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207-097
By James Brooks at 7:59 am, Feb 07, 2025 Abandoned 1/13/2025 JSB RBDMS JSB 021425 xG DSR-4/7/25JJL 6/3/25 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.02.06 16:22:28 - 09'00' Sean McLaughlin (4311) ACTIVITYDATE SUMMARY 9/22/2024 MI SU ***Job Continued 9-23-24*** 9/22/2024 ***WELL S/I ON ARRIVAL*** (Ctd). RU POLLARD UNIT #60 ***CONTINUED ON 9/23/24 WSR*** 9/23/2024 ***Job Continued from 9-22-23*** T/I/O=980/148/0 ( CTD ) Assist Slickline. Pumped 220 bbls 125* SW down TBG. Pumped 38 bbls DSL down TBG for Freeze Protect. Pumped 1 bbl of DSL to bring TBG to 1300 psi to test plug. MIT-T **PASSED** Max:3300 psi / Target: 2970 psi. Pumped 1.5 bblsof DSL down TBG to reach max pressure of 3324 psi. After first 15 min TBG lost 60 psi. After second 15 min TBG lost 25 psi. Bled back 1.5 bbls. CMIT-TxIA **PASSED** Max: 4100 psi / Target: 3870 psi. Pumped 7.6 bbls of DSL down TBG & IA to reach max pressure of TBG: 4102 psi & IA: 4106 psi.After first 15 min TBG lost 43 psi & IA lost 40 psi. After second 15 min TBG lost 21 psi & IA lost 21 psi. After third 15 min TBG lost 18 psi & IA lost 17 psi. Bled back 6.8 bbls. Well left in slicklines control. Pad Op notified upon departure. FWHP = 1500/170/0 9/23/2024 ***CONTINUED FROM 9/22/24 WSR*** (Ctd) DRIFT w/ 20'x3.70" DUMMY WHIPSTOCK DRIFT TO 11,553' SLM (11,556' MD) LRS LOADED TBG w/ 220BBLS SEAWATER, 38BBL DIESEL FP. SET 3.81" PX PLUG BODY, 1.75" P PRONG @ 11,317' MD LRS CONDUCTED PASSING MIT-T, AND CMIT-TxIA PULLED 3.81" PX PLUG BODY AND PRONG FROM 11,317' MD *** WELL S/I ON DEPARTURE *** 10/20/2024 ***WELL S/I ON ARRIVAL*** (MILL / WHIPSTOCK SET) MIRU HALLIBURTON ELINE PT PCE 300PSI LOW 3000PSI HIGH MILL XN @ 11,338' TO 3.800" WITH WELLTEC MILL AND DRIFT THROUGH. CONFIRM 3.800" OD ON SURFACE. CORRELATE TO SLB CBL DATED 01-NOV-07 SET BAKER 4.5"X7" WHIPSTOCK WITH TOW @ 11504' (340 DEG ROHS). TAG AFTER SET. RDMO HALLIBURTON E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE 12/21/2024 RU target 90 to flow cross, RU 4x7 XO to SV, Torqued to spec, PT'd against SV 350/5000 (PASS), PT'd aginst SSV 350/5000 (PASS). 1/7/2025 T/I/O = SSV/60/VAC. Temp = SI. WHPs/IA FL (Ops request). CDR tree installed. Well house removed, flowline disconnected & scaffold removed. IA FL @ 40' ( 1 bbl ). SV, WV, SSV, MV = C. IA, OA = OTG. 14:00 Daily Report of Well Operations PBU S-126 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UN AURO S-126 JBR 03/13/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 R2 and B2 both serviced and passed retest. Precharge Bottles = 10@1000psi, 3@1025psi and 3@1050psi. Test Results TEST DATA Rig Rep:N. Wheeler / E. GregoryOperator:Hilcorp North Slope, LLC Operator Rep:R. Burnett / D. Scarpella Rig Owner/Rig No.:Nabors CDR2AC PTD#:2070970 DATE:1/11/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB250112064412 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 2700 Sundry No: 324-320 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 7 1/16"P #1 Rams 1 blind/shear P #2 Rams 1 2 3/8"P #3 Rams 1 3"P #4 Rams 1 2 3/8"P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"P Kill Line Valves 2 2 1/16"FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P2040 200 PSI Attained P20 Full Pressure Attained P64 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P10@2035 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P3 #1 Rams P3 #2 Rams P2 #3 Rams P2 #4 Rams P2 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 R2 and B2 both serviced and passed retest Kill Line Valves 2 FP Drilling Manager 05/30/24 Monty M Myers By Grace Christianson at 1:02 pm, May 30, 2024 DSR-5/30/24SFD 5/31/2024 10-407 324-320 * BOPE test to 3500 psi. Annular to 2500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner on upcoming sidetrack. * Separate 10-403 required for hydraulic fracturing. MGR12AUG24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.27 17:23:31 -08'00'08/27/24 RBDMS JSB 082824 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 30, 2024 Re: PBU S-126 Sundry Request Sundry approval is requested to set a whipstock and mill the window in PBU S-126, as part of the pre-rig for drilling and completing of the proposed PBU S-126A CTD lateral. Proposed plan for PBU S-126A Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. E-line will set a 4- 1/2"x7" whipstock. Coil will mill the XN nipple and window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See S-126A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x7" whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Kuparuk C and land in the Kuparuk B. The lateral will continue into the adjacent fault block to the west then turn to the south and drill into the southern fault block to find the oil/water contact. The rig will then set a billet and drill a sidetrack (revised S-126A plan will be submitted after rig up) targting the Kuparuk C sands across the two fault blocks which will then be completed with a 3-1/2"x3-1/4"x2-7/8” L80 solid liner, cemented in place to top of liner. The well will have a post rig single stage toe frac with 30' of post rig perforations (to be performed under separate sundry). Future add perfs and surveillance will help us understand frac growth in the C2 interval. This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging the existing Kuparuk 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)). Pre-Rig Work - (Estimated to start July 2024): 1. Slickline: Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 2. Fullbore: MIT a. MIT-IA to 3,000 psi 3. E-line: Set 4-1/2”x7” whipstock a. Top of whipstock at 11,504’ MD (5’ from top of whipstock = pinch point) b. Top of window at 11,509’ MD c. Oriented 340° ROHS 4. Service Coil: Mill Window (mill with rig if needed) a. Mill XN nipple at 11,338’ MD to 3.80” b. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,700 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 7” liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU S-126A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,700psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Set Billet, Sidetrack and Drill Revised A lateral 5. Run and Cement Liner* 6. Perforate (only if not done post-rig) 7. Freeze Protect and RDMO Post Rig: 8. Set LTP* (if needed) and perforate 30’ post rig 9. Single stage frac (separate sundry) * Approved alternate plug placement per 20 AAC 25.112(i) PTD 224-084 Sundry 324-320 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x S Pad is an H2S pad. No H2S readings on PBU S-126 being an injector. x Max H2S recorded on S Pad: 500 ppm (S-201 in 2005). Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,374 psi at 6,700 TVDSS. (9.7 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,700 psi (from estimated reservoir pressure). x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 9.7 ppg equivalent S Pad is an H2S pad. Coiled Tubing BOPs 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 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Planned PB1 - 14,802' MD Planned billet at 12,910' MD Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-126 (PTD #2070970) will lapse on AOGCC MIT-IA Date:Tuesday, June 18, 2024 8:12:21 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, June 15, 2024 9:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-126 (PTD #2070970) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-126 (PTD # 2070970) is due for its 4-year AOGCC MIT-IA in June 2024. The well is currently shut-in and there are no plans to bring it online before the end of June 2024. It will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-126 207097 500292336300 3 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 MEMORANDUM TO: Jim Regg j P.I. Supervisor 1111 FROM: Bob Noble Petroleum Iaspector ("Inkezo NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. S-126 PRUDHOE BAY UN AURO S-126 See: Inspector Reviewed By: P.L Supry zz— Comm Well Name PRUDHOE BAY UN AURO S-126 API Well Number 50-029-23363-00-00 Inspector Name: Bob Noble Permit Number: 207-097-0 Inspection Date: 6/62020 InSp Num: mitRCN200606170803 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I S-126 ' Type Ini I w ' TVD 6544 - Tnbing 1769 - 176& 1768 1767 ' PTD 1 2070970 Type Test SPT Test pst 1636 - IA 325 2705 ' 2653 2646 ' BBL Pumped: 27 BBLReturned: 2.7 • OA 31 60 63' 65 Interval 4YRTST p/F P Notes: Monday, June 15, 2020 Page 1 of 1 207097 by Date: 811/7/2019 3 1 3 ? 3 Transmittal Number: S-126 Gyro BPXA WELL DATA TRANSMITTAL Enclosed is a disc containing the information listed below. If you have any questions please contact Joe Lastufka +907-564-4091 Joseph. LastufkaCa bp.com SW Name API I Date Comr)anvi Description Disk Number S-126 500292336300 10/21/2007 BPXA rOMPOSITED GYROSCOPIC SURVEY 1 Please Sign yid Email a copy of this transmittal to. Joseph.Lastufka(i ,bp.co Thank you, Joe Lastufka AOGCC *oV 0/ Za19 #100cc 1 Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 41) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg P.I.Supervisor /c r SUBJECT: Mechanical Integrity Tests /( 1 BP EXPLORATION(ALASKA)INC. S-126 FROM: Jeff Jones PRUDHOE BAY UN AURO S-126 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tar-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-126 API Well Number 50-029-23363-00-00 Inspector Name: Jeff Jones Permit Number: 207-097-0 Inspection Date: 6/4/2016 Insp Num: mitJJ160608085335 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-126 - Type Inj W TVD 6544 , Tubing j 1967 - 1967 1964 _j 1966 • PTD 2070970 Type Test SPT Test psi 1636 IA I 267 2749 2719 _ 2713 _ Interval 4YRTST P/F P OA 22 174 - 169 , 165 • Notes: 1 well inspected,no exceptions noted. SCANNED DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the tile. ~~ 7- ~ ~~ Well History File Identifier Qrganizing (done) ^ Two-sided III IIIII II III II III ^ Rescan Needed III IIIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~lor Items: ~kettes, No. ~ ^ Maps: ^ Greyscale Items: Other, No/Type: ~i~ ~a ~ ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ Protect Proofing UI 111111 IIIII II III BY: Maria Date: ` /s/ Scanning Preparation y'` x 30 = + ~~~ =TOTAL PAGES (Count does not include cover sheet) n~ BY: _ Maria Date: ~ ~' (~. n ~ /s/ ~/ V li Production Scanning Stage 1 Page Count from Scanned File: yL~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~S NO BY: Maria Date: 1 ~~' 1 ©p /s/ . p Stage 1 If NO In stage 1, page(s) dlscrepancles were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III IIlI II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II'I III P 10/6/2005 Well History File Cover Page.doc i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 2C DATE: Tuesday, June 26, 2012 TO: Jim Regg P.I. Supervisor '(( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -126 FROM: Lou Grimaldi PRUDHOE BAY UN AURO S -126 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S - 126 API Well Number 50 029 - 23363 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 207 - 097 - Inspection Date: 6/8/2012 Insp Num: mitLG120608123213 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S -126 - Type Inj W, TVD 6544 - IA 611 2730 , 2700 2690 PTD 2070970 - Type Test SPT Test psi i 1636 OA 72 . 228 230 227 - Interval 4YRTST - P/F P Tubing 2016 - 2010 2000 1987 - Notes: 2 . 2 bbl's pumped, 2.0 Returned. Good stable test. JUL 3 r/ U I Z Tuesday, June 26, 2012 Page 1 of 1 ~ °, , _' § `~ ,~ ~" Sh 4 r ~ ~ ^~ .~~~ +v ~ ~J,.- MICROFILMED 6/3.0/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • b~ BP Exploration (Alaska) Inc. • Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ .`'~'~~' ~~l;L ~~ ~~ ~Dt~~ .~.~~ ~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Spad ~. il~ nate Well Name PTD # Initial top of cemen[ Vol. of cement um d Final rop of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al S-01B 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951690 0 NA 0 NA 0.9 5/26l2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-116 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA t.7 6/1/2009 S-13 1621350 8 NA 9 NA 55.3 6/1/2009 5-15 1840170 025 R1A 025 NA 3 6/2/2009 S-17C 2020070 025 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1867160 0.75 NA 0.75 NA 22 5/19/2009 S-2DA 2010450 025 NA 025 NA 1.3 5/19/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5l25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 0.25 fVA 0.25 NA 7.7 5/25/2009 S-2a8 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982740 0.5 NA 0.5 NA 2.s 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/37I2009 S-29A1t 1960720 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 fJA 5.7 5l31l2009 S37A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31I2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5J26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 5-35 192/480 0 NA 0 NA .BSin 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 S37 1920990 1.25 NA 125 NA 17.9 5/27/2009 S-38 1921270 025 NA 025 NA 70.2 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 0.25 NA 025 NA 1.~ 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29l2009 5-102L1 2031560 125 NA 125 NA 11.1 5/31/2009 5-103 2001660 1.5 NA 1.5 NA 71.9 5/16/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 327 5/20I2009 5-106 2010120 1625 NA 76.25 NA 1~4.3 6/2/2009 5-707 20}t130 225 NA 225 NA 28.9 5/18/2009 5-~08 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-io9 2022450 2 NA 2 NA 21.3 5/30/2009 S-170 2071290 17.75 NA 11.75 NA ee.6 5/30l2009 S-y t t 2050510 2 NA 2 NA 19.6 5/30/'2009 S-1t2 2021350 0 NA 0 NA 0.5 5/30/2009 S-Y73 2021430 1J5 NA 1J5 NA 22.t 5/18I2009 5-114A 2021980 125 NA 125 NA 702 5/30/2009 S-~t5 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 S-Y 16 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-717 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-778 2032000 5 NA 5 NA 76.5 5/28I2009 S-7i9 2041620 1 NA t NA 5.2 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060470 4.5 NA 4.5 NA 53.6 5/29/2009 S-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 7.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1 JS NA 17.9 5/26l2009 5-125 2070830 2.25 NA 2.25 NA 20.4 5/28/2009 ( S-t26 . 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 1.25 NA 125 NA 14.5 5/28/2009 S-2o1 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S•277 2070950 0.25 NA 025 NA 7.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S,401 2060780 16 NA 16 NA s9.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28l2009 fi/25/2009 r~ L ~~~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070970 Well Name/No. PRUDHOE BAY UN AURO S-126 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23363-00-00 MD 11910 TVD 7076 REQUIRED INFORMATION Mud Log No Samples No Directional Surve DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, DEN, NEU, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D D Asc Directional Survey 0 11910 Open 11/7/2007 Directional Survey 0 11910 Open 11/7/2007 I, Log See Notes 5 Col 1 0 11800 Open 11/9/2007 I Isolation Scanner, PDC Log, IBC, CBL, GPIT, GR, C Exc Directional Surve 0 723 C ~ 11/9/2007 CCL 1-Nov-2007 R i ll i D y c S un Ins pe de ri P ~Rp Directional Survey 0 723 et / ~ - Cie 11/9/2007 Run Inside Drill Pie ~~, P ' D C Lis 15795 Sonic 148 11712 Case 12/21/2007 LIS Veri, USIT, CCL w/PDS and TIF graphics ~D C Lis ~ ~ Induction/Resistivity 54 11911 eta 12/21/2007 LIS Veri, GR, ROP, FET, /~q4 RPM, DRHO, NPHI, w/PDS and TIF graphics (Cog Induction/Resistivity 25 Blu 54 11910 t:e~e 12/21/2007 MD Vision Service 28-Oct- 2007 ~,j/~og Induction/Resistivity 25 Blu 54 11910 rpvv~ ~:~51s 12/21/2007 TVD Vision Service 28-Oct- 2007 ~ See Notes D ~~i~"~` ~ 5 Col 0 11814 Case 12/21/2007 Isolation Scanner, PDC i Log, IBC, CBL, GPIT, GR, CCL 1-Nov-2007 og Perforation 5 Blu 1 10000 11800 Case 3/4/2008 Jelwery/Pert Log, 2-7/8' PJ Omega 15-Feb-2008 ', D C Pdf 15988 Perforation 10000 11800 Case 3/4/2008 Jelwery/Pert Log, 2-7/8' PJ Omega 15-Feb-2008 Well C ore s/Samples Information: S ample Interval Set Name Start Stop Sent Received N umber Comments Completion Date 2/15/2008 Completion Status WAGIN Current Status WAGIN DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070970 Well Name/No. PRUDHOE BAY UN AURO S-126 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23363-00-00 MD 11910 TVD 7076 Completion Date 2/15/2008 ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y / Analysis -~Pl- Received? Comments: Compliance Reviewed By: Completion Status WAGIN Current Status WAGIN UIC Y Daily History Received? Y Formation Tops N Date: MEMORANDUM `• To: Jim Regg \ ~f 2~5d(v~i P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 30, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-126 PRUDHOE BAY [JN AURO 5-126 Src: Inspector NnN-f'(1NFiilF.NTi A i Reviewed By: P.I. Suprv ~Jh.~-- r., ~„ Well Name' PRUDHOE BAY UN AURO S-t26 API Well Number: 50-029-23363-00-00 Inspector Name: Jeff.rones Insp Num: miUJ080623173440 Permit Number: 207-097-0 Inspection Date: 6!23/2008 Rel Insp Num: _ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~1e~ S-126 ~ Type Inj. W T'~ ~ 1 6544 ._ jA 590 4000 - 3930 --- 3910 --~----_- p zo7o97o TypeTest sPT Test psi I 1636 OA 31o sss szo a9s 1 ------- Interval OTHER p~F P__., Tubing 1730 I 1730 i 1730 - -_- 1730 i i _ - NOtes• Pre-WAG swap MIT. 2.6 BBLS methanol pumped, no exceptions noted. Monday, June 30, 2008 Page I of I • • Page 1 of 1 Maunder, Thomas E (DOA) From: Tirpack, Robert B [Robert.Tirpack@bp.com] Sent: Monday, May 12, 2008 3:15 PM To: Maunder, Thomas E (DOA); West, Taylor Cc: Regg, James B (DOA); Tirpack, Robert B; Young, Jim; Kolstad, Scott R; Meyer, Cheve (Schlumberger) Subject: RE: S-126 (207-097) Tom, As per our conversation this afternoon, after reviewing the S-126 USIT log with a Schlumberger logging rep, the ODE, the Pad Engineer and myself, we feel the cement in S-126 does provide adequate isolation and containment for water and/or MI injection into the Kuparuk. We also feel that additional diagnostic logs are not required at this time. This decision is based on the following: 1) cement from TD to the top of the Kuparuk is patchy, but provides adequate isolation in the perf intervals and 2) the 300' MD of HRZ above the Kuparuk also shows isolation with no channeling through the cment. In the future we will scrutinize our comments in the DIMS more closely to avoid any confusion and hopefully give a better description of what is seen in the USIT log. Regards, Rob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 08, 2008 9:51 AM To: West, Taylor; Tirpack, Robert B Cc: Regg, James B (DOA) Subject: S-126 (207-097) I know Rob was involved with this well, not sure about you Taylor. Please forward if this is not for you. I am catching upon some completion reports. Sorry this not is delayed. For this well, it appears that the 9-7/8" hole drilled well and the 7" casing was run and cemented successfully. However there is a comment late on November 1 after running the USIT, that says "patchy cement from bottom to 8800' and no bond from there to TOC at 5480". According to the production/injection report water injection began at the end of March. Based on the operations summary, I am surprised at how pessimistic the USIT log is. It appears that best practices were employed during the cementing operation. I request an assessment of the cement isolation of the perforated interval. Does BP plan any diagnostic logs to assure that water and eventually MI is confined to the authorized injection zone? Call or message with any questions. Tom Maunder, PE AOGCC 5/12/2008 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 08, 2008 3:35 PM To: 'Kolstad, Scott R' Subject: RE: S-126 (207-097) Scott, As a comparison, you might look at the USIT from V-223. The only difference I can see is that S-126 was 9-7/8" hole and deeper versus 8-3/4" for V-223. There is a marked difference in the bond logs. Tom From: Kolstad, Scott R [mailto:Scott.Kolstad@bp.com] Sent: Thursday, May 08, 2008 12:22 PM To: Maunder, Thomas E (DOA) Subject: RE: S-126 (247-097) Tom, This was one of my wells. I don't recall the USIT log off the top of my head. 1'll look into it and get back w/you. Scott From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Thursday, May 08, 2008 10:00 AM To: Kolstad, Scott R Subject: FW: S-126 (207-097) Scott, I got a bounceback from Rob's email. Was this one of your wells? Tom From: Maunder, Thomas E (DOA) Sent: Thursday, May 08, 2008 9:51 AM To: West, Taylor; `Robert Tirpack' Cc: Regg, James B (DOA) Subject: S-126 (207-097) I know Rob was involved with this well, not sure about you Taylor. Please forward if this is not for you. I am catching up on some completion reports. Sorry this not is delayed. For this well, it appears that the 9-7/8" hole drilled well and the 7" casing was run and cemented successfully. However there is a comment late on November 1 after running the USIT, that says "patchy cement from bottom to 8800' and no bond from there to TOC at 5480". According to the production/injection report water injection began at the end of March. Based on the operations summary, I am surprised at how pessimistic the USIT log is. It appears that best practices were employed during the cementing operation. I request an assessment of the cement isolation of the perforated interval. Does BP plan any diagnostic logs to assure that water and eventually MI is confined to the authorized injection zone? 5/8/2008 -G~~ STATE OF ALASKA ~O~ ALASKA~L AND GAS CONSERVATION COMMISSION RECEIVt MAR 1 1 208 WELL COMPLETION OR RECOMPLETION REPORT AND,40~a Ojl & Gas ~n~. s~~ 1a. Wetl Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 Well Class: zoAACZS.,os zoAACZS.,,o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One ®Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. ~ 2/15/2008 207-097 i 3. Address: 6. Date Spudded 13. API Number , P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 10/20!2007 50-029-23363-00-00 4a. Location of Well (Governmental Section): 7: Date T.D. Reached 14. Well Name and Number: Surface:. 10/28/2007 S-126 ' ' ' FEL, SEC. 35, T12N, R12E, UM 3171 FSL~ 4565 Top of Productive Horizon: 8. KB (ft above MSL): 67 15. Field /Pool(s): , 3090' FSL, 2403' FEL, SEC. 33, T12N, R12E, UM Ground (ft MSL): 38.5' Prudhoe Bay Field /Aurora Pool Total Depth: 9. Plug Back Depth (MD+TVD) ~ 3144' FSL, 2613' FEL, SEC. 33, T12N, R12E, UM 11814 6993 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 618885 y- 5979374 Zone- ASP4 ~ 11910 - 7076 ADL 028258 TPI: x- 610490 y- 5979165 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: - 5979216 Zone- ASP4 Total Depth: x- 610279 N!A y 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rin ed information er 20 AAC 25.050 N/A ft MSL (Approx.) 1800 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, PWD, DEN, NEU, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 42" 260 sx Arctic Se A rox. 10-3/4" 45.5# L-80 Surface 4808' Surface 3193' 13-1/2" 1101 sx AS Lite 434 sx Class'G' 7" 26# L-80 Surface 11898' Surface 7066' 9-7/8" 720 sx LiteCrete 298 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 2-7/8" Gun Diameter 6 SPF 4-1/2", 12.6#, L-80 11360' 11294' , MD TVD MD TVD CEMENT SQUEEZE ETC. ACID FRACTURE 25 11477' - 11495' 6701' - 6717' , , , . 11499' - 11506' 6720' - 6726' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11511' -11518' 6730' - 6736' 11532' 6742' 11524' 6748' 2447' Freeze Protected with 83 Bbls of Diesel - - 11538' - 11548' 6754' - 6762' 11562' - 11567' 6774' - 6779' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not On Injection N/A Date Of Test: HOUI'S Tested: PRODUCTION FOR (71L-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 2.50._071. None t ~ -~~ Form 10-407 Revised 02/2007 ~~~ CONTINUED ON REVERSE SIDE ~ J•77~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD We11 Teste ^ Yes ®No Permafrost Top 29' 29~ If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2073' 1933' detailed test information per 20 AAC 25.071. Top of Ugnu 5724' 3552' None Top of Ugnu 'M' Sands 8384' 4642' Top of Schrader Bluff'N' Sands 8809' 4832' Top of Schrader Bluff'O' Sands 9039' 4947' Base of Schrader / Top of Colville 9566' 5239' Top of Horizon 11254' 6511' Top of Kalibuk 11453' 6680' Kuparuk'C' 11473' 6698' Kuparuk'B' 11598' 6805' Kuparuk'A' 11745' 6933' Top of Miluveach 11831' 7007' Formation at Total Depth (Name): Miluveach 11910 7076 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Leak-Off Test Summary and a Post Rig Work Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ Signed Sondra ewman , Title Drilling Technologist Date ~ - S-126 207-097 Prepared eyName/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: ScottKolstad, 564-5347 Permit No. / A royal No. INSTRUCTIONS Gerlew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE _ 4-1/16" CMJ WELLHEAD = FMC GEN 5 ACTUATOR = HYD KB. ELEV - 67.00 BF. ELEV = 38.5 KOP = 400' Max Angle= 69° @ 4341' Datum MD = Datum TV D = 10 3/4" CSG, 45.5#, L-80, ID = 9.950" ~~ 4808' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5845 10107 3600 5600 67 39 KBG-2 KBG-2 DMY DMY BK BK 0 0 02/09/08 02/09/08 Min ID = 3.725" @ 11338' 4-1 /2" HES'XN' NIPPLE 11273' ~ 4-1/2" HES X NIP, ID = 3.813" I 11294' 7" X 4-1 /2" BKR S-3 PKR, ID = " 11317' 4-1/2" HES X NIP, ID = 3.813" 11338' 4-1/2" HES XN NIP, ID = 3.725" ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.943" ~ PERFORATION SUMMARY REF LOG: MWD ON 10/26/07 TIE-IN LOG: USff ON 11!01/07 ANGLE AT TOP PERF: 31 @ 11477' Note: Refer to Production DB for historical perf data SIZE SPF IM'ERVAL Opn/Sqz DATE 2-7/8" 6 11477 - 11495 O 02/16/08 2-7/8" 6 11499 - 11506 O 02/16/08 2-718" 6 11511 - 11518 O 02/16/08 2-718" 6 11524 - 11532 O 02/16/08 2-7/8" 6 11538 - 11548 O 02/16/08 2-718" 6 11562 - 11587 O 02/16/08 S-126 SA NOTES: 994' -iTAM port collar 2443' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS PBTD ~-~ 11$14' 7", 26#, L-80, .0383 bpf, ID = 6.276" ~-~ 11898' 11360' -i4-1/2" WLEG, ID = 4.00" ELMD TT NOT LOGGED 11424' -I7"MARKERw/RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 11/03/07 N9ES ORIGINAL COMPLETION 11/05/07 /TLH CORRECTIONS 02/09/08 TAO/PJC WELL ANGLE/ ID CORRECTION 02/16/08 WWR/TL PERFS; GLV GO (02/09/08) GPB AURORA WELL: S-126i PERMff No: 2070970 API No: 50-029-23363-00-00 SEC 35, T12N, R12E, 3171' FSL, 4565' FEL BP Exploration (Alaska) g F Page 1 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABORS 9ES Rig Number: 9-ES Date ;From - To ~' Hours Task Code I NPT ! Phase. Description of Operations 10/18/2007 18:00 - 00:00 6.00 MOB P PRE Back rig off of well. Lay mats around S-126i. RU Diverter line. 10/19/2007 00:00 - 04:00 4.00 MOB P PRE Position diverter line. Back rig over well. Spot pit module to 04:00 - 06:00 2.00 RIGU P PRE 06:00 - 14:30 8.50 RIGU P PRE 14:30 - 15:00 0.50 RIGU P PRE 15:00 - 00:00 9.00 RIGU P PRE 10/20/2007 00:00 - 01:00 1.00 RIGU P PRE 01:00 - 02:00 1.00 RIGU P PRE 02:00 - 03:30 1.50 RIGU P PRE 03:30 - 07:00 3.50 RIGU P PRE 07:00 - 08:30 1.50 RIGU P PRE 08:30 - 09:00 0.50 RIGU P PRE 09:00 - 10:00 1.001 DRILL P ~ SURF 10:00 - 10:30 0.50 DRILL P SURF 10:30 - 11:00 0.50 DRILL P SURF 11:00 - 20:00 9.00 DRILL P SURF 20:00 - 20:30 ~ 0.50 ~ DRILL ~ N ~ WAIT ~ SURF 20:30 - 00:00 I 3.501 DRILL I P I I SURF 10/21/2007 100:00 - 01:00 1.001 DRILL P SURF sub unit. 'Accept rig to S-126i C~ 0400 hrs. Take on fluid for spud mud. NU Diverter. Install flow nipple and drilling riser. Continue mixing spud mud. Prepare drillpipe in shed. Function test diverter system. Witness waived by AOGCC rep Chuck Scheve. Te§Twifnessd-6y BP-W5L air eu e NAD TP Bill Bixby. PU 5" drillpipe from pipe shed and stand back in derrick. Rack back 46 stands = 138 joints. PU 5" HWDP, MU Drilling Jars, Stand back in derrick. Prepare cellar. Service Topdrive. Update Epoch System software. Pressure test lines. PU 13.5" bit & near bit stabilizer. Clean out conductor Ice from 46' to 100'. PJSM. Continue to MU 13.5" Surface hole drilling BHA. Hang Gyrodata sheave wheel in derrick. Prepare rig floor for spud. Hold Pre-Spud meeting with Quittschreiber Crew, Hohn Crew, directional driller, MWD hand, Mud Engineers, Wellsite Geologist, BP WSL's, NAD Toolpusher. Spud S-126 13.5" surface hole and drill from 108' to 324'. High RO an low weight on bit -likely drilling in thaw bulb. 575 gpm, 682 psi on, 45 rpm, 1.5k TO off, PU - 57k, SO - 57k, RWT - 57k. CBU C~ 575 gpm, 680 psi. POOH from 324' md. PU Jar stand and RIH to 324' md. Directionally drill 13.5" surface hole from 324' to 1,481'. Hole took 150 bbls spud mud in thaw bulb_fr_om conductor t_o_ Gyro surveyed as necessary. 650 gpm, 1,660 psi on, 1,380 psi off 80 rpm, 6.5k TO on, 3.Ok TO off PU - 90k, SO - 70k, RWT - 85k Wipe 30' prior to connections. No hydrates seen. Circulate and reciprocate while emptying cuttings tank w/ last super sucker on location. Stand by for truck arrival. Trucks delayed from changeout and safety meeting. Directionally drill 13.5" surface hole from 1,481'to 1,764'. 650 gpm, 1,752 psi on, 1,514 psi off 80 rpm, 6.5k TO on, 2.7k TO off PU - 95k, SO - 75k, RWT - 90k, WOB - 35k. AST - 3.48 hrs, ART - 3.81 hrs. Survey every stand. Wipe 30' prior to connections. No hydrates seen as of yet. *RD Gyrodata and Sperry E-Line out of critical path. Circulate and reciprocate ~ 1,764' md. Circulate 4 bottoms up. 660 gpm, 1500 psi, 80 rpm, 4.5k TO, PU - 100k, SO - SOk, RWT - 90k, MW - 9.2 ppg. Shakers cleaned up ~ 3.5 BU. Printed: 2/27/2008 3:21:16 PM ~' g P Page 2 of 1 1 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABOBS 9ES Rig Number: 9-ES Date From - To Hours Task I Code NPT Phase Description of Operations 10/21/2007 01:00 - 02:00 1.00 DRILL P SURF Monitor well - OK. POH for wiper trip from 1,764' to 324'. Hole in good shape. No swabbing. 3-4 25k overpulls on trip out, but no need to bring pumps online. 02:00 - 03:00 1.00 DRILL P SURF Run in hole from 324' to 1,764' smooth -only taking 5k weight intermittantly. Wash last stand to TD C~ 1,764' md. 03:00 - 12:00 9.00 DRILL P SURF Directionally drill 13.5" surface hole from 1,764'to 3,081' and Surveyed hole every stand. PU - 118k, SO - 70k, RTW - 95k. Slow spots at 2,360' and & 2,410' md. Erratic To_ rgue while working wood at those depths. 650 gpm, 1,749 psi off, 2,139 psi on, 80 rpm 12.5k TO on, 6.Ok TO off, 30k WOB Wipe 30' prior to connections. No hydrates seen. Permafrost came in at - 2,060' md. AST = 2.3 hrs, ART = 2.61 hrs. 12:00 - 19:00 7.00 DRILL P SURF Directionally drill 13.5" surface hole from 3,081' to 4,200' and Surveyed hole every stand. PU - 113k, SO - 75k, RTW - 95k. 675 gpm, 1,700 psi off, 2,100 psi on, 80 rpm 10.5k TO on, 5.5k TQ off, 40k WOB Wipe 30' prior to connections. 19:00 - 22:00 3.00 DRILL P SURF Directionally drill 13.5" surface hole from 4,200' to 4,661' and Surveyed hole every stand. PU - 113k, SO - 75k, RTW - 95k, 700 gpm, 1,700 psi off, 2,200 psi on, 80 rpm 11.Ok TO on, 6.Ok TO off, 40k WOB Wipe 30' prior to connections. Losing mud to formation at 150 bbl / hr from 4 120 - 4 680. Reduced flow rates to 600 gpm 1800 psi and string in Mix II until losses healed up. 22:00 - 00:00 2.00 DRILL P SURF Directionally drill 13.5" surface hole from 4,661' - 4,779 and Surveyed hole every stand. PU - 125k, SO - 85k, RTW - 105k. 600 gpm, 1,760 psi off, 1,850 psi on, 80 rpm 11.Ok TO on, 6.Ok TO off, 25k WOB Wipe 30' prior to connections. Losses have healed u . Total losses for da = 320 b 10/22/2007 00:00 - 00:30 0.50 DRILL P SURF Directionally drill 13.5" surface hole from 4,779' - 4,815' and TD. Slide last stand to TD. PU - 125k, SO - 85k, RTW - 105k. 600 gpm, 1,760 psi off, 1,850 psi on, 25k WOB. 00:30 - 03:30 3.00 DRILL P SURF Circulate 3.5 bottoms up while reciprocating pipe 60'. 700 gpm, 2,100 psi, 100 rpm, 8.Ok TO, RTW - 110k, MW - 9.8 ppg, 300 viscosity. Consistant sand and clav returns over shakers. No runnin ravels or wood roblems. Shut down, monitor well - static. 03:30 - 05:30 2.00 DRILL P SURF POH dry for wiper trip from 4,815' to 2,700' with intermittent 10-30k drag. Wipe tight areas. PU - 135k, SO - 80k. 05:30 - 08:00 2.50 DRILL P SURF Work tight hole. From 2,700' - 2,500' and pump out of hole Ca? 125 gpm. Indications of tight spot being at the bit. Pressure increases w/ pull (mud motor seeing torque), but not packing Printed: 2/27/2008 3:21:16 PM gp Page 3 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABOBS 9ES Rig Number: 9-ES Date. From - To Hours Task Code NPT Phase Description of Operations 10/22/2007 05:30 - 08:00 2.50 DRILL P SURF off. Shut down pumps and pull dry from 2,500' to 2,200'. Pump out of hole from 2,200' - 2100'. Pull dry from 2,100' and to 1,669' md. 08:00 - 10:30 2.50 DRILL P SURF Trip back in hole from 1,669' to 4,779' and without pumping. PU - 100k, SO - 70k. Had intermittent down drag to but able to work past. Wipe all tight spots. Fill pipe and precautionary wash down last stand to bottom at 4,815'. 10:30 - 13:30 3.00 DRILL P SURF Circulate 3 bottoms up reciprocating 70' keeping bit in SV2 shale while circulating. 700 gpm, 2,080 psi, 100 rpm, 8.9k TO, PU - 135k, SO - 85k, RTW - 105k, MW - 9.6 ppg. 13:30 - 19:30 6.00 DRILL P SURF Monitor well - OK. PU - 135k, SO - 85k. POH to run surface casing from 4,815' to 820' with intermittant 5-20k drag. Work tight hole from 2,610' to 2,044' and with and without pumps as necessary. While pumping, parameters were 125gpm, 310 psi. 19:30 - 22:00 2.50 DRILL P SURF Stand back HWDP, Jar and DC stands from 820' to 200'. 22:00 - 23:00 1.00 DRILL P SURF Laydown BHA #1: MWD, motor and bit. Bit Grade 3-4-WT-A-F-2-NO-TD. Both stabalizers packed w/ clad Bit not as packed. 23:00 - 00:00 1.00 DRILL P SURF Clean and clear rig floor of BHA handling equipment. 'Losses to well for d 10/23/2007 00:00 - 02:00 2.00 CASE P SURF Rig up to run surface casing, Make dummy run with hanger and landing joint. 02:00 - 05:00 3.00 CASE P SURF PJSM. Pick up and Baker-Lok 10 3/4" shoe track. Check floats - OK. Run in hole with 29 joints 10 3/4" 45.5# L-80 BTC surface casing to 1,271'. Make up torque to mark - 9,500 ft/Ibs avg. using Best-O-Life 2000 NM. Ran 25 bowspring centralizers on first 25 joints with 1 locked down 10 ft above Float Shoe and Float Collar. Fill every joint with casing fill-up tool. Losing displacement volume to formation while running in hole at 2 min Point. 05:00 - 05:30 0.50 CASE P SURF Circulate down 2 joints casing at 10 min /joint, 5 bpm. Lost displacement volume but no more. 05:30 - 07:00 1.50 CASE P SURF Continue RIH ~ 2 min /joint from 1,360' to 2,050'. 07:00 - 08:30 1.50 CASE P SURF Circulate each joint down from 2,050' to 2,686' @ 5.7 bpm, 500 psi. 08:30 - 12:00 3.50 CASE P SURF Continue running in hole, breaking circulation every 10 joints from 2,686' to 4,776'. 'Lost total of 41 bbls while runnin casin . 12:00 - 12:30 0.50 CASE P SURF Make up hanger and landing joint. Remove casing slips and land casing on depth C~ 4,807'. 12:30 - 13:00 0.50 CEMT P SURF Break out and laydown Franks tool. Make up cement head and rig up circulating lines. 13:00 - 16:30 3.50 CEMT P SURF Reci rocate casin and sta a um s u to 7 b m, 485 psi. PU - 225k, SO - 110k. Condition mud for cement job to an 89 Vis, 16 YP. Held cement PJSM while circulating. ,*No mud losses. 16:30 - 21:30 5.00 CEMT P SURF -Switch to Dowell. Pump 5 bbls of fresh water. Test lines to 3,500 psi - OK. -Pump 108 bbls of 10.3 ppg MudPush II spacer C~ 4.9 bpm. -Drop bottom plug. Printed: 2/27/2008 3:27:16 PM g P Page 4 of 1 1 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABOBS 9ES Rig Number: 9-ES Date ~ From - To Hours Task '~, Code ~, NPT Phase Description of Operations 10/23/2007 16:30 - 21:30 - 5.00 CEMT -- - P SURF - - -Mix on the fly and pump 755 bbls of 10.7 ppg DeepCrete lead cement with 1 ppb Cemnet @ 7 bpm, 255 ICP, 490 psi FCP. (Set casing on landing ring with 544 bbls of cement away) -Pump 64 bbls of batched mixed 15.8 ppg Class "G" tail cement @ 5 bpm, 450 psi ICP, 330 psi FCP. -Pump 24 bbls of batched mixed 16.3 ppg Class "G" with DuraStone tail cement C~ 4.9 bpm, 305 psi ICP, 310 psi FCP. -Drop top plug and kick out with 10 bbls of fresh water. -Switch to rig and displace cement with 445 bbls of 9.6 ppg mud. -1st 350 bbls ~ 6.3 bpm 390 psi ICP, 1,010 psi FCP. Started getting cement back in 1st 100 strokes. -Next 85 bbls Q 5 bpm, 925 psi ICP, 1,270 psi FCP. -Last 10 bbls C~ 3 bpm, 1,030 psi ICP, 970 psi FCP. -Bump plug on schedule with 95% effc. -CIP ~ 21:25 hr. -"Returned 423 bbls of "Sidewalk Cement" to surface. o mu osses. 21:30 - 22:00 0.50 CEMT P SURF Continue pressuring up on casing after bump to 3 50~ ns.i. -Hold ressure for 30 minute casin test. Good test. Bleed off pressure and check floats - OK. 22:00 - 22:30 0.50 CEMT P SURF Wash out surface BOP stack and flush flowline. 22:30 - 00:00 1.50 CEMT P SURF Rig down circulating lines. Laydown cement head. Back out and laydown landing joint. Flush diverter knife valve. `No mud losses for tour. `Lost 41 bbls for the day. 'Lost total of 726 bbls of S ud mud for the well. 10/24/2007 00:00 - 00:30 0.50 CEMT P SURF Clear and clean rig floor. 00:30 - 01:30 1.00 CEMT P SURF Rig down 350 ton elevators. Change out bales. 01:30 - 03:00 1.50 DIVRTR P SURF Nipple down diverter equipment. 03:00 - 04:30 1.50 WHSUR P SURF Install casing head and tubing spool. Test head to 1,000 psi for 10 minutes - OK. 04:30 - 07:00 2.50 BOPSU P SURF Nipple up BOPE. 07:00 - 08:00 1.00 BOPSU P SURF Rig up to test BOPE. 08:00 - 13:00 5.00 BOPSU P SURF Test BOPE to 250 psi low, 4,000 psi high. Tested annular preventer to 250 psi low, 3,500 psi high. All tests 5 minutes each. Perform accumulator drawdown test. Test witnessed by A_OGCC rep Lou Grimaldi, BP WSL Blair Neufeld and NAD TP Ron Dalton. 13:00 - 14:30 1.50 BOPSU P SURF Rig down and blow down BOP test equipment. Install wear bushing and mouse hole. 14:30 - 22:30 8.00 DRILL P PROD1 Pick up 141 joints of drill pipe from shed to 4,439 22:30 - 00:00 1.50 DRILL P PRODi Circulate bottoms up C~ 6 bpm, 250 psi. 10/25/2007 00:00 - 01:30 1.50 DRILL P PROD1 POH standing back drill pipe in derrick from 4,439' to surface. 01:30 - 05:30 4.00 DRILL P PROD1 PJSM. Pick up and make up BHA #2: New 9 7/8" Hycalog DSX619M-610 bit, 1.5 deg PDM, XO, NM STAB, ARC, MWD, ADN, tea NM DC, SS, 5" HWDP, Jar, 19ea 5" HWDP. 05:30 - 06:00 0.50 DRILL P PROD1 Run in hole with BHA #2 picking up drill pipe out of shed from 814' to 1,285'. 06:00 - 06:30 0.50 DRILL P PROD1 Perform a quick test on Tam port collar to 1,000 psi - OK. Shallow hole test MWD. 510 gpm, 915 psi - OK. 06:30 - 10:00 3.50 DRILL P PROD1 Continue running in hole, picking up 5" drill pipe out of shed from 1,285' to 4,219'. Printed: 2/27/2008 3:21:16 PM gp Page 5 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABORS 9ES Rig Number: 9-ES Date.. !, From - To ~ Hours Task I Code ~~ NPT ' Phase ~ Description of Operations 10/25/2007 06:30 - 10:00 -- 3.50 DRILL P PROD1 -- PU - 130k, SO - 55k. 10:00 - 11:00 1.00 DRILL P PROD1 Cut and slip drilling line 78 ft. 11:00 - 11:30 0.50 DRILL P PROD1 Service topdrive, crown, blocks and drawworks. 11:30 - 12:00 0.50 DRILL P PROD1 Make up topdrive blower hose and break circulation. 12:00 - 12:30 0.50 DRILL P PROD1 Run in hole from 4,219' to 4,597'. Wash down from 4,597' to float collar C~ 4,794'. (Float collar on depth) 12:30 - 13:15 0.75 DRILL P PROD1 Drill out float collar, cement and shoe to 4,807'. Clean out rathole to 4,815'. 550 gpm, 1,350 psi off, 1,670 psi on. 60 rpm, 11 k TO off, 12k TO on, WOB - 10k. Displaced well to 9.0 ppg LSND mud while drilling out shoe and rathole. 13:15 - 13:30 0.25 DRILL P PROD1 Drill 20' of new hole from 4,815' to 4,835'. New mud back to surface. Pull back up into casing. 13:30 - 14:00 0.50 DRILL P PROD1 Perform LOT: MD - 4,815', TVD - 3,193'. LO pressure 710 psi. EMW - 13.28 ppg 14:00 - 15:00 1.00 DRILL P PROD1 Obtain benchmark ECD's and parameters. 700 gpm, 1,400 psi, 80 rpm, 5-6k TO, PU - 104k, SO - 75k, RWT - 105k. CECD - 9.46 ppg, RECD - 9.87 ppg 15:00 - 00:00 9.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 4,835' to 6,395'. 700 gpm, 2,080 psi off, 2,280 psi on. 80 rpm, 9.6k TO off, 12k TO on, WOB - 25k. PU - 151 k, SO - 82k, RWT - 113k. AST - 0.08 hrs, ART - 4.08 hrs CECD - 10.00 ppg, AECD - 10.57 ppg. Survey each connection. Pumped Hi Vis sweep C~3 5,315' with 10% increase in cuttings when back to surface. 10/26/2007 00:00 - 12:00 12.00 DRILL P PRODi Directionally drill 9 7/8" production hole from 6,395' to 7,808'. 700 gpm, 2,045 psi off, 2,650 psi on. 80 rpm, 11-12k TO off, 12-14k TO on, WOB - 5-35k. PU - 175k, SO - 100k, RWT - 120k. CECD - 10.00 ppg, AECD - 10.77 ppg. AST - 1.1 hrs, ART - 6.6 hrs Survey each connection. Backream each stand prior to connections for ECD control. Pumped Hi Vis sweep C~ 6,439' with no increase in cuttings when back to surface. 12:00 - 00:00 12.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 7,808' to 9,413'. 700 gpm, 2,590 psi off, 2,870 psi on. 80 rpm, 17k TO off, 19.4k TO on, WOB - 35k. PU - 194k, SO - 107k, RWT - 141 k. CECD - 10.19 ppg, RECD - 10.64 ppg. AST - 2.18 hrs, ART - 5.88 hrs Survey each connection. Backream each stand prior to connections for ECD control. 10/27/2007 00:00 - 12:00 12.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 9,413' to 10,069'. 700 gpm, 2,790 psi off, 2,840 psi on. 80 rpm, 21 k TO off, 18k TO on, WOB - 35k. PU - 210k, SO - 110k, RWT - 148k. Printed: 2/27/2008 3:21:16 PM gp Page 6 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABORS 9ES Rig Number: 9-ES Date ', From - To Hours Task Code NPT Phase Description of Operations -- - 10/27/2007 00:00 - 12:00 12.00 - DRILL P -__ PROD1 - CECD - 10.38 ppg, AECD - 10.50 ppg. AST - 3.46 hrs, ART - 6.3 hrs. Survey each connection. Backream 60 ft prior to connections. Pumped Hi Vis sweep ~ 9,653' with no increase in cuttings when sweep back to surface. 12:00 - 00:00 12.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 10,069' to 10,795'. 700 gpm, 2,840 psi off, 3,040 psi on. 80 rpm, 17-19k TO off, 17-21 k TO on, WOB - 35k. PU - 221 k, SO - 125k, RWT - 165k. CECD - 10.38 ppg, AECD - 10.48 ppg. AST - 0.63 hrs, ART - 9.70 hrs. Survey each connection. Backream 30 ft prior to connections. Pumped Hi Vis Nut Plug sweep C~? 10,163' with 5% increase in cuttings when sweep back to surface. Pumped EP Mud Lube pill C~ 10,445'. Had initial decrease in torque from 21 k to 16k then gradually climbed back to 19k on bottom torque. 10/28/2007 00:00 - 10:00 10.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 10,795' to 11,200'. 650 gpm, 2,890 psi off, 3,130 psi on. 80 rpm, 16k TO off, 18k TO on, WOB - 35k. PU - 225k, SO - 130k, RWT - 170k. Weighted up mud system from 9.6 ppg to 10.4 ppg. CECD - 11.21 ppg, AECD - 11.24 ppg. Survey each connection. Backream 30 ft prior to connections. 10:00 - 10:30 0.50 DRILL N RREP PROD1 Mud line seal washed out at interconnect. Replace seal. Reciprocate pipe without pumping. PU - 245k, SO - 130k. 10:30 - 16:30 6.00 DRILL P PROD1 Directionally drill 9 7/8" production hole from 11,200' to 11,551'. 650 gpm, 2,900 psi off, 3,130 psi on. 80 rpm, 20-22k TQ off, 19-20k TO on, WOB - 35k. PU - 230k, SO - 131 k, RWT - 172k. CECD - 11.21 ppg, AECD - 11.21 ppg. Survey each connection. Backream 30 ft prior to connections. 16:30 - 17:00 0.50 DRILL N SFAL PROD1 Circulate and reciprocate with one pump while changing swab on #2 mud pump. 301 gpm, 915 psi 17:00 - 21:30 4.50 DRILL P PROD1 Directionally drill 9 7/8" production hole from 11,551' to TD 11,910 MD', 7,076' TVD. 655 gpm, 2,760 psi off, 3,000 psi on. 80 rpm, 21-24k TO off, 19-21 k TQ on, WOB - 10-35k. PU - 240k, SO - 135k, RWT - 182k. CECD - 11.21 ppg, AECD - 11.20 ppg. AST - 0.38 hrs, ART - 15.91 hrs (Total for the day) Survey each connection. Backream 30 ft prior to connections. Started pumping 40 bbl 12.4 ppg weighted sweep tail end of last stand while drilling. 21:30 - 23:00 1.50 DRILL P PROD1 Continue circulating out weighted sweep to surface. No increase in cuttings with sweep back to surface. Printed: 2/27/2008 3:21:16 PM ~ ~ gp Page 7 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABOBS 9ES Rig Number: 9-ES Date From - To ,Hours Task Code NPT Phase Description of Operations 10/28/2007 21:30 - 23:00 1.50 DRILL P PROD1 655 gpm, 2,700 psi, 80 rpm, 19k TO. 23:00 - 00:00 1.00 DRILL P PROD1 Monitor well -static. Backream from 11,910' to 11,360'. 654 gpm, 2,732 psi, 80 rpm, 18.5k TO. CECD - 11.21 ppg, AECD 11.23 ppg. 10/29/2007 00:00 - 05:30 5.50 DRILL P PROD1 Continue backreaming from 11,360'to 9,480'. (Bit past 1st ghost reamer, upper reamer in casing) 650 gpm, 2,700 psi, 80 rpm, 16k TO. CECD - 11.21 ppg, AECD 11.24 ppg, MW - 10.4 ppg. PU - 185k, SO - 115k, RWT - 140k. 05:30 - 06:30 1.00 DRILL P PROD1 Circulate 1 1/2 times bottoms up. 700 gpm, 2,800 psi, 80 rpm, 14k TO PU - 185k, SO - 115k. 10.4 ppg MW. 06:30 - 10:30 4.00 DRILL P PROD1 Monitor well -static. POH from 9,480' to 4,807' without problem. 10:30 - 13:00 2.50 DRILL P PROD1 Monitor well -static. POH from 4,807' to 2,041' 13:00 - 15:00 2.00 DRILL P PROD1 Continue POH laying down drill pipe from 2,041' to 814'. 15:00 - 15:30 0.50 DRILL P PROD1 Continue POH laying down HWDP from 814'to 169'. 15:30 - 17:30 2.00 DRILL P PROD1 PJSM. Laydown BHA #2. Bit grade: 1-1-WT-A-X-1-NO-TD 17:30 - 18:00 0.50 DRILL P PROD1 Clear and clean rig floor. 18:00 - 18:30 0.50 BOPSU P RUNPRD Pull wear bushing. Flush stack with jetting tool. Install BOPE test plug. 18:30 - 19:30 1.00 BOPSU P RUNPRD Chan a out upper 3.5" x 6" VBRs to 7" rams. 19:30 - 20:00 0.50 BOPSU P RUNPRD Pressure test 7" rams to 250 si low 4 000 si hi h. Slowdown and rig down BOPE test equipment. 20:00 - 21:30 1.50 CASE P RUNPRD Rig up to run 7" casing. Make dummy run with hanger and landing joint. 21:30 - 00:00 2.50 CASE P RUNPRD PJSM. Pick up, Baker Lok and make up 7" 26# L-80 BTC-M casing shoe track. Check floats - OK. Continue running in hole with 7" BTC-M casing to 1,540'. Fill every joint and break circulation every 20 joints. Made up connections to 8,600 fUlbs avg TO to mark. Used BOL 2000 pipe dope. 10/30/2007 00:00 - 06:00 6.00 CASE P RUNPRD Continue running in hole with 7" BTC-M casing from 1,540' to 4,785'. Fill every joint and break circulation every 20 joints. Made up connections to 8,600 ft/Ibs avg TO to mark. Used BOL 2000 pipe dope. 06:00 - 07:00 1.00 CASE P RUNPRD Circulate bottoms up 22 ft above surface casing shoe. 5 bpm, 385 psi ICP, 335 psi FCP. PU - 135k, SO - 97k. 07:00 - 09:30 2.50 CASE P RUNPRD Continue running in hole with 7" BTC-M casing from 4,785' to 5,683' (X-over joint). Fill every joint and circulate down every 10th joint for 3 minutes each C~ 3 bpm 180 psi. 'Ran total of 137 joints of 7" BTC-M casing plus full X-over joint. 09:30 - 10:00 0.50 CASE P RUNPRD Circulate and reciprocate while rigging up Torq Turn equipment. 5 bpm, 390 psi. PU - 125k, SO - 97k. 10:00 - 19:00 9.00 CASE P RUNPRD Continue running in hole with BTC-M x TCII casing from 5,683' to 11,870' without problem and with proper mud displacement. 151 TCII total joints. Fill every joint and circulate down every 10th joint for 3 minutes each C~ 5 bpm 650 psi. Made up connections to 10,100 ft/Ibs TO to mark. Used Jet Lube pipe Printed: 2/27/2008 3:21:16 PM BP Page 8 of 11 Operations Surnmary Report ..Legal Well Name: S-126 Common Well Name: S-126 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Start: 10/18/2007 Rig Release: 11/3/2007 Rig Number: 9-ES Spud Date: 10/20/2007 End: 11 /3/2007 Date From - To~ Hours Task Code NPT 10/30/2007 10:00 - 19:00 9.00 CASE P 19:00 - 19:30 0.50 CASE P 19:30 - 20:00 0.501 CEMT P 20:00 - 23:45 I 3.751 CEMT I P 23:45 - 00:00 I 0.251 CEMT I P 10/31 /2007 ~ 00:00 - 01:30 1.50 CEMT P Phase Description of Operations RUNPRD dope. RUNPRD Pick up and make 7" hanger and landing joint. Land casing at planned depth at 11,898'. PU - 275k, SO - 125k. HES Float Shoe set ~ 11,898' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float collar ~ 11,814' (PBTD) 9 Jts 7", 26#, L-80 BTC-Mod (#3-11) 7", 26#, L-80 BTC-Mod Marker Pup w/ RA in collar ~ 11,423' 126 Jts 7", 26#, L-80 BTC-Mod (#12-137) 7" 26# L-80 TC-I I X BTC-M crossover joint ~ 6,214' 151 Jts 7", 26#, L-80 TC-I I (#1 - 151) 7" 26# L-80 TC-II Pup Jt. FMC Hanger 7 1/8" x 9 5/8 & 8 1/4" Rigid Straight Blade Centralizers: Jt. # 1 8 1/4" 1 cent. locked 5 ft up from shoe. Jt. # 2 9 5/8" 2 cent. w/ stop ring locked in mid jt Jt. # 3 8 1/4" 2 cent. Floating with stop ring in the middle BTC-M Jt. #4 thru # 11 9 5/8" 2 ea. Floating with stop ring in the middle BTC-M Jts. #12 thru # 22 - 9 5/8" 2 ea. Floating with stop ring in the middle BTC-M Jt. # 23 thru # 56 9 5/8" 1 ea cent. Free Floating BTC-M Jt. # 57 thru # 69 9 5/8" 2 ea. Floating with stop ring in the middle BTC-M Jt. # 70 thru # 87 8 1/4" 2 ea. Floating with stop ring in the middle 100 ea 9 5/8" Centralizers 39 ea 8 1/2"" Centralizers 51 ea Total stop rings RUNPRD Back out and laydown Franks tool. Slowdown topdrive. Make up cementing head and circulating lines. RUNPRD Sta e u umps to 7 bpm circulate and condition mud for cement'ob. Circulated 3 bottoms up C~3 7 bpm, 780 psi P, 575 psi FCP. Reci rocate casing 20 ft strokes. Initial PU - 275k, SO - 125k, Final PU - 270k, SO - 138k MW-10.4 ppg,Vis-47,PV-14,YP-16. Held cementing PJSM while circulating. RUNPRD Switch to Dowell. Pump 5 bbls of fresh water. Pressure test lines to 4,200 psi - OK. RUNPRD Continue 7" casing cement job. Mix and pump 39 bbls of 11.0 ppg MudPush II spacer ~ 4.9 bpm, 400 psi ICP, 340 FCP. Drop bottom plug. Mix on the fly and pump 318 bbls of 12.0 ppg LiteCrete lead cement ~ 4.7 bpm, 365 psi ICP, 260 FCP. Printed: 2/27/2008 3:21:16 PM ~ r gp Page 9 of 11 Operations Summary Report Legal Well Name: S-126 Common Well Name: S-126 Spud Date: 10/20/2007 Event Name: DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 Contractor Name.: NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 Rig Name: NABOBS 9ES Rig Number: 9-ES Date from - To i Hours Task Code NPT Phase Description of Operations - - - -- - 10/31/2007 00:00 - 01:30 1.50 CEMT P RUNPRD Mixon the fly and pump 62 bbls of 15.8 ppg Class "G" tail cement ~ 3.5 bpm, 275 psi ICP, 210 psi FCP. Wash up cement line to Tee. Kick out plug with 5 bbls of fresh water. 01:30 - 03:30 2.00 CEMT P RUNPRD Switch to rig. Displace cement with 447 bbls of seawater. 1st 395 bbls C~ 5 bpm, 105 psi ICP. 108 bbls before catching up to plug. 1,775 psi FCP. Last 52 bbls ~ 3 bpm, 1,600 psi ICP, 1,840 psi FCP. Stopped reciprocating pipe with 9 bbls left to end of displacement. PU - 225k, SO - 63k. Bump plug with calculated 95% effcy to 2,400 psi. CIP ~ 03:23 hr. Bleed off pressure, check floats - OK. No mud losses for entire cement 'ob. 03:30 - 04:30 1.00 CASE P RUNPRD Switch back to Dowell. Pack lines with water. Pressure test 7" casing to 4,000 si 30 minutes -Good Test! leed off pressure. 04:30 - 05:30 1.00 CEMT P RUNPRD Rig down cement head, circulating lines. Laydown landing joint. Clear floor of casing equipment. 05:30 - 06:30 1.00 WHSUR P RUNPRD Install 7" x 10 3/4" packoff. Test same to 5,000 psi - 15 minutes - OK. 06:30 - 07:30 1.00 CASE P RUNPRD Change out bails, install 5" elevators and install mousehole. 07:30 - 08:30 1.00 CASE P RUNPRD Rig up and perform OA LOT MD - 4,815', TVD - 3,193'. LO pressure 550 psi. EMW - 13.71 ppg Inject 3 bbls of 10.4 ppg mud down OA @ 1/2 bpm, 620 psi. 08:30 - 11:00 2.50 BOPSU P RUNPRD Install BOPE test plug. Change out top rams from 7" to 3.5" x 6" VBR's. 11:00 - 12:00 1.00 BOPSU P RUNPRD Make up 4.5" test joint and pressure test rams to 250 psi low, 4,000 psi high. 12:00 - 12:30 0.50 BOPSU P RUNPRD Blowdown and rig down BOPE test equipment. Install wear bushing. 12:30 - 00:00 11.50 CASE P RUNPRD Laydown 387 joint of 5" drill pipe out of derrick using mousehole to laydown 1 x 1. 'Sim Ops C~ 12:30 hr: Injected 130 bbls of 10.4 mud down OA C~ 1.5 bpm, 1,860 psi ICP, 2.5 bpm, 75 psi psi 'Sim Ops (~ 20:45 hr: Freeze protect OA with 119 bbls of dead crude. Tested lines to 3 500 si. Initial OA pressure - 250 psi. 3 bpm, 1,050 psi ICP. 3 bpm, 1,250 psi FCP. SIP - 750 psi. 11/1/2007 00:00 - 00:30 0.50 CASE P RUNPRD Clear rig floor. Laydown mousehole. 00:30 - 01:30 1.00 CASE P RUNPRD Cut and slip 95 ft of drilling line. 01:30 - 03:00 1.50 EVAL P OTHCMP PJSM. Rig up SWS E-line tools. 03:00 - 05:30 2.50 EVAL P OTHCMP Run in hole with USIT logging tools. Spot check tools at 1,800'. entralization not good enough to log. POH and add power caliper to tool. Printed: 2/27/2008 3:21:16 PM gp Page 10 of 11 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 11 /1 /2007 105:30 - 08:30 S-126 S-126 Spud Date: 10/20/2007 DRILL+COMPLETE Start: 10/18/2007 End: 11/3/2007 NABOBS ALASKA DRILLING I Rig Release: 11/3/2007 NABOBS 9ES Rig Number: 9-ES Hours ~ Task I Code ~ NPT Phase Description of Operations 3.001 EVAL I P 08:30 - 18:00 9.50 EVAL P 18:00 - 20:00 2.00 EVAL P 20:00 - 21:00 1.00 EVAL P 21:00 - 22:00 1.00 BUNCO 22:00 - 00:00 I 2.00 OTHCMP Run in hole with USIT logging tools to 4,180. Unable to go down past 4,180' (67 deg). POH, remove gemco centralizers. Reconfigure toolstring configuration with 2 PPC calipers above and below Sonic with CME-Z centralizers. OTHCMP Run in hole with USIT logging tools to 11,814'. Log up from 11,814'to 150'. Pull up to surface. OTHCMP Run in hole with same tools to 3,000'. Make second pass from 3,000' to 2,500'. OTHCMP Rig down and laydown logging tools and equipment. RUNCMP Rig up to run 4.5" completion. Pull wear bushing. Make dummy hanger run. RUNCMP PJSM. Pick up and make up 4.5" 12.6# L-80 TCII completion jewelry and 8 joints of 4.5" TCII tubing to 420'. Baker Lok'd all connection below the Baker S-3 production packer. Torq Turn connections to 3,850 ft/Ibs. Used Jet Lub Seal Guard pipe dope. 'USIT lop indicated patchy cement from bottom to 8,800'. No 11/2/2007 100:00 - 03:00 3.00 03:00 - 04:30 I 1.50 04:30 - 12:00 I 7.50 12:00 - 17:00 I 5.00 17:00 - 18:00 I 1.001 BUNCO RUNCMP ~ Continue running in hole with 4.5" TCII completion from 420' to 2,419'. HMAN RUNCMP Change out damaged joints #57 & 58. Extract box end out of topdrive quill, laydown joints 58 & 57. Pick up and make up 2 joints from extra tubing inventory. (Relief driller slacked off too far and jammed box end of #58 into topdrive quill which also damaged the box end of #57 in the slips) RUNCMP Continue running in hole with 4.5" TCII completion from 2,419' to 7,329'. Changed out bad joint #126. RUNCMP Continue running in hole with 4.5" TCII completion from 7,329' to 11,333'. RUNCMP Make up tubing hanger to landing joint. Land tubing on depth C~ 11,360'. Up wt = 140k, Dn wt = 80k ITEM 4.5" 12.6 # WLEG, 4.5" TC-II set C~3 11,360' Tops: 4.5" HES 'XN' Nipple: ID 3.725" 11,338' 4.5" HES 'X' Nipple: 3.813" ID RHC-M Plug 11,317' 7" x 4.5" Baker S3 Production Packer 11,294' 4.5" HES 'X' Nipple: 3.813" ID 11,273' 28 Jts 4.5" 12.6# TCII Tbg (#1 - 28) GLM #1 - 9Cr 4.5" x 1 "KBG2-1 R w/ Dummy -Top Latch - 10,107' 104 Jts 4.5" 12.6# TCII Tbg (#29 - 132) GLM #2 - 9Cr 4.5" x 1" KBG2-1 R w/ DCK Shear Valve 5,845' 83 Jts 4.5" 12.6# TCII Tbg (#133 - 215) 4.5" HES 'X' Nipple: 3,813" ID 2,443' Printed: 2/27/2008 3:21:16 PM • g p Page 11 of 11 Operations Summary Report ''Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To S-126 S-126 DRILL+C NABOB NABOB Hours OMPLE S ALAS S 9ES Task TE KA DRI Code LING ' NPT Start I Rig Rig ~ Phase Spud Date: 10/20/2007 : 10/18/2007 End: 11/3/2007 Release: 11/3/2007 Number: 9-ES :.Description of Operations 11/2/2007 17:00 - 18:00 1.00 BUNCO RUNCMP 59 Jts 4.5" 12.6# TCII Tbg (#216 - 274) 4.5", 12.6#, L-80 TC-II Hanger Pup FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads 23.21' 18:00 - 22:00 4.00 BUNCO RUNCMP Rig up circulating lines. Reverse circulate 384 bbls of clean seawater, followed by 101 bbls of corrosion inhibited seawater and followed by 110 bbls of clean seawater. Placed inhibited seawater between packer and upper GLM w/shear valve. Pumped at 3 bpm, 240 psi. 22:00 - 22:30 0.50 BUNCO RUNCMP Drop 1 7/8" ball on roller rod assembly with 1.375" fishing neck down tubing. Laydown landing joint. 22:30 - 23:00 0.50 BUNCO RUNCMP Pressure up on tubing, set packer and hold 4,000 psi on tubing for 30 minutes -Good test! 23:00 - 00:00 1.00 BUNCO RUNCMP Bleed tubing pressure to 2,500 psi. Pressure test inner annulus to 4,000 psi for 30 minutes -Good test! 11/3/2007 00:00 - 01:00 1.00 BUNCO RUNCMP Bleed off annulus pressure to 0 psi. Bleed tubing pressure to 0 psi. Pressure up on annulus and shear DCK valve at 2,700 psi. Pressure only dropped 250 psi with circulation. Bring pump rate up to 3.5 bpm 3,750 psi with circulation up tubing. Bleed off pressure and pump down tubing C~3 3 bpm, 2,460 psi with circulation up annulus. Bleed off pressure and pump down annulus again C~3 3 bpm, 2,400 psi with circulation up tubing. Bleed off pressure. 01:00 - 02:00 1.00 BUNCO RUNCMP Set 2-way check valve with T bar. Pressure test check valve from below to 1,000 psi - OK. 02:00 - 04:30 2.50 BOPSU P RUNCMP Nipple down BOPE. 04:30 - 09:30 5.00 WHSUR P RUNCMP Nipple up tree adaptor. Test same to 5,000 psi 15 minutes - OK. Nipple up tree with hydraulic actuator valve. Test to 5,000 psi - not OK. Trouble shoot leaks. Test to 5,000 psi - OK. 09:30 - 10:30 1.00 WHSUR P RUNCMP Make up lubricator. Test to 500 psi - OK. Pull 2-way check valve. 10:30 - 12:00 1.50 WHSUR P RUNCMP Rig up LRHOS. 12:00 - 14:00 2.00 WHSUR P RUNCMP PJSM. Pressure test lines to 3,500 psi - OK. Reverse circulate 83 bbls of 80 deg diesel down inner annulus ~ 2.2 bpm, 1,350 psi ICP, 1,900 psi FCP. U-tube diesel back to tubing. Freeze protected IA and tubing to 2,447' MD, 2,200' TVD. 14:00 - 15:00 1.00 WHSUR P RUNCMP Blow down lines. Make up lubricator and install BPV. Test from below with diesel, pumped by LRHOS, to 1,000 psi - OK. 15:00 - 16:00 1.00 WHSUR P RUNCMP Secure well. Install gauges on tree. Secure and pump out cellar. 'Rig released from operations on S-1261 for move to W-2141 C~3 16:00 hr, 11/3/2007. Printed: 2/27/2008 3:21:16 PM BP Page 1 of 1 Leak-Off Test Summary Legal Name: S-126 Common Name: S-126 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/25/2007 LOT 4,807.6 (ft) 3,192.9 (ft) 9.00 (ppg) 710 (psi) 2,203 (psi) 13.28 (ppg) CJ Printed: 2/27/2008 3:02:51 PM ' • Well History Well Date Summary S-126 S-126 S-126 S-126 S-126 S-126 S-126 S-126 11/3/2007 Pulled 4" TWC H Type. 11/3/2007 Set 4" H Rug BFV 1/1/2008 T=O. Pull 4-1/16" CM/ "H" BPV. (Post Rig). Pulled 4-1/16" CMJ "H" BPV thru tree w ith 1 - 2' ext @ 86". No problerrs. 2/9/2008 *** WELL S/I ON ARRNAL *** PULLED B&R @ 11,297' SLM PULLED STA#2 BEK-DCK SHEAR VALVE @ 5233' SLM /SET STA#2 BK-DGLV @ 5233' SLM R3~FORMED MIT-IA 3000# ***PASSED*** PULLED 3.81" RHGM PLUG BODY @ 11,307' SLM DRIFTED TBG W/ 2 7/8" DMY GUN, TEL, S. BAILER LOCATED TBG TAIL @ 11,339' SLM (+21' =11,360' MD) TAGGED TD @ 11,807' CORRECTED DEPTH (STICKY ON BTM) RECOVERED SMALL AMOUNT OF CEMENT IN S. BAILER (NOTE ELMD TT IS NOT LOGGED, CORRECTED TO MD) '*' JOB CONTINUED ON 02-10-08 WSR *** 2/10/2008 *** CONTINUED FROM 2/9/08*** RIG DOWN SLICKLINE UNIT *** LEFT WELL SHUT IN *** 2/15/2008 ***WELL SHUT IN UPON ARRNAL*** INffVaL T/VO = 500/500/0 PSI. JEWELERY LOG FROM 11800' UP TO 10000' ELMD. TD FOUND AT 11801'. 4 PERF GUN RUNS. ALL PERFORATIONS MADE WITH 2-7/8" POWERJET OMEGA 6SPF, 60 DEG PHASE, 36" PENETRATION, 0.34" ENTRANCE HOLE PERFORATION INTERVALS TO SHOOT: 11477'-11495', 11499'-11506', 11511'-11518', 11524'-11532', 11538'-11548', 11562'-11567'. USED SLB USIT LOG DATED 01 NOV 07 FOR TIE IN (-1' TO TIE IN LOG TO =REFERENCE LOG - SLB MWD GR DATED 26 OCT 07) ***LOG CONTINUED ON FOLLOWING DAY*'* 2/16/2008 *********LOG CONTINUED FROM PREVIOUS DAY************* INfiIAL T/VO = 100/450/0 PSI. 4 PERF GUN RUNS IN TOTAL. ALL PERFORATIONS MADE WITH 2-7/8" PDWERJET OMEGA 6SPF, 60 DEG PHASE, 36" PENETRATION, 0.34" ENTRANCE HOLE GUN #4 PERFORATION MADE FROM: 11477' - 11495' USED SLB USIT LOG DATED 01 NOV 07 FOR TIE IN (-1' TO TIE IN LOG TO =REFERENCE LOG - SLB MWD GR DATED 26 OCT 07) SBHP SURVEY LOGGED AFTER PERFORATIONS. STOP COUNTS AT 11669', 11554', 11437', 11320'. FINAL T/VO = 250/450/0 PSI ***JOB COMPLETED*'* 3/5/2008 **** WELL S/I ON ARRNAL**** DRIFT W/ 2' 1 7/8" STEM, 3.5 CENT, XO, S. BAILER TO 3325' SLM. (NO SAMPLE) DRIFT W/ 2' * 1 7/8" STEM, XO, 2.25 CENT, S. BAILER TO 3325' SLM (BAILER FULL OF HYDRATES) ***** WELL LEFT SHUT IN AND TURNED OVER TO DSO ***** Print Date: 3/11/2008 Page 1 of 1 by _ = -f ~~ .~. `~~~~~~ S-126 Su Report Date: Odober 29, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: S-PAD / S-126 Well: S-126 Borehole: S-126 UWVAPI#: 500292336300 Survey Name /Date: S-126 /October 29, 2007 Tort /AHD / DDI / ERD ratio: 171.648° / 8708.47 ft / 6.401 / 1,231 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.35230418, W 149.03466946 Location Grid NIE Y/X: N 5979374.300 ftUS, E 618885.300 ftUS Grid Convergence Angle: +0.90913669° Grid Scale Factor: 0.99991606 Report Schlumberger Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 270.320° Vertical Section Origin: N 0.000 ft, E 0.000 tt TVD Reference Datum: Rotary Table TVD Reference Elevation: 67.00 ft relative to MSL Sea Bed /Ground Level Elevation: 38.50 ft relative to MSL Magnetic Declination: 23.394° Total Field Strength: 57648.174 nT Magnetic Dip: 80.912° Dedination Date: October 26, 2007 Magnetic Dedination Model: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.394° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft tt ft de 00 ft ftUS ftUS nit v.vv U.vv v.vv -bi.uu U. uV u.uu U.uV u.uu V.VU U.UU U.UU 5y/y~/4.:iU GYD CT DMS 100.00 0.19 13.18 33.00 100. 00 -0.04 0.17 0.17 0.16 0.04 0.19 5979374.46 200.00 0.16 57.20 133.00 200. 00 -0.19 0.46 0.44 0.40 0.19 0.13 5979374.70 300.00 0.19 6.33 233.00 300. 00 -0.33 0.74 0.72 0.64 0.33 0.15 5979374.94 400.00 1.73 262.36 332.98 399. 98 1.15 2.26 1.30 0.60 -1.15 1.79 5979374.88 500.00 6.76 276.05 432.68 499. 68 8.51 9.63 8.56 1.02 -8.50 5.10 5979375.19 600.00 9.37 275.24 531.68 598. 68 22.48 23.66 22.59 2.39 -22.46 2.61 5979376.33 700.00 11.09 269.13 630.09 697. 09 40.21 41.40 40.30 2.98 -40.19 2.03 5979376.65 MWD+IFR+MS 760.46 11.96 267.36 689.33 756. 33 52.28 53.48 52.33 2.61 -52.26 1.55 5979376.08 855.35 12.40 266.17 782.09 849. 09 72.26 73.50 72.26 1.47 -72.25 0.53 5979374.63 949.40 12.40 265.66 873.94 940. 94 92.39 93.70 92.39 0.04 -92.39 0.12 5979372.87 1044.00 14.79 263.88 965.89 1032. 89 114.52 115.93 114.55 -2.02 -114.53 2.56 5979370.46 1138.42 17.54 263.18 1056.56 1123. 56 140.61 142.21 140.73 -5.00 -140.64 2.92 5979367.07 1233.03 19.35 264.60 1146.31 1213. 31 170.36 172.14 170.60 -8.16 -170.41 1.97 5979363.43 1326.69 21.87 265.30 1233.97 1300. 97 203.18 205.11 203.55 -11.05 -203.25 2.70 5979360.02 1421.70 24.35 266.19 1321.35 1388. 35 240.35 242.40 240.83 -13.81 -240.43 2.64 5979356.68 1515.55 26.96 265.08 1405.94 1472. 94 280.84 283.03 281.45 -16.92 -280.94 2.83 5979352.93 1610.74 28.14 263.59 1490.33 1557. 33 324.62 327.05 325.44 -21.27 -324.75 1.44 5979347.88 1704.83 31.63 263.02 1571.90 1638. 90 371.14 373.92 372.26 -26.75 -371.30 3.72 5979341.66 1796.97 35.12 263.66 1648.83 1715. 83 421.45 424.60 422.90 -32.62 -421.64 3.81 5979335.00 1891.85 37.45 263.41 1725.31 1792. 31 477.20 480.75 479.01 -38.94 -477.43 2.46 5979327.79 1985.05 39.50 263.69 1798.27 1865. 27 534.78 538.73 536.97 -45.45 -535.04 2.21 5979320.37 2079.19 39.95 263.88 1870.68 1937. 68 594.56 598.90 597.12 -51.96 -594.86 0.50 5979312.91 liltitStSS.:iU N /U.;ibL:iV416 W 14y.U:i4(i6y46 618885.34 N 70.35230462 W 149.03466916 618885.49 N 70.35230527 W 149.03466790 618885.62 N 70.35230592 W 149.03466680 618884.14 N 70.35230583 W 149.03467879 618876.78 N 70.35230697 W 149.03473850 618862.80 N 70.35231070 W 149.03485185 618845.07 N 70.35231233 W 149.03499575 618833.01 N 70.35231130 W 149.03509376 618813.04 N 70.35230820 W 149.03525603 618792.93 N 70.35230427 W 149.0354 618770.83 N 70.35229866 W 149.0355 618744.76 N 70.35229053 W 149.03581 2 618715.06 N 70.35228187 W 149.03605295 618682.27 N 70.35227397 W 149.03631956 618645.14 N 70.35226645 W 149.03662146 618604.69 N 70.35225795 W 149.03695033 618560.96 N 70.35224604 W 149.03730599 618514.50 N 70.35223107 W 149.03768393 618464.27 N 70.35221504 W 149.03809261 618408.59 N 70.35219775 W 149.03854554 618351.09 N 70.35217996 W 149.03901331 618291.40 N 70.35216215 W 149.03949890 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-126\S-126\S-126\S-126 Generated 3/10/2008 3:41 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft it it de tMft ftUS ftUS n /J.Sy 41.45 261. 8/ 1 y4Z.Z4 2UUa.Z4 655.58 titiu.45 558.63 -5y. 61 -655. y3 "L11 59/93U4. 2y 1318230.46 N 70.35214124 W 149.03999472 2266.36 43.27 260. 81 2010.79 2077.79 717.32 722.95 721.03 -69. 04 -717. 72 2.11 5979293. 89 618168.83 N 70.35211549 W 149. 04049635 2361.11 46.73 259. 08 2077.78 2144.78 783.20 789.94 787.82 -80. 76 -783. 67 3.87 5979281. 12 618103.08 N 70.35208344 W 149. 04103176 2454.37 53.76 264. 41 2137.41 2204.41 854.03 861.57 859.37 -90. 87 -854. 55 8.72 5979269. 89 618032.37 N 70.35205579 W 149. 04160726 2548.59 55.73 266. 94 2191.80 2258.80 930.71 938.50 936.26 -96. 65 -931. 26 3.03 5979262. 89 617955.77 N 70.35203997 W 149. 04223001 2643.27 57.99 265. 89 2243.56 2310.56 1009.79 1017.78 1015.47 -101. 62 -1010 .38 2.56 5979256. 67 617876.75 N 70.35202638 W 149. 04287232 2739.92 60.34 266. 74 2293.09 2360.09 1092.57 1100.76 1098.41 -106. 95 -1093 .19 2.55 5979250. 03 617794.04 N 70.35201180 W 149. 04354462 2833.74 61.79 265. 32 2338.49 2405.49 1174.44 1182.86 1180.48 -112. 64 -1175. 09 2.04 5979243. 04 617712.24 N 70.35199621 W 149. 04420957 2927.61 63.20 267. 02 2381.84 2448.84 1257.48 1266.12 1263.70 -118. 19 -1258. 16 2.20 5979236. 17 617629.28 N 70.35198101 W 149. 04488396 3021.65 65.50 265. 48 2422.55 2489.55 1342.03 1350.89 1348.43 -123. 74 -1342. 74 2.86 5979229. 28 617544.81 N 70.35196579 W 149. 04557063 3116.15 65.96 264. 73 2461.39 2528.39 1427.82 1437.03 1434.58 -131. 10 -1428 .57 0.87 5979220. 57 617459.11 N 70.35194566 W 149. 046267 6 3210.04 66.24 265. 12 2499.43 2566.43 1513.28 1522.87 1520.42 -138. 69 -1514 .08 0.48 5979211. 62 617373.74 N 70.35192487 W 149. 0469t~ 3303.13 66.21 265. 10 2536.96 2603.96 1598.12 1608.06 1605.60 -145. 95 -1598 .96 0.04 5979203. 01 617289.00 N 70.35190499 W 149. 04765070 3396.44 65.83 264. 76 2574.88 2641.88 1683.00 1693.32 1690.86 -153. 49 -1683 .88 0.53 5979194. 13 617204.21 N 70.35188435 W 149. 04834013 3490.88 67.16 263. 50 2612.55 2679.55 1769.09 1779.92 1777.45 -162. 35 -1770 .02 1.87 5979183. 91 617118.23 N 70.35186009 W 149. 04903949 3585.81 67.05 263. 80 2649.48 2716.48 1855.95 1867.37 1864.89 -172. 02 -1856. 94 0.31 5979172. 86 617031.48 N 70.35183361 W 149. 04974509 3681.42 66.58 263. 84 2687.12 2754.12 1943.27 1955.26 1952.77 -181. 48 -1944. 32 0.49 5979162. 01 616944.27 N 70.35180770 W 149. 05045445 3776.31 66.14 263. 35 2725.17 2792.17 2029.60 2042.19 2039.68 -191. 18 -2030 .70 0.66 5979150. 95 616858.06 N 70.35178115 W 149. 05115574 3870.33 66.04 262. 78 2763.28 2830.28 2114.86 2128.14 2125.60 -201. 55 -2116 .02 0.56 5979139. 22 616772.92 N 70.35175273 W 149. 05184841 3966.51 66.46 262. 65 2802.01 2869.01 2202.12 2216.17 2213.59 -212. 72 -2203 .35 0.45 5979126. 67 616685.80 N 70.35172217 W 149. 05255732 4058.28 66.32 262. 75 2838.77 2905.77 2285.47 2300.26 2297.64 -223. 40 -2286 .75 0.18 5979114. 66 616602.58 N 70.35169291 W 149. 05323443 4153.30 68.06 263. 85 2875.60 2942.60 2372.40 2387.85 2385.21 -233. 62 -2373 .74 2.12 5979103. 07 616515.77 N 70.35166493 W 149. 05394060 4247.74 68.34 263. 99 2910.68 2977.68 2459.54 2475.53 2472.89 -242. 90 -2460 .93 0.33 5979092. 40 616428.74 N 70.35163948 W 149. 05464845 4341.41 68.55 263. 99 2945.09 3012.09 2546.13 2562.65 2560.01 -252. 03 -2547. 57 0.22 5979081. 91 616342.27 N 70.35161449 W 149. 05535181 4436.52 68.51 263. 97 2979.90 3046.90 2634.09 2651.16 2648.52 -261. 31 -2635 .59 0.05 5979071. 23 616254.41 N 70.35158904 W 149. 05606639 4529.96 66.63 264. 24 3015.55 3082.55 2719.95 2737.53 2734.88 -270. 18 -2721 .50 2.03 5979061. 00 616168.66 N 70.35156472 W 149. 05676381 4624.71 66.77 264. 25 3053.03 3120.03 2806.49 2824.55 2821.91 -278. 91 -2808 .09 0.15 5979050. 90 616082.23 N 70.35154080 W 149. 05746672 4720.88 66.66 264. 42 3091.05 3158.05 2894.34 2912.89 2910.24 -287. 63 -2895 .99 0.20 5979040. 79 615994.48 N 70.35151688 W 149. 05818034 4755.40 66.49 264. 09 3104.77 3171.77 2925.84 2944.56 2941.92 -290. 80 -2927 .51 1.01 5979037. 12 615963.02 N 70.35150819 W 149. 058 4836.41 65.49 263. 21 3137.73 3204.73 2999.34 3018.56 3015.91 -298 .98 -3001 .06 1.58 5979027. 77 615889.62 N 70.35148575 W 149. 4 0590 4906.08 65.14 264. 35 3166.83 3233.83 3062.23 3081.86 3079.21 -305 .84 -3063 .98 1.57 5979019. 92 615826.82 N 70.35146695 W 149. 05954409 5000.15 66.86 264. 76 3205.09 3272.09 3147.73 3167.80 3165.14 -313. 99 -3149 .53 1.87 5979010. 41 615741.42 N 70.35144458 W 149. 06023856 5094.99 67.23 265. 44 3242.08 3309.08 3234.69 3255.13 3252.46 -321. 45 -3236 .54 0.77 5979001. 57 615654.55 N 70.35142410 W 149. 06094492 5190.69 67.41 265. 29 3278.98 3345.98 3322.66 3343.43 3340.75 -328 .58 -3324 .55 0.24 5978993. 04 615566.67 N 70.35140450 W 149. 06165940 5284.90 67.38 265. 06 3315.19 3382.19 3409.29 3430.40 3427.71 -335 .90 -3411 .22 0.23 5978984. 35 615480.14 N 70.35138441 W 149. 06236294 5378.86 67.35 265. 77 3351.35 3418.35 3495.69 3517.12 3514.42 -342 .83 -3497 .66 0.70 5978976. 05 615393.82 N 70.35136536 W 149. 06306470 5473.77 67.22 265. 03 3388.00 3455.00 3582.92 3604.67 3601.96 -349 .85 -3584 .93 0.73 5978967. 64 615306.68 N 70.35134607 W 149. 06377313 5567.52 67.00 265. 47 3424.47 3491.47 3668.94 3691.04 3688.31 -357 .01 -3671 .00 0.49 5978959. 13 615220.75 N 70.35132642 W 149. 06447185 5660.58 67.10 264. 99 3460.76 3527.76 3754.30 3776.73 3774.00 -364. 13 -3756 .39 0.49 5978950. 65 615135.48 N 70.35130683 W 149. 06516510 5756.66 67.22 265. 57 3498.05 3565.05 3842.50 3865.28 3862.54 -371 .42 -3844 .64 0.57 5978941. 96 615047.37 N 70.35128681 W 149. 06588148 5848.90 66.85 265. 50 3534.04 3601.04 3927.14 3950.21 3947.45 -378 .03 -3929 .31 0.41 5978934. 01 614962.82 N 70.35126862 W 149. 06656884 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-126\S-126\S-126\S-126 Generated 3/10/2008 3:41 PM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft it ft tt ft de OOft ftUS ftUS Sy42.39 6/.Ul Z65.y/ 35/U.ti/ ati3/.ti/ 4U1L.88 4U3(i.L2 4U33.45 -3ti4. 43 -4U15.Uti U.49 59/tf9L(i.26 6148//.16 N 70.35125102 W 149. 06726517 6038.45 66.89 265.98 3608.28 3675. 28 4101.01 4124.61 4121.81 -390. 63 -4103.26 0.13 5978918. 65 614789.11 N 70.35123394 W 149. 06798095 6132.25 66.91 266.54 3645.09 3712. 09 4187.07 4210.89 4208.05 -396. 26 -4189.35 0.55 5978911. 66 614703.12 N 70.35121844 W 149. 06867987 6226.50 66.87 266.50 3682.08 3749. 08 4273.57 4297.58 4294.69 -401. 52 -4275.88 0.06 5978905. 03 614616.70 N 70.35120393 W 149. 06938230 6320.80 66.30 266.96 3719.55 3786. 55 4359.93 4384.11 4381.17 -406. 46 -4362.27 0.75 5978898. 72 614530.40 N 70.35119031 W 149. 07008364 6414.40 67.01 265.39 3756.64 3823. 64 4445.64 4470.05 4467.07 -412. 19 -4448.01 1.72 5978891. 63 614444.77 N 70.35117450 W 149. 07077969 6507.61 66.95 265.52 3793.09 3860. 09 4531.12 4555.84 4552.85 -418. 99 -4533.53 0.14 5978883. 47 614359.38 N 70.35115579 W 149. 07147391 6601.26 66.39 267.31 3830.19 3897. 19 4616.91 4641.83 4638.80 -424. 37 -4619.35 1.85 5978876. 73 614273.66 N 70.35114095 W 149. 07217059 6696.50 67.46 264.08 3867.52 3934. 52 4704.23 4729.44 4726.40 -430. 96 -4706.71 3.32 5978868. 76 614186.43 N 70.35112281 W 149. 07287974 6788.84 67.59 264.22 3902.82 3969. 82 4789.06 4814.77 4811.72 -439. 65 -4791.59 0.20 5978858. 72 614101.70 N 70.35109890 W 149. 07356878 6881.91 67.50 263.79 3938.37 4005. 37 4874.55 4900.78 4897.72 -448. 64 -4877.13 0.44 5978848. 38 614016.32 N 70.35107421 W 149. 07426 6977.31 67.36 264.33 3974.99 4041. 99 4962.12 4988.88 4985.81 -457. 75 -4964.75 0.54 5978837. 88 613928.86 N 70.35104915 W 149. 0749 7069.82 67.01 264.80 4010.86 4077. 86 5046.96 5074.15 5071.08 -465. 83 -5049.64 0.60 5978828. 46 613844.12 N 70.35102693 W 149. 07566356 7165.81 66.98 264.57 4048.37 4115. 37 5134.89 5162.50 5159.44 -474. 01 -5137.62 0.22 5978818. 88 613756.29 N 70.35100440 W 149. 07637773 7259.58 65.41 263.54 4086.22 4153. 22 5220.17 5248.29 5245.22 -482. 89 -5222.94 1.95 5978808. 64 613671.12 N 70.35097998 W 149. 07707039 7355.72 65.03 263.22 4126.51 4193. 51 5306.81 5335.58 5332.48 -492. 96 -5309.65 0.50 5978797. 21 613584.60 N 70.35095232 W 149. 07777422 7450.44 64.73 263.34 4166.72 4233. 72 5391.93 5421.34 5418.22 -502. 99 -5394.82 0.34 5978785. 82 613499.60 N 70.35092474 W 149. 07846561 7543.12 64.93 263.32 4206.14 4273. 14 5475.18 5505.22 5502.08 -512. 74 -5478.13 0.22 5978774. 76 613416.46 N 70.35089796 W 149. 07914189 7637.57 64.62 262.88 4246.39 4313. 39 5559.95 5590.66 5587.49 -523. 00 -5562.96 0.53 5978763. 15 613331.82 N 70.35086975 W 149. 07983045 7731.40 64.83 263.45 4286.46 4353. 46 5644.14 5675.51 5672.31 -533. 10 -5647.20 0.59 5978751. 72 613247.75 N 70.35084199 W 149. 08051429 7826.58 64.08 263.44 4327.50 4394. 50 5729.39 5761.39 5758.17 -542. 90 -5732.52 0.79 5978740. 57 613162.61 N 70.35081503 W 149. 08120682 7920.44 63.66 265.30 4368.84 4435. 84 5813.20 5845.65 5842.43 -551 .17 -5816.37 1.83 5978730. 97 613078.91 N 70.35079227 W 149. 08188752 8016.64 64.00 266.25 4411.27 4478. 27 5899.27 5931.99 5928.75 -557 .53 -5902.47 0.95 5978723. 24 612992.92 N 70.35077471 W 149. 08258647 8111.84 63.58 265.75 4453.31 4520. 31 5984.44 6017.40 6014.13 -563 .49 -5987.68 0.65 5978715. 94 612907.83 N 70.35075825 W 149. 08327812 8206.18 63.56 266.19 4495.30 4562. 30 6068.67 6101.88 6098.59 -569. 42 -6071.95 0.42 5978708. 66 612823.67 N 70.35074184 W 149. 08396220 8299.91 63.17 266.44 4537.32 4604. 32 6152.25 6185.67 6182.34 -574. 81 -6155.56 0.48 5978701. 95 612740.17 N 70.35072695 W 149. 08464092 8392.99 64.26 268.12 4578.55 4645. 55 6235.58 6269.12 6265.70 -578 .76 -6238.91 2.00 5978696. 68 612656.89 N 70.35071595 W 149. 08531759 8487.30 64.76 274.13 4619.16 4686. 16 6320.65 6354.23 6350.25 -577 .08 -6323.97 5.78 5978697. 01 612571.82 N 70.35072035 W 149. 08600812 8582.51 64.99 278.95 4659.61 4726. 61 6406.31 6440.43 6434.63 -567 .27 -6409.58 4.59 5978705. 46 612486.08 N 70.35074697 W 149. 0867 8677.68 62.09 281.10 4702.01 4769. 01 6490.28 6525.62 6516.92 -552 .46 -6493.47 3.66 5978718. 94 612401.97 N 70.35078723 W 149. 0873 8771.87 61.25 279.62 4746.71 4813. 71 6571.91 6608.52 6596.96 -537 .54 -6575.02 1.65 5978732. 56 612320.20 N 70.35082778 W 149. 08804642 8865.98 61.38 279.81 4791.88 4858 .88 6653.37 6691.08 6676.96 -523 .61 -6656.39 0.22 5978745. 19 612238.62 N 70.35086564 W 149. 08870714 8960.10 59.43 280.80 4838.36 4905 .36 6733.96 6772.92 6756.11 -508 .98 -6736.91 2.26 5978758. 55 612157.89 N 70.35090542 W 149. 08936089 9055.38 56.45 280.25 4888.93 4955. 93 6813.42 6853.66 6834.18 -494 .22 -6816.29 3.17 5978772. 04 612078.29 N 70.35094553 W 149. 09000542 9147.86 56.49 280.48 4940.02 5007. 02 6889.33 6930.75 6908.84 -480 .35 -6892.12 0.21 5978784. 70 612002.26 N 70.35098323 W 149. 09062116 9244.00 56.41 280.52 4993.15 5060. 15 6968.20 7010.87 6986.45 -465 .75 -6970.91 0.09 5978798. 05 611923.26 N 70.35102292 W 149. 09126083 9337.95 56.25 280.57 5045.24 5112 .24 7045.14 7089.06 7062.22 -451 .44 -7047.77 0.18 5978811. 14 611846.18 N 70.35106182 W 149. 09188498 9433.85 56.30 282.60 5098.49 5165 .49 7123.36 7168.82 7139.19 -435 .43 -7125.90 1.76 5978825. 91 611767.81 N 70.35110537 W 149. 09251937 9527.02 56.11 281.32 5150.31 5217 .31 7199.19 7246.25 7213.85 -419 .38 -7201.65 1.16 5978840. 75 611691.83 N 70.35114901 W 149. 09313441 9619.20 55.67 282.21 5202.01 5269.01 7274.00 7322.57 7287.56 -403 .82 -7276.37 0.93 5978855. 12 611616.88 N 70.35119132 W 149. 09374111 9713.29 50.82 283.86 5258.29 5325 .29 7347.51 7397.93 7359.96 -386 .86 -7349.79 5.34 5978870 .92 611543.21 N 70.35123747 W 149. 09433732 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-126\S-126\S-126\S-126 Generated 3/10/2008 3:41 PM Page 3 of 4 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft fl ft ft ft de 100 ft ftUS ftUS 9805.65 46.07 285. 56 5319.54 5386.54 7414.45 7467.02 7425.82 -369 .35 -7416 .62 5.32 5978887.36 9899.20 41.79 284. 88 5386.90 5453.90 7477.15 7531.91 7487.52 -352 .30 -7479 .23 4.60 5978903. 41 9993.58 39.75 284. 44 5458.38 5525.38 7536.86 7593.54 7546.37 -336 .70 -7538 .85 2.18 5978918. 06 10088.54 39.57 284. 63 5531.48 5598.48 7595.61 7654.14 7604.32 -321 .49 -7597 .52 0.23 5978932. 34 10181.96 39.21 284. 67 5603.68 5670.68 7653.04 7713.43 7661.01 -306 .50 -7654 .88 0.39 5978946. 42 10276.29 38.92 285. 04 5676.92 5743.92 7710.59 7772.88 7717.83 -291 .26 -7712 .34 0.39 5978960. 75 10369.36 42.28 288. 19 5747.58 5814.58 7768.68 7833.43 7775.16 -273 .89 -7770 .33 4.23 5978977. 19 10464.12 41.80 288. 18 5817.96 5884.96 7829.08 7896.88 7834.74 -254 .09 -7830 .62 0.51 5978996. 03 10560.59 41.41 288. 77 5890.09 5957.09 7889.95 7960.94 7894.84 -233 .79 -7891 .37 0.57 5979015. 36 10655.24 41.19 288. 41 5961.20 6028.20 7949.27 8023.41 7953.46 -213 .87 -7950 .58 0.34 5979034. 33 10748.11 40.80 288. 50 6031.30 6098.30 8007.16 8084.33 8010.74 -194 .59 -8008 .37 0.42 5979052. 70 10842.95 38.77 287. 62 6104.17 6171.17 8064.96 8145.01 8067.98 -175 .77 -8066 .06 2.22 5979070. 60 10937.03 36.01 287. 00 6178.92 6245.92 8119.58 8202.14 8122.15 -158 .76 -8120 .60 2.96 5979086. 74 11031.20 33.64 285. 62 6256.21 6323.21 8171.27 8255.91 8173.46 -143 .64 -8172 .20 2.65 5979101. 03 11125.06 32.96 285. 51 6334,66 6401.66 8220.99 8307.44 8222.86 -129 .81 -8221 .84 0.73 5979114. 07 11219.30 32.16 286.02 6414.09 6481.09 8269.87 8358.16 8271.46 -116.04 -8270.65 0.90 5979127.07 11313.21 31.57 285.51 6493.85 6560.85 8317.66 8407.73 8318.99 -102.57 -8318.36 0.69 5979139.78 11408.34 30.99 285.60 6575.15 6642.15 8365.32 8457.13 8366.42 -89.32 -8365.95 0.61 5979152.27 11503.16 30.66 285.06 6656.57 6723.57 8412.24 8505.71 8413.15 -76.47 -8412.80 0.45 5979164.37 11597.08 30.37 285.44 6737.49 6804.49 8458.32 8553.40 8459.05 -63.93 -8458.81 0.37 5979176.18 11691.71 29.94 285.61 6819.31 6886.31 8504.20 8600.94 8504.77 -51.21 -8504.62 0.46 5979188.17 11786.47 29.51 285.82 6901.60 6968.60 8549.50 8647.92 8549.93 -38.48 -8549.84 0.47 5979200.18 Last Survey 11834.66 29.31 285.99 6943.58 7010.58 8572.29 8671.59 8572.66 -32.00 -8572.60 0.45 5979206.30 TD (Projected) 11910.00 29.31 285.99 7009.28 7076.28 8607.80 8708.47 8608.08 -21.84 -8608.06 0.00 5979215.90 Survey Type: Definitive Survey NOTES: GYD-CT-DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot s urveys with continuou s tool (RGS-CT) in drill-pipe. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Leaal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 3171 FSL 4565 FEL S35 T12N R12E UM 5979374.30 618885.30 BHL : 3144 FSL 2613 FEL S33 T12N R12E UM 5979215.90 610279.41 611476.11 N 70.35128512 W 149.09488005 611413.24 N 70.35133152 W 149.09538846 611353.39 N 70.35137398 W 149.09587261 611294.49 N 70.35141537 W 149.09634901 611236.91 N 70.35145618 W 149.09681478 611179.22 611120.96 611060.37 610999.31 610939.79 610881.71 610823.73 610768.94 610717.11 610667.26 610618.24 610570.33 610522.54 610475.49 610429.29 610383.30 610337.88 610315.02 610279.41 N 70.35149765 W 149.09728139 N 70.35154493 W 149.09775239 N 70.35159886 W 149.09824199 N 70.35165413 W 149.09873539 N 70.35170837 W 149.09921625 N 70.35176089 W 149.0996 N 70.35181214 W 149.1001 N 70.35185844 W 149.10059699 N 70.35189959 W 149.10101605 N 70.35193722 W 149.10141918 N 70.35197471 W 149.10181558 N 70.35201137 W 149.10220305 N 70.35204740 W 149.10258949 N 70.35208236 W 149.10297003 N 70.35211648 W 149.10334368 N 70.35215110 W 149.10371565 N 70.35218572 W 149.10408297 N 70.35220337 W 149.10426779 N 70.35223101 W 149.10455573 r~ L J SunreyEditor Ver SP 2.1 Bld( doc40x_100) S-126\S-126\S-126\S-126 Generated 3/10/2008 3:41 PM Page 4 of 4 o2/2a1os ~Cl~llillb~t'I~~~ NO. 4612 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Aurora,GNI,Pt.Mac,Milne Pt,Endicott Wall .Inh if Inn Ilacr_rinfinn rlafa RI [`nlnr Ctrl 15-25A 12014000 LDL 1 Cp ~ 02/20/08 1 1 A-12A 11963077 MCNL sr 3 01119108 1 1 GNI-04 12031448 TEMP SURVEY (REVISED) ~~- ~ (p 01122108 1 1 P2-32 11968730 USIT - - ~- 02/13/08 1 1 17-02 11996384 USIT /~Q - ~' 02/17108 1 1 Y-07A 11962781 SCMT '-}- / O # 02/03/08 1 1 P2-58 12031456 USIT /~j~ - ~/ 02125108 1 1 MPH-12 12005205 MEM INJ PROFILE ~ _ j''}Q tt ~ 02/15/08 1 1 4-14/R-34 11975755 USIT V=e ~ 02/25/08 1 1 S-126 11968731 JEWELRY/PERF/SBHP ~" ~ 02/15108 1 1 YLtASt AGKNUWLtUGt KtGt1Y1 t3Y SIGNING ANU KtiUKNING VNt I.VYY tAl:Ff IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. _ Anchorage, Alaska 99508 Date Delivered: ~` ; /1~ 1i ~~}/y;7 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth ~ Received by: 12119/07 • Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4526 Company: Alaska Oil 8 Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris, Aurora Date BL Color CD W-214 S-126 11855826 11594528 USIT ISOLATION SCANNER REVISED 11119107 11101107 1 1 5-126 11594528 CH EDIT PDC ISOLATION SCANNER 11101/07 1 5-126 40015989 OH MWDILWD EDIT - 10128107 2 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH -i O: BP Exploration (Alaska) Inc. Petrotechnical Data Cenler LR2-1 ~ - - 900 E Benson Blvd. ~ ~' `'i Anchorage AK 99508-4254 ,, __ - ...-, R9,~.f ~~ Date Delivered: ~.~p_~(,~~ .~ ~~ I9 ~j' ~tld7i^ii+')y' Schlumberger-DCS 2525 Gambell Sl, Suite 400 Anchorage, AK 99503-2838 ~ ATTN: Belh J Received by: gy data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 November 13, 2007 State of Alaska - AOGCC Attn:. Christine Mahnken 333 W. 7th Ave, Suite 1.00 Anchorage, Alaska 99501 Re: S-Pad, Well #S-126 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Shoup North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation C~ gy tlata Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP S Pad #S-126 Prudhoe Bay, AK AK1' 007G_553 21 Oct 2007 Serving the Worldwide Energy Industry with Precision Survey Instrumentation ~ n~ - ®°~~ A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) 1NC Lease: S Pad Well: S-126, Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1007G 553 Run Date: 21 Oct 2007 Surveyor: Michael Villarreal Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.352305 deg. N Longitude: 149.034669 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey BP Exploration (Alaska) Inc Lease: S Pad Well: S-126 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1007G 553 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg. min. deg./ feet feet deg. 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0 - 723 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 5" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. 100.00 0.19 13.18 N 13 11 E 200.00 0.16 57.20 N 57 12 E 263.00 0.31 19.65 N 19 39 E 300.00 0.19 6.33 N 6 20 E 400.00 1.73 262.36 S 82 22 W 500.00 6.76 276.05 N 83 57 W 600.00 9.37 275.24 N 84 46 W 700.00 11.09 269.13 S 89 8 W 723.00 11.85 266.50 S 86 30 W Final Station Closure: Distance: 44.81 ft Az: 273.74 deg. HORIZONTAL COORDINATES feet 0.00 N 0.00 E 0.19 100.00 0.2 13.2 0.16 N 0.04 E 0.14 200.00 0.4 26.1 0.40 N 0.20 E 0.32 263.00 0.7 28.4 0.61 N 0.33 E 0.35 300.00 0.8 25.9 0.76 N 0.37 E 1.79 399.98 1.3 303.0 0.72 N 1.11 W 5.09 499.68 8.5 277.7 1.14 N 8.47 W 2.61 598.68 22.6 276.4 2.51 N 22.42 W 2.03 697.09 40.3 274.4 3.10 N 40.14 W 4.01 719.63 44.8 273.7 2.92 N 44.71 W 2 • • BP Exploration (Alaska) Inc - Wetl: S Pad S-126 Location: Nabors #9ES, Prudhoe Bay, Alaska Inrun Gyrodata AK1007G_553 DEFINITIVE 3.0 ~TTOM HO ~CATED D: 723.00 2.5 2.0 z 1.5 O z 1.0 0.5 • -45 -40 -35 -30 -25 -20 -15 -10 -5 0 FASTING (ft) BP Exploration (Alaska) Inc Well: S Pad 5-126 Location: Nabors #9ES, Prudhoe Bay, Alaska 10 9 8 7 0 0 T-, 6 v~ a~ -~ ~. ~ 5 w w v} J 4 C7 O 3 2 1 0 Inrun Gyrodata AK1007G_553 DEFINITIVE LOCATED MD: 723.00 ~~ • 100 200 300 400 500 600 700 800 MEASURED DEPTH (ft) BP Exploration (Alaska) Inc Well: S Pad S-126 Location: Nabors #9ES, Prudhoe Bay, Alaska 12 11 10 9 8 z 7 O Q z 6 J U Z 5 4 3 2 0 Inrun Gyrodata AK1007G_553 DEFINITIVE BOTTOM H L CA LE MD: 723.00 i 10 0 20 0 30 0 40 0 50 0 60 0 70 0 A0 0 MEASURED DEPTH (ft) 11 /08/07 i Schfumfrerger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job tl Log Description NO. 4487 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Aurora Orion Date BL Color CD 5-201 5-126 11676972 11594528 LDL ISOLATION SCANNER 11/07107 11101107 1 1 V-205 40014729 OH MWDILWD EDIT / 01129107 2 1 V-205L1 40014729 OH MWDILWD EDIT 02/03107 1 1 V-205L2 40014729 OH MWDILWD EDIT - 02I12I07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: Schlumberger-DCS 2525 Gambell St Stilte 440 Anchorage, AK 99503-2 8 ~ P.l ATTN: Beth -' - Receivetl by: ~~~6't~-)L~c_~-j` O J SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ...............: Engineer .................. COUNTY :................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ BP Alaska Exploration Aurora 5-126 50-02923363-00 J. Wilson North Slope Borough Alaska ethods------------- Minimum curvature Mason & Taylor 29-Oct-2007 09:43:58 Spud date ................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 19-Oct-07 29-Oct-07 129 0.00 ft 11910.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 19-Oct-2007 Magnetic field strength..: 57648.03 GAMA Magnetic dec (+E/W-).....: 23.41 degrees Magnetic dip .............: 80.91 degrees ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drillers Depth GL above permanent.......: 38.87 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 67.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 270.32 degrees [(c)2007 IDEAL ID12_OC_13] ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 57648.00 GAMA 80.91 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.41 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.41 .degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ ~-k^~ ti~`I ~ ~ ?nab ~IA~k~ ~~1 ~ (~~' ~~-~~ ~~~mi~cn(~ ~-t'char+~~~ • • ORIGINAL SCHLUMBERGER Survey Report 29-Oct-2007 09:43:58 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 265.43 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.19 13.18 100.00 100.00 -0.04 0.16 0.04 0.17 13.18 0.19 BP _GYD CT DMS 3 200.00 0.16 57.20 100.00 200.00 -0.19 0.40 0.19 0.44 25.84 0.13 BP _GYD CT DMS 4 300.00 0.19 6.33 100.00 300.00 -0.33 0.64 0.33 0.72 27.22 0.15 BP _GYD CT DMS 5 400.00 1.73 262.36 100.00 399.98 1.15 0.60 -1.15 1.30 297.69 1.79 BP GYD CT DMS 6 500.00 6.76 276.05 100.00 499.68 8.51 1.02 -8.50 8.56 276.86 5.10 BP _GYD CT DMS 7 600.00 9.37 275.24 100.00 598.68 22.48 2.39 -22.46 22.59 276.07 2.61 BP _GYD CT DMS 8 700.00 11.09 269.13 100.00 697.09 40.21 2.98 -40.19 40.30 274.25 2.03 BP _GYD CT DMS 9 760.46 11.96 267.36 60.46 756.33 52.28 2.61 -52.26 52.33 272.86 1.55 BP _MWD+IFR+MS 10 855.35 12.40 266.17 94.89 849.09 72.26 1.47 -72.25 72.26 271.17 0.53 BP MWD+IFR+MS 11 949.40 12.40 265.66 94.05 940.94 92.39 0.04 -92.39 92.39 270.02 0.12 BP _MWD+IFR+MS 12 1044.00 14.79 263.88 94.60 1032.88 114.52 -2.02 -114.53 114.55 268.99 2.56 BP _MWD+IFR+MS 13 1138.42 17.54 263.18 94.42 1123.56 140.61 -5.00 -140.64 140.73 267.97 2.92 BP _MWD+IFR+MS 14 1233.03 19.35 264.60 94.61 1213.31 170.36 -8.16 -170.41 170.60 267.26 1.97 BP _MWD+IFR+MS 15 1326.69 21.87 265.30 93.66 1300.97 203.18 -11.05 -203.25 203.55 266.89 2.70 BP MWD+IFR+MS 16 1421.70 24.35 266.19 95.01 1388.35 240.35 -13.81 -240.43 240.83 266.71 2.64 BP _MWD+IFR+MS 17 1515.55 26.96 265.08 93.85 1472.94 280.84 -16.92 -280.94 281.45 266.55 2.83 BP _MWD+IFR+MS 18 1610.74 28.14 263.59 95.19 1557.33 324.62 -21.27 -324.75 325.44 266.25 1.44 BP _MWD+IFR+MS 19 1704.83 31.63 263.02 94.09 1638.90 371.14 -26.75 -371.30 372.26 265.88 3.72 BP _MWD+IFR+MS 20 1796.97 35.12 263.66 92.14 1715.83 421.45 -32.62 -421.64 422.90 265.58 3.81 BP MWD+IFR+MS 21 1891.85 37.45 263.41 94.88 1792.31 477.20 -38.94 -477.43 479.01 265.34 2.46 BP _MWD+IFR+MS 22 1985.05 39.50 263.69 93.20 1865.27 534.78 -45.45 -535.04 536.97 265.14 2.21 BP _MWD+IFR+MS 23 2079.19 39.95 263.88 94.14 1937.67 594.56 -51.96 -594.86 597.12 265.01 0.50 BP _MWD+IFR+MS 24 2173.59 41.45 261.87 94.40 2009.24 655.58 -59.61 -655.93 658.63 264.81 2.11 BP _MWD+IFR+MS 25 2266.36 43.27 260.81 92.77 2077.79 717.32 -69.04 -717.72 721.03 264.51 2.11 BP MWD+IFR+MS 26 2361.11 46.73 259.08 94.75 2144.78 783.20 -80.76 -783.67 787.82 264.12 3.87 BP _MWD+IFR+MS 27 2454.37 53.76 264.41 93.26 2204.41 854.03 -90.87 -854.55 859.37 263.93 8.72 BP _MWD+IFR+MS 28 2548.59 55.73 266.94 94.22 2258.80 930.71 -96.65 -931.26 936.26 264.07 3.03 BP _MWD+IFR+MS 29 2643.27 57.99 265.89 94.68 2310.56 1009.79 -101.62 - 1010.38 1015.47 264.26 2.56 BP _MWD+IFR+MS 30 2739.92 60.34 266.74 96.65 2360.09 1092.57 -106.95 -1093.19 1098.41 264.41 2.55 BP MWD+IFR+MS • C~ [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 29-Oct-2007 09:43:58 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2833.74 61.79 265.32 93.82 2405.49 1174.45 -112.64 -1175.09 1180.48 264.52 2.04 BP _MWD+IFR+MS 32 2927.61 63.20 267.02 93.87 2448.84 1257.48 -118.19 -1258.16 1263.70 264.63 2.20 BP _MWD+IFR+MS 33 3021.65 65.50 265.48 94.04 2489.55 1342.03 -123.74 -1342.74 1348.43 264.73 2.86 BP _MWD+IFR+MS 34 3116.15 65.96 264.73 94.50 2528.39 1427.82 -131.10 -1428.57 1434.58 264.76 0.87 BP _MWD+IFR+MS 35 3210.04 66.24 265.12 93.89 2566.43 1513.28 -138.69 -1514.08 1520.42 264.77 0.48 BP MWD+IFR+MS 36 3303.13 66.21 265.10 93.09 2603.96 1598.12 -145.95 -1598.96 1605.60 264.78 0.04 BP _MWD+IFR+MS 37 3396.44 65.83 264.76 93.31 2641.88 1683.00 -153.49 -1683.88 1690.86 264.79 0.53 BP _MWD+IFR+MS 38 3490.88 67.16 263.50 94.44 2679.55 1769.09 -162.35 -1770.02 1777.45 264.76 1.87 BP _MWD+IFR+MS 39 3585.81 67.05 263.80 94.93 2716.48 1855.95 -172.02 -1856.94 1864.89 264.71 0.31 BP _MWD+IFR+MS 40 3681.42 66.58 263.84 95.61 2754.12 1943.27 -181.48 -1944.32 1952.77 264.67 0.49 BP MWD+IFR+MS 41 3776.31 66.14 263.35 94.89 2792.17 2029.60 -191.18 -2030.70 2039.68 264.62 0.66 BP _MWD+IFR+MS 42 3870.33 66.04 262.78 94.02 2830.28 2114.86 -201.55 -2116.02 2125.60 264.56 0.56 BP _MWD+IFR+MS 43 3966.51 66.46 262.65 96.18 2869.01 2202.12 -212.72 -2203.35 2213.59 264.49 0.45 BP _MWD+IFR+MS 44 4058.28 66.32 262.75 91.77 2905.77 2285.47 -223.40 -2286.75 2297.64 264.42 0.18 BP _MWD+IFR+MS 45 4153.30 68.06 263.85 95.02 2942.60 2372.40 -233.62 -2373.74 2385.21 264.38 2.12 BP MWD+IFR+MS 46 4247.74 68.34 263.99 94.44 2977.68 .2459.54 -242.90 -2460.93 2472.89 264.36 0.33 BP _MWD+IFR+MS 47 4341.41 68.55 263.99 93.67 3012.09 2546.13 -252.02 -2547.57 2560.01 264.35 0.22 BP _MWD+IFR+MS 48 4436.52 68.51 263.97 95.11 3046.90 2634.09 -261.31 -2635.59 2648.52 264.34 0.05 BP _MWD+IFR+MS 49 4529.96 66.63 264.24 93.44 3082.55 2719.95 -270.18 -2721.50 2734.88 264.33 2.03 BP _MWD+IFR+MS 50 4624.71 66.77 264.25 94.75 3120.03 2806.49 -278.91 -2808.09 2821.91 264.33 0.15 BP MWD+IFR+MS 51 4720.88 66.66 264.42 96.17 3158.05 2894.34 -287.63 -2895.99 2910.24 264.33 0.20 BP _MWD+IFR+MS 52 4755.40 66.49 264.09 34.52 3171.77 2925.84 -290.80 -2927.51 2941.92 264.33 1.01 BP _MWD+IFR+MS 53 4836.41 65.49 263.21 81.01 3204.73 2999.34 -298.98 -3001.05 3015.91 264.31 1.58 BP _MWD+IFR+MS 54 4906.08 65.14 264.35 69.67 3233.83 3062.23 -305.84 -3063.98 3079.21 264.30 1.57 BP _MWD+IFR+MS 55 5000.15 66.86 264.76 94.07 3272.09 3147.73 -313.99 -3149.53 3165.14 264.31 1.87 BP MWD+IFR+MS 56 5094.99 67.23 265.44 94.84 3309.08 3234.69 -321.45 -3236.54 3252.46 264.33 0.77 BP _MWD+IFR+M5 57 5190.69 67.41 265.29 95.70 3345.98 3322.66 -328.58 -3324.55 3340.75 264.36 0.24 BP _MWD+IFR+MS 58 5284.90 67.38 265.06 94.21 3382.19 3409.29 -335.90 -3411.21 3427.71 264.38 0.23 BP _MWD+IFR+MS 59 5378.86 67.35 265.77 93.96 3418.35 3495.69 -342.83 -3497.66 3514.42 264.40 0.70 BP _MWD+IFR+MS 60 5473.77 67.22 265.03 94.91 3455.00 3582.92 -349.85 -3584.93 3601.96 264.43 0.73 BP MWD+IFR+MS r1 ~J • [(c)2007 IDEAL ID12_OC_13] • SCHLUMBERGER Survey Report 29-Oct-2007 09:43:58 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5567.52 67.00 265.47 93.75 3491.47 3668.94 -357.00 -3671.00 3688.31 264.45 0.49 BP _MWD+IFR+MS 62 5660.58 67.10 264.99 93.06 3527.75 3754.30 -364.13 -3756.39 3774.00 264.46 0.49 BP _MWD+IFR+MS 63 5756.66 67.22 265.57 96.08 3565.05 3842.50 -371.42 -3844.64 3862.54 264.48 0.57 BP _MWD+IFR+MS 64 5848.90 66.85 265.50 92.24 3601.04 3927.14 -378.03 -3929.31 3947.45 264.50 0.41 BP _MWD+IFR+MS 65 5942.39 67.01 265.97 93.49 3637.67 4012.88 -384.43 -4015.08 4033.45 264.53 0.49 BP _MWD+IFR+MS 66 6038.45 66.89 265.98 96.06 3675.28 4101.01 -390.63 -4103.26 4121.81 264.56 0.13 BP _MWD+IFR+MS 67 6132.25 66.91 266.54 93.80 3712.08 4187.07 -396.26 -4189.35 4208.05 264.60 0.55 BP _MWD+IFR+MS 68 6226.50 66.87 266.50 94.25 3749.08 4273.57 -401.52 -4275.88 4294.69 264.64 0.06 BP _MWD+IFR+MS 69 6320.80 66.30 266.96 94.30 3786.55 4359.93 -406.46 -4362.27 4381.17 264.68 0.75 BP _MWD+IFR+MS 70 6414.40 67.01 265.39 93.60 3823.64 4445.64 -412.19 -4448.01 4467.07 264.71 1.72 BP _MWD+IFR+MS 71 6507.61 66.95 265.52 93.21 3860.09 4531.12 -418.99 -4533.53 4552.85 264.72 0.14 BP _MWD+IFR+MS 72 6601.26 66.39 267.31 93.65 3897.18 4616.91 -424.37 -4619.35 4638.80 264.75 1.85 BP _MWD+IFR+MS 73 6696.50 67.46 264.08 95.24 3934.52 4704.23 -430.96 -4706.71 4726.40 264.77 3.32 BP _MWD+IFR+MS 74 6788.84 67.59 264.22 92.34 3969.82 4789.06 -439.65 -4791.59 4811.72 264.76 0.20 BP _MWD+IFR+MS 75 6881.91 67.50 263.79 93.07 4005.37 4874.55 -448.64 -4877.13 4897.72 264.74 0.44 BP MWD+IFR+MS 76 6977.31 67.36 264.33 95.40 4041.98 4962.12 -457.75 -4964.75 4985.81 264.73 0.54 BP _MWD+IFR+MS 77 7069.82 67.01 264.80 92.51 4077.86 5046.96 -465.83 -5049.64 5071.08 264.73 0.60 BP _MWD+IFR+MS 78 7165.81 66.98 264.57 95.99 4115.37 5134.89 -474.01 -5137.62 5159.44 264.73 0.22 BP _MWD+IFR+MS 79 7259.58 65.41 263.54 93.77 4153.22 5220.16 -482.89 -5222.94 5245.22 264.72 1.95 BP_MWD+IFR+MS 80 7355.72 65.03 263.22 96.14 4193.51 5306.81 -492.96 -5309.65 5332.48 264.70 0.50 BP MWD+IFR+MS 81 7450.44 64.73 263.34 94.72 4233.72 5391.93 -502.99 -5394.82 5418.22 264.67 0.34 BP _MWD+IFR+MS 82 7543.12 64.93 263.32 92.68 4273.14 5475.18 -512.74 -5478.13 5502.08 264.65 0.22 BP _MWD+IFR+MS 83 7637.57 64.62 262.88 94.45 4313.39 5559.95 -523.00 -5562.96 5587.49 264.63 0.53 BP _MWD+IFR+MS 84 7731.40 64.83 263.45 93.83 4353.46 5644.14 -533.10 -5647.20 5672.31 264.61 0.59 BP _MWD+IFR+MS 85 7826.58 64.08 263.44 95.18 4394.50 5729.39 -542.90 -5732.51 5758.17 264.59 0.79 BP MWD+IFR+MS 86 7920.44 63.66 265.30 93.86 4435.84 5813.20 -551.17 -5816.37 5842.43 264.59 1.83 BP_MWD+IFR+MS 87 8016.64 64.00 266.25 96.20 4478.27 5899.27 -557.53 -5902.47 5928.75 264.60 0.95 BP _MWD+IFR+MS 88 8111.84 63.58 265.75 95.20 4520.31 5984.43 -563.49 -5987.67 6014.13 264.62 0.65 BP _MWD+IFR+MS 89 8206.18 63.56 266.19 94.34 4562.30 6068.67 -569.42 -6071.94 6098.59 264.64 0.42 BP _MWD+IFR+MS 90 8299.91 63.17 266.44 93.73 4604.32 6152.25 -574.81 -6155.56 6182.33 264.67 0.48 BP MWD+IFR+MS • • [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 29-Oct-2007 09:43:58 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8392.99 64.26 268.12 93.08 4645.55 6235.58 -578.76 -6238.91 6265.70 264.70 2.00 BP_MWD+IFR+MS 92 8487.30 64.76 274.13 94.31 4686.16 6320.65 -577.08 -6323.97 6350.25 264.79 5.78 BP_MWD+IFR+MS 93 8582.51 64.99 278.95 95.21 4726.61 6406.31 -567.27 -6409.58 6434.63 264.94 4.59 BP_MWD+IFR+MS 94 8677.68 62.09 281.10 95.17 4769.01 6490.28 -552.46 -6493.46 6516.92 265.14 3.66 BP_MWD+IFR+MS 95 8771.87 61.25 279.62 94.19 4813.71 6571.91 -537.54 -6575.02 6596.95 265.33 1.65 BP MWD+IFR+MS 96 8865.98 61.38 279.81 94.11 4858.88 6653.36 -523.61 -6656.39 6676.96 265.50 0.22 BP_MWD+IFR+MS 97 8960.10 59.43 280.80 94.12 4905.37 6733.96 -508.98 -6736.91 6756.11 265.68 2.26 BP_MWD+IFR+MS 98 9055.38 56.45 280.25 95.28 4955.94 6813.42 -494.22 -6816.29 6834.18 265.85 3.17 BP_MWD+IFR+MS 99 9147.86 56.49 280.48 92.48 5007.02 6889.33 -480.35 -6892.12 6908.84 266.01 0.21 BP_MWD+IFR+MS 100 9244.00 56.41 280.52 96.14 5060.15 6968.19 -465.75 -6970.90 6986.45 266.18 0.09 BP MWD+IFR+MS 101 9337.95 56.25 280.57 93.95 5112.24 7045.14 -451.44 -7047.77 7062.22 266.33 0.18 BP_MWD+IFR+MS 102 9433.85 56.30 282.60 95.90 5165.49 7123.36 -435.43 -7125.90 7139.19 266.50 1.76 BP_MWD+IFR+MS 103 9527.02 56.11 281.32 93.17 5217.31 7199.19 -419.38 -7201.65 7213.85 266.67 1.16 BP_MWD+IFR+MS 104 9619.20 55.67 282.21 92.18 5269.01 7273.99 -403.82 -7276.36 7287.56 266.82 0.93 BP_MWD+IFR+MS 105 9713.29 50.82 283.86 94.09 5325.29 7347.51 -386.86 -7349.79 7359.96 266.99 5.34 BP MWD+IFR+MS 106 9805.65 46.07 285.56 92.36 5386.54 7414.44 -369.35 -7416.62 7425.81 267.15 5.32 BP_MWD+IFR+MS 107 9899.20 41.79 284.88 93.55 5453.90 7477.15 -352.30 -7479.23 7487.52 267.30 4.60 BP_MWD+IFR+MS 108 9993.58 39.75 284.44 94.38 5525.38 7536.85 -336.70 -7538.85 7546.37 267.44 2.18 BP_MWD+IFR+MS 109 10088.54 39.57 284.63 94.96 5598.48 7595.60 -321.49 -7597.52 7604,32 267.58 0.23 BP_MWD+IFR+M5 110 10181.96 39.21 284.67 93.42 5670.68 7653.04 -306.50 -7654.87 7661,01 267.71 0.39 BP MWD+IFR+MS 111 10276.29 38.92 285.04 94.33 5743.92 7710.59 -291.26 -7712.33 7717.83 267.84 0.39 BP_MWD+IFR+MS 112 10369.36 42.28 288.19 93.07 5814.58 7768.68 -273.89 -7770.33 7775.16 267.98 4.23 BP_MWD+IFR+MS 113 10464.12 41.80 288.18 94.76 5884.96 7829.08 -254.09 -7830.62 7834.74 268.14 0.51 BP_MWD+IFR+MS 114 10560.59 41.41 288.77 96.47 5957.09 7889.94 -233.79 -7891.37 7894.83 268.30 0.57 BP_MWD+IFR+MS 115 10655.24 41.19 288.41 94.65 6028.20 7949.26 -213.87 -7950.58 7953.46 268.46 0.34 BP MWD+IFR+MS 116 10748.11 40.80 288.50 92.87 6098.30 8007.16 -194.59 -8008.37 8010.73 268.61 0.42 BP_MWD+IFR+MS 117 10842.95 38.77 287.62 94.84 6171.17 8064.95 -175.77 -8066.06 8067.98 268.75 2.22 BP_MWD+IFR+MS 118 10937.03 36.01 287.00 94.08 6245.92 8119.58 -158.76 -8120.59 8122.15 268.88 2.96 BP_MWD+IFR+MS 119 11031.20 33.64 285.62 94.17 6323.21 8171.27 -143.64 -8172.20 8173.46 268.99 2.65 BP_MWD+IFR+MS 120 11125.06 32.96 285.51 93.86 6401.66 8220.98 -129.81 -8221.84 8222.86 269.10 0.73 BP MWD+IFR+MS • [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 29 -Oct-2007 09:43:58 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 11219,30 32.16 286.02 94.24 6481.09 8269.87 -116.04 - 8270.65 8271.46 269.20 0.90 BP_MWD+IFR+MS 122 11313.21 31.57 285.51 93.91 6560.85 8317.66 -102.57 - 8318.36 8318.99 269.29 0.69 BP_MWD+IFR+MS 123 11408.34 30.99 285.60 95.13 6642.15 8365.31 -89.32 - 8365.94 8366.42 269.3.9 0.61 BP_MWD+IFR+MS 124 11503.16 30.66 285.06 94.82 6723.57 8412.24 -76.47 - 8412.80 8413.15 269.48 0.45 BP_MWD+IFR+MS 125 11597.08 30.37 285.44 93.92 6804.49 8458.32 -63.93 - 8458.81 8459.05 269.57 0.37 BP MWD+IFR+MS 126 11691.71 29.94 285.61 94.63 6886.31 8504.19 -51.21 - 8504.61 8504.77 269.66 0.46 BP_MWD+IFR+MS 127 11786.47 29.51 285.82 94.76 6968.60 8549.49 -38.48 - 8549.84 8549.93 269.74 0.47 BP_MWD+IFR+MS 128 11834.66 29.31 285.99 48.19 7010.58 8572.29 -32.00 - 8572.60 8572.66 269.79 0.45 BP_MWD+IFR+MS 129 11910.00 29.31 285.99 75.34 7076.28 8607.80 -21.84 - 8608.05 8608.08 269.85 0.00 Projected to TD [(c)2007 IDEAL ID12_OC_13] • • • ORIGINAL ~,~~ - o~~ • ~ ~ ~ ~ SARAH PALIN, GOVERNOR oiµ~~7~ OIL of«1 Vr0~7 333 W. 7th AVENUE, SUITE 100 C011T5ERV.A7'I011T CO1rII~II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, 5-126 BP Exploration Alaska Inc. Permit No: 207-097 Surface Location: 3171' FSL, 4565' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 3214' FSL, 2620' FEL, SEC. 33, T12N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to .witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of July, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~~~ STATE OF ALASKA ,7 /P-D~ ALAS IL AND GAS CONSERVATION COMMI~N j~~~ PERMIT TO DRILL ~'" `~ 20 AAC 25.005 ,, ':- ~ ~. 2007 ~. C~mmissi0~l 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is propos~d;,fgr; ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 - 11. Well Name and Number: S-126 ^ 3. Address: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11976 - TVD 7103 12. Field /Pool(s): Prudhoe Bay Field /Aurora Pool 4a. Location of Well (Governmental Section): Surface: 3171' FSL 4565' FEL SEC R12E UM 35 T12N 7. Property Designation: ADL 028258 - , , . , ~ , , Top of Productive Horizon: 3177' FSL, 2492' FEL, SEC. 33, T12N, R12E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: August 15, 2007 Total Depth: 3214' FSL, 2620' FEL, SEC. 33, T12N, R12E, UM ~ 9. Acres in Property: 2560. 14. Distance to Nearest Property: 9200' , 4b. Location of Well (State Base Plane Coordinates): Surface: x-618885 y-5979374 Zone-ASP4 10. KB Elevation Plan (Height above GL): 67 feet 15. Distance to Nearest Well Within Pool: 1700' - 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 67 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3659 Surface: 2948 18. Casin Pr ram: S 'ficatto ns To - Settin' De h - l3o ttom uant' of Cement c.f. or sacks Hole Casin Wei ht Grade Cou tin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC 4760' Surface Surface 4760' 3187' 760 sx AS Lite 442 sx Class'G' 9-7/8" 7" 26# L-80 TCII 6260' Surface Surfa a 6260' 3780' Se Below 9-718" 7" 26# L-80 BTC-M 5716' 6260' 3780' 11976' 7103' 787 sx LiteCrete 257 sx Class'G' 19. PRESE NT WELL CONDITION SUMMARY (To be completed foi• Redrilt and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Dritling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Dritling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify tha the foregoing is true and correct. Contact Scott Kolstad, 564-5347 Printed Name ~ rt Tirpack Title Senior Drilling Engineer `~ ! O„7~ a Prepared By Name/Number: Si nature ~ ;_ Phone 564-4166 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: 0~0~1~D API Number: 50-Oa?9-~,~ -OiD-~ Permit Approval See cover letter for • !) other re uirements Date: c Conditions of Approval: ~¢+~7c v1 ~S ~Q ~~ gC~r1J-.,r„~~<< ~ ,,~ SL1C ~G.C+~- 1~C3`~ '` ~®Q~ ~ ~,( If box is checked, well may not be used to explore f r, test, or produce coalbed met ane, g drates, or gas contained shales: LI ~°'L ~~~MCc~'~C.~ JGa`~~-~ ~p Samples Req'd: ^ Yes ~No Mud Log Req'd: ,^,/Yes ~No ~Q~ PS, ~p'~S~~tS ~~~~ , HZS Measures: [Yes ^ N irectional Survey Req'd: L Yes ^ No Other: ~ ~~~~~..~ ©~2 rGT~©nS1'~ Cg C<O~ W ~ /~ ~ , APPROVED BY THE COMMISSION Date ~Z,S •• ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate o~~~~NA~ ~~~~ • Well Name: S-126 Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector Surface Location: X=618885 Y=5979374 As-Staked 2108' FNL, 714' FWL , T12N, R12E, Sec. 35 Target Locations: X=610400 Y=5979250 To Kur aruk: 2103' FNL, 2492' FEL, T12N, R12E, Sec. 33 Bottom Hole Location: X =610271 Y =5979285 2066' FNL, 2620' FEL, T12N, R12E, Sec. 33, Ri Nabors 9ES Estimated Start Date: 8/15/2007 O eratin da s to com lete: 19 MD: 11976' TVD: 7103' RT/GL: 28.5' RTE: 67' Well Desi n conventional, slimhole, etc.: Modified Slimhole Ob'ective: Injector in the Kuparuk River C Sand Directional: Ver. Anadrill P6 KOP: 300' Maximum Hole An le: 67° tangent Close Approach Wells: All wells pass major risk criteria. Ensure anticollision scan is run after S- 217 is drilled. The nearest wells are: S-217 -15.79' at 385' MD S-16 -16.25' ctr-ctr @ 450' MD Nearest well within Pool 1,700' west of S-125 heel No wells within'/ mile radius at TKUP. IFR-MS corrected surve swill be used for surve validation. Distance to Nearest Property 9,200' to PBU boundary Line: S-126 Permit application Page 1 • Lo in Pro ram: Surface Drilling: MWD / GR Open Hole: None Cased Hole: None Intermediate Hole Drilling: MWD/GR/RES/PWD/DEN/NEU Open Hole: None Cased Hole: USIT Mud Program: 13 1/2"Surface Hole: Fresh Water Surface Hole Mud Density Viscosity seconds Yield Point Ib/1~_ API FL mis/30min PH Initial 8.5 - 9.2 250-300 50 - 70 15 - 20 8.5 - 9.5 Base PF to to SV 9.0 - 9.5 250-300 30 - 45 < 10 8.5 - 9.5 SV toTD 9.5 max 250-300 20 - 40 < 10 8.5 - 9.5 9 7/8" Intermediate Hole: LSND Interval Density (ppg) Tau o YP PV pH API Filtrate 10' Gel Upper 9.2 4-7 25-30 10-15 8.5-9.5 6-10 10 Interval 100' above 10.4 3-7 20-25 10-15 8.5-9.5 4-6 10 Top of HRZ to TD Casing/Tubing Program: Hole Size Csg/ Tb O.D. Wt/Ft Grade Connection Length Top MD/TVD Btm MD/TVD bkb 42" Insulated 20" 91.5 H-40 WLD 80' GL 110'/110' 13'/2" 10 3/" 45.5 L-80 BTC 4760' GL 4760' / 3187' 9 7/8" 7" 26 L-80 TC-II 6260' GL 6260' / 3780' 9 7/8" 7" 26 L-80 BTC-m 5716' 6260'/3780' 11976' / 7103' Tubin 4'/2" 12.6 L-80 TC-II 11560' GL 11560' / 6727' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' - 50' from surface shoe LOT Expected >12.5 p S-126 Permit application Page 2 • Cement Calculations: The followin surface cement calculations are based upon a single stage job. Casing Size 10 3/4" Surface String Basis: Lead: Based on conductor set at 110', 2032' of annulus in the permafrost @ 250% excess and 1729' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 1000' MD above the casing shoe + 30% excess + 80' shoe track volume. Tail TOC: At 3761' MD Total Cement Volume: Lead 601 bbl / 3374 ft / 760 sks of Schlumberger Arctic SET Lite 10.7 and 4.44 cf/sk. Tail 92 bbl / 517 ft / 442 sks of Schlumberger Neat "G" at 15.8 and 1.17 cf/sk. Intermediate Casin Casin Size 7" Intermediate Basis: Lead: Based on 6216' of open hole with 30% excess. Lead TOC: At 5760' MD (1000' MD below surface casing shoe). Tail: Based on 80' shoe track volume and 816' of open hole (to 500' MD above top Kuparuk formation) with 30% excess. Tail TOC: 500' MD above the TKUP, At 11,160' MD Total Cement Volume: Lead 331 bbl / 1858 ft / 787 sks of Dowell LiteCrete at 11.5 ppg at 2.36 cf/sk Tail 53 bbl / 298 ft / 257 sks of Dowell Premium `G' w/ latex at 15.8 pDq and 1.16 cf/sk. S-126 Permit application Page 3 • Formation Tops(TVDss) and Estimated Pore Pressures Commercial Hydrocarbon Est. Pore Est. Formation To s Uncertain Bearin Press. Est. Pore Press. Formation TVDss eet) Yes/No) (Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells Gl 330 +/- 30' no 149 8.7 SV6 1545 +/- 30' no 699 8.7 Base Permafrost 1845 +/- 30' no 835 8.7 EOCU 2075 +/- 30' no 939 8.7 Poss. Gas SVS 2190 +/- 30' h drates 991 8.7 Poss. Gas SV4 2350 +/- 30' h drates 1063 8.7 Poss. Gas SV3 2730 +/- 30' h drates 1235 8.7 Poss. Free gas SV2 2865 +/- 30' or as h drates 1296 8.7 Poss. Free gas SVl 3170 +/- 30' or ash drates 1434 8.7 UG4 3495 +/- 30' Thin coal 1581 8.7 Heavy Oil (3640-3790' UG4A 3520 +/- 30' ss 1592 8.7 Heavy Oil (4045-4175' UG3 3845 +/- 30' ss 1739 8.7 Heavy Oil (4430-4570' UG1 4330 +/- 30' ss 1959 8.7 Heavy Oil (4560-4590' UG Ma 4560 +/- 30' SS 2063 8.7 UG Mbl 4600 +/- 30' no 2081 8.7 UG Mb2 4650 +/- 30' no 2104 8.7 UG Mc 4720 +/- 30' no 2135 8.7 +/-.100' Fault 1 4755 M.D. 2151 8.7 SB NA 4755 +/- 30' no 2151 8.7 SB NB 4780 +/- 30' no 2162 8.7 SB NC 4805 +/- 30' no 2174 8.7 Possible SB OA 4890 +/- 30' viscous oil 2187 8.6 Possible SB OBa 4940 +/- 30' viscous oil 2209 8.6 Possible SB OBb 4975 +/- 30' viscous oil 2225 8.6 Possible SB OBc 5015 +/- 30' viscous oil 2243 8.6 S-126 Permit application Page 4 C • SB OBd 5060 +/- 30' Possible viscous oil 2263 8.6 SB OBe 5125 +/- 30' no 2292 8.6 SB OBf 5145 +/- 30' no 2301 8.6 OBf Base 5175 +/- 30' no 2314 8.6 CM-2 5420 +/- 50' no 2424 8.6 CM-1 5980 +/- 50' no 2674 8.6 TLBK 6370 +/- 50' no 2849 8.6 THRZ 6545 +/- 50' no 2927 8.6 TKLB 6735 +/- 50' no 3012 8.6 TKC4 6750 +/- 50' es 3019 8.6 TKC3E 6760 +/- 50' es 3023 8.6 TKC2E 6800 +/- 50' es 3041 8.6 TKC1C 6860 +/- 50' es 3068 8.6 TKB/LCU 6900 +/- 50' no 3588 10.0 Ku B2 7005 +/- 50' no 3643 10.0 Ku Bl 7030 +/- 50' no 3656 10.0 TD 7036 +/- 50' no 3659 10.0 Ku A6 7060 +/- 50' no 3671 10.0 Ku AS 7070 +/- 50' no 3676 10.0 Ku A4 7090 +/- 50' no 3687 10.0 TMLV 7140 +/- 50' no 3570 9.6 Well TD Criteria I50' MD below TKB/LCU (ie ??ft TVD, ??ft Rathole, etc.) Comments S-126 Permit application Page 5 C Well Control: Surface hole will be drilled with diverter. The intermediate hole 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. BOP equipment will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval- • Maximum anticipated BHP: 3659 psi @ 7103' TVD -Kuparuk River B • Maximum surface pressure: 2948 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: 250 / 4000 psi • Planned completion fluid: 8.5 ppg seawater / 6.8 ppg diesel (2,200' TVD) Kick Tolerance / Int rit Testin Summa Table Casing / Casing Test Maximum Mud Exp Pore LOT I Interval Pressuure Influx Weight.: .Press FIT..... Volume Surface Casing / 4000 psi 136 BBLS 10.4 10.0 LOT 9 7/8" hole (assuming (Kuparuk B) 12.5 LOT Intermediate 4000 psi NA NA NA NA Casin Disposal: • No annular disposal in this well. • Cuttings 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 disposal. Haul all Class I wastes to Pad 3 for disposal. Varience Request: • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. S-126 Permit application Page 6 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC landing ring for the FMC slimhole well head on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test diverter. PU 5" DP as required and stand back in derrick. 3. MU 13 1/2"drilling assembly with MWD/GR/Dir and drill surface hole to approximately 250' TVD below the SV2 Sand top. 4. Run and cement the 10 3/4", 45.5# surface casing back to surface. 5. ND diverter and NU casing /tubing head. NU BOPE and test. 6. MU 9 7/8" drilling assembly with MWD/GR/DIR/RES/PWD and RIH to float collar. Test the 10 3/4" casing to 4,000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill 20' - 50' of new formation and perform Leak Off Test. 8. Drill to +/-100' above the HRZ, ensure mud is in condition and up to required weight and perform short trips as needed. Ensure Pre-Reservoir meeting is held high lighting kick tolerance and detection prior to entering the Kuparuk. 9. Drill ahead to TD in the Kuparuk, 150' MD below the top of the Kuparuk B/LCU. 10. Condition hole for running 7" 26# intermediate casing. POOH and LD DP. 11. Run and cement the 7" intermediate casing. Displace cement with seawater. 12. Wait on Cement. 13. Run USIT w/ CBL to evaluate cement. 14. Test the 7" casing to 4000 psi for 30 minutes. 15. Freeze protect the 7" x 10 3/4" annulus as required. Record formation breakdown pressure on the Morning Report. 16. Run the 4'/2", 12.6 #, L-80, TC-II completion. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear the GLM shear valve and install TWC. Test below to 1000 psi. 17. Nipple down the BOPE. Nipple up and test the tree with hydraulic actuator to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect well to 2,200' TVD with diesel. 19. Rig down and move off. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug. 2. Pull shear valve, install GLV in all of the other mandrels as per the PE. 3. Perforate as per PE. S-126 Permit application Page 7 • L~ Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: Interval Psi EMW TVDss Schrader, OA 2187 (8.6) 4,890 Ku aruk B 3659 (10.0) 7,036 II. Hydrates and Shallow gas: A. Gas Hydrates are not expected at S-Pad and were not seen on recent wells. Recommended practices for drilling hydrates should be followed if hydrates are encountered. III. Lost Circulation /Breathing: A. Lost circulation risk is considered low. IV. Kick Tolerance /Integrity Testing: A. The 10 3/"casing will be cemented to surface. The 7" casing will be cemented to 1000' MD from the surface casing shoe. B. Kick Tolerance / Inte rit Testin Summa Table Casing I Casing Test Maximum Mud Exp Pore LOT / Interval Pressure Influx Weight Press FIT Volume Surface Casing / 4000 psi 136 BBLS 10.4 10.0 LOT 9 7/8" hole (assuming (Kuparuk B) 12.5 LOT Intermediate 4000 psi NA NA NA NA Casin V. Stuck Pipe A. There could be differential sticking across the Schrader Bluff while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide A. S Pad is not designated as an HZS site, however Standard Operating Procedures for HZS precautions should be followed at all times. HzS Summar Table Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level S-16 15 1/23/2004 #2 Closest SHL Well H2S Level S-17 50 3/20/2007 #1 Closest BHL Well H2S Level S-117 10 1/12/2007 #2 Closest BHL Well H2S Level S-13B 10 3/15/2007 Max. Recorded H2S on Pad/Facilit S-03 70 5/11/2007 VII. Faults Formation Where Encounter MD TVDss Est. Throw Fault Intersect Intersect Throw Direction Uncertaint Fault #1 -Schrader B1uffN down to Sands 8853 4755 30 east +/-100' CONSULT THE S PADDATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION S-126 Permit application Page 8 by ~~ Schlumberger '~111~ S-126 (P6) Pro posal Report Date: May 23, 2007 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski ° Client: BP Exploration Alaska Vertical Section Azimuth: Vertical Section Origin: 270.320 N 0.000 ft, E 0.000 ft Field: Structure I Slot: Prudhoe Bay Unit - WOA S-PAD / S-126 gt ~y D MSL l ic i vaton: TVD ReReference Ele ative to 67.00 ft re well: ~ Plan S-126 5~~ y Sea Bed 1 Ground Level Elevation: 38.50 ft relative to MSL Borehole: ~ ~ Plan S-126 a Magnetic Declination: 23.426° UWIIAPI#: Survey Name 1 Date: 50029 S-126 (P6)1 May 23, 2007 Total Field Strength: 57646.757 nT ° Tort 1 AHD I DDI 1 ERD ratio: 118.213° / 8712.72 ft 16.240 / 1.227 Magnetic Dip: Declination Date: 80.911 2007 October 05 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Magnetic Declination Model: , BGGM 2007 Location LatlLong: N 70.35230337, W 149.03467194 North Reference: True North Location Grid NIE YIX: N 5979374.000 ftUS, E 618885.000 ftUS ° Total Corr Mag North -> True North: +23.426° Grid Convergence Angle: X0.90913436 Local Coordinates Referenced To: Well Head Grid Scale Factor: 0.99991606 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Depth (ft _ __ de de ft _~ nn ft ) n nn RTt KOP Bld 1.5/100 G1 Bld 2.5/100 SV6 End Bld V.VV 300.00 397.01 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1667.37 1700.00 1800.00 1900.00 2000.00 2013.57 0.00 1.46 1.50 3.00 4.50 6.00 8.50 11.00 13.50 16.00 18.50 21.00 23.50 26.00 28.50 30.18 31.00 33.50 36.00 38.50 38.84 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 265.43 233.00 330.00 332.99 432.91 532.69 632.27 731.46 830.01 927.73 1024.42 1119.92 1214.03 1306.57 1397.38 1486.28 1545.00 1573.09 1657.65 1739.81 1819.41 1830.00 300.00 397.00 399.99 499.91 599.69 699.27 798.46 897.01 994.73 1091.42 1186.92 1281.03 1373.57 1464.38 1553.28 1612.00 1640.09 1724.65 1806.81 1886.41 1897.00 • Vertical NS Eyy Gravity DLS Directional Northing Easting Latitude I Longitude I Section Tool Face Difficulty (ft) (ft) (ft) (deg) (deg1100 ft) OU O Index UU U (ftUS) 5`J/y.S/4.VV (ftUS ) o iooo~.VV ^' ~n 7c94nQZ7 \N 9dQ n4dF7994 0.00 0.00 0.00 --- HS . 00 0 . 00 0 5979374.00 618885.00 N 70.35230337 W 149.03467194 0.00 0.00 0.00 HS . 1 50 . 25 0 5979373.88 618883.77 N 70.35230310 W 149.03468191 1.23 -0.10 -1.23 1 30 HS . 1 50 . 0.29 5979373.88 618883.70 N 70.35230309 W 149.03468253 1.30 -0.10 . - 22 5 HS . 50 1 1.20 5979373.50 618879.79 N 70.35230223 W 149.03471430 5.22 -0.42 . - . 94 0 74 -11 HS 1.50 1.72 5979372.88 618873.28 N 70.35230081 W 149.03476723 11.73 . - . 20 86 HS 1 50 2.10 5979372.00 618864.17 N 70.35229882 W 149.03484128 20.85 -1.67 . - HS . 2 50 2 46 5979370.80 618851.61 N 70.35229607 W 149.03494340 33.42 -2.67 -33.44 32 50 HS . 2 50 . 2.75 5979369.18 618834.76 N 70.35229238 W 149.03508045 50.29 -4.02 . - 71 47 HS . 50 2 2.99 5979367.16 618813.64 N 70.35228776 W 149.03525215 71.43 -5.71 . - . 74 7 84 -96 HS 2.50 3.19 5979364.72 618788.30 N 70.35228222 W 149.03545818 96.80 . - . HS 50 2 3 38 5979361.89 618758.79 N 70.35227577 W 149.03 14 126.34 -10.10 -126.40 HS . 2 50 . 53 3 5979358.67 618725.16 N 70.35226841 W 149.0.. 0 160.01 -12.80 -160.08 HS . 50 2 . 68 3 5979355.05 618687.47 N 70.35226017 W 149.036 801 197.73 -15.81 -197.82 HS . 2 50 . 81 3 5979351.06 618645.80 N 70.35225105 W 149.03661680 239.44 -19.15 -239.55 . . 06 285 80 -22 -285.19 HS 2.50 3.92 5979346.68 618600.23 N 70.35224108 W 149.03698732 . 317 95 . 43 -25 -318.10 HS 2.50 4.00 5979343.53 618567.37 N 70.35223389 W 149.03725448 . 334 50 . 75 -26 -334.65 HS 2.50 4.03 5979341.95 618550.84 N 70.35223027 W 149.03738887 . 387 66 . 00 -31 -387.84 HS 2.50 4.13 5979336.85 618497.74 N 70.35221865 W 149.03782068 . 444.45 . -35.54 -444.65 HS 2.50 4.23 5979331.41 618441.01 N 70.35220624 W 149.03828193 504 75 36 -40 -504.98 HS 2.50 4.32 5979325.63 618380.76 N 70.35219305 W 149.03877175 . 513.20 . -41.04 -513.44 --- 2.50 4.33 5979324.82 618372.32 N 70.35219121 W 149.03884036 WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-126\Plan S-126\Plan S-126\S-126 (P6) Generated 5/23/2007 9:41 AM Page 1 of 3 Comments Bld 3/100 EOCU SV5 SV4 End Bld S V3 SV2 10-3/4" Csg SV1 UG4 UG4A UG3 UG1 Ma Mb1 Crv 4/100 Mb2 Mc Fault Crossing Na Nb Nc End Crv S-126 Tgt OA OA i Directional i Latkude Longitude Measured Inclination Azimuth Sub-Sea ND ND Vertical Section NS EW Grav ty Tool Face DLS Difficulty Northing East ng De th P ref (deo 1 (deg) k) ft k) k ( ft (de ) de 1100 ft n nn Index 4.44 kUS 5979323.67 ftUS 618360.30 N 70.35218858 W 149.03893810 2032.83 38.84 265.43 1845.00 1912.00 525.23 -4~.uv -oco.4i 2052.08 38.84 265.43 1860.00 1927.00 537.27 -42.96 -537.51 NS 0.00 4.35 5979322.52 618348.28 N 70.35218594 2100.00 40.28 265.43 1896.94 1963.94 567.67 -45.40 -567.93 HS 3.00 4.39 5979319.60 618317.91 N 70.35217930 W 149.03928279 2200.00 43.28 265.43 1971.51 2038.51 634.04 -50.70 -634.33 HS 3.00 4.47 5979313.24 618251.60 N 70.35216478 W 149.03982189 2300.00 46.28 265.43 2042.49 2109.49 704.21 -56.32 -704.54 HS 3.00 4.55 5979306.52 618181.51 N 70.35214943 W 149.04039184 2347.67 47.71 265.43 2075.00 2142.00 738.94 -59.10 -739.28 HS 3.00 4.59 5979303.19 618146.81 N 70.35214183 W 149.04067393 2400.00 49.28 265.43 2109.68 2176.68 777.99 -62.22 -778.35 HS 3.00 4.63 5979299.44 618107.81 N 70.35213328 W 149.04099106 2500.00 52.28 265.43 2172.91 2239.91 855.16 -68.39 -855.56 HS 3.00 4.70 5979292.05 618030.71 N 70.35211639 W 149.04161793 2528.21 53.12 265.43 2190.00 2257.00 877.52 -70.18 -877.93 HS 3.00 4.72 5979289.90 618008.37 N 70.35211150 W 149.04179951 2600.00 55.28 265.43 2231,99 2298.99 935.53 -74.83 -935.97 HS 3.00 4.77 5979284.34 617950.42 N 70.35209879 W 149.04227071 2700.00 58.28 265.43 2286.78 2353.78 1018.87 -81.50 -1019.34 HS 3.00 4.83 5979276.35 617867.17 N 70.35208054 W 149.04294762 2827.08 62.09 265.43 2350.00 2407.00 1128.79 -90.29 -1129.32 HS 3.00 4.92 5979265.81 617757.36 N 70.35205646 W 149.043 2900.00 64.28 265.43 2382.85 2449.85 1193.54 -95.48 -1194.10 FiS 3 00 5.01 5979252.54 617619.60 N 70.35202614 W 149.04496449 2981.24 66.71 265.42 2416.54 2483.54 1267.19 -101.37 -1267.77 __~ 0.00 5.26 5979182.93 616894.18 N 70.35186700 W 149.05085851 3774.15 66.71 265.42 2730.00 2797.00 1992.85 -159.47 -1993.78 0.00 5.34 5979152.96 616581.97 N 70.35179840 W 149.05339691 4115.64 66.71 265.42 2865.00 2932.00 2305.38 -184.49 -2306.45 _ 0.00 5.46 5979096.34 615992.23 N 70.35166873 W 149.05819162 4760.68 66.71 265.42 3120.00 3187.00 2895.72 -231.75 -2897.06 --- 0.00 5.48 5979085.24 615876.60 N 70.35164329 W 149.05913175 4887.16 66.71 265.42 3170.00 3237.00 3011.47 -241.01 -3012.86 0.00 5.61 5979013.07 615124.98 N 70.35147781 W 149.06524255 5709.27 66.71 265.42 3495.00 3562.00 3763.86 -301.25 -3765.60 0.00 5.61 5979007.52 615067.16 N 70.35146507 W 149.06571261 5772.50 66.71 265.42 3520.00 3587.00 3821.73 -305.88 -3823.50 0.00 5.71 5978935.36 614315.54 N 70.35129937 W 149.07182331 6594.61 66.71 265.42 3845.00 3912.00 4574.12 -366.11 -4576.23 0.00 5.83 5978827.67 613193.90 N 70.35105170 W 149.08094216 7821.45 66.71 265.42 4330.00 4397.00 5696.91 -456.00 -5699.54 --- 0.00 5.88 5978776.60 612661.98 N 70.35093409 W 149.08526649 8403.25 66.71 265.42 4560.00 4627.00 6229.37 -498.63 -6232.25 0.00 5.89 5978767.72 612569.48 N 70.35091363 W 149.08601855 8504.43 66.71 265.42 4600.00 4667.00 6321.97 -506.04 -6324.89 8556.99 66.71 265.42 4620.78 4687.78 6370.07 -509.89 -6373.01 127.68R 0.00 5.89 5978763,11 612521.43 N 70.35090299 W 149.08640917 8600.00 65.67 266.92 4638.14 4705.14 6409.31 -512.52 -6412.27 127.07R 4.00 5.91 5978759.86 612482.21 N 70.35089572 W 149.08672788 8628.41 64.99 267.92 4650.00 4717.00 6435.10 -513.68 -6438.07 126.66R 4.00 5.91 5978758.29 612456.45 N 70.35089248 W 149.08693726 8700.00 63.30 270.49 4681.22 4748.22 6499.50 -514.58 -6502.47 125.53R 4.00 5.94 5978756.36 612392.07 N 70.35088986 W 149.08746010 8783.53. 61.39 273.59 4720.00 4787.00 6573.44 -511.97 -6576.40 124.10R 4.00 5.96 5978757.80 612318.11 N 70.35089683 W 149.080 8800.00 61.02 274.21 4727.93 4794.93 6587.84 -510.99 -6590.80 123.80R 4.00 5.97 5978758.55 612303.71 N 70.35089948 W 149.0 8 8854.84 59.82 276.32 4755.00 4822.00 6635.35 -506.62 -6638.28 HS 4.00 5.98 5978762.17 612256.16 N 70.35091131 W 149.088 270 8854.86 59.82 276.32 4755.01 4822.01 6635.37 -506.61 -6638.30 122.75R 4.00 5.98 5978762.17 612256.14 N 70.35091131 W 149.08856284 8900.00 58.86 278.10 4778.03 4845.03 6673.92 -501.75 -6676.82 121.85R 4.00 6.00 5978766.43 612217.55 N 70.35092452 W 149.08887561 8903.80 58.77 278.25 4780.00 4847.00 6677.14 -501.28 -6680.04 121.77R 4.00 6.00 5978766.84 612214.33 N 70.35092577 W 149.08890172 8951.35 57.79 280.16 4805.00 4872.00 6717.09 -494.82 -6719.96 120.77R 4.00 6.01 5978772.67 612174.31 N 70.35094333 W 149.08922588 9000.00 56.81 282.16 4831.29 4898.29 6757.30 -486.90 -6760.13 119.69R 4 00 6.05 5978797.84 612057.90 N 70 35606687 W 149.09016783 9094.48 55.00 286.16 4884.26 4951.26 6833.25 -467.80 -6835.97 -- 9104.48 55.00 286.16 4890.00 4957.00 6841.13 -465.52 -6843.84 0.00 6.05 5978800.00 612049.99 N 70.35102309 W 149.09023183 9104.50 55.00 286.16 4890.01 4957.01 6841.14 -465.51 -6843.85 --- S-126\Plan S-126\Plan S-126\S-126 (P6) Generated 5/23/2007 9:41 AM Page 2 of 3 WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) Vertical Gravity Comments Measured Inclination Azimuth Sub•Sea TVD TVD Section NS EW Tool Fac Depth ft de (de (ft (ft (ft ft) ft de ) 62 6898 70 OBa OBb OBc OBd OBe OBf OBf Base Crv 4/100 CM2 End Crv CM1 Crv 4/100 TLBK THRZ TKLB End Crv / Tgt TKC4 TKC3E TKC2E TKC1C TKBILCU TK82 TK81 TD / 7" Csg 00 11500 28.21 286.16 6606.69 6673.69 8417.51 . 11600.00 26.21 286.16 6695.63 6762.63 8461.49 11643.72 25.33 286.16 6735.00 6802.00 8479.78 11660.29 25.00 286.16 6750.00 6817.00 8486.56 11660.31 25.00 286.16 6750.01 6817.01 8486.56 11671.33 25.00 286.16 6760.00 6827.00 8491.04 11715.46 25.00 286.16 6800.00 6867.00 8508.99 11781.67 25.00 286.16 6860.00 6927.00 8535.90 11825.80 25.00 286.16 6900.00 6967.00 8553.84 11825.81 25.00 286.16 6900.01 6967.01 8553.85 11941.66 25.00 286.16 7005.00 7072.00 8600.95 11969.24 25.00 286.16 7030.00 7097.00 8612.16 11975.80 25.00 286.16 7035.95 7102.95 8614.83 Beall 0 ft 1 ~ DD' dex~l (ftUS g 22 4 00 55 16 286 4930.00 4997.00 6896.08 -449. - ~ 00 0 05 6 5978828.18 917 . 24 9235 . 55.00 . 286.16 4965.00 5032.00 6944.17 -435.70 -6946.71 ___ . 00 0 . 6.06 5978843.21 . 9304.98 55.00 286.16 5005.00 5072.00 6999.13 -419.80 -7001.58 . 15 9392 55.00 286.16 5055.00 5122.00 7067.82 -399.92 -7070.16 --- 0.00 00 0 6.06 6.07 5978862.00 5978884.54 . 76 9496 55.00 286.16 5115.00 5182.00 7150.25 -376.06 -7152.47 . 00 0 6.07 5978892.05 . 63 9531 00 55 286.16 5135.00 5202.00 7177.73 -368.11 -7179.90 . 00 0 6.07 5978905.21 . 65 9592 . 55.00 286.16 5170.00 5237.00 7225.82 -354.20 -7227.91 LS . 00 0 6.07 5978916.48 . 9644.95 55.00 286.16 5200.00 5267.00 7267.03 -342.27 -7269.06 . 00 9700 80 52 286.16 5232.43 5299.43 7309.82 -329.89 -7311.78 LS S 4.00 00 4 6.09 11 6 5978928.18 5978948.56 . 00 9800 . 48.80 286.16 5295.63 5362.63 7384.36 -308.32 -7386.19 L LS . 4 00 . 6.13 5978967.74 . 00 9900 44.80 286.16 5364.07 5431.07 7454.47 -288.03 -7456.19 LS . . 81 9976 41.73 286.16 5420.00 5487.00 7505.10 -273.38 -7506.74 4 00 6 15 5978982 34 . 9981.15 41.55 286.16 5423.24 5490.24 7507.87 -272.57 -7509.51 --- 13 10725 41.55 286.16 5980.00 6047.00 7982.60 -135.19 -7983.48 180 --- 00E 0.00 00 0 6.16 6.16 5979112.18 5979130.95 . 10832.69 41.55 286.16 6060.50 6127.50 8051.24 -115.33 -8052.01 32 094 . 180 00E . 2.00 6.17 5979142.54 10900.00 40.21 286.16 6111.39 6178.39 8093.62 -103.07 . -8 0 . 0 59 2 64 -68 10 -8213. 180. 00E 2.00 6.19 5979175.08 00.00 111 36.21 286.16 6268.51 6335.51 . 821 . 00 11200 34.21 286.16 6350.22 6417.22 8268.05 -52.59 -8268.47 180. 180 00E 00E 2.00 00 2 6.20 6.20 5979190.24 5979193.75 . 11223.85 33.73 286.16 6370.00 6437.00 8280.87 -48.88 -8281.27 07 8321 . 180 00E . 2.00 6.21 5979204.65 11300.00 32.21 286.16 6433.89 6500.89 8320.73 -37.34 92 22 . - 83 -8370 180 . .00E 2.00 6.22 5979218.28 11400.00 30.21 286.16 6519.41 6586.41 8370.57 73 . - 82 -18 . 97 -8384 180. 00E 2.00 6.22 5979222.15 11429.52 29.62 286.16 6545.00 6612.00 8384. . . WeIlDesign Ver SP 2.1 Bld( docAOx_100 ) 33 -9 -8417.69 180.00E 2.00 6.23 5979231.12 . 39 3 -8461.60 180.00E 2.00 6.23 5979243.15 . 68 8 -8479.86 180.00E 2.00 6.24 5979248.15 . 65 10 -8486.63 --- 2.00 6.24 5979250.00 . 10.65 -8486.63 --- 0.00 6.24 5979250.00 94 11 -8491.11 --- 0.00 6.24 5979251.23 . 14 17 -8509.02 --- 0.00 6.24 5979256.13 . 24 93 -8535.90 --- 0.00 6.24 5979263.49 . 12 30 -8553.81 --- 0.00 6.24 5979268.40 . 30.12 -8553.81 --- 0.00 6.24 5979268.40 75 43 -8600.84 --- 0.00 6.24 5979281.28 . 99 46 -8612.03 --- 0.00 6.24 5979284.35 . 47.77 -8614.70 --- 0.00 6.24 5979285.08 S-126\Plan S-126\Plan S-126\S-126 (P6) Fasting I Latitude Longitude (ftUS1 611946.67 N 70.35110428 W 149.09106712 611891.56 N 70.35114759 W 149.09151267 611822.68 N 70.35120172 W 149.09206961 611740.02 N 70.35126667 W 149.09273794 611712.46 N 70.35128833 W 149.09296072 611664.24 N 70.35132621 W 149.09335059 611622.91 N 70.35135869 W 149.09368476 611580.00 N 70.35139240 W 149.09403166 611505.26 N 70.35145113 W 149.09463595 611434.96 N 70.35150637 W 149.09520439 611384.18 N 70.35154626 W 149.09561493 611381.40 N 70.35154844 W 149.095 610905.35 N 70.35192242 W 149.09948 0 610836.52 N 70.35197649 W 149.10004303 610794.03 N 70.35200986 W 149.10038661 610733.05 N 70.35205776 W 149.10087964 610674.72 N 70.35210357 W 149.10135128 610619.11 N 70.35214725 W 149.10180095 610606.26 N 70.35215734 W 149.10190490 610566.28 N 70.35218874 W 149.10222811 610516.31 N 70.35222799 W 149.10263223 610502.11 N 70.35223914 W 149.10274705 610469.24 610425.13 610406.80 610400.00 610400.00 610395.50 610377.51 610350.52 610332.52 610332.52 610285:29 610274.04 610271.37 N 70.35226495 W 149.10301282 N 70.35229959 W 149.10336943 N 70.35231399 W 149.10351769 N 70.35231933 W 149.10357266 N 70.35231933 W 149.10357270 N 70.35232286 W 149.10360904 N 70.35233699 W 149.10#~f853 N 70.35235818 W 149.1 78 N 70.35237231 W 149.1 27 N 70.35237232 W 149.10411831 N 70.35240940 W 149.10450020 N 70.35241823 W 149.10459113 N 70.35242033 W 149.10461276 Generated 5/23/2007 9:41 AM Page 3 of 3 _ f O V ~ B 8 s" 8 L z~ ~ ~~ .s pa p o _ z~ ~ . D C a ~ ~ A ~s ~a- o ~ ~~ _xs ~~~ o L _ 1 ~ v9iw D ~ c z O ,~ M L a =3 O O s N x O O r Q $ ~ a o co N ~ ~ „8 IA V ~ 5f °- m p ~u 5 £ E • p p O p p O N ~ ~ N M O ~ • p p O p p O ~ p N ~ p r p p O p O pO pp ~ p0 O N ~ p d' p ~ ~ N M by Schlumberger fIE LD STRUCTURE WEL` S 126 (P6) Prudhoe Bay Unit - WOA S-PAD Surface Location NAD2] Alaska Sulo Planes. Zone 04. US Feot Miscellaneous Magnetic Paramoters 61 5-136 NDRet. Rotary TaEle {fi].00 Xabove M6L1 Mtl RGGM 200] DO 60911" Date: Odo6er 05. 200] N]0316293 IJOnM1inq 59]9J]a 00 ttU5 Gnd Canv ~0.9091b%° 5 Date: Ma 33.200] M 9Da IJ 436 F6 5]6468T W 9 489 E 9 61886500 XUS F 09999160554 PI 5-261P61 ^'Y Y -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 2000 00 • 1000 n n n Z 0 0 0 0 c a> m U ~ -1000 V V -2000 00 000 ?000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 c« W Scale = 1(in):1000(ft) E »> BP Alaska Anticollision Report ! Company: BP Amoco Date: 5123/2007 Time: 10:02:56 - - Page: ' t Field:: Prudhoe Bay Co-ordinate NE Reference: Well: Plan S-126, True North Reference Site: PB S Pad ~ ~ Reference Well: Plan S-126 Vertical (TVD) Refereence: S-126 Plan 67.0 Reference Wellpath: Plan S-126 Db:-Oracle __. _ -- - _ _, _ _ ~__ - _. - - - - ! GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1[l;(pI{'Hu¢ells in thisRlitlldlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 11975.80 ft Scan Method: Trav Cylinder North 1 Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing , __ _ _ _ - - _ Survey Program for Definitive Wellpath Date: 5/22/2007 Validated: No Version: 10 Planned From To Survey Toolcode Tool Name ~ - _ 28 50 - 00 700 - ___ - Planned: Plan #6 V1 YD-GC-SS yrodata gyro singes o s . '! 700.00 . 2100.00 Planned: Plan #6 V1 MWD MWD+IFR+MS MWD -Standard MWD +IFR + Multi Station 700.00 4700.00 Planned: Plan #6 V1 MWD+IFR+MS MWD +IFR + Multi Station 4700.00 11975.80 Planned: Plan #6 V1 Casing Points r -- MU TVD Diameter -Hole Size Name ft ft in in r 4760.68 3187.00 J 10.750 13.500 10 3/4" 111975.80 7102.95 7.000 9.875 7" Summary <~----------- --- Offset Wellpath ---- -------------~ Reference Affset Ctr-Ctr No-Go Site `Yell Wellpath MD MD, Distance Area ft ft ft ft ~ PB S Pad --- Plan S-125 --- - Plan S-125 Alt 1 V1 PI 4507.28 4655.00 984.19 131.11 PB S Pad Plan S-125 Plan S-125 Alt 2 V1 PI 4586.92 4850.00 888.29 114.40 PB S Pad Plan S-125 Plan S-125 V8 Plan: PI 4349.36 4495.00 981.13 183.39 27 133 !' PB S Pad Plan S-125 Plan S-125P61 V5 Plan: 4374.03 4520.00 981.56 . PB S Pad ' Plan S-125 Plan S-125P62 Alt 2 V1 4586.92 4850.00 888.29 114.40 ~ PB S Pad Plan S-214 Plan S-214 V1 Plan: S- 2765.49 3500.00 390.62 69.87 PB S Pad Plan S-217 (216-15) Plan S-217 V4 Plan: PI 385.02 385.00 15.79 7.43 i PB S Pad S-116 Plan S-116L1 V1 Plan: 2680.01 3255.00 615.27 45.83 PB S Pad S-116 S-116 V6 2680.01 3255.00 615.27 45.83 ! PB S Pad S-15 S-15 V2 670.88 675.00 124.11 14.79 PB S Pad S-16 S-16 V1 449.71 450.00 16.25 7.97 PB S Pad S-17 S-17 V1 669.41 670.00 96.81 12.84 PB S Pad S-17 S-17A V1 669.41 670.00 96.81 12.84 PB S Pad S-17 S-17AL1 V1 669.41 670.00 96.81 12.84 PB S Pad S-17 S-17AP61 V1 669.41 670.00 96.81 12.84 PB S Pad S-17 S-176 V1 669.41 670.00 96.81 12.84 PB S Pad S-17 S-17C V1 669.41 670.00 96.81 12.73 PB S Pad S-17 S-17CPB1 V2 669.41 670.00 96.81 12.73 PB S Pad S-17 S-17CP62 V1 669.41 670.00 96.81 12.73 PB S Pad S-18 S-18 V1 627.68 635.00 206.34 12.44 PB S Pad S-18 S-18A V16 625.68 630.00 206.28 12.23 PB S Pad S-215 S-215 V9 429.66 435.00 102.43 8.53 PB S Pad ' S-400 Plan S-400A V3 Plan: P 2748.72 3000.00 408.76 55.27 , PB S Pad S-400 S-400 V4 2760.04 3015.00 408.63 55.34 '~ PB S Pad S-40A S-40A V1 709.24 710.00 130.22 10.97 ', PB S Pad S-40 S-40 V1 709.24 710.00 130.22 10.97 Allo~~able Deviation Warning ft 853.08 Pass: Major Risk 773.89 Pass: Major Risk 797.74 Pass: Major Risk 848.29 Pass: Major Risk ~ 773.89 Pass: Major Risk 320.75 Pass: Major Risk 8.37 Pass: Major Risk j 569.43 Pass: Major Risk ! 569.44 Pass: Major Risk 109.32 Pass: Major Risk 8.28 Pass: Major Risk 83.97 Pass: Major Risk 83.97 Pass: Major Risk 83.97 Pass: Major Risk 1 83.97 Pass: Major Risk 83.97 Pass: Major Risk 84.08 Pass: Major Risk ', 84.08 Pass: Major Risk 84.08 Pass: Major Risk 193.90 Pass: Major Risk 194.06 Pass: Major Risk 93.90 Pass: Major Risk ', 353.48 Pass: Major Risk 353.29 Pass: Major Risk '~ 119.25 Pass: Major Risk 119.25 Pass: Major Risk • FieldPrudhoe Bay SitePB S Pad We11:Plan 5-126 WellpathElan 5-126 313 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t : PB S Pad Sit Target: 5-126 Tgt OA Well: -126 P e Drilling Target Conf.: 95% rogram Based ]armed Vertical Depth: 4890.00 ft below Mean Sea Level Description: Map Northing: 5978800.00 ft Local +N/-S: -465.52 ft Local +E/-W: -6843.82 ft Map Fasting : 612050.00 ft Longitude: 149°OS24.834W Latitude: 70°21'03.683N Radius: 150 ft Shape: Circle _. _. __ _ __ _ _ _ - _ - _"- _ - ~~ ~ 00 - 200 - 000 - 4-00 '~ -500 -000 _ __ _ _ _-_ -100 ~ 0 0 ~ ~ ~ ~ ~ ~ ~ ~ o ~ ~- 0 0 ~o ~o ~ ~ D ~ ~ ~ ' ~ O f • ~ Target: 5-126 Tgt Kup S-126 l W Site: PB S Pad e ~ Base Planned Program Drilling Target Conf.: 95% Vertical Depth: 6750.00 ft below Mean Sea Level Description: Map Northing: 5979250.00 ft Local +N/-S: 10.65 ft Local +E/-W: -8486.61 ft Map Easting : 610400.00 ft ' Longitude: 149°06' 12.862W 08.350N Latitude: 70°21 Radius: 150 ft Shape: Circle _. __ ~~-00 I~ 300 i ', '. i, I 200 I ~~ 00 i' 0 00 200 ;o 0 0 0 0 0 0 ~ ~ ° ° ~~ ~ ~ ~ ~ ~ ~ ~~ TREE= 4-1/16" CNV DATE REV BY COMMENTS DATE REV BY COMMENTS GPB AURORA 06/21/07 SRK Proposed Completion WELL: S-126i PEF2Mff No: API No: 50-029 SEC , TN, RE, ' FSL, ' FEL BP Exploration (Alaska) ^ 31 ^7 ^ 124i ^ 123 ^ 6 ^ 28 ^ 27 ^ 5 ^ 26 ^ 25 ^ 4 ^ 24 ^ 21 ^3 ^ 23 ^ 20 ^2 ^ 1s ^ 22 ^1 )DUCE MODULE N I 1s 1s n 1s n n ae 20 18 ^ 18 NOTES: 1. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27 & S PAD PLANT. 2. GEODETIC COORDINATES ARE NAD-27. 3. WOA S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. 4. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-1 & S-2. 5. BASS OF VERTICAL CONTROL IS TBM 18-90-26A PER F.R. BELL & ASSOC. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. 6. REFERENCE FIELDBOOK: W001-05 PGS. 17-27. 7. DATE OF SURVEY: JANUARY 30, 2001. LEGEND ~- RENAMED CONDUCTOR ^ EXISTING CONDUCTOR GRAPHIC SCALE 0 100 z00 a00 ( IN FEET ) 1 inch = 200 ft. LOCATED WITHIN PROTRACTED SEC. 35. T. 1? N.. R. 17 F.. UMiAT MERIDIAN. AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS S-1261 Y=5,979,374.30 N 964.89 70'21'08.295" ' 70.3523042° 38.5' 3,171 FSL X= 618,885.30 E 1480.74 149°02 04.810" 149.0346694' 4,565 FEL r, nvuci~ BARNHART CHECKED: ~ ~~/\ MANSER N O O OAiE: 6/22/07 °~ DRAWING: FR807 woS 03-00 WOA S-PAD SNEET: ®~~~OO ~o ~°D No. RENAMED AS-BUILT CONDUCTOR 0 6 22 07 RENAME OLD WELL SS-13 TO NEW S-126I 7FB SPM wa~~as u~o uuo wmcmxs SCALE: 1 OF 1 „~~, ~~,nm ,.,~ 1"= 200• WELL SS-13 N0. DAlE REVISION BY CHK woxu,~. unss° msu 27 26 ~ I25 S PAD ~n ~ -N- 34 ~~~~1 35 ~~ T.12N. 3 T.11 N. 2 VICINITY MAP N.T.S. ~P~~ °OF ° ACS b ~~°4-9 ~ ~ °°9~ '~ °°° Leonard J. O'Hanley f 11386 °° ,~ ° ° PEA _ ESSIONA~ ~' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 30, 2001. Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y RENAMED CONDUCTOR REVISION NOTE WELL SS-13 ~ THIS AS-BUILT DRAWING IS A REISSUE OF PREVIOUS AS-BUILT DRAWING FOR CONDUCTOR ~ SS-13. RENAMED CONDUCTOR IS AS FOLLOWS: ~ OLD COND. NAME LVEW COND. NAME SS-13 S-126i EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 ---- 5950000 5900000 }- - 5850000 400000 500000 600000 700000 800000 • 'Alaska Department of Natural sources Land Administration System Page 1 of 4 • r,~sF~ ._ ~;;~, .~~s F~I;~ts ~ o,ier`s Search State Cabins l~i~tur~ 5~D41C~ES Alaska DNR Case Summary File Type: ADL ~ File Number: 28258 ~ ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~` Yes r' NO New Search LAS Menu ~ Case Abstract I Case Detail I Land Abstract _ , F[Ic~: :U)L 28258 `''~' Search for Status Plat Updates <~~ of 07;'1 S%007 Customer: 000107377 C3P C 1PLC1IZ~17-ION (ALASKA) W C PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 99.5196612 Case Type: 7 OIL & GAS .LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DN O1L AND GAS Case Status: 35 ISS/APPRV/ACTV MTH Status Date: 09/1/1965 Total Acres: 2560.000 DateInitiated.~05/28/1965 Office of Primary Res~ofrsibility : DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: S NORT H SLOPE Last Transaction: AA-NRB ASSI GNMENT APP ROVED lleridicr~l: 11 Trnr~l_shrh: UI?N K~o1~e°: O1~'E Section: 2? .Sectio~r:'Icr~~~s: 6~0 Search Plats ~~PYl~~lc01: ~I 7ULt'nS'I711): U~2N li'an~~rC: ~ai~1. .~~c'clLU71.~ ~~ ,5r'CIIU7t.~CYL'.~': UFO 1~~'f'lt~ltlll: ~_~ ~U11'nS'{117: 0~ ~'J\ IZUi1,~8: (~~ ~i. .ti~c'C/IUIl: ~~ ~ ~~~CCfIUn ~~CPB~": (i~0 11~E'I7C~lan: 1 i IO1t~nJ{IC~7: (~ ~ ~~' jlC/ll Vie': ~)~ ~~ SPA"IIUn: >=1 :SC'~'I(Qn ~1C]'t'S': ~~~~~ Leal Description OS-28-196 * * * SALE NOTICE LEGAL DESCRIPTION C14- ~ 3 12N 12E UM 27, 28, 33, 34 2560.00 04-OI -1977 ~ * * UNITIZED AND PARTICIPATING AREA LEGAL DESCRIPTION* ENTIRE LEASE COMMITTED TO PR UDHOE BAY UNIT AND OIL RIM PA PR UDHOE B A Y UNIT, TRACT 21, IN ENTIRETY OIL RIMPARTICIPATINGARE4 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28258&... 7/18/2007 Alaska Department of Natura~sources Land Administration System Page 2 of 4 • T. 12 N., R. 12 E., UMIAT MERIDIAN, ALASKA SECTION 27: ALL; SECTION 28: ALL; SECTION 33: ALL; SECTION 34: ALL; CONTAINING 2.60.00 ACRES, MORE OR LESS. 11-01-2000 * * *A URORA PARTICIPATING AREA FORMED LEGAL DESCRIPRION* ~` PRUDHOE BAY UNIT, TRACT 21 (PARTIAL) AURORA PARTICIPATING AREA T. 12 N, R 12 E., U.M. SECTION 27 ~ ALL, 640 ACRES; SECTION 28: E/2, E/ZW/2, 480 ACRES; SECTION 33: E/2, 320 ACRES; SECTION 34: ALL, 640 ACRES; CONTAINING APPROXIMATELY 2, 080.00 ACRES, MORE OR LESS. 11-DI -1999 * * *POLARIS PARTICIPATING AREA LEGAL DESCRIPRION* PRUDHOE BAY UNIT, TRACT 21 (PARTIAL) A UR~RA PARTICIPATING AREA T. 12 N, R. 12 E., U.M. SECTION 27: ALL. 640 ACRES; SECTION 33: SE/4SE/4, 40 ACRES; SECTION 34: E/2W/2, SW/4SW/~l, E/2, 520 ACRES; CONTAINING 1,200.00 ACRES, MORE OR LESS. http://www.dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28258&... 7/ 18/2007 ' `Alaska Department of Natural,~sources Land Administration System Page 3 of 4 • 10-01-2004 * * * A URORA PA EXPANDED LEGAL DESCRIPTION IS AS FOLLOWS: PRUDHOE BAY UNIT AURORA PARTICIPATING AREA TRACT 21 T.12N., R.12E., UNIIAT MERIDIAN, ALASKA SECTION 2?: ALL, 640.00 ACRES: SECTION 28: ALL, 640.00 ACRES: SECTION 33: ALL, 640.00 ACRES; SECTION 34: ALL, 640.00 ACREA; THIS TRACT CONTAINS 2, 560.00 ACRES, MORE OR LESS. '~ U N" http://www. dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=2825 8&... 7/18/2007 ' `Alaska Department of Natural,~sources Land Administration System Page 4 of 4 Last updated on 07/1812007. Not sure who to contact? Have a question about DNR? Visit the F~uiic Irtfcartnatc~n Center. Report technical problems with this page to the l~Vebaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all (!CaKIE must be accepted. State ©#.Aiaska Natural Resources LAS Home Copyright Privacy System Status http://www. dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2825 8&... 7/18/2007 Terrie L. Hubble BP Exploration AK Inc. An h orage6 AK 99519 5 PAY TO THE ORDER OF • "Mastercard Check" as-sn2sz 345 DATE ~ •D 10~ ~~ ~;~25200060~:99L46227L556~~' 0345 • • Td2.A~~fS1dtITTA.I, LE~'TEEa C'1EIECICLIST WELL NAititE ,~~~/ ~'- /~,/o PTD# v?O~p9,~p Development ~ Service Ex lorato Yon-Conventional Welt p ~"~ ~ Stratigraphic Test Circle Appropriate Letter /paragraphs to be Included in "fransmitta[ Getter ' CHECK w'HAr APPLIES ADD-ONS (OPTIONS) I MliLTt LATERAL ([f last two digits API. number between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new weltbore segment of existing ~ well in I Permit Yo. are ~ ,API No. 50- _ Production should continue to be reported as a function of the originaI.4Pt number stated above. PILOT HOLE (n accordance with 20 AAC 2.005 (f), at! record;, data and Iogs acquired for the pilot hole m t b us e clearly differentiated in both Hanle ( I PH) and APt number ; (Sal ~ i - fr ~ acquired for wet! -~ om records, data and logs I SPACING The permit is approved subject to tut! 'EXCEPTION com (lance with 20 (25.035. Approval to perforate and aroduceP inject is contin e I ,' ~ t upon issuance of a conservation order approving a spa~ng ;exception. I ' liabili of an assumes the tY y protest to the spacing exception that may occur. ~ DRY DITCH i SAMPLE I All dry ditch sample sets submitted to the-Eommission must be in i ~ no greater than 30' sample intervals from below the from whe n ' ~ ~ re samples are first caught and 10' sample in~enrals through target zones . i I~ W "Conventional r j Please note the following special condition of this _ ~ production or production testing of coal bed methane is not all w ~t i for (name of well) until after Corn anv Iv`ame has designed and j ~ implemented a water well testing program to provide baseline data on water quality and u ti ~ q an ty. 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