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209-125
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 12/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 01-28 + 01-28A -PTD 186-095 (01-28) -PTD 209-125 (01-28A) -API 50-029-21597-00-00 (01-28) -API 50-029-21597-01-00 (01-28A) Gyrodata Survey 11/20/2023 Gyro + MWD Definitive Composite Survey Main Folder Contents: Definitive Survey Sub-Folder Contents: PBU 01-28A Gyrodata Survey Sub-Folder Contents: Please include current contact information if different from above. PBU 01-28 PTD: 186-095 T38203 PBU 01-28A PTD: 209-125 T38204 12/6/2023 () PTD 209-125 (01-28A) () API 50-029-21597-01-00 (01-28A) Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 11:40:41 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 01-28A JBR 01/18/2024 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:3 5K test Flange on choke manifold leaked,tighten and pass re-test. HCR kill FP. Upper 2" pipe slip rams; mud seal failed and was replaced. Pased re-test Test Results TEST DATA Rig Rep:Coyne/HensonOperator:Hilcorp North Slope, LLC Operator Rep:Perl/Kavanagh Rig Owner/Rig No.:Nabors CDR2AC PTD#:2091250 DATE:12/2/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE231206093820 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 13 MASP: 2415 Sundry No: 323-532 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 1 FPCH Misc Stripper 1 2"P Annular Preventer 1 7 1/16"P #1 Rams 1 blind/shears P #2 Rams 1 2"pipe slip FP #3 Rams 1 2 3/8" pipe sli P #4 Rams 1 2" pipe slip P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"FP Kill Line Valves 2 2 1/16"P Check Valve 0 NA BOP Misc 2 2"P System Pressure P3050 Pressure After Closure P2275 200 PSI Attained P21 Full Pressure Attained P54 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@2070 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 P4 #1 Rams P6 #2 Rams P2 #3 Rams P3 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 9 9 choke manifold leaked,HCR kill FP.Upper 2" pipe slip rams; mud seal failed FP FP FP Drilling Manager 09/27/23 Monty M Myers By Grace Christianson at 8:31 am, Sep 28, 2023 * BOPE pressure test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner on upcoming sidetracked lateral. * Variance to 20 AAC 25.036 c.4.C approved for window milling with service coil without a firewall to shield accumulators. 10-407 DSR_9/28/27MGR03OCT23SFD 10/4/2023*&:JLC 10/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.05 08:59:12 -08'00'10/05/23 RBDMS JSB 100523 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: Re: PBU 01-28A Sundry Request Sundry approval is requested to set a whipstock and mill the window in 01-28A as part of the drilling and completion of the proposed 01-28B CTD lateral. Proposed plan for 01-28B Producer: Prior to drilling activities, slickline will pull the LTP and screening will be conducted to drift and caliper for whipstock and MIT. E-line will set a 3-1/4" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. 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 3-1/4" packer whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 4. The lateral will continue in Zone 4 and 3 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. This Sundry covers plugging the existing perforations via the packer whipstock and 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 in October 15th, 2023)Reference 01-28B Sundry submitted in concert with this request for full details. 1. Slickline: Pull LTP. Caliper Whipstock Setting location. Dummy WS drift. Dummy GLVs 2. E-Line: Set Whipstock 3. Fullbore: MIT-IA and MIT-T to 2500 psi 4. Coil: Mill Window (if window not possible, mill with rig) 5. VS: Pre-CTD Tree Work 6. Ops: Remove wellhouse and level pad. Rig Work: (Estimated to start in December 11, 2023) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,415 psi). a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure. Kill well. 2. Mill 2.74” Window. (If not done pre-rig) a. Top of window (whipstock pinch point) at 9988' MD. b. Single string exit (out of 3-1/4" liner) plus 10' of rathole. 3. Drill build section: 3.25" OH, ~257' (42 deg DLS planned) and production lateral: 3.25" OH, ~1881' (12 deg DLS planned). a. Drill with a constant bottom hole pressure for entire sidetrack b. Pressure deployment will be utilized c. Lay in completion/kill weight fluid in preparation for liner run after TD and on the last trip out of hole d. No flow test prior to laying down drilling BHA. Confirm well is dead prior to picking up liner. Sundry 323-532 PTD 223-0XX 4. Run 2-3/8” 13Cr liner. Pump primary cement job: 18 bbls, 15.3 ppg Class G, TOC at TOL*. a. Have 2" safety joint with TIW valve ready to be picked up while running liner b. Swap well over to KCl d. Freeze protect well to a min 2,200' TVDss e. RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop: Valve & tree work 2. Slickline: SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil: Post rig perforate (~300’) and RPM. 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 2.74” 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 10 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 DS 01 is an H2S pad. H2S reading on 01-28A: 24 ppm on 01/11/2020. x Max H2S recorded on DS 01: 375 ppm. x 3 fault crossings expected. x Medium lost circulation risk. Reservoir Pressure: x The reservoir pressure is expected to be 3294.72 psi at 8800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,415 psi. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka 907-244-4357 9988' 9988' 12,126' Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 209-125 PBU 01-28A 323-532 SFD 10/4/2023 SFD 10/4/2023 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .Qo - Lca,-6— History File Identifier Organizing (done) ❑ nizin Two -sided III I III ❑ Rescan Needed III 11 1111 1 11 1 RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: i � reyscale Items: [ ° they, No/Type: G� NO' 1 ❑ Other Items Scannable by t � Imo — a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: Date: / s/ BY: AZ, Date: l A P Project Proofing II EIIII II 1111 Date: r{ BY:� -, p+ -. 151 J I /s/ Scanning Preparation x 30 = 3 . + = TOTAL PA GES 5. g p 1. p (Count does not include cover sheet) Date: 5' /s/ BY: �� , Production Scanning III MINIM g Stage 1 Page Count from Scanned File: ,..53 (Count does include cover heet) Page Count Matches Number in Scann Pre aration: t/ YES NO 9 a BY: 410 Date: a I S f rr l /s/ rf Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I I11E111111H ReScanned II 1111111 lill BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111E11111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 ANk ; A.US 1 7 ZU12 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue } Anchorage, Alaska 99501 a — ) /a Subject: Corrosion Inhibitor Treatments of GPB DS -01 O Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -056 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -178 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -198 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 _ 0.4 7/8/2011 9.4 10/22/2011 01 -228 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 --- 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA _ 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA • STATE OF ALASKA a ALASKA AND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations IN StimulateD Other Q 5 m Lo Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development eg Exploratory ❑ .. 209 -1250 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 •A• 50- 029 - 21597 -01 -00 8. Property Designation (Lease Number) : „ 9. Well Name and Number: ADLO- 028329/028328 v PBU 01 -28A 10. Field /Pool(s): �„ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11980 feet Plugs (measured) 11700 feet true vertical 8684.6 feet Junk (measured) None feet Effective Depth measured 11943 feet Packer (measured) 9317 9398 feet true vertical 8700.83 feet (true vertical) 8246 8313 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 30 - 110 30 - 110 1490 470 Surface 2484' 13- 3/8 "68 #/72 #K- 55/L -80 29 - 2513 29 - 2513 Production 9905' 9 -5/8" 47# L -80 28 - 9933 28 - 8763 6870 4760 Liner 62' 3 -1/2" 8.81# L -80 9317 - 9379 8246 - 8297 Liner 1536' 3- 3/16" 6.2# L -80 9379 - 10915 8297 - 9024 Liner 1065' 2 -7/8" 6.16# L -80 10915 - 11980 9024 - 8685 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: - _ • Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 9455 27 - 8360 Packers and SSSV (type, measured and true vertical depth) 3.7" BAKER KB LINER TOP PACKER 9317 8246 4 -1/2" Baker SB -3A HYD PERM PKR 9398 8313 RECEIVED 12. Stimulation or cement squeeze summary: ry : AUG 2 5 2011 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Mika Oil & Gas Cot. Gommission Anclterbg8 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 739 39,563 1,205 763 Subsequent to operation: 838 23,664 3,283 679 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Developments 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil •• IN Gas ❑ WDSPL ❑ GSTOR ❑ WINJ p WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - • - Lastufka�4 Title Petrotechnical Data Technologist Signatur= MA s Phone 564-4091 Date 8/25/2011 RBDMS AUG 2 6 201P427 Form 10 -404 Revised 10/2010 a'..26.1( Submit Original Only 4 41( Sk4 01 -28A 209 -125 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -28A 12/19/09 PER 10,500. 10,640. 9,073.33 9,070.48 01 -28A 12/19/09 PER 10,750. 10,780. 9,057.14 9,051.98 01 -28A 12/19/09 PER 11,290. 11,320. 8,955.08 8,948.02 01 -28A 12/19/09 PER 11,720. 11,780. 8,793.69 8,768.07 01 -28A 12/19/09 PER 11,810. 11,830. 8,756.04 8,748.25 01 -28A 8/3/11 BPS 11,700. 11,830. 8,802.25 8,748.25 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 01 -28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/3/2011 **Continued from WSR 08- 02 -11 ** Scope; PPROF, SCMT, CIBP Continue logging SCMT w/ 1.61" ctc, 1.69" dfcv, disco, 1.67" ported crossover, 1.75' KJ, 1.69" SCMT /GR/CCI . BHA OAL = 37.09'. Completed two 30 fpm up passes from flag at 11909' to 9200' while keeping hole full of 1% KCL. painted flag at 11600' on last pass.Pooh. MU and RIH w/ 1.61" ctc, 1.69" dfcv, disco, 1.49" crossover, 1.69" inflation valve, setrting tools, 2.21" adapter, 2.22" CIBP (oal= 15.94') stop and tie into !flag and set 2 7/8" BOT CIBP at 11700' stack 2k down wt on plug, pick up clean and ,pooh. Freeze protect well w/ 52 bbls of 50/50 meth. Recovered ball. * *job complete ** FLUIDS PUMPED BBLS 214 1% KCL W/ 0.6% SAFELUBE 52 50/50 METH 266 TOTAL TREE= FMC GEN 4 WELLHEAD = FMC • SAFETY NO * * *4 -1 /2" CHROME TBG* ** ACTUATOR = BAKER C _ ** *WELL AN > 70° @ 10353' * ** KB. ELEV = 70' BF. ELEV = ..._ -.. — ? ' 1 KOP = 2800' Max Angle = 116° @ 11625' I 2219' 1- 14 -1/2" HES X NIP, ID = 3.813" 1 Datum MD = 10054' Datum TV D = 8800' SS 113 -3/8" CSG, 68 #/72 #, K- 55/L -80, ID = 12.347" I-1 2513' 1-41 ' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3288 3262 27 CA -MMG -M DOME RK 16 12/25/09 2 5666 5256 33 CA -MMG -M SO RK 20 12/25/09 Minimum ID = 2.360" 9322' 3 7745 6967 36 CA -MMG -M DMY RK 0 01/03/99 4 9283 8217 34 CA -MMG -M DMY RK 0 01/03/99 BOT SEAL ASSY 9317' j--I BOT 45 KB LTP, ID = 2.370" I ► e ill ,, 9322' H BOT SEAL ASSY, ID = 2.360" I TOC I-1 9325' ►# 9325' H3.70" BTT DEPLOYMENT SLV , ID = 3.00" I �$ '411111 9346' H3-1/2" HES X NIP, ID = 2.812" I 3 -1/2" LNR, 8.81 #, L -80 STL, -I 9379' 14*, 141 ►� 9379' 3 -1/2" X 3- 3/16 ", ID = 2.786" .0087 bpf, ID = 2.990" �+ A ' ♦4 •1 1'i ■•• 4 -1/2" TBG, 12.6 #, 13 - CR NEW VAM, —I 9386' I *I * i • XO TO 13 - CR NSCT •I 1 9398' I'i 9.5/8" X 4 -h12" BKR SB -3 PKR, ID = 3.875" 1 Z�Est A Q 4 I I 9432' 1- 14 -1/2" HES X NIP, ID = 3.813" Behind 4 -1/2" TBG, 12.6 #, 13 - CR NSCT, 9455' CT LNR .0152 bpf, ID = 3.958" 9455' — 14 -1/2" WLEG, ID = 3.958" 1 1IL I H ELMD TTNOTLOGGED 1 I3 5/8" BKR WHIPSTOCK H 9923' " # D = 8 9 -5/8 CSG, 47 , L -80, I.681" —9933 � H MILLOUT WINDOW (01 -28A) 9924' - 9933' RATAG 9933 ' ' i. - 1 ■ 1 10915' I- 3 -3/16 X 2 -7/8" X0, PERFORATION SUMMARY 4/4444444444 tttOtNN+ ID = 2.377 "_ REF LOG: SWS MCNL /GR/CCL 12/18/09 t1.t.1.��1.t.1.��1t�1� 11700' ( 2 -7I$" CIBP ANGLE AT TOP PERF: 85° @ 10500' ∎r' (08/03/11) Note; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10500 - 10640 0 12/19/09 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, -I 10915' , 2" 6 10750 - 10780 0 12/19/09 ID = 2.80" e4�1�1 2" 6 11290 - 11320 0 12/19/09 44. 2" 6 11720 - 11780 C 12/19/09 1 PBTD I 1 11943' 2" 6 11810 - 11830 C 12/19/09 - _ - 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, -I 11980' 1 ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/28/86 ORIGINAL COMPLETION WELL: 01 - 28A 01/03/99 RWO PERMIT No: 2091250 12/20/09 RRW CTD SIDETRACK (01 - 28A) API No: 50 - 029 - 21597 - - 01/12/10 WH/JMD DRLG DRAFT CORRECTIONS SEC 8, T1ON, R15E, 1500" FWL & 958' FNL 08/08/11 RMFV PJC SET CIBP (08/03/11) BP Exploration (Alaska) uo9 5 24 -AUG -2011 SchNMMkerge No. 5782 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacific. 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 11 -09A BCRC -00086 PPROF WI DEFT & GHOST 16-Jul-11 1 1 MPJ -15 BD88 -00141 IPROF 25-Jul-11 1 1 MPJ -18 BCRC -00108 (PROF 24-Jul-11 1 1 MPI -08 BAUJ -00096 IPROF 26-Jul-11 1 1 3- 31/K -32 BBSK -00082 PPROF WI DEFT & GHOST 26-Jul-11 1 1 M -08 BCRJ -00104 SBHPS 8- Aug -11 1 1 01 -28A BUTT -00001 PPROF WI DEFT & GHOST 2- Aug -11 1 1 01 -28A BUTT-00001 CEMENT BOND LOG 3- Aug -11 % I 1 2- 341P -14 BCRC -00109 IPROF 27-Jul-11 1 1 Z -12 BJGT -00058 IPROF 2- Aug -11 1 1 _ V -03 BG4H -00066 SBHPS 29-Jul-11 1 1 W -34A BINC-00054 PRIMARY DEPTH CONTROL 26-Jul-11 1 1 17 -02 AWJI -00151 PPROF WIDEFT 14-Jul-11 1 1 A -11 BSM4 -00018 (PROF 1- Aug -11 1 1 P1 -07A AWJI -00152 XFLOW 8- Aug -11 1 1 F -29A BG4H -00072 SBHPS 10- Aug -11 1 1 11 -11 BBSK -00085 PPROF WIDEFT 1- Aug -11 1 1 Z -06 BD88 -00146 TEMP SURVEY 3- Aug -11 1 1 Z -20 BBSK -00085 SBHPS 31-Jul-11 1 1 MPF -13 BUTT -00003 (PROF 9- Aug -11 1 1 MPL -15 BUTT -00003 IPROF 5- Aug -11 1 1 MPK-33 BJGT -00056 USIT 30Jul -11 £- I 1 L2 -18A AWJI -00153 LEAK DETECTION LOG 11- Aug -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 - 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 DATA SUBMITTAL COMPLIANCE REPORT 2/10/2011 Permit to Drill 2091250 Well Name /No. PRUDHOE BAY UNIT 01 -28A Operator BP EXPLORATION (ALASKA) INC API No. 50 -029- 21597 -01 -00 MD 11980 TVD 8685 Completion Date 12/20/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR / CCL / CNL (data taken from Logs Portion of Master Well Data Maint 0 Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / � T � ype - Med /Frmt Number Name Scale Media No Start Stop CH Received Comments 4�Rpt LIS Verification 9900 11980 Open 3/18/2010 LIS Veri, GR, ROP, RAD, i RAS, RPD, RPS ''ED C Lis 19460-Tduction /Resistivity 9900 11980 Open 3/18/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 4t Induction /Resistivity 25 Col 9923 11980 Open 3/18/2010 MD MPR, GR -Log Induction /Resistivity 5 Col 9923 11980 Open 3/18/2010 TVD MPR, GR ESg Gamma Ray 25 Col 9923 11980 Open 3/18/2010 MD GR )‘6g Neutron 25 Blu 9122 11852 Case 4/26/2010 MCNL, Mem Lee CCL, GR, TNF, TNN `E15 C Lis 19582 "�leutron 9122 11852 Case 4/26/2010 MCNL, Mem Lee CCL, GR, TNF, TNN ED Asc Directional Survey 9954 11980 Open • pt Directional Survey 9954 11980 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/10/2011 Permit to Drill 2091250 Well Name /No. PRUDHOE BAY UNIT 01 -28A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21597 -01 -00 MD 11980 TVD 8685 Completion Date 12/20/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y Daily History Received? / N Chips Received? Y-/-Pl Formation Tops / N Analysis • Received? Comments: Compliance Reviewed By: Date: _ 1 ( � APR J C L(.)I 04/21/10 Schiumherger NO. 5511 r + >' « Gel Uprth. La.s .,, Alaska Data & Consulting Services Company: State of Alaska AlletWiter.re 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 Well Job # Log Description Date BL Color CD F -30 BBUO-00014 PRODUCTION PROFILE 1 if a ( b /M 0 fri 03/17/10 1 1 12 -14AL1 AYKP -00079 PRODUCTION PROFILE an 1 19, -b(_ 03/18/10 1 1 12 -15 B3S0.00049 PRODUCTION PROFILE 1 '3' 4 I a, - 03/18/10 1 1 17 -11 B350.00053 PRODUCTION PROFILE — . . . ..„ ; 03/30/10 1 1 17 -05 B350-00052 PRODUCTION PROFILE , e — ow - — a 03/29/10 1 1 J -23A BCUE -00010 MEM PRODUCTION PROFIL U( . � ^ -' . 8 04/14/10 1 1 `Q — � 07-18 BC72. FL DETERMINATION/PERF f '0 — if .511 1 04/17/10 1 1 LE 04/14/10 1 1 o Ill P2 -31A B3S0 -00046 CH EDIT PDC JUNK BASKET) 0011 — 1 b I9 513 02/27/20 `1 I �0 C -15A AWJI -00069 MCNL • - 4 02/18/10 1 1 K -07E B2NJ -00054 MCNL 01 -28A BAUD -00004 MCNL '‘ b 9 .. ( 9 5' 1 W 12/18/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 RECEIVED • STATE OF ALASKA III ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 9 2010 4 WELL COMPLETION OR RECOMPLETION REPORT A la. Well Status: ® Oil ❑ as 0 SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: AnChorag6 2OAAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL 0 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. 12/202009 209 - 125 3_ Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 12!102009 50 - 029 - 21597 - 01 - 00 , 4a. Location of Well (Governmental Section): 7_ Date T.D. Reached: 14. Well Name and Number Surface: 12!162009 PBU 01 -28A ` 4323' FSL, 3780' FEL, SEC_ 08, T1ON, R15E, UM 8. (ft above MSL): 70' 15. Field / Pool (s )- Top of Productive Horizon: 86' FSL, 113' FEL, SEC_ 05, T1ON, R15E, UM GL (ft above MSL): 42.64' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD): Oil Pool 729' FSL, 1411' FEL, SEC. 05, T1ON, R15E, UM 11943' 8701° 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x- 698839 y- 5939969 Zane- ASP4 11980' 8685' ADL 028329 & 028328 TPI: x- 702473 y- 5941109 Zone- ASP4 11. SSSV Depth (MD+TVD): 17. Land Use Permit: 1 Total Depth: x- 701157 Y 5941718 Zone- ASP4 None 18. Directional Survey ® Yes ®� 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MIND DIR, GR, RES, GR / CCL! CNL 9924' 8755' 23. CASING, UNER AND CEMENTING RECORD HOLE Cass (Wr. PER FT. GRADE S Top I Borrow To ' 1 Bouar -nail S� �o I FULLED 20" 92# H Surface 110' Surface 110' 3(T sx Poleset 13 -3/8' 681k ! 72# K - 55 /1 Surface 2513' Surface 2513' 17-1/2 sx CS III, 400 sx CS II ;; Top Job: 125 sx CS II 9-5/8" 47# L Surface 9924' Surface 8755' 12-1/4" 100 sx Class '0'. 300 sx Coldset I 3-1/2" x 3 -3/16" 9.21/ 6.211 L-80 9317' 11980' 8246' 8685' 4-1/8" 160 sx Class 'G x 2 -7/8" / 6.16# 24. Open to production or injection? ® Yes 0 No 25. Tussle RECORD If Yes, Iist each interval open SIZE DEPTH SET (MO PACKER SET (MD 1 TVD) (MD+TVD of Top & Bottom; Perforation Size and Number): 2" Gun Diameter, 6 spf 4-12', 12.6#, 13Cr 9455' 9398' - 8313' MD TVD MD TVD 10500' -10640' 9073' - 9070" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10750' - 10780' 905T - 9052' 11290' - 11320' 8955' - 8948' DEPTH INTERVAL (MD), AMOUNT AND KIND OF MATERIAL USED 11720' - 11780' 8794' - 8768" 2500' Freeze Protect with Diesel 11810' - 11830' 8756' - 8748" 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 3, 2010 Flowing Date of Test: Hours Tested: Production For Oii-Bat: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: 1/132010 24 Test Period 4 1,354 34,527 1,486 80 25,500 Flow Tubing Casing Press: Calculated OIL -BBL: GAS - MCF: WATER -BBL: OIL GRAVITY API (corm): Press. 755 650 24 -Hour Rate ♦ 1,354 34,527 1,486 Not Available 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ®No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, Iist 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, cone chips, photographs and laboratory analytical results per 20 AAC 250.071. COMPLE1'i0t4 None e,, h '._ .. Form 10-407 Revised S MAR 2010 s_�-� y, C j O � NTINUED ON REVERSE 3 '2 -/ 0 3� 29. GEOLOGIC MARKERS (List all formations angirkers encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briery summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. (From Parent Wellbore) Zone 4 9780' 8633' None (Top of Productive Interval) Zone 3 9995' 8819' Zone 2C 10065' 8879' Zone 2B 10166' 8954' Zone 2A 10398' 9056' Zone 2A 10779' 9052' Zone 2B 11282' 8957' Zone 2C 11505' 8885' Zone 3 11670' 8815' Zone 4A 11805' 8758' Formation at Total Depth (Name): Zone 4B (From Base) 11805' 8758' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, New As -Built (for Surface Location) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. /�en Signed: Terrie Hubble -1 s t 1 (.44 . Title: Drilling Technologist Date: t / PBU 01 - 28A 209 - 125 Prepared By Name/Number Tenie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Wilmer Hoffman, 564 -4592 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water- Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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. Item 13: The API number reported to AOGCC must be 14 digits (ex 50 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. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: 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. Item 30: 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 12/2009 Submit Original Only 0 e h l I t a: } : 1 ' ' .. 7(''''' : : ----rn \ `. ., - .::.7 ''' : C;- \l '' ''' '-.'''';;-- •1 .. i ,./..,,,, 0_ c i _ 7/ ---".r '.., , _ , - 1 f D 17 18 ,sD`S1 co ` --t —E21 32 �e > F = fr 15 3 .t:, r f Q - --I -1122 33 ` (t �'% fr 14 III � f 16 ---t_. ■23 MI 4 £4 r r r, < 13 d ': 12 VICINITY MAP —■25 - 6 11 NTS -- ■26 18 -- ��� { { { {{ {fit c ...., L ir c ,■..... %o 0 t ,r----,___ 3, /g 1 a I k DRILL SITE 1 34 i `J i 10 S V. Leonard J. O'Hanley ° ° ° Z ._ . �� 11386 `` LEGEND i � I/ i , 1j ''N ts SIOW - , ; `�� i * AS —BUILT WELL { {„"` SURVEYOR'S CERTIFICATE • EXISTING WELL I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED NOTES: P THE STATE C OF L ALASKA R AND I THAT 1. DATE OF SURVEY: JANUARY 15 & 17, 2010. THIS AS —BUILT REPRESENTS A SURVEY 2. REFERENCE FIELD BOOK: NS10 -02 PG's. 33 -39. MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL 3. COORDINATES ARE DATUM NAD 27, ALASKA STATE PLANE, ZONE -4. DIMENSIONS AND OTHER DETAILS ARE 4. GEODETIC COORDINATES ARE NAD -27. CORRECT AS OF JANUARY 15, 2010. 5. DRILL SITE 1 AVERAGE SCALE FACTOR IS: 0.9999443. 6. HORIZONTAL & VERTICAL CONTROL IS BASED ON GRAPHIC SCALE DS -1 OPERATOR MONUMENTS. 0 250 500 1000 7. ELEVATION DATUM ARCO MLLW. ( IN FEET ) 1 inch = 500 ft. LOCATED WITHIN PROTRACTED SEC. 08, T. 10 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) TUBING SPOOL OFFSETS 1 -28 Y= 5,939,969.35 N= — 2256.63 7014'24.193" 70.2400536' 42.64 4323FSL X= 698,838.28 E= 1150.23 148'23'38.981" 148.3941614' 3780 FEL 1 -29 Y= 5,939,910.35 N= — 2,316.91 70'14'23.609" 70.2398913' 42 30 ' 4264 FSL X= 698,850.61 E= 1149.82 148'23'38.669" 148.3940747' 3769 FEL F. Robert BARNHART h • !`� CHECKED: WOLF D II Ul f� DATE 1/16/10 �. 'a , 102 SHEET EOA DRILL SITE 1 ISM. JOB NO FRAW1NC . AS —BUILT WELL LOCATION � � ...„. SCALE 00 1/16/10 ISSUED FOR INFORMATION TFB VI nor MOW we t =see WELLS 1 -28, 1 -29 1 OF 1 NO. DA1E REVISION BY CHK mar. MAx° Mm 1 BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2009 13:00 - 17:00 4.00 MOB P PRE MOBILIZE RIG FROM 01 -19 TO 01 -28 17:00 - 21:30 4.50 RIGU P PRE ACCEPT RIG AT 1700 HRS, 12/05/09. NU BOPS AND RU ASSOCIATED RIG EQUIPMENT 21:30 - 21:45 0.25 RIGU P PRE PJSM FOR PULLING COIL ACROSS AND STABING INTO INJECTOR. 21:45 - 00:00 2.25 RIGU P PRE PULL COIL ACROSS AND STAB INTO INJECTOR AND LUBRICATOR. 12/6/2009 00:00 - 02:00 2.00 RIGU P PRE FINISH PULLING COIL ACROSS, MU CTC AND BALL CATCH 02:00 - 07:30 5.50 BOPSUF P PRE TEST BOPE PER AOGCC REGS,, PERMIT TO DRILL, AND WELL PLAN TEST TO 250 PSI LOW AND 3,500 PSI. TEST ANNULAR TO 2500 PSI ALL DATA RECORDED ELECTRONICALY AND ON ROLL CHART ALL DATA RECORDED INTO AOGCC TEST FORM AND EMAILED TO AOGCC TEST WITNESS WAIVED BY JEFF JONES OF AOGCC 07:30 - 07:40 0.17 WHIP P WEXIT BOPE TEST COMPLETE. RECOVER 7/8' BALL FROM COIL REEL. 07:40 - 08:40 1.00 WHIP P WEXIT REVERSE CIRCULATE COIL FOR SLACK MANAGEMENT 08:40 - 08:55 0.25 WHIP P WEXIT PJSM FOR CUTTING COIL WITH HYDRAULIC CUTTER 08:55 - 13:00 4.08 WHIP P WEXIT CUT COIL TO FIND E -LINE. CUT TOTAL OF 377' OF COIL. MEG E -LINE. MU AND PULL TEST CTC TO 40K. MU BHI HEAD. PT CTC TO 500 PSI LOW AND 3500 PSI HIGH 13:00 - 13:15 0.25 WHIP P WEXIT PJSM REGARDING MU OF PILOT MILLING BHA 13:15 - 13:45 0.50 WHIP P WEXIT MU 3.80" PILOT MILLING BHA 13:45 - 14:30 0.75 WHIP P WEXIT CIRCULATE COIL VOLUME FORWARD FOR SLACK MANAGEMENT 14:30 - 16:10 1.67 WHIP P WEXIT RIH WITH 3.80" PILOT MILLING BHA ORIENTED TO THE HIGH SIDE._ 16:10 - 17:50 1.67 WHIP P WEXIT LOG TIE IN PASS AT 90 FPH FROM 9300'. UNABLE TO GET TIE IN AT THIS DEPTH. PUH FOR RE -LOG FROM 8700'. UNABLE TO GET TIE IN AT THIS DEPTH. PUH TO 7250 FOR RE -LOG. PUW AT 9300' = 44K. 17:50 - 19:00 1.17 WHIP N HMAN WEXIT POOH FOR BHI TOOL FAILURE PJSM FOR HANDELING BHA'S WHILE POOH 19:00 - 20:10 1.17 WHIP N HMAN WEXIT LD FAILED BHA #1 AND MU /PU NEW BHA #2 WITH NEW DGS AND HOT STAB ON AND TEST TOOLS 20:10 - 21:40 1.50 WHIP N HMAN WEXIT RIH BHA #2 STILL READING HOT. SUSPECT RA TUBING.? BHA #1's DGS TESTED GOOD ON SURFACE. CONTINUE IN HOLE TRIED A TIE IN © 7250 FT AGAIN - STILL UNABLE RIH TO 9300 FT - END NPT 21:40 - 21:55 0.25 WHIP P WEXIT CONTINUE TO RIH TAG TOP OF CEMENT © 9501.6 FT WITH NO CORRECTION IT MATCHES EXPECTED TOC. 21:55 - 22:05 0.17 WHIP P WEXIT TAG AT TOP OF CEMENT CO 9501.6 FT RIHWT = 24K PU WT = 40K FS = 2540 PSI CP 2.53 BPM UNABLE TO ORIENTATE WITH HOT - HAS GOOD COMS Printed: 1/4/2010 8:22:08 AM 41/ 1 1111 BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2009 21:55 - 22:05 0.17 WHIP P WEXIT BACK AND FORTH AND CAN READ VALVES OPENING AND CLOSING BUT TOOL WILL NOT ORIENTATE. 22:05 - 22:30 0.42 WHIP N HMAN WEXIT UNABLE TO ORIENT TF - HOT HAS GOOD COMS BACK AND FORTH AND CAN READ VALVES OPENING AND CLOSING BUT TOOL WILL NOT ORIENTATE. 22:30 - 22:50 0.33 WHIP N HMAN WEXIT SET DOWN ON TOC AT 9501 FT. PU TO BO WT AND SET UP FOR CCL LOG WHILE POOH FOR TOOL FAILURE. LOG UP TO 9230 FT. STOP AND OPEN EDC 22:50 - 00:00 1.17 WHIP N HMAN WEXIT POOH TO SWAP BACK TO BHA #1's TOOLS. 12/7/2009 00:00 - 00:20 0.33 WHIP N HMAN WEXIT CONTINUE TO POOH PJSM FOR LD / PU BHA 00:20 - 01:10 0.83 WHIP N HMAN WEXIT LD BHA #2 AND PU BHA #3 01:10 - 02:45 1.58 WHIP N HMAN WEXIT RIH WITH BHA #3 WHICH HAS ALL OF BHA #1's TOOLS. 02:45 - 03:10 0.42 WHIP N HMAN WEXIT LOG FOR TIE IN WITH CCL AT GLM #4 FROM 9250 FT TO 9400 FT. WITH -1 FT CORRECTION TO PDC LOG. CAN'T USE GR DUE TO HOT TUBING NOT ALLOWING FOR USE OF DGS. WERE TIED INTO GEO PDC LOG BY CORRECTING THE "19 NOV 09 PDS CCL LOG" TO THE "29 MAY 1986 CEMENT BOND LOG" WICH WAS CORRECTED TO GEO PDC LOG. 03:10 - 03:25 0.25 WHIP N HMAN WEXIT CONTINUE TO RIH AND ESTABLISH FREE SPIN OF 2550 PSI @ 2.6 BPM TAG TOC AT 9,503.7 FT 03:25 - 06:00 2.58 WHIP P WEXIT DRILL AHEAD WITH 2850 PSI @ 2.6 BPM WITH 500 #'S DHWOB AND ROP =48 FPH SLOWING DOWN TO 20 FPH WITH 3,200 #'S DH WOB MADE WIPER @ 9558 FT DRILLED TO 9565 FT 06:00 - 12:40 6.67 WHIP P WEXIT CONTINUE DRILLING AHEAD FS =2600 PSI I@ 2.6 BPM MILLING WITH 3020 PSI (420 PSI MW) DHWOB= 2850 #'S ROP =28 FPH 12:40 - 13:00 0.33 WHIP P WEXIT WIPER TO GLM #4 AND TIE -IN LOG FROM 9250' TO 9550' AT - 20 FPM 13:00 - 18:00 5.00 WHIP P WEXIT CONTINUE TO MILL AHEAD FROM 9670 TO 9760 FT 18:00 - 18:35 0.58 WHIP P WEXIT WIPER TRIP UP TO 9430 FT INSIDE 4 -1/2" TUBING TAIL. 18:35 - 23:00 4.42 WHIP P WEXIT CONTINUE TO DRILL 3.80" PILOT HOLE FROM 9760 FT TO 9850 FT MADE SHORT TRIPS AT 9790 FT AND 9820 FT. ROP'S OF 20 TO 30 FPH BUT PRETTY MUCH 25 FPH IS THE NORM. HAVING PROBLEMS KEEPING SHAKERS CLEANED OFF AND WE ARE NOT RUNNING CENTRAFUGES DUE TO NORDIC SOP. 23:00 - 23:35 0.58 WHIP P WEXIT WIPER TO TUBING TAIL FROM 9850 FT. 23:35 - 00:00 0.42 WHIP P WEXIT CONTINUE TO DRILL AHEAD FROM 9850 FT TO 9859 FT 12/8/2009 00:00 - 04:30 4.50 WHIP P WEXIT CONTINUE TO DRILL 3.80" CEMENT PILOT HOLE TO 9880 FT TO 9950 FT MADE 2 SHORT TRIPS AND HAD CONSISTANT ROPS 04:30 - 05:00 0.50 WHIP P WEXIT WIPER INTO TUBING TAIL FROM 9950 FT AND THEN BACK DOWN TO 9525 FT 05:00 - 05:20 0.33 WHIP P WEXIT DRESS TOP OF CEMENT PILOT HOLE FROM 9525 FT UP WITH 30 DEG RT AND L OF AS DRILLED TF WITH ONE Printed: 1/4/2010 8:22:08 AM 411 1111110 BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2009 05:00 - 05:20 0.33 WHIP P WEXIT PASS EACH. 05:20 - 07:00 1.67 WHIP P WEXIT PULL INTO TUBING TAIL OPEN EDC RIH TO PUT EDC INTO CEMENT PILOT AND THEN POOH WITH 3.3 BPM THROUGH THE 9 -5/8" SECTION AT 11 FPM. AFTER PULLING INTO THE 4 -1/2" TUBING TAIL BROUGHT THE PUMPS TO 2.5 ON THE OUT RATE. AND POOH NORMAL 07:00 - 07:15 0.25 WHIP P WEXIT PJSM WITH CREW REGARDING LD OF PILOT MILLING BHA 07:15 - 09:30 2.25 WHIP P WEXIT LD MILLING BHA AND PU 3.625" BTT WHIPSTOCK DRIFT 09:30 - 11:15 1.75 WHIP P WEXIT RIH WITH 3.625" WHIPSTOCK DRIFT ASSEMBLY 11:15 - 12:00 0.75 WHIP P WEXIT LOG TIE IN PASS 9300' AT 20 FPM. PUW = 42K AT 9250' -3' CORRECTION 12:00 - 15:15 3.25 WHIP N STUC WEXIT RIH AT 30 FPM FOR DRY TAG OF PILOT HOLE. TAG AT 9740' AND UNABLE TO MOVE PIPE. CONTINUE TRYING TO WORK COIL FREE. STACK WT, JAR DOWN, STILL STUCK PULL TO 66K AND JAR FREE. 15:15 - 17:00 1.75 WHIP N DPRB WEXIT POH FOR CEMENT MILLING / REAMING BHA. 17:00 - 17:15 0.25 WHIP N DPRB WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING BHA. 17:15 - 17:40 0.42 WHIP N DPRB WEXIT LAY OUT DRIFT BHA. RECOVERED 100% OF TOOLS. M/U CEMENT MILLING / REAMING BHA WITH 3.79" MILL AND 3.78" STRING REAMER. 17:40 - 19:45 2.08 WHIP N DPRB WEXIT RIH TO 9,250' 19:45 - 20:05 0.33 WHIP N DPRB WEXIT LOG TIE IN FROM 9,250' TO 9,403' -3' CORRECTION RESET DEPTH TO 9,400' 20:05 - 20:15 0.17 WHIP N DPRB WEXIT RIH TO TOP OF CMT @ 6FPM BRING PUMPS UP TO 1.9BPM ORIENT TOOL 160DEG LHS 20:15 - 00:00 3.75 WHIP N DPRB WEXIT REAM 3.79 PILOT HOLE FS 2,750PSI @ 2.4BPM MILL TO 9,550' & BACK REAM TO 9,500' SMOOTH MILL TO 9,600' & BACK REAM TO 9,500' SMOOTH MILL TO 9,650' & BACK REAM TO 9,500' SMOOTH MILL TO 9,700' & BACK REAM TO 9,525' SMOOTH MILL TO 9,770' & BACK REAM TO 9,525' SMOOTH CHANGE TF TO ODEG HS & REAMED 9,725' TO 9,775' CHANGE TF BACK TO 160DEG LHS BACK REAM TO 9,525' SMOOTH MILL TO 9,800' & BACK REAM TO 9,525' SMOOTH MILL TO 9,850' & BACK REAM TO 9,525' SMOOTH 12/9/2009 00:00 - 02:50 2.83 WHIP N DPRB WEXIT CONTINUE REAM 3.79 PILOT HOLE FS 2,750PSI @ 2.4BPM MILL TO 9,900' & BACK REAM TO 9,525' SMOOTH MILL TO 9,950' & TAG TD, BACK REAM TO 9,500' 02:50 - 03:20 0.50 WHIP N DPRB WEXIT PU TO 9,500',OPEN EDC & RIH TO 9,550' & CIRCULATE 2 BU WITH 30BBLS HIGH VIS GEO VIS SWEEP CO 3.1BPM WHILE WASHING UP & DOWN IN 9 -5/8" FROM 9,500' TO 9,450' WITH EDC Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/9/2009 03:20 - 03:40 0.33 WHIP N DPRB WEXIT DROP PUMPS TO MIN RATE @ .2BPM WHILE RIH TO TAG TD TAG TD @ 9,950' WITHOUT STACKING WT 03:40 - 05:00 1.33 WHIP N DPRB WEXIT POH @ .8BPM TO 9,500' INCREASE PUMP RATE TO 2.8BPM WHILE POOH PJSM FOR LD MILLING BHA WHILE POH 05:00 - 05:40 0.67 WHIP N DPRB WEXIT LD MILLING BHA GAUGED MILL AT 3.77" ORIGINAL DIA 3.79 05:40 - 06:30 0.83 WHIP N DPRB WEXIT PREP RIG FLOOR FOR CHROME TUBING MANAGEMENT 06:30 - 06:45 0.25 WHIP N DPRB WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CUTTING COIL, RE- HEADING AND M/U BHA. 06:45 - 09:00 2.25 WHIP N DPRB WEXIT CUT OFF 103' OF COIL AND M/U CTC, PULUPRESS TEST. M/U BHI UQC AND TEST E -LINE OK. 09:00 - 09:45 0.75 WHIP N DPRB WEXIT M/U 3.625" DRIFT BHA FOR RUNNING WHIPSTOCK 09:45 - 12:15 2.50 WHIP N DPRB WEXIT RIH WITH WHIPSTOCK DRIFT BHA #6. CIRC 0.3 BPM, 900 PSI. UP WT AT 9500' = 42K, CIRC 2.0 BPM, 2000 PSI, RIH CLEAN TO 9700', UP WT = 43 K, RIH CLEAN TO 9850', UP WT = 43K, RIH CLEAN AND TAG PBTD OF 9954', UNCORRECTED. 12:15 - 14:00 1.75 WHIP P WEXIT POH WITH WHIPSTOCK DRIFT. CIRC 2.0 BPM, 1950 PSI. 43K UP WT OFF BOTTOM. POH CLEAN THRU CEMENT. POH. 14:00 - 14:15 0.25 WHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING BHA. 14:15 - 15:00 0.75 WHIP P WEXIT LAY OUT DRIFT BHA. M/U BTT OPEN HOLE ANCHOR AND STEEL TRAY, SETTING TOOL AND COILTRAK BHA #7. TWO PIP TAGS INSTALLED 9.0' FROM TOP OF WHIPSTOCK. BHA OAL = 75.34'. 15:00 - 17:15 2.25 WHIP P WEXIT RIH WITH WHIPSTOCK BHA #7. OPEN EDC. TEST COILTRAK TOOLS. CIRC AT MINIMUM RATE AT 0.2 BPM, 700 PSI. 17:15 - 17:30 0.25 WHIP P WEXIT LOG CCL TIE -IN AT 9450', -4' CORRECTION. 43K UP WT, 24K DOWN WT. 17:30 - 18:00 0.50 WHIP P WEXIT ORIENT WHIPSTOCK TOOLFACE TO 180 DEG ROHS. RIH THRU PILOT HOLE. POSITION TOP OF WHIPSTOCK AT 9925' WITH A 180 DEG ROHS TF. CLOSED EDC. PRESS UP AND SHEARED SETTING TOOL AT 3900 PSI. STACK 3K, ANCHOR IS SET. 18:00 - 20:00 2.00 WHIP P WEXIT POH WITH SETTING TOOL BHA. CIRC 1.0 BPM, 1250 PSI. 44K UP WT. PJSM TO LD WS SETTING BHA & PU MILLING BHA 20:00 - 20:15 0.25 WHIP P WEXIT LD WS SETTING BHA 20:15 - 21:10 0.92 STWHIP P WEXIT PU WINDOW MILLING BHA 21:10 - 22:45 1.58 STWHIP P WEXIT RIH WITH WINDOW MILLING BHA RIH TO 9,480' 22:45 - 23:00 0.25 STWHIP P WEXIT LOG TIE IN TO 9,600' Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From To Hours Task Code NPT Phase Description of Operations 12/9/2009 22:45 - 23:00 0.25 STWHIP P WEXIT CORRECTION OF -6' RESET DEPTH TO 9,594' 23:00 - 23:30 0.50 STWHIP P WEXIT RIH TO TOWS WITH WINDOW MILLING BHA TAG @ 9,923.5' 23:30 - 00:00 0.50 STWHIP P WEXIT PU TO 9,914' FS 2,650PSI @ 2.5BPM RIH TO 9,923.25' TIME MILL WINDOW 1' FPH 1K WOB, 150 - 325PSI MTR WORK 12/10/2009 00:00 - 06:30 6.50 STWHIP P WEXIT PU TO 9,914' FS 2,650PSI @ 2.5BPM RIH TO 9,923.25', TOP OF WINDOW TIME MILL WINDOW 1' FPH 00:30 - 9,924.3' 1.9K, 2,955PSI 01:30 - 9,925.2' 2.5K, 2,992PSI 02:30 - 9,926.3' 1.7K, 2,856PSI 03:40 - 9,927.4' 1.5K, 2,834PSI 04:35 - 9,928.3' 1.5K, 2,823PSI 05:30 - 9,929.3' 1.1K, 2,820PSI 06:30 - 9,930.1', .5K, 2,800PSI 06:30 - 09:45 3.25 STWHIP P WEXIT MILL 3.80" WINDOW THRU 9 -5/8 ", 47 #, L -80 CASING LOWSIDE EXIT, 2.6 BPM, 2860 PSI, 1K WOB, 1 FPH TIME MILLING FOR EXIT OF WINDOW. TIME MILLED TO 9933.3'. 10' OF WINDOW MILLED. BOTTOM OF WINDOW AT 9933.3'. 09:45 - 13:00 3.25 STWHIP P WEXIT MILL 10' FORMATION, 3 -4K WOB, 2 -4 FPH, 2.6 BPM, 3100 PSI, MILLED TO 9944' 13:00 - 15:00 2.00 STWHIP P WEXIT REAM WINDOW UP AND DOWN 3 TIMES, NO MOTOR WORK. DRY TAG CLEAN AT 9944'. WINDOW IS CLEAN. 15:00 - 16:45 1.75 STWHIP P WEXIT POH TO 9600', OPEN EDC. CIRC 3.3 BPM, 2900 PSI. CLEANOUT 9 -5/8" CASING. UP /DOWN /UP. POH. 16:45 - 17:00 0.25 STWHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT MILLING BHA. 17:00 - 17:45 0.75 STWHIP P WEXIT LAY OUT MILLING BHA. MILL AND STRING REAMER GAUGED AT 3.79" NO -GO. 17:45 - 18:15 0.50 STWHIP P WEXIT COMPLETE ELECTRICAL MAINT. IN SCR ROOM 18:15 - 19:15 1.00 STWHIP P WEXIT JET BOP STACK TO CLEAR DEPRIS FROM MILLING OPERATIONS PJSM TO PU BUILD BHA 15MIN 19:15 - 20:15 1.00 DRILL P PROD1 PU BUILD BHA 20:15 - 22:00 1.75 DRILL P PROD1 RIH WITH BUILD BHA TO 9,400' 22:00 - 22:40 0.67 DRILL P PROD1 LOG TIE IN TO 9,620' CORRECTION OF -6' RESET DEPTH TO 9,614' 22:40 - 23:00 0.33 DRILL P PROD1 RIH TO TD TAG @ 9,946' 23:00 - 00:00 1.00 DRILL P PROD1 DRILL BUILD FROM 9,946' FS 2,600PSI (12) 2.5BPM MTR WORK 30 - 50PSI, 0.5K WOB, ECD 9.73 DRILL TO 9,978' Printed: 1/4/2010 8:22:08 AM • • BP EXPLORATION Page 6 o 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2009 00:00 - 06:00 6.00 DRILL P PROD1 DRILL BUILD FROM 9,978' FS 2,600PSI @ 2.5BPM 40 - 100PSI MTR WORK, .4 - .5K WOB, 9.77 ECD STALL @ 9,979', 9,994, 10,015' 01:00 - 9,995' 200PSI, .5K WOB, 9.76 ECD 02:00 - 10,004' 75PSI, 2.5K WOB, 9.71 ECD 03:00 - 10,020' 205PSI, 1.7K WOB, 9.72ECD 04:00 - 10,030' 2,750PSI, 2.2K WOB, 9.71 ECD 06:00 - 10,052', 2700 PSI, 2.3K WOB, 9.74 ECD 06:00 - 08:45 2.75 DRILL P PROD1 DRILL BUILD/TURN SECTION IN ZONE 2, 2.7 BPM, 2620 - 3500 PSI, 85L TF, 40 -60 FPH, 4K WOB, 9.8 ECD, DRILLED TO 10130'. 08:45 - 10:30 1.75 DRILL P PROD1 DRILL BUILD/TURN SECTION IN ZONE 2, 2.7 BPM, 2620 - 3500 PSI, 60L TF, 42 INCL, 40 -60 FPH, 3 -4K WOB, 9.8 ECD, DRILLED TO 10200'. 10:30 - 11:00 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. 11:00 - 12:30 1.50 DRILL P PROD1 DRILL BUILD/TURN SECTION IN ZONE 2, 2.6 BPM, 2650 - 3300 PSI, 60L TF, 55 INCL, 40 -60 FPH, 3 -4K WOB, 9.8 ECD, SWAPPED TO NEW GEOVIS AT 10240'. DRILLED TO 10,243'. 12:30 - 14:00 1.50 DRILL P PROD1 LOG MAD PASS UP TO WINDOW AT 600 FPH WITH NEW GEOVIS IN HOLE FOR CORRECT API GR LOG. RIH CLEAN TO BOTTOM. 14:00 - 14:15 0.25 DRILL P PROD1 DRILL BUILD SECTION, STACKING 4K WOB AND SLOW ROP IN CLEAN SAND. BIT IS WORN. DRILLED TO 10246'. 14:15 - 16:45 2.50 DRILL P PROD1 PON FOR BIT. OPEN EDC ABOVE WINDOW. CLEANOUT 9 -5/8" CASING AT 4.0 BPM, 3350 PSI, UP /DWN 3 TIMES. POH FOR BIT. CIRC 3.0 bpm. 16:45 - 17:00 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING COILTRAK BHA AND BIT. ALSO HOW TO CLEAN HEAVY FROST FROM DERRICK. 17:00 - 18:00 1.00 DRILL P PROD1 ISOLATE RIG FLOOR AND KEEP ALL PERSONNEL OF OF RIG FLOOR. CLEAR HEAVY FROST FROM DERRICK, 3 -4" OF FROST BUILD UP. 18:00 - 18:30 0.50 DRILL P PROD1 CREW CHANGE OVER PJSM TO LD BUILD BHA 18:30 - 19:15 0.75 DRILL P PROD1 LD BUILD BHA BIT RUNG OUT 19:15 - 19:30 0.25 DRILL P PROD1 PJSM TO PU BUILD BHA WITH USED HCC BI- CENTER BIT 19:30 - 20:15 0.75 DRILL P PROD1 PU BUILD BHA WITH USED BICENTER BIT 20:15 - 22:15 2.00 DRILL P PROD1 RIH TO 10,000' 22:15 - 22:30 0.25 DRILL P PROD1 LOG TIE IN FROM 10,000' TO 10,022' CORRECTION +1' RESET DEPTH TO 10,023' 22:30 - 10:40 12.17 DRILL P PROD1 RIH TO TD TAG TD @ 10,253' 10:40 - 00:00 13.33 DRILL P PROD1 DRILL BUILD FROM 10,253' FS 2,100PSI @ 2.5BPM Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From To Hours Task Code NPT Phase Description of Operations 12/11/2009 10:40 - 00:00 13.33 DRILL P PROD1 200 - 300PSI, .8 - 1K WOB, 9.48ECD DRILL TO 10,328' 12/12/2009 00:00 - 02:00 2.00 DRILL P PROD1 DRILL BUILD FROM 10,328' FS 2,100PSI @ 2.5BPM 01:45 - 10,370', 2,560PSI, 2.6k WOB, 9.44 ECD 02:00 - 10,378' 02:00 - 02:40 0.67 DRILL P PROD1 WIPER TO WINDOW 02:40 - 06:00 3.33 DRILL P PROD1 DRILL BUILD FROM 10,378' FS 2,320PSI, © 2.5BPM 03:00 - 10,389', 2,500PSI, 1.2K WOB, 9.48 ECD STALL CO 10,407, 10,412', 10,459', 10,486', 10,489' 04:00 - 10,450' SHORT WIPER TO 10,350' DUE TO FAST ROP 05:15 - 10,483' 2,600PSI, 2.3K WOB, 9.48 ECD 0600 DRILLED TO 10500'. 06:00 - 08:15 2.25 DRILL P PROD1 DRILL BUILD/TURN, 2.5 BPM, 2300 -2600 PSI, 70L TF, 85 DEG INCL, 50 FPH, 1 -2K WOB, LANDED WELL AT 10575' AT 9007' TVD. DRILLED TO 10575'. 08:15 - 11:00 2.75 DRILL P PROD1 POH FOR LATERAL / RES BHA. OPEN EDC ABOVE WINDOW AND WASH 9 -5/8" CASING AREA AT 4 BPM, UP /DWN /UP POH WHILE CIRC 3.0 BPM. 11:00 - 11:15 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT DRILLING BHA. 11:15 - 11:45 0.50 DRILL P PROD1 LAY OUT DRILLING BHA. BIT HAD CHIPPED CUTTERS. BIT GRADE [ 4,3,1 ]. 11:45 - 12:00 0.25 BOPSUF P PROD1 FUNCTION TEST BOPE. WEEKLY TEST. 12:00 - 14:00 2.00 DRILL N RREP PROD1 RIG ELECTRICIAN MODIFIED GENERATOR BREAKER CONTROLS IN SCR ROOM. 14:00 - 14:15 0.25 DRILL P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR RUNNING CSH WORKSTRING 14:15 - 15:00 0.75 DRILL P PROD1 RIH WITH 5 JTS OF 1 -1/4" CSH WORKSTRING. TROUBLE WITH CLUTCH ON DRAWWORKS. 15:00 - 19:00 4.00 DRILL N RREP PROD1 REPLACE AIR CLUTCH FOR RIG DRAWWORKS. SPARE PARTS WERE ON NORDIC 2 IN MILNE POINT. 19:00 - 22:30 3.50 DRILL N PROD1 MU 1 -1/4" CSH WORKSTRING 22:30 - 22:45 0.25 DRILL N PROD1 PJSM TO STAND BACK 1 -1/4" CSH IN DERRICK 22:45 - 00:00 1.25 DRILL N PROD1 STAND BACK 1 -1/4" CSH IN DERRICK 12/13/2009 00:00 - 00:45 0.75 DRILL P PROD1 STAND BACK 1 -1/4" CSH IN DERRICK 00:45 - 01:00 0.25 DRILL P PROD1 PJSM TO MU LATERAL BHA ASSY 01:00 - 02:00 1.00 DRILL P PROD1 MU LATERAL BHA ASSY 02:00 - 04:00 2.00 DRILL P PROD1 RIH WITH LATERAL BHA TO 10,000' 04:00 - 04:30 0.50 DRILL P PROD1 LOG TIE IN FROM 10,000' TO 10,042' CORRECTION OF -3' RESET DEPTH TO 10,039' 04:30 - 05:00 0.50 DRILL P PROD1 RIH TO TD 10,571' 05:00 - 08:15 3.25 DRILL P PROD1 DRILL LATERAL FROM 10,571' FS 2,300PSI, © 2.5BPM 300 - 600PSI, 2K - 4K WOB, ECD 9.65, 90L TF, DRILLED TO 10750'. 08:15 - 09:00 0.75 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2009 09:00 - 11:15 2.25 DRILL P PROD1 DRILL ZONE 2 LATERAL, 2.7 BPM, 2600 -3100 PSI, 2 -4K WOB, 90L TF, 101 DEG INCL, 40 -70 FPH, DRILLED TO 10820'. 11:15 - 14:00 2.75 DRILL P PROD1 DRILL ZONE 2 LATERAL, 2.7 BPM, 2600 -3100 PSI, 2 -4K WOB, 90L TF, 101 DEG INCL, DRILLING UP THRU 22N SHALE, 30 FPH, DRILLED OUT OF SHALE AT 10870'. DRILLED TO 10900'. 14:00 - 15:00 1.00 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. 15:00 - 16:30 1.50 DRILL P PROD1 DRILL ZONE 2 LATERAL, 2.6 BPM, 2650 -3100 PSI, 2 -4K WOB, 90L TF, 101 DEG INCL, DRILLED TO 10943'. STACKING WT. 16:30 - 17:00 0.50 DRILL P PROD1 MAD PASS UP WHILE CIRC NEW GEOVIS FROM PILL PIT TO CHECK FOR GR SHIFT FROM USED MUD. 17:00 - 17:45 0.75 DRILL P PROD1 DRILL ZONE 2 LATERAL, 2.6 BPM, 2650 -3100 PSI, 2 -4K WOB, 90L TF, 101 DEG INCL, SLOW DRILLING, STACKING WT, BIT APPEARS TO BE BALLED. DRILLED TO 10947'. 17:45 - 20:30 2.75 DRILL P PROD1 POH FOR BALLED BIT. CIRC 2.6 BPM, 2750 PSI. PULL ABOVE WINDOW, OPEN EDC, CLEANOUT 9 -5/8" CASING AREA AT 4.0 BPM. UP /DWN /UP. POH TO 9,500' & WASH 9 -5/8" THREE TIMES POH TO SURFACE 30MIN PJSM TO LD BHA WHILE POOH 20:30 - 21:15 0.75 DRILL P PROD1 STAND BACK INJECTOR & LD LATERAL BHA 21:15 - 21:30 0.25 DRILL P PROD1 PJSM FOR COIL MANAGEMENT 21:30 - 00:00 2.50 DRILL P PROD1 COIL MANAGEMENT CUT 55' OFF COIL & CABLE FROM REEL & REHEAD SAME 12/14/2009 00:00 - 01:00 1.00 DRILL P PROD1 REHEAD COIL AFTER COIL MANAGEMENT PT & PULL TEST SAME, TEST GOOD 01:00 - 01:15 0.25 DRILL P PROD1 PJSM TO MU LATERAL BHA 01:15 - 01:45 0.50 DRILL P PROD1 MU LATERAL BHA & REPLACE PACKOFF 01:45 - 03:50 2.08 DRILL P PROD1 RIH WITH LATERAL BHA TO 10,000' 03:50 - 04:05 0.25 DRILL P PROD1 LOG TIE IN FROM 10,000 TO 10,032' NO CORRECTION NEEDED 04:05 - 04:45 0.67 DRILL P PROD1 RIH TO TD TAG @ 10,949' 04:45 - 09:30 4.75 DRILL P PROD1 DRILL LATERAL FROM 10,949'. DRILLING SHALE, STACKING WT. FS 2,400 @ 2.5BPM, 2 -4K WOB, 70 R TF, 99 DEG INCL, 30 FPH, 9.9 ECD. DRILLED TO 11067' 09:30 - 10:10 0.67 DRILL P PROD1 DRILL LATERAL, 2.6 BPM, 2700 - 3300 PSI, 2 -4K WOB, 70R TF, 99 DEG INCL, 9.9 ECD, DRILLED TO 11100'. 10:10 - 11:30 1.33 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. 11:30 - 13:55 2.42 DRILL P PROD1 DRILL LATERAL, 2.6 BPM, 2600 - 3300 PSI, 2 -4K WOB, 70R TF, 100 DEG INCL, 10.0 ECD, SWAPPED TO NEW GEOVIS AT 11,180'. DRILLED TO 11250'. Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2009 13:55 - 16:30 2.58 DRILL P PROD1 LOG MAD PASS UP TO 10300' WITH RES /GR. HOT GEOVIS HAD GIVEN HIGH GR READINGS. WIPER UP TO WINDOW. RIH CLEAN TO BOTTOM. 16:30 - 20:05 3.58 DRILL P PROD1 DRILL LATERAL, 2.6 BPM, 2550 - 3300 PSI, 2 -4K WOB, 70L TF, 100 DEG INCL, 9.7 ECD 20:05 - 11,400', 2,700PSI, 1.8K WOB, ECD 9.69 20:05 - 21:20 1.25 DRILL P PROD1 WIPER TRIP TO 9 -5/8" RIH TO 10,000' 21:20 - 21:35 0.25 DRILL P PROD1 LOG TIE IN FROM 10,000' TO 10,025' CORRECTION OF +4' RESET DEPTH TO 10,029' 21:35 - 22:15 0.67 DRILL P PROD1 RIH TO TD TAG @ 10,405' 22:15 - 00:00 1.75 DRILL P PROD1 DRILL LATERAL FS 2,250PSI 2.4BPM 2,400 - 2,650PSI, 2 -4K WOB 9.67 ECD DRILL TO 11,435 12/15/2009 00:00 - 03:30 3.50 DRILL P PROD1 DRILL LATERAL FS 2,200PSI © 2.4BPM 01:15 - 11,472', 2,500PSI, 1.6K WOB, 9.73 ECD 02:45 - 11,518', 2,800PSI, 3K WOB, 9.76 ECD 03:30 - 11,539', 2,750PSI, 2.8K WOB, 9.72 ECD DRILLED TO 11538 03:30 - 04:30 1.00 DRILL N RREP PROD1 GENERATOR #1 WENT OFF LINE CAUSING LOSS OF PUMP PRESSURE WIPER UP © 18FPM, 1.4 BPM WHILE WAITING FOR ELECTRITIAN TO FIX PROBLEM 04:30 - 06:00 1.50 DRILL P PROD1 WIPER TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. 06:00 - 09:15 3.25 DRILL P PROD1 DRILL UP THRU ZONE 3, 2.6 BPM, 2540 -3100 PSI, 2 -3K WOB, 115 DEG INCL, 16 -10 FPH, 9.8 ECD, FULL RETURNS, DRILLED TO 11590'. 09:15 - 11:30 2.25 DRILL P PROD1 DRILL UP THRU ZONE 3, 2.6 BPM, 2540 -3100 PSI, 2 -3K WOB, 115 DEG INCL, 16 -5 FPH, 9.8 ECD, STACKING 4 KWOB, VERY SLOW DRILLING, BIT IS WORN OUT. DRILLED TO 11614'. 11:30 - 14:15 2.75 DRILL P PROD1 POH FOR BIT, CLEAN TRIP UP TO WINDOW, OPEN EDC CLEANOUT 9 -5/8" AREA AT 4.0 BPM, UP /DWN /UP. POH WHILE CIRC 2.8 BPM. 14:15 - 14:30 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CHANGING OUT BIT AND ADDING AGITATOR TO LATERAL BHA. 14:30 - 16:00 1.50 DRILL P PROD1 LAY OUT BHA. BIT WAS WORN DOWN FLAT ON PILOT, RIDING ON IMPACT BUTTENS AND MATRIX. M/U NEW HYC TREX BC BIT, 1.2 DEG MOTOR, AGITATOR, RES AND COILTRAK TOOLS. BHA OAL = 87.99 16:00 - 18:00 2.00 DRILL P PROD1 RIH WITH LATERAL COILTRAK / RES BHA. CIRC 0.2 BPM. 18:00 - 19:00 1.00 DRILL P PROD1 LOG GR TIE -IN FROM 10015 FT. CORRECT +2 FT. CONTINUE RIH TO BOTTOM. 19:00 - 00:00 5.00 DRILL P PROD1 DRILL FROM 11614 FT. MAINTAIN 115 DEG INC TO MOVE Printed: 1/4/2010 8:22:08 AM BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase ` Description of Operations 12/15/2009 19:00 - 00:00 5.00 DRILL P PROD1 OUT OF Z3 AND INTO Z4. INITIAL ROP IS 30 FT /HR WITH 1 -2 KLBS DWOB, LATER GOING TO 10 -15 FT /HR NEAR THE TOP OF Z3. PVT = 318 BBLS. 21:00 - DRILL AT 11650 FT AT 18 FT /HR. AFTER 11670 FT ROP GOES TO 30 -40 FT /HR. DRILL TO 11730 FT. 12/16/2009 00:00 - 00:45 0.75 DRILL P PROD1 CONTINUE DRILLING FROM 11730 FT TO 11750 FT. 00:45 - 02:40 1.92 DRILL P PROD1 WIPER TRIP FROM 11750 FT TO WINDOW. CLEAN PASS UP AND DOWN. 02:40 - 06:00 3.33 DRILL P PROD1 DRILL FROM 11750 FT IN ZONE 4. CONTINUE HOLDING AROUND 115 DEG INC. ROP IS 30 -50 FT /HR, WITH 2 -3 KLBS DWOB. PVT = 273 BBLS. DRILLED TO 11850'. 06:00 - 07:40 1.67 DRILL P PROD1 DRILL Z4 LATERAL, 2.4 BPM, 3200 -3800 PSI, 60R TF, 115 DEG INCL, 2 -4K WOB, 25 FPH, DRILLED TO 11896'. 07:40 - 10:00 2.33 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. RIH CLEAN TO BOTTOM. 10:00 - 12:00 2.00 DRILL P PROD1 DRILL Z4 LATERAL, 2.4 BPM, 3300 -3800 PSI, 7OR TF, 114 DEG INCL, 3 -4K WOB, 45 FPH, DRILLED TO TD OF 11975'. 12:00 - 13:15 1.25 DRILL P PROD1 WIPER TRIP TO WINDOW. CLEAN HOLE. 13:15 - 13:45 0.50 DRILL P PROD1 LOG GR TIE -IN NEAR WINDOW. ADD 4.5' CTD. 13:45 - 16:00 2.25 DRILL P PROD1 RIH CLEAN TO BOTTOM. TAG FINAL TD AT 11980'. POH WHILE LAYING IN 30 BBL NEW GEOVIS LINER PILL WITH 100# BEADS. PULL CLEAN TO WINDOW. OPEN EDC. CLEANOUT 9 -5/8" CASING AREA AT 4.0 BPM. CIRC UP /DWN /UP /DWN /UP. 16:00 - 17:30 1.50 DRILL P PROD1 POH WHILE CIRC 3.0 BPM 17:30 - 17:45 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT DRILLING BHA. 17:45 - 18:00 0.25 DRILL P PROD1 LAY OUT DRILLING BHA. 18:00 - 18:40 0.67 DRILL P PROD1 CREW CHANGE AND PJSM FOR UD BHA, AND PUMPING SLACK OUT. 18:40 - 19:20 0.67 DRILL P PROD1 FINISH UD BHA #13. BIT IS 6 -2, WITH RINGING ON THE NOSE. FILL WELL WITH 3.1 BBLS. REMOVE BHI CABLE HEAD AND INSTALL CABLE BOOT. 19:20 - 21:00 1.67 CEMT P RUNPRD M/U 1 JT PH6 AND M/U CT RISER. PUMP SLACK FORWARD 3 TIMES AT 4.3 BPM UNTIL CABLE STOPS MOVING. POP OFF WELL, CUT OFF 330 FT OF CABLE 21:00 - 21:20 0.33 CEMT P RUNPRD INSTALL BTT SLIP CONNECTOR, PULL TEST TO 45K, PRESSURE TEST TO 3500 PSI, GOOD. 21:20 - 22:00 0.67 CEMT P RUNPRD PREP RIG FLOOR FOR RUNNING LINER. 22:00 - 22:15 0.25 CEMT P RUNPRD SAFETY MEETING. DISCUSS HAZARDS AND MITIGATIONS FOR RUNNING LINER. 22:15 - 00:00 1.75 CEMT P RUNPRD M/U LINER AS PER PROGRAM., GUIDE SHOE, 2 FLOATS, LANDING COLLAR, STAGE COLLAR, 32 JTS 2 -7/8" STL, 48 JTS 3.19" TCII, 1 JT 3 -1/2 ", X NIPPLE, LINER DEPLOYMENT SLEEVE, GEN 2 SELRT, 3/4" DISCONNECT, 4 JTS PH6 AND Printed: 1/4/2010 8:22:08 AM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2009 22:15 - 00:00 1.75 CEMT P RUNPRD LOCKABLE SWIVEL. BHA OAL = 2792.23 FT. 12/17/2009 00:00 - 04:00 4.00 CEMT P RUNPRD CONTINUE M/U LINER BHA AS PER PROGRAM. FILL WITH WATER AFTER 2 -7/8" IS RUN, AND AGAIN BEFORE M/U CT TO LINER. 04:00 - 04:55 0.92 CEMT P RUNPRD M/U SWIVEL AND CT RISER. PUMP 20 BBLS MUD THROUGH LINER PRIOR TO RIH. 04:55 - 06:15 1.33 CEMT P RUNPRD RIH. CIRC 0.3 BPM1500 PSI. UP WT AT 9900' = 43K DWN WT = 22K RIH THRU WINDOW CLEAN. 06:15 - 07:00 0.75 CEMT P RUNPRD RIH AT 60 FPH, CIRC 0.2 BPM, 1600 PSI. 17K DWN WT AT 11500' SET DOWN IN SHALE AT 11640'. SET DOWN AGAIN. 43K UP WT. PICK UP 100', RIH, SET DOWN AGAIN AT 11640'. PICK UP, CIRC .9 BPM TO INDEX SHOE. RIH PAST SHALE. RIH AT 60 FPM, 0.2 BPM, 1600 PSI, 15K DWN WT AT 11800'. LANDED LINER AT TD AT 11983' CTD. CORRECTED TD IS 11980'. PICK UP AND TAG TD AGAIN AT SAME DEPTH. 43K UP WT OFF TD. PICK UP TO BALL DROP POSITION. 07:00 - 09:30 2.50 CEMT P RUNPRD CIRC 0.5 BPM, FULL RETURNS, CIRC 1.0 BPM, FULL RETURNS, CIRC 1.5 BPM, 2200 PSI, FULL RETURNS FILL OUT LOCK OUT/TAG OUT FOR LAUNCHING 5/8" STEEL BALL. BLEED PRESS. ISOLATE STANDING IRON. ISOLATE REEL WITH PINS. LAUNCH 5/8" BALL WITH 1200 PSI, DISPL WITH 2.0 BPM 2450 PSI, SET DOWN 10K AT TD. DID NOT HEAR BALL ROLLING. SLOW PUMP TO 0.9 BPM AT 38 BBL. 1800 PSI. BALL NOT ON SEAT AT 60 BBL. PICK UP 100', RIH, CIRC 2 BPM, SURGE PUMP. LAUNCH A SECOND BALL WITH 2000 PSI. CIRC 1.8 BPM, BALL IS MOVING IN COIL. STACK 10K WOB. DISPL BALL WITH 1.9 BPM, 2400 PSI, SLOW 0.7 BPM AT BALL ON SEAT AT 47 BBL, SHEARED AT 4400 PSI. PICK UP FREE FROM LINER AT 38K. 09:30 - 13:00 3.50 CEMT P RUNPRD CIRC WELL TO DOUBLE SLICK, 2% KCL WATER. CIRC 2.5 BPM, 1360 PSI WITH SLICK KCL. CIRC 1.5 BPM, 590 PSI WITH SLICK KCL. MIX 70 BBL, 2# BIOZAN TO DISPLACE CEMENT 13:00 - 13:15 0.25 CEMT P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PUMPING CEMENT JOB. 13:15 - 14:00 0.75 CEMT P RUNPRD BATCH UP CEMENT. CEMENT AT WT AT 1350 HRS. STAGE 5 BBL KCL WATER TO HEAT CEMENT LINE AND PRESS TEST. PRESS TEST CEMENT LINE WITH 4000 PSI. 14:00 - 15:15 1.25 CEMT P RUNPRD STAGE 33 BBL, 15.8 PPG G CEMENT Printed: 1/4/2010 8:22:08 AM • • BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From To Hours Task Code NPT Phase Description of Operations 12/17/2009 14:00 - 15:15 1.25 CEMT P RUNPRD 10 BBL CMT, 2.1 BPM, 1900 PSI, 20 BBL CMT, 2.0 BPM, 2200 PSI. 30 BBL CMT, 2.0 BPM, 2000 PSI 32.9 BBL CMT, STOP PUMP, ISOLATE COIL FROM CEMENTERS. PUMP BIOZAN TO CEMENTERS. BLOWDOWN LINE TO CEMENTERS WITH AIR. STAGE 2# BIOZAN DISPLACEMENT. COIL CAP = 54.4 BBL. STOP DISPL AT 52.4 BBL 10 BBL DISPL, 2.2 BPM, 1200 PSI, FULL RETURNS 20 BBL DISPL, 30 BBL DISPL, 39 BBL DISPL, ZERO OUT MICRO TOTAL, CMT AT SHOE. 50 BBL DISPL, 52.4 BBL DISPL, STOP PUMP, 2 BBL CMT LEFT INSIDE COIL PICK UP 13' TO OPEN DOGS ABOVE DEPLOYMENT SLEEVE. SET DOWN 10' HIGHER ON DOGS. PRESSURE UP TO 700 PSI, PEE WEE DART IS ON LWP. PICK UP 1 FT PAST BREAKOVER AT 40K, PRESSURE FELL OFF. PUMP 5 BBLS SIDE EXHAUST 53.1 BBL DISP / 15.0 BBL OUT 58.2 / 20 BBLS - STOP AND OPEN BAKER CHOKE. RIH STACK 10K DOWN AT 11974.4' (10 FT HIGHER) CLOSE BAKER CHOKE, PRESSURE UP AND SHEAR LWP AT 3700 PSI. DISP LWP TO LANDING COLLAR. 60 BBL IN, 2.3 BPM, 2700 PSI, FULL RETURNS 65 BBL IN, 2.3 BPM, 2820 PSI 70 BBL IN, 1.7 BPM, 2300 PSI 72 BBL IN, 1.0 BPM, 1850 PSI 76 BBL IN, 0.9 BPM, 1800 PSI 76.4 BBL, BUMP WITH 2200 PSI, HOLD 5 MIN 32.5 BBL CMT RETURNED PER OUT TOTAL 15:15 - 15:20 0.08 CEMT P RUNPRD BLEED OFF PRESSURE TO CHECK FLOATS, OK. PRESSURE TO 700 PSI, STING OUT AND CIRC 5 BBLS AT TOL 1.0 BPM / 1100 PSI, FULL RETURNS. 15:20 - 17:00 1.67 CEMT P RUNPRD POOH PUMP TO REPLACE COIL VOIDAGE. 17:00 - 17:15 0.25 CEMT P RUNPRD SAFETY MEETING. DISCUSS HAZARDS AND MITIGATIONS FOR UD BHA. 17:15 - 18:00 0.75 CEMT P RUNPRD TAG STRIPPER AND LID BHA. RECOVER BOTH 5/8" STEEL BALLS. 18:00 - 18:30 0.50 CEMT P RUNPRD TOUR CHANGE AND PJSM WITH NEW CREW. 18:30 - 22:40 4.17 EVAL P LOWER1 M/U MCNL + CLEANOUT BHA. 2.30" MILL, 2.12 MOTOR, 2 JTS 1.25 CSH, LOGGING CARRIER, 1/2" CIRC SUB, 5/8" DISCONNECT, 44 STDS 1.25 CSH, 3/4" DISCONNECT, DBPV, 2 JTS PH6, LOCKABLE SWIVEL. BHA OAL = 2896.7 FT. Printed: 1/4/2010 8:22:08 AM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/17/2009 22:40 - 23:20 0.67 EVAL N SFAL LOWER1 M/U LOCKABLE SWIVEL, SET SCREW THAT HOLDS LOWER MANDREL IS NOT USABLE, NONE ON THE RIG. WAIT FOR SOME TO ARRIVE FROM BTT IN DEADHORSE. 23:20 - 00:00 0.67 EVAL P LOWER1 M/U CT RISER AND RIH, PUMP 0.2 BPM. 12/18/2009 00:00 - 01:20 1.33 EVAL P LOWER1 CONTINUE RIH. 01:20 - 06:30 5.17 EVAL P LOWER1 RIH TO 50' BELOW LINER TOP AND CIRC AT 0.9 BPM, PULL BACK UP HOLE AND WAIT ON CMT. CIRC OUT CONTAMINATED CEMENT TO SURFACE AND DISPOSE OF IT. CIRC IN 290 BBLS NEW DOUBLE SLICK KCL WATER. 06:30 - 08:10 1.67 EVAL P LOWER1 UCA CEMENT AT 500 PSI. LOG DOWN WITH MCNUGR/CCL AT 30 FPM FROM 9200'. CIRC 1.0 BPM, 850 PSI, TAG PBTD AT 11939' CTD UNCORRECTED. 08:10 - 09:00 0.83 EVAL P LOWER1 LOG UP FROM PBTD AT 60 FPM WHILE LAYING IN NEW 30 BBL FLOPRO PERF PILL. 0.6 BPM, 700 PSI. 46K UP WT. 09:00 - 11:15 2.25 EVAL P LOWER1 POH WITH MEMORY LOGGING / CLEANOUT BHA. CIRC 1.0 BPM 800 PSI. 11:15 - 11:30 0.25 EVAL P LOWER1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR STANDING BACK CSH WORKSTRING. 11:30 - 14:00 2.50 EVAL P LOWER1 LAY OUT 2 JTS PH6, STANDBACK 44 STDS CSH. 14:00 - 14:15 0.25 EVAL P LOWER1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT THE SWS MEMORY CNUGR/CCL LOGGING TOOLS AND MOTOR AND MILL. 14:15 - 15:15 1.00 EVAL P LOWER1 LAY OUT SWS MEMORY CNUGR/CCL LOGGING TOOLS. DOWN LOAD DATA, GOOD DATA. SEND LOG TO ANC GEO. 15:15 - 16:30 1.25 CEMT P RUNPRD JET STACK WITH SWIZZLE STICK TO CLEAR CEMENT FROM STACK AND TREE. 4 BPM, 2800 PSI. 16:30 - 21:00 4.50 CEMT P RUNPRD WO CEMENT. WAITING FOR CEMENT UCA TO REACH 2000 PSI. CEMENT HAD AN 8 HOUR THICKENING TIME FOR THE NEW GEN II SELRT. LOAD PERF GUNS INTO PIPESHED WHILE WAITING. PREP RIG FLOOR TO RUN SWS 2" PERF GUNS. 21:00 - 22:00 1.00 CEMT P RUNPRD ALL PERF GUNS LOADED INTO SHED FOR UPDATED PERF INTERVAL. START LINER LAP TEST. ESTIMATED COMPRESSIVE STRENGTH IS 1920 PSI FROM UCA GRAPH. PRESSURE UP WELL TO 2000 PSI. PRFSSURE BLEEDS OFF 282 PSI IN 10 MIN. TRY AGAIN, PRESSURE BLEEDS OFF 300 PSI IN 12 MIN, FAILED TEST. 22:00 - 22:20 0.33 PERFOB P LOWER1 SAFETY MEETING. PJSM TO DISCUSS M/U PERF GUNS. 22:20 - 00:00 1.67 PERFOB P LOWER1 M/U PERF GUNS AS PER PROGRAM. 2" PERF GUNS WITH E -FIRE HEAD, 5/8" DISCONNECT, 46 JTS 1.25 CSH, 3/4" DISCONNECT, DBPV, 2 JTS PH6, SWIVEL. BHA OAL = 2851.33 FT. 12/19/2009 00:00 - 03:30 3.50 PERFOB P LOWER1 CONTINUE M/U PERF BHA. 03:30 - 03:50 0.33 PERFOB P LOWER1 M/U SWIVEL AND CT RISER. Printed: 1/4/2010 8:22:08 AM 1 • BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2009 03:50 - 05:20 1.50 PERFOB P LOWER1 RIH WITH PERF BHA. 05:20 - 06:00 0.67 PERFOB P LOWER1 TAG AT 11945 FT, 2 TIMES. • PICK UP TO STRING WT AND CORRECT DEPTH TO 11938 FT. PICK UP TO BOTTOM SHOT DEPTH OF 11830 FT. FIND 2 GOOD PUMP RATES FOR FIRING GUNS, USE 0.3 AND 1.3 BPM. 06:00 - 06:30 0.50 PERFOB P LOWER1 PUMP FIRING RATES. GUNS FIRED ON DEPTH. GOOD INDICATION AND LOST RETURNS FOR 3 MIN. PERFORATED INTERVALS: 10500 -10640 10750 -10780 r 11290 -11320 11720 -11780 11810 - 11830 06:30 - 09:00 2.50 PERFOB P LOWER1 POH WHILE CIRC 1.5 BPM, FLOW CHECK AT TOP OF LINER. POH WHILE CIRC IN NEW KCL WATER AT 2.1 BPM, CIRC 170 BBL NEW KCL TO LEAVE CLEAN FLUID IN 4 -1/2" TUBING. FLOW CHECK AT SURFACE. NO FLOW. 09:00 - 09:15 0.25 PERFOB P LOWER1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR STANDING BACK CSH WORKSTRING. 09:15 - 10:45 1.50 PERFOB P LOWER1 STANDBACK CSH WORKSTRING. 23 STDS. 10:45 - 11:00 0.25 PERFOB P LOWER1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT FIRED PERF GUNS. 11:00 - 15:45 4.75 PERFOB P LOWER1 LAY OUT FIRED SWS 2" PERF GUNS. ALL GUNS FIRED. 63 GUNS AND BLANKS. LOAD OUT FIRED GUNS OUT OF PIPESHED. 15:45 - 16:00 0.25 CASE P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U BOT LT PACKER AND RUNNING TOOLS BHA. 16:00 - 16:45 0.75 CASE P RUNPRD M/U BOT SEAL ASSEMBLY, BOT 45 KB LINER TOP PACKER, SETTING TOOL, HYD DISC, 2 JTS PH6, SWIVEL AND CTC. BHA OAL = 86.79'. 16:45 - 18:30 1.75 CASE P RUNPRD RIH WITH BAKER 45 KB LINER TOP PACKER WITH 30K RELEASE RING ON RUNNING TOOLS. CIRC 0.2 BPM. 18:30 - 20:40 2.17 CASE P RUNPRD WT CHECK AT 9270 FT IS 43K. RIH SLOWLY TO STING INTO DEPLOYMENT SLEEVE, PUMP 0.2 BPM. PRESSURE INCREASE AT 9330 FT, STOP CT AND PUMP. OPEN BAKER CHOKE, RIH AND STACK 10K TO 9338.2 FT. PU TO BREAKOVER WT +1 FT TO 9332.1 FT, REPEAT WITH SAME RESULTS. PU TO BALL DROP POSITION, DROP 5/8" STEEL AND LAUNCH WITH 2000 PSI. BALL IS HEARD ROLLING AND LEAVING REELHOUSE. SLOW TO 0.5 BPM AT 30 BBLS AWAY. BALL NOT ON SEAT AFTER 55 BBLS, CYCLE PUMP AND CT, NO LUCK. TRY LAUNCHING AGAIN AT SURFACE WITH 1500 PSI 2 TIMES, NO LUCK. Printed: 1/4/2010 8:22:08 AM • BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: 01 -28 Common Well Name: 01 -28 Spud Date: 5/11/1986 Event Name: REENTER +COMPLETE Start: 11/30/2009 End: 12/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2009 18:30 - 20:40 2.17 CASE P RUNPRD PUMP 18 BBLS HI -VIS SWEEP DOWN. BALL IS ON SEAT AFTER 8 BBLS PILL IS IN REEL. 20:40 - 21:15 0.58 CASE P RUNPRD RIH TO 9338.4 FT AT 15K WT, SAME AS BEFORE. PICK UP TO BREAKOVER WT +1 FT. CLOSE BAKER CHOKE. PRESSURE UP CT TO 1900 PSI TO SET SLIPS AND PACKER ELEMENT. SET DOWN TO 15K AND BLEED OFF BAKER CHOKE, ABOUT 2.5 FT HIGHER THAN BEFORE CONFIRMING SLIPS SET. PICK UP TO 40K WT AND PT BACKSIDE TO 2000 PSIFOR 10 MIN, GOOD. TEST IS CHARTED. 21:15 - 21:20 0.08 CASE P RUNPRD BLEED OFF ANNULUS PRESSURE AND LINE UP TO PUMP DOWN THE CT. RIH STACK 10K, PUMP UP CT PRESSURE TO 3700 PSI TO SHEAR OFF PACKER. 21:20 - 23:00 1.67 CASE P RUNPRD POOH PUMP 1.5 BPM. 23:00 - 23:15 0.25 CASE P RUNPRD SAFETY MEETING. PJSM FOR UD BHA. 23:15 - 23:45 0.50 CASE P RUNPRD TAG STRIPPER AND UD BHA. 5/8" STEEL BALL RECOVERED, TOOL HAS FUNCTIONED NORMALLY. 23:45 - 00:00 0.25 WHSUR P POST M/U FREEZE PROTECT BHA WITH DBPV. 12/20/2009 00:00 - 01:10 1.17 WHSUR P POST RIH WITH FREEZE PROTECT BHA. 01:10 - 02:00 0.83 WHSUR P POST FREEZE PROTECT WELL WITH DIESEL FROM 2500 FT. 02:00 - 02:30 0.50 WHSUR P POST TAG STRIPPER, POP OFF WELL AND UD FREEZE PROTECT BHA. 02:30 - 02:45 0.25 WHSUR P POST SAFETY MEETING. PJSM FOR SETTING BPV. 02:45 - 03:00 0.25 WHSUR P POST GREASE TREE VALVES AND SET BPV. CLOSE MASTER AND SWAB VALVE. TREE IS EMPTY OF FLUID FROM THE SWAB TO THE BPV. 03:00 - 07:00 4.00 RIGD P POST SET INJECTOR ON LEGS. PURGE DOWNHOLE END OF CT WITH AIR. PREP FOR N/D STACK. ROLL WHEELS ON RIG TO WARM UP DRIVE SYSTEM. N/D BOPs, CLEAN PITS AND CUTTINGS BOX. 07:00 - 08:00 1.00 RIGD P POST N/U TREE CAP AND PRESS TEST WITH DIESEL. RELEASED RIG AT 0800 HRS, 12/20/2009. A TOTAL OF 14 DAYS, 15 HRS FROM RIG ACCEPT TO RELEASE. FURTHER RIG INFORMATION IS ON DIMS DS 01 -14A. Printed: 1/4/2010 8:22:08 AM • • ru BAKER HHES INTEQ North America - ALASKA - BP Prudhoe Bay PBDS01 01 -28 - Slot 28 01 -28A Survey: MWD Survey Report - Geographic 17 December, 2009 � bp M ,� • • moms Survey Report - Geographic bP INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -28 - Slot 28 Project: Prudhoe Bay TVD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Site: PB DS 01 MD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Well: 01 -28 North Reference: True Wellbore: 01 -28A Survey Calculation Method: Minimum Curvature Design: 01 -28A Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 01, TR -10 -15 I Site Position: Northing: 5,941,932.14ft Latitude: 70° 14' 43.905 N From: Map Easting: 697,237.60ft Longitude: 148° 24' 24.004 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.50 ° Well 01 -28 API No 500292159700 Well Position +N / -S 0.00 ft Northing: 5,939,967.60 ft Latitude: 70° 14' 24.176 N +E / -W 0.00 ft Easting: 698,834.29 ft Longitude: 148° 23' 39.099 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore 01 -28A API No 500292159701 Magnetics Model Name Sample Date Declination Dip Angle Field Strength j (') ( *) ( nT) BGGM2009 9/4/2009 22.64 80.92 57,675 Design 01 -28A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,900.00 Vertical Section: Depth From (TVD) +N /-S +E / -W Direction (ft) (ft) (ft) ( °) 30.00 0.00 0.00 54.48 Survey Program Date: 12/17/2009 From To (ft) (ft) Survey (Welibore) Tool Name Description 100.00 9,900.00 1 : Sperry-Sun BOSS gyro multi (01 -28) BOSS -GYRO Sperry-Sun BOSS gyro multishot 9,923.00 11,980.00 MWD (01 -28A) MWD MWD - Standard 12/17/2009 11 :09:47AM Page 2 COMPASS 2003.16 Build 71 • • IN RV HUGHLIS Survey Report - Geographic 0 by INTEQ Company: ' North America - ALASKA - BP Local Co Reference: Well 01 - 28 - Slot 28 pan y oca Project: Prudhoe Bay TVD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Site: PB DS 01 MD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Well: 01 - 28 North Reference: True Wellbore: 01 - 28A Survey Calculation Method: Minimum Curvature Design: 01 - 28A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/ -W Northing Easting (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,900.00 31.92 88.39 8,735.11 1,044.98 3,727.60 5,941,110.47 702,532.83 70° 14' 34.445 N 148 21' 50.730 W TIP 9,923.00 31.87 88.16 8,754.63 1,045.34 3,739.75 5,941,111.15 702,544.96 70° 14' 34.448 N 148° 21' 50.376 W KOP 9,954.96 23.68 80.12 8,782.90 1,046.72 3,754.53 5,941,112.92 702,559.71 70° 14' 34.462 N 148 21' 49.947 W 9,985.18 27.25 71.35 8,810.19 1,049.97 3,767.07 5,941,116.50 702,572.16 70° 14' 34.494 N 148° 21' 49.582 W 10,014.28 29.52 64.90 8,835.79 1,055.15 3,779.88 5,941,122.01 702,584.82 70° 14' 34.545 N 148° 21' 49.209 W 10,044.66 31.92 48.57 8,861.95 1,063.65 3,792.71 5,941,130.85 702,597.42 70° 14' 34.628 N 148° 21' 48.836 W 10,074.94 34.63 35.57 8,887.30 1,075.96 3,803.73 5,941,143.45 702,608.11 70° 14' 34.749 N 148° 21' 48.516 W 10,105.74 40.21 26.82 8,911.77 1,091.98 3,813.32 5,941,159.71 702,617.28 70° 14' 34.907 N 148° 21' 48.237 W 10,135.50 45.70 19.34 8,933.56 1,110.63 3,821.19 5,941,178.56 702,624.65 70° 14' 35.090 N 148° 21' 48.008 W 10,162.58 50.34 11.38 8,951.68 1,130.02 3,826.47 5,941,198.08 702,629.41 70° 14' 35.281 N 148° 21' 47.854 W 10,194.34 55.64 4.45 8,970.81 1,155.11 3,829.90 5,941,223.25 702,632.19 70° 14' 35.527 N 148° 21' 47.754 W 10,227.94 60.21 358.94 8,988.65 1,183.54 3,830.71 5,941,251.70 702,632.24 70° 14' 35.807 N 148° 21' 47.730 W 10,263.78 63.57 349.61 9,005.57 1,214.94 3,827.52 5,941,283.00 702,628.23 70° 14' 36.116 N 148° 21' 47.822 W 10,292.08 65.95 342.56 9,017.65 1,239.76 3,821.36 5,941,307.65 702,621.41 70° 14' 36.360 N 148° 21' 48.001 W 10,324.26 68.07 336.01 9,030.23 1,267.44 3,810.87 5,941,335.04 702,610.20 70° 14' 36.632 N 148° 21' 48.305 W 10,352.66 68.97 329.08 9,040.64 1,290.87 3,798.69 5,941,358.14 702,597.41 70° 14' 36.863 N 148° 21' 48.659 W 10,382.70 71.16 322.32 9,050.89 1,314.18 3,782.78 5,941,381.02 702,580.89 70° 14' 37.092 N 148° 21' 49.121 W 10,412.20 75.00 316.09 9,059.48 1,335.52 3,764.34 5,941,401.86 702,561.90 70° 14' 37.302 N 148° 21' 49.657 W 10,445.44 80.43 309.81 9,066.56 1,357.61 3,740.58 5,941,423.32 702,537.56 70° 14' 37.519 N 148° 21' 50.348 W 10,473.92 83.37 304.65 9,070.57 1,374.66 3,718.14 5,941,439.77 702,514.68 70° 14' 37.687 N 148° 21' 51.000 W 10,494.96 84.21 300.45 9,072.85 1,385.91 3,700.51 5,941,450.55 702,496.76 70° 14' 37.798 N 148° 21' 51.512 W 10,526.76 87.20 294.72 9,075.23 1,400.59 3,672.42 5,941,464.48 702,468.29 70° 14' 37.942 N 148° 21' 52.329 W 10,566.14 92.39 288.87 9,075.37 1,415.20 3,635.88 5,941,478.12 702,431.39 70° 14' 38.086 N 148° 21' 53.391 W 10,597.34 93.55 285.52 9,073.76 1,424.41 3,606.12 5,941,486.54 702,401.39 70° 14' 38.177 N 148° 21' 54.256 W 10,626.24 94.80 281.85 9,071.65 1,431.22 3,578.12 5,941,492.62 702,373.23 70° 14' 38.244 N 148° 21' 55.070 W 10,659.36 95.11 278.01 9,068.79 1,436.91 3,545.63 5,941,497.45 702,340.59 70° 14' 38.300 N 148° 21' 56.015 W 10,690.08 96.66 273.36 9,065.64 1,439.94 3,515.23 5,941,499.67 702,310.13 70° 14' 38.330 N 148° 21' 56.898 W 10,724.10 98.42 269.42 9,061.17 1,440.76 3,481.52 5,941,499.60 702,276.41 70° 14' 38.338 N 148° 21' 57.878 W 10,753.16 99.58 265.67 9,056.62 1,439.53 3,452.85 5,941,497.62 702,247.79 70° 14' 38.327 N 148° 21' 58.712 W 10,783.16 100.43 262.18 9,051.41 1,436.41 3,423.48 5,941,493.72 702,218.51 70° 14' 38.296 N 148° 21' 59.566 W 10,811.90 101.65 258.15 9,045.91 1,431.59 3,395.69 5,941,488.17 702,190.86 70° 14' 38.249 N 148° 22' 0.374 W 10,842.14 102.71 253.13 9,039.52 1,424.27 3,367.06 5,941,480.10 702,162.44 70° 14' 38.177 N 148° 22' 1.206 W 10,871.86 103.14 253.94 9,032.87 1,416.06 3,339.29 5,941,471.16 702,134.89 70° 14' 38.096 N 148° 22' 2.014 W 10,901.94 101.31 256.79 9,026.50 1,408.63 3,310.85 5,941,462.99 702,106.65 70° 14' 38.023 N 148° 22' 2.841 W 10,936.90 100.70 260.93 9,019.83 1,402.01 3,277.18 5,941,455.47 702,073.18 70° 14' 37.958 N 148° 22' 3.820 W 10,961.68 100.09 263.63 9,015.35 1,398.73 3,253.03 5,941,451.56 702,049.12 70° 14' 37.926 N 148° 22' 4.522 W 10,990.52 100.02 266.22 9,010.32 1,396.22 3,224.75 5,941,448.31 702,020.92 70° 14' 37.902 N 148° 22' 5.344 W 11,020.90 100.65 269.96 9,004.87 1,395.22 3,194.89 5,941,446.52 701,991.09 70° 14' 37.892 N 148° 22' 6.212 W 11,050.94 99.88 273.41 8,999.51 1,396.09 3,165.34 5,941,446.61 701,961.54 70° 14' 37.901 N 148° 22' 7.071 W 11,081.08 100.35 278.47 8,994.22 1,399.16 3,135.84 5,941,448.90 701,931.97 70° 14' 37.931 N 148° 22' 7.929 W 11,111.04 100.27 283.37 8,988.85 1,404.75 3,106.91 5,941,453.72 701,902.90 70° 14' 37.986 N 148° 22' 8.770 W 11,141.06 100.14 287.34 8,983.53 1,412.57 3,078.42 5,941,460.79 701,874.22 70° 14' 38.063 N 148° 22' 9.598 W 11,171.08 100.83 292.78 8,978.06 1,422.69 3,050.71 5,941,470.17 701,846.25 70° 14' 38.163 N 148° 22' 10.404 W 11,202.10 100.54 298.57 8,972.31 1,435.89 3,023.25 5,941,482.65 701,818.45 70° 14' 38.292 N 148° 22' 11.202 W 11,236.12 100.67 304.41 8,966.04 1,453.35 2,994.75 5,941,499.34 701,789.50 70° 14' 38.464 N 148° 22' 12.030 W 11,265.18 101.90 303.04 8,960.35 1,469.17 2,971.05 5,941,514.54 701,765.39 70° 14' 38.620 N 148° 22' 12.719 W 11,295.52 102.75 300.52 8,953.88 1,484.78 2,945.85 5,941,529.47 701,739.80 70° 14' 38.774 N 148° 22' 13.452 W 11,326.68 105.50 298.89 8,946.27 1,499.75 2,919.61 5,941,543.75 701,713.17 70° 14' 38.921 N 148° 22' 14.214 W 11,354.82 107.81 296.82 8,938.21 1,512.35 2,895.78 5,941,555.71 701,689.02 70° 14' 39.045 N 148° 22' 14.907 W 11,384.74 109.93 294.96 8,928.53 1,524.71 2,870.31 5,941,567.40 701,663.23 70° 14' 39.167 N 148° 22' 15.647 W 11,416.70 110.78 291.97 8,917.41 1,536.65 2,842.83 5,941,578.60 701,635.45 70° 14' 39.284 N 148° 22' 16.446 WI 11,465.62 111.71 287.70 8,899.68 1,552.12 2,799.95 5,941,592.94 701,592.18 70° 14' 39.436 N 148° 22' 17.693 W 11,501.62 112.70 283.94 8,886.07 1,561.20 2,767.90 5,941,601.18 701,559.90 70° 14' 39.526 N 148° 22' 18.625 W 12/17/2009 11:09:47AM Page 3 COMPASS 2003.16 Build 71 • • HUM ES Survey Report - Geographic 0 bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -28 - Slot 28 Project: Prudhoe Bay TVD Reference: 44 : 28 12/26/1998 06:00 © 70.00ft (Nabors 18E) Site: PB DS 01 MD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) WeII: 01 - 28 North Reference: True Wel lbore: 01 - 28A Survey Calculation Method: Minimum Curvature Design: 01 - 28A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/ -W Northing Easting (ft) O ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,533.12 114.27 281.84 8,873.51 1,567.65 2,739.74 5,941,606.88 701,531.58 70° 14' 39.589 N 148° 22' 19.443 W 11,565.48 115.20 277.81 8,859.97 1,572.67 2,710.79 5,941,611.13 701,502.51 70° 14' 39.639 N 148° 22' 20.285 W 11,593.85 114.93 272.67 8,847.94 1,575.01 2,685.21 5,941,612.80 701,476.88 70° 14' 39.662 N 148° 22' 21.029 W 11,624.65 116.09 269.02 8,834.68 1,575.43 2,657.42 5,941,612.48 701,449.09 70° 14' 39.666 N 148° 22' 21.836 W 11,652.95 115.42 270.79 8,822.38 1,575.39 2,631.93 5,941,611.77 701,423.61 70° 14' 39.666 N 148° 22' 22.578 W 11,685.49 115.25 276.20 8,808.45 1,577.18 2,602.59 5,941,612.79 701,394.24 70° 14' 39.684 N 148° 22' 23.431 W 11,713.61 115.32 279.73 8,796.43 1,580.70 2,577.42 5,941,615.64 701,368.98 70° 14' 39.718 N 148° 22' 24.162 W 11,751.35 115.61 284.69 8,780.20 1,587.90 2,544.13 5,941,621.96 701,335.52 70° 14' 39.789 N 148° 22' 25.130 W 11,781.01 114.39 288.65 8,767.66 1,595.62 2,518.38 5,941,629.00 701,309.58 70° 14' 39.865 N 148° 22' 25.879 W 11,807.83 112.95 291.76 8,756.89 1,604.10 2,495.34 5,941,636.87 701,286.32 70° 14' 39.949 N 148° 22' 26.549 W 11,834.73 112.88 294.57 8,746.41 1,613.85 2,472.56 5,941,646.01 701,263.29 70° 14' 40.045 N 148° 22' 27.211 W 11,866.67 114.62 299.73 8,733.54 1,627.17 2,446.56 5,941,658.65 701,236.95 70° 14' 40.176 N 148° 22' 27.967 W 11,895.07 114.97 304.06 8,721.63 1,640.79 2,424.67 5,941,671.68 701,214.72 70° 14' 40.310 N 148° 22' 28.603 W 11,922.55 116.01 308.03 8,709.80 1,655.38 2,404.62 5,941,685.73 701,194.29 70° 14' 40.453 N 148° 22' 29.186 W 11,980.00 116.01 308.03 8,684.60 1,687.19 2,363.95 5,941,716.46 701,152.79 70° 14' 40.766 N 148° 22' 30.368 W TD - 2 7/8" Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/ -W Northing Easting - Shape ( ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 01 -28A Polygon 0.00 0.00 70.00 1,127.04 4,012.05 5,941,200.00 702,815.00 70° 14' 35.250 N 148° 21' 42.459 W - survey misses target center by 8670.16ft at 9900.00ft MD (8735.11 TVD, 1044.98 N, 3727.60 E) - Polygon Point 1 70.00 1,127.04 4,012.05 5,941,200.00 702,815.00 Point 2 70.00 1,453.66 3,955.64 5,941,525.00 702,750.00 Point 3 70.00 1,760.39 2,378.09 5,941,790.00 701,165.00 Point4 70.00 1,412.20 2,303.88 5,941,440.00 701,100.00 Point 5 70.00 1,134.03 3,747.13 5,941,200.00 702,550.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,980.00 8,684.60 2 7/8" 2.875 4.125 I Survey Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E/-W (ft) (ft) (ft) (ft) Comment 9,900.00 8,735.11 1,044.98 3,727.60 TIP 9,923.00 8,754.63 1,045.34 3,739.75 KOP 11,980.00 8,684.60 1,687.19 2,363.95 TD Checked By: Approved By: Date: 12/17/2009 11:09:47AM Page 4 COMPASS 2003.16 Build 71 TREE = FMC GEN 4 WELLHEAD = FMC S TES: ***4-1/2" CHROME TBG* ** ACTUATOR = BAKER C JMD ®RA T * * *W ELL ANGLE > 70° @ 10353' * ** KB. ELEV = 70' 01 -28 A BF. ELEV = ? j I KOP = 2800' Max Angle = 116° @ 11625' I 2219' H4 -1/2" HES X NIP, ID = 3.813" Datum MD = 10054' Datum TV D = 8800' SS 113 -3/8" CSG, 68 #/72 #, K- 55/L -80, ID = 12.347" H 2513' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3288 3262 27 CA -MMG -M SO RK 20 12/25/09 2 5666 5256 33 CA- MMG -M DOME RK 16 12/25/09 Minimum ID = 2..360" 9322' 3 7745 6967 36 CA -MMG -M DMY RK 0 01/03/99 4 9283 8217 34 CA -MMG -M DMY RK 0 01/03/99 BOT SEAL ASSY 9317' 1 - 1 BOT 45 KB LTP, ID = 2.370" I e e 9322' -I BOT SEAL ASSY, ID = 2.360 "? I TOC 9325' , , ►4 1 9325' H3.70" BTT DEPLOYMENT SLV, ID = 3.00" I $ M 9346' H3-1/2" HES X NIP, ID = 2.812" I 3 -1/2" LNR, 8.81 #, L -80 STL, 9379' ► 1� 1 0087 bpf, ID = 2.990" ■/• 1/� 9379' H3-1/2" X 3- 3/16 ", ID = 2.786" I ■ 1 4 1 ►/4 ■ 1/j • ■ * , 4 -1/2" TBG, 12.6 #, 13 - CR NEW VAM, — 9386' I : / XO TO 13 - CR NSCT ► 4 / o „TA ► 4 ' 1 � ��� 9398' I - 19 X 4-1/2" B KR S B -3 PKR, ID = 3.875" / 1/ 41 14 � Lt4 04 Lt I 9432' 1- 14 -1/2" HES X NIP, ID= 3.813" I Behind 4 -1/2" TBG, 12.6 #, 13 - CR NSCT, 945 ∎• o / o CT LNR .0152 bpf, ID = 3.958" .1 ili 9455' —14 -1/2" WLEG, ID = 3.958" I 13.80" PILOT HOLE TOP 1 9501' / � * 111• I H ELMD TT NOT LOGGED 1 1 1 1. 0 I3 -5/8" BKR WHIPSTOCK I 9923' ***• .0 1 1 / 1 / 1 1111111 ,111111 I I RA TAG H 9933' • 1 4 1• � 1 lk I , 1� MILLOUT WINDOW (01 - 28A) 9924' - 9933' 1 3.80" PILOT HOLE BOT I-1 9950' /V1t/f1�/•/•.. •••••••••• TOP OF FILL (TAGGED (06/19/09) H 10258' //////////////// 0. I I . 1 PBTD I 10421' _ ` ` 1 10915' 1 3 -3/16 X 2 -7/8" X0, 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I 10481' '•444444'•'•4'• 1 ID = 2.370 "? ////1/////1///1 /1/1/∎ / ■ PERFORATION SUMMARY , REF LOG: SWS MCNL /GR/CCL 12/18/09 , ANGLE AT TOP PERF: 85° © 10500' , Note: Refer to Production DB for historical perf data 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, 10915' SIZE SPF INTERVAL Opn /Sqz DATE ID = 2.441" ,�t. 2" 6 10500 - 10640 0 12/19/09 2" 6 10750 - 10780 0 12/19/09 I PBTD 1-I 11943' 2" 6 11290 - 11320 0 12/19/09 2" 6 11720 - 11780 0 12/19/09 2" 6 11810 - 11830 0 12/19/09 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, -1 11980' 1 ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/28/86 ORIGINAL COMPLETION WELL: 01 - 28A 01/03/99 RWO PERMrf No: ° 2091250 12/20/09 RRW CT SIDETRACK (01 - 28A) API No: 50 - 029 - 21597 - - 01/05/10 ? /JMD DRLG DRAFT CORRECTIONS SEC 8, T1 ON, R15E, 1500" FWL & 958' FNL BP Exploration (Alaska) • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 RECEIVED Anchorage, Alaska 99501 Attention: Christine Mahnken MAR 2010 Alaska 6 St Gas Cons. Commission Anchorage Reference: 01 -28A Contains the following: � a 1 color print — GR Directional Measured Depth Log (to follow) I 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) u" LAC Job#: 2914334 Dog / / y6,6 Sent by: Alfredo Ma 'nez Date: 03/11/10 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive HUGHES Anchorage, Alaska 99518 Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 • s k a ' SEAN PARNELL, GOVERNOR Li . r , ,I i ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 / FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU01 -28A BP Exploration (Alaska), Inc. Permit No: 209 -125 Surface Location: 958' FNL, 1500' FWL, SEC. 08, T1ON, R15E, UM Bottomhole Location: 543' FNL, 3853' FWL, SEC.05, T1ON, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development 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 represen ' e of the Commission to witness any required test, contact the Commission's a leum field inspector at (907) 659 -3607 (pager). - , incere r v 0� Dan 'W "Se. ount, r. Chai DATED this Oday of October, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS JN IL AND GAS CONSERVATION COMMI _� - PERMIT TO DRILL RECEIVED 20 AAC 25.005 � 5 ? � � 1 a. Type of work: 1 b. Proposed Well Class: _■ Development Oil ❑ Service - Wini ❑ Single Zone 1 c. Specify t I i props or: ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone [il Cgalb G,a Ni� ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp 8SKK8 R at Li n 2. Operator Name: 5. Bond: - Blanket ❑ Single Well 11. Well Name WNW: ., 1 BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 01 - 28A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11905' TVD 8681'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028329 & 028328 958' FNL, 1500' FWL, SEC. 08, T1ON, R15E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 90' FSL, 64' FWL, SEC. 04, T1ON, R15E, UM December 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 543' FSL, 3853' FWL, SEC. 05, T1ON, R15E, UM 2560 24,500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 70' feet 15. Distance to Nearest Well Open Surface: x- 698839 y- 5939969 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 960' 16. Deviated Wells: Kickoff Depth: 9974' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 120 degrees Downhole: 3250 Surface: 2370 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/8" 3- 3/16" x 2 -7/8" 6.2# / 6.16# L -80 TCII / STL 2495' 9410' 8253'ss 11905' 8681'ss 116 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10485' 9238' None 10421' 9182' None Casing ; Length ` Size Cement Volume MD TVD Conductor / Structural 110' 20" 8 sx Poleset 110' 110' Surface 2513' 13 - 3/8" 2000 sx CS 111, 400 sx CS 11; Top Job: 125 sx CS 11 2513' 2513' Intermediate Production 10481' 9-5/8" 1000 sx Class 'G'. 300 sx CS I 10481' 9234' Liner Perforation Depth MD (ft): 10198' - 10293' Perforation Depth TVD (ft): 8990' - 9071' 20. Attachments: ❑ Property Plat ® BOP Sketch IS Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foreg $f g is t d co ct. Contact Wilmer Hoffman, 564 - 4592 Printed Name John ' Title Engineering Team Leader Prepared By Name/Number: Signature ' { Phone 564 -4711 Date / a //5 /c ' Terrie Hubble, 564 -4628 t Commission Use Only Permit To API Number: Permit Approval Date: See cover letter for Number: 4,4 50- 029 - 21597 -01 -00 Iv /23/09 I other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Er Other:' 350o PSG 8 C 1 Q St' Samples Req'd: ❑ Yes I'No Mud Log Req'd: ❑ Yes L7 / No /) w/a �S H Measures: 'Yes ■ Directional Survey Req'd: B Yes ❑ No il 2,500 D0 ,ps Arm l L. #,L I7 n) Q II APPROVED B THE COMMISSION Date /6 -15-0 / ! , COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the • : of - 25. ( 15(. )) Submit In Du icate ORIGINAL / /..z,.... m ,e,./`007- • DS 01 -28A — Coiled Tubing•Iling To: Tom Maunder Petroleum Engineer bp Alaska Oil & Gas Conservation Commission From: Wilmer Hoffman CTD Engineer Date: October 15, 2009 Re: 01 -28A Application for Permit to Drill Request CTD Drill and Complete 01 -28A program: Spud in December 15, 2009 Pre -Rig Work: 1. S Caliper tubing from 10,133' MD (done on 6/16/09) 2. S Drift and tag top of the sand (done on 6/16/09) 3. 0 MIT-0A to 2,000 psi and MIT -IA to 3,000 psi (passed both on 6/18/09) 4. 0 AC -LDS; AC- PPPOT -IC, T (all passed on 6/21/09) 5. C Set 70 bbl, 17 # /gal cement plug from 10,258' to base of the 4 -1/2" tubing tail at 9,455' 6. C Freeze protect the well and thoroughly wash the tree 7. 0 Bleed wellhead pressures down to zero. 8. 0 Bleed production flow lines and GL lines down to zero and blind flange 9. 0 Set BPV su 309 -3S1 10. 0 Remove wellhouse, level pad CTD Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 'rAs 2. Drill 3.8" pilot hole and cement ramp from top of cement at 9,455' down to 9,960'. 3. Mill 3.8" window at 9,960' and 10' of rathole in Zone 4. Swap the well to Geo -Vis. 4. Drill Build: 4.125" OH, 750' (28 deg/100 planned) with resistivity 5. Drill Lateral: 4.125" OH, 1,200' (12 deg/100 planned) with resistivity 6. Run 3- 3/16" x 2 -7/8" tapered L -80 liner leaving TOL at 9,410' 7. Pump primary cement leaving TOC at 9,410', 24 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2,000 psi. 10. Perforate liner per asset instructions ( -400') 11. Freeze protect well, set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's October 15, 2009 • DS 01 -28A — Coiled Tubing Oiling Mud Program: • Well kill: 8.6 ppg seawater / brine • Milling /drilling: 8.6 ppg Geo -vis or biozan for milling, new Geo -vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class 1 wastes will go to Pad 3 for disposal. Hole size: 4 -1/8" Casing Program: • 3- 3/16 ", 6.2 #, L -80, TC -II 9,410' MD — 10,700' MD • 2 -7/8 ", 6.16 #, L -80, STL 10,700' MD - 11,905' MD • A minimum of 24 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,410'MD) Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 120 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line — 24,500' East • Distance to nearest well within pool — 960' (01 -16) Anticollision Summary • No anti - collision issues Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • The maximum recorded H2S level on 01 -28 is 30 ppm (03 -20- 2008). Drill Site 01 is not an H2S pad. • Lost circulation risk is low. No fault crossings are expected and the occurrence of losses in nearby wells is moderate. Reservoir Pressure • Reservoir pressure is estimated to be 3,250 psi at 8,800'ss (7.1 ppg EMW). Maximum surface pressure with gas (0.10 psi /ft) to surface is 2,370 psi. Wilmer Hoffman CTD Engineer October 15, 2009 1 DS 01 -28A - Coiled Tubing•Iling TREE. FI CGD44 0 '. I SAFETY NOUS: 44/1" aiRCNIE TM, 0 1 -28 EHBI= ? 200e -- Arab. 39439000 LE1. io-a6a 1 1 ( 22 1a' H 4. w2" FESE NP, D.3E13" TVD. m0)'S 1 13984" CSt3, 5I*T211, I64164.410, D.12147" H 1511' GAS LIFTWNDELS IIYSI't k1N1m IO a 3..813" 422 2219' K.1 HES X NIPPLE 0 a uvml9a - 9999' H9.H9• x 4.111 8AIca28B4P4Q . co • 3875• I 1 1 1 0432. { 4.1/2"FESX NP, D.31t1• 4.112'TBG. MS,.13.clL 0 152 .D.3. r 9es 94e s' 4- 10* TOG TAL, D•4.000 I a re► H H I 1 H BED Tr NOT LEGGED I PH2R3MTU01 SL891MRY 1 pare c cs'r» a e to I Z 8 19E L.00G 8FCS C140604/04 AN LEATTCPMP 301p 1OIOR c� — P Flier b P►aduabn ED Far h®Itriral pad dab SIZE SI F 04190/AL CprdSg4 DATE 7 3981 4 10108.10212 0 12120E8 3918" 4 102215 10251 0 1212000 3.14r 4 10273.10293 0 1181893 ISM 14421' 1 ii1+4444441 44 #101 + +i4 1.040.40. 111+104 ,s 0 82 9.9 cen, at LAE .89 104$1' 4014 00000 .0+001440* +;40 Dl_1im • 9U_ttm 9: x'1:1'199999999[":•:' 1:i mom PFLIC UNIT .i<t;'_ .t., [.:MEMLUL_L..111:'J' .i..rH..:. =.s e :_ WELL: 0144 1 LILIA •. i :r': y1.I,, ;; 1 �i' i:$' Ot PERI TFM ,r ,'l !? ��:- !IIr \'LrU2 :! ; � API Net 900211.21997d0 r_. ts.:: = ft.�. +_ t , . -- SEC a. TIM Rt4E. MEOW FELARUM t Lr'." - - ! EhtpFapNo,a {Ate4Mey October 15, 2009 0 DS 01 -28A - Coiled Tubing •ling TREE- FIICGEN4 WELLHEAD FIE 01 -28A I SAFETY NOTES: 412" CHROMETBO. ACTUATOR - AXEL90N Id!.ELEV - 70 Proposed CTD Sidetrack BF. ELEV - ? POP- MQ Max MIN gN - 36 4e 8004 L j r, Dat4m IID- 10058' I 19 H 4-111' HESX NP, D- 3.313' I Dat1mTJD- 81100 SS 1 13 CSG, !MIT 21t, K- 5 n -0, D - 12347' H 25 1 3 GAS LIFT MANDRELS ST HD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.30" @ 9410- 1 3235 3262 27 CA.EI MAUI DEW RK D 01)16429 Li 2 9866 62516 33 CA- HMG -II DIVY RK 0 01/164 TOL 3-3116" ( 3 77 45 69G 36 CA-11111E-1.1 MY RK 0 01.0399 4 9'1233 5217 34 CA- ft 0IG -II DIIY R K 0 01.0399 9380 H9643'X4- 117BAkHiSB -0 PM. D -3875' 7-1 0' 'Too 33'' I1 I TO L I I X H 4-1 HESX NP. ID- 3.813' 1 4 -111' TBG, 12.6N, 18' -CP. !1152 t Y, D -3958' H 9455' I X , L 9459 4 111' TAG TAIL, D - 4000• I 1 H 8. LID TT NOT LOGGED I PERFORATONSUMARY REF LOG: BHCS ONO 6124.66 TSG R 9652' 1 ANGLEATIDP PERF: 3014 10195' Not: Refer toProd401N DB tor ltbrCalpert data SEE SPF NTERVAL OplrSgz DATE 9 960' Ha," it Ramp UlII1doM1 I 3-3,43' 4 10196 -10202 0 1211586 I, ti , I 10700' H3-3/16x2- 7r6X-0uerI 3-3.43' 4 1 0225 - 102S1 0 12/23136 k5 3,3,43' 4 10273 - 10293 0 1 1.06/93 \-, ti_ 1-- ,1204 31 ' '�- -_ -�� --,� I 3- 3116'X2- 7V11er H 11905' hole or parted 9 -518" 10128' / _ I 10258' -{ A04atd said tp 1 z PBTD 10421' .11)111.44WOgifill I 9i51S CSS, 474, Lam, D -8581' H 10481' 6 TD 10489 DATE REV BY 03 EIMEMS DATE REV BY I 031.111.1ENIS PRUDHOEBAY UNIT 0 ORIG !NIL COMPLETION 11/29104 DFR?LP 13 -3 CSG CORRECTION WELL: 01 -26.3. 0143199 R91.0 050E1436 DIM WELL HEA000RRECTIONS PERMIT No: 02115/01 TP CORRECTIO 02.0309 LIEFISV GLV C.O P1116A ) API No: 50- 029~21597 -01 051161131 DAV1tl1 03RRECTONS011N.L 0611509 RISE PRO POSED CIO SDETRACK StE 3, T10N ,R15E,5030.36'FEL &5134.49'FNL 0711 4)131 RN?P 03RRECT)DPIS 04.081W JJ1K4K GLV C . O BP Bpi oratlon (Ala IN ) October 15, 2009 . • DS 01 -28A — Coiled Tubing•lling All Measurements are from top of Riser 10/13/2009 i Q) CC 01 -28A top of bag t —Th BAG 7 1 /16" 5000 psi bttm of bag middle of blind /shears I Blind/Shears I I TOTs middle of pipe /slips I 2 3/8" combi ram /sli 71/16" 5000 psi I Mud Cross Mud Cross middle of flow cross 7 1/16" 5000 psi I I v middle of rams I 2 3/8" X 3 1/2" VBR's I I TOTs I 2 3/8" combi ram /slips middle of pipe /slips 7 1/16" 5000 psi I I e Swab Valve I I Flow Tee October 15, 2009 `R ■ BP Exploration Alaska 0 . NYiNa Baker Hughes INTEQ Planning Report bP INTEQ Company, • No rth Ameri - ALASKA - BP Local Co- ordinate Reference;, Well 01 -28 - Slot 28 project.: Prudhoe Bay TVD Reference: Mean Sea Level Site *. . PB DS 01 MD Reference; 44 : 28 12/26/1998 06:00 @ 70.008 (Nabors 18E) Well 01 -28 North Reference: True 1Nelibore: Plan 10, 01 -28A Survey. Calculation Method: Minimum Curvature Design Plan 10 a�tabase; EDM 16 - Anc Prod - WH24P Survey Tool Program :. Date 9/4/2009 From To ( ft) ,.. ( .' S urvey (Weilbor Toot Name Description ' " 100.00 9,900.00 1 : Sperry- BOSS gyro mult (01 -28) BOS -GYRO Sperry-Sun BOSS gyro multishot 9,900.00 11,905.00 Plan 10 (Plan 10, 01 -28A) MWD MWD - Standard Planned Survey . MD Inc Azi TVDS Northing ; Eastlng DLeg V. Sec TFace ( ( °): (6 .: ( (ft) (ft) (ft) (ft) ( ° /1(pft) (ft ( ° 9,900.00 31.92 88.39 8,665.11 1,044.98 3, 5,941,110.47 702,532.83 0.00 -3,330.12 0.00 TIP - 01 -28A Polygon 9,960.00 31.79 87.79 8,716.07 1,046.03 3,759.25 5,941,112.36 702,564.44 0.57 - 3,360.42 - 112.57 KOP 9,974.00 32.23 77.25 8,727.95 1,047.00 3,766.58 5,941,113.52 702,571.74 40.00 -3,367.25 90.00 End of 40 deg / 100 ft DLS 10,000.00 32.95 63.78 8,749.89 1,051.66 3,779.70 5,941,118.52 702,584.73 28.00 - 3,378.72 -90.00 10,100.00 46.33 24.25 8,827.93 1,097.57 3,819.76 5,941,165.47 702,623.56 28.00 - 3,405.53 -78.63 10,188.38 65.00 4.34 8,877.90 1,167.74 3,836.18 5,941,236.04 702,638.12 28.00 - 3,403.23 -47.51 4 I 10,200.00 63.93 0.94 8,882.91 1,178.21 3,836.66 5,941,246.52 702,638.33 28.00 - 3,400.99 - 110.00 10,300.00 58.53 329.48 8,931.97 1,261.51 3,815.31 5,941,329.23 702,614.80 28.00 - 3,358.81 - 108.50 10,338.38 58.57 316.87 8,952.06 1,287.64 3,795.75 5,941,354.83 702,594.55 28.00 - 3,333.15 -93.07 5 10,400.00 63.27 297.85 8,982.21 1,319.93 3,753.12 5,941,385.98 702,551.09 28.00 -3,283.62 79.00 10,418.38 65.16 292.53 8,990.21 1,326.96 3,738.15 5,941,392.62 702,535.94 28.00 - 3,267.33 -69.68 End of28 deg /100ft DLS 10,500.00 72.25 285.27 9,019.86 1,351.45 3,666.28 5,941,415.20 702,463.45 12.00 - 3,191.57 -45.00 10,600.00 81.27 277.13 9,042.78 1,370.20 3,570.95 5,941,431.42 702,367.67 12.00 - 3,094.64 -42.36 10,695.14 90.00 269.74 9,050.03 1,375.84 3,476.41 5,941,434.57 702,273.01 12.00 - 3,001.86 -40.48 7 10,700.00 90.00 270.33 9,050.03 1,375.84 3,471.55 5,941,434.44 702,268.16 12.00 -2,997.17 90.00 COMPASS 2003.16 Build 71 9/4/2009 4:32:06PM Page 3 �1 UR ■ BP Exploration Alaska M11LNs Baker Hughes INTEQ Planning Report 0 b INTEQ Company:. North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -28 - Slot 28 .Project Prudhoe Bay TVP Reference:..: Mean Sea Level '; Site PB DS 01 MD Reference: ; 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Weil 01 -28 ; . . North Reference: �; True Weilbore:, Plan 10, 01 -28A : ... Survey Calculation Method Minimum Curvature Deslgn :'; : ' Plan 10 .' ::Database EDM .16 - Anc Prod - WI-124P Planned Survey .. . MD lnc Azl WS.. EIW Northing Fasting DLeg V. Sec TFece TVDSS ft .. (f '._,,:..: _. (ft) ...: ( _'.. .. "; . (it) :.... . . ( . ' (7/ .. .:: ,.. . (ft)..., ., .,,.. ' ( °) : . ..: : 10,752. 90.00 2 76.5 9 9,00.03 1,378.99 3,19.46 5,941,4 702,216.00 12.00 - 2,946.0 90.0. 01 -28A Target 1 10,781.14 90.00 280.06 9,050.03 1,383.18 3,390.84 5,941,439.65 702,187.29 12.00 - 2,917.31 90.00 8 10,800.00 92.26 280.06 9,049.65 1,386.47 3,372.28 5,941,442.45 702,168.64 12.00 - 2,898.53 0.00 10,881.14 102.00 280.06 9,039.59 1,400.52 3,293.10 5,941,454.41 702,089.12 12.00 - 2,818.40 0.00 9 10,900.00 102.80 277.90 9,035.54 1,403.40 3,274.91 5,941,456.81 702,070.87 12.00 - 2,800.09 -69.00 10,981.14 106.04 268.41 9,015.30 1,407.76 3,196.55 5,941,459.10 701,992.43 12.00 - 2,723.28 -69.47 10 11,000.00 106.42 270.73 9,010.03 1,407.63 3,178.45 5,941,458.49 701,974.34 12.00 - 2,705.82 80.00 11,100.00 107.99 283.19 8,980.34 1,419.14 3,083.84 5,941,467.50 701,879.47 12.00 - 2,611.47 80.65 11,181.14 108.68 293.43 8,954.76 1,443.28 3,010.83 5,941,489.71 701,805.85 12.00 - 2,534.69 84.35 11 11,200.00 108.86 291.04 8,948.69 1,450.04 2,994.31 5,941,496.03 701,789.15 12.00 - 2,516.98 -85.00 11,300.00 109.31 278.35 8,915.87 1,473.97 2,903.13 5,941,517.54 701,697.38 12.00 - 2,422.71 -85.77 11,400.00 108.89 265.66 8,883.03 1,477.25 2,808.92 5,941,518.34 701,603.12 12.00 - 2,330.87 -89.9iik 11,431.14 108.58 261.72 8,873.02 1,474.01 2,779.62 5,941,514.33 701,573.91 12.00 - 2,303.40 -94.1 12 11,500.00 108.38 270.43 8,851.16 1,469.55 2,714.54 5,941,508.15 701,508.98 12.00 - 2,241.70 90.00 11,581.14 107.64 280.65 8,826.01 1,477.00 2,637.85 5,941,513.58 701,432.13 12.00 - 2,165.69 92.77 13 11,600.00 109.09 278.81 8,820.07 1,480.03 2,620.22 5,941,516.14 701,414.42 12.00 - 2,147.88 -50.00 11,700.00 116.40 268.48 8,781.35 1,486.10 2,528.42 5,941,519.79 701,322.50 12.00 - 2,057.63 -50.58 11,731.14 118.52 265.02 8,766.99 1,484.54 2,500.83 5,941,517.50 701,294.96 12.00 - 2,031.39 -54.59 14 11,800.00 119.63 274.39 8,733.47 1,484.20 2,440.76 5,941,515.58 701,234.92 12.00 - 1,973.45 80.00 11,900.00 120.05 288.22 8,683.52 1,501.12 2,356.01 5,941,530.26 701,149.76 12.00 - 1,887.21 84.56 9/4/2009 4 :32 :O6PM Page 4 COMPASS 2003.16 Build 71 M! ■ BP Exploration Alaska tailis Baker Hughes INTEQ Planning Report 0 bP ' INTEQ Company: North America - ALASKA - BP> .. Local Co- ordinate Reference Well 01-28 - Slot 2 8 Project: : Prudhoe Bay TVD Reference Mean Sea Level , Site: PB DS 01 MD Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Well: 01 -28 North Reference: True Wetlbot'e Plan 10, 01 -28A Survey Calculation Method: Minimum Curvature Design: Plan 10 latabase EDM .16 - Anc Prod - WH24P Planned Sunrey :•: , . MD Inc Azi TVOSS ' N1 /S EJW ... Northing ' La sting DLeg ' Y Sec TFace tft ? ,,. ,.. ( °) (�) , ...... .. . (ft) (ft) ( (ft) (ft) ( °1100ft): (ft) <.. (°) 11,903.68 120.04 288.73 8,681.68 1,502.13 2,352.99 5,941,531.18 701,146.71 12.00 1,884.03 91.47 01 -28A Target 2 11,905.00 120.03 288.91 8,681.02 1,502.50 2,351.90 5,941,531.53 701,145.62 12.00 - 1,882.89 91.73 TD at 11905.00 - 2 7/8" - 01 -28A Fault 1 Tairget .. Target Name • hit/ttiiss target Dip Angle" Dip Dir. TVD +N/-S +E/ -W Northing Easfing • Shape ( °) (1 ( (ft) (ft) ( ( Latitude Longitude 01 -28A Target 2 0.00 0.00 8,681.00 1,492.02 2,350.01 5,941,521.00 701,144.00 70° 14' 38.847 N 148° 22' 30.775 W - plan misses target center by 10.56ft at 11903.68ft MD (8681.68 TVD, 1502.13 N, 2352.99 E) - Point 01 -28A Fault 1 0.00 0.00 0.00 1,488.33 2,831.10 5,941,530.00 701,625.00 70° 14' 38.809 N 148° 22' 16.788 W - plan misses target center by 8694.25ft at 11905.00ft MD (8681.02 TVD, 1502.50 N, 2351.90 E) - Polygon Point 1 0.00 1,488.33 2,831.10 5,941,530.00 701,625.00 Point 2 0.00 1,452.05 2,500.01 5,941,485.00 701,295.00 01 -28A Polygon 0.00 0.00 0.00 1,127.04 4,012.05 5,941,200.00 702,815.00 70° 14' 35.250 N 148° 21' 42.459 W - plan misses target center by 8670.16ft at 9900.00ft MD (8665.11 TVD, 1044.98 N, 3727.60 E) - Polygon Point 1 0.00 1,127.04 4,012.05 5,941,200.00 702,815.00 Point 2 0.00 1,453.66 3,955.64 5,941,525.00 702,750.00 Point 3 0.00 1,760.39 2,378.09 5,941,790.00 701,165.00 Point4 0.00 1,412.20 2,303.88 5,941,440.00 701,100.00 Point 5 0.00 1,134.03 3,747.13 5,941,200.00 702,550.00 01- 28ATarget 1 0.00 0.00 9,051.00 1,378.77 3,419.45 5,941,436.00 702,216.00 70° 14' 37.729 N 148° 21' 59.684 W - plan hits target center - Point 1 9/4/2009 4:32:O6PM Page 5 COMPASS 2003.16 Build 71 SAUCER ■ BP Exploration Alaska N 0 bP . IIONIIR$ Baker Hughes INTEQ Planning Report INTEQ Company :: ° North America - ALASKA - BP = . Local Co- ordinate Reference: Well 01 -28 Slot 28 Project `: Prudhoe Bay ' TYD Reference: ::Mean Sea Level Site PB DS 01 MD. Reference: 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Weit 01 -28 North Reference: True Weilbore: Plan 10, 01 -28A Survey Calculation Method: Minimum Curvature Design: ' Plan 10 .. " " database EDM .16 - Anc Prod - WH24P Casing Points" " `' Measured Vertical Casing Hcie , .: ? . " Depth. d Depth . Diameter Diameter; 11,905.00 8,681.02 2 7/8" 2.875 4.125 Plan Annotations Measured Vertical . Local Coordinates Depth Depth +N/-S +E/ -W (ft) (ft) (ft) (ft) ! Commen 9,900.00 8,665.11 1,044.98 3,727.60 TIP 9,960.00 8,716.07 1,046.03 3,759.25 KOP 9,974.00 8,727.95 1,047.00 3,766.58 End of 40 deg / 100 ft DLS 10,188.38 8,877.90 1,167.74 3,836.18 4 10,338.38 8,952.06 1,287.64 3,795.75 5 10,418.38 8,990.21 1,326.96 3,738.15 End of 28 deg / 100 ft DLS 10,695.14 9,050.03 1,375.84 3,476.41 7 10,781.14 9,050.03 1,383.18 3,390.84 8 10,881.14 9,039.59 1,400.52 3,293.10 9 10,981.14 9,015.30 1,407.76 3,196.55 10 11,181.14 8,954.76 1,443.28 3,010.83 11 11,431.14 8,873.02 1,474.01 2,779.62 12 11,581.14 8,826.01 1,477.00 2,637.85 13 11, 731.14 8,766.99 1,484.54 2,500.83 14 11,905.00 8,681.02 1,502.50 2,351.90 TD at 11905.00 Checked By: Approved By: Date: 9/4/2009 4:32:O6PM Page 6 COMPASS 2003.16 Build 71 • Azimgrolo Nuths lv ToMoo North . g1 .1 rth WELLBORE DETAILS: Plan 10, 01 - 28A REFERENCE INFORMATION / Project: Prudhoe Bay Ma: 22.64 ■ Site: PB DS 01 Magnetic F�eq 500292159701 Coordinate (NIE) Reference: Wel 01 -28 - Slot 28, True North BAKER 0 bp Well: 01 -28 Strength: 57675.5snT Vertical (W0) Reference. Mean Sea Level 11YfiNES • Wellllore: Plan 10, 01 -28A De Angle. 110 92" Sector (VS) Reference Slot - 28(0009, 000E) P lan: Plan 10 01- 26/Plan 10, 01 -28A Date. 914/2000 Parent Wellbore. 01-28 Measured Depth Reference. 44:281226/1998 06:00 @ 70.008 (Nabors 18E) M otler. BGGM2000 Tie on MD. 9900.00 Calculation Method Minimum Curvature I NTEQ 19110 1 _ : : : : :■ _ ... . ,._ • 1800 uw.. • ...■u WELL DETAILS 01 -28 1700 0I -28A Targe - :• - 01 -28A Fault 1 :■...._.: $ ;: gf l ;$ ...; -' ' a mi Ground Level: 0.00 � . � , . _ I -'' I $$$$$$$$$$$$$$$$$$R := +EI-W +N/-S Northing Easting Latittude Longitude Slot ■... ' ' ' ' _ 01 28 Taiga -. , - ..... _, Too 0.00 5939967.60 69883429 70° 14' 24.176 N 148° 23' 39.099 W 28 1600 MI ■ t 14 N_ ■■.. ' _ - -,- _ n � `�iio 1 3 _ I II ni Gndtf - deg / 10 ft DLS SECTION DETAILS ANNOTATIONS 1500 : ° :. _ P olygon Sec MD Inc Azi SsTVD +NI -S +E / -W DLeg TFace VSec Target Annotation 1400 - : - _ �; •m .'.r' .-- ■■■■■a N "' Zi 1 9900,00 31.92 88.39 8665.11 1044.98 3727.60 0.00 0.00 - 3330.12 TIP I ^ ume.cc. _ - ..n euuu _ la nn■ Jii= � -::: 3 9974.00 32.23 77.25 8727.95 1047.00 3766.58 40.00 270.00 - 336725 End of 40 deg 1100 ft DL.0 1300 4 10188.38 65.00 4.34 8877.90 1167.74 3836.18 28.00 270.00 - 3403.23 4 V. ED at II IUS.UO', .77., .zlr n 1 i' 5 10338.38 58.57 316.87 8952.06 1287.64 3795.75 28.00 250.00 - 3333.15 5 01200 -- • -. 6 10418.38 65.16 292.53 8990.21 1326.96 3738.15 28.00 281.00 - 326733 End of 28 deg /100 ft DUI , t 1 7 10695.14 90.00 269.74 9050.03 1375.84 3476.41 12.00 315.00 -3001.86 7 .- 8 10781.14 90.00 280.06 9050.03 1383.18 3390.84 12.00 W.00 - 2917.31 8 + .lai!!!i!! 9 • 10881.14 102.00 280.06 9039.59 1400.52 3293.10 12.00 0.00 - 2818.40 9 Y 10 10981.14 106.04 268.41 9015.30 1407.76 3196.55 12.00 291.00 - 2723.28 10 0 1000 . n 01...8 III "2 11 11181.14 108.68 293.43 8954.76 1443.28 3010.83 12.00 80.00 - 2534.69 11 12 11431.14 108.58 261.72 8873.02 1474.01 2779.62 12.00 275.00 - 2303.40 12 ,- 900 .2,-- : : :■. : $$ TIP KDP 13 11581.14 107.64 280.65 8826.01 1477.00 2637.85 12.00 90.00 - 2165.69 13 - ° _ _ _.Lnd of 40 deg / 100 (1 s 14 11731 14 118.52 265.02 8766.99 1484.54 2500.83 12.00 310.00 - 2031.39 14 - _ ii 15 11905.00 120.03 288.91 8681.02 1502.50 2351.90 12.00 80.00 - 1882.88 TD at 11905.00 p 800 . - - III 700 600 : un nn 500 400 _... __ :::$: ::$: 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 West( -) /East( +) (100 ft/in) + } II II 8650- - - :......: T1 % seer ' sucseie ; : ; ; =. m.0a!Aicw■errudi t 8700- _' . $ a1 11905.00 , I : : :. :.: .�^ : t. uoor•vno 40 deg / (00 0 D ■■ • 8750 - /, End of LS .;■ na 8850 - - : I . .... : • O - _ rI : :: :EMI I : :::91 .. __._,_ ..,. ' 8900 . - _ . A - ' , 1 CI -1 03 nd of 28 deg / 100 it DLS . ::: • ' ■ :a.. :r I ..........:..l...: : :. :.: :■: 03 _ m.::: ' E:: :::p:9'' % : I , 5 - 1� . __ muuuu 01 -29A Target 1 .. - •� : o f 9000 -- _' r• ••:::: • peer- - - 111 -' e���m:... - T 1 : _8 1 I p 10 : . ::: a : N 9050 01 4 of : .r•r�n ■ ■■ t ` === _ `:::: +l - I . : -I 9 ;; . -. _ :: ■: INN $$$..$$$$iii F - ' 9111 •••••••• - 11111111111•11••••••••11111111 , •: :_o.a�.� Mid 9150 • . _ t�nr>•ri_r••n• ..r .a.r�■ ■■ __ I �_ : 9200 ' ... r •• $: :: .: -3550 -3500 -3450 -3400 -3350 -3300 -3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 Vertical Section at 285.00° (50 ft/in) �R ■ • BP Exploration Alaska • I tS Travelling Cylinder Report 0 bp INTEQ Company North America - ALASKA - BP Local Ca- ordinate Reference: Well 01 -28 - Slot 28 Project Prudhoe Bay TYD Reference:: : Mean Sea Level Reference Site:: PB DS 01 MD. Reference: ; 44 : 28 12/26/1998 06:00 @ 70.00ft (Nabors 18E) Site`Error 0.00ft North Reference: True Reference Welt 01 -28 Survey Calculation Method:. Minimum Curvature Well".Error O.00ft Output errors are at ` 1.00 sigma Reference Wellhore, Plan 10, 01 -28A Database: EDM .16 - Anc Prod - WH24P Reference Des gn :Plan 10 Offset r/D Reference: Offset Datum Reference Plan 10 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,900.00 to 11,905.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,387.50ft Error Surface: Elliptical Conic Survey Tool PraYn Date 8/4/2009' from To (ft). Surlily elibore Tool Name descrl tion 100.00 9,900.00 1 : Sperry-Sun BOSS gyro multi (01 -28) BOSS -GYRO Sperry-Sun BOSS gyro multishot 9,900.00 11,905.00 Plan 10 (Plan 10, 01 -28A) MWD MWD - Standard Casing. Points: Measured .. V ertt ca . .' Casing - Hale Depth Depth . Diamnefer : Dlemeter (ft3 " (ft): Name (in) 11,905.00 8,681.02 2 7/8" 2.875 4.125 Summary : Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning De : Distance'. (ft) .: from Ptanr Site. Name � � . � � � � pth Depth . Offset Weli: Wellbore - Design (ft) . (ft) . (ft) ,. - (ft) PB DS 01 01 -01 - 01 -01 - 01 -01 Out of range 01-01A - 01-01A- 01-01A Out of range 01 -01A- 01- 01B- 01 -01B Out of range 01 -05 - 01 -05 - 01 -05 Out of range 01 -05 - 01 -05B - 01-05B Out of range 01 -05 - 01 -05B - Plan 01 -05B Wp16 Out of range 01 -05 - 01 -05PB1 - 01 -05P81 Out of range 01 -06 - 01 -06 - 01 -06 10,300.00 10,200.00 1,359.64 833.39 571.89 Pass - Major Risk 01 -06A - 01 -06A - 01 -06A Out of range 01 -08 - 01 -08 - 01 -08 Out of range 01 -09 - 01 -09 - 01 -09 Out of range 01-09A - 01 -09A - 01 -09A Out of range 01 -12 - 01 -12 - 01 -12 9,903.33 10,525.00 1,224.54 1,479.54 17.42 Pass - Major Risk 01 -12 - 01 -12A - 01 -12A 9,903.33 10,525.00 1,224.54 1,479.54 17.42 Pass - Major Risk 01 -12 - 01 -12A - Plan #3 9,903.33 10,525.00 1,224.54 1,479.54 17.42 Pass - Major Risk 01 -16 - 01 -16 - 01 -16 11,700.00 10,050.00 914.82 651.57 286.65 Pass - Major Risk 01 -28 - 01 -28 - 01 -28 9,974.95 9,975.00 0.77 11.76 -10.98 FAIL - Major Risk 01 -31 - 01 -31 - 01 -31 Out of range 01 -34 - 01 -34 - 01 -34 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/4/2009 4 :39 :35PM Page 2 of 9 COMPASS 2003.16 Build 71 Alaska Department of Naturalsources Land Administration System • Page 1 oft C' :?s Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources �r Alaska DNR Case Summary File Type: ADL File Number: 28328 Printable Case File Summary See Township, Range, Section and Acreage? New Search 0 Yes 0 No LAS Menu ;Case Abstract I Case Detail I Land Abstract File: ADL 28328 nua__ Search for Status Plat Updates As of 10/16/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O10N Range: 015E Section: 03 Section Acres: 640 Search Plats Meridian: U Township: O10N Range: 015E Section: 04 Section Acres: 640 Meridian: U Township: O10N Range: 015E Section: 09 Section Acres: 640 Meridian: U Township: 010N Range: 015E Section: 10 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -158 T10N- R15E -UM 3, 4,9,10 2560.00 U- 3- 7 07 -06 -1987 * ** LISBURNE PARTICIPATING AREA LEGAL DESCRIPTION * ** T. ION., R. 15E., U.M. SECTION 3: ALL 640 ACRES SECTION 4: ALL 640 ACRES http: / /dnr.alaska.gov /projects /las /Case Summary.cfin ?FileType= ADL &FileNumber = 283... 10/16/2009 Alaska Department of Naturalsources Land Administration System Page 1 of? ( Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28329 a Printable Case File Summary See Township, Range, Section and Acreage? Yes Q No New Search LAS Menu 1 Case Abstract I Case Detail 1 Land Abstract File: ADL 28329 +lap Search for Status Plat Updates As of 10/16/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2501.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 010N Range: 015E Section: 05 Section Acres: 640 Search Plats Meridian: U Township: 010N Range: 015E Section: 06 Section Acres: 609 Meridian: U Township: O10N Range: 015E Section: 07 Section Acres: 612 Meridian: U Township: O10N Range: 015E Section: 08 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -159 T10N- R15E -UM 5, 6, 7, 8 2501.00 U- 3- 7 End of Case Summary Last updated on 10/16/2009. http: / /dnr.alaska.gov /projects /las /Case_Summary.cfin ?FileType= ADL &FileNumber = 283... 10/16/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME Ord J7ff • PTD# o2 09/03,5"" ✓ Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: / POOL: 1,el/d�0 19)4 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(D, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 01 -28A Program DEV Well bore se PTD#: 2091250 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is welibore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative app roval Yes ACS 10/16/2009 13 Can permit be approved before 15 -day wait Yes • 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31,05.0300„1.A),(j,2.A -D) NA 18 Conductor string provided NA Conductor set in DS 01 -28 Engineering 19 Surface casing protects all known USDWS NA Surface casing set in DS 01 -28 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in DS 01 -28 22 CMT will cover all known productive horizons Yes Tapered liner to be cemented back to window. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -351 26 Adequate welibore separation proposed Yes Proximity analysis performed. Closest welibore is 01 -28 and paths diverge. 27 If diverter required, does it meet regulations NA BOP stack in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3250 psi (7.1ppg EMW) Will drill with 8.6 ppg mud GLS 10/21/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2370 psi Will test BOP's to 3500 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S present on DS1 .. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on well 01 -28 is 30ppm (3/20/08). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones _ _ NA ACS 10/16/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Cub; Date: Dat C1)- iQ (e..,ii. eDate Commissioner: Co i i ne : . • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. 4 tapescan.txt * * ** REEL HEADER * * ** MWD 10/03/10 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 09/12/16 2914334 01 3" CTK * ** LIS COMMENT RECORD * ** 11III111 1 111 111 Remark File Version 1.000 1111111111111111111 Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP, NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9900.0000: Starting Depth STOP.FT 11980.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 01 -28A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 14' 24.176 "N 148 deg 23' 39.099 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 16 Dec 2009 API . API NUMBER: 500292159701 Parameter Information Block #MNEM.UNIT Value Description SECT. 08 Section TOWN.N T1ON Township RANG. R15E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 70.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 70.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 • tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and any depth adjusting has been waived. The MWD data is the Primary Depth Control (PDC) log for well 01 -28A per Mikie weeks with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 01 -28 through a milled window in a 9.625 inch liner. Top of window 9923 ft.MD (8684.8 ft.TVDSS) Bottom of window 9932 ft.MD (8692.4 ft.TVDSS) (9) Tied to 01 -28 at 9900 feet MD (8665.1 feet TVDSS). (10) The interval from 11930 ft to 11980 ft MD (8636.1 ft. to 8614.6 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 74 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** ����III I ! IIII III Remark File version 1.000 The data presented here is final and any depth adjusting has been waived. The MWD data is the Primary Depth Control (PDC) log for well 01 -28A Page 2 • • tapescan.txt per Mikie weeks with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 116 Tape File Start Depth = 9900.000000 Tape File End Depth = 11980.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 2 129 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD *°* Page 3 • tapescan.txt 1111111111111111 Remark File version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 232 Tape File Start Depth = 9900.000000 Tape File End Depth = 11980.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 245 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 09/12/16 2914334 01 Page 4 . • tapescan.txt * * ** REEL TRAILER * * ** MWD 10/03/10 BHI 01 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9900.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9900.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10000.0000 50.4000 17.1000 49.4970 564.7600 86.5600 71.0340 10100.0000 32.7000 46.3000 41.0250 95.3690 53.2840 46.7410 10200.0000 36.1000 31.2000 5.8270 6.3200 6.0080 5.9160 10300.0000 45.9000 80.0000 7.0170 6.6190 5.9760 5.1440 10400.0000 42.3000 85.7000 9.1400 10.2060 8.8960 8.0290 10500.0000 39.1000 52.2000 6.5590 6.4170 6.5270 6.5580 10600.0000 38.3000 73.7000 11.6590 16.9420 17.9500 20.1300 10700.0000 36.4000 115.8000 4.8940 4.3260 3.8440 3.3460 10800.0000 145.6000 20.6000 18.6350 26.2960 22.2400 20.2300 10900.0000 63.1000 75.9000 5.1830 7.4450 7.4520 10.3300 11000.0000 109.4000 39.0000 25.5970 33.4390 Page 5 . • • tapescan.txt 27.9940 23.8060 11100.0000 39.1000 62.0000 4.2740 4.9140 4.7280 5.0850 11200.0000 34.5000 90.6000 4.7240 4.4580 4.3680 4.1050 11300.0000 33.6000 63.6000 13.5000 16.0900 12.9430 11.2980 11400.0000 29.5000 24.7000 50.6120 157.4900 76.7830 65.2950 11500.0000 33.7000 56.8000 49.4550 159.4400 82.9190 70.8620 11600.0000 39.1000 17.2000 57.6520 388.1720 50.6220 37.6890 11700.0000 58.8000 36.7000 42.0000 87.8350 52.2130 45.8970 11800.0000 53.5000 43.1000 57.1070 671.8660 95.0250 77.2880 11900.0000 94.1000 64.9000 47.2450 79.4010 37.9500 29.4590 11980.0000 - 999.2500 25.3000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9900.000000 Tape File End Depth = 11980.000000 Tape File Level spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9900.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9900.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10000.0000 50.4000 17.1000 49.4970 564.7600 86.5600 71.0340 10100.0000 32.7000 46.3000 41.0250 95.3690 53.2840 46.7410 10200.0000 36.1000 31.2000 5.8270 6.3200 l 6.0080 5.9160 10300.0000 45.9000 80.0000 7.0170 6.6190 5.9760 5.1440 10400.0000 42.3000 85.7000 9.1400 10.2060 8.8960 8.0290 Page 6 . tapescan.txt 10500.0000 39.1000 52.2000 6.5590 6.4170 6.5270 6.5580 10600.0000 38.3000 73.7000 11.6590 16.9420 17.9500 20.1300 10700.0000 36.4000 115.8000 4.8940 4.3260 3.8440 3.3460 10800.0000 145.6000 20.6000 18.6350 26.2960 22.2400 20.2300 10900.0000 63.1000 75.9000 5.1830 7.4450 7.4520 10.3300 11000.0000 109.4000 39.0000 25.5970 33.4390 27.9940 23.8060 11100.0000 39.1000 62.0000 4.2740 4.9140 4.7280 5.0850 11200.0000 34.5000 90.6000 4.7240 4.4580 4.3680 4.1050 11300.0000 33.6000 63.6000 13.5000 16.0900 12.9430 11.2980 11400.0000 29.5000 24.7000 50.6120 157.4900 76.7830 65.2950 11500.0000 33.7000 56.8000 49.4550 159.4400 82.9190 70.8620 11600.0000 39.1000 17.2000 57.6520 388.1720 50.6220 37.6890 11700.0000 58.8000 36.7000 42.0000 87.8350 52.2130 45.8970 11800.0000 53.5000 43.1000 57.1070 671.8660 95.0250 77.2880 11900.0000 94.1000 64.9000 47.2450 79.4010 37.9500 29.4590 11980.0000 - 999.2500 25.3000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9900.000000 Tape File End Depth = 11980.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 7
