/H 0 371 GR MWD030 API 7.64 118.43 RPS MWD030 OHMM 0.1 2000 RPD MWD030 OHMM 0.1 2000 FET MWD030 HOUR 0.42 84.63 First Last Mean Nsam Reading Reading 6732.5 7821 4777.5 8687.5 134.063 7709 4833.5 8687.5 62.1529 7716 4777.5 8635 15.1376 7616 4807 8614.5 24.3688 7616 4807 8614.5 1.75024 7616 4807 8614.5 First Reading For Entire File .......... 4777.5 Last Reading For Entire File ........... 8687.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/01/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/01/04 Origin ................... STS Scientific Technical Services 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
