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Home My WebLink About201-1161a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: 2/6/2022 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 48.2' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 109' 7-5/8" L-80 2,572' 5-1/2" L-80 6,966' x3-1/2" 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 7/10/2001 7/2/2001 00-001 ADL 028239 1900' (Approx.) N/AN/A None 7,190' / 6,983' MWD, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 91.5# 29.7# 109' 24' 7,173' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 15.5#/9.3# 24' DEPTH SET (MD) PACKER SET (MD/TVD) 27' CASING WT. PER FT.GRADE 582353 582328 TOP SETTING DEPTH MD 28' SETTING DEPTH TVD 5979255 BOTTOM TOP 6-3/4" 28' 9-7/8" HOLE SIZE AMOUNT PULLED 50-029-23025-00-00 PBU L-116 583174 5978094 1740' FNL, 731' FWL, Sec. 34, T12N, R11E, UM, AK CEMENTING RECORD 5979252 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 2372' FSL, 3743' FEL, Sec. 34, T12N, R11E, UM, AK 1737' FNL, 706' FWL, Sec. 34, T12N, R11E, UM, AK 201-116 / 321-523 Prudhoe Bay Field / Borealis Oil Pool 76.2' 6,675' / 6,468' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 30" 27' 2,653'443 sx AS Lite, 175 sx Class 'G' 260 sx Arctic Set (Approx.) 217 sx LiteCrete 6438'3-1/2" 9.2# 13Cr80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 9:29 am, Feb 22, 2022 Abandonment Date 2/6/2022 MDG RBDMS 2/23/2022 MDG MGR09MAR2022 DLB 04/26/2022 DSR-4/27/22 xG Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 6675' 6468' 4089' 3932' 4362' 4194' 4469' 4297' 4852' 4668' 5849' 5645' 6504' 6298' 6675' 6468' 6833' 6626' 6939' 6732' 7029' 6822' Miluveach 7029' 6822' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. 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. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Kuparuk A Summary of Pre-Rig Work, Daily Drilling Report, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS This form and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Base Kuparuk / Miluveach Kuparuk C LCU / Kuparuk B If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager CM 1 Kalubik Schrader Bluff Schrader Bluff N Schrader Bluff O Base Schrader / Colville Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 2.22.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.02.22 08:44:59 -09'00' Monty M Myers ACTIVITYDATE SUMMARY 12/18/2021 ***WELL SI ON ARRIVAL*** DRIFT & TAG TD @ 6,770' SLM W/ 20' x 2.70" DMY WHIPSTOCK DRIFT RUN READ 24 ARM CALIPER FROM 6,750' SLM TO SURFACE ***CONT WSR ON 12/19/2021*** 12/19/2021 ***CONT WSR FROM 12/18/2021*** SET 3-1/2" X-CATCHER IN X-NIPPLE @ 6,399' MD PULL 1" INT-OGLV FROM STA #2 @ 5,720' MD PULL 1" INT-LGLV FROM STA #3 @ 5,002' MD PULL 1" INT-LGLV FROM STA #4 @ 4,253' MD PULL 1" INT-LGLV FROM STA #5 @ 3,535' MD SET 1" BK-DGLV IN STA #5 @ 3,535' MD SET 1" BK-DGLV IN STA #4 @ 4,253' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** READ Ticket #15819 1/4/2022 ***WELL S/I ON ARRIVAL*** (pre ctd) SET BK-DGLV IN ST #3 @ 5,002' MD 2 ATTEMPTS TO SET BK-DGLV IN ST #2 @ 5,720' MD LRS PUMPED 82 BBLS CRUDE DWN IA TO LOAD SET INT-DGLV IN ST #2 @ 5,720' MD PULLED 3-1/2" X CATCHER @ 6399' MD (empty) LRS PUMPED 86 BBLS CRUDE DWN TBG TO LOAD SET 3-1/2" EVOTRIEVE PLUG @ 6616' MD (ME) ***WSR CONT. ON 1/5/22*** 1/4/2022 T/I/O= 1070/1000/300 LRS 72 Assist Slickline (CTD). Pumped 85 bbls of crude into the IA. S/L set last DGLV. Pumped 10 bbls of crude to varify last DGLV was set.Pumped 86 bbls crude into TBG. *** WSR Continued on 01/05/22*** 1/5/2022 ***WSR CONT. FROM 1/4/22*** (pre ctd) LRS PERFORMED MIT-IA TO 4000 PSI **PASS** LRS PERFORMED MIT-T TO 4500 PSI **PASS** PULLED 3-1/2" EVOTRIEVE PLUG @ 6616' MD DRIFTED TO 6,700' SLM (6,724' MD) W/ 20' x 2.74" DUMMY WHIPSTOCK ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 1/5/2022 E-Line unit SLB 2316 Job Scope: Set Packer Whipstock - Pre CTD. MIRU. Make up, surface test orientation, and RIH w/ Northen Solutions 350 Mono- Pack retrievable packer w/ 350 Wedge Whipstock w/ RA tags, Baker 10 setting tool, orienter, GR/CCL and 7/32" cable head. Set packer Whipstock @ 6675' (top of tray) oriented 175 deg ROHS. Middle of element @ 6682'. POH. RD SLB E-Line 1/5/2022 *** WSR Continued from 01/04/22 *** MIT-IA PASSED to 4022 psi Max Applied Pressure=4200 psi target Pressure=4000 psi Pressured Tbg to 2464 psi with 1.64 bbls of crude. MIT-IA lost 135 psi in the 1st 15 minutes and 28 psi in the 2nd 15 min for a total loss of 163 si during a 30 min test. Bled IA to 1491 psi recovering ~ 1.2 bbls. MIT-T PASSED to 4787 psi Max Applied Pressure=5000 psi Target Pressure=4500 psi Pressured TBG to 4964 psi with 1.31 bbls of crude. MIT-T lost 135 psi in the 1st 15 minutes and 42 psi in the 2nd 15 min for a total loss of 177 psi during a 30 minute test. Bled TBG to 1475 psi recovering ~ .9 bbls. PSL in control of well upon Departure. CV's=OTG FWHP's=1500/1000/300 Daily Report of Well Operations PBU L-116 () LRS PERFORMED MIT-IA TO 4000 PSI **PASS** LRS PERFORMED MIT-T TO 4500 PSI **PASS** Daily Report of Well Operations PBU L-116 1/6/2022 ***WELL S/I ON ARRIVAL*** (pre ctd) SET 3-1/2" X CATCHER IN X NIP @ 6399' MD PULLED BK-DGLV IN ST# 3 @ 5002' MD, REPLACED w/ INT-DGLV PULLED BK-DGLV IN ST# 4 @ 4253' MD, REPLACED w/ INT-DGLV ***WSR CONT. ON 1/7/22** 1/7/2022 ***WSR CONT. FROM 1/6/22*** PULLED BK-DGLV IN ST# 5 @3535' MD, REPLACED w/ INT-DGLV BLED IA DWN f/ 1100 - 500 PSI TO VERIFY VALVES ARE HOLDING PULLED 3-1/2" X CATCHER @ 6399' MD (empty) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 2/1/2022 T/I/O = 1200/500/300. Remove 3-1/8" flow cross kill port flange. Install CTD kill line assembly, torque to API spec. Remove tree cap assembly & install tapped blind flange, torque to API spec.PT tree assembly to 500 psi low/5000 psi high. PT SV to 3500 psi to verify valve will meet BOP test criteria (Pass). Install fusable cap on SSV, drain hydraulic fluid from actuator. RDMO. Activity Date Ops Summary 2/5/2022 Started moving the rig down the L-Pad access road and the lead NES weighted sow truck broke down. Notified L-Pad Operator that we are blocking the road. Decision made to backup both subs back to V-Pad and swap Sow out for Dozer to assist moving the Main Sub;Continue moving rig to L-pad;Main & Pits subs on L- Pad, remove Jeeps. Verify all Tree & CSG Valves are closed and spot Main & Pit Subs. Rig spotted and accepted at 14:00. Safe out rig and start MIRU Ops Checklist. Cycle tree valves, 925 psi on well, call out grease crew swab will not hold pressure. Leak test on swab is good. Remove tree cap. Install BOPs.;Make up MP line. Grease choke valves and BOP test valves. Load KCl and PowerVis drilling fluid into pits.;Swap out risers to get correct working height. Get RKB measure- ments. Install spill catcher around riser. Rig up test chart. Configure test joint. M/U nozzle, M/U injector to well. Line up valves, fluid pack lines. Fill reel forward. Get good shell test. Test BOPs. 2/6/2022 Continue testing BOPE (05:00 start). Test #1 - IRV, Stripper, C7, C9, C10, C11 - Pass. PU injector and install night cap. Test #2 - Blind Shear, R2, BL2, C-15 - Pass. Remove night cap and install Test Cap with 2" Test Joint. Test #3 - Annular, TIW#1, B1, B4 - Pass. Test #4 - Upper 2" P/S, TIW #2, B2, B3 - Pass. Test #5 - Lower 2" P/S, C5, C6, C8, TV2 - Pass. Test #6 - Choke A, Choke C - Pass. Drawdown Test - Pass;Test Gas & PVT Alarms. Test #7 - Upper 2" Pipe/Slips, C1, C4, TV1 - Pass. Test #8 - 2-3/8" Pipe/Slips, C2, C3 - Pass;RD test equipment and PU PDL's and test to 3500psi, MASP = 2828psi;PDL's tested to 3500psi, install BHI Floats and PT floats and body test to 3500psi. Good PT to 3500psi on floats & body;PJSM to MU the Milling BHA. Pressure deploy BHA. Mill is 2.79" No-Go reamer is 2.80" No-Go. RIH pump 1.5 bpm through open EDC. Keep WHP above initial value then adjust to keep returns around 1.0 bpm. Tie-in depth from 6600' correct -10.5'. Up wt is 32k. Tag whipstock 6675'. Pick up and circulate remaining KCl around. Circ 1.8 / 1.36 bpm at 9.94# EDC with 396 psi WHP. With clean KCl to sur- face shut down, shut in ECD = 9.88 ppg. Resume circulating KCl out to tiger tank. Purge riser to bleed trailer. Swap to mud, once mud at bit losses increasing, gradually open choke. Mud at surface bring returns inside. Close EDC. Pump 1.7 bpm mud getting 0.6 bpm back. Discuss plan forward with ODE. Open EDC and circulate. Line up trucking and fluids for milling with reduced mud system. Enough fluids on location. Close EDC, RIH and tag window at 6675'. Pick up and start milling. 1.71 / 1.33 bpm at 3500 psi FS. MW 8.6 / 8.59 ppg In / Out. 2/7/2022 Continue milling window f/6674.9' to 6677.4'. In rate = 1.70 bpm Out rate = 1.54 bpm loss rate avg 12-18 bph. Circ PSI = 3530 psi WOB = 2.18k ECD = 10.28 ppg. WHP = 123 psi IAP = 825 psi OAP = 294 psi. 6679.1' WOB dropped off indicating BOW. Continue milling at 1 fph to dress the BOW with the string mill and mill 10' of Rat Hole. Rat hole milled to 6689.4', PUH at as milled TF for first back ream pass. A little motor work at the top on the as milled TF. Back ream at 160° a little MW at the top. Back ream at 190° a little MW at the top. Lost pumps, close choke, WHP at 190psi and climbing, ECD dropped to 9.6 ppg eqv. Pumps back online, not sure why we lost pumps, electrician looking at control panel for pumps. Zero out MM for a bottoms up and verify TT line is clear if we have to divert returns outside. Seeing a little motor work at the top of the window, continue back ream at as mill TF until clean. Circ PSI = 3527 psi WOB = 0 k ECD = 10.27 ppg. WHP = 122 psi IAP = 852 psi OAP = 301 psi. Bottoms up was clean, no change in rate or density. Last back ream was clean, shut down pump trapping 10.4 ECD for losses and then dry drift window. Dry drift down was clean. PU dry and window is clean, open the EDC and POOH for build BHA. 50-029-23025-01-00API #: Well Name: Field: County/State: PBW L-116A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska p tag window at 6675'. 6679.1' WOB dropped off i 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,190'None Casing Collapse Conductor 470 Surface 4,790 Production 4,990 / 10,530 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: December 1, 2021 3-1/2" 9.2# None Authorized Title: Drilling Manager Authorized Name: Monty Myers 24' - 7,173' Perforation Depth MD (ft): 6,675' - 6,835' 7,149' Perforation Depth TVD (ft): Tubing Size: 5-1/2" x 3-1/2" 24' - 6,966' 20" 7-5/8" 81' 2,626' MD 1,490 6,890 28' - 109' 27' - 2572' 28' - 109' 27' - 2,653' Prudhoe Bay Field / Borealis Oil Pool PBU L-116 PRESENT WELL CONDITION SUMMARY L-80 TVD Burst 6,432' 7,000 / 10,160 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 028239 201-116 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 50-029-23025-00-00 Hilcorp North Slope, LLC COMMISSION USE ONLY Tubing Grade: Tubing MD (ft): 6,468' - 6,628' Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 6,983' 7,032' 6,825' 2,828 None Length Size Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 9.30.2021 By Meredith Guhl at 1:39 pm, Sep 30, 2021 321-523 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.09.30 13:27:03 -08'00' Monty M Myers X Set whipstock, mill window DSR-9/30/21 BOPE test to 3500 psi for service coil window milling operations. 24 hour notice. DLB 10/01/2021 10-407 MGR01OCT2021 Variance to 20 AAC 25.112(i) alternate plug placement approved. dts 10/4/2021 JLC 10/4/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.04 13:28:03 -08'00' RBDMS HEW 10/7/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 30, 2021 Re: PBU L-116 Sundry Request Sundry approval is requested to set a packer whipstock and mill a window in L-116 pre-rig as part of the drilling and completion of the proposed L-116A CTD lateral. Proposed plan for L-116A Producer: Prior to drilling activities, a 3-1/2" Packer Whipstock will be set pre-rig with E-line in the 3-1/2" casing. The top parent perforations will remain open (6,675'-6,682' MD – above whipstock packer element). The parent perforations below 6,682’ MD will be abandoned. Service Coil will mill a single string window in the 3-1/2” casing (if scheduling needs arise, the rig will mill the window). See the L-116A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The well will kick off drilling in the Kuparuk C, build through C and land in Kuparuk B. The well will build back up and drill the lateral in Kuparuk C to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner, cemented in place and selectively perforated and fracked post rig (see future L-116A Frac Sundry). This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging some of the existing Kuparuk perforations via the packer whipstock, 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 December 2021): 1. Slickline: Dummy WS drift, dummy all mandrels, run caliper, set/pull plug for MIT a. Drift past whipstock setting location b. Run caliper across whipstock setting location c. Dummy all 3-1/2” GLMs d. Set plug and perform MITs. Pull after MIT-T and MIT-IA are complete. 2. Fullbore: MIT-IA to 4,000 psi and MIT-T to 4,500 psi 3. E-line: Set 3-1/2” packer whipstock a. Top of whipstock set at 6,675’ MD (top of window - pinch point) b. Oriented 180° ROHS 4. Service Coil: Mill Window a. Mill 2.80” window with straight motor plus 10’ of rat hole b. Single string window exit out of 3-1/2” casing 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU L-116A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,828 psi 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* (if needed) and perforate/frac post rig (see future L-116A Frac Sundry) * Approved alternate plug placement per 20 AAC 25.112(i) PTD End of Sundry 321-523 Service coil window milling surface kit. 24 hour notice to AOGCC to witness BOPE test to 3500 psi. 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 or Pad 3. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 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 PBU L-pad is an H2S pad. o The highest recorded H2S well on the pad was from L-110 (1,110 ppm) in 2021. o Last recorded H2S on L-116 was 108 ppm in 2018 Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,488 psi at 6,600’ TVD (10.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,828 psi. x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs Well Slimhole 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 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" Pipe/Slips ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~ '1 ,l `r ~; ~`r~tr~ ~~f4~~~~ `'!~ . .~ u~~ C~ bp ~.~~r~~~~~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, OCT 0 5 2009 ~ias~C~ ~il & Gas Cons. Commis~ion Anchorag~ ~,p ~ -- f l ~O ~~-~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, WeN Integrity Coordinator • • BP Exploretion (Alaska ) Inc. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) nwro L pad R/13/9()04 Well Name PTD # API # IniGal to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibkor Corrosion inhibitod sealant date ft bbls ft na al L-Ot 2010720 50029230110000 NA 6 NA 612 6/25/2009 ~-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 ~-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L•111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2017160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6127l2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L404 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L410 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6l25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27J2009 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COI~SSION REPORT OF SUNDRY WELL OPERATIONS ~~~ 1. Operations Performed: ' ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing . ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development. ^ Exploratory 201-116 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23025-00-00 7. KB Elevation (ft): 76 7'' 9. Well Name and Number: PBU L-116- 8. Property Designation: 10. Field /Pool(s): ADL 028239 ~ Prudhoe Bay Field /Borealis Pool 11. Present well condition summary Total depth: measured 7190' - feet true vertical 6983' - feet Plugs (measured) 6520' Effective depth: measured 7062' feet Junk (measured) None true vertical 6855' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 109' 109' 1490 470 Surface 2626' 7-5/8" 2653' 2572' 6890 4790 Intermediate Production 7149' S-1/2" x 3-1/2" 7173' 6966' 7000 4990 Liner t~~y~L ej g1PS~ ~h~~~~1w~DYC~F~! ~~4.J ~' C~ LV~ld c~ 4;7j Q yJ Perforation Depth MD (ft): Below Plug: 6675' - 6740' Perforation Depth TVD (tt): 6468' - 6533' 3-1/2", 9.2# 13Cr80 6438' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ®Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil~ ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact David Bjork, 564-5683 N/q Printed Name T rrie Hubble Title Drillin Technolo ist Prepared By Name/Number: i2 Signature Phone 564-4628 Date d~ erne Hubble 564-4628 Form 10-404 Revised 04/2006 r Submit Original Only / Jl t-~ • • L-116, Well History (Pre Rig Workover) Date Summary 10/10/2008 WELL SHUT IN ON ARRIVAL. PULLED 3-1/2" WFD ER PKR, SPACER PIPE, SNAP LATCH ASSY ,''FROM 6322' SLM. CURRENTLY TRYING TO FREE PKR FROM SSSVN @ 2198' SLM. 10/11/2008 RECOVERED 3 1/2" WFD ER PKR FROM SSSVN @ 2198' SLM, ELEMENT & SLIPS INTACT. PULLED 3 1/2" LOWER ANCHOR FROM 6337' SLM, MISSING ELEMENT, SLIPS INTACT. RAN 2.70" CENT, 3 1/2" BLB & S. BAILER SD @ 6719' SLM. RECD -4" OF ELEMENT & FRAC SAND. RAN 2.70" CENT SD @ 6719' SLM, DRIFT CLEAR.. RAN 3 1/2" X-LOCK FOR CORRECTION SD @ 2190' SLM, UNABLE TO WORK PAST. RAN 3 112" BLB & 2.60" 3-PRONG GRAB SD @ 6650' SLM, RECD -4" PIECE OF ELEMENT. RAN SAME X-LOCK TO 6650' SLM [CLEARI TAGGED X-NIP @ 6356' SLM, 6368' MD. SET 3 1/2" WFD WRP ON SLB E-FIRE @ 6520' MD. OD= 2.69", OAL= 2.42'. PERFORMED CMITxTxIA TO 3500psi. 10/12/2008 DUMP BAILED 3 BAGS [-9 gals] SLUGGITS ON WRP @ 6507' SLM. SET 3 1/2 JUNK CATCHER ON TOP OF SLUGGITS @ 6482 SLM.. (TL; 122", 3-1/2 GS F.N., 2.69" OD) PULLED STA #1 DGLV-INT @ 6431' SLM, LEFT OPEN AS PER PROGRAM. RDMO. LEFT WELL S/I, TURNED WELL OVER TO PAD- OP. 10/13/2008 T/I/O =SSV/300/200. Temp = SI. OA FL (RWO). OA FL @ 160' (3 bbls). WV,SSV & SV =Closed. MV = Open. IAV & OAV = OTG. NOVP. 10/13/2008 T/I/O=SSV/300/200, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (1300 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (2.25"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (150 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (2.25"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 10/14/2008 T/I/0= 250/260/150 Temp= SI Circewell. MIT OA PASSED to 2000 psi (Pre RWO) Pumped 5 bbls meth, 192 bbls 9.8# Brine, & 20 bbls diesel down tubing, up IA, to L-51's flowline. U-tube to freeze protect well. Bled tubing and IA to zero. MIT OA to 2000 psi..Pressured OA w/ 3.5 bbls crude OA lost 140 psi 1st 15 mins and 20 psi 2nd 15 mins for a total loss of 160 psi in 30 min. Bled to zero. FWHP's = 0/0/0. Did NOT freeze protect L-51's flowline. Using it to take returns on next job (L-114 LDL). Swab = shut, SSV =shut, Master =open, Wing =shut, IA =open, OA =open and tagged, AL =shut. 10/18/2008 T/I/)=0/0/0. Set 3" CIW H BPV. Pre-Doyon 14. Page 1 of 1 • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: N From - To ', -116 -116 WORKO ABOBS NABOBS Hours VER ALASK 9ES Task ; DRI Code LING NPT Start I Rig Rig N Phase Spud Date: 7/1/2001 : 10/26/2008 End: Release: umber: 9ES Description of Operations 10/26/2008 06:00 - 07:30 1.50 RIGD P PRE -RD stand pipe and manifold, windwall brace and top drive rail brace. -Lay over gas buster. 07:30 - 08:30 1.00 RIGD P PRE Mobilize block trolley, bridle yolk, block pull, back line and sheave. 08:30 - 11:00 2.50 RIGD P PRE -Slip on drilling line. -RD torque tube and link tilt. -Pull in conveyor. -Disconnect choke flange, mud bucket line, stand pipe jumper hose and mouse hole hydraulic lines. -RU A-leg hydraulic lines 11:00 - 12:00 1.00 RIGD P PRE -RD kelly hose -Remove off-driller-side carriage roller 12:00 - 13:30 1.50 RIGD P PRE -Remove service lines from top drive. -LD top drive. 13:30 - 14:30 1.00 RIGD P PRE Install carriage and attach to blocks. 14:30 - 16:00 1.50 RIGD P PRE -Unhang rig tongs and tie lines back. -Bring down bridle lines 16:00 - 17:30 1.50 RIGD P PRE -Hang and pin C-section -Bridle up. 17:30 - 19:00 1.50 RIGD P PRE -Prepare to LD wind walls. -Take down lights and camera. -Get rig floor ready to skid and blow down same. 19:00 - 20:30 1.50 RIGD P PRE -Skid rig floor to moving position. -Blow down and remove heaters in cellar. 20:30 - 21:30 1.00 RIGD P PRE Move rig off well 11-34 and position on pad to LD derrick. 21:30 - 22:00 0.50 RIGD P PRE Skid rig floor back to LD errick position 22:00 - 00:00 2.00 RIGD P PRE LD wind walls. 10/27/2008 00:00 - 01:00 1.00 RIGD P PRE -Remove windwall heater. -Verify derrick secured. 01:00 - 02:00 1.00 RIGD P PRE -Remove derrick pins. -Lay over derrick. -Remove pins f/ A-legs and tip same. 02:00 - 03:00 1.00 RIGD P PRE -Install rear boosters. -Pull ahead and verify boosters working. 03:00 - 04:00 1.00 MOB P PRE Wait on Security and CPS. 04:00 - 12:00 8.00 MOB P PRE Move rig f/ DS 11 down West Dock Rd towards K-pad Rd. 12:00 - 00:00 12.00 MOB P PRE Cont. moving rig down West Dock Rd, then on K-pad Rd to Spine Rd, and on Spine Rd to Kuparuk River (east channel). 10/28/2008 00:00 - 08:30 8.50 MOB P PRE Cont. moving rig f/ Kuparuk River (east channel) to L-Pad. 08:30 - 10:30 2.00 RIGU P PRE -Position rig to raise derrick. -Remove boosters. -Install mouse hole, cellar heaters and cellar doors. 10:30 - 11:30 1.00 RIGU P PRE Raise derrick and pin same. 11:30 - 14:00 2.50 RIGU P PRE Raise wind walls. 14:00 - 14:30 0.50 RIGU P PRE Skid rig floor forward to full moving position (in preparation to spot rig over well) 14:30 - 17:00 2.50 RIGU P PRE -Lower C-section -Bridle down and hang same. -Remove trolley. 17:00 - 20:30 3.50 RIGU P PRE -PU top drive. -Install roller and hook up service loops. -Move conveyor back into place. Printed: 11/25/2008 11:01:03 AM • BP EXPLORATION Operations Summary Report Page 2 of 6 ~ Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: WORKOVER Start: 10/26/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To I Hours Task Code NPT ' Phase Description of Operations 10/28/2008 17:00 - 20:30 3.50 RIGU P PRE -Set rig malts. 20:30 - 22:00 1.50 RIGU P PRE Position rig over well L-116. 22:00 - 23:00 1.00 RIGU P PRE Skid rig floor to drilling position. 23:00 - 00:00 1.00 RIGU P PRE -Spot rock washer -Cont. working on conveyor. 10/29/2008 00:00 - 01:00 1.00 RIGU P PRE -Cont. spotting and berming rock washer. -Cont. working on conveyor. 01:00 - 02:00 1.00 RIGU P PRE Build barricade around live well close to beaverslide prior to using beaverslide to lay down/ bring uploads. 02:00 - 04:00 2.00 RIGU P PRE -Install IBOP /saver sub on top drive. 04:00 - 08:00 4.00 RIGU P 08:00 - 09:00 I 1.001 WHSUR I P 09:00 - 10:00 1.001 WHSUR P 10:00 - 10:30 0.50 W HSU R i P 10:30 - 11:30 I 1.001 WHSUR I P 11:30 - 12:00 0.50 WHSUR P 12:00 - 14:30 2.50 WHSUR P 14:30 - 18:00 I 3.501 WHSUR I P 18:00 - 23:30 5.501 WHSUR P -Take on 9.8 ppg brine in pits. -Cont. working on beaverslide area. -Install braces on snubbing post. -Install kelly hose. -Demobilize block trolley, rollers and bridle yoke off rig floor. -Mobilize mud manifold, cement line and stand pipe sections to rig floor. PRE -Install link tilt assy. and torque tube. -RU mud manifold, cement line and stand pipe. -Install gas buster stack. DECOMP -RU DSM lubricator on tree. Test chart. -Pull BPV. -RD lubricator. DECOMP -RU lines to tree. -Hang mud bucket. Install top drive X-brace rail. -Hard line crew RU hard line. Install and berm tiger tank. DECOMP -Test hard line w/ 100 psi air and check for leaks. -Steam hard line and fill w/ water. Test to 3500 psi. -Blow down hard line and line it up to get returns f/ tubing. DECOMP Displace out freeze protect (well was freeze protected w/ 20 bbls diesel per handover form): -Pump 10 bbls 9.8 ppg brine down IA, taking returns out tubing to tiger tank. -Blow down lines. Swap lines in tree and line up hard line to take returns f/ IA. -Pump 30 bbls 9.8 ppg brine down tubing, taking returns out IA to tiger tank. -Blow down hard line. DECOMP Allow any diesel remains to migrate f/ 30 min. DECOMP -Circulate well surface-surface w/ 140 bbls of 9.8 ppg brine. 150 gpm ~ 1050 psi. -Confirm well dead. Blow down lines. DECOMP -FMC rep dry rod in TWC. -Test TWC f/ below to 1000 psi x 10 min on chart. -Attempt to test TWC f/above to 4000 psi. TWC would not test after several attem ts. -Troubleshoot tree and concluded that TWC is leaking. DECOMP -Call for DSM lubricator. -Install lubricator on tree and test same to 500 psi x 5 min on Printed: 11/25/2008 11:01:03 AM • • BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: WORKOVER Start: 10/26/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code I NPT Phase Description of Operations 10/29/2008 18:00 - 23:30 5.50 WHSUR P DECOMP .Pull TWC. 23:30 - 00:00 I 0.501 WHSUR I P 10/30/2008 100:00 - 02:00 I 2.001 WHSUR I P 02:00 - 07:00 I 5.001 BOPSUR P 07:00 - 08:30 I 1.501 BOPSUR P 08:30 - 15:30 7.00 BOPSUp P -Close master valve in tree and test f/ below to 1000 si er FMC reo. request. Observe that master valve in tree leaks. -Install new TWC. Test f/ above to 4000 six 10 min on chart and f/ below to 1000 psi x 10 min on chart. All tests good. -RD lubricator. DECOMP ND tree. Barriers in place: 2 - Tested WRP ~ 6520' - Tested TWC in tubing hanger. DECOMP -Cont. ND tree and adapter flange. -Check 3-1/2" NSCT pin x 3-1/2" IF XO on tubing hanger (7.5 turns to make up). Barriers in place: 2 - Tested WRP ~ 6520' - Tested TWC in tubin han er. DECOMP -NU BOP w/ 11" 5M x 13-5/8" 5M adapter spool. -Remove 18" spacer spool f/ choke line. -Install riser and flow line. Tighten turnbuckles. -Install mouse hole 13-5/8" 5M BOP stack configuration: - Annular preventer - 3-1/2" x 6" VBR (too rams) - Blind Rams - Mud cross - 2-7/8" x 5" VBR bottom rams DECOMP -MU XOs to 3-1/2" testjt. Screw into tubing hanger. -Close rams and center stack. -RU testing equipment. DECOMP .Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 4000 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart. Perform all tests w/ 3-1/2" testjt. Test witnessed by WSL and Toolpusher. Chuck Scheve, AOGCC Rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3000 psi 2. Pressure after close: 1700 psi 3. 200 psi attained at 31 sec 4. Full pressure attained at 2 min 42 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1.13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) Printed: t vzsizoott 11:U1:UJ HM • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: WORKOVER Start: 10/26/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Date ~ From - To ~; Hours I, Task Code NPT Phase Description of Operations 10/30/2008 08:30 - 15:30 7.00 BOPSU P DECOMP 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and lower kelly valves (upper and lower top drive IBOP) 15:30 - 16:00 0.50 BOPSU P DECOMP -RD testing equipment. -Blow down choke and kill lines. 16:00 - 18:30 2.50 WHSUR P DECOMP -Install lubricator extension in stack and close top rams. RU DSM lubricator. -Test lubricator and extension to 500 psi x 5 min on chart. 18:30 - 19:00 I 0.501 PULL I P 19:00 - 20:00 1.001 PULL P 20:00 - 21:30 1.501 PULL P 21:30 - 00:00 I 2.501 PULL I P 10/31/2008 100:00 - 05:00 I 5.001 PULL I P 05:00 - 05:30 I 0.501 PULL I P 05:30 - 06:00 0.50 WHSUR P 06:00 - 07:00 1.00 EVAL P 07:00 - 13:30 I 6.50 I EVAL I P 13:30 - 14:30 1.00 EVAL P 14:30 - 15:00 0.50 WHSUR P 15:00 - 18:30 3.50 WHSUR P -RD lubricator and extension. DECOMP -RU to pump down IA, taking returns through tubing. -Spot 35 bbls Safe Lube pill in IA f/ surface to SSSV. 168 gpm ~ 1100 psi. MW in 9.8 ppg / MW out 9.8 ppg RU bales and 4" elevators while pumping tube pill. DECOMP -MU XOs on 1 jt 4" DP and screw into tubing hanger. MU top drive. BOLDS. -Pull tubing hanger and observe same free. Cont. pulling seals off sealbore. Seals free w/ 195k pull (95k over estimated string weight). String weight ~ 105k after seals pull loose. -Pull tubing hanger to rig floor. Weights and pulls indicated include 50k blocks weight. DECOMP -RU to LD 3-1/2" tubing: C/O elevators, install power tongs, install control line spooling unit. -Flow check well x 10 min. OK DECOMP -LD tubing hanger w/ pup jt. FMC Rep. took tubing hanger to redress it and C/O 3-1/2" L-80 IBTx NSCT pup jt to 3-1/2" 13Cr80 Vam Top x NSCT pup jt. -LD 3-1/2" 9.2# L-80 IBT tubin 6432' to 5232'. Recovering 1/4" dual control lines and SS bands. DECOMP Cont. LD 3-1/2" 9.2# L-80 IBT tubing and completion equipment f/ 5232' to surface. -Total jts tubing LD: 203. -Completion equipment: SSSV, 4 GLM assy, X nipple assy. and seal assy. -Recover 1/4" dual control lines and 75 SS bands (1 SS band left in the well). DECOMP -RD tubing handling equipment. -Clear rig floor. DECOMP Install wear bushing DECOMP -Mobilize Schlumberger a-line equipment to rig floor. -RU sheaves and air line wiper (tested WRP ~ 6520' as barrier) -MU and test USIT tool. DECOMP -RIH w/ USIT tool on a-line to 6375'. -Take USIT log in cement evaluation mode f/ 6375' to 400'. -POOH DECOMP RD Schlumberger a-line equipment. DECOMP Pull wear bushing. DECOMP -BOLDS. Pull mandrel packoff through BOP stack (OA lined up to tiger tank through hard line, no pressure). -Install new packoff through BOP stack. RILDS. Printed: 11/25/2008 11:01:03 AM • • BP EXPLORATION Operations Summary Report Page 5 of 6 ~ Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: WORKOVER Start: 10/26/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Task i Code i NPT i Phase Description of Operations Date I From - To I Hours , 10/31/2008 ~ 15:00 - 18:30 ~ 3.50 ~ WHSUR ~ P 18:30 - 20:30 I 2.00 20:30 - 00:00 I 3.50 11 /1 /2008 00:00 - 00:30 0.50 00:30 - 08:00 7.50 08:00 - 09:00 I 1.00 09:00 - 10:00 I 1.00 10:00 - 11:00 I 1.00 11:00 - 12:30 I 1.50 12:30 - 14:30 ~ 2.00 ~ RU DECOMP -Attempt to test packoff. It does not test. -BOLDS. Pull pack off. C/O damaged seal. Install packoff. RILDS. -Test packoff to 3500 psi x 30 min per FMC rep. Test good. RUNCMP RU to run 3-1/2" tubing and completion equipment: C/O bales and elevators; install compensator, power tongs and torque turn equipment. MU XOs to floor valve. RUNCMP -MU seal assy and X nipple assy. -Run 3-1/2" 9.2# 13Cr80 Vam Top tubing and completion e ui ment. Torque turn all connections to 2900 ft-Ib. RUNCMP Lubricate rig. Inspect top drive. RUNCMP Cont. running 3-1/2" 9.2# 13Cr80 Vam Top tubing and completion equipment 6347'. Torque turn all connections to 2900 ft-Ib. RUNCMP -Obtain parameters: PUW 105k /SOW 95k (blocks weight 50k). -Break circulation C~? 2 BPM / 210 psi. -Run and tag top of sealbore ~ 6425'. Stab seals and observe ressure increase. Pressure up to 500 psi, shut pumps down and hold x 5 min. -Cont. slacking off until setting No-Go on top of sealbore (bottom of mule shoe @ 6441'). RUNCMP -LD 4 jts 3-1/2" tubing. -Space out. MU pup jts (2.08', 9.82' and 9.83') on top of tubing jt #195. MU tubing jt #196. -RU to reverse circulate. RUNCMP Reverse circulate 20 bbls hi-vis sweep + 111 bbls 9.8 ppg brine w/ corrosion inhibitor + 10 bbls hi-vis sweep. Chase at the end w/ 10 bbls 9.8 ppg brine. -3 BPM / 380 psi. RUNCMP -MU tubing hanger, XOs and 1 jt 4" DP. -Land tubing hanger. RILDS. -Total jts 3-1/2" tubing run: 196 -13.5' swallow in on a 16.5' PBR. Bottom of mule shoe ~ 6438.5' RUNCMP -RU testing equipment. -Test tubing and seals to 3500 psi x 30 min on chart. Pressurg drop) and stabilized. MIT- to same. -Bleed off pressure in tubing and observe DCK-3 valve shear (valve in GLM ~ 4252'). Pump down IA, out tubing, ~ 3 BPM / 2550 psi. Pump down tubing, out IA, @ 3 BPM 2100 psi. 14:30 - 15:30 1.00 WHSUR P RUNCMP -RD landing jt. -FMC Re . d rod TWC. -Test TWC f/ bottom to 1000 psi x 10 min on chart. 15:30 - 17:00 1.50 BOPSU P RUNCMP -ND BOP. Barriers in place: -Tested WRP ~ 6520' (below sealbore). Seals in sealbore tested. Printed: 11/25/2008 11:01:03 AM • BP EXPLORATION Operations Summary Report Legal Well Name: L-116 Page6of6~ Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: WORKOVER Start: 10/26/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES Date ~ From - To I Hours ~I Task Code NPT Phase Description of Operations 11/1/2008 15:30 - 17:00 1.50 BOPSU P RUNCMP -Tubing hanger landed and tested (w/ IA test). Tested TWC in tubing hanger. 17:00 - 18:30 1.50 WHSUR P RUNCMP NU adapter flange and tree. 18:30 - 20:00 1.50 WHSUR P RUNCMP -Test adapter flange to 5000 psi x 30 min per FMC Rep. -Fill tree w/ diesel and test to 5000 psi x 10 min on chart. 20:00 - 20:30 0.50 WHSUR P RUNCMP -RU DSM lubricator and test same to 500 psi x 5 min on chart. -Pull TWC. 20:30 - 22:00 1.501 WHSUR ~ P 22:00 - 23:00 1.001 WHSUR i P 23:00 - 00:00 1.00 ~ W HSUR ~ P 11/2/2008 100:00 - 02:00 2.001 WHSUR RUNCMP -RU Little Red to IA to freeze protect. -Test lines to 4000 psi. -Pre-heat diesel to 60 F. RUNCMP -Pump diesel down IA, circulating through sheared DCK-3 valve C~ 4252', and taking returns out tubing to tiger tank. -Pump first 50 bbls ~ 2 BPM / 1100-1600 psi (diesel entering tubing C~ 50 bbls pumped away). -Increase pump rate and finish pumping diesel C~ 3 BPM / 2350 psi. Monitor returns on surface. Stop pumping when observing clean diesel returns. -Total diesel pumped f/ freeze protect: 87 bbls (tubing and IA freeze protected to 4252'). RUNCMP -RU DSM lubricator and test same to 500 psi x 5 min on chart -RD lubricator. -Test BPV (using diesel w/ Little Red) to 1000 psi x 10 min on chart. RUNCMP -Bleed pressure. RD Little Red. -Remove secondary valve in IA. -Remove pump in flanges. Install blanks. -Install gauges. Secure tree and cellar. -Release rip (~ 02:00 OA=O psi / IA=O psi / TBG=O psi Printed: 11/25/2008 11:01:03 AM • L-116, Well History (Post Rig Workover) Date Summary 11/8/2008 T/I/0= 0/0/0. Pulled 3-1/8" CIW "H" BPV #324 thru tree Post Rig. 1-2" ext. used, tagged C~ 84". Complete. 11/23/2008 WELL S/I ON ARRIVAL. SET 3 1/2" X-LOCK C-SUB @ 6395' SLM. PULL STA #3 INT-DGLV FROM 4997' SLM. 11/24/2008 PULL INT-DCK3 FROM STA #4 C~ 4245' SLM. PULL INT-DGLV FROM STA #5 C~2 3522' SLM. SET INT- LGLV (16/64", 1500#) IN STA #5 C~3 3522' SLM. SET INT-DGLV IN STA #4 C~3 4245' SLM. SET INY- OGLV (20/64") IN STA #3 C~ 4997' SLM. PULL EMPTY X-LOCK C-SUB FROM 6395' SLM. PULLED 10' x 3 1/2" JUNK CATCHER FROM 6482' SLM. MADE 5 RUNS FROM 6498' SLM TO 6503' SLM W/ 10' x 2.25" P.BAILER, FLAPPER (RECOVERED -4 GAL SLUGGITS, RUBBER DEBRIS). LEFT WFD WRP PULLING TOOL ON WRP, CURRENTLY IN HOLE ATTEMPTING TO RE-LATCH WFD TOOL. 11/25/2008 MADE UNSUCCESSFUL ATTEMPT TO RETRIEVE WFD WRP PULLING TOOL (frac sand in GR). RAN 10' X 2.25" PUMP BAILER (flat flapper bottom), RECOVERED -1 TBSP FRAC SAND/FILL *METAL MARKS*. MADE THREE RUNS W/ 10' x 2.25" P.BAILER, SNORKEL BTM, TO WRP C~ 6503' SLM -3/4 GAL FRAC SAND RECOVERED. MADE TWO RUNS W/ 9' x 2.65" HYDROSTATIC BAILER TO WRP C«3 6503' SLM, -1/2 GALLON FRAC SAND RECOVERED. MADE TWO MORE RUNS W/ 10' X 2.25" P- BAILER, SNORKEL, RECOVERED -1 1/2 GALLON FRAC SAND /FORMATION SAND / SLUGGIT MIX. 11/26/2008 MADE 3 RUNS W/ 10'x 2.25" P.BAILER, SNORKEL BTM, TO 6503' SLM -1 gal of fill recovered. RECOVERED 3 1/2" WFD WRP PULLING TOOL Q 6503' SLM. BAILED -- 7 GAL OF SLUGGITS. 11/27/2008 BAILED 3 GAL SLUGGITS FROM TOP OF WRP. ATTEMPTED TO LATCH WRP (UNSUCCESSFUL). RAN HYDROSTATIC BAILER (RECOVERED ONLY FLUID). ATTEMPTED TO EOL WRP W/WRP PULLING TOOL W/ NO COLLETS (INCONCLUSIVE). RAN 2-1/2 BAILER W/WRP EOL SLV TO 6522' SLM (SAW TBG PRESS CHANGE, IA TRACKING). 11/28/2008 EQUALIZED WRP W/ 3 1/2 WRP EO BAILER BTM. RAN 2.70" LIB TO WRP(6528' SLM). GOOD IMPRESSION. RAN 3 1/2 WFD WRP PULLING TOOL(UNABLE TO LATCH). PLANTED 3 1/2 BAIT SUB, 3" CORELESS JD Q 6528' SLM. ATTEMPTED TO PULL WRP 3 TIMES (1 HR EA) W/ 3" CORELESS JD (.108 WIRE). ATTEMPTED TO PULL WRP 3 TIMES (1 HR EA) W/ 3" CORELESS JD (.125 WIRE). 11/29/2008 ATTEMPTED ONCE TO PULL WRP (.125 WIRE, 13' x 2.125" STEM). PULLED SAFETY SUB AND F.N. FROM WRP C~? 6528' SLM. RAN 2.80" LIB TO WRP (6526' SLM). GOOD IMPRESSION. RAN 5' x 2.50" P. BAILER TO 6525' SLM (NO RETURNS). SET 3-1/2" BAIT SUB & 2.55" OVERSHOT C~ 6524' SLM ON WRP. ATTEMPTED TO PULL 3 1/2 WRP (2 HRs). PULLED 3 1/2 BAIT SUB & OVERSHOT OFF WRP, BROKE OVERSHOT. 11/30/2008 PLANTED 3-1/2" BAIT SUB & 2.72" OVERSHOT @ 6524' SLM. JAR ON WRP C~3 6524' SLM FOR -6 HOURS W/ NO MOVEMENT. LEFT WELL S/I, NOTIFY PAD-OP. NOTE: WRP W/ 3 1/2 BAIT SUB & OVERSHOT IN HOLE ~ 6520' SLM. Page 1 of 1 WELLHEAD = 11" FMC CTUATOR =' B. E~.EV = 76.7' F. ELEV = 52.5' OP= 1218' ax Angle = 25 @ 2431' atum MD = 6884' atum TVD = 6600' SS DRLG DRAFT 17-518" CSG, 29.7#, L-80 BTGM, ID = 6.875" I Minimum ID = 2.813 " @ 2202' 3-1 /2" HES X NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2754 2664 24 KBG-2 DMY BK 0 11/02/08 5 3535 3401 17 KBG-2 DMY BK 0 11/02/08 4 4253 4089 17 KBG-2 DMY BK 0 11102/08 3 5002 4814 13 KBG-2 DCK BEK 0 11/02/08 2 5720 5518 8 KBG-2 DMY BK 0 11/02/08 1 6310 6104 5 KBG-2 DMY BK 0 11/02108 6399 1-'13-112" NES X-NIP, 1D = 2.813" 3-1/2" TBG, 9.2#, 13Cr80, Vam Top„ ID = 2.992" ~-{ 6420 L-116 I bAftIYNUIt,: 1014' 7-518" TAM PORT COLLAR 2202 3-1/2" HES X-NIPPLE, ID = 2.813" 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 6421 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 4 @ 6675' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 6675 - 6720 C 09/14/01 2-1/2" 6 6734 - 6740 C 09/14/01 PBTD -112" CSG, 9.2#, L-80 NSCT, .0087 bpf, ID = 2.992" I 7172' I 6421' -i BKR SEAL ASSY w MULESHO~ ID = 3.00" 6433' 5-1 /2" X 3-1 /2" XO, ID = 2.968" 64$2' 2.69" JUNK CATCHER (10/12/08) 6510 SLUGGITS (10/12/08) 6520 3-1/2" WRP (2.69" O.D.)- 10!11/08 6662' 3-1/2" PUPJT W / RA TAG 1' ~~ 3-1 /2" PUP JT W / RA TA G DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNff 07/16/01 CHIKAK ORIGINAL COMPLETION WELL L-116 11102/08 D14 RWO PERMIT No: 2011160 API No: 50-029-23025 SEC 34, T12N, R11 E, 2372' NSL & 3743' WEL BP Exploration (Alaska/ STATE OF ALASKA >o ~~~ ALA~OIL AND GAS CONSERVATION COM N® ZOOS REPORT OF SUNDRY WELL QPERATION~ 1. Operations Abandon ~ Repair Well ~, Plug Perforations ~ $ OnS. ~~a~BING PATCH Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver[~f1C~lr~ictension ~ FAILED , Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 6340'-6353' 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~~ Exploratory r 2o1-11so- 3. Address: P.O. Box 196612 Stratigraphic r Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23025-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 76.7 KB - L-116 _ 8. Property Designation: 10. Field/Pool(s): ADLO-028239 - PRUDHOE BAY Field/ BOREALIS OIL Pool 11. Present Well Condition Summary: Total Depth measured 7190 ~ feet Plugs (measured) None true vertical 6982.72 feet Junk (measured) None Effective Depth measured 7029 feet true vertical 6821.88 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 Surface - 109' Surface - 109' 1490 470 Surface 2653' 7-5/8" 29.7# L-80 Surface - 2653' Surface - 2752' 6890 4790 Production 6421' 5-1/2" 15.5# L-80 Surface - 6421' Surface - 6215' 7000 4990 Production 751' 3-1/2" 9.2# L-80 6421' - 71 6215' - 6965' 10160 10530 7 2 ' y~ {{~~Op g ~ ~- A ~1 `+ Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 SURFACE - 6419' 0 0 - Packers and SSSV (type and measured depth) 3-1/2" LOWER WFD ER PKR 6353' 3-1/2" UPPER WFD ER PKR 6340' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after Droposed work: Copies of Logs and Surveys Run Exploratory ~ Development ly ~ Service (- Daily Report of Well Operations X 16. Well Status after proposed work: Oil - r Gas r WAG r GINJ ~ WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/8/2008 Form 10-404 R ised 04/2006 ,, , „v, , ~ ! ~. ,, . t-.-, Submit Original Only ~`` L-116 201-1160 PERF ~TT~(:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L-116 9/14/01 PER 6,675. 6,720. 6,468.32 6,513.24 L-116 9/14/01 PER 6,734. 6,740. 6,527.22 6,533.21 L-116 10/14/01 FIL 6,873. 7,025. 6,666.04 6,817.88 L-116 10/15/01 FCO 6,873. 7,025. 6,666.04 6,817.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 v • • L-116 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY acTtvr-~~r~A~>~ ~ su _ .t. 8/16/2008 """WELL SHUT IN ON ARRIVAL. INTITIAL T/I/O: 1600/1750/150""" E RIG UP E-LINE FOR BOTTOM HOLE STATIC PRESSURE LOG. UNABLE TO DEEPER THAN 6736'. j STATIC PRESSURES TAKEN AT 6729', 6683', 6583' AND SURFACE. """JOB IN PROGRESS, CONTINUES ON 17-AUG-2008"*' 8/16/2008 *''""WELL SHUT IN ON ARRIVAL. INTITIAL T/I/O: 1600/1750/150***" RIG UP E-LINE FOR BOTTOM HOLE STATIC PRESSURE LOG. UNABLE TO ,GET PAST 6736'. €€ STATIC PRESSURES TAKEN AT 6729', 6683', 6583' AND SURFACE. ' """`*LOG CONTINUED ON 17-AUG-2008'""'* 8/17/2008 ~*`LOG CONTINUED FROM 16-AUG-2088"** SET WEATHERFORD 3.5" ER PACKER @ 6353'. (5600# TO RELEASE) FINAL T/I/O = 1600/1750/200. ;SWAB=C, WING=C, MASTER=O, SSV=C, VALVES OPEN TO GAUGES. ;WELL LEFT SHUT-IN. DSO NOTIFIED ""*JOB COMPLETE""" 7/2008=*""*LOG CONTINUED FROM 16-AUG-2088*"""` 'SET WEATHERFORD 3.5" ER PACKER C~ 6353'. (5600# TO RELEASE) FINAL T/I/O = 1600/1750/200. SWAB=C, WING=C, MASTER=O, SSV=C, VALVES OPEN TO GAUGES. ~""'*''WELL LEFT SHUT-IN. DSO NOTIFIED."""` 3/2008T/I/O = 1400/1560/250. Temp = SI. Tbg & IA FLs (SL). AL C~ 1620 psi & SI :casing valve. Tbg FL C surface. IA FL @ surface. WH Valve positions turned over to SL unit on well. NOVP. 9/13/2008 """ WELL S/I ON ARRIVAL """ SET 3-1/2" WFD ER UPPER PKR AND PATCH AT 6340' SLM. (16' OAL / 1.75" ~irn ATTEMPT MIT-IA TO 2500 PSI THREE TIMES. ALL THREE ATTEMPTS FAILED. ''"' WEL LEFT S/I ON DEPARTURE "*" 11 /04!08 t1~i111~~1l~r~~i~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth W[±It .Inh !k 1 nn rlncnriwi.... - n... N0.4952 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeri 333 West 7th Ave, Suite 100 Anchorage, AK 99501 D-29 12103692 USIT ( 10/19/08 1 1 13-16 12103694 INJECTION PROFILE (REVISED) / 10/20!08 1 1 13-19 12103695 INJECTION PROFILE ~I 10/21/08 1 1 03-04 12031526 INJECTION PROFILE 10/22/08 1 1 J-08A 12031514 CBL Off- ~ I 09!20/08 1 1 06-17 11970850 PRODUCTION LOG ~ 1(p (o 10/30/08 1 1 01-33 11999052 RST - ~j 10/10/08 1 1 1-45/0-26 12096920 ~ LDL "~-• 10/10/08 1 1 3-05/0-29 12083416 MEM LDL ~ 10/24/08 1 1 L-116 11999055 USIT O .. f ~ I a 10/31/08 1 1 . __.. .. .........~ ..~.. ~.. ... .,......,....-...... ,.~. v~umw v~.~ vvr ~ owa.n ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ? f 1 ;~; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99 03-283 ATTN: Beth Received by: ----~ • • 08/25/08 ~~ ~~ S ,... _~ O r~ri SAS>a ~t`~ Sc~~umb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth Well .Inh S N0.4826 Company: State of Alaska Alaska Oil & Gas Cons Comm ~~~~~ S ~ ~ ~ t~ ~t1~4 Attn: Christine Mahnken V U U 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Inn flearrinfinn flsfn RI !`nlnr !`h A-02 12086677 RST ~ - ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 1 A-13 12086676 RST ~() 07/23/08 1 1 G-02A 11968945 RST S- ~ 06/08/08 1 1 B-19A 12017500 RST - ~ ~ 06/14/08 1 1 15-18A 12005216 MCNL (~-~ (~ '- 06/24/08 1 1 C-02 11982437 RST L / ~ 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - G ~ 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT ~ 07/23/08 1 1 V-207 11999031 MDT QUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) - ~ 0 07/28/08 1 1 B-18 11978471 USIT _ ~ / (Q ~ ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 07/21/08 1 1 13-29L1 11962614 LDL Q a -Q ~ 07/30/08 1 1 13-29L1 11966271 USIT - (o(~ f (p 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 ~- w -at rLnNx Al.nrvVVVLCUl1C rICl.CIf' 1 CT JWnI1n1U AIVU Fit l UFi1VI1Vli UIYt GUI'T tAGM I V: BP Exploration (Alaska) Ina E a ~~^ Petrotechnical Data Center LR2-1 '. ~ '~ ~~ ,; 900 E. Benson Blvd. -° ~' `-" Anchorage, Alaska 99508 1, y )r( ~~ Date Delivered: ~"~°~~~ {J ~ L~~u(3 ~~°~„~ll i~~'41G)~ . '.t' 1w, Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: • a`~~ 01 /18/08 ~chlumb~rer Alaska Data & Consulting Services r 2UU~t ~'{~"~ ~~~ LU NO. 4560 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Well .Inh $ Lnn Deerrintinn ~ Da}e RI Cnlnr CD L-219 11966240 MDT ~-- IC 12/22/07 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL ti " ~ 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE ~ ~- a(~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ t, 01102/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~} - 01/04/08 1 15-046 12005202 MEM CEMENT BOND LOG - 12/28/07 1 G-31A 11962778 SCMT j - L 01101108 1 S-26 11978425 USIT 12129/07 1 02-16C 11628793 MCNL '~- ~ 08/28/07 1 1 G-046 11628765 MCNL - ~ ~ 04/06/07 1 1 K-02D 11209613 MCNL ~ ~ L 07/21/06 1 1 17-07B 11649940 MCNL - ~ / ~ 02/17/07 1 1 L2-28 11975742 RST - 12/05107 1 1 Z-06 11968821 RST ~ 12173107 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EAGN TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ,~ ';~' ~tm„ 900 E. Benson Blvd. - ~'~ ~ `'~"" Anchorage, Alaska 99508 1 ~ [ r ~rt(1$1 Date Delivered: ~~,~x ~ ~. r_. ~~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: c: • ~~ L-116 (PTD #2011160) UNDER EV~UATION -Sustained Casing Pressure~IA Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, September 26, 2007 9:34 AM ~1~c (~~' ~~~7 To: 'NSU, ADW Well Integrity Engineer' Subject: RE: L-116 (PTD #2011160) UNDER EVALUATION -Sustained Casing Pressure on IA Please check the specs on the 5.5" casing. Everything in well file and schematic you sent shows the pipe as L80, 15.5ppf. I was not able to locate the MIY rating for that (I did find 17ppf L80 and 15.5ppf J/K55). Thank you. Jim Regg ,_1•`~ = 2lOt~~; ~ ~~ = ~Ga~~ip:~` AOGCC ~ ~ ti1~.1#' 333 W.7th Avenue, Suite 100 `" ~` ~Q~ ~ `~ ~~~~ C}t~.1~ C~~'t2 Anchorage, AK 99501 ° phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegri ngineer@BP.com] Sent: Friday, September 14, 2007 9:12 AM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Oakley, Ray (PRA); Robertson, Daniel B (Alaska) Cc: Roschinger, Torin T.; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: L-116 (PTD #2011160) UNDER EVALUATION -Sustained Casing Pressure on IA Paul, Well L-116 (PTD #2011160) has been found to have sustained casing pressure on the IA. The wellhead pressures were 260/2100/280 psi on 09/09/07. A subsequent TIFL failed later on 09/14/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: D: TIFL -FAILED 2. S: Change out S/O & LGLVs 3. D: Re-TIFL A wellbore schematic has been included for reference. «L-116.ZIP» Please call with any questions or concerns. Thank you, Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 9/26/2007 • TREE= 3-1/8"5MCNV WELLHEAD = 11"FMC ACTUATOR = KB. ELEV = 76.7' BF. ELEV = 52.5' KOP= 1218' Max Angle = 25 @ 2431' Datum MD= 6884' Datum TVD = 6600' SS PERFORAl10N SUMMARY REF LOG: ANGLE AT TOP PERT: 4 @ 6675' Note: Refer to Production DB for historical rtdata SIZE SPF INTERVAL O Sqz DATE 2-1/7' 6 6675 - 6720 O 09/14/01 2-1/7' 6 6734 - 6740 O 09/14/01 ST MD TVD DEV TYPE VLV LATCH PORT ROTE 4 3640 3425 17 KBG-2 DOME INT 16 01/29/02 3 5491 5215 12 KBG-2 DOME INT 16 04!17/03 2 6224 5941 5 KBG-2 DMY INT 0 07/16/01 1 6342 6059 5 KBG-2 SO INT 24 04/17!03 6422' TOPOF BKR PBR, ID= 4.00" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/16/01 CH/KAK ORIGNALCOMPLETiON 09/14/01 CWSIKK Pff2FS 11/17/01 GC/KAK PfftFCORRECTgN 12/30/02 R4GKK GLV CORRECTIONS 04!08/03 DRSlTP TVDlM3 ~RRECTIONS 04/17/03 JCM/TLH GLV UP44TE BOREALIS UNIT' WB.L: L-116 PERMIT No: 2011160 API No: 50-029-23025 SEC 34, T12N, R11 E, 2372' NSL & 3743' WEL BP 6rpbration (Alaska) SAFETY NOTES: L-116 e e '" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker.doc o o --lCD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~0 0 ~ ~0 ~ ~0 ~'~ 0 0 0 ~0 t~q 0 0 0 O~ 0 Z Z Z Z Z Z Z Z Z Z Z Z Z ~ z z o ~ "' 9 i'~ STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COM ~l,5SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 12127/01, Put on Line 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-116 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23025-00 ".".'- . ......... 9. Unit or Lease Name 4. Location of well at surface ".:'..'.. ~ ..... ".i'.~ . 2371 NSL, 3742' WEL, SEC. 34, T12N, R11E, UM :. ~i.:7-!:- i.O,.::.^'~';,O;'~.~: Prudhoe Bay Unit At top of productive interval 3538' NSL, 4547' WEL, SEC. 34, T12N, R11E, UM ' . ' · At total depth :'.:~i i [~~ 10. Well Number L-116 3541' NSL, 4572' WEL, SEC. 34, T12N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and ~" 11. Field and Pool Prudhoe Bay Field / Borealis Pool KBE = 76.70' ADL 028239 (Undefined) 7-2-2001 7-10-2001 9-14-2001 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 7190 6983 ETI 7029 6822 ETI []Yes [] NoI (Nipple) 2208' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES / AlT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 109' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 27' 2653' 9-7/8" 443 sx AS Lite, 175 sx Class 'G' 5-1/2,, x 3-1/2,, 15.5# x 9.2# L-S0 24' 7173' 6'3/4" 217 SX LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.3#, L-80 6432' N/A MD TVD MD TVD 6675' - 6720' 6468'- 6513' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 6734' - 6740' 6527' - 6533' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6675' - 6740' Fractured with 16 / 20 Carbolite Placed 156,230 #'s proppant behind pipe. 27. PRODUCTION TEST ,, Date First Production MethOd of Operation (Flowing, gas lift, etc.) November 9, 2001 Gas Lift ~ate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE I GAs-OIL RATIo 11/23/2001 4 TEST PERIOD 5343 2681 0 176I 502 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) :Press. 24-Hour RATE 28. CORE DATA Brief description oflithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corechips. RECEIVED 2 8 ~,. Naska 0il & Gas Cons. C0mmissio~ Anchorage Form 10-407 Rev. 07-01-80 ORIGINAb,,,S,rL Submit In Duplicate 2 3 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Schrader Bluff 4089' 3932' Schrader Bluff N 4362' 4194' Schrader Bluff O 4469' 4297' Base Schrader Bluff / Top 4852' 4668' Colville Mudstone CMl 5849' 5645' TKLB 6504' 6298' Top Kuparuk C 6675' 6468' LCU / Top Kuparuk B 6833' 6626' Top Kuparuk A 6939' 6732' Base Kuparuk / Top Miluveach 7029' 6822' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and Leak Off Integrity Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble,~j~_ ~'/'/ ' Title TechnicalAssistant Date L-116 201-116 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM '1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _X Add Perfs / Frac Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~]e, AK 99519-6612 5. Type of Well: Development _X Exploratow__ Stratigraphic__ Service__ 4. Location of well at surface 2909' FNL, 3742' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 2909' FNL, 4547' FEL, Sec. 34, T12N, R11 E, UM At effective depth 1738' FNL, 714' FWL, Sec. 34, T12N, R11E, UM At total depth 1738' FNL, 4570' FEL, Sec. 34, T12N, RllE, UM (asp's 583174, 5978092) (asp's 582354, 5979250) (asp's 582336, 5979253) (asp's 582331, 5979253) 12. Present well condition summary Total depth: measured true vertical 7190 feet Plugs (measured) 6983 feet 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-116 9. Permit number / approval number 201-116 10. APl number 50-029-23025 11. Field / Pool Prudhoe Bay Field / Kuparuk River Oil Pool Effective depth: measured true vertical 7029 feet Junk (measured) 6822 feet Casing Length Conductor 109' Surface 2626' Production 7149' Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arctic Set (Approx 136' 136' 7-5/8" 443 sx AS Lite, 175 sx 2653' 2572' Class 'G' 5-1/2" x 3-1/2" 217 sx LiteCrete 7173' 6966' Perforation depth: measured Open Perfs 6675' - 6720', 6734'- 6740' true vertical Open Perfs 6468' - 6513', 6527' - 6533' Tubing (size, grade, and measured depth) RECEIVED DEC 1 2001 Alaska 0il & Gas Cons. Commission 3-1/2" 9.2#, L-80 TBG @ 6422'. 3-1/2" 9.2# Tubing Tail to 6432'. Anchorage Packers & SSSV (type & measured depth) 5-1/2" x 3-1/2" Baker Packer @ 6422'. 3-1/2" HES XDB BV Nipple @ 2208'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-in Well Shut-in Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I_hereby certify that the foregoing is true and correct to the best of my knowledge. .,~'"~,~.~~~ Title: Technical Assistant DeWayne R. Schnorr ~' Form 10-404 Rev 06/15/88 · ORIGINAL Date October 29.2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 09/14/2001 09/16/2001 09/21/2001 09/22/2001 09/22/2001 09/25/2001 09/25/2001 09/26/2001 09/26/2001 10/02/2001 10/03/2001 10/15/2001 09/14/2001 09/16/2001 09/21/2001 09/22/2001 09/22/2001 L-116 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: PERFORATION STATIC SURVEY (POST PERF) SET MEM GAGUES & FRAC SLEEVE (PRE-FRAC) SET FRAC SLEEVE (PRE FRAC) FRAC TREATMENT KUP "C" SAND FISH TREE SAVER CUP (POST FRAC) POST FRAC FCO POST FRAC FCO PULL FRAC SLEEVE(POST FRAC) DRIFT, FISH GAUGES, F/TD, RUN GLV'S SET GLV & PULL CATCHER FCO / PULL PRESSURE GAUGES EVENT SUMMARY COMPLETED JEWELRY LOG AND IPERF. SHOT TWO INTERVALS (6675' - 6720') & ( 6734'- 6740') THREE GUN RUNS WITH 2-1/2" POWERFLOW HMX, 6 SPF, 60 DEGREE PHASED. FLUID LEVEL @ SURFACE AFTER ALL SHOTS. WH TEMP 43 DEGREES. STATIC SURVEY W/TANDEM PETRADAT GAUGES. ALL DEPTHS -24 SLM TO CORR. TO MD. TAGGED TD @ 7024' SLM. 40 MIN STOP @ 6700' SS (6984' MD), 20 & 30 MIN STOPS @ 6600' SS (6884' MD), & 20 MIN STOP @ 6500' SS (6784' MD). AVERAGE PRESS & TEMP @ 6600' SS - 3470 PSI & 158 DEG F. WELL SHUT IN. SET MEMORY GAUGES @ TD (7002' SLM). NOTE: GAUGES ARE IN A 5'X 2.5" DRIVE DOWN BAILER BODY BAITED WITH A 1 3/4" ROPE SOCKET W/A 1 3/4" FISHING NECK. SET FRAC ISOLATION SLEEVE IN SSSV NIPPLE @ 2190' SLM, GOOD TEST ON BAL AND CONTROL LINES. LEFT 4500 PSI ON BOTH LINES. WELL SHUT IN. PUMP 50 BBL YF130LG DATA FRAC. PUMPED @ 5 BPM TILL PAD ON PERFS WHP-2495 PSI, THEN INCREASED TO 25 BPM WHP=5100 PSI. ISIP=2003 PSI FG=.74, WATCHED FALL OFF EST CLOSURE @ 7.4 MIN. 66% FLUID EFF., NET PSI= 423 PSI. CLOSURE PSI= 1567. REDESIGNED FRAC TO 50 BBL PAD, A 1 TO 6 PPA SAND RAMP STAGE, AND A 6 TO 10 PPA STEP SAND STAGE. STARTED 10 PPA 40 BBLS EARLY IN 9 PPA STAGE FROM DESIGN. SCREEN OUT (N2 POP OFF WENT @ 8100 PSI) 109 BBLS INTO 10 PPA STAGE. PLACED 156,230# 16/20 C-LITE INTO FM. LAST 50 BBLS INTO FM WAS 10# PROP (14,577#). WELL FILLED TO SURFACE WITH 10 PPA PROP. EST VOL - 19,000 # IN W/B. PULLED TREESAVER AND Page I L-116 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/22/2001 BOTTOM CUP MISSING. CIRCULATED SAND FROM WELLHEAD W/2 BBL (Continued) DIESEL. 09/25/2001 FISH TREE SAVER CUP FROM TREE. SET DOWN WITH SAMPLE BAILER ON FRAC SAND IN TREE. ( PRE CTD FILL C/O ). 09/25/2001 MIRU CTU #3, MU BHA - STINGER 2" JS NOZZLE. JET FROM SURFACE. FIRST TAG @ 150'. TAKE 35' BITES AND CHASE UP W/XS 2%KCL. JET TO SSSV INSERT @ 2204'. PUMP BIO SWEEP. CHASE TO SURFACE. SWAP TO METH/WTR TO FP COIL/LINES. 09/26/2001 CHASE TO SURFACE. FP COIL. STANDBY FOR SLICKLINE RETRIEVAL OF INSERT. RIG DOWN SL. RIG COIL INJECTOR BACK ON WELL. RIH. CONTINUE FCO/JETTING. CLEAN OUT DOWN TO 7029' CTMD W/175 BBL 2# BIO & 870 BBLS XS KCL (TOTALS FOR BOTH DAYS). EST -100 BBL RETURNS IN ADDITION TO VOL PUMPED. WELL DID NOT SHOW STRONG INDICATION OF COMING BACK. LAID IN DIESEL 1:1 FROM TD TO SURFACE TO LIGHTEN COLUMN & FP. ***LEFT WELL SI & FP. READY FOR SLICKLINE*** 09/26/2001 STANDBY FOR CTU TO FCO AND JET ICE PLUG. R/U. PULL FRAC SLEEVE @ 2199' SLM. PURGE BALANCE & CONTROL LINES. PURGE GOOD. RDMO. 10/02/2001 DRIFT AND TAG W/2.70" CENT. AND SAMPLE BAILER TO 6883' WLM -- SET 3 1/2 X-KEYED CATCHER SUB IN X-NIPPLE @ 6353' WLM -- PULL DGLV'S FROM STA.# 4 & 3 -- SET LGLV IN GLM # 4 @ 3640' MD. -- ATTEMPT TO SET OGLV IN GLM # 3 @ 5491' MD. UNABLE TO SET. 10/03/2001 SET NEW BOTTOM LATCH, 16/64", TRO 1750, GLV. IN GLM # 4 @ 5491' MD. GOOD SET -- PULL CATCHER FROM X- NIPPLE @ 6353' WLMD. -- RUN PUMP BAILER TO GET SAMPLE FROM FILL @ 6868' POOH W/SAMPLE OF FRAC SAND. -- RETURN WELL TO OPERATOR. 10/15/2001 MIRU DS CTU#8, RIH W/2.25" JSN. START JETTING SAND @ 6873' CTD, CO TO GAUGES AT 7025' CTD, POOH. MU 1.75" HYD JDC. RIH. PUMP MIN RATE DOWN CT. TAG FISH @ 7031'. POH. FISH/GAGES SUCCESSFULLY RETRIEVED. FREEZE PROTECT WELL TO 3000' W/60/40 METH. LEAVE WELL SI. Page 2 L-116 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (2 TESTS) 90 DIESEL 35 METHANOL WATER 126 60/40 METHANOL WATER 981 2% KCL WATER 869 2% KCL WITH EXTRA SLICK WATER 175 2% KCL WATER WITH 2# BIO 2O 1.5 # BIO 2298 TOTAL 09/14/2001 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-1/2" POWERFLOW CHARGE, 6 SPF, 60 DEGREE PHASING, RANDOM PHASING. 6675'-6720' 6734'-6740' Page 3 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well ~[ Oil [] Gas [] Suspended [] Abandoned [] Service _ TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-116 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23025-00 ... ;4. Location of well at surface .... -- ![-OC~ON,~ 9. Unit or Lease Name 2371'At topNSL'of productive3742' WEL,intervaiSEC. 34, T12N, R11 E, UU '--, - ~.~.~"~/ .~IYJll~l'J~ I Prudhoe Bay Unit 3538' NSL, 4547' WEL, SEC. 34, T12N, R11E, UM . ~' ~' At total depth - .:.~:.'.;'i"~ ~.i' 10. Well Number 3541' NSL, 4572' WEL, SEC. 34, T12N, R11 E, U M ..... /J'.~ ....... L-116 , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Borealis Pool KBE - 76.70' ADL 028239 (Undefined) 12. Date Spudded 7-2-2001 113' Date I'D' Reached I14' Date C°mp'' Susp'' °r Aband'7-10-2001 9-14-2001 I15' Water depth' if °ffsh°re N/A MSL 116' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 7190 6983 FTI 7029 6822 FTI [] Yes [] NoI (Nipple) 2208' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES / AlT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 109' 30" 260 sx Arctic set (Approx.) 7-5/8" 29.7# L-80 27' 2653' 9-7/8" 443 sx AS Liter 175 sx Class 'G' 5-1/2,,x3-1/2,,15.5#x9.2# L-80 24' 7173' 6-3/4" 217 sx LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH S,,ET' (MD) PACKER SET (MD)" 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.3#, L-80 6432' N/A MD TVD MD TVD 6675' - 6720' 6468' - 6513' 6734' - 6740' 6527' - 6533' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6675' - 6740' Fractured with 16 / 20 Carbolite Placed 156,230 #'s proppant behind pipe. 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Row Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HouR RATE ,,,., 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or w~i~,E~EJ~L) 0CT'0 5 2001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Schrader Bluff 4089' 3932' Schrader Bluff N 4362' 4194' Schrader Bluff O 4469' 4297' Base Schrader Bluff / Top 4852' 4668' Colville Mudstone CMl 5849' 5645' TKLB 6504' 6298' Top Kuparuk C 6675' RECEIVED LCU / Top Kuparuk B 6833' 6626' Top KuparukA 6939' 6732' 00T 0 5 .Alaska Oil & Gas Cons. Base Kuparuk / Top Miluveach 7029' 6822' gnchorage 3i. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and Leak off Integrity Tesi Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ..~,/~j~ ~ Title Technical Assistant Date 1~)'' · L-116 201-116 Prepared By Name/Nurnber'. Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. , .......... INSTRUCTIONS GENEEAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL c~ uJ L~ n : ...... 2}"' :'~ ~. s :' . .~ . . ...... . ........ . · ... :.'. ': ~. ..~. . .... . . .. . ~':' . ~ ~ ~ .. .... ... ~ W .g ~ ~ '~._ ... .. .. · . ~ · .'.. ~ · 0 .. .... ~ ~ ,,, . . :. z E ... .... BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: DRILL+COMPLETE Start: 7/1/2001 End: 7/16/2001 Contractor Name: NABORS Rig Release: 7/16/2001 Rig Name: NABORS 9ES Rig Number: Date From - To HoUrs Activity Code NPT Phase Description of Operations 7/1/2001 16:00 - 21:00 5.00 MOB PRE Commence rig dn, move in on L-116. Spot pits, connect same Spot camp and shop, re-connect same. Connect riser. Assemnble drip pan. 21:00 - 00:00 3.00 RIGU PRE Accept rig @ 2100 hrs. Mix spud mud during RU. 7/2/2001 00:00 - 02:00 2.00 RIGU PRE Resume rig up on L-116, while mix spud mud. 02:00 - 03:30 1.50 DRILL SURF Service top dry, cut / slip drlg line. 03:30 - 07:00 3.50 DRILL SURF PJSM, make up bha with 1.5 deg motor, align scribes, orient. 07:00 - 07:30 0.50 DRILL SURF Pre - spud meeting. 07:30 - 08:00 0.50 DRILL SURF Function test diverter, waived by John Crisp AOGCC. Test successful. i08:00 - 08:30 0.50 DRILL SURF Break circ, fill lines, check for leaks. 08:30 - 18:30 10.00 DRILL SURF Spud well L-116 at 0830 hrs, drill ahead 9 7/8 hole 106 - 844 ft. Hole good cond, no sloughing, hydrates. 18:30 - 19:00 0.50 DRILL SURF Flow check, circ btms up. 19:00 - 19:30 0.50 DRILL SURF Flow check, poh for XO change to 4" on top dry. 19:30 - 21:00 1.50 DRILL SURF Change out XO at top dry. 21:00 - 21:30 0.50 DRILL SURF Flow check, rih to 810 ft. 21:30 - 22:00 0.50 DRILL , SURF Wash to btm, no fill, cont drlg 844 - 869 ft. 22:00 - 22:30 0.50 DRILL N RREP SURF Change out lower top dry IBOP (leaking) 22:30 - 00:00 1.50 DRILL P SURF Resume drill ahead 9 7/8 hole 869 - 942 ft. Up 80, Dn 77, Rot 79 60 rpm, Wt 25 K, Press 1220, 520 gpm 7/3/2001 00:00 - 15:30 15.50 DRILL P SURF Directionally Drill 9 7/8" Hole from 942' to 2670': TD per Geologist. WOB = 20K to 32K. RPM 50 to 70. GPM = 490 tO 550. AST = 4.75 Hrs. ART = 7 Hrs. 15:30 - 16:30 1.00 DRILL P SURF CBU @ 550 GPM & 2200 psi. Pump Pill. 16:30 - 20:00 3.50 DRILL P SURF Wiper Trip. Work through tight spots @ 1985', 1770' to 1750'. Had to back ream 1255' to 1200', 962' to 900' 20:00 - 21:00 1.00 DRILL N FLUD SURF C & C Mud. Bring Vis to 300. Gravel running - Clean Hole. 21:00 - 22:30 1.50 DRILL N DPRB SURF POH w/4" DP, 5" HWDP and BHA. Check Stabs. and Bit. No Bailing but Bit worn out & 3/16" Underguage. 22:30 - 00:00 1.50 DRILL P SURF Clean floor, Service Top Drive, Draworks & Crown. 7/4/2001 00:00 - 07:30 7.50 DRILL N DPRB SURF RIH w/Bit #3. Wash & Ream through tight spots @ 998', 1050', 1150', 1660', 1750'. Wash & Ream from 1850' to 2400' - Surveys to this point indicated still in original hole. Sidetracted at 2400' and drilled to 2665'MD/2583'TVD. 07:30 - 08:30 1.00 DRILL N DPRB SURF Pump Sweep @ 500 GPM - 1800 psi. 08:30 - 14:30 6.00 DRILL N DPRB SURF POH. Tight from 1950' to 1800' - pulled 20K over. Stand back DC's and L/D MWD, Stab., Lead Cir. and Bit. 14:30 - 15:30 1.00 DRILL N DPRB SURF M/U 9 7/8" Smith Porcupine HO BHA. 15:30 - 16:30 1.00 DRILL N DPRB SURF RIH to TD @ 2665" Open Hole good. Took wt. @ 2400'. Picked up and went right through the next try with no drag. 16:30 - 18:30 2.00 DRILL N DPRB SURF Pump Sweep and circulate hole clean @ 510 gpm. Spot Casing Pill. Flow check. Pump slug. 18:30-22:00 3.50 DRILL N DPRB SURF POH. Pulled 20Kover@ 1775' - Wiped through OK. L/D Hole-opener, NMDC and 5" HWDP. 22:00 - 22:30 0.50 DRILL P SURF Clear & Clean Rig Floor. 22:30 - 00:00 1.50 CASE P SURF PJSM. Make Dummy Run w/7 5/8" Landing Jt. and Hanger. Change out Bails. R/U Franks Tool. R/U Casing Equipment. 7/5/2001 00:00 - 00:30 0.50 CASE P SURF Finish R/U 7 5/8" casing equipment. 00:30 - 01:00 0.50 CASE P SURF Held PJSM with Rig Crews prior to running 7 5/8" surface casing. Printed: 7/23/2001 11:09:53 AM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: DRILL+COMPLETE Start: 7/1/2001 End: 7/16/2001 Contractor Name: NABORS Rig Release: 7/16/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/5/2001 01:00 - 06:00 5.00 CASE P SURF Run 64 joints ( 2623' ) of 7 5~8" 29.7# L-80 BTC-M casing with Shoe @ 2652'. No hole problems encountered while RIH. 06:00 - 06:30 0.50 CASE P SURF PJD Franks casing fill-up tool and R/U Dowell cement head. 06:30 - 07:30 1.00 CASE P SURF Establish circulation. Stage pumps up to 12 bpm with 820 psi circ pressure. Circulate and condition mud. Reduce mud viscosity to 60. Had full returns while circulating. 07:30 - 10:00 2.50 CASE P SURF PJSM. Cement 7 5~8" surface casing as follows. Pump 10 bbl CWl00, test cement lines to 3500 psi. Drop bottom plug and pump a additional 40 bbl CWl00 + 75 bb110.2# MudPush spacer. Mix and pump cement. Lead Slurry = 257 bbl ( 325 sx ) 10.7# Artic Lite ( yield = 4.44 ft3/sk ). Tail Slurry = 33 bbl ( 175 sx ) 15.8# Class 'G' + ADDITIVES ( yield = 1.17 ft3/sk ). Drop Top plug, Dowell pump 10 bbl water. Switch over to Rig Pumps & displace with 107.5 bbl 9.5# mud @ 8 bpm. Reduce pump rate to 2 bpm the last 10 bbl. Bump plug with 2600 psi. Release pressure, floats held. ClP - 09:50 Hrs. Had full returns while cementing. Observed spacer but NO CEMENT. ; 10:00 - 11:00 1.00 CASE P SURF RID Cement head. R/U 4" Drill pipe elevators and related equipment. 11:00-12:00 1.00 CASE N CEMT SURF M/U TAM Combo Tool and TIH with same on 4" DP to1015'. 12:00 - 12:30 0.50 CASE N CEMT SURF Engage TAM collar with Combo Tool. Take 5K overpull and test Combo Tool to 1000 psi. S/O with 10K and open TAM Port Collar. 12:30 - 13:30 1.00 CASE N CEMT SURF Establish circulation through TAM Port Collar. Stage pumps up to 7.5 bpm w/550 psi. Observed cement to surface after pumping 49 bbl of mud. Continue pumping and dump 84 bbl of cement. Drag chain on cutting ditch broke. Divert returns to cellar. Pump another 12 bbl with mud at surface. Shut down rig' pumps. 13:30 - 14:30 1.00 CASE N CEMT SURF Clean surface equipment of excess cement from well. 14:30 - 15:30 1.00 CASE N CEMT SURF Break Circ. Shut down Rig pumps. SWS pumped 5 bbls water. Test Lines to 4000 psi. Pump 10 bbls water followed by 93 bbls 10.7 PPB, ARCTICSET LITE III Cement.. Observed good Cement at surface; then pumped 15 bbls Water to displace DP and Lines. Close TAM Collar and test to 1500 psi. Bleed pres and release Combo tool from Port collar. 15:30 - 16:00 0.50 CASE N CEMT SURF Pump two annular volumes with rig pumps @ 6 BPM - 450 psi. Returns Clean. 16:00 - 17:00 1.00 CASE N CEMT SURF POH. L/D Combo Tool 17:00 - 21:00 4.00 BOPSUF P SURF Break out Landing Jt. Rinse out Diverter. N/D Diverter Line and Valves. N/D Riser, Dresser sleeve. N/D Diverter. 21:00 - 00:00 3.00 BOPSUF.P PROD1 N/U FMC GEN-5 11" 5M Speed Head, Tubing Spool and Adaptor Flange. Dummy run w/new Test Jt. N/U 13 5/8" BOP.Stack. FMC hand pressure test Casing Head seals to 1000 psi.- OK. 7/6/2001 00:00 - 02:00 2.00 BOPSUF.P PROD1 Complete N/U 13 5/8", 5K, BOPE. 02:00 - 06:30 4.50 BOPSUF.P PROD1 Test BOPE: Annular to 250 / 3500 psi. Test all othe components: Rams, Lines & valves to 250 / 4000 psi. All tests APl. Witness of tests waived by John Spaulding, ^OGCC. 06:30 - 07:00 0.50 BOPSUF.P PROD1 Run and set Wear Bushing. 07:00 - 07:30 0.50 DRILL . P PROD1 Service Top Drive Printed: 7/23/2001 11:09:53 AM BP ExpLORATION Page 3 of 5 Operations Summa Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: DRILL+COMPLETE Start: 7/1/2001 End: 7/16/2001 Contractor Name: NABORS Rig Release: 7/16/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/6/2001 07:30 - 12:00 4.50 DRILL P PROD1 P/U 78 Jts 4" DP Stand back in derrick. 12:00 - 15:00 3.00 DRILL P PROD1 M/U BHA # 4 ( 6 3~4" Steerable ) & RIH. Note: The 3.5" HWDP had a excessive amount of rust & scale dropping out when it was picked-up off the pipe rack. 15:00 - 16:00 1.00 DRILL P PROD1 Flow Test MWD - No Signal. 16:00 - 22:30 6.50 DRILL N DFAL PROD1 POH, Change out MWD, RIH & Test - NO Signal on 2nd. Tool. POH. RIH w/HWDP. Pump and Spot Hot Caustic Flush Inside HWDP. Let soak for 1/2 Hr. Circulate out..POH. P/U MWD #3 and RIH. Flow Check MWD - OK. 22:30 - 00:00 1.50 DRILL P PROD1 Continue RIH P/U 4" DP. 7/7/2001 00:00 - 00:30 0.50 DRILL P PROD1 Cont. RIH; P/U Singles 00:30 - 01:30 1.00 DRILL P PROD1 Kick while Tripping Drill followed by Stripping Drill. 01:30 - 02:00 0.50 DRILL P PROD1 RIH, P/U Singles to 2474'. 02:00 - 03:00 1.00 DRILL P PROD1 Break Circulation. Test 7 5/8" Casing to 4000 psi. Chart for 30 minutes while having Reservoir Meeting with Lunda's Crew. 03:00 - 03:30 0.50 DRILL P PROD1 Reservoir Meeting with Hunt's Crew. 03:30 - 07:00 3.50 DRILL P PROD1 Drill Float Collar, Hard Cement, Float Shoe and Rathole to 2665'. .07:00 - 07:30 0.50 DRILL P PROD1 Drill from 2665' to 2686'. 90 ROT., 4-6K on Bit, 290 GPM w/ 1650 psi. 07:30 - 08:30 1.00 DRILL P PROD1 Displace Hole with New 9.4 ppg LSND Mud. 08:30 - 09:00 0.50 DRILL P PROD1 Perform Leak Off Test to 15.45 ppg. EMW. Leakoff pressure was 813 psi. with 9.4 ppg Mud. Kick Tolerance is 36.9 13bls. with 10.8 ppg. Mud 09:00 - 00:00 15.00 DRILL P PROD1 Directional Drill 6 3/4" Hole from 2685' to 4097. Rot Rpm: 50 to 90 285 GPM @ 1900 psi. Torque: 2 to 3K. P/U = 106K, S/O = 92K ROT = 101K. ART = 8.5 Hrs. AST = 1 Hr. 2100 U. Gas @ 4064' 7/8/2001 00:00 - 02:30 2.50 DRILL P PROD1 Directional Drill 6 3/4" Hole from 4097' to 4375'. P/U = 117K S/O = 90K ROT = 101K. 287 GPM @ 2050 psi. Trq. = 2-3K 70 RPM. WOB = 1 to 10K ART = 1.5 Hrs. AST = 0.5 Hrs. 02:30 - 03:30 1.00 DRILL P PROD1 Circulate Hi - Vis Sweep. Hole Clean. 03:30 - 04:30 1.00 DRILL P PROD1 POH to 7 5/8" Shoe. Max Drag 10K. 04:30 - 05:00 0.50 DRILL P PROD1 Service Top Drive. 05:00 - 06:00 1.00 DRILL P PROD1 RIH. Wash Last stand to bottom. No Fill - Hole Slick. 06:00 - 00:00 18.00 DRILL P PROD1 Directional drill 6 3/4" HOle from 4375' to 5360'. P/U = 130K S/O = 105K ROT = 117K. 290 GPM @ 2200 psi. RPM = 60 to 100 Torque = 3 to 5K ART + 13.5 AST = 1 Bit Bailing heavily in Colville. Adding DRILL-N-SLIDE, SAPP & Nut Hulls to alleviate problem. 7/9/2001 00:00 - 18:30 18.50 DRILL P PROD1 Drill 6 3/4" Hole from 5360' to 6145'. - All Rotate - 15.5 Hrs ART 300 GPM @ 2700 psi. WOB = 4 to 15K. Torque = 4 to 6K. P/U = 142K S/O = 112K ROT= 126K Increase Mud Wt. to 10.8 ppg starting @ 5900' with addition of 200 bbls 14 ppg premixed and treated mud. ROP dropping - very difficult to maintain pressure differential on bit for good mud motor performance. i18:30 - 19:30 1.00 DRILL P PROD1 Circulate Hi - Vis Sweep, Survey, pump slug. 19:30 - 22:30 3.00 DRILL P PROD1 POH w/4" DP. No Problems - Minimum Drag. Printed: 7/23/2001 11:09:53 AM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: DRILL+COMPLETE Start: 7/1/2001 End: 7/16/2001 Contractor Name: NABORS Rig Release: 7/16/2001 Rig Name: NABORS 9ES Rig Number: Date From - To HOurs Activity Code NPT Phase DeScription of Operations .... 7/9/2001 22:30 - 00:oo 1.50 DRILL P PROD1 POH Stand back HWDP, Jars, Flex Collars Break out Bit. 7/10/2001 00:00 - 01:30 1.50 DRILL P PROD1 CIO Bit & MWD, Orient.. RIH w/BHA. Test MWD - OK. 01:30 - 02:30 1.00 DRILL P PROD1 RIH to Shoe @ 2652'. 02:30 - 04:00 1.50 DRILL P PROD1 Cut & Slip Drilling Line. Service Top Drive, Crown & Brakes. 04:00 - 06:30 2.50 DRILL P PROD1 Cont. RIH to 6052'. Wash last stand to bottom - 6145' No Fill - Hole in good shape. 06:30 - 00:00 17.50 DRILL P PROD1 Drill 6 3~4" directional Hole from 6145' to 7190' - TD per on site Geologist. All Rotate. ART 12.5 Hrs. 296 GPM @ 2830psi. WOB = 3 to 10 K. Torque = 4 to 6K. P/U = 175K S/O = 125K ROT = 140K Mud loses < 1 BPM. 7/11/2001 00:00 - 01:00 1.00 DRILL P PROD1 Circ hi - vis sweep, shaker clean, pump wt pill. 01:00 - 05:00 4.00 DRILL P PROD1 Flow check, poh, 10 - 25 K drag interrmittent. No swab, losses 1 bph. 05:00 - 07:00 2.00 DRILL P PROD1 Flow check at bha, lay mud motor / drctnl equip. 07:00 - 08:00 1.00 DRILL P PROD1 Make up hole opener assy, rih same to 6714 ft. 08:00 - 12:30 4.50 DRILL P PROD1 Flow check, break circ, ream / wash to btm at 7190 ft. no fill, abnormalties. 12:30 - 14:00 1.50 DRILL P PROD1 Circ sweep, spot lube pill, pump wt pill. 14:00 - 17:30 3.50 DRILL P PROD1 Flow check, poh for E-logs, hole good condition. 17:30 - 18:30 1.00 EVAL P PROD1 PJSM, place Schlum equip on floor, rig up same. 18:30 - 00:00 5.50 EVAL P PROD1 Rih wireline run #1, "platform express". 7/12/2001 00:00 - 00:30 0.50 EVAL P PROD1 Cont E-logs (PEX), poh wireline. 00:30 - 01:30 1.00 EVAL P PROD1 Flow check, lay out all related Shclum equip. 01:30 - 04:30 3.00 EVAL P PROD1 Rih 6 3/4 hole opener, filling at 2652 ft, 5780 ft. MU blower hose top drive. 04:30 - 05:30 1.00 EVAL N HMAN PROD1 Drop end wrench down hole. Drain bop stack, inspect for wrench. Do not find. 05:30 - 12:00 6.50 EVAL P PROD1 Flow check, cont rih, wash / ream 6434 - btm 7190 ft. No fill. Dropped wrench not encountered during rih. 12:00 - 13:30 1.50 EVAL P PROD1 Circ hi - vis sweep, shaker clean. Cuttings normal. Pump wt pill. 13:30 - 17:30 4.00 EVAL P PROD1 Flow check, poh for E-logs. Hole good cond, no abnormalties. 17:30 - 18:30 1.00 EVAL P PROD1 PJSM, rig up Schlum, all related equip. 18:30 - 00:00 5.50 EVAL P PROD1 Flow check, commence rih. run #2 (RFT) - Static Mud loses = 1 to 1 1/2 bbl/hr. 7/13/2001 00:00 - 04:30 4.50 EVAL P PROD1 Cont E-logs ( Run #2, RFT ), and complete. Poh wireline. 04:30 - 05:30 1.00 EV^L P PROD1 PJSM, retrieve fluid samples. 05:30 - 06:30 1.00 EVAL P PROD1 Flow check, rig dn all related Schlum equip. Release unit. 06:30 - 14:00 7.50 CASE P COMP Rih bha / 4" dp, lay dn 23 stds dp, bha. 14:00 - 20:00 6.00 CASE P COMP PJSM, prepare and rih 5 1/2 X 3 1/2 tapered string, check floats, cont rih, filling pipe during rih. 20:00 - 21:00 1.00 CASE P COMP Break circ at 7 5/8 shoe 1 1/2 csg volume. No losses. 21:00 - 00:00 3.00 CASE P COMP Flow check, cont rih 5 1/2" interval csg string. ( L80 BTC 15.5# ) 7/14/2001 00:00 - 03:00 3.00 CASE P COMP Run 3.5" X 5.5" Production String. 22 Jts 3.5" & 156 Jts 5.5". Shoe set at 7172'. Plug receptacle at 7064'. Top of PBR @ 6422'. 03:00 - 12:00 9.00 CEMT P COMP Attempted circ. 1 Jt. prior to landing. Recipr°cating pipe. No returns for 1st 95 bbls pumped then partial rtns with losses of 80 bbls/Hr.; improving steadily to 20 bbls / Hr. by 08:30. Adding Barofibre and thinning mud. Mud thinned and wt at 10.7 Printed: 7/23/2001 11:09:53 AM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: L-116 Common Well Name: L-116 Spud Date: 7/1/2001 Event Name: DRILL+COMPLETE Start: 7/1/2001 End: 7/16/2001 Contractor Name: NABORS Rig Release: 7/16/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/14/2001 03:00 - 12:00 9.00 CEMT P COMP ppg with 5 lb / bbl barofibre at 12:00 Hrs. Losses < 12 bbl / Hr. 12:00 - 14:30 2.50 CEMT P COMP PJU Dowell Pump 5 bbl CWl00. Test lines to 4000 psi. Pump 5 bbls CW100 followed by 50 bbls 11.3 ppg. Mud Push XL Spacer. Drop wiper dart and pump 90 bbls 12.0 ppg LiteCrete Cement. Drop Plug dart and displace with 159 bbls filtered seawater. Bump plug with 3200 psi. Hold for 5 min, bleed off & check floats - OK. 14:30 - 16:30 2.00 WHSUR P COMP RD Cmt equip. & Landing jt. M/U packoff running tool and install Packoff. RILDS. L/D running tool. Test Packoff to 5000 psi. 16:30 - 17:30 1.00 RUNCOI~ COMP Clear rig floor, rig up, make ready to run comp assy. ' 17:30 - 22:30 5.00 RUNCOI~ COMP PJSM, MU seal assy / shoe, rih same, follow with 3 1/2, 9.3#, L80 BTC-M, prod tbg. 22:30 - 23:30 1.00 RUNCOI~ COMP Place Camco control line equip on rig floor, prepare test csg. 23:30 - 00:00 0.50 RUNCOI~' COMP PJSM, test lines for csg test. 7/15/2001 00:00 - 01:00 1.00 RUNCO~ COMP Test 5 1/2 X 3 1/2 tbg / csg to 4000 psi / 30 min. Test successful. 01:00 - 02:00 1.00 RUNCO~ COMP Manifold in hot oil / kill line, test same to 3000 psi, in preparation for LOT. 02:00 - 03:30 1.50 RUNCOI~ COMP Perform LOT dn 5 1/2 X 7 5/8 annulus. 1 bpm, 5 stroke intervals. Leak off press at 404 psi ( EMW 13.61 ). Test interval 2652 - 3770 ft ( TOC ). Hold press, bleed to 264 psi and holding. Cont inject 47 bbls 10.6 ppg mud, follow with 33 bbls hot oil. 650 psi- 3 bpm. Rig dn injection equip. Release unit. 03:30 - 04:00 0.50 RUNCO~ COMP Mu sssv, test control lines to 5000 psi 04:00 - 09:00 5.00 RUNCO~ COMP Cont rih 3 1/2 tbg, installing control lines. 09:00 - 14:00 5.00 RUNCOI~ COMP Sting in to pbr with slow pump, note sting in with press build. Space out for tg hgr, make up pups, connect control lines to hgr, test lines to 5000 psi. Test successful. Verify space out. 14:00 - 15:00 1.00 RUNCO~ COMP Reverse circ Corexit 3 bpm at 440 psi. 15:00 - 16:00 1.00 RUNCO~ COMP Land tbg hgr, run in Ids. Rig up for test. 16:00 - 18:30 2.50 RUNCO~ COMP Test tbg 4000 psi / 30 min., bleed to 2000 psi. Test 3 1/2 X 5 1/2 annulus to 4000 psi / 30 min. Bleed tbg and shear RP at 2900 psi. differential. Set TWC, test below check to 2800 psi. All tests successful. No re-tests. 18:30 - 20:30 2.00 WHSUR P COMP Nipple dn bope. 20:30 - 00:00 3.50 WHSUR P COMP Connect control lines to ports, nipple up tree, test control lines, all hgr / tree seals to 5000 psi. Test succesful. 7/16/2001 00:00 - 00:30 0.50 WHSUR P COMP Test Tree to 5000 psi. 00:30 - 03:00 2.50 WHSUR P COMP Rig up Little Red Hot Oiler to tree. Test lines to 3500 psi. Freeze Protect 3.5" X 5.5" annulus and inside tubing down to 2200' with 56 bbls diesel. Let diesel U-Tube to stabilization. Shut in well. R/D Little Red. 03:00 - 04:00 1.00 WHSUR P COMP R/U DSM lubricator. Install BPV & Test to 1000 psi from below. Rig Down lines. Secure Well. RIG RELEASED @ 04:00 HRS. Printed: 7/23/2001 11:09:53AM Well: L-116 Rig Accept: 07/01/01 Field: Prudhoe Bay Field / Borealis Pool Rig Spud: 07/02/01 APl: 50-029-23025-00 Rig Release: 07/16/01 Permit: 201-116 Drilling Rig: Nabors 9ES POST - RIG WORK 09102/01 & 09/03101 Rig up Slickline unit and pressure test 300/3000 PSI. Pull 3-1/2" DSSSV from BVN at 2187' WLM, set 3-1/2" Slipstop catcher at 3799' WLM, pull RP GLV from STA # 4 at 3626' WLM, set DBLV in STA # 4 at 3626' WLM, Pull 3-1/2" Catcher sub from 3799' WLM and pressure test tubing and IA to 4000 PSI for ~,,~ hour, Good test. Drift tubing with 2-1/2" Dummy Gun and sample bailer to 6416' WLMD. Run 2" Pump Bailer to 7024' WLMD and drift with 2-1/2" Dummy Gun to 7022' LMD. 09114101 Completed Jewelry log and IPERF. Shot two intervals (6675' - 6720') and (6734' - 6740') three gun runs with 2-1/2" Power flow HMX, 6 SPF, 60 degree phased, Fluid level at surface after all shots. 09116/01 Static Survey with tandem Petredat gauges; All depths - 24 SLM to CORR to MD. Tagged TD at 7024' SLM. 40 MIN stop at 6700' SS (6984' MD), 20 & 30 MIN stop at 6500' SS (6784' MD). Average PRESS and TEMP a t 6600' SS = 3700 PSI and 158 Degrees F. 09/21/01 Set memory gauges at TD (7002' SLM). Note: Gauges are in a 5' x 2.5" drive down bailer body baited with a 1-3/4" rope socket with a 1-3/4" fishing neck. 09122/01 Set FRAC Isolation sleeve in SSSV nipple at 2190' SLM, good test on BAL and Control lines. Left 4500 PSI on both lines. Pumped 50 bbls of YF130LG data FRAC at 5 BPM till pad on PERFS WHP = 2495 PSI, then increased to 25 BPM WHP = 5100 PSI, ISIP = 2003 PSI and FG = 74. Watched fall off EST closure at 7.40 MIN 66% fluid effective, net PSI = 423, Closure PSI = 1567. Redesigned FRAC to 50 bbls pad, a 1 to 6 PPA sand ramp stage, and a 6 to 10 PPA step sand stage. Started 10 PPA 40 bbls early in 9 PPA stage from design. Screen out (N2 POP off went at 8100 PSI) 109 bbls into 10 PPA stage. Placed 156230 #'s of 16 / 20 C-LITE into FM. Last 50 bbls into FM was 10# Proppant (14577#). Well filled to surface with 10 PPA Proppant estimated volume ~19000 #'s in W/B. Pulled Treesaver and bottom cup missing. Circulated sand from Wellhead with 2 bbls diesel. 09125/01 & 09/26/01 MIRU CTU # 3, MU BHA - Stinger 2" JS nozzle, jet from surface. First tag at 150', take 35' bites and chase up with XS 2% KCL. Jet to SSSV insert at 2204'. Pump BIO Sweep; chase to surface, swap to Methanol / Water to Freeze protect coil lines. Standby for Slickline retrieval of insert, rig down Slickline. Rig Coil injector back on well, RIH continue FCO /Jetting. Clean out down to 7029' CTMD with 175 bbls 2 # / BIO and 870 bbls XS KCL (totals for both days), estimate ~100 bbl returns in addition to volume pumped. Well did not show strong indication of coming back. Laid in Diesel 1:1 from TD to surface to lighten column and Freeze protect. Standby for CTU to FCO and jet ice plug. Rig up pull FRAC sleeve at 2199' SLM. Purge balance and control lines. Z ~-=. ~ ~ ~ ~ -~oooo O0 00000 88888 _.~ ~ A ~ ZZ ZZZZZ ~ ~ ~ ~o 0 ~ ~ ~0000 -- . .... o ~ ~ ~ ~ ..... 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II II II ~-I I~ II · 0 II ~ -il ~ II -,-t .Il .IJ II ~ II ~ II II II o~ 1~- o r-I o~ II ..... IIo o ,--I ~-I o 0 O10~ O~ 0 ,~ C~ P1 ~0 ~0 O~ ~1 W1 0 0 0 ~P O1Lfl ~ ~-t CO ~ r~ 00~ O~ 0 ~ ~ 0 0 0 0 0 0 0 0 0 0 ~ 0 II II 1"3 CO ~l~l I~'1 r'- LI3 ['-- r~3 r'- ~,1 (~ O0 IZl ~'l 0 0 0 O0 rtl II ................. II I~ --.. II tO ~ ~ [" ~ 0 ~0 ,'-I ~ ,~' mr-- ~ ,--I o II ,-'1 ,-I I~ II o~ m ~ Ln ~0 m ~ ["- ~ eq II ~ I~1 I~ II ............... II H I1:1 "-' II II II II I~ II r-I eq m ,~ I%1 ~ ~ ~ ~ 0 II (].l q:l: I II M3 ~D kD tD ~0 ~0 M::) q3 q::) E',- II U~ II ~m < 'E ~D, I- 0 ITl --! .q m ..q o --. "ID 0 b p Date: 08-03-2001 Transmittal Number:92108 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type L-116 07-11-2001 ANA 1 0 7190 SURVEY REPORT; (HARDCOPY/DISKETTE;) Thank You, James H. Johnson Petrotechnical Data Center Attn: Sandy Lemke (Phillips) Attn: Susan Nisbet (Exxon) :~t't:n'; 'Lis ~eePie' ,(AOGC~ RECEIVED AUG 0 6 2001 Amlm~&Gas Cons.~rt Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 9951%6612 E E 0 (D ~KA OIL AND GAS CONSI~RVA~I~ION COM~I~SSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Drilling Superintendent BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519 Re-' Prudhoe Bay Unit L-116 BP Exploration (Alaska) Inc. Permit No: 201-116 Sur Loc: 2371' NSL, 3742' W'EL, SEC. 34, T12N, R11E, UM Btmhole Loc. 3527' NSL, 4491' WEL, SEC. 34, T12N, R11E, UM Dear Mr. Stone: Enclosed is the apprOved application for permit to drill the above referenced well. The permit to drill does 'not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operatiOns until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L- 116. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (apProximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~'{~ day of June'2001. jjc/Enclosures CC: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. "' STATE OF ALASKA .,,,~ '~ fi' '~ ALASKA O1[ ,ND GAS CONSERVATION COMMIS~..N PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work B Drill [] Redrill lb. Type of well Re-Entry [] Deepen Service Development Gas Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 77.0' Prudhoe Bay Field / Borealis 3. Address 16. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2371' NSL, 3742' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3527' NSL, 4491' WEL, SEC. 34, T12N, R11E, UM L-116 Number 2S100302630-277 At total depth 9. Approximate spud date 3527' NSL, 4491' WEL, SEC. 34, T12N, R11E, UM 06/23/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028241, 3527' MDI No Close Approach 2560 7210' MD / 6946' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 450' MD Maximum Hole Angle 26 ° Maximum surface 2759 psig, At total depth (TVD) 6315' / 3390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stare data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC 2664' Surface Surface 2664' 2577' 287 sx AS Lite, 158 sx Class 'G' 6-3/4" s-1/2,,x3-~/2,, 15.5#x9.2# L-80 BTC-MxlBT-M 7210' Surface' Surface 7210' 6946' 89 sx LiteCrete, 219 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate RECEIVED Production Liner JUN 1 g 2001 Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical ;20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 56~-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 "21. I hereby certify that the foregoing_~~orrect~fb"~'~st of my knowledge ~ Signed Anthony S. Bunch for Dan Ston-T~'~~e,__.~ Drilling,,,,, ~, ,,,rSuperintendent Date Permit Number APl Number oAgppR~~Zi~d~?/(~) ! See cover letter .% O / - ,///~ 50- ~:~_-~ ~---- ~ ~ ~:~ .~r ~ for other requirements Conditions of Approval: Samples Required [] Yes ~]'No Mud L ' - [] Yes [~No Hydrogen Sulfide Measures [] Yes ~'No Directional Survey Required .[~Yes [] No Required Working Pressure for BOPET-12K [] 3K [] 4K [] 5K [] 10K [] 15K ,~3.5K psi-fee,liliU Other: OF(~(~,~[~j. M. Heusser$'GNED BY by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Triplicate I Well Name: I L-1 16 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: As-Staked Target Location: Top Kuparuk Bottom Hole Location: X = 583,174.09' Y = 5,978,092.83' 2371' FSL (2908' FNL), 3742' FEL (1537' FWL), Sec. 34, T12N, R11E X = 582,409.97' Y = 5,979,239.98' 3527' FSL (1752' FNL), 4491' FEL (787' FWL), Sec. 34, T12N, R11E X = 582,409.97' Y = 5,979239.98' 3527' FSL (1752' FNL), 4491' FEL (787' FWL), Sec. 34, T12N, R11E I AFE Number: 15M4028 I I Estimated Start Date: 1 6/23/2001 I~: 7210' I TW: 169~6' I Rig: I Nabors 9ES I Operating days to complete: I 13.0 I BF/~S: 130' I I RKB: 177.0' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) 1 Objective: I Kuparuk Formation (Target zones C sands) Mud Program: 9-7/8" Surface Hole (0-2664'~,: Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/100ftz) (mls/30min) Initial 8.5 o 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below Permafrost 9.3 o 9.5 200-150 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 150 25 - 35 < 10 8.5 - 9.5 6 3A,, Intermediate / Production Hole (2663'- 7210'): Fresh Water LSND Interval Density Tau o YP PV pH APl HTHP (ppg) Filtrate Filtrate Upper 9.1-9.5 4-7 20-25 8-14 8.5-9.5 4-6 Interval Top of 10.8 5-8 20-25 8-14 8.5-9.5 3-5 <10 by HRZ HRZ L-116 Permit to Drill Page 1 Directional: Ver. Sperry WP-02 KOP: 450' Maximum Hole Angle: 26° at 2281' MD Close Approach Wells: All wells pass major risk criteria. Logging Program: Surface Intermediate/Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR/Res Open Hole: MDT / GR-Neu-Den / Dipole Sonic, Cuttings samples Cased Hole: USIT cement evaluation (contingency) Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1542 1465 SV4 1701 1610 Base Permafrost 1873 1775 SV3 2O57 195O SV2 2241 212O SVl 2597 2440 UG4A 2931 2716 Not hydrocarbon bearing '""' ~_-_ """'"~ UG3 3360 3080 ~"'~'~ UG1 3945 3563 Ma 4142 3830 WS2 (N sands) 4207 4108 Not hydrocarbon bearing WS1 (O sands) 4512 4231 Not hydrocarbon bearing Obf Base 4995 4655 CM2 (Colville) 5191 4850 THRZ 6340 6000 BHRZ (Kalubik) 6523 6182 K-1 6596 6255 TKUP 6656 6315 3390 psi, 10.3 ppg TMLV (Miluveach) 7060 6719 TD Criteria 7210 6869 150' below Miluveach top L-116 Permit to Drill Page 2 Casinclrrubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 110/110 9-7/8" 7 5/8" 29.7# L-80 BTC 2664' GL 2664'/2577' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 6506' GL 6506'/6242' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 704' 6506'/6242' 7210'/6946' Tubing 3-1/2" 9.2# L-80 IBT-mod 6506' GL 6506'/6242' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casin~. Basis: Size 17-5/8" Surface Lead: Based on 1873' of annulus in the permafrost @ 175% excess and 204' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2077' MD (2045' TVDbkb). Lead 1 227 bbl / 1273ft~ / 287 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 33 bbl / 185 ft~ / 158 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. Casing Size 15'l/2''x3'l/2''Longstring Production Basis: Lead: Based on 'I'OC 500' above top of Schrader formation & 30% excess above Tail. Lead TOC: 3707' MD, 3514' TVDbkb Tail: Based on TOC 1000' TVD above top of Kuparuk C4B target and 30% excess + 80' shoe volume Tail TOC: 5655' MD, 5391' TVDbkb ITotal Cement Volume: I Lead 38 bbls / 212 ft~/89 sks of Dowell LiteCrete at 12.0 ppg land 2.39 cf/sk. I Tail 1 47 bbls / 263 ftc/219 sks of Dowell Premium 'G' at 15.8 I ppg and 1.20 cf/sk. L-116 Permit to Drill Page 3 Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3390 psi @ 6315' TVDss - Kuparuk Sands 2759 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOPtest pressure: 3500 psi · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-116 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. Operations: MIRU Nabors 9ES. Nipple up diverter spool and riser. PU 4" DP as reqUired and stand back in derrick. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2664' MD / 2577' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/RES and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for logging and POOH. 9. RU Schlumberger E-line unit. Run GR/DEN/NEUT, Dipole Sonic and MDT logs. POOH and RD Schlumberger. 10. If logging time is excessive, RIH with 6-3/4" cleanout assembly and condition hole for running the 5 Y2" x 3 Y2" casing. POOH laying down excess 4" DP. 11. Run and cement the tapered production casing as required from TD to 500' above the Schrader Bluff. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. 12. Test the casing to 3500 psi for 30 min. 13. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Sting seal assembly into tieback receptacle and test to 3500 psi for 30 minutes both the tubing and annulus. 14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Freeze protect the well to -2200' and secure the well. 16. Rig down and move off. Estimated Spud Date: 6-23-2001 L-116 Permit to Drill Page 5 L-116 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. The closest surface locations are NWE1-01, NWE1-02 and L-01. All are greater then 85' from well L-116. No surface shut-in's will be required. Reference RPs Operational Specifics Job 2: Drillinq Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by L-116 in the surface interval. There are no close approach issues in the surface hole. All wells pass major risk criteria. The closest existing well, L-01, is at roughly 86' center-center at approximately 625' MD. Gas hydrates were observed by the NWE1-01and NWE1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. L-01 surface interval encountered hydrates from the base of permafrost to TD in the SV1 sand. Expect to encounter hydrates from the base of permafrost to the surface shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation. Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs Operational Specifics Job 3: Install surface Casing Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs L-116 Permit to Drill Page 6 Operational Specifics Job 7: Drillinq Intermediate / Production Hole Hazards and Contingencies ~ L-116 will cross a fault in the Collvile/'l'op HRZ, @-6251' MD/5987' TVD. The estimated throw of the E-W fault is approximately 200'. The well will be vertical when crossing the fault. Loss circulation is not considered to be a risk. KICK TOLERANCE: In the worst case scenario of 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 18 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.5 ppg. Reference RPs Operational Specifics Job 8: Loq Production Hole Hazards and Contingencies ~ Ensure the hole is in very good condition to avoid a stuck tool string ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 Y2"x 3 W' Iongstring casing. Reference RPs Operational Specifics Job 9: Case & Cement Production Hole Hazards and Contingencies The Ugnu 4A is not expected to be oil bearing. For this reason the 5-1/2" casing will be cemented to 500' above the Schrader sand. The top of the hydrocarbon interval should be verified with LWD resistivity Icg. ~ After freeze protecting the 5 Y=" x 7-5/8" casing annulus with 33 bbls of dead crude, the hydrostatic pressure will be greater than the formation pressure, (11.1 EMW.) > This is the first microbore completion on Nabors 9ES or on L-pad. Most of the differences between this well design and other more conventional designs (apart from hole size) is in the tapered Iongstring and tubing/seal-bore items. Thorough pre-job planning meetings will help ensure success. Reference RPs L-116 Permit to Drill Page 7 Operational Specifics Job 12: Run Completion Hazards and Contingencies ~' No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-116 Permit to Drill Page 8 Borealis L-116: TREE: 3-1/8" - 5M CIW L-80 WELLHEAD: 11" - 5M FMC G5 Proposed Completion Cellar Elevation = 47' RKB - MSL = 77' 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I 2200' 7-5/8", 29.7 #/ft, L-80, BTC 3-1/2' x 1' Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS MD Size Valve Type TBD 1" DV TBD 1" DV TBD 1" DV TBD 1" DV 3-1/2" 9.2# IBT Mod L-80, Tubing 5-1/2", 15.5 #/ft, L-80, BTC-Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" Seal Asembly 3-1/2" PBR 5-1/2"x3-1/2" XO placed at +/-150' above the Kuparuk Formation I 6506' MD I Plug Back Depth 3-1/2", 9.2 #/ft, L-80,IBT Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID. Date Rev By Comments 3/5/-01 BWS Proposed Seal Bore Completion - WP2 Microbore with 5-1/2"x3-1/2" tapered Iongstring 3/7/-01 LRC Corrected Surf casing depth 6/12/01 JAS Final Proposed Completion Borealis WELL: L-116 APl NO: 50-029-????? BP Alaska Drilling & Wells (.9 [U!/].~O0~] (+)tt]~oN/(-)tl]nO~ BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/20/2001 Time: 06:37:58 Page: Field: Prudhoe Bay Coordinate(NE) Reference: Well: Plan L-116, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-116 Section CVS) Reference: Well (0,00E.0.00N,326.97Azi) Weilpath: Plan L-116 Plan: L-116 WP02 ............................................................................................................................................................. North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zene: Alaska, Zone 4 Ceo Datum: NAD27 (Clarke 1866) Cenrdinate System: Well Centre Sys Datum.:_. Mea~n- ~_a_.~?~e_! ............................................ G_e_e~a_g_n. et_ic_~ .0_d?_:_ ....... BGGM2000 Site: PB L Pad UNITED STATES · North Slope Site Position: Northing: 5978232.73 ft Latitude: 70 21 1.823 N From: Map Easting: 582996.83 ft Longitude: 149 19 34.141 W Position Uncertainty: 0.00 ff North Reference: True Ground Level: 0.00 ff Grid Convergence: 0.63 deg Well: Plan L-116 Slot Name: S-J Surface Position: +N/-S -141.87 ft Northing: 5978092.83 ft Latitude: 70 21 0.428 N +EI-W 175.72 ft Easting: 583174.09 ft Longitude: 149 19 29.005 W Position Uncertainty: 0,00 ft Reference Point: +N/-S -141.87 ft Northing: 5978092.83 ft Latitude: 70 21 0.428 N +E/-W 175.72 ft Easting: 583174.09 ft Longitude: 149 19 29.005 W Measured Depth: 77.00 ft Inclination: 0.00 deg VerticaIDepth: 77.00 ft Azimuth: 0.00 deg Wellpath: Plan L-116 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Temp Plan elevation 77 Height 77.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/10/2001 Declination: 26.46 deg Field Strength: 57446 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 326.97 -' :: ~.~ :~: ~':'~:::.L L~.: ':' ~.:.. ::::::::::::::::::::::::::::::: L:~:':;~:_~*::::::::':: ::::::.i ~.:::::::::.::~: :::.~:':~:~: ::'~.~ Plan: L-116 WP02 Date Composed: 1/10/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information ............................................... .... MD Incl·" Azim TVD +N/$ +E/-W DLS Build Turn TFO Target ft ft ft deg/100ft degll00ft deg/100ft deg ..................... · . . ft deg deg . ............................ 77.00 0.00 320.57 77.00 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 320.57 450.00 0.00 0.00 0.00 0.00 0.00 320.57 950.00 5.00 345.00 949.37 21.06 -5.64 1.00 1.00 0.00 345.00 1774.63 17.00 326.19 1757.55 156.46 -82.32 1.50 1.46 -2.28 333.89 1975.87 17.00 326.19 1950.00 205.35 -115.06 0.00 0.00 0.00 0.00 2280.83 26.15 326.19 2233.29 298.42 -177.39 3.00 3.00 0.00 0.00 3956.52 26.15 326.19 3737.48 912.04 -588.27 0.00 0.00 0.00 0.00 5263.96 0.00 326.19 5000.00 1155.67 -751.41 2.00 -2.00 0.00 180.00 6655.96 0.00 326.19 6392.00 1155.67 -751.41 0.00 0.00 0.00 326.19 7059.96 0.00 326.19 6796.00 1155.67 -751.41 0.00 0.00 0.00 326.19 7209.96 0.00 326.19 6946.00 1155.67 -751.41 0.00 0.00 0.00 326.19 P_L_6 Section 1 : Start : :: ::degi:::: i, ,' ;ft:,:::: : 77.00 0.00 320,57 77.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 320.57 100.00 0.00 0.00 0.00 0.00 0.00 0.00 320,57 200.00 0.00 320,57 200.00 0.00 0.00 0.00 0.00 0.00 0,00 320.57 300.00 0.00 320,57 300.00 0.00 0.00 0.00 0.00 0.00 0.00 320.57 400,00 0.00 320,57 400.00 0.00 0.00 0.00 0.00 0.00 0,00 320,57 450.00 0.00 320.57 450.00 0.00 0.00 0.00 0.00 0,00 0.00 320.57 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2./2012001 Time: 06:37:58 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-116, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-116 Section (VS) Reference: Well (0.00E,0.00N,326.97Azi) Wellpatb: Plan L-116 Plan: L-116 WP02 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/lOOft deg/lOOft deg/lOOft deg 500.00 0.50 345.00 500.00 0.21 -0.06 0.21 1.00 1.00 0.00 0.00 600.00 1.50 345.00 599.98 1.90 -0.51 1.87 1.00 1.00 0.00 0.00 700.00 2.50 345.00 699.92 5.27 -1.41 5.19 1.00 1.00 0.00 0.00 800.00 3.50 345.00 799.78 10.32 -2.77 10.16 1.00 1.00 0.00 0.00 900.00 4.50 345.00 899.54 17.06 -4.57 16.79 1.00 1.00 0.00 0.00 950.00 5.00 345.00 949.37 21.06 -5.64 20.73 1.00 1.00 0.00 0.00 Section 3: Start ......... ~-ii- ...... -g;F ...... ~ ...... 7-~ -':~/--~---¥~/--w .... ~-', .... ~'~-'~.~ ..... -~ ......... -~'6 .......................................... ft deg deg ft ft ft ft deg/100ft deg/lOOft deg/100ft deg 1000.00 5.68 341.66 999.15 25.51 -6.98 25.20 1.50 1.37 -6.67 -26.11 1100.00 7.09 336.95 1098.53 35.89 -10.96 36.06 1.50 1.41 -4.71 -22,79 1200.00 8.53 333.81 1197.60 48.23 -16.65 49.50 1.50 1.44 -3.14 -18.11 1300.00 9.98 331.57 1296.30 62.50 -24.05 65.51 1.50 1.46 -2.24 -14.99 1400.00 11.45 329.90 1394.55 78.72 -33.15 84.07 1.50 1.47 -1.67 -12.78 1500.00 12.93 328.60 1492,29 96,85 -43.96 105.16 1.50 1.47 -1.30 -11.14 1600.00 14.41 327.57 1589.46 116.90 -56.46 128.78 1.50 1,48 -1.03 -9.87 1700.00 15.89 326.73 1685.98 138.85 -70.64 154.92 1.50 1.48 -0.84 -8.87 1774.63 17.00 326.19 1757.55 156,46 -82.32 176.04 1.50 1.49 -0.72 -8.04 Section 4: Start Section 5: Start 'ft:::, : deg ~:,deg ;' :: ,:, :: :; , 2000.00 17.72 326.19 1973.03 211.33 -119.07 242.08 3.00 2100.00 20.72 326.19 2067.44 238.69 -137.39 275.00 3.00 2200.00 23.72 326.19 2160.00 270.11 -158.43 312.81 3.00 2280.83 26.15 326.19 2233.29 298.42 -177.39 346.88 3.00 3.00 0.00 0.00 3.o0 0.00 0.00 3.o0 0.00 0.00 3.00 0.00 0.00 Section 6: Start 2300.00 26.15 326.19 2250.50 305.44 -182,09 355.33 0.00 0.00 0.00 0.00 2400.00 26.15 326.19 2340.26 342.06 -206.61 399.40 0.00 0.00 0.00 0.00 2500.00 26.15 326.19 2430.03 378.68 -231.14 443.47 0.00 0.00 0.00 0.00 2600.00 26.15 326.19 2519.79 415.30 -255.66 487.53 0.00 0.00 0.00 0.00 2700.00 26.15 326.19 2609.56 451.92 -280.19 531.60 0.00 0.00 0.00 0.00 2800.00 26.15 326.19 2699.32 488.54 -304.71 575.67 0.00 0.00 0.00 0.00 2900.00 26.15 326.19 2789.08 525.15 -329.23 619.74 0.00 0.00 0.00 0.00 3000.00 26.15 326.19 2878.85 561.77 -353.76 663.81 0.00 0.00 0.00 0,00 3100.00 26,15 326.19 2968,61 598.39 -378.28 707.87 0.00 0.00 0.00 0.00 3200.00 26.15 326.19 3058.38 635.01 -402.80 751.94 0.00 0.00 0.00 0.00 3300.00 26.15 326.19 3148.14 671.63 -427.33 796.01 0.00 0.00 0,00 0.00 3400.00 26.15 326.19 3237.91 708.25 -451.85 840.08 0.00 0,00 0.00 0.00 3500.00 26.15 326.19 3327.67 744.87 -476.37 884.15 0.00 0.00 0.00 0.00 3600.00 26.15 326.19 3417.43 781.49 -500.90 928.22 0.00 0.00 0.00 0.00 3700.00 26.15 326.19 3507.20 818.11 -525.42 972.28 0.00 0.00 0.00 0.00 3800.00 26.15 326.19 3596.96 854.73 -549.95 1016.35 0.00 0.00 0.00 0.00 3900.00 26.15 326.19 3686.73 891.35 -574.47 1060.42 0.00 0.00 0.00 0.00 3956.52 26.15 326.19 3737,48 912.04 -588.27 1085.29 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/2012001 Time: 06:37:58 Page: 3 Field: Prudhoe Bay Co-erdinate(NE) Reference: Well: Plan L-116, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-116 Section (VS) Reference: Well (0.00E,0.00N,326.97Azi) Wellpath: Plan L-116 Plan: L-116 WP02 Section 7: Start MD Incl Azim TVD +N]-S +EI-W VS DLS Build Turn TFO ft deg deg ff ft ft ft deg/100ft degll00ft deg/100ft deg 4000.00 25.28 326.19 3776.65 927.72 -598.77 1104.16 2.00 -2.00 0.00 180.00 4100.00 23.28 326.19 3867.80 961.88 -621.65 1145.27 2.00 -2.00 0.00 180.00 4200.00 21.28 326.19 3960.33 993.38 -642.74 1183.18 2.00 -2.00 0.00 180.00 4300.00 19.28 326.19 4054.13 1022.18 -662.03 1217.84 2.00 -2.00 0.00 180.00 4400.00 17.28 326.19 4149.08 1048.24 -679.48 1249.20 2.00 -2.00 0.00 180.00 4500.00 15.28 326.19 4245.06 1071.53 -695.08 1277.23 2.00 -2.00 0.00 180.00 4600.00 13.28 326.19 4341.97 1092.03 -708.81 1301.89 2.00 -2.00 0.00 180.00 4700.00 11.28 326.19 4439.67 1109.70 -720.64 1323,16 2.00 -2.00 0.00 180.00 4800.00 9.28 326.19 4538.06 1124.53 -730.57 1341.00 2.00 -2.00 0.00 180.00 4900.00 7.28 326.19 4637.02 1136.49 -738.58 1355.40 2.00 -2.00 0.00 180.00 5000.00 5.28 326.19 4736.41 1145.58 -744.67 1366.34 2.00 -2.00 0.00 180.00 5100.00 3.28 326.19 4836.13 1151.78 -748.82 1373.80 2.00 -2.00 0.00 180.00 5200.00 1.28 326.19 4936.04 1155.09 -751.04 1377.78 2.00 -2.00 0.00 180.00 5263.96 0.00 326.19 5000.00 1155.67 -751.41 1378.47 2.00 -2.00 0.00 180.00 Section 8: Start 5300.00 0.00 326.19 5036.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 5400.00 0.00 326.19 5136.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 5500.00 0.00 326.19 5236.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 5600.00 0.00 326,19 5336.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 5700,00 0.00 326.19 5436.04 1155,67 -751.41 1378.47 0.00 0.00 0.00 326.19 5800.00 0.00 326.19 5536.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 5900.00 0.00 326.19 5636.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6000.00 0.00 326.19 5736.04 1155.67 -751.41 1378.47 0,00 0.00 0.00 326.19 6100.00 0.00 326.19 5836.04 1155.67 -751.41 1378.47 0.00 0,00 0.00 326.19 6200.00 0.00 326.19 5936.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6300.00 0.00 326.19 6036.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6400.00 0.00 326.19 6136.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6500.00 0.00 326.19 6236.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326,19 6600.00 0.00 326.19 6336.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6655.96 0.00 326.19 6392.00 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 Section 9: Start '1 6700.00 0.00 326.19 6436.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6800.00 0.00 326.19 6536.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 6900.00 0.00 326.19 6636.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 7000.00 0.00 326.19 6736.04 1155.67 -751.41 1378.47 0.00 0.00 0.00 326.19 ~05.9:96 .......... 0:00 ....... 326:!_9 ........ 6796:0.0 ............ !.! ~5:.67. ........... ?.5.!.:.4.! !_3.7._8:4_Z .................. 0_:_.0_0_ ............. 0_:.00. ................ 0.:.00 ......... 326.:_! ? Section 10: Start ',:: 'MD, = =Incl 7100.00 0.00 7209.96 0.00 326.19 6836,04 1155.67 -751.41 1378.47 0,00 0.00 0.00 326.19 326.19 6946.00 1155.67 -751.41 1378,47 0.00 0.00 0.00 326.19 Survey 77.00 0.00 320.57 77.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W 100.00 0.00 320.57 100.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W 200.00 0.00 320.57 200.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W 300.00 0.00 320.57 300.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W 400.00 0.00 320.57 400.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W 450.00 0.00 320.57 450.00 0.00 0.00 5978092.83 583174.09 70 21 0.428 N 149 19 29.005 W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/20/2001 Time: 06:37:58 Page: 4 Field: Prudhoe Bay Coordinate(NE) Reference: Well: Plan L-116, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-116 Section (rS)Reference: Well (0.00E,0.00N,326.97Azi) Wellpatb: Plan L-116 Plan: L-116 WP02 Survey Map Map <-- Latitude --> <-- Longitude --> MD Incl Azim TVD +N/-S +F_d-W Northing Easting Deg Min Sec Deg Min Sec ft deg de9 ft ft ~t ft ft 500.00 0.50 345.00 500.00 0.21 -0.06 5978093.04 583174,04 70 21 0.430 N 149 19 29.007 W 600.00 1.50 345.00 599.98 1.90 -0.51 5978094.72 583173.57 70 21 0.446 N 149 19 29.020 W 700.00 2.50 345.00 699.92 5.27 -1.41 5978098.08 583172.62 70 21 0.480 N 149 19 29.047 W 800.00 3.50 345.00 799.78 10.32 -2.77 5978103.12 583171.21 70 21 0.529 N 149 19 29.086 W 900.00 4.50 345.00 899,54 17.06 -4.57 5978109.84 583169.33 70 21 0.596 N 149 19 29.139 W 950.00 5.00 345.00 949.37 21.06 -5.64 5978113.82 583168.22 70 21 0.635 N 149 19 29.170 W 1000.00 5.68 341.66 999.15 25.51 -6.98 5978118.26 583166.83 70 21 0.679 N 149 19 29.209 W 1100.00 7.09 336.95 1098.53 35.89 -10.96 5978128.59 583162.74 70 21 0.781 N 149 19 29.326 W 1200.00 8.53 333.81 1197.60 48.23 -16.65 5978140.86 583156.92 70 21 0.902 N 149 19 29.492 W 1300.00 9.98 331.57 1296.30 62.50 -24.05 5978155.06 583149.36 70 21 1.043 N 149 19 29.708W 1400.00 11.45 329.90 1394.55 78.72 -33.15 5978171.17 583140.07 70 21 1.202 N 149 19 29.974W 1500.00 12.93 328.60 1492.29 96.85 -43.96 5978189.18 583129.07 70 21 1.380 N 149 19 30.290W 1600.00 14.41 327.57 1589.46 116.90 -56.46 5978209.09 583116.35 70 21 1.578 N 149 19 30.655W 1700.00 15.89 326.73 1685.98 138.85 -70.64 5978230.87 583101.92 70 21 1.793 N 149 19 31.070W 1774.63 17.00 326.19 1757.55 156.46 -82.32 5978248.35 583090.05 70 21 1.967 N 149 19 31.411 W 1800.00 17.00 326.19 1781.81 162.62 -86.45 5978254.47 583085.86 70 21 2.027 N 149 19 31.532W 1900.00 17.00 326.19 1877.44 186.92 -102.72 5978278.58 583069.32 70 21 2.266 N 149 19 32.007W 1975.87 17.00 326.19 1950.00 205.35 -115.06 5978296.87 583056.77 70 21 2.447 N 149 19 32.368W 2000.00 17.72 326.19 1973.03 211.33 -119.07 5978302.81 583052.70 70 21 2.506 N 149 19 32.485W 2100.00 20.72 326.19 2067.44 238.69 -137.39 5978329.95 583034.08 70 21 2.775 N 149 19 33.021 W 2200.00 23.72 326.19 2160.00 270.11 -158.43 5978361.14 583012.69 70 21 3.084 N 149 19 33.636W 2280.83 26.15 326.19 2233.29 298.42 -177.39 5978389.23 582993.42 70 21 3.363 N 149 19 34.190W 2300.00 26.15 326.19 2250.50 305.44 -182.09 5978396.20 582988.64 70 21 3.432 N 149 19 34.327W 2400.00 26.15 326.19 2340.26 342.06 -206.61 5978432.54 582963.71 70 21 3.792 N 149 19 35.044W 2500.00 26.15 326.19 2430.03 378.68 -231.14 5978468.88 582938.79 70 21 4.152 N 149 19 35.761 W 2600.00 26.15 326.19 2519.79 415.30 -255.66 5978505.22 582913.86 70 21 4.512 N 149 19 36.477W 2700.00 26.15 326.19 2609.56 451.92 -280.19 5978541.57 582888.94 70 21 4.872 N 149 19 37.194W 2800.00 26.15 326.19 2699.32 488.54 -304.71 5978577.91 582864.01 70 21 5.232 N 149 19 37.911 W 2900.00 26.15 326.19 2789.08 525.15 -329.23 5978614.25 582839.08 70 21 5.593 N 149 19 38.628W 3000.00 26.15 326.19 2878.85 561.77 -353.76 5978650.59 582814.16 70 21 5.953 N 149 19 39.345W 3100.00 26.15 326.19 2968.61 598.39 -378.28 5978686.93 582789.23 70 21 6.313 N 149 19 40.061 W 3200.00 26.15 326.19 3058.38 635.01 -402.80 5978723.27 582764.30 70 21 6.673 N 149 19 40.778W 3300.00 26.15 326.19 3148.14 671.63 -427.33 5978759.61 582739.38 70 21 7.033 N 149 19 41.495W 3400.00 26.15 326.19 3237.91 708.25 -451.85 5978795.95 582714.45 70 21 7.393 N 149 19 42.212W 3500.00 26.15 326.19 3327.67 744.87 -476.37 5978832.30 582689.53 70 21 7.753 N 149 19 42.929W 3600.00 26.15 326.19 3417.43 781.49 -500.90 5978868.64 582664.60 70 21 8.113 N 149 19 43.645W 3700.00 26.15 326.19 3507.20 818.11 -525.42 5978904.98 582639.67 70 21 8.474 N 149 19 44.362W 3800.00 26.15 326.19 3596.96 854.73 -549.95 5978941.32 582614.75 70 21 8.834 N 149 19 45.079W 3900.00 26.15 326.19 3686.73 891.35 -574.47 5978977.66 582589.82 70 21 9.194 N 149 19 45.796W 3956.52 26.15 326.19 3737.48 912.04 -588.27 5978998.20 582575.79 70 21 9.397 N 149 19 46.199W 4000.00 25.28 326.19 3776.65 927.72 -598.77 5979013.76 582565.12 70 21 9.552 N 149 19 46.506W 4100.00 23.28 326.19 3867.80 961.88 -621.65 5979047.66 582541.87 70 21 9.888 N 149 19 47.175W 4200.00 21.28 326.19 3960.33 993.38 -642.74 5979078.92 582520.42 70 21 10.197 N 149 19 47.792W 4300.00 19.28 326.19 4054.13 1022.18 -662.03 5979107.50 582500.82 70 21 10.481 N 149 19 48.355W 4400.00 17.28 326.19 4149.08 1048.24 -679.48 5979133.37 582483.08 70 21 10.737 N 149 19 48.866W 4500.00 15.28 326.19 4245.06 1071.53 -695.08 5979156.48 582467.23 70 21 10.966 N 149 19 49.322W 4600.00 13.28 326.19 4341.97 1092.03 -708.81 5979176.82 582453.28 70 21 11.167 N 149 19 49.723W 4700.00 11.28 326.19 4439.67 1109.70 -720.64 5979194.36 582441.25 70 21 11.341 N 149 19 50.069W 4800.00 9.28 326.19 4538.06 1124.53 -730.57 5979209.07 582431.16 70 21 11.487 N 149 19 50.359W 4900.00 7.28 326.19 4637.02 1136.49 -738.58 5979220.95 582423.01 70 21 11.605 N 149 19 50.593W 5000.00 5.28 326.19 4736.41 1145.58 -744.67 5979229.97 582416.82 70 21 11.694 N 149 19 50.771 W 5100.00 3.28 326.19 4836.13 1151.78 -748.82 5979236.12 582412.60 70 21 11.755 N 149 19 50.893W 5200.00 1.28 326.19 4936.04 1155.09 -751.04 5979239.40 582410.35 70 21 11.788 N 149 19 50.957W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/2012001 Time: 06:37:58 P~e: 5 Field: Prudhoe Bay Ce-erdr~ate(NE) Reference: Well: Plan L-116, True North Site: PB L Pad Vertical (T'~)) Reference: Temp Plan elevation 77 77.0 Well: Plan L-116 Section (VS) Reference: Well (0.00E,0.00N,326.97Azi) Wellpath: Plan L-116 Plan: L-116 WP02 Survey Map Map <~ Latitude --> <-- Longitude =-> MD Incl Azim TVD +N/-S +FJ-W Northing Easting Deg Min Sec Deg Min Sec ff deg deg fl ff ff ft ff 5263.96 0.00 326.19 5000.00 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5300.00 0.00 326.19 5036.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5400.00 0.00 326.19 5136.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5500.00 0.00 326.19 5236.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5600.00 0.00 326.19 5336.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5700.00 0.00 326.19 5436.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968 W 5800.00 0.00 326.19 5536.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 5900.00 0.00 326.19 5636.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6000.00 0.00 326.19 5736.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6100.00 0.00 326.19 5836.04 1155,67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6200.00 0.00 326.19 5936.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6300.00 0.00 326.19 6036.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6400.00 0.00 326.19 6136.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6500.00 0.00 326.19 6236.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6600.00 0.00 326.19 6336.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6655.96 0.00 326.19 6392.00 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6700.00 0.00 326.19 6436.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6800.00 0.00 326.19 6536.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 6900.00 0.00 326.19 6636.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 7000.00 0.00 326.19 6736.04 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 7059.96 0.00 326.19 6796.00 1155.67 -751.41 5979239.98 582409.97 70 21 11.793 N 149 19 50.968W 7100.00 0.00 326.19 6836.04 1155.67 -751.41 5979239,98 582409.97 70 21 11.793 N 149 19 50.968W 7209.96 0.00 326.19 6946.00 1155.67 -751.41 5979239,98 582409,97 70 21 11.793 N 149 19 50.968W Targets 64 -6O -4O -3 0 -2o f 10 --2O --30 24( --4O --5O 2 '~0 64 ~'rav~lling Cy!inder F]'om Colour To MD 0 -- 300 300 -- 600 600 -- 900 900 -- 1200 1200 1500 1500 ~--'-'-~ 2000 2000 ....... 2500 2500 -- 3000 00 3500 4500 -- 5500 )0 ~imuth (~'FO, ~Zi;) [d6g] ,~S C:entre (6 Ceni~e S~amtio~ [ 2()fi/i~] BP Amoco Anticollision Report Company: BP Amoco Date: 6/8/2001 Time: 10:52:35 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: Plan L-116, True North Reference Well: Plan L-116 Vertical (TVD) Reference: Temp Plan elevation 77 77.0 ~__R~_f~_r_e_~_ce Wellpath: Plan L-116 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ard~iE~i~e~ells in thili~i~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 77.00 to 7209.96 ft Scan Method: Trav Cylinder North Maximum Radius: 913.30 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/10/2001 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name 77.00 500.00 Planned: L-116 WP02 Vl CB-MAG-SS Camera based mag single shot 500.00 7209.96 Planned: L-116 WP02 V1 MWD MWD - Standard Casing Points ........... ~)---' ...... ;F-~'i~ ...... -~i~-m-~r-: ..... ft ft . in in 7209.95 6945.99 5.500 6.750 5 1/2" Summary ':=: - ' -: '~ '"? .... :'~ "V-~ ~ S ~-; ~'~ ~ ~, ~ ~'~ ....... -~ :~,"': ..... : ...... ~7 ~: -:~: - - ~...' ~ : :. - -~ ~.f.~ ; ~ ~.~-;- ~-i('~ --~ ~-~ ~:- ~V6 ~.--~ ~ ; ~ ~ ~' ~-V- ~ Site , Well ' :' Wellpath, , . ':MD: ~: ',~ ~ Distance'Area' ~:': Deviation :, Warning EX NWE#1 NWE1-01A NWE1-01AV4 399.93 400.00 271.30 10.17 261.13 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01 V3 399.93 400.00 271.28 10.17 261.12 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 1345.71 1325.00 198.57 26.05 173.03 Pass: Major Risk PB L Pad Plan L-01 Plan L-01 V9 Plan: L-0 622.70 625.00 85.90 15.50 70.40 Pass: Major Risk PB L Pad Plan L-01 Plan L-01a V5 Plan: L- 624.49 625.00 85.92 15.57 70.35 Pass: Major Risk PB L Pad Plan L-02 Plan L-02 V1 Plan: L-0 449.98 450.00 185.46 13.30 172.16 Pass: Major Risk PB L Pad Plan L-100 kwa Plan L-100 V0 Plan: L- 300.00 300.00 60.01 7.36 52.65 Pass: Major Risk PB L Pad Plan L-102 Plan L-102 V4 Plan: L- 449.98 450.00 251.97 13.07 238.90 Pass: Major Risk PB L Pad Plan L-103 Plan L-103 V1 Plan: L- 599.96 600.00 237.08 16.04 221.04 Pass: Major Risk PB L Pad Plan L-104 Plan L-104 V3 Plan: L- 698.81 700.00 221.11 15.87 205.25 Pass: Major Risk PB L Pad Plan L-105 Plan L-105 V5 Plan: L- 748.85 750.00 176.23 17.49 158.75 Pass: Major Risk PB L Pad Plan L-106 Plan L-106 V7 Plan: PI 950.00 950.00 190.78 19.92 170.85 Pass: Major Risk PB L Pad Plan L-107 Plan L-107 V6 Plan: L- 499.92 500.00 116.94 13.83 103.12 Pass: Major Risk PB L Pad Plan L-108 Plan L-108 V3 Plan: L- 1023.62 1025.00 160.39 19.73 140.66 Pass: Major Risk PB L Pad Plan L-109 Plan L-109 V3 Plan: L- 524.88 525.00 14.88 14.09 0.79 Pass: Major Risk PB L Pad Plan L-110 Plan L-110 V4 Plan: L- 474.96 475.00 31.50 13.20 18.30 Pass: Major Risk PB L Pad Plan L-111 Plan L-111 Vll Plan: L 724.77 725.00 30.81 17.22 13.59 Pass: Major Risk PB L Pad Plan L-112 Plan L-112 V2 Plan: L- 1562.10 1525.00 179.99 29.84 151.65 Pass: Major Risk PB L Pad Plan L-113 Plan L-113 V3 Plan: L- 1489.20 1475.00 143.12 27.22 115.90 Pass: Major Risk PB L Pad Plan L-114 Plan L-114 SWV6 Plan: 1251.81 1250.00 105.01 27.81 77.20 Pass: Major Risk PB L Pad Plan L-115 Plan L-115 V5 Plan: L- 750.22 750.00 61.06 21.63 39.44 Pass: Major Risk PB L Pad Plan L-117 Plan L-117 V4 Plan: L- 501.60 500.00 234.85 18.33 216.52 Pass: Major Risk PB L Pad Plan L-118 Plan L-118 V5 Plan: L- 449.98 450.00 253.74 13.39 240.35 Pass: Major Risk PB L Pad Plan L-119 Plan L-119 V5 Plan: L- 501.61 500.00 285.68 14.63 271.06 Pass: Major Risk Site: EX NWE#1 Well: NWE1-01A Rule Assigned: Major Risk Wellpath: NWE1-01A V4 Inter-Site Error: 0.00 ft Reference ' ,' Semi~MajorAxis , i~::= , : Ctr-Ctr No-Go Allowable 99.99 99.99 100.00 100.00 0.08 0.06 282.50 282.50 267.79 1.31 266.48 Pass 124.99 124.99 125.00 125.00 0.24 0.07 282.49 282.49 267.84 2.07 265.77 Pass 149.99 149.99 150.00 150.00 0.40 0.07 282.49 282.49 267.90 2.83 265.07 Pass 174.99 174.99 175.00 175.00 0.56 0.08 282.49 282.49 267.98 3.58 264.40 Pass 199.99 199.99 200.00 200.00 0.72 0.10 282.48 282.48 268.08 4.38 263.70 Pass 224.99 224.99 225.00 225.00 0.85 0.13 282.46 282.46 268.21 5.10 263.10 Pass 249.99 249.99 250.00 250.00 0.98 0.16 282.43 282.43 268.40 5.84 262.57 Pass 274.99 274.99 275.00 275.00 1.11 0.18 282.38 282.38 268.68 6.55 262.13 Pass 300.03 300.03 300.05 300.04 1.25 0.20 282.32 282.32 269.03 7.26 261.77 Pass 324.97 324.97 325.00 324.98 1.37 0.24 282.23 282.23 269.47 8.00 261.47 Pass TRA(,oMITAL LETTER CHECK LIST {~ CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 CHECK WHAT APPLIES DEVELOPMENT REDRILL EXPLORATI.ON INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR, DI~.S.I?OSAL (~,.~) NO ANNULAR DISPOSAL (,, ,) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION "CLUE" The permit is for a new wellbore segment of existing well ~, Permit No, ~ APl No. __. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates I..!191144 DATE I ~) CHECK NO. 6/04/01 0191144 VENDOR AI-ASKAO I LA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 060101 CK06010i 100. O0 100. O0 PYMT COMMENTS: PERMIT TO DRILL FEE HANDLINO INST: S/H - TERRIE HUBBLE X46P8 tHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. · ~ro] ~-~ ~ ] 100. O0 100. O0 BP EXPLORATION, (ALASKA)INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No. H 191144 CONSOLIDATED COMMERCIAL ACCOUNT 00191144 PAY To The ORDER De ONE':HUNDRED & ********************************************* US., DQLLAR 'i .::..DATE i::.:' AMOUNT 06:/0'~'/01 "::'" I, $100"00'::':':1' NOT:VALI£ DAYS SUITE 1OO ANCHORAOE AK 995:.01 II'~,q~,ihh,, m:Ohli~O~SqSm-' 008t, WELL PERMIT CHECKLIST , FIELD & POOL ADMINISTRATION DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. · · · 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... COMPANY ~,~/Z) NAME. ~"~//~::::~ PROGRAM: exp INIT CLASS ~ ?.--,~_,~ ~/ G ~L AREA Y N Y N Y N. Y N Y N Y N Y N dev ~ reddl serv. wellbore sag ann. disposal para req GEOLOGY 22. 23. 24. 25. 26. 27. 28. 29. 30. 31 32. 33. 34. APPR Adequate weilbore separation proposed. ' If diverter required, does it meet regulations .......... Drilling.fluid program schematic & equip list adequate.. ~ . . N BOPEs, do they meet regulation ....... ',,'~-c~ .... BOPE press rating appropriate; test to ~..,W, jLj Dsig. Choke manifold complieS w/APl RP-53 (May 84) ........ (~ N Work will occur without operation shutdown ........... Is presence of H2S gas probable ................ Permit can be issued wlo hydrogen sulfide measures ...... Y N ,/ Data presented on potential overpressure zones ....... Y !~ /~ ~,~// Seismic analysis of shallow gas zones ............. _Y~_. Seabed condition survey (if off-shore) ............. /Y N ' Contact name/phone for weekly progress reports [exploratory onl~,[ Y N UNIT# ///C, ~' o ON/OFF SHORE ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the Well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; .and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQGY: ENGINEERING: ' UlClAnnular COMMISSION: . . Comments/Instructions: c:~msoffice\wordian~diana\checklist (rev. 111011/00)