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Home My WebLink About197-196MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:6 Township:13N Range:10E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:21,780 ft MD Lease No.:ADL025509 Operator Rep:Suspend:X P&A: Conductor:20"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 9,544 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 21,749 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 20,886 Feet Tbg Cut@ 20,524 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bottom 20,886 ft 20,519 ft 8.34 ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing 2411 2367 2345 IA 2596 2553 2531 OA 80 84 79 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: MPU F-17 was a rotary sidetrack that got stuck in the window @ 20,866 ft MD and had cutoff BHA. Well has 4-1/2 " kill string to 9,079 ft MD. This is verification of reservoir abandonment cement plug. Tagged top of cement at 20,519 ft with 10K lbs down weight. September 29, 2025 Sully Sullivan Well Bore Plug & Abandonment MPU F-17 Hilcorp Alaska LLC PTD 1971960; Sundry 325-462 none Test Data: P Casing Removal: Josh Stephens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0929_Plug_Verification_MPU_F-17_ss                      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: Reservoir Plug 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21,780'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT F-17 MILNE POINT KUPARUK RIVER OIL N/A 7,734' 21,664' 7,725' 1,387 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Aug-25 Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355016 197-196 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22823-00-00 Hilcorp Alaska LLC C.O. 816 Proposed Pools: 112' 112' Drill Pipe TVD Burst 20,886' MD 4,607' 7,732' 9,544' 21,749' Length Size Ryan Lewis 74' 20' 9-5/8" 7" 9,508' 21,716' N/A 5,750psi 7,240psi ryan.lewis@hilcorp.com 303-906-5178 4-1/2" 12.6 / L-80 / IBT 19,119' See Schematic See Schematic 4-1/2" N/A and N/A N/A and N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:58 am, Aug 07, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.08.07 10:39:03 - 08'00' Taylor Wellman (2143) DSR-8/14/25MGR20AUG2025 * Service coil tag ( TOC ~ 20,355' MD) and pressure test (2000 psi) of reservoir cement abandonment plug. 10-404 325-462 A.Dewhurst 19AUG25JLC 8/20/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.20 14:29:22 -08'00'08/20/25 RBDMS JSB 082025 MPF-17 Res P&A Well Name:MPU F-17 API Number:50-029-22823-00-00 Current Status:Shut in Pad:F-Pad Estimated Start Date:August 2025 Rig:CTU Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts Permit to Drill Number:197-148 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:Job Type:Res P&A Current Bottom Hole Pressure: 1,799 psi @ 4,112’ TVD SBHPS (Taken on 7/28/25) | 8.2 MWE, 8.4 KWF MPSP:1,387 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 87° @ 21,460 MD | Greater than 70° at 4,000’ MD Max Dogleg:0.5°/100ft @ 19,849’ MD Brief Well Summary: MPU F-17 was a Rotary Sidetrack that got stuck in the window and we had to cut off the BHA, run a kill string and RDMO. A Reservoir P&A is required to complete the Operational SD. Objective: x Reservoir P&A the Kuparuk. Procedure: Coil 1. MIRU CTU (2.0” coil) and PT to 250 psi low / 2000 psi high. 2. Drift/tag fish at ~20,524’. Paint flag. 3. RIH with 2” coil to 20,500’ and circulate the hole clean. 4. Close in the backside and perform an injection test prior to pumping cement. 5. Plan to pump and spot cement 1 bbl from nozzle with choke open 6. Pump cement (13ppg FineCem) a. 5 bbl fresh water b. 5 bbl FineCem c. 5 bl fresh water behind 7. Displace cement down with choke open 8. Spot cement 1 bbl from nozzle, close choke and begin squeezing a. Squeeze pressures may exceed 4790psi and MM will need to be bypassed. 9. PU hole, circulate clean and POOH. 10. WOC 11. Notify AOGCC to witness cement tag. 12. RIH Tag cement, POOH. 13. RDMO. AOGCC witness pressure test of cement plug to 2000 psi. MPF-17 Res P&A Attachments: 1. Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised By RJL 1/21/2025 SCHEMATIC Milne Point Unit Well: MPU F-17 / F-17L1 Last Completed: 2/1/1998 PTD: 197-196 & 223-093 TD = 21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.60’/ GL Elev.: 12.70’(N27E) RT to Tbg. Spool = 31.64’ (N 27E) 7” 9-5/8” 1 FISH: BHA: Top @ 20,524 PBTD =21,664’ (MD) / PBTD = 7,725’(TVD) KUP Sands EST TOC @ 19,274’MD D shale Btm @20750’ MD FISH: BHA: Btm @ 20,886’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 21,749’ 0.0383 TUBING DETAIL 4-1/2" Kill String 12.6 / L-80 / IBT 3.958 Surface 9,119’ 0.0152 4-1/2" Drill Pipe N/A N/A 20,524’ 20,886 N/A JEWELRY DETAIL No Depth Item 1 9,079’ 4-1/2” WLEG –Btm @ 9,119’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A3 20,950’ 21,020’ 7,667’ 7,677’ 70 3-3/8” Open Kup. A2 21,080’ 21,540’ 7,685’ 7,717’ 460 3-3/8” Open Ref Log: Cement USIT-GR-CCLU 1-27-1998 / 3-3/8” Alpha Jet Charges OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 2,650 sx PF ‘E’, 1,100 sx Class ‘G’, 160 sx PF ‘E’ in a 12-1/4” Hole 7” 170 sx Class ‘G’, 185 sx Foamed ‘G’ in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 800’ / L1 20,884’ Max Hole Angle = 80° @ 7,900’ +70° 4,000’ to 20,000’ +80° 20,000 to 21,780 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tubing. Hanger, 4.5” NSCT top and bottom CIW 4” H BPV Profile GENERAL WELL INFO API: 50-029-22823-00-00 Drilled, Cased, Perfed & Completed by Nabors 27E - 2/1/98 Set 4-1/2” Model D Packer – 8/1/2000 DS Coil Tubing /Jet Pump – 9/12/2000 Set Baker IBT – 6/9/2009 L1: Doyon 14 Operations Shutdown 12/28/2023 _____________________________________________________________________________________ Revised By TDF 8/1/2025 PROPOSED Milne Point Unit Well: MPU F-17 / F-17L1 Last Completed: 2/1/1998 PTD: 197-196 & 223-093 TD =21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.:45.60’/ GL Elev.: 12.70’(N27E) RT to Tbg. Spool = 31.64’ (N 27E) 7” 9-5/8” 1 FISH: BHA: Top @ 20,524 PBTD =21,664’ (MD) / PBTD = 7,725’(TVD) KUP Sands EST TOC @ 19,274’MD Dshale Btm @20750’ MD FISH: BHA: Btm @ 20,886’ TOC @ ± 20,355’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 21,749’ 0.0383 TUBING DETAIL 4-1/2" Kill String 12.6 / L-80 / IBT 3.958 Surface 9,119’ 0.0152 4-1/2" Drill Pipe N/A N/A 20,524’ 20,886 N/A JEWELRY DETAIL No Depth Item 19,079’4-1/2” WLEG–Btm @ 9,119’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A3 20,950’ 21,020’ 7,667’ 7,677’ 70 3-3/8” Open Kup. A2 21,080’ 21,540’ 7,685’ 7,717’ 460 3-3/8” Open Ref Log: Cement USIT-GR-CCLU 1-27-1998 / 3-3/8” Alpha Jet Charges OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 2,650 sx PF ‘E’, 1,100 sx Class ‘G’, 160 sx PF ‘E’ in a 12-1/4” Hole 7” 170 sx Class ‘G’, 185 sx Foamed ‘G’ in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 800’ / L1 20,884’ Max Hole Angle = 80° @ 7,900’ +70° 4,000’ to 20,000’ +80° 20,000 to 21,780 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tubing. Hanger, 4.5” NSCT top and bottom CIW 4” H BPV Profile GENERAL WELL INFO API: 50-029-22823-00-00 Drilled, Cased, Perfed & Completed by Nabors 27E - 2/1/98 Set 4-1/2” Model D Packer –8/1/2000 DS Coil Tubing /Jet Pump –9/12/2000 Set Baker IBT –6/9/2009 L1: Doyon 14 Operations Shutdown 12/28/2023 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, 19 August, 2025 11:39 To:Ryan Lewis; Joseph Lastufka Cc:Rixse, Melvin G (OGC); Guhl, Meredith D (OGC) Subject:RE: MPU F-17 Suspension Sundry (325-462): Question Ryan, Understood. It appears that you only made ~2’ of new hole. Then to keep the record simple and clear, I suggest that we not create a separate record for the attempted L1 lateral: x cancel the L1 PTD (223-093 ) with our permitting email address x record the activity of the kickoƯ attempt, stuck BHA, and future reservoir abandonment activity (this sundry) on the suspension 10-407 for this F-17 (197-196) wellbore; no need to create a separate 10-407 for the L1 x We will proceed with this sundry If you have any questions, let me know. Thanks, Andy From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Tuesday, 19 August, 2025 09:37 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU F-17 Suspension Sundry (325-462): Question The plan is to Reservoir abandon F-17L1. We are not planning to make another attempt. Thanks, RL From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Friday, August 15, 2025 11:22 AM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] MPU F-17 Suspension Sundry (325-462): Question Ryan, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 I’m reviewing the MPU F-17 sundry for a reservoir plug and suspension and have a question for you. What are your intentions for the F-17L1 well? Are you planning on making another attempt in the near future (I couldn’t tell as there is no estimated date on this sundry)? I ask because the PTD 223-093 was classiƱed as a L1 “lateral” because the parent wellbore hadn’t been plugged. After the proposed work in this sundry, that will change. If you drill the L1 well, it won’t actually be a lateral anymore, it would be a normal “redrill”. That would necessitate a diƯerent API number and likely name change (to F-17A or such). If this is the plan, then we will need to do a series of changes which I can explain later. If you want to suspend the well only and do not plan on redrilling it soon, then we can proceed with the sundry. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 01/02/24 Monty M Myers By Grace Christianson at 12:36 pm, Jan 03, 2024 DSR-1/26/24WCB 2024-07-02 RBDMS JSB 010324 _____________________________________________________________________________________ Created By: JNL 12/28/2023 Operations Shutdown Milne Point Unit Well: MPU F-17 / F-17L1 Last Completed: 8/1/2000 PTD: 197-196 / 223-093 OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset (Approx.) 12-1/4" 2650 sx PF E, 110 sx Class G, 160 sx PF E 7-5/8” 170 sx Class G, 185 sx Class G CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 7" Production 26 / L-80 / BTC-Mod 6.151 Surface 21,749’ TUBING DETAIL 4-1/2” Killstring Surface 9,100’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status F-17: Kuparuk 20,950’ 21,020’ 7,668’ 7,678’ 70’ 3-3/8” Closed F-17: Kuparuk 21,080’ 21,540’ 7,685’ 7,717’ 460’ 3-3/8” Closed TD =21,781’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.6/ GL Elev.: 12.7’ 7” 5 4 1 9-5/8” 2 3 4-1/2” Killstring PBTD =20,884’(MD) / PBTD = 7,657’(TVD) L1PBTD =20,919’(MD) /L1 PBTD =7,663’(TVD) L1 TD = 20,919’ (MD) / L1TD = 7,663’ (TVD) TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tbg hgr, 4.5” NSCT top & btm CIW 4” H BPV profile JEWELRY DETAIL No Depth Item 1 20,528’ Fish: Tricone Bit, Motor, MWD, GR, 4” Drillpipe 2 20,884’ Whipstock 3 20,906’ CIBP 4 20,911’ Whipstock 5 20,925’ CIBP WELL INCLINATION DETAIL KOP @ 744’ / L1 KOP @ 20,884’ Max Hole Angle = 80 deg @ 7900’, +70 deg 4,000 – 20,000, +80 from 20,000 to TD GENERAL WELL INFO API: 50-029-22823-00-00 / L1: 50-029-22823-60-00 Drilled, Cased & Completed: 8/1/2000 L1: Doyon 14 Operations Shutdown 12/28/2023 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Jay Murphy - (C) Cc:Regg, James B (OGC) Subject:RE: Doyon 14 12-14-23 Date:Tuesday, January 23, 2024 1:50:20 PM Attachments:Doyon 14 12-14-23 Revised.xlsx Jay, Attached is a revised report adding the missing PTD # 1971960. I also changed the misc. fields to “NA”. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Jay Murphy - (C) <Jay.Murphy@hilcorp.com> Sent: Friday, December 15, 2023 6:10 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Doyon 14 12-14-23 Thank You and Best Regards, Jay Murphy/ DSM Hilcorp Alaska, LLC Doyon Rig 14 Office: 907-670-3090 Doghouse: 907-670-3092 Cell: 907-715-9211 Jay.Murphy@Hilcorp.com 0LOQH3RLQW8QLW) 37' revised report missing PTD # 1971960 hanged the misc. fields to “NA” The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:14 DATE: 12/14/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1971960 Sundry #323-554 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1900 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 N/A NA Trip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"X5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" X 5000 P Time/Pressure Test Result HCR Valves 2 3-1/8" X 5000 P System Pressure (psi)2950 P Kill Line Valves 2 3-1/8" X 5000 P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)41 P BOP Misc 0NAFull Pressure Attained (sec)180 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1963 P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 16 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/12/23 08:24 Waived By Test Start Date/Time:12/14/2023 6:00 (date) (time)Witness Test Finish Date/Time:12/14/2023 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Doyon Test Annular with 4" test joint to 250/2500 psi. All other tests performed to 250/4000 psi. Test lower & upper rams w/ 4" & 4-1/2" test joints. Test H2S and LEL gas alarms. Test PVT- gain/ loss and flow paddle. Waived at 12/13/23 at 14:48 hours. J. Hansen / J. Charlie Hilcorp J. Murphy / J. Vanderpool MPU F-17 Test Pressure (psi): rig14@doyondrilling.com skaNS-Doyon14-DSMs@hilcorp.c Form 10-424 (Revised 08/2022) 2023-1214_BOP_Doyon14_MPU_F-17 +LOFRUS$ODVND//& 9 9 9 999 9 9 9 9 9 -5HJJ 9 MEU CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Doug Yessak - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Nathan Sperry; Alaska NS - Doyon 14 - DSMs Subject:Doyon 14 BOP 12-7-2023 Date:Thursday, December 7, 2023 10:59:29 AM Attachments:Doyon 14 BOP_ MPU F-17_12-7-23.xlsx Doug Yessak Hilcorp DSM Doyon 14 907-670-3090 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW) 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:14 DATE: 12/7/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1971960 Sundry #323-554 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1900 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.P Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 N/A NA Trip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"X5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" X 5000 P Time/Pressure Test Result HCR Valves 2 3-1/8" X 5000 P System Pressure (psi)2975 P Kill Line Valves 2 3-1/8" X 5000 P Pressure After Closure (psi)1675 P Check Valve 0NA200 psi Attained (sec)47 P BOP Misc 1 see remarks FP Full Pressure Attained (sec)188 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1975psi P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 16 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:6.5 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12-4-23 18:08 Waived By Test Start Date/Time:12/6/2023 19:00 (date) (time)Witness Test Finish Date/Time:12/7/2023 1:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Doyon Test Annular with 4" test joint to 250/2500 psi. All other tests performed to 250/4000 psi. Test lower & upper rams w/ 4" & 4-1/2" test joints. Test H2S and LEL gas alarms. Test PVT- gain/ loss and flow paddle. F/P 13-5/8" x 11" spacer spool flange leak, Bled off & tightened and tested good J Hansen / N Hamilton Hilcorp D Yessak / J Vanderpool MPU F-17 Test Pressure (psi): rig14@doyondrilling.com skaNS-Doyon14-DSMs@hilcorp.c Form 10-424 (Revised 08/2022) 2023-1207_BOP_Doyon14_MPU_F-17 9 9 9 9 9 9 9 9 9 9 9 -5HJJ FP spacer spool flange leak CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Doug Yessak - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Nathan Sperry; Alaska NS - Doyon 14 - DSMs Subject:Doyon 14 BOP 11-29-2023 Date:Wednesday, November 29, 2023 7:24:08 PM Attachments:Doyon 14 BOP_ MPU F-17_11-29-23.xlsx Doug Yessak Hilcorp DSM Doyon 14 907-670-3090 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW) 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:14 DATE: 11/29/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11971960 Sundry #323554 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1900 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.P Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 N/A NA Trip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"X5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" X 5000 P Time/Pressure Test Result HCR Valves 2 3-1/8" X 5000 P System Pressure (psi)3000 P Kill Line Valves 2 3-1/8" X 5000 P Pressure After Closure (psi)1700 P Check Valve 0NA200 psi Attained (sec)44 P BOP Misc 0NAFull Pressure Attained (sec)187 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1938psi P No. Valves 14 P ACC Misc 0NA Manual Chokes 1FP Hydraulic Chokes 1FP Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 17 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:14.5 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11-27-23 06:56 Waived By Test Start Date/Time:11/29/2023 0:00 (date) (time)Witness Test Finish Date/Time:11/29/2023 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Doyon Test Annular with 4" test joint to 250/2500 psi. All other tests performed to 250/4000 psi. Test lower & upper rams w/ 4" & 4- 1/2" test joints. Test H2S and LEL gas alarms. Test PVT- gain/ loss and flow paddle. All test performed against BPV w/ CTS plug. FP on Manual and Hydraulic choke valves. Rebuild both, test good O. Williams / J. Charlie Hilcorp J. Murphy / I. Toomey MPU F-17 Test Pressure (psi): rig14@doyondrilling.com skaNS-Doyon14-DSMs@hilcorp.c Form 10-424 (Revised 08/2022) 2023-1129_BOP_Doyon14_MPU_F-17 99 9 9 9 999 9 9 9 MEU 9 9 9 -5HJJ FP FP jg FP on Manual and Hydraulic choke valves Drilling Manager 10/05/23 Monty M Myers By Grace Christianson at 3:19 pm, Oct 05, 2023 MGR12OCT23 10-407 BOPE test to 3500 psi. Annular to 2500 psi. SFD 10/5/2023 SFD DSR-10/5/23*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.10.17 13:02:58 -06'00' RBDMS JSB 101723 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Cut Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Mill and Push Packer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 21,780 feet N/A feet true vertical 7,734 feet 19,526 feet Effective Depth measured 21,664 feet 19,522 feet true vertical 7,725 feet 7,376 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / IBT 19,548' 7,383' Packers and SSSV (type, measured and true vertical depth)7" x 4-1/2" Baker S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 323-356 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Taylor Wellman twellman@hilcorp.com 907-777-8449 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 50 Size 112' 4,607' 0500 0 00 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-196 50-029-22823-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0355016, ADL0355017 & ADL0355018 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT F-17 Plugs Junk measured LengthCasing Conductor 21,716' 9,544'Surface Production 20' 9-5/8" 7" 74' 9,508'5,750psi 7,240psi21,749' 7,732' Burst N/A Collapse N/A 3,090psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.31 08:57:29 - 08'00' Taylor Wellman (2143) By Grace Christianson at 9:55 am, Aug 31, 2023 WCB 4-9-2024 DSR-8/31/23 RBDMS JSB 083123 _____________________________________________________________________________________ Revised By TDF 8/30/2023 SCHEMATIC Milne Point Unit Well: MPU F-17 Last Completed: 2/1/1998 PTD: 197-196 TD =21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.60’/ GL Elev.: 12.70’ (N27E) RT to Tbg. Spool = 31.64’ (N 27E) 7” 9-5/8” 1 Tubing Cut @ 19,516’ on 7/8/2023 PBTD=21,664’ (MD) / PBTD = 7,725’(TVD) KUP Sands 2 4 3 FISH: Top of Milled DB Packer pushed to 19,525.5’ on 7/3/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 21,749’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / IBT-Mod 3.958 Surface 19,548’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,219’ HES X-Nipple – 3.813” ID 2 19,522’ 7” x 4-1/2” Baker S-3 Packer 3 19,536’ 4-1/2” HES XN-Nipple – 3.725” ID 4 19,547’ 4-1/2” WLEG –Btm @ 19,548’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A3 20,950’ 21,020’ 7,667’ 7,677’ 70 3-3/8” Open Kup. A2 21,080’ 21,540’ 7,685’ 7,717’ 460 3-3/8” Open Ref Log: Cement USIT-GR-CCLU 1-27-1998 / 3-3/8” Alpha Jet Charges OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 2,650 sx PF ‘E’, 1,100 sx Class ‘G’, 160 sx PF ‘E’ in a 12-1/4” Hole 7” 170 sx Class ‘G’, 185 sx Foamed ‘G’ in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 800’ Max Hole Angle = 80° @ 7,900’ +70° 4,000’ to 20,000’ +80° 20,000 to 21,780 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tubing. Hanger, 4.5” NSCT top and bottom CIW 4” H BPV Profile GENERAL WELL INFO API: 50-029-22823-00-00 Drilled, Cased, Perfed & Completed by Nabors 27E - 2/1/98 Set 4-1/2” Model D Packer – 8/1/2000 DS Coil Tubing /Jet Pump – 9/12/2000 Set Baker IBT – 6/9/2009 Well Name Rig API Number Well Permit Number Start Date End Date MP F-17 CTU#2 50-029-22823-00-00 197-196 7/2/2023 7/9/2023 6/30/2023 - Friday No operations to report. 6/28/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/29/2023 - Thursday No operations to report. Continue BOP testing. MU & RIH w/ BOT Venturi BHA with 3.66" shoe. Venturi from 13,500' CTMD down to top of DB packer reciprocating across each weight bobble as well as across the heel. Recover 1-2 cups of fine metal shavings with no larger pieces. Make up RBP setting BHA and tag at 3734' CTMD, right at the heel. Unable to work past, POOH. Make up FCO BHA with 3.25" JSN and RIH. Drift very clean to TD. Chase out of hole pumping max rate with frequent powervis sweeps. No operations to report. 7/1/2023 - Saturday Continue RIH w/ HES GR/CCL logging tools w/ 3.66" venturi & muleshoe on bottom. Venturi from 13,787' CTMD to 19,533' CTMD. Tag fish(packer)/XN Nipple @ 19,533' CTMD - Venturi across RBP set depth. RBIH. Tag fish(packer)/XN Nipple @ 19,533' CTMD. Park for 5 minutes. Log up from compression. Paint Red flag at 19,450.35'. Top of logging interval @ 19,000.48''. POOH and encounter multiple overpulls 14,400-15,600'. Attempt to venturi, but unable to clear. POOH. Venturi recovered 1 gallon of fine metal cuttings and rubber strips from packer element, venturi screen plugged off. Confirm -8' correction, top of milled DB Packer at 19525.5'. Make up Venturi BHA with 3.66" shoe and RIH. Venturi from 13800 down to top of DB packer reciprocating across each weight bobble. POOH clean and recip from 13750 to 15100 - still had 3 sticky spots. POOH. Venturi completely packed off - returned 1/2 gallon fine metal cutting, one ~6" metal band, and ~12 big chunks of metal (slips/shear ring). BOP test. 7/4/2023 - Tuesday 7/2/2023 - Sunday PT down to disco of 300/3500. Make up Packer Milling BHA with 3.75" nose mill. Tag Packer at 14503' CTMD. Time mill until released and push downhole. Push to 19527' CTMD and tag XN Nipple. POOH. BD Packer Milling BHA. MU & RIH w/ HES GR/CCL logging tools w/ 3.66" venturi & mule shoe on bottom. 7/3/2023 - Monday Make up Packer Milling BHA with 3.75" nose mill. Tag Packer at 14503' CTMD. Time mill until released and push downhole. Push to 19527' CTMD and tag XN Nipple. POOH top of milled DB Packer at 19525.5'. Well Name Rig API Number Well Permit Number Start Date End Date MP F-17 CTU#2 / Fullbore 50-029-22823-00-00 197-196 7/2/2023 7/9/2023 7/7/2023 - Friday Continue RIH with 2.78" Hydraulic JDC to retrieve IBP. Correct depth at flag and then tag IBP at 19490. Begin fishing. Could not get a latch. POOH to reconfigure tools. RIH with 3.625" Hydraulic JDC. Correct depth at flag. Latch the IBP at 19490'. POOH. Recovered IBP, all intact. 7/5/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continued slowly RBIH while waiting on replacement belt from LRS shop in Prudhoe. FCO to surface. Make up Baker 4.5" RBP and RIH. Set down and 8524'. Shear off and left plug in hole. Attempted to pressure test the IA. Failed. Lost 195 psi in 60 mins.Make up Fishing BHA and recovered RBP from 8524' ctm. RBP completely intact. Stand by for 2.5" IBP. 7/6/2023 - Thursday Make up and RIH with 2.5" IBP. Correct depth at flag. Set IBP at 19490'. CMIT TxIA PASSED to 2554 psi. RIH with 2.78" Hydraulic JDC to retrieve IBP. No operations to report. RIH with BOT mechanical tubing cutter. RIH and tag top of milled up DB packer and correct depth. Pull up and postion cutter. Bring pump online and set anchor. Slack off and cut pipe at 19516.3'. Took ~63 mins to get good indication cut made with IA response. Drop 3/4" ball and pump circ sub, POOH. Freeze protect tubing with 48 bbls of diesel. RDMO 7/8/2023 - Saturday No operations to report. 7/11/2023 - Tuesday 7/9/2023 - Sunday Pumped down IA to confirm Tubing cut and communication TxIA 7/10/2023 - Monday RIH with BOT mechanical tubing cutter. RIH and tag top of milled up DB packer and correct depth. Pull up and postion cutter. Bring pump online and set anchor. Slack off and cut pipe at 19516.3'. Took ~63 mins to get good indication cut made with IA response. Drop 3/4" ball and pump circ sub, POOH. Milne Point Unit (MPU) F-17 Sundry Program Version 1 August 1, 2023 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program ....................................................................................................................... 4 4.0 Drill Pipe Information ............................................................................................................... 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Wellbore Schematics .................................................................................................................. 6 7.0 Drilling / Completion Summary ................................................................................................ 9 8.0 Mandatory Regulatory Compliance / Notifications ................................................................ 10 9.0 R/U and Test BOPE ................................................................................................................. 12 10.0 Pull 4-1/2” Tubing, Mill Packer............................................................................................... 14 11.0 Mill 6-1/8” Window and Kick Off ........................................................................................... 15 12.0 Doyon 14 BOP Schematic ........................................................................................................ 18 13.0 Wellhead Schematic ................................................................................................................. 19 14.0 Days Vs Depth .......................................................................................................................... 20 15.0 Formation Tops & Information............................................................................................... 21 16.0 Anticipated Drilling Hazards .................................................................................................. 22 17.0 Doyon 14 Layout ...................................................................................................................... 24 18.0 FIT Procedure .......................................................................................................................... 25 19.0 Doyon 14 Choke Manifold Schematic ..................................................................................... 26 20.0 6-1/8” Hole Section MASP ....................................................................................................... 27 21.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 28 22.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 29 Page 2 Milne Point Unit F-17L1 Drilling Procedure 1.0 Well Summary Well MPU F-17L1 Pad Milne Point “F” Pad Planned Completion Type 4-1/2” Pre-Drilled Liner Target Reservoir(s) Kuparuk A Planned Well TD, MD / TVD 31,272’ MD / 8,139’ TVD PBTD, MD / TVD 31,272 MD / 8,139’ TVD Surface Location (Governmental) 1809' FSL, 2429' FWL, Sec 6, T13N, R10E, UM, AK Surface Location (NAD 27 –Zone 4) X=541,834 Y=6,035,260 Top of Productive Horizon (Governmental) 2509' FNL, 1858' FEL, Sec 32, T14N, R10E, UM, AK TPH Location (NAD 27) X=545,718, Y=6,052,356 BHL (Governmental) 2570' FNL, 1562' FEL, Sec 8, T14N, R10E, UM, AK BHL (NAD 27) X=548,021, Y=6,062,596 AFE Drilling Days 26 Days AFE Completion Days 5 Days Maximum Anticipated Pressure (Surface) 1,900 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2,666 psi (6.7ppg EMW) Work String 4” 14# S-135 XT-39 KB Elevation above MSL: 33.7 ft + 12.7 ft = 46.4 ft GL Elevation above MSL: 12.7 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit F-17L1 Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit F-17L1 Drilling Procedure 3.0 Tubular Program Hole Section OD (in) ID (in)Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) 6-1/8” 4-1/2” 3.92 3.795 4.714 13.5 L-80 H625 9,020 8,540 279 4.0 Drill Pipe Information Hole Section OD (in) ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension** (k-lbs) Production 4” 3.34” 2.563”4.875”14 S-135 XT39 18,500 22,200* 446 **Assumes 1.0 friction factor pipe dope *Tension Rating Based on Premium Pipe All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit F-17L1 Drilling Procedure 5.0 Internal Reporting Requirements Fill out daily drilling report and cost report on Wellez. Report covers operations from 6am to 6am Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. Ensure time entry adds up to 24 hours total. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. Enter the MD and TVD depths EVERY DAY whether you are making hole or not. Afternoon Updates Submit a short operations update each work day to mmyers@hilcorp.com, nathan.sperry@hilcorp.com,jengel@hilcorp.com and joseph.lastufka@hilcorp.com Intranet Home Page Morning Update Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. EHS Incident Reporting Health and safety: Notify EHS field coordinator. Environmental: Drilling Environmental coordinator Notify Drlg Manager & Drlg Engineer Submit Hilcorp Incident report to contacts above within 24 hrs Casing Tally Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com Casing and Cement report Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Drilling Engineer Nathan Sperry 907.777.8450 907.301.8996 nathan.sperry@hilcorp.com Operations Engineer Taylor Wellman 907.777.8449 907.947.9533 twellman@hilcorp.com Geologist Graham Emerson 907.564.5242 907.793.0315 Graham.emerson@hilcorp.com Reservoir Engineer Alan Abel 907.564.5032 Alan.abel@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com Safety Manager Laura Green 907.777.8314 907.342.7511 lagreen@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com Page 6 Milne Point Unit F-17L1 Drilling Procedure 6.0 Wellbore Schematics Page 7 Milne Point Unit F-17L1 Drilling Procedure Page 8 Milne Point Unit F-17L1 Drilling Procedure Page 9 Milne Point Unit F-17L1 Drilling Procedure 7.0 Drilling / Completion Summary MPU F-17L1 is a sidetrack injection well targeting the Kuparuk River Pool, located on Milne Point ‘F-pad’. The directional plan is a single string horizontal well with the kick off point at 20,907’ MD. Maximum hole angle is ~91 degrees. Drilling operations are expected to commence approximately November15th, 2023, pending rig schedule. Production liner will be 4-1/2” 12.6# L-80 pre-drilled liner run to 31,246’ MD / 8,139’ TVD. There are no plans to pre-produce the well. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on “B” pad. General sequence of operations: 1. MIRU Doyon 14 2. N/U 13-5/8” x 5M BOPE and test 3. Pull tubing from cut 4. Mill Baker S3 packer and push to bottom 5. Run 7” CIBP and set same. 6. Set 7” WS and mill 6-1/8” window Steps 1-6 will be covered under the Sundry. Steps 7-11 will be covered under the PTD. 7. Drill with kickoff (motor) assembly until sufficient separation achieved 8. Drill 6-1/8” hole with RSS to TD 9. Run 4-1/2” production liner 10. Run 4-1/2” production tubing 11. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Production Hole: No mud logging. LWD: GR/Res Page 10 Milne Point Unit F-17L1 Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that all drilling and completion operations comply with all applicable AOGCC regulations. Operations stated in this PTD application may be altered based on sound engineering judgement as wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. BOPs shall be tested at (1) week intervals prior to initiating window milling and (2) week intervals during the drilling and completion of MPU F-17L1. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. The initial test of BOP equipment will be to 250/4,000 psi & subsequent tests of the BOP equipment will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial and subsequent tests).Confirm that these test pressures match those specified on the APD. If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: None Page 11 Milne Point Unit F-17L1 Drilling Procedure Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 6-1/8” 13-5/8” x 5M Hydril “GK” Annular BOP 13-5/8” x 5M Hydril MPL Double Gate o Blind ram in btm cavity Mud cross w/ 3” x 5M side outlets 13-5/8” x 5M Hydril MPL Single ram 3-1/8” x 5M Choke Line 3-1/8” x 5M Kill line 3-1/8” x 5M Choke manifold Standpipe, floor valves, etc Initial Test: 250/4000 Subsequent Tests: 250/4000 Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: Well control event (BOPs utilized to shut in the well to control influx of formation fluids). 24 hours notice prior to spud. 24 hours notice prior to testing BOPs. 24 hours notice prior to casing running & cement operations. Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 12 Milne Point Unit F-17L1 Drilling Procedure 9.0 R/U and Test BOPE This is an in-reservoir sidetrack. The existing perforations will be isolated via a CIBP. 9.1 Ensure Sundry, PTD, and drilling program are posted in the rig office and on the rig floor. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Ensure rig mats cover entire footprint of rig. 9.4 MIRU Doyon 14, Ensure rig is centered over the wellhead to prevent any wear to BOPE or wellhead. Mud loggers will not be used on F-17L1. A CMIT-TxIA to 2500 psi passed on 7/6/2023. 9.5 RU to pump down the tubing and take returns from the IA to a tank. Pump at least 1 truck of seawater followed by at least one soap sweep surface to surface per MI. Estimated Kuparuk pore pressure is 6.7ppg. The whipstock will be set at ~20,907’ MD. Note that it is recommended to circ another BU after pulling the hanger to the floor to clear the annulus of any scale/debris. Tubing volume to the cut depth is ~297 bbls IA volume to the cut depth is ~450 bbls. 9.6 Install BPV. N/D the tree. Install test dart in the BPV. 9.7 N/U 13-5/8” x 5M BOP as follows: BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity,blind ram in bottom cavity. Single ram can be dressed with 2-7/8” x 5” VBRs N/U bell nipple, install flowline. Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 9.8 Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. Test 2-7/8” x 5” VBR’s with 4” and 4-1/2” test joints Confirm test pressures with PTD Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug Page 13 Milne Point Unit F-17L1 Drilling Procedure Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 9.9 R/D BOP test equipment. 9.10 Pull test dart and BPV. 9.11 Order out 8.6ppg fluid for production hole. 9.12 Ensure 5-1/2” or 5-3/4” liners in mud pumps (maximize available pump pressure). Page 14 Milne Point Unit F-17L1 Drilling Procedure 10.0 Pull 4-1/2” Tubing, Mill Packer The tubing was cut at 19,517’ CT MD in July 2023. 10.1 PU landing joint or spear and recover the tubing hanger. The hanger was installed in 1998. The hanger is an FMC 11” x 4-1/2” w/ a 19.5” pup below. 10.2 Back out lock down screws. 10.3 Pull tubing hanger with landing joint/XO to the floor. 10.4 The tubing is expected to be in good condition. 10.5 Note and record PU weight required to pull the tubing from cut. 10.6 The expected weight of the string in a vertical hole filled with seawater is 198 klbs (assumes 19,517’ cut depth). PU weight will be significantly less due to the deviation. 10.7 Recommend that at least 1X BU is circulated after pulling the hanger to the floor. If desired, circulate another soap sweep surface-to-surface to clean the tubing. 10.8 Pull and lay down the tubing from the cut. Note: CT saw positive indication of a good cut. If the tubing cut was incomplete, an e-line conveyed cutter will need to be tractored into the well to make a second cut. 10.9 Run wear ring. 10.10 PU 4” drill pipe and RIH with packer milling assembly per Baker rep. The primary plan is to burn over the packer and push it to bottom. 10.11 Mill packer following Baker Hughes procedure. 10.12 Chase packer down below 21,000’ MD. 10.13 When on bottom circulate at max rate a minimum of 1X BU or until returns are clean. Pump high vis sweep if necessary. 10.14 POOH with milling assembly. 10.15 PU 7” CIBP per Baker rep. RIH and set in the middle of joint below KOP and above top perf. Perform 10 min assurance test to 1,000 psi. POOH. Page 15 Milne Point Unit F-17L1 Drilling Procedure 11.0 Mill 6-1/8” Window and Kick Off Note: All following operations will be covered under by the PTD for F-17L1 A USIT was run on January 27, 1998. The top of the logging interval was 18,600’ and the log shows cement from 18,600’ to TD with good bond across the planned KOP. 11.1 Whipstock Set Depth Information: Planned TOW: ~20,907’ MD i. Collars are located at 20,944’ and 20,902’ and 20,860’ and 20,822’ (parent RKB reference) WS will be set to avoid a collar based on the F-17 7” tally (Nabors 22E RKB of 33.05’). Note that the original paperwork reports a 12.7’ ground level and the 33.05’ RKB is from the rig floor to the base flange. Doyon 14’s RKB on F-17L1 is 33.7’ (RKB to base flange) plus 12.7’ ground level for 46.4’. There is almost no shift required from the parent tally (33.05’ vs. 33.7’). Drilling foreman, whipstock service hand, and drilling engineer to review parent tally and agree on the set depth. 11.2 MU 6-1/8” mill/whipstock assembly as per Baker Hughes tally Make up HWDP, string magnets, and float sub Ensure magnets are in trough, under shakers and flow area to capture metal shavings circulated 11.3 Install MWD and orient. Rack back mill assembly. Ensure a dedicated MWD is available for orientation of the whipstock 11.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD and milling rep. Document and record offset in well file. 11.5 Slowly run in the hole as per fishing Rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bolt. 11.6 Run in hole at 1 ½ to 2 minutes per stand, or per Fishing Rep. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 11.7 Shallow test MWD 11.8 Stop at least 30-45’ above planned set depth (10,200’ MD), obtain survey with MWD. 11.9 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient whipstock face. Page 16 Milne Point Unit F-17L1 Drilling Procedure 11.10 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 0 ROHS. 11.11 Whipstock Orientation Diagram: Desired orientation of the whipstock face is 15L to 15R, target is 0 ROHS Hole Angle at window interval (20,900’ MD) is ~81°, Azimuth 10°. 11.12 Once whipstock is in desired orientation, set WS per fishing rep. 11.13 Pressure up per rep to set hydraulic set whipstock, (verify highlighted values with Baker rep) P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the whipstock shear bolt. (35klbs shear value, verify with Baker rep). 11.14 P/U 5-10’ above top of whipstock. 11.15 Displace to window milling fluid. CBU and confirm 8.6 ppg MW in/out Ensure mud properties are sufficient for transporting metal cuttings Milling fluid will be 8.6 ppg solids free mud 11.16 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high visc sweeps as necessary. 11.17 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 11.18 Clean catch trays and ditch magnets frequently while milling window. 11.19 Mill window until the uppermost mill has passed across the entire tray and 20’ of new hole has been milled. Dress and polish window as needed. 15R15L Page 17 Milne Point Unit F-17L1 Drilling Procedure 11.20 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 11.21 Circulate bottoms up until even MW in/out and hole is clean of metal shavings. 11.22 Pull back into 7” casing and perform FIT to 11.5 ppg EMW. Chart Test. Note: A 9.0ppg FIT with 8.6ppg fluid density provides 115 bbl kick tolerance assuming 6.7ppg pore pressure (swabbed kick at 8.6ppg). 11.23 POOH & LD milling BHA. Gauge mills for wear. 11.24 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. All operations following milling the window are detailed in the Application for Permit to Drill. Page 18 Milne Point Unit F-17L1 Drilling Procedure 12.0 Doyon 14 BOP Schematic Typical Ram Configuration Page 19 Milne Point Unit F-17L1 Drilling Procedure 13.0 Wellhead Schematic FMC Gen 5 Typical 2-7/8” Page 20 Milne Point Unit F-17L1 Drilling Procedure 14.0 Days Vs Depth Page 21 Milne Point Unit F-17L1 Drilling Procedure 15.0 Formation Tops & Information Formation TVD TVDss MD EMW (PPG) Top A3 7662.2 -7615.8 20911.5 6.7 Top A2 7685.9 -7639.5 21109.2 6.7 Top A1 7713.2 -7666.8 21397.6 6.7 MPU F-Pad Data Sheet Page 22 Milne Point Unit F-17L1 Drilling Procedure 16.0 Anticipated Drilling Hazards Window Exit: Tracking Casing The KOP is cemented. The motor run will help us ensure departure from the parent bore prior to drilling ahead with a rotary steerable system. Production Hole Sections: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of 200 ft/min. Lost Circulation: Monitor ECD’s during production section to ensure ECD’s stay below 12.5ppg (target as low as possible). Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. The Kuparuk FG is predicted to be ~12.6ppg. Wellbore Stability: This is an in-zone sidetrack. Wellbore instability is viewed as a low risk. Maintain sufficient MW for stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles. Use MPD to offset swab effect while TOOH. Anti-Collision: This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic interference while drilling ahead. Faulting: There are no mapped faults in the production interval. H2S: Treat every hole section as though it has the potential for H2S. H2S events have typically been minor from F-pad Kuparuk wells. The vast majority of sample data is less than 10 ppm. F-69 recorded a sample with 47 ppm. F-53 had one sample test come back with 32 ppm. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Page 23 Milne Point Unit F-17L1 Drilling Procedure 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 24 Milne Point Unit F-17L1 Drilling Procedure 17.0 Doyon 14 Layout Page 25 Milne Point Unit F-17L1 Drilling Procedure 18.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 26 Milne Point Unit F-17L1 Drilling Procedure 19.0 Doyon 14 Choke Manifold Schematic Page 27 Milne Point Unit F-17L1 Drilling Procedure 20.0 6-1/8” Hole Section MASP Page 28 Milne Point Unit F-17L1 Drilling Procedure 21.0 Spider Plot (NAD 27) (Governmental Sections) Page 29 Milne Point Unit F-17L1 Drilling Procedure 22.0 Surface Plat (As Built) (NAD 27) Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Cut Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Mill and Push Packer 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: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 21,780'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC 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 AOGCC 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 Name and Digital Signature with Date: AOGCC USE ONLY twellman@hilcorp.com 777-8449 Taylor Wellman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355016 197-196 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22823-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT F-17 Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,734' 21,664' 7,725' 1,542 N/A 74' 20' MILNE POINT MD N/A 5,750psi 7,240psi 4,607' 7,732' 9,544' 21,749' 9,508' 21,716' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" Tubing Grade: Tubing MD (ft): 12.6 / L-80 / IBT 19,548' 7/1/2023 4.5" Baker DB & 7" x 4.5" Baker S-3 and N/A 14,503 MD/ 5,958 TVD & 19,522 MD/ 7,376 TVD and N/A See Schematic See Schematic 4-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Operations Manager By Grace Christianson at 8:01 am, Jun 22, 2023 323-356 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2023.06.21 14:38:05 - 08'00' David Haakinson (3533) DSR-6/23/23 , ADL0355018, ADL0355017 10-404 ADL0025509, MGR22JUNE2023 MDG 6/23/2023 BWH 6/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 11:53:05 -08'00'06/26/23 RBDMS JSB 062723 Rig Sidetrack Screen & Prep Well: MPU F-17 Date: 04/27/2023 Well Name:MPU F-17 API Number:50-029-22823-00-00 Current Status:Producer [Shut in ESP]Pad:F-Pad Estimated Start Date:July 1, 2023 Rig:EL & CTU Reg. Approval Req’d?No Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts Permit to Drill Number:197-196 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) AFE Number:Job Type:CTU FCO Current Bottom Hole Pressure: 2,242 psi @ 7,000’ TVD SBHPS (Taken on 1/9/23) |6.16 PPG Maximum Expected BHP:2,242 psi @ 7,000’ TVD SBHPS (Taken on 1/9/23) |6.16 PPG MPSP:1,542 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 87° @ 21,460 MD | Greater than 70° at 4,000’ MD Max Dogleg:0.5°/100ft @ 19,849’ MD Brief Well Summary: MPU F-17 was originally drilled as an injector into the Kuparuk formation in 1998. The well developed tubing leaks between 19,500’ – 14,500’ MD. A 4-1/2” permanent packer was set in the tubing in 2004 and the well was converted to a coil tubing deployed forward circulating jet pump in 2001. The well operated as a forward circulating jet pump until 2003. The well was converted back to an injection well in 2005 before becoming shut-in in 2005. The well is being evaluated as a rotary sidetrack candidate. Mechanical Condition: x 6/9/09 CMIT-TxIA passed to 1,500psi (IBP set in tubing tail) o IBP in tubing tail has failed. Confirmed w/ FL shots, BHP survey reading subnormal pressure and attempt to fluid pack tubing failed. x 1/9/23 SL drift to 14,257’ MD Objective: x Mill and push/fish the 4-1/2” DB Packer at 14,503’ MD x Confirm integrity of the 7” casing to 19,522’ MD x Cut the 4-1/2” tbg at ±19,517’ MD Coil Tubing Procedure – 1. MIRU Coiled Tubing Unit with 1.75” coiled tubing and spot ancillary equipment. 2. Pressure test BOPE to 4,000 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7-day test BOPE test period, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. 3. MU DB Packer Milling BHA w/ 2-7/8” motor. 4. RIH and dry tag DB packer at 14,503’ MD. Obtain milling parameters and mill to release. a. Fluid returns are not expected due to the low BHP. Multiple runs and a venturi may be needed to clear top of packer to be able to mill through the slips and element. Rig Sidetrack Screen & Prep Well: MPU F-17 Date: 04/27/2023 b. Once released, chase and push out of the tubing tail to PBTD or as deep as possible. c. Contingency: Spear and recover the packer if unable to push out the tubing tail. d. The 4-1/2” Baker DB Packer was run in July 2000. 5. MU GR/CCL logging BHA. RIH and log from 19,600’ – 19,000’ MD. a. Paint flag at 19,480’ MD. 6. Set 4-1/2” RBP at ±19,530’ MD. 7. Load well and CMIT-TxIA to 2,500psi. a. Contingency: If CMIT-TxIA fails, contact OE. i. MU leak detect tools. LLR will determine what type of logging tools required. Most likely tools will be acoustic leak detect tools. ii. Sit on top of RBP and pressure up to activate leak. Log from RBP – 14,000’ MD. iii. Download data and contact OE w/ results while RIH to pull RBP. 8. Pull 4-1/2” RBP from ±19,530’ MD. 9. Repaint flag at 19,480’ after pulling RBP. 10. MU Jet Cutter BHA and cut tubing at ±19,517’ MD. 11. RDMO CTU. Attachments: 1. Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised By TDF 6/21/2023 SCHEMATIC Milne Point Unit Well: MPU F-17 Last Completed: 2/1/1998 PTD: 197-196 TD =21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.60’/ GL Elev.: 12.70’ (N27E) RT to Tbg. Spool = 31.64’ (N 27E) 7” 9-5/8” 1 PBTD=21,664’ (MD) / PBTD = 7,725’(TVD) 2 KUP Sands 3 4 5 6 8 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 21,749’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / IBT-Mod 3.958 Surface 19,548’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,219’ HES X-Nipple – 3.813” ID 2 14,503’ Baker Model DB Packer 3 14,506’ Baker Seal Bore Ext. – 2.688” ID 4 14,513’ WLEG -2.0” Min ID 5 19,522’ 7” x 4-1/2” Baker S-3 Packer 6 19,530’ Baker IBP – 8.17’ OAL with 1.188” External FN 7 19,536’ 4-1/2” HES XN-Nipple – 3.725” ID 8 19,547’ 4-1/2” WLEG –Btm @ 19,548’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A3 20,950’ 21,020’ 7,667’ 7,677’ 70 3-3/8” Open Kup. A2 21,080’ 21,540’ 7,685’ 7,717’ 460 3-3/8” Open Ref Log: Cement USIT-GR-CCLU 1-27-1998 / 3-3/8” Alpha Jet Charges OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 2,650 sx PF ‘E’, 1,100 sx Class ‘G’, 160 sx PF ‘E’ in a 12-1/4” Hole 7” 170 sx Class ‘G’, 185 sx Foamed ‘G’ in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 800’ Max Hole Angle = 80° @ 7,900’ +70° 4,000’ to 20,000’ +80° 20,000 to 21,780 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tubing. Hanger, 4.5” NSCT top and bottom CIW 4” H BPV Profile GENERAL WELL INFO API: 50-029-22823-00-00 Drilled, Cased, Perfed & Completed by Nabors 27E - 2/1/98 Set 4-1/2” Model D Packer – 8/1/2000 DS Coil Tubing /Jet Pump – 9/12/2000 Set Baker IBT – 6/9/2009 _____________________________________________________________________________________ Revised By TDF 6/21/2023 PR0POSED Milne Point Unit Well: MPU F-17 Last Completed: 2/1/1998 PTD: 197-196 TD =21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.60’/ GL Elev.: 12.70’ (N27E) RT to Tbg. Spool = 31.64’ (N 27E) 7” 9-5/8” 1 Tubing Cut @ ± 19,517’ PBTD=21,664’ (MD) / PBTD = 7,725’(TVD) KUP Sands 2 4 3 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 21,749’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / IBT-Mod 3.958 Surface 19,548’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,219’ HES X-Nipple – 3.813” ID 2 19,522’ 7” x 4-1/2” Baker S-3 Packer 3 19,536’ 4-1/2” HES XN-Nipple – 3.725” ID 4 19,547’ 4-1/2” WLEG –Btm @ 19,548’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A3 20,950’ 21,020’ 7,667’ 7,677’ 70 3-3/8” Open Kup. A2 21,080’ 21,540’ 7,685’ 7,717’ 460 3-3/8” Open Ref Log: Cement USIT-GR-CCLU 1-27-1998 / 3-3/8” Alpha Jet Charges OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 2,650 sx PF ‘E’, 1,100 sx Class ‘G’, 160 sx PF ‘E’ in a 12-1/4” Hole 7” 170 sx Class ‘G’, 185 sx Foamed ‘G’ in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 800’ Max Hole Angle = 80° @ 7,900’ +70° 4,000’ to 20,000’ +80° 20,000 to 21,780 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tubing. Hanger, 4.5” NSCT top and bottom CIW 4” H BPV Profile GENERAL WELL INFO API: 50-029-22823-00-00 Drilled, Cased, Perfed & Completed by Nabors 27E - 2/1/98 Set 4-1/2” Model D Packer – 8/1/2000 DS Coil Tubing /Jet Pump – 9/12/2000 Set Baker IBT – 6/9/2009 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 w.. ..T . R.. .._ ., ... Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 St.MINEn FEB 1 7 2012 - 9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue F I 7 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 12 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20A 8/22011 MPF -13 1950270 50029225490000 0.2 N/A 02 WA 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 -31m. MPF -17 1971960 50029228230000 4.1 WA 4.1 WA 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/92011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/12011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 WA 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 17 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF -61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/112011 MPF -66A 1961620 50029226970100 , 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 08 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 02 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 WA 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/32011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 12 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 WA 11.9 8/13/2011 MPF-92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 '\ STATE OF ALASKA) ALA~ .J. OIL AND GAS CONSERVATION COMrvlo~SION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 45.7 KB 8. Property Designation: ADL-355016 11. Present Well Condition Summary: Total Depth measured 21781 true vertical 7734.12 Effective Depth measured 21664 true vertical 7725.43 Casing Conductor Surface Production Length 76 9509 21715 Size 20" 91.5# H-40 9-5/8" 40# L-80 7" 26# L-80 Perforation depth: Measured depth: 20950 - 21020 True Vertical depth: 7667.71 - 7677.72 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ß?1: Stratigraphic r feet feet feet feet MD 36 - 112 35 - 9544 34 - 21749 21080 - 21540 7685.15 - 7716.58 4-1/2" 12.6# Stimulate D Other 0 Convert to Injector Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 197-1960 Service D! 6. API Number: 50-029-22823-00-00 9. Well Name and Number: MPF-17 10. Field/Pool(s): Milne Point Field 1 Kuparuk River Oil Pool Plugs (measured) Junk (measured) None None TVD 36 - 112 35 - 4606.92 34 - 7731.75 Collapse 470 3090 5410 Burst 1490 5750 7240 ~t:;ANNtI» JAN 2 0 2000, L-80 32 - 19548 4-1/2" Baker DB Packer 4-1/2" Baker S-3 Perm Packer Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 o 2000 720 15. Well Class after proposed work: Exploratory r Development C 16. Well Status after proposed work: Oil r Gas r WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal I .~_ <e::/ ~ / Signat~~1/?7'1.d-tC/A-e ~~...tl Form 10-404 Revised 04/2004 14503 19522 RBDMS BFL ,JAN 1 8 2006 Tubing pressure o 2800 Service ¡;r GINJ r WDSPL r WINJ P' Sundry Number or NIA if C.O. Exempt: 304-298 Title Data Mgmt Engr Phone 564-4424 Date 1/12/2006 Submit Original Only MPF-17 EVENT SUMMARY I ACTIVITYDATE I SUMMARY 7/20/2004 Test check valve in coil tubing string Initial- T /1/0=200/0/60 Final- T /1/0=0/100/80 9/23/2004 ( Kill Well and FP ) Pump 10.5 Brine Down Well To Kill Press. / Freeze Protect Well. to 500' with 8 bbls diesel. IWH P=0/200/0. FWH P=O/O/O 9/24/2004 ( Pressure Test IA / Packer) Pump Diesel Down IA To pt Packer to 800 psi and ball check. U-tube well and bled psi off the coil and the coil annulus to zero. IWHP=100/100/0. FWHP=O/O/O 9/25/2004 Checked psi on the coil annulus (2 psi) and the coil (zero). Support Techs are slated to demobe and will bleed off the remaining trapped gas. 9/26/2004 Psi on the coil annulus and coil tubing bled to zero immediately when open to bleed off. It bled like a wisp of trapped gas in the closed system. 9/27/2004 ( RWO PREP) Demobe well and set up for coil retrieval. ') ') Pumped Diesel Thru Hardline To Clean Up Ice .( Heated Diesel To 120 Degrees) Well Support Tech removed the well house, flowlines and the foundation. They then installed an baited overshot on the coil (4-1/2" G fishing neck looking up, 21-1/2" from Pedcor hanger top to the top of fishing neck) and put the tree with an extra valve on top back on. The fish neck leans slightly towards 1 :30 from the front of the tree and sticks through the SSV rendering it unoperable. There is zero psi on the coil and the coil annulus. The well is overbalanced will probably go on a strong vacuum once the seal assembly is pulled from the seal bore due to the 10.5 ppg brine and 500' diesel FP cap. EMW is expected to be approximately 9.5 ppg. «The well is ready for the CTU prep.»> 10/31/2004 Work on unit conversions to 2" pipe. 11/1/2004 Heat upright tanks to 140* as directed by CTU. 11/1/2004 MIRU CTU #4: Pressure test surface equipment. Job in progress. 11/2/2004 Continued from 11-2-04 Heat upright tranks to 140* as direcected. 11/2/2004 Continued from WSR of 11/1/04. Perform weekly BOP test. MU Baker MHA and 4" GS spear. Latch 2" CT string at 17' and pull to 53k before weight broke back to 28k (unstung from seal bore). Monitor well and back fill with 27 bbls of diesel over 3 hours until fluid level stable. Cut pipe, make up double cold role connector and begin spooling pipe. POH with fish. Job in progress. 11/3/2004 ( Flush Tree) Assist CTU. Flush Tree With 43 BBLS Diesel. 11/3/2004 CTU #9 w/2" CT and WWP. Continued from WSR of 11/2/04. Continue POH. At surface and unable to get through Pedcor hanger.Split Pedcore hgr from base fig pick hgr tree bope to floor, remove fish belowhgr. NU up to base fig, split tree above Pedcore hgr, stripover topfish to floor, remove top fish from hgr. Remove Pedcore hgr and NU tree to master vlv. PT tree and all surface connections to 4000 psi. MU coil and blow down reel. Well left shut-in awaiting S/L to complete PT on tree. «< Continued on WSR 04-Nov-04 »> 11/4/2004 CTU #9 w/2" CT & WWP. Continued from WSR 03-Nov-04. RDMO CTU and head in for conversion from 2.00" CT to 1.75" CT. «< JOB COMPLETE »> 11/5/2004 CTU #9 conversion from 2.00" CT to 1.75" CT. 11/20/2004 ( MIT-IA ) Pressure Test IA To 2500 Psi. and 2000 psi for MIT. Attempted three tests with all failing. 11/27/2004 «PJSM» T/I/O= 0/0/0 Support RU, set TWC, PT tree to 5000 psi, good test, Pulled TWC. RDMO 11/30/2004 *** WELL SI UPON ARRIVAL *** 1ST STOP @ 13967' MD FOR 15 MINUTES 2ND STOP @ 14506' MD FOR 1 HOUR *** WELL LEFT SI *** · STATE OF ALASKA') ALAL ) OIL AND GAS CONSERVATION COMrvlovSION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 45.7 KB 8. Property Designation: ADL-355016 11. Present Well Condition Summary: Total Depth measured 21781 true vertical 7734.12 Effective Depth measured 21664 true vertical 7725.43 Casing Conductor Surface Production Size 20" 91.5# H-40 9-5/8" 40# L-80 7" 26# L-80 Length 76 9509 21715 Perforation depth: Measured depth: 20950 - 21020 True Vertical depth: 7667.71 - 7677.72 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0: Stratigraphic r! feet feet feet feet MD 36 - 112 35 - 9544 34 - 21749 21080 - 21540 7685.15 - 7716.58 4-1/2" 12.6# Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D' 197-1960 Service R1 6. API Number: 50-029-22823-00-00 9. Well Name and Number: MPF-17 10. Field/Pool(s): Milne Point Field 1 Kuparuk River Oil Pool Plugs (measured) Junk (measured) None None TVD 36 - 112 35 - 4606.92 34 - 7731.75 Burst 1490 5750 7240 Collapse 470 3090 5410 ~«;^NNE,D JAN 2 (D 2nn5' L-80 32 - 19548 4-1/2" Baker DB Packer 4-1/2" Baker S-3 Perm Packer 14503 19522 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 2000 720 15. Well Class after proposed work: Exploratory r Development r 16. Well Status after proposed work: Oil r Gas C WAG r GINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal ,// ~M' -! .>- '/ . ~l Signatur - ~1.ç:-t-L-?"-l./ (¿¿.~ Form 10-404 Revised 04/2004 RBDMS BFl.JAN ] 8 2006 Tubing pressure o 2800 Service ¡;r WINJ P' WDSPL r Sundry Number or NIA if C.O. Exempt: NIA Title Data Mgmt Engr Date 1/12/2006 Phone 564-4424 Submit Original Only · ~ ) ) MPF-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 3/1/2005 T/I/O = SI/150/660. OA Downsqueeze. MIRU DS. Hold PJSM. PT lines to 2500 psi. Pumped 10 bbls 60/40 Methanol, 10 bbls of CW 101 surfactant, 405 bbls of freshwater and 43.2 bbls of 15.7 ppg Arctic Set 1 cement. Displaced cement to shoe with 5 bbls of freshwater and 224 bbls of crude. SD and monitored OAP for 5 min. OAP dropped from 1370 psi to 1030 psi. Final WHP's = SI/370/1030. 3/4/2005 T/I/O = SI/160/650. MIT-OA FAILED. (Post OA Downsqueeze). LLR = 2 bpm @ 2480 psi. Pressured OA to 2900 psi with 3 bbls of crude. At 4 bbls away OAP started to dropped off to 2100 psi at 0.7 bpm. Increased pump rate to 1.5 bpm. OAP increased to 2250 psi. Pumped 5 bbls with no change in pressure. Increased rate to 2 bpm. OAP increased to 2480 psi. Pumped 10 bbls with no change in pressure. SD and monitored OAP for 10 min. OAP dropped to 1320 psi. No significant change in lAP during test. Bled OA to 280 psi. Final WHP's = SI/180/280. 3/17/2005 T/I/0=S-1/200/460. Pump 80 bbls crude down OA for injectivity test. 2 bpm @ 2500 psi. 2.5 bpm @ 2800 psi. FWP=S-I/260/1500 3/18/2005 T/I/O = SI/240/870. OA Downsqueeze. MIRU DS pump. PJSM, PT. Pumped 40 bbls of crude to establish injectivity. Pumped 10 of DS CW 101 surfactant, 380 bbls of freshwater, 10 bbls of DS CW 101 surfactant, 5 bbls of freshwater and 47.4 bbls of 15.7 ppg Arctic Set 1 cement, the 1 st 10 bbls containing 1/4# per sack of cello-flake. Displaced cement to shoe with 5 bbls of freshwater and 215 bbls of Crude. Final WHP's = SI/460/2250. 3/22/2005 T/I/0=S/I/200/900. MIT OA FAILED. LLR = .75 bpm @ 3060 psi. (Post OA Downsqueeze). Pressured OA to 3000 psi with 3.4 bbls of Crude. SD to monitor wellhead. OAP dropped to 2200 psi in 3 min. Re-pressured to 3000 psi and SD. OAP dropped to 2450 in 2 min. Pressured OA to 3500 psi and slowed rate to .5 bpm. OAP dropped to 3060 psi. Increased rate to .75 bpm and maintained 3060 psi with 10 bbls. SD and monitored pressures for 10 min. OAP dropped to 1950 psi. Bleed OA down to 800 psi. FWP=S/I/200/800. 4/22/2005 T/I/O = SI/250/860. OA Downsqueeze. MIRU DS pump, PJSM PT. Pumped 20 bbls of crude to establish injectivity. Pumped 10 bbls of DS CW101 surfactant,253 bbls of freshwater, and 43 bbls of 15.8 ppg class G cement, the 1 st 10 bbls containing 1/4# per sack of celloflake. Displaced cement with 5 bbls of freshwater and 112 bbls of crude. SD and monitored for 10 min. OAP dropped from 3000 psi to 1520 psi. Pumped 2 additional bbls of crude at 1 bpm and OAP increased to 2040 psi. SD, RD MOL. FLUIDS PUMPED BBLS 20 40 1058 133.4 613 1864.4 MeOH Surfactant Fresh H20 Cement Crude TOTAL e e ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 6, 2006 RECE\VEO JAN 1 1 2006 Alaska Oil & Gas Coos. Commission Anchorage Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: MPF-17 (PTD # 1971960) Application for Cancellation of Sundry #304-298 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304-298. The sundry was for temporary water injection with TxlA communication. The well will remain shut-in. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, Jve~ Joe Anders, P.E. Well Integrity Coordinator ~C~NED <,¡, (j:,,', ') (i fir' J.:. Iki c-v L;'", Attachments Application for Sundry Cancellation form 1 0-404 _ STATE OF ALASKA _ ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~E;CEIVSD JAl~ ~ L 1 eOV6 1. Operations Abandon 0 Repair Well D Plug Perforations 0 Stirn""" D~~'f!&lt:ilSíl. Performed: Alter Casing 0 Pull TubingD Perforate New Pool 0 WalverD TI '. ~ Change Approved Program 0 Operat. Shutdown D Perforate 0 Re-enter Sus'pen~Well e 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 197-1960 3, Address: P.O, Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22823-00-00 7. KB Elevation (ft): 9. Well Name and Number: 45.7 KB MPF-17 8. Property Designation: 10. Field/Pool(s): ADL-355016 Milne Point Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 21781 feet Plugs (measured) None true vertical 7734.12 feet Junk (measured) None Effective Depth measured 21664 feet true vertical 7725.43 feet Casing Length Size MD TVD Burst Collapse Conductor 76 20" 91.5# H-40 36 - 112 36 - 112 1490 470 Surface 9509 9-5/8" 40# L-80 35 - 9544 35 - 4606.92 5750 3090 Production 21715 7" 26# L-80 34 - 21749 34 - 7731.75 7240 5410 Perforation depth: Measured depth: 20950 - 21020 21080 - 21540 True Vertical depth: 7667.71 - 7677.72 7685.15 - 7716,58 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 32 - 19548 Packers and SSSV (type and measured depth) 4-1/2" Baker DB Packer 14503 4-1/2" Baker S-3 Perm Packer 19522 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS 8Ft .IAN ] 2 2006 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: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14, Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations 16. Well Status after proposed work: Oil ir Gas r WAG P GINJ WINJ r W DS PL 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: 304-298 Contact Joe Anders Printed Name Joe Anders Title Well Integrity Engineer Signature ~NJ (L-Â.J#} ,I fo/ 0'0 Phone 907-659-5102 Date 1/6/2006 oJ Form 10-404 Revised 04/2004 ['" .~ ,j I~L Submit Original Only Re: Request to Extend Sundry #304-298 for Milne Point F-17 ) ) Subject: Re: Request to Extend Sundry #304-298 for Milne Point F -17 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 27 lun 2005 14:48:07 -0800 To: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> CC: Jim Regg <jim_regg@admin.state.ak.us>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Engel, Harry R" <EngeIHR@BP.com>, "Dube, Anna T" <Anna.Dube@BP.com>, "Gurbanov, Ali G" <GurbanAG@BP.com>, "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Reeves, Donald F" <ReevesDf@BP.com>, "Sauve, Mark A" <mark.sauve@BP.com>, "Townsend, Monte A" <TownseMA@BP.com>, "Mielke, Robert L." <robert.mielke@BP.com>, "Wilson, Douglas A" <WilsonDA@BP.com> Joe, Thanks for the call regarding how wells with integrity losses are now handled. It appears that with the moving of Milne issues to your and Anna's review that additional internal checks and assurances were accomplished and that the internal issues identified by your work have been satisfied. With the well in active service, this extension should allow this investigation to be completed. Your request to extend to December 31, 2005 is acceptable. Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote: Hi Tam. Thanks for the response, appreciate your help with topic. BP reassigned Well Integrity responsibilities for Milne Point to the Well Integrity Coordinators (Anna and me) on February 1, 2005. We reviewed the sundry for this well with Prudhoe Bay SOP's in mind and decided to attempt to get a passing surface casing pressure test to confirm an additional barrier system. 3 OA downsqueezes were conducted in March and April in an attempt to get a passing MITOA. An MITOA conducted after the third OA downsqueeze lost 500 psi in 4 minutes at 3000 psi. After the unsuccessful attempts to get a passing MITOA, we determined there was not potential for contamination of ground water since only fresh water would be injected. The internal BP waiver was finalized and injection commenced on May 30, 2005. We strive to have all the internal BP approvals in place before initiating discussions with the AOGCC regarding Administrative Actions, Sundry's, etc. Unfortunately, this well got caught up in a responsibility realignment. We'll make every effort to keep this from re-occurring in the future. FYI, Doug Wilson is looking into the status of submitting 1 0-404's on the MPF-17 OA downsqueeze jobs. Thanks again for the help, please call if you have any further questions. Joe 1-907 -659-5102 SCANNED ~1UN 2· ? 2005 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 27, 2005 10:26 AM To: Anders, Joe L Cc: Jim Regg Subject: Re: Request to Extend Sundry #304-298 for Milne Point F-17 Joe, It seems the plans for injecting into MPF-17 keep getting delayed. I am curious about your comment regarding 1 of3 6/27/2005 2:48 PM Re: Request to Extend Sundry #304-298 for Milne Point F-17 ) ) the Risk Assessment and the OA downsqueezes. What were the issues here?? If I remember correctly, a "slow/small" tubing leak was believed to be the communication problem. Were other problems diagnosed?? I would appreciate understanding how the BP process works regarding this well in particular. From the context of your message, it would appear that there were several internal BP criteria/hurdles that needed to be met before the planned injection could begin. Was having regulatory (AOGCC) approval to inject part of the internal checklist?? Where in the "process" does AOGCC approval lie?? This matter seems similar to another well approval were T x IA communication was involved and AOGCC approval appeared to be a part of the justification used to secure internal BP approval. I feel this appears to be a "cart before the horse" situation. It has been my belief that when an operator submits a proposal to the Commission that our approval is the "end" of the process and that management is already in support of the submitted proposal. Am I wrong in this?? Tom Maunder, PE AOGCC Anders, Joe L wrote: Hi Tom. We request a 6 month extension of the expiration date on Sundry #304-298, from 1 July 2005 to 31 December 2005. This is for a temporary injection test into well Milne Point F-17 (PTD 1971960). Injection started into MPF-17 on 30 May 2005. Injection startup was delayed while we reviewed the RiskAssessment and conducted a series of OA downsqueezes. Current plans are to continue the injection test through the end of the year, assuming approval of the sundry expiration extension. We'll continue to comply with the Sundry requirements, including water only injection, daily monitoring of well rates and pressures and a monthly report to the AOGCC. Thank you for your assistance in this matter. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWellIntegr.ityEngineer@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, January OS, 2005 11:13 AM To: Sauve, Mark A Subject: Re: MPF-17 Follow-up Mark, Sorry this matter has slipped to the new year. I will be sending this by letter, however be advised that your plan to operate MPF-17 with a known integrity loss for a period of approximately 6 months is acceptable. The T/I/O/rate information should be submitted monthly as has been done for other similar wells. Please call or message with any questions. Tom Maunder, PE AOGCC Sauve, Mark A wrote: > Tom, > > As per our recent conversation concerning Milne Point water injection > well MPF-17 (PTD# 1971960) please find the following enclosure which > contains the results of a recent MIT-IA (post CTU-workover). The > information contained within supports the contention that the slow 20f3 6/27/20052:48 PM Re: Request to Extend Sundry #304-298 for Milne Point F-17 ) ') > tubingxIA leak identified in May 2004 has not significantly increased > in magnitude. > > «MPF-17 MIT-IA 11-20-04.doc» > > Our plan forward for well MPF-17 is to continue with the actions > outlined in approved Sundry #304-298 and to place the well on > temporary water-only injection for a six month trial period with a > known slow leak between the tubing and inner annulus. MPF-17 will be > included on the monthly increased monitoring program for the duration > of this temporary injection period and monthly reports will be > submitted to the AOGCC. Your concurrence for this plan of action is > requested along with your approval for an extension of the temporary > injection period from the current expiration date of March 1, 2005 to > a new expiration date of July 1, 2005. > > Note: If the 11-20-04 MIT-IA enclosure does not come through for any > reason please let me know and I will find another way to get it to you. > > Thanking you in advance, > > Mark Sauve > *Milne Point Artificial Lift & Production Coordinator* *BP Exploration > - Alaska * *900 E. Benson Blvd * *Anchorage, AK 99519* *Work Ph #: > 907-564-4660* *Work Fax #: 907-564-4440* > *E-mail: sauvema@bp.com* > 30f3 6/27/20052:48 PM ... ) r;:.:;'\ I:-?r-'\ r II n ~ í L ¡ A', '! lWû ~lb ) ~u lJŒ A.IfA.~1iA. OIL AlU) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 5, 2005 Mark Sauve Milne Point AL & Production Coordinator BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPF -17 PTD: 197-196 Sundry Number: 304-298 Dear Mr. Sauve: This letter is in reply to your request for a time extension for the sundry approval given for MPF -17. MPF -17 was most recently a production well and temporary conversion to injection service was requested in order to allow the gathering of information to determine if the well BHL is satisfactory to provide support to offset wells or if redrilling to another location is more advisable. Your application for sundry approval was granted on July 30, 2004 and contained an expiration date of March 1, 2005. You are requesting that the expiration date be extended to July 1, 2005. The need for a "temporary" approval is due to the well exhibiting tubing to annulus (T x IA) communication. The governing injection order (AIO lOB) and AOGCC regulations require that injection wells maintain mechanical integrity unless specific approval to operate is given by the Commission. When the sundry was originally approved, it was expected that any work necessary to allow injection would have been completed shortly after the approval. The work was not accomplished as planned, hence the request for time extension. In order to mitigate concerns regarding operating the well in a compromised condition, diagnostic testing has shown the leak to be small with no known casing integrity concern. Only water will be injected and well pressures and rate will be monitored daily and reported to the Commission monthly. Operating the well as proposed will not endanger fresh water. SCANNED JAN 0 {) 2005 ) ) Therefore, your request to operate the well in water service only for purposes of evaluating future well work is approved. The term of the approval is extended to July 1, 2005. The required monitoring reports must be submitted monthly, as has been done previously. If observation of pressures or rates indicates any additional integrity compromise, the well must immediately be shut in and the Commission notified on the next working day. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requeste ~ Re: [Fwd: MPF-17 Follow-up] ) Subject: Re: [Fwd: MPF-17 Follow-up] From: James Regg <jim _regg@admin.state.ak.us> Date: Mon, 13 Dee 2004 10:03:22 -0900 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Granting an extension to the existing sundry seems to be the right thing to do here since the intended work was not able to be started yet. I assume they have justified to you the need for a 6 month temporary injection period. This well should have been put on their monthly report beginning in May 2004 - they need to understand when a well has indication, notification to Commission is needed (I assume that was done) and the well should be added to their monthly report. Also, when they do an MIT (looks like they did 3 here - 2 failed (1 aborted) and 1 passed), they need to provide the results to Commission in our normal excel format Suggest you handle this with a letter rather than email correspondence. Jim Thomas Maunder wrote: Jim I request your input on this. We approved a sundry in mid summer to allow temporary operation with known T x IA communication. Their operations have been delayed and they only recently got the coil out of the well. Their proposal is to inject to evaluate response in offset wells. That information will allow them to determine if workover is justified or if it is better to sidetrack the well. I think since the operation time is limited and they have stated objectives that what they propose is acceptable. The July 1 date would be a HARD LINE. The need will be to have a "corrective action" plan proposed and approved or they need to apply for the administrative approval. Tom Subject: Date: From: To: CC: MPU, -------- Original Message -------- MPF-17 Follow-up Tue, 07 Dee 2004 09:50:04 -0900 Sauve, Mark A <mark.sauve@bp.com> Thomas Maunder <tom maunder@admin.state.ak.us> Townsend, Monte"'''A'''''''~T'¿;wïis'eïïjïA(~bp''':.''c-onl';'.'~_.''''''.Gu'rEanov";'. Ali G <Gurba.nAG@bp. com>, Well Op era t ion s S up e rv i so r .::,::.!.,§:,~,,~,,:?.P...~,~ a. t ion s s ~1.P..§:Fv i s 0 r:,~;e,p..,~_.~.:?],~:~. Tom, As per our recent conversation concerning Milne Point water injection well MPF-17 (PTD# 1971960) please find the following enclosure which contains the results of a recent MIT-IA (post CTU-workover). The information contained within supports the contention that the slow tubingx1A leak identified in May 2004 has not significantly increased in magnitude. «MPF-17 MIT-IA 11-20-04.doc» Our plan forward for well MPF-17 is to continue with the actions outlined in approved Sundry #304-298 and to place the well on temporary water-only injection for a six month trial period with a known slow leak between the tubing and inner annulus. MPF-17 will be included on the monthly increased monitoring program for the duration of this temporary injection period and monthly reports will be submitted to the AOGCC. Your concurrence for this plan of action is requested along with your approval for an extension of the temporary injection period from the current expiration date of March I, 2005 to a new expiration date of July I, 2005. Note: If the 11-20-04 MIT-1A enclosure does not corne through for any reason please let me know and I will find another way to get it to you. SCANNED JAN () {) 2005 10f2 1/5/2005 1 :45 PM Re: [Fwd: MPF-17 Follow-up] 20f2 ~h~nking you in advance, Mark Sauve *Milne Point Artificial Lift *BP Exploration - Alaska * *900 E. Benson Blvd * *Anchorage, AK 99519* *Work Ph #: 907-564-4660* *Work Fax #: 907-564-4440* *E-mail: sauvema@bp.com* ) & Production Coordinator* 1/5/2005 1 :45 PM ) WELL SERVICE REPORT WELL JOB SCOPE MPF-17 RWOCAPITAL DATE DAILY WORK 11/20/2004 MIT-IA AFE KEY PERSON MKD337401 LRS-ANDERSON MINID 0" DEPTH 0 FT ') UNIT LRS 40 DAY SUPV HULME NIGHT SUPV HULME TTL SIZE 0" DAILY SUMMARY . . -.-...---.-... . . . . ( MIT-IA ) Pressure Test IA To 2500 Psi. and 2000 psi for MIT. Attempted three tests with all failing. Init-> 0 0 0 BPM BBLs FLUID TEMP TBG IA OA TIME 13:30 14:12 14:58 15:00 15:10 15:25 15:40 15:56 16:04 16:19 16:42 16:57 17:12 17:38 19:00 .75 .5 start diesel 6.3 0 0 0 0 0 0 0 0 0 100 2510 2460 2410 2380 2500 2485 1970 1945 1920 FLUID SUMMARY . . .... 8 BBLS Diesel Final-> ~,...~~--_._- 0 SCANNED .JAN 0 ß 2.005 COMMENTS Start Ticket 1 Travel To MPF-17 ........ . ..n.." ..... , Arrive On Locationl Rig-Up IStandby PT IA To 2900 Psi . . " '" . Down IA 425 Test 425 15 Min Test " ^ . .... . 425 30 Min Test 425 45 Min Test 425 Retest 425 15 Min Test 425 Retest 425 15 Min 425 30 MIN Shut Down ... . .... . RDMO 1 Stop Ticket 1 Travel 0 0 e -- e !V\"ì' U f="" - ¡ "1 01' ~ 19~ HECB.ANICAL INTEGRITY REPORT· '- 5PUD D.:.'2::::: . I~· 1<:< \1 n.-:¡' - . "'J..,., . -. I OPER & FIELD B· P)( fVìP!J 0)"1-1 q.b :~.IG RELE;'..S~: Z.\ ¡! OJ '¿¡ ~-:::LL NIDiBER ~,..¡ ¡;LL DATA TD: 2..11 'OotID. r10S- TVD; :?ETD: ¡J '" b ¿¡ MD l' ~ 91 TVD )...~O Cas i::g : -=''98 -1'Ð~ Shoe: ø¡S"M HD L.~'" J,..~Bo :"~:-¡.gr: ft. '2.~.a Shoe: 2-1'1-49 MJ) I 2,,"- ~ -=-iJoi:::g: ";~z, "''6ðp acke~ 1'\$'2.1..' till TVD¡ DV: MD Tvu TVD; :CF: HD :'iJ . TV1) ; Set ê.t } "I 54B Perfs 2,.0'; 5"0 to 2.J 5""1-0 :'ole Size !'ZY4 ana ß 1/2... M:ECr.Þ...NIC;'~ INTEGRITY - PART fl Annulus Press Test: ~~ 15 m~n 30 IDln Com:r:;:¡ents: /' MECF~~ICÞ~ INTEGRITY - PÞ~T /2 1'10 SÀ G Cemen t: Volumes: Amt. l.iner 1'5 s~ RJA.NlP>~s g \o..)~\- "'f. ~~\i"'\. '( ~~-\- J-S \)~\ 4'" ~~ \ \()~ ~ 24·,')'0 S~ Pf €.- ¡IOÐ S)I ~ 1 ~o ~ Pffj DV Cwt ~ol to cover Der£s ~ ,. ht J, I 't Zb~":.. f;5t,""·/J..f" . ~ . t::>" 10.-4 St,.S" 5 f/ê:. "ß3hß~YI J.-f" (zr:.¡..t¡.Cj - Z,lb"--4))\ .! B 3-6 + ('2.1 i 8 ð - z.¡ 149J>¡ .3.3068 ..ç.. hF?4 f:1 - ZP'iSU)X .Io8~ ':. 112 ,S- S X r¡<'B'I7 -:: -. . 1· . ~ ~ ':":leOretlca~ TOC , ¡(:¡~3 "Jy.¡ t..r ~2..·Y1 ' . I L (3S"S' - HZ,S L)7 .I083l ~ ~£'ï'! I --.~ -- or No) \1-bù : In AOGCC File (JJ¡¡ AJ)'I1f:,c;fJ- t z.ot.'}S-o Cement Bond Log (Yes CEL ~valuation, zone above perfs A. f"\ . \j.þ0: f:- f\DÎ~ Ü ¡ 10 (:) F\,iSov{, f~.. .\t) ~~\'1 ðdif\+i ~ín-OY Prociuction Log: Type : Evaluation CONCLUSIONS: ",:; ; z ? ar t if 1 : ? ar:: ; 2 : 1\ ^ , ¡ Vi' 16 } ,,-' D ¡ GAç'í 6."') / WI"'I -¿( 2..31 e¡ ~ Re: MPF-17 ( PTD #1971960) Application to pull coil tubing and pl... ') ) Subject: Re: MPF-17 (PTD #1971960) Application to pull coil tubing and place on temporary water inj ection From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 29 Jul 2004 11 :43 :37 -0800 To: "MPU, Wells Ops Coord" <MPUWellsOpsCoord@BP.com> John, I have no problem with your call. You have more knowledge of the well particulars. One thing the MIT as we/you have it now does show is that there needs to be some field judgment regarding how long one might observe a test. It would appear that the pressure was stabilizing, but another 1/2 hour would have been a nice observation period to have. I will be expecting the new paperwork. Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Tom, If it is ok with you, I would like to pass on doing another pressure test After thinking about it some more, am concerned that we could damage the integrity of the downhole check if we get too rough with the pressure testing. If we lost the check, it would add another level of risk to the act of pullíng the tree and attaching the connector to the coil. Let me know if this approach gives you heart-burn Tom. We can definitely give it another pressure test if you feel strongly about needing one. Thanks again, John Cubbon MPU Well Operations Coordinator 1-907 -670-3387 -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 28, 2004 3:54 PM To: MPU, Wells Ops Coord Subject: Re: MPF-17 ( PTD #1971960) Application to pull coil tubing and place on temporary water injection John, It meets the less than 10% criteria and appears to meet the stabilization criteria although the tubing will likely be operating at more pressure than 2000, right?? A further observation period would have been nice to have. My only thoughts here are that the prior leak is below the CTU packer. Any test of the CT x tbg annulus will at least confirm that portion of the tubing string. Your call. Tom MPU, Wells Ops Coord wrote: SCl~NNEi.) JAN 0 (; 2005 lof3 1/6/2005 8:39 AM Re: MPF-17 ( PTD # 1971960) Application to pull coil tubing and pl... ') ) Tom, I just talked with Lee. He actually pumped the MIT last week and his notes show that the 15 Olin pressure drop was from 1980 to 1880 (-100 psi) and from 1880 psi to 1850 psi (-30 psi) the second 15 minutes. Please let me know if this will suffice. Thanks, JRC -----Original Message----- From: Thomas Maunder fmailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 28, 2004 2:47 PM To: MPU, Wells Ops Coord Subject: Re: MPF-17 ( PTD #1971960) Application to pull coil tubing and place on temporary water injection John, That might be a good thing to do. I am not sure how that sort of annulus would behave especially with produced fluids in it. . Tom MPU, Wells Ops Coord wrote: Tom, We did do a CMIT coil x 4-1/2" tubing to 2000 psi on 7/24/04 to 2000 psi (the IA pressure was at 200 psi during the test). Final pressure after 30 minutes was 1850 psi (they didn't record the 15 minute pressure). If you would like, we could repeat the test at a higher pressure and check for pressure stabilization. Let "me know. Thank s , John Cubbon MPU Well Operations Coordinator 1-907-670-3387 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 28, 2004 2:14 PM To: MPU, Wells Ops Coord Subject: Re: MPF-17 ( PTD #1971960) Application to pull coil tubing and place on temporary water injection John, Have Nick resubmit the sundry and include the work plan that you have provided here. There is an important distinction since you have included a time limit for the evaluation. Please note that the sundry will be for WATER ONLY given the tubing leak. With the coil pump in the 20f3 I/6/2005 8:39 AM Re: MPF-17 ( PTD # 1971960) Application to pull coil tubing and pl... ) tubing, is it possible to get a test on the tubing x coil annulus or am I remembering that the coil has a leak as well?? Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Hi Tom, As a follow-up to this mornings phone conversation concerning the Milne Point F-17 well, we would like to proceed with well work and diagnostics as follows: 1. Pull the coil tubing from the well. 2. Put the well on water injection for a maximum of 6 months to evaluate offset response and the need for a rig sidetrack. 3. 8I the well after 6 months of injection and evaluate options for either tubing replacement or rig sidetrack with tubing replacement. (Note: This well is needed for WAG injection and the tubing will be replaced after the injection test - either as part of a rig sidetrack, or just a RWO) . Our proposal for the 6 month water injection test is based on the following mechanical integrity test that shows a very slow leak rate: 5/6/2004: Initial T/I/O=50/100/45. (Eval for tubing integrity) Pumped 5.8 bbls meoh down IA for MITIA to 3500 psi. IA lost 35 psi in the first 15 min, 75 psi in 30 min. Retest. IA lost 10 psi in 15 min, 40 psi in 30 min. Bled back to starting pressures. Returned 4.4 bbls. MITIA passed - but did not truly exhibit pressure stabilization during the 30 minute tests. Final T/I/O=340/100/50. Thanks for your time Tom. We look forward to hearing back from you. John Cubbon MPU Well Operations Coordinator 1-907-670-3387 30f3 1/6/2005 8:39 AM O:,~P .¡... . '. To: From: Subject: BP Exploration Alaska Milne Point , .,;. ¡ - . ~, .\,O~ " '.' .,\ Tom l\'aundel AOGCC ~Ct~~,ù~~\ldt~\¿j -\"\~~~~L... "'~ Nick Frazier \k.:)()\\c../~~~ \\.Q~ F-Pad Enginee 0. b~",~\'N\!t \~~, l\.'¡PF-17 Con\ IPè.~~M..~ ò-~~,~~, Injector lOR Cost AFE Date: June 28. 2004 300 BOPD $400 1\'1 .0... Recompletion Fl\I ¡qì-/1b The objective of this procedure is to pull the 2" coil that is within the 4.5" tubing in order to return this well to injection for ~ 6 month trial with water injection only. If the well proves to be a poor injector then a sidetrack would be performed in August of 2005. In this case, the tubing would be cut right above the T' x 4.5" Baker S-3 Packer and cement would be laid. This would give plenty of rOOIn for the sidetrack's kick off point. If the well proves to be a good injector. a RWO will im1nediately ensue and the tubing \vill be pulled and replaced with cOlnpetent premium thread tubing for WAG injection. BP is applying to place this \vell in operation for a 6 month water injection test according Rule 8 Administrative Action. -----.. Our proposal for the 6 n1011th water injection test is based on the following lnechanical integrity test that shows a VeI)1 slo\v leak rate: 5/6/200-\.: Initial T/UO=50/l 00/45. (Eval for tubing integrity) Pumped 5.8 bbls meoh down lA for l\tIITIA to 3500 psi. IA lost 35 psi in the first] 5 min. 75 psi in 30 min. Retest. IA lost] 0 psi in ] 5 min. -\.0 psi in 30 min. Bled back to starting pressures. Returned -\.,4 bbls. tvlITlA passed - but did not truly exhibit pressure stabilization during the 30 Ininute tests. Final T/UO=3-1-0/l00/50. 0 0 0 C C c S 0 0 0 \ -( 5~'js'~, *p 1- :- . v f'\.tJ:~X- 'C S c..o ~~ \, Circl~lat~ kill tlui.d with 1 0 pp~ brine and w~tch ~or a(fe\\j da~s .., Obtam dIspensatIon for 1 barner \vhen tree IS off ~V'\() ~\~ ~ ~\v..~\""~ 3 Plant an overshot before coil comes \J CJ... \ "V ~ ""'" Unsting coil from packer (KJondike will be needed) 5 Kill well don'B ('oil and hHí.~ks¡d,~ of coil as I)c¡"fs a.re e'oposlt'd --1Þ (BOPs should be on and FloPro can be used) ~ 6 Pull 14.500' of 2" coil (leave packer in well) 7 Obtain SBHP (3-5 hr) 8 Obtain dispensation for injecting water down tubing with hole in it 9 Graduallv ramp up injection to 2500 BWPD performing a step rate test 10 Evaluate injector after 6 months water injection only and chose between R\,yO or ST Summary of Proposed Operations ORIGINAL .' Key Risks and lVlitigation Descri ption of Risk Only I batTier \vhen tree is off Hole in tubing while injecting Probabilit), Case P90 P50 PIO APPROV ALS Rate and Reserves Summary Resen-es Recovered (Barrels) 0 Mtvl 2.0 rvll'\i1 2..+ 1\n\ 1 First \' ear Benefit (bopd) 0 300 700 Bill Mathews, 2004Capex Owner l\'Utigation Steps Over kill the well with 10 ppg brine Closely monitor annuli pressure per State reg. Assumed Cost ($) Cost per Barrel ($lBarrel) .fOOM 0.2 Monte Townsend, PE Advisor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA:)...,,- 20 AAC 25.280 1 r/.~ ,.d ..- 'l(~ i Ii!: 1. Type of Request: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD Wa,verD Annular DisposalD StimulateD Time ExtensionD OtherŒ] Re-enter Suspended WellD Convert to Injector 5. Permit to Drill Number: 197-1960 Abandon D Suspend D Alter Casing 0 Repair Well 0 Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. Length Development [!] Exploratory D StratigraphicD Service D 9. Well Name and Number: MPF-17 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 21664 7679.7 MD TVD 6. API Number 50-029-22823-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 45.70 KB 8. Property Designation: ADL-355016 11. Total Depth MD (ft): 21780 Casing Size Plugs (md): None Burst Junk (md): None Collapse Total Depth TVD (ft): 7734.1 Conductor 76 Production 21715 Surface 9509 Perforation Depth MD (ft): 20950 - 21020 21080 - 21540 Packers and SSSV Type: 4-1/2" Baker DB Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: Description Summary of Proposal D Detailed Operations Program ŒJ BOP Sketch D 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 7667.7 7677.7 7685.2 7716.6 top 36 34 35 bottom top 112 21749 9544 Tubing Size: 36.0 34.0 35.0 bottom 112.0 7731.8 4606.9 Tubing Grade: HS-80 L-80 1490 7240 5750 Tubing MD (ft): 32 32 470 5410 3090 2" 0.00277 # 4.5 " 12.6 # Packers and SSSV MD (ft): 14513 19548 14503 19522 13. Well Class after proposed work: ExploratoryD DevelopmentD Service[! 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG D GINJD PluggedD AbandonedD WINJŒ] WDSPLD Prepared by Garry Catron 564-4657. August 12,2004 Contact Monte Townsend :~~:~~ame ~;::=:":/ Title Phone Petroleum Engineer Advisor 564-4602 7/29/04 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 30V-.:?2~¿:- ~5()() ~<':>\ ""'\"'\~~~ ~CJ~~.\ . Plug Integrity BOP Test}ll Mechanciallntegrity Test ~ Location Clearance D ~ t\, t:~ C)~ Other: T~\ ~ Û, (('/. \~cs. M(.lo.:"~" ~ \ 3-00 S- .. O~<~-\\t)~~ -\;ö '-De- -:..o"'~~<:~;:) \. r'\ ~ C) L-\ 0- ~'-O ,2) '-'.J [ ~ \ 0 \ (J \S . ~~~~g~~~~ION Date: ~ /At V Subsequent F. Approved by. 0 RIG I ~\1,41., Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE REC01\'IPLETION JUSTIFICATION Probability Case P90 P50 PIO First Year Benefit (bopd) 0 300 700 Table #1 - Rate and Reserves Summary Resen'es Reco\'ered (Barrels) 0 Mrv'l 2.0 T\'1M 2AMM Assumed Cost ($) Cost per Barrel ($lBarrel) -too l\1 0.2 RATE STREAl\': A response is expected to be seen after 3 months. Simulation has shown that after 3 months there is a 300 BOPD benefit for the first two years \vith a decline shown belo\v. 2005 300 2006 300 2007 258 2008 222 2009 191 2010 165 2011 142 2012 122 2013 105 2014 90 2015 78 2016 67 2017 58 2018 50 2019 43 2020 37 \VELL HISTORY: F-17 \Vas originally drilled as a water injector in Apr/98 to support lVIPF-3-\.. The well injected a pulse of water for 2 months and water breakthrough was observed in F34 after 2 lTIonths, for this reason it was decided to discontinue the injection. The \vater cut in well F-34 \Vas never higher than 15lk, and only 10lk, or less of the water injected was produced. It is possible that a fault system connects the two wells. F-17 was subsequently converted to a producer in Oct/2000 produced a total of 0.12 Inmstb. The well has been shut-in since Dec-2002 due to a hole in the coil tubing. The plan is to convert F-17 to injection and potentially relnove the scheduled F-17 sidetrack from the 2005 plan. Current vision for the ERD program is to sidetrack F-3"' and F-17 by Aug/05. Therefore. it is necessary to observe if F-17 provides pressure support to F-34 by then. The proposed conversion represents an acceleration of expenditure from the sidetrack plan (Aug.05) with potential benefits as described above. CURRENT \VELL STATUS: GENERAL WELL INFORlVIATION: API Number: 500292282300 Well Type: Jet Pun1p Producer Original KB Elev: 45.7' l\Ilinimum ill: 2.00" Coil Current Production Rate: Shut In BHP and BHT INFORl\J1A TION: BHP: 3447 psi BHT: 180 F DIRECTIONAL INFORl\JIATION: KOP: 800' l\IID Max Angle: 80 @ 7900' MD Max DLS: 6.21 @ 2900' MD Angle through perfs: Horizontal PERFORATION IN FORl\lA TION: EFFECTIVE MEAS MEAS NAME START DATE .DEPTH DEPTH TOP BASE TVD TOP TVD BASE FLOW OPEN CAPABLE! -- ---- - -- - --- --. ----- '-- - - -- -- ------- -------- --- -- - - ,'- - - - - - - - - -------- - ------ , - - - - ----- -------¡--- - --: SL ! 1/27/98 20950 I 21020 I 7638 7649: y i__~_J ! SL ! 1/27/98 21080 ¡ 21540 i 7656 7687 i y r y : '------- - -- h"" __--_dO! --- - - ---'--- - ---- ----- -'--' __!__h--- -------- --- -- -. ------ .1__--_.....-.--.-..--.--- _h___- -- --'- '-'-- -. --- ----.- - - -. .--- ---- - - ----- - -- ..--- -- . --- --. -- .___--i__--- ----, _m__-- -- ,_i- --- -- -- --, - ------ ------ - . -..' PRESSURE DATA: NAME DATE ci~p~~ TOOL DEPTH SS DAYS 51 S~~~~V PRES AT DATUM DATUM SS, JH --8/00--- U - --1-- -----T10--1 SBHPi --3447 - ¡-loao ---, r--TiÚ)ü!HH__- - nTn --!61f¡TSBHPr-~3388---T-7()oo: 1-_-!6I98fn_------T~-----!- --r-PFö-i 2990--Troõö~-' ,- -.-------- ,--~----- - -. ------------- - --- -- -----r--_m---- --- ------- - r------ --- -------- ------- --.- __m- ---- -----__--.__h______--- --- --- r'---- ---- .-- -------- -----, I 14/98 I I I SBHP 3068 I 7000 ¡ ¡---- -T- - --- ------T u- __---n I -----T !--------------------: [=[=I--~-=-=---~-~-- - - -- [~=]_____L-_~=- ~==I - --- PROGRAl\1 DETAILS: Recompletion from Jet Pump Producer to an Injector The objective of this procedure is to pull the 2" coil that is within the 4.5" tubing in order to return this well to injection for a 6 lnonth triaL The 4.5" Baker model DB packer will be left in place in order to reduce the cost of conversion. Adequate rates can still be obtained through the packer's 2" minimum ID. If the well proves to be a poor injector then a sidetrack would be performed in August of 2005. In this case, the tubing would be cut right above the 7" x 4.5" Baker S-3 Packer and celnent would be laid. This would gi ve plenty of room for the sidetrack's kick off point. If the well proves to be a good injector, a RWO will ensue and the tubing will be pulled and replaced with competent premium thread tubing. Categor)! Step 0 1 0 2 0 3 C 4 C 5 C 6 S 7 0 8 0 9 0 10 Description Circulate kill fluid with 10 ppg brine and watch for a few days Obtain dispensation for 1 barrier when tree is off Plant an overshot before coil comes Unsting coil from packer (Klondike \vill be needed) Kin well down coil and hackside of cuil. as pelofs are t'xpost'd ( BOPs should be on and FloPro can be used) Pull 14.500' of 2" coil (leave packer in well) Obtain SBHP (3-5 hr) Obtain dispensation for injecting water down tubing \vith hole in it Gradually raInp up injection to ')500 R\VPO performinr. a step rate test Evaluate injector after 6 months water injection only and chose bet\veen RWO or ST Note: Plea~e look at the jobs performed on C-21 and C-26. Checking into the problems associated pulling the coil from these wells may provide insight into potential problems at F-17 and possibly pre\\~1ll them. Safet)' Note: A poli~y Dispensation from BP Drilling and Wells Operations Policy will need to be obtained prior to remo\'ing the tree and pulling the 2" coil string since there \\ill only be 1 barrier between the formation and the atmosphere. SCOPE I. Circulate 10 ppg brine in coil and coil x tubing annulus and watch for 5 days and obtain 3 \VHPIFL's on days 3. -1-. and 5 in order to estimate the rate of pressure build up. The last \alid pressure measurement was 3-1--1-7 psi at 7000't\'d from a SBHP in 8/2000. NOTE: If the well pressures up, call ANC office and consult about raising brine weight. ., Plan! 0\ ershot prior to coil arri\'ing 3. Rig up surface equipment such that circulation and returns can be accomplished either down the T coil or the coil x tubing annulus. 4. Make Slire a waiver from BP Policy has beell obtailled. Remove tree and install coil connector. At this point the kill weight fluid will be the onl}' barrier. Reinstall tree. 5. l'vlIRU Klondike. 6. l\nRU 2" Coil Tubing Unit. Hook up BOPs. 7. RIH and latch the fishing neck. Pull 2" coil. The coil is expected to release from the Baker Model DB Packer (at 1~503' MD) with a straight pull 8. Once the coil has been released from the packer, kill the well down coil and backside of coil as now the perfs are exposed. FloPro can be used. The last valid pressure measurement of 3~~7 psi at 7000'tvd from a SBHP in 8/2000 yields an El'vl\V of9.5 ppgl. Fluid pack all annuluses (including 70 bbl diesel cap) and monitor the well. Be prepared to raise El\'I\V if needed. 11. Pull 1~.513' MD of coil and raise fishing neck abO\e BOP's. set slips. strip off injector. cut off fishing net:k and make a coil sp1ice. Monitor coil and annulus for free flow. strip back onto the BOP stack and pull I~.5I3' of coil spooling onto 2" reel. 12. Freeze protet:t and secure well. Blow do\\n reel and RDl\IO Coil Tubing Unit. 13. Obtain a SBHP with Slickline (3-5 hour stop, ~$ ~aGCC I~. Make slIre a \\'ai\'{!rfrom BP Policy has been obtained since (here is a hole in/he lllbing. Graduall) ramp up injection (02500 B\VPD. Stan at 500 BWPD for 3 days. then 1000 B\VPD for 3 days, then 1500 B\VPD for 3 days. Ihen 2000 B\\'PD for 3 days. then to the final 2500 B\VPD. 15. Closely monitür annuli pressures per State requirements 16. After 6 months. det:ide whether to sidetrack \vell or to replace the tubing that has a hole. Last Static: 8/5/2000 3447 psi POINTS OF CONTACT: Production Engineer: Nick Frazier Office: 564-4638 Home: 346-1918 lVIPU 'Veils Operation Super\'isor: Jerry Bixby & Clint Spence Office: 670-3330 Fax: 670-6390 Tree: 4-1/16' - 5M FMC Wellhead: 11' x 4-1/16" 5M FMC Gen 5 FMC Tubing Hanger, 4.5" nsct top, 4.5" mod but!. btm. CIW 4" H BPV profile Pedcor COil Tubing Hanger 4-1/16" x 5M x 2" 20" 91.1 ppf. H-40 112' I KOP @ 800' MAX HOLE Angle 80' @ 7.900' + 70' 4,000' to 20,000' +80 from 20,000 10 21,780 pdtd 9 5/8 , 40#/ft, L-80 Btrc. Float Shoe. 9544' (î.um~ "':.~un-",-,::'u"C',".,' 1uw,g J.;.I "'um[. ,",¡)nrl~urd'IJrl ~' ~' !' ~~(~' ~' 1,.. 3 :1It! .. & "" 1,J1.,¿, " ~. ::\', ! ? , f.mJ ~ Wt!! ~]'.lIìfl ¡$f:. ,""I.: / 1+ I ) "-,,"'''- / 4.5", 126 ppf, L-80 Btrc. tubing (cap. = 0.0152 bpf. dnll = 3.958") 7" 26 ppf. L.80, NSCC production casing (drift 10 = 6.151", cap:: 0 0383 bpi J Minimum tubing restriction = 3.725" "XN" profile @ 19,536' md. ~ MPU F-17 r ...... ~ /. J- -.f¡ ~ Ii --* ~ ~gj ¡. I , it TL- J I' ; ,I '1; ~ . ~ ~ ,~ ¡uj ~, .;¡ ~ i ~ ~ V' t ~ ! / ~ '~ Ij-A ,:~ ',~ ~: 1" Perforation Summary Pr'~"~l";"'( Ref log: Cement USIT-GR-CCLU 01-27-98~ r,,:.I,~;,~ ~~.-, ~ SIZE SPF INTERVAL lTVD) ,,=T f-'umJ.i 3-3/8' 4 20,950-21,020' ì,638'.7,6~9' = 3-3/8" 4 21,080'.21,540 ï,656'-7.687' ::. 3-3 'S" Alpha Jet charges @ 60 deg. phasing ORIG. KB. ELEV = 45.60' (N 27E) ORIG. GL. ELEV = 12.70 '(N 27E RT To Tba. Spool = 31.64' i 4.5" HES X-Nipple ( 3.813" Id ) I 2219' I 2" Coil tubing (drifted to 1.56" min., .0156" wall, HS-80, 10 1.688", .00277 bbl/ft.) set inside original tubing completion Power fluid pumped down coil tubing .... Trico Jet Pump & Standing Valve 14500' 4.5"Baker mociel DB packer I Baker seal bore ext 2 688" 10 I Wireline entry guide 2.0" 10 I 14503' 14512' 14513' Tx 4.5" Baker 'S-3" Packer I 19522' 4 5" HES 'XN' Nipple ( MIN. 10 3.725") 19536' 4 5" WLEG I 19548' 7" Float Coller 21664' I 21749' I ~~ 7" 26#, L-SO, BTRS Float Shoe PBTD DATE REV. BY COMMENTS MILNE POINT UNIT 02 1 03 1 98 MDO Cased Hole, perf & Completion 27 E WELL MPU F-17i 08/01 /00 M. Linder 4.5" Model 0 packer set. API NO: 50-029-22823 09/12/00 GMH OS Coil Tubing/Jet Pump 09/16/01 BMH Addition of Jet Pump flow schematic BP EXPLORATION (AK) Re: [Fwd: MPF-17 (PTD #1971960) Application to pull coil tubing... ') ) Subject: Re: [Fwd: MPF-17 (PTD#1971960) Application to pull coil tubing and place on temporary water injection] From: James Regg <jim_regg@admin.state.akus> Date: Wed, 28 Jul2004 13:49:47 -0800 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Tom - Recommend approving application; might consider a sundry approval to do this given the language in Rule 2 of AIO lOB (underground injection must be through a well approved via PTD or Sundry); MIT should be performed after startup of 6-month temp injection (once thermally stable) and should be witnessed by inspector. Jim Thomas Maunder wrote: Jim, Here is the first communication I have had from BP regarding the sundry we denied. What are your thoughts on what they propose?? Originally, what they planned was more or less open ended. This is move toward repair, but... Tom -------- Original Message -------- Subject: MPF-17( PTD #1971960) Application to pull coil tubing and place on temporary water injection Date: Wed, 28 Jul 2004 11:17:33 -0800 From: MPU, Wells Ops Coord-~MPUWellsOpsCoord@BP.com> To: Torn Maunder (E-mail)<tommaunder@admin.state.ak.us> CC: Frazier, Nicholas B <fra.zrlþ@BP. com>, MPU, Well Operations Supervisor .S.~~!.:..!.:..~P..~.~~9.:.~-~.9.!:?:.§..§..~.P~..Ey-.~..§..S?~@BP. com.?., MPU, Wells Ops Coord ..::!.1..?Y:~-~.!.:..~-§..QP_§!.~.S?.9._rd@BP. com> Hi Torn, As a follow-up to this mornings phone conversation concerning the Milne Point F-17 well, we would like to proceed with well work and diagnostics as follows: 1. Pull the coil tubing from the well. 2. Put the well on water injection for a maximum of 6 months to evaluate offset response and the need for a rig sidetrack. 3. SI the well after 6 months of injection and evaluate options for either tubing replacement or rig sidetrack with tubing replacement. (Note: This well is needed for WAG injection and the tubing will be replaced after the injection test - either as part of a rig sidetrack, or just a RWO) . Our proposal for the 6 month water injection test is based on the following mechanical integrity test that shows a very slow leak rate: 5/6/2004: Initial T/I/O=50/100/45. (Eval for tubing integrity) Pumped 5.8 bbls meoh down IA for MITIA to 3500 psi. IA lost 35 psi in the first 15 min, 75 psi in 30 min. Retest. IA lost 10 psi in 15 min, 40 psi in 30 min. Bled back to starting pressures. Returned 4.4 bbls. MITIA passed - but did not truly exhibit pressure stabilization during the 30 minute tests. Final T/I/O=340/100/50. Thanks for your time Tom. We look forward to hearing back from you. John Cubbon MPU Well Operations Coordinator 1-907-670-3387 SCANNED ) r¡) ')on¡;: {oj b L J¡JJ 1/6/2005 8:39 AM '.': , c:;.: ,-'., t..:; ".:::J r ~ \ l L! ! ~ " t" ¡ ( ! I ,I ,,\. I! I l. ,.. , I \ ,: ~=~ \ ~ ¡ ¡ ;-. \...., L1:.. i \.~ l.; 1. ~:: .¡("Il~11 If ï.-,~,' /~~\\ i"1 /)\-\ I, Cd [ll('! IT\\ ~ - . ~ ' I, , I \ . "', J r .. I , ! \ ) I I I i L \ ¡, L'" \., IJ' '. ¡ ~ \ ': ,. - I ,-\ !:- L' ~-,\ \ fl.1 I l \ \ L' i''-\ \ \,::",' lJ h,'..---I' -' "-' ....\,...... FRANK H. MURKOWSKI, GOVERNOR A.'/A.~1iA OIL AND GAS CONSERVATION COMMISSION / 333 W. r>' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 20, 2004 Mr. Nick Frazier Petroleum Engineer BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 Re: MPF-17 BP Exploration Alaska Pennit No: 197-196 Sundry No: 304-254 dated July 6, 2004 Dear Mr. Frazier: Enclosed is the Sundry Notice (Fol111 403) you submitted regarding conducting well work on MPF-17 to remove certain production equipment (coil and coil deployed jet pump) and convert the well to water injection service. The Commission is denying your proposal \\i'ithout prejudice as explained be1o\v. If successfully accomplished, your proposed work will remove the production equipment resulting in a clear tubing string. Your work plan however does not address repair of the tubing leak that had been identified in May 1998 when the we]} had previously been in injection service. Injection operations in all pools at Milne Point are governed by Area Injection Order (AIO) 1 DB. Rule 5 (Notification of \~lell Integrity Failure) of said order in part requires the operator to "'.. .submit a plan of cOITective action on Fom1 ] 0-403 for Commission approva1." (emphasis added) As noted, your work proposal does not address any repairs with regard to the previously identified tubing leak. If it is your intention not to perform the \vork necessary to return the wel1 to full mechanical integrity~ you may Il1ake an application to place the well in operation according to Rule 8 Administrative Action. Such an application should include infol111ation that justit1es BP's decision with regard to the work plan for the subject wel1. VerytrulY~ Dan Seamount, Commissioner cc: Mr. Monte Townsend, BP II STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION r:' I~;:: / :J::~' '\ ,¡~:::. r"" APPLICATION FOR SUNDRY APPROVAL ~.- -~' ~-.." '.' ..J_~ :,..j JUL J - 2004 1. Type 01 Request: 20 AAC 25.280 Abandon D Suspend 0 Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 45.70 KB 8. Property Designation: ADL-355016 11. Total Depth MD (ft): 21780 Casing Total Depth TVD (ft): 7734.1 Length 76 21715 9509 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: ,. I ..... PerforateD ~Wa¡vÚtl -A;'~lairÐi[pošafO StimulateD Time ExtensionD " ~ ,- ."~ c OtherŒJ Re-enter Suspended WellD Convert to Injector 5. Permit to Drill Number: 197-1960 Development ŒJ Stratigraphic D 9. Well Name and Numb. MPF-17 10. Fleld/Pool(s): Kuparuk River F' Id / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft¡: Effecti Depth TVD (ft): 21664 7679.7 TVD Size Conductor Production Surface Perforation Depth MD (ft): 20950 - 21020 21080 - 21540 Packers and SSSV Type: 4-1/2" Baker DB Packer 4-1/2" Baker S-3 Perm Packer ð .tI 12. Attachments: Description Summary of Proposal jiG. ~ Detailed Operations Program ~ BOP Sket 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD ~ 7667.7 7677.7 7685.2 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 36.0 34.0 35.0 2" 0.00277 # 4.5 " 12.6 # Packers and SSSV MD (It): 6. API Number 50-029-22823-00-00 " Plugs (md¡: None Burst Junk (md): None Collapse boUom 112.0 7731.8 4606.9 Tubing Grade: HS-80 L-80 1490 7240 5750 Tubing MD (11): 32 32 470 5410 3090 14513 19548 14503 \ 19522 1~ell Class after proposed work: ..,J 04 ¡ - J 15. Well Status after proposed work: ,\ . ~il D sO PluggedD AbandonedD ~ ~, WA GINJD WINJ~ Av WDSPLD ~ Prepared by Garry Catron 564.4657 to t"1e l3e~ot m} kn\u ~edge~ C t t ~' on ac Monte Townsend '" \ Title Petroleum Engineer Advisor . Phone 564-4602 ~/6IQ.4 7/ (¡;(O'1 .Jc ~ommission Use Only Conditions of approval: Notify Commission so that a representative may witness Other: Subsequent Form Requ Approved by: BOP TestD Mechanciallntegrity Test D ExploratoryD DevelopmentD Service ŒJ I Sundry Number: /' 30~-~~~)C ~~\tQ. G~L\J Location Clearance D '1 BY ORDER OF THE COMMISSION Date: IL a 1 100~ R8DMS 8fl nQfh'~J^1 bp ~\ V To: From: Subject: 0 0 ., 0 3 C 4 C 5 C 6 S 7 0 8 0 9 BP Exploration Alaska Milne Point Jerr)' Bixb)' and Clint Spence l\fPU We]) Operations Supervisor lOR Cost AFE Date: June 28. 2004 300 BOPD $400 1\-1 .0-1 Recompletion Fl\1 Nick Frazier F-Pad Engineer l\'PF -17 Con\/ersion from JP Producer to Injector Sunlnlary of Proposed Operations Circulate kill fluid \\lith 10 ppg brine and watch for a few days Obtain dispensation for I barrier when tree is off Plant an overshot before coil comes Unsting coil fro111 packer (Klondike will be needed) Kill well do\\ n 4,.'oH an(1 batksidc of' roil us I)l~rfs art" exposed ( BOPs should be on and FloPro can be used) Pull 14.500' of 2" coil {leave packer in well) Obtain SBHP (3-5 hr) Obtain dispensation for injecting water down tubing \\'ith hole in it Gradually ranlp up injection to 2500 B\VPD performing a srep rate test Ke~' Risks and l\.Jitigation Description of Risk Only 1 barrier when tree is off Coil could fear to pieces when pulling Probability Case P90 P50 PIO APPROVALS l\-litigation Steps Over kill the \\'ell with 10 ppg brine Rate and Reserves SUnlmar)' Reserves Recovered (Barrels) 01\11\'1 ~.o 1\11\1 2,4 1\11\1 First \' ear Benefit (bopd) 0 300 700 Assumed Cost ($) Cost per Barrel ($/Barrell -+00 1\ 1 0.1 Billl\'lathe\\'s. ~OO-l-Capex O\\'ner l\'lonte To\\'nsend. PE Advisor RECOl\IPLETION JUSTIFICATION Probability Case P90 P50 PIO First Year Benefit (bopd) 0 300 700 Table #1 - Rate and Reser\'es Summary Resen'es Recovered (Barrels) 0 tv1 tv1 1.0 l\'1l\'1 1..+ tvl M Assumed Cost ($) Cost per Barrel ($lBarrel) -too tv1 0.2 RATE STREAlVI: A response is expected to be seen after 3 months. Simulation has shown that after 3 l110nths there is a 300 BOPD benefit for the first two years with a decline sho\\ln below. 2005 300 2006 300 2007 258 2008 222 2009 191 2010 165 2011 142 2012 122 2013 105 2014 90 2015 78 2016 67 2017 58 2018 50 2019 43 2020 37 'VELL HISTORY: F-17 was originally drilled as a water injector in Apr/98 to support !vlPF-34. The well injected a pulse of \\'ater for 2 l110nths and water breakthrough was observed in F3-1- after 2 months. for thi~ reason it was decided to discontinue the injection. The water cut in well F-3-1- was never higher than 15(,1, and only 10~, or less of the water injected was produced. It is possible that a fault system connects the two wells. F-17 was subsequently converted to a producer in Oct/2000 produced a total of 0.12 111nlstb. The well has been shut-in since Dec-2002 due to a hole in the coil tubing. The plan is to convert F-17 to injection and potentially remo\'e the scheduled F-17 sidetrack from the 1005 plan. Current vision for the ERD program is to sidetrack F-3-1- and F-17 by Aug/05. Therefore, it is necessary to observe if F-17 provides pressure support to F-3-1- by then. The proposed conversion represents an acceleration of expenditure from the sidetrack plan fAug.05) with potential benefits as described abo\'e. PROGRA~I DETAILS: Recompletion from Jet Pump Producer to an Injector The objective of this procedure is to pull the 2" coil that is within the 4.5" tubing in order to return this well to injection. The 4.5" Baker model DB packer will be left in place in order to reduce the cost of conversion. Adequate rates can still be obtained through the packer's 2" nlÍnio1um ill. If the well proves to be a poor injector then a sidetrack would be performed in August of 2005. In this case, the tubing would be cut right above the 7" x 4.5" Baker S-3 Packer and cement would be laid. This would give plenty of room for the sidetrack's kick off point. Category Step 0 I 0 2 0 3 C 4 C 5 C 6 S 7 0 8 0 9 Description Circulate kill fluid with 10 ppg brine and \vatch for a few days Obtain dispensation for 1 barrier when tree is off Plant an overshot before coil comes Unsting coil from packer (Klondike will be needed) Kill wcn down (oil and had..side of l.oil as perfs an' l-'\pnst~d ( BOPs should be on and FloPro can be used) Pull 14,500' of 2" coil (leave packer in well) Obtain SBHP (3-5 hr) Obtain dispensation for injecting water down tubing with hole in it Gradually ramp up injection to 2500 BWPD perforn1ing a step rate test Note: Please look at the jobs performed on C-21 and C-26. Che~king into the problems associated pulling the ~oil from these wells may provide insight into pOtential problems at F-17 and possibly prevent them. Safety Note: A policy Dispensation from BP Drilling an \Vells Operations Policy will need to be obtained prior to removing the tree and pulling the 1" coil string since there \\'ill only be 1 barrier between the formation and the atmosphere. SCOPE I. Circulate 10 ppg brine in ~oil and coil x tUbing annulus and watch for 5 days and obtain 3 \VHPIFL's on days 3. 4, and 5 in order to estimate the rate of pressure build up. The last valid pressure measurement was .......... 3447 psi at 7000'tvd from a 5B HP in 812000. NOTE: If'the well pressures uP. call ANC office and ~ q 0.5 ~~~ consult about raising brine weight. - 1. Plant o\ershot prior to ~oil arriving 3. Rig up surface equipment such that circulation and returns ~an be accomplished either down the 2" coil or the coil x tUbing annulus. 4. Make slIre a \l'ail'C/".ri'ol1/ BP Policy has been obrailled. Removc tree and install coil connector. At this point the kill weight fluid will be the only barrier. R~inslalltree. CURRENT \VELL ST A TLTS: GENERAL "'ELL INFOInIATION: API Number: 500292282300 We)) Type: Jet Pump Producer Original KB Elev: 45.1' Minimum ill: 2.00" Coi] Current Production Rate: Shut In BHP and BHT INFORl\'JATION: BHP: 3447 psi BHT: 180 F DIRECTIONAL INFORl\IA TION: KOP: 800~ l\'ID 1\1ax Angle: 80 @¡ 7900' MD J\,lax DLS: 6.21 @ 2900' MD Angle through perfs: Horizontal PERFORATION INFORl\'¡ATION: MEAS MEAS NAME EFFECTIVE DEPTH DEPTH START DATE TOP BASE TVD TOP TVD BASE FLOW OPEN CAPABLE' ,--- ---..-- "-'--j" SL I 1/27/98 --. . - - --' ~- ---".... . ~ . - .- -.A - ....--- --......- ~~. .'.-" ""'""'''--.'' ,~. --.... "'-"--~--'''''''''''--''.'''''----''-'''''''''''--''''''''' ... .~.- ~....-----.-' - I I SL j 1/27/98 -- -- . _h- _0'. .. - - - -.. .. 20950 21020 21080 i 21540 - .1.- --- -----, 7638 7656 7649 7687 .- ~ --. --- '-- - ,< <-- -' ... ..- , , Y f Y , , ~- -- --- -- ___on - --- ----- -.- -~-----.. Y y _m" . - ---. - -- - PRESSURE DATA: NAME DATE ci~p~~ TOOL DEPTH SS DAYS SI S~~~~Y PRES AT DATUM DATUM S8: "," ì ".' ,.,- -' - - -i -..- --- --. r-- -'.,..-d---' --._o-¡ -- --- '-' ---- -.--- -.---'------- I' - - .. ---'- --.' '... : 8/00i I ! 10 i SBHP i 3447 ¡ 7000 ' " : I: I I f- -- - - - -- ! - ----- - -- - .-- -- ----- - __n -- -- --- __n - - -- ------. -- - ---- .--- -~. - ! ---. - .,-..-- ---~--- ~--r------- -- ..-- -~. - - --- ¡.. --- ...- - -- . -- - --~----_. - . ---..----- .-- -- - . . --- .. -- -_.~ --- -- -~ ¡ 3/00; ¡ : 616 : SBHP ¡ 3388 7000 I _--d_, --- --';- ----- - ------------- -"----1-------'-----------------------"--------- ------------------------------r-----------------r-------- --------___-__h_---_------------ -,- -----------------------: ¡ 6/981 I ¡ \ PFO i 2990 7000: ---------- ----- i --4/9S! -- ,- -- --------- -----..--------- ¡ -..- ------- ----------- - ------ ---- -- --------r----- -- ------- ---r--SS-H P --- ¡----- - ---30-68------- - ------7-0-0-0--- -----: ! -----------;- -----------,.---- -.. --- -- n ----------------,-------- -------------------------------¡--------- --- ---r------------------r------------------------------ --- -------- I ! j j , - - : - -- - - - --,- --. - - ----------- --- '1---- - n ---- --- - ---- - -- _--Oh --- ---r- -- on- _n___- -----1"--- ----- - -- -------í-- ---- ------ - - -- -- - --- ------ - - ---- ---i-- --- ,--, ----. --- - -- ---- I 'I j , I - j -- _--d- ---- --- -- j - ---_J_--- ----------;, -- -------- -- _1_-- 5. !\lIRU Klondikè. 6. !\1IRU 2.' Coil Tubing Unit. Hook up BOPs. 7. RIH and larch the fishing nèck. Pull 2'. coil. Thè coil is expected to release from the Bakèr !\fodel DB Packer (at 14503' MOl with a straight pull 8. Once thè coil has beèn released from the packer. kill the well down coil and backside of coil as no\\' the perfs arè exposèd. FloPro can be used. The last valid pressure measurement of 34-J7 psi at 7000.t\'d from a SBHP in 8/2000 yields an El\'f\V of9.5 ppg). Fluid pack all annulusès t'including 70 bbl diesel cap I and monilOr thè well. Be prepaœd to raise EM\\! if needed. II. Pull 14.513' 1\'10 of coil and raise fishing neck above BOp.s, set slips, strip off injècror. cut off fishing neck and make a coil splice. I\lonitor coil and annulus for free flow. strip back onto the BOP stack and pull 14.513. of coil spooling onto 2" reel. 12. Freeze protect and secure well. Blow down reel and ROl\10 Coil Tubing Unit. 13. Obtain a SBHP with Slickline (3-5 hour stop I 14. Make sure a lI'ah'CI"JÌ.ol1l BP Policy l1as been oblllined since ll1ere is a l10le i/l 111e IUbing. Gradually ramp up injection 1O 2500 B\VPO. Start at 500 B\VPO for 3 days. then 1000 B\VPO for 3 days. then 1500 B\\'PD for 3 days, then 2000 B\VPO for 3 days. then to the final 2500 B\VPO. Last Static: 8/5/2000 3447 psi POINTS OF CONTACT: Production Engineer: Nick Frazier Office: 564-4638 Home: 346-2918 l\,IPU \Vells Operation Supervisor: Jerry Bixby & Clint Spence Office: 670-3330 Fax: 670-6390 DISTRIBUTION: l'v1PF-17 Anchorage \Vell File l\1PU AdInin. Assistant: Norrh Slope IVIPF-17 \Vell File l\,IPU Ops Super\'isors: JerryBixby/Clint Spence l\IPU Ops Coord: l\-Iark O"l\.'alley/Lee Hulme/John Cubbon l'vIPU \\,'ell Arrificial Lift Coord: lVlark Sau\'e Tree. 4-'''-16'' - 5M FMC t Wellhead: , 1 x 4-1, , 6" 5M FMC Gen 5 FMC Tubing Hanger. 4.5 nsel top. 4 5" mod bun. blm CIW 4" H BPV profrle Pedeor Coil Tubing Hanger 4-1,,"6" x 5M x 2" MPU F-17 20 9'.' ppf, H-40 112' i KOP @ 800' MAX HOLE Angle 80' @ 7.900' ... 70: 4.000' 1020,000' ...80 from 20,000 10 21,780 pdld ~ ~ i . t ç - . ~ - : I . \. '01 >'..~" '. :,,',1, :"' ;,,': ,., h ~ , ~ "u. i:'í 8t l' t - I :10r : -- I I ~ ,~ .... ~(~" ~ I ~, l. \11'. ~ ~~ ~ - ~ II ~ 1 / II ~ ';~~lr.it~I'f";:r:r, ~,TI ~ ,~ ,/ ~. I." ,~ " I f ~ ~ I ~ ':;.;;.;' :'" ,:"", Î, 1- ~ I~~{J "r' 1 9 5"8", 4011,11. L-80 Blre. Float Shoe. 9544' ... 45",12.6 ppf. L-BO Btrc. tUbing (cap. = 0.0152 bpf, dllfl = 3.958") ì" 26 ppf, L-80. NSCC production casing (drift 10 = 6.151". cap:::: 0.0383 bpI) Minimum tubing restriction = 3.725" "XN" profile I,q;, 19,536' rnd ¡ ~ 1" Perforation Summary Ref log: Cement USIT-GR-CCLU 01-27-98 ~ SIZE SPF INTERVAL (TVD, Pi'jiJu'.o;:-'j ¡!oj,.:1 up S IIt~lrIIJ Inl,.', t3 ":" ¡:.urYr.1 3-3,,'8' 4 20.950-21,020' ì.638'-7,649' = 3-3"'8" 4 21,080'-21.5"'¡0 7,656'- ì,687' = 3-3 '8" Alpha Jet er,arges IQ.' 60 deg phasing ~ ORIGt ':::LEV = 4560 (N 27EI ORIG GL ELEV = 12.70 (N 27EI RT To Tba Spool = 31 €A , "'¡s' HES X-Nipple ( 3.813" Id ) I 2219' I 2" Coil tubing (drifted to 1.56" min., .0156" wall, HS-80, 10 1.688", .00277 bbl/ft.) set inside onginal tubing completion Power fluid pumped down coil tubing .... Trico Jet Pump & Standing Valve 14500' 4,S"Baker model DB packer I Baker seal bore ext 2 688" 10 I Wrrelrne entry guide 2,0" 10 I 14503' 14512' 14513' d T'x 4.5" Baker 'S-3" Packer I 19522' 4 5" HES 'XN' Nipple ( MIN. 10 3, ì25" ) 19536' ~ ,5" WLEG I 19548' 7" Float Coller 21664' I 21749' I PBTD 7' 2611, L-80, BTRS Floal Shoe DATE REV. BY COMMENTS MILNE POINT UNIT 02 / 03 / 98 MDO Cased Hole, perl & Completion 27 E WELL MPU F-17i 08/01 /00 M. Linder 4.5" Model D packer set. API NO: 50-029-22823 09/12/00 GMH OS Coil Tubing/Jet Pump 09/16/01 BMH Addition of Jet Pump flow schematic BP EXPLORATION (AK) MPF-17 (197-196---30-1-25-1) Subject: l\1PF- 17 (197- I 96---304-254) From: Thomas Maunder <tonl- maunder@;admin.state.ak.us> Date: Thu, 08 Jul 2004 15:30:40 -0800 To: Nick Frazier <fraznb@BP.com> CC: lVlonte To\vnsend <TownselVIA@BP.com>, Mark Sauve <mark.sauve(@bp.conl> Nick and Monte, I have left some voice messages regarding your proposal for this well, but here are my questions. 1. Has the internal MOC for performIng the initial operations with only 1 barrier in place been approved? NO If it has, I request a copy for our file. 2. If the MOC has not been approved, is BP's ultimate approval dependent on AOGCC approvIng the sundry?? ~)(. According to the reports in our file, the well had tubing x IA communication during its first life as an injector. Was that communication ever repaIred?? u.. /. It is noted that you plan on using the "Klondike" and cOlI. Is the coil \ linte'9Tal" to Klondike or is it one of the work coils available on the slope?? C".4". You plan to observe pressures and shoot fluid le"lels on 3 of 5 obser'/ation ':J days. 10 PP9 should proT/ide an o':erbalance based on the last SBHP. What are the present fluid level and surface pressure?? What is the estImate of how BHP has changed since 8/2000?? . )if. I presume SInce you ha':e ad':anced this plan that there is no alternatl':e to ~ attachIng the call connector. Would you please provide some further information regarding the mechanical conditions and lImitations with regard to attachIng thE coil connector?? When the coil was installed, was the tree off so the connector could be removed?? I am also copying this to Mark since I have not had any luck speaking wIth either of ~,'ou. I look forward to L'our repl i es . \4 \~,",-\J~Z) ) ,---, \" S- - dO ec, \~ ~.\~,\~",~c~~ c..-d-\ .'--d\O @~\\~c. d~ ~\\\S~~ \,,~~'~\ (A~~~\.)~ \ ç;\ç~\ I ~, '{~s h~s. ~þ.."f \ <-D~~'Y',\C£A~\.C)\'..' \-\0\'- ~~\a~ c.... ,\j F\c:.c~5:-- \..)S~ ð~ \L\c~\"-C¿ ~'l'-~ '-.Jek . \N<.,"- \<? Q c:S,-<i::CjLO-~ -\-~ \:'ö\\o""~ c...~\ \ , ?\c..~~ ~<è,~lQI\~1(' No \\ë:o...\ 0.. \~~\\~(C, Tom Maunder, PE AOGCC ~, 5, ~. 1 of 1 7 '8200-1 3:30 PI\J ~--'\f u r - \ i ~1-1~b ~SC~~ICÞ~ INTEGRITY P2~ORT "" . .:?UD :.2: G 2 E i. .::;..::: '::: . Z.!I{ O¡ ~ -,.~il. NilliBE~ ß'P~ I~\~ U 0'01- ( ~ b G.~.:':: : , J 2.13 d C1 t O?ER &. FIELD "ri"""E:LL DA T;'~ TD: 2.. J "1 ~o till r 1 0 S- TVD; ? E TD: ;U b ,,~ !1D "1 b 91 :-vD }... ~ 0 C ë. S i~ g: 0) IS}A ~Ðij.. Sho e: ")5""+i Xl) L~~ ~-Bo ~=-;-:er: .,.,. 'Zb4t Shoe: 2..r~49 :-m Il,.~~ -':-"..1 D:i..:: g : -4'Iz. L.o-SÛp 2. c~: e:::- 1 '\$'2:Z.: ~ TVD¡ TJV: ~ . -:"'',11) TVU j :CE: ~.ill -:..~J TVD i Set ê. ï: ) ~ 51 B I ::ole S:.=e I 'Z.. '14 ë.nå 8 ~/2- Pe!"£.s 2..0~S-O "La :u 5""1-0 :'SC?.Þ_N~C;'...:L l:NTEGRITY - ? ART ¡ 1 Annül~s ?ress Test: :? 15 Iilin .30 min C01Ii!::Je!lc.s: ,.- . L w~ \-"f. ç."."1M. '< f'\~ -\- i ~CHÞ1~IC;.l INTEGRITY - PART /2 J-S~~\ 4,",\\)\ $)~~, I ì 0 5.\ b 2J., So n flf E.. C c'AN\'iJ) '-. J 100 S>, '" Ce.!Denr: Volumes: ..~t. =":.ner j"~S1 rurv..; L.sg Ibo ~ HG DV Cwi: .. :2b t:t -=.. .Iß ~~ ')1-IJ-f" 'Iz..: '5'3l:ß~Y, J.j ><-'81/z..: ~. .:...:"".:.eCo"!"e cical I c B:3 ''JYo / J-("" 701 ~o cove~ ~er~.s J 5"". h" 10. -4 S b . S- l z.r:¡JrCi - Z.lbb~J ^ . 8 ~ ¿ + /21-=1 8 ð - 2..t149J~ ..~3-b8 -+-l'¿F¡~ 9 - zÞ9S"O)~ .lo8~ ~- J Ie .S- s x --=-===--- TDC 2..095'0 - 2..2-39 ' . r ( ~S-S - JlZS ,) 7 ./<:>83 J" -!'ði '!' No) ~~~ -; In AOGCC :F" ile 'Yl1 AD'-llSOt:L- Cement Bond Log (Yes or CEL ~valuation, ~one ëDove perfs ?roåuc.tion Log: !ype ':', L. :C~~~ç' ~c (.,~t.>~N\\Z:..'-I'\ULV'\..'~ ~~~~ c ~ ~j~ <-O~~\~~\$ \"'-<c..or-\'-j ~ ð~ ~ ,I ; Evalu2.t:ion #::,:1'v1 ~J lc¡' -0 Iv t1 D E:..~\J.p.."1 é.- DO/'J Û' rJ (:) ?\j!:p\, 'f..- Pt.~~ '- CONCLJS"I.Or~s : .';)~-- .11 - c::1..l. l.. r : ? a=:: ; 2. : M, J -5 ¡IV D , LA7l:....f) / WM 2,12-31 ") ~ RE: ~PF-17 (197-196---30~-~5.n Subject: RE: lVIPF-17 (197-196---304-254) From: "Frazier. Nicholas B" <fraznb@','BP.com> Date: Fri. 16 Jul 2004 13:41 :35 -0800 To: Th0111as f\,'launder <tom_maunder(@admin.state.ak.us> Tom- I have enclosed the internal BP dlspensation for the conversion of MPF-17. This verSlon does not have the signatures but I will mail you a copy of the slgned version if you so desire. We are also planning a conversion of MP-90 from production to injectoin and would like to discuss some issues concerning this with you at your convenience. We are concerned about packer set depth and also how to prove isolation of our injection water. I will be out of town from July 18 - July 25. If you would like to discuss this while I am gone then please contact Monte Townsend @ 907 564 4602. Thank you and ha\'e a wonderful day. Nick Frazier Petroleum Engineer Milne Subsurface ACT! (907) 564 4638 (907) 830 5450 cell I of 1 7/19,'~OO4 11'06 .-\1\1 MPF-17 Prep work for pulling of jet pump coil completion Summary of events: To prepare the well for retrieval of the coil string and allow the well to be put on injection down the 4 ~" tubing, a single block dispensation is needed in order to remove the tree above the Pedcor hanger. A pressure test will be conducted against the ball check in the coil string to again insure that the check is undamaged followed by kill fluid sufficient to over balance the SBHP above the check (10 ppg). The well will be monitored for 5 days to insure no flow conditions, during which time 3 WHP/FL's will be retrieved and recorded on days 3, 4, and 5. The well head equipment above the Pedcor hanger will then be removed allowing the reentry guide to be removed and a coil overshot with 'G' fishing neck installed for coil retrieval. The tree will be reinstalled with the addition of a spacer spool (extra valve) to cover the length of the added coil overshot. Pre-Job PrelJaration 1. Hold "Pre-Job safety meeting" with all parties. 2. Spot crane and spacer spool (extra valve) near well head. Open gate valve. 3. Insure proper hand tools are available on location. . "Vrenches. slings, C-p1ate, ring gasket, pry bar, hammer, etc. Procedure 1. Rig up bleed trailer to coil annulus (4 %" tubing). Insure annulus is dead. Pull tree cap gauge, open all tree valves checking for pressure. Monitor well for 15 minutes for static condition. 2. PJSM and hazard assessment. Review wind direction, safe area, job responsibilities, rigging operation, suspended loads, pinch points and need to minimize open hole operation time. 3. Have dirty vac truck on location. 4. Sling wellhead tree for proper lift. Unbolt above Pedcor hanger leaving two full bolts with nuts in place and lift load slightly clearing the flange. If all conditions are acceptable, lower load, remove final two nuts, remove the tree and set aside for installation of spacer spool or valve. 5. Remove the re-entry guide on top of the coil and install a 2" coil overshot with 'G' fish neck on to the coil. Pull test the coil overshot to the Baker Service Rep specifications to insure proper installation. 6. Set new tree rig gasket. Set and bolt up tree with spacer (extra valve) installed. Close all valves above the coil overshot. Install tree cap and gauge. PART I - RiSK/HAZARD ASSESSMENT WELL NAME: DATE: ACTIVITY: SUPERVISOR: Operation Slips Trips & falls MPF-17 7/15/04 Well Kill, Tree Removal and Fish Recovery Mark O'Malley/John Cubbon Potential Problem Personnel injuries caused by slick location Working at height Personnel injuries - (ladder) Falls, dropped items Overhead Loads - Crane Personnel injuries - Operations from falling loads. Economic Loss/Environmental Damage - Damage to tree components from dropped valve. Personnel injury - potentially fatal Loss of well control (flow) Risk Assessment Medium Occurrence-low impact Low Occu rrence- Medium impact Low Occurrence- Medium impact Low Occurrence- Medium impact Low Occurrence - High impact Environmental - major Low Occurrence spill; contamination of - High impact land and water Remediation Slick spots in traffic areas will be covered with nut plug or sand. Wear fall protection. Loads to be secured and checked prior to lifting. Personnel will be cautioned to stay out of the load path. Use tag lines where possible. Keep load as low as possible. Discuss roles and responsibility in safety meeting. Well is loaded with 10 ppg kill weight fluid prior to the open hole operations. Well will be monitored for flow/no flow prior to opening any valves to atmosphere. Well is :t200 psi overbalanced with 10 Pinch points - moving equipment with boom truck, nippling up hardline etc. Backing Accidents Spills Weather/Wind Economic Loss - Low occurrence - ppg brine. damage to equipment, medium impact Notify ERT's of pending operation and clean up keep them informed, Personnel Injury Personnel Injury - bodily harm Economic Loss - equipment damage Low Occurrence - low impact Medium Occurrence - low impact Environmental Damage Low occurrence - low impact Personnel Injury Economic Loss - equipment damage. Numbers of visitors/non- Personnel injury - essential personnel Low occurrence- low impact. Very low occurrence - low impact. Discuss at pre-job safety meeting. Keep contact with boom truck operator using predetermined hand signals and/or radio communication. Cover in pre-job safety meeting. Use spotters when backing equipment Discuss any simultaneous operations prior to start. Establish a parking area and parking guidelines (backing in, etc). Cover in pre-job safety meeting. Spill containment dikes used in all fluid transfers. Herculite will be laid down to set the tree on during removal period. Take weather readings at the beginning of job. Follow the ASH handbook guide on crane use in cold weather. Low Occurrence- The Wells Group Supervisor will be low impact responsible to manage the number of non-essential personnel in the work areas. POLICY DISPENSATION FORM DRilliNG AND WEllS OPERATIONS Business Unit and Field MPU SUBJECT (Short one line description) PROPOSED DEPARTURE FROM POLICY (Include full identification of policy item and reason for request) RISK ASSESSl\'IENT (What additional risks does this incur, and what is being done to mininlize those risks) DURATION (Timing of specific well, or field-wide application) SIGNATURES Well Number or Development MPF-17 NUt11ber of pressure barriers required for a speci fic we11 operation on well capable of sustaining flow to surface. V.le propose to utilize one pressure barrier (kill weight fluid) for a specific operation that requires removal of the tree. This is a departure from the Drilling and Wells Policy Barriers and Plugging, Section 24.2. This departure is requested due to the design of the coil tubing jet pump completion, no BPV profile and the coil 10 nlaking a second barrier unfeasible or unavailable. The well will be killed with 10 ppg brine leaving the well :tl00 psi overbalanced. The kill fluid will be above a one way top down check valve. The well will be monitored for flow/no flow. Once it has been detemlined the well is static, the tree will be unflanged abo\'e the Pedcor coil hanger (at which point we have the one pressure batTier) and a coil o\'ershot installed for retrieval of the coil string. The risk is flow from the well. The well will be killed abo\'e the tubing dowlù10le check valve for rell10val of 2" coil tubing jet pUtl1p velocity string and will be nl0nitored for 5 days prior to tree renlo\'al \vork. A pressure test will be administered against the tubing check to insure retention of the kill fluid in the tubing. Once confident of no flow conditions, the first step will be to un flange and lift the tree without clearing the studs to deten11ine if it is safe to continue removal. Exposure time will be minimized by assigrunent of on site responsibilities. Vac truck will be on stand by and ERT personnel will be alerted to job activities. The duration of the project is anticipated to be approximately 2 hours. The period of time the well is open to atmosphere is about 30 Inin (best case) and 1 hour (worst case). NAME SIGNATURE DATE Policy Paragraph Number 24.2 (Printed name, signature, date) ORIGINATOR l\Jark O~l\lalley REVIEW Lee Hulme ENDORSEMENT Gary Christman (Regional Drilling l\lanager) APPROVAL (Business Unit Leader or delegate) Don Nicolson Summary by Month: Individual Well Injection / Disposal Well Name: t\lIlNE PI UNIT "-R F-17 API: 50-1)29-21 Xl 3 -0(1.(11) Permit to Drill: 1971960 Operator: BP E:\PLORATION IALAS"-.A,) INC Field/Pool: I\lILNE POINT. KlIPARliK RIVER OIL Sale~ Cd: 55 :\cct Grp: 106 Final Status: 1\\'1NJ Current Status: I-OIL 1998 .Ian Feb Mar Apr May .Iun .Iul Aug Sep Oct No\' Dec Meth \VAG WAG WAG WAG Shut-In Shut-In Shut-In Shut-In Shut-In Days 28 19 2-1 8 (I 0 I) 0 0 Wtr 3-1.182 20,889 26.819 8,609 (I 0 0 0 0 Gas 0 I) 0 U 0 0 0 0 0 1998 Totals: Watl>r 90,499 Gas 0 Cum Wtr 90,499 Cum Gas 0 1999 .Ian Feb lVl a r Apr May .Iun .Iul Aug Sep Oct No\' Dec Meth Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Days 0 (I 0 0 0 0 t) (I 0 0 0 0 \Vtr 0 (I 0 (I 0 0 0 0 0 () 0 0 Gas (I I) () 0 0 0 (I 0 0 0 0 0 1999 Totals: Watt>r 0 Gas 0 Cum Wtr 90,499 Cum Gas 0 2000 ,Jan Feb Mar Apr May .Iun .Iul Aug Sep Oct No\' Dec Meth Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Days 0 n U 0 0 0 f) 0 I) 0 \Vtr 0 I) 0 (I 0 0 0 0 0 0 Gas I) 0 () (I 0 (I 0 0 I) 0 2000 Totals: Watt>r 0 Gas 0 Cum \Vtr 90,499 Cum Gas 0 Wednesday. July 07. 200-1 Page I Summary by Month: Individual Well Production Well Name: 1\1IlNE PT UNIT KR F-17 API: 50-029-22823-00-1)0 Permit to Drill: 1971960 Operator: BP EXPLORA nON (ALASKA) INC Field/Pool: 1\1IlNE POINT. KUPARUK RIVER OIL Sales Cd: 55 Acct Grp: 106 Final Status: IWINJ Curren! Status: I-OIL 2000 Jan Feb 1\-1 a r Apr May Jun Jul Aug Sep Oct Nov Dec Ml'th Gas Lift Gas Lift Gas Lift Days 6 30 30 Oil 16 573 7,599 \Vtr 2,669 13.616 1.296 Gas 8 255 3,576 2000 Totals: Oil 8,188 Water 17,581 Gas 3.839 Cum Oil 8,188 Cum Wtr 1 7,581 Cum Gas 3.839 2001 .Jan Feb 1\1 a r Apr 1\'1 a y Jun Jul Aug Sep Oct No\' Dec J\Ieth Gas Lift Gas Lift Gas L.ift Gas Lift Ga') Lift Gas Lift Gas Ldì Gas Lift Gas Lift Gas Lift Gas Lift Flo\\ ing Da)'s 31 28 31 30 31 30 31 31 29 26 30 31 Oil 5.3~~ 3.4 -10 ~.201 8.97~ 9.806 5.093 5.15~ ~.558 ~.33~ 4,269 4.068 3.4~ 1 Wtr 2,675 3,~95 4.625 1,598 1.790 ~2 2~ ( 0 0 0 0 Gas 1.75~ 1,(l9~ IA07 3.937 3 J48 1,48~ 1.545 1.-L:!9 1.474 1.3~5 1.508 1,549 2001 Totals: Oil 62,682 \'\later 14.249 Gas 21.874 Cum Oil 70.870 Cum \Vtr 31 .830 Cum Gas 25,713 2002 Jan Feb Mar Apr May Jun .Jul Aug Sep Oct No\' Dee Meth Flowing Flo\~ing Flo\\ ing Flow Ing fk'wing Flowing Flowing Flowing film in g. Fh:1\\ ing Film Ing draullc Pump Days 31 28 31 31) 31 30 26 27 II 2~ 30 31 Oil 3.319 3355 2.424 4,234 4.585 4,387 3.766 3,909 1,758 4.214 5,316 2.079 \Vtr 0 U 0 0 0 0 0 IJ 0 (I 0 (I Gas 1.014 889 620 1.206 IA48 490 991 1.201 489 1,275 1.690 1.347 2002 Totals: Oil 43,346 Water 0 Gas 13,160 Cum Oil 114.216 Cum \Vtr 31 ,830 Cum Gas 38,873 2003 Jan Feb 1\'1 a r Apr May Jun Jul Aug Sep Oct Nov Dec Meth draulic Pump ShuI-ln Shm-In Shut-In ShuI-ln Shut-In Shut-In Shul-In Shut-In Shut-In Shut-In Shut-In Days 18 I) (I I) 0 (I (I 0 0 0 0 0 Oil 1.1 I) 0 I) (I I) (I I) 0 0 0 ( 0 0 Wtr 0 I) (I U (I \J (I I.t 0 0 0 0 Gas 749 ( 0 (I 0 (J tI () 0 0 0 0 2003 Totals: Oil 1,100 \Vater 0 Gas 749 Cum Oil 115.316 Cum Wtr 31 ,830 Cum Gas 39,622 We-dnesda). Jul) 07. 200-t Page 1 Summary by Month: Individual Well Production 2004 Jan Feb ~Iar Apr 1\11 a y Meth Shut-Ln Shut-In Shut-In Shut-In Shut-In Days 0 () U () 0 Oil 0 1I 0 (I 0 Wtr (I 0 I) (I 0 Gas 0 (I 0 (I 0 2004 Totals: Oil 0 \Vater 0 Gas 0 Sep JUD Jul Aug Cum Oil 115.316 Cum Wtr 31,830 WednödLJ~. Jul~ 07.20(1-1 Oct No\' Cum Gas 39,622 Dec Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Conversion - Inject to Prod Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3471' FNL, 2731' FEL, Sec. 06, T13N, R10E, UM At top of productive interval 2178' FNL, 3997' FEL, Sec. 20, T14N, R10E, UM At effective depth 1281' FNL, 3866' FEL, Sec. 20, T14N, R10E, UM At total depth 1166' FNL, 3852' FEL, Sec. 20, T14N, R10E, UM Perforate _ Other_X Conversion to Prod 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ (asp's 541834, 6035260) (asp's 545683, 6052414) (asp's 545805, 6053312) (asp's 545818, 6053427) 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Milne Point Unit 8. Well number MPF-17 9. Permit number / approval number 197-196 / 300-112 10. APl number 50-029-22823 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical 21780 feet Plugs (measured) 7705 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 9512' Production 21717' 21664 feet Junk (measured) 7697 feet Size Cemented 20" 250 SX ArcticSet I (Appro 2650 sx PF 'E', 1100 sx 9-5/8" 'G', 160 sx PF 'E' 170 sx 'G', 185 sx 7" Foamed 'G' Measured Depth True Vertical Depth 112' 112' 9544' 4641' 21749' 7732' RECEIVED Perforation depth: measured Open Perfs 20950' - 21020', 21080' - 21540' BEC 0 ? true vertical Open Perfs 7638' - 7649', 7656' - 7687' Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 19522' MD. Tubing Tail @ 19548'. Packers & SSSV (type & measured depth) 4-1/2" Baker Model DB Packer @ 14503'. 7" x 4-1/2" Baker S-3 Packer @ 19522'. 4-1/2" HES X-Nipple @ 2219'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 08/28/2000 Subsequent to operation 12/04/2001 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Shut-in, Well Converted to Producer on 10/26/2000. 288 126 0 Casing Pressure Tubing Pressure 367 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 · Date December 10, 2000 Prepared by DeWayne R. Schnorr 564-5174 BnMs BFL EEC I 0 ')"r'' SUBMIT IN DUPLICATE MPF-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/26/2000 CONVERTED TO PRODUCING OIL WELL 12/04/2000 DALLY PRODUCTION RESULTS EVENT SUMMARY 10/26/2000 FIRST DAY AS A PRODUCING OIL WELL. 12/04/2000 DAILY PRODUCTION --- 288 STBO, 0 WATER, 126 MSCF GAS, AND WELL HEAD TUBING PRESSURE - 367 PSI. Page 1 c..Loi~I~a.D°c ................................ M'~'"~6~'~ ~ F~i7 ................................... 50] 029~22823-0'0 'BP ExpLoRATioN 197-196-0 MD 21780 TVD 07705 ~ompletionDate: ~/1/98 Completed Status: 1WINJ Current: T Name Interval Sent Received T/C/D L ADN-MD C~AL 18900-21700 OH 8/18/98 8/20/98 T L ADN-TVD vFI~NAL 7200-7700 OH 8/18/98 8/20/98 T L CDR-MD ~,,FI~qAL 6059-21780 OH 8/18/98 8/20/98 T L CDR-TVD ~/AL 3900-7700 OH 8/18/98 8/20/98 T L CMTADVISOR O}//BL(C)18650-21350 INHISTORY CH 5 1/30/98 2/6/98 L CMTADVISOR 1 ~C) 18650-21350 CH 5 2/4/98 2/4/98 L INJP-SPIN/TEM/ FINAL PRES 15350-16196 CH 5 12/17/98 1/5/99 R GYRO MULTISHOT ~5~LP1PE SCHLUM 0-11700 OH 6/30/98 7/1/98 R SRVYRPT ,~LUM 33-21781. OH 6/30/98 7/1/9~ T 8618 ~/ SCHLUM CDR/ADN OH 8/13/98 8/20/98 Daily Well Ops ]a!/~$/f?-- ]//3 ~/c?C3 Are Dry Ditch Samples Required? yes ~_..And Received? ye~..~---~ Was the well cored? yes ~-. Analysis Description R~2-4~--n'O"~-~-Sample Set # Comments: Thursday, February 03, 2000 Page 1 of 1 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 13, 1998 TO: BP Exploration (Alaska) Inc. Petmtectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Measured Depth CDPJADN,& CDR/ADN TVD for well MPF-17, Job # 98086 was sent to: BP Exploration (Alaska) Inc. Petmtechnical Data Center, MB3-3 900 E. Benson Blvd.. Anchorage, AK 99519-6612 ; State of Alaska ~,~. Alaska Oil & C°nservation Gas "A-rrm ~..__L_o..~!. T~a.y__!_o.._r..- 3001 Porcupine Drive E-TRANS- 8/11/98 3 Bluelines each I Film each -"~'~~_ I OH LIS Tape ~-,.,1J~Jueline each OXY USA, Inc. Attn: Dadene Faidy P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape I Blueline each 1 RF Sepia each Sent Certified Mail: P 067 695 469 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnicai Data Center MB3-3 900 E. Benson Blvd ..... '3. ""-' Anchorage, Alaska ~-~~ [a~D Date Delivered: AUG 2 0 1998 Naska Oil & LSas gon$. L;~ammJssJon Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ?-{.' ~-.~ .;"' :~'-~ ~'; :~, .,,~ .... WELL COMPLETION OR RECOMPLETION REPORT AND LOG ': ~- ,-'¢ 1 Status of Well Classification of Service ~7~It "¢'- '¢'~'~'~; '-¢,;z" E~ Oil [~ Gas E~] Suspended [~ Abandoned ~ Service Water Injectioh!!~.t,.%-"(,~ 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 97-196 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612:..:.~_ .: ......... ~.~~-- 50-029-22823 4. Location of well at surface ; .... ,~~-~-~ 9. Unit or Lease Name 1808'NSL, 2731'WEL, SEC. 6, T13N, R10E, UM ..;~~!?~7' ~' i _~i 10. MilnePointUnitwellNumber At top of productive interval '--¢~----~ ~! .., 3101' NSL, 1282' EWL, SEC. 20, T14N, R10E, UM At total depth ; ........... j i MPF-17i 4113' NSL, 1427' EWL, SEC. 20, T14N, R10E, UM '~' ...... '~ .... ~ ....... -' ''~ ~'~~" 11. Field and Pool , Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 46'I ADL 355016 12. Date Spudded12/31/97 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffshOre I 16' N°' Of cOmpletiOnsl/18/98 2/1/98 N/A MSLI One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 21780 7705 FTI 21664 7697 FTI [~Yes [~No (x-nipple) 2219' MD 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, USIT/GR/CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 9544' 12-1/4" 2650 sx PF 'E', 1100 sx 'G', 160 sx PF 'E' 7" 26# L-80 33' 21749' 8-1/2" 170 sx Class 'G', 185 sx Foamed 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 19548' 19522' MD TVD MD TVD 20950'-21020' 7639'-7649' 21080'-21540' 7656'-7688' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 106 bbls diesel Date First Production I Method of Operation (Flowing, gas lift, etc.) April 3, 1998 t Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BEE GAS-MCF WATER-DEL iCHOKE SIZE I GAS-OIL RATIO iTEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL 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 water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 'A' 20751' 7606' Top Kuparuk 'A' 20899' 7631' Top Kuparuk A2 20937' 7637' Top Kuparuk A1 21060' 7654' 31. List of Attachments Summary of Daily Drilling Reports, Surveys e~i~a~~r~re tr/~and~eectt°f my 32. I hereby c going is t to the be~ knowledge Drilling Engineerin~l Supervisor Date . MPF/17i 97-196 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 $: 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 ~)4: 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 Performance Enquiry Report Operator BP Exploration Date 17:58, 23 Jun 98 Page 1 The analysis is from - 03:00, 09 Jan 98 - to - 03:00, 09 Jan 98 Programs in Result Table: MPF-17 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPF-17 Event 03:00, 09 Jan 98 03:00, 09 Jan 98 0 hr 0 min Obtained leak off 12.6 Hole Size MDR 8-1/2 Facility M Pt F Pad Progress Report Well MPF- 17 Rig Nabors 27E Page Date 1 23 June 98 Date/Time 29 Dec 97 30 Dec 97 31 Dec 97 01 Jan 98 02 Jan 98 03 Jan 98 04 Jan 98 05 Jan 98 06 Jan 98 14:00-20:00 20:00-01:00 01:00-06:00 06:00-10:30 10:30-18:00 18:00-00:00 00:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:0(~-10:30 10:30-13:00 13:00-14:30 14:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-19:00 19:00-20:00 20:00-21:00 21:00-23:00 23:01)-06:00 06:00-14:00 14:00-15:00 15:00-17:00 17:01)-18:00 18:00-19:00 19:00-20:00 20:01)-21:00 21:00-00:30 00:30-06:00 06:00-18:30 18:30-20:30 20:30-21:30 21:30-22:00 22:00-06:00 06:00-18:00 18:00-19:30 19:30-20:30 20:30-21:00 21:00-06:00 06:00-07:00 07:00-09:00 09:00-12:30 12:30-13:30 13:30-14:30 14:30-18:30 18:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 Duration 6hr 5hr 5hr 4-1/2 hr 7-1/2 hr 6hr 4-1/2 hr lhr 1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 15-1/2 hr 1/2 hr lhr 1/2 hr 1/2hr 10-1/2 hr lhr lhr 2hr 7hr 8hr lhr 2hr lhr lhr lhr lhr 3-1/2 hr 5-1/2 hr 12-1/2 hr 2hr lhr 1/2 hr 8hr 12hr 1-1/2 hr lhr 1/2 hr 9hr lhr 2hr 3-1/2 hr lhr lhr 4hr 10hr 1-1/2 hr 1/2 hr lhr Activity Rigged down Lines / Cables Rig moved 30.00 % Rig moved 45.00 % Rig moved 70.00 % Rig moved 100.00 % Rigged up Lines / Cables Rigged up Divertor Rigged up Drillfloor / Derrick Held safety meeting Held safety meeting Made up BI-IA no. 1 Tested Divertor Tested Fluid system Drilled to 356.0 ft Made up BHA no. 1 Drilled to 2400.0 ft Drilled to 2493.0 ft Circulated at 2493.0 ft Pulled out of hole to 997.0 ft R.I.H. to 2493.0 ft Drilled to 3991.0 ft Circulated at 3991.0 ft Pulled out of hole to 1744.0 ft R.I.H. to 3991.0 ft Drilled to 4936.0 ft Drilled to 6058.0 ft Circulated at 6058.0 ft Pulled out of hole to 219.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 1020.0 ft Serviced Top drive R.I.H. to 6058.0 ft Drilled to 6469.0 ft Drilled to 7003.0 ft Circulated at 7003.0 ft Pulled out of hole to 5656.0 ft R.I.H. to 7003.0 ft Drilled to 7407.0 ft Drilled to 8250.0 ft Circulated at 8250.0 ft Pulled out of hole to 6664.0 ft R.I.H. to 8250.0 ft Drilled to 8682.0 ft Drilled to 8747.0 ft Circulated at 8747.0 ft Pulled out of hole to 50.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 8747.0 ft Drilled to 9560.0 ft Circulated at 9560.0 ft Circulated at 9560.0 ft Pulled out of hole to 8150.0 ft Progress Report Facility M Pt F Pad Well MPF- 17 Rig Nabors 27E Page 2 Date 23 June 98 Date/Time 07:30-08:00 08:00-11:30 11:30-15:30 15:30-18:30 18:30-20:00 20:00-04:30 07 Jan 98 04:30-06:00 06:00-08:00 08:00-11:00 11:00-13:00 13:00-16:00 16:00-19:00 19:00-22:30 22:30-04:30 08 Jan 98 04:30-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-12:30 12:30-13:30 13:30-14:30 14:30-21:30 21:30-22:30 22:30-23:30 23:30-01:30 09 Jan 98 01:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 10 Jan 98 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-11:30 11:30-12:30 12:30-14:00 14:00-20:00 20:00-21:00 21:00-06:00 11 Jan 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 12 Jan 98 06:00-06:30 06:30-10:00 10:00-10:30 10:30-11:30 11:30-12:30 12:30-18:00 18:00-18:30 Duration 1/2 hr 3-1/2 hr 4hr 3hr 1-1/2 hr 8-1/2 hr 1-1/2 hr 2hr 3hr 2hr 3hr 3hr 3-1/2 hr 6hr 1/2 hr lhr 1/2 hr 2hr lhr 3hr lhr lhr 7hr lhr lhr 2hr lhr 1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr lhr 1-1/2 hr 6hr lhr 9hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr 1/2hr lhr lhr 5-1/2 hr 1/2 hr Activity R.I.H. to 9560.0 ft Circulated at 9560.0 ft Pulled out of hole to 241.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 9544.0 ft (9-5/8in OD) Circulated at 9544.0 ft Circulated at 9544.0 ft Mixed and pumped slurry - 554.000 bbl Circulated at 2125.0 ft Mixed and pumped slurry - 696.000 bbl Rigged down Divertor Mixed and pumped slurry - 62.000 bbl Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested BOP stack Installed Wear bushing Made up BHA no. 4 R.I.H. to 2125.0 ft Drilled installed equipment - Cementing packer R.I.H. to 9455.0 ft Serviced Top drive Tested Casing Drilled installed equipment - Float collar Circulated at 9580.0 ft Performed formation integrity test Drilled to 9900.0 ft Held safety meeting Drilled to 10781.0 ft Held safety meeting Drilled to 11816.0 ft Held safety meeting Drilled to 12004.0 ft Circulated at 12004.0 ft Pulled out of hole to 9544.0 ft Serviced Block line R.I.H. to 12004.0 ft Rigged up Drillfloor / Derrick Conducted electric cable operations Rigged down Drillfloor / Derrick Drilled to 12782.0 ft Held safety meeting Drilled to 13624.0 ft Held safety meeting Drilled to 14300.0 ft Held safety meeting Drilled to 14537.0 ft Circulated at 14537.0 ft Pulled out of hole to 12000.0 ft R.I.H. to 14537.0 ft Drilled to 14537.0 ft Held safety meeting Facility M Pt F Pad Progress Report Well MPF- 17 Rig Nabors 27E Page Date 3 23 June 98 Date/Time 13 Jan 98 14 Jan 98 15 Jan 98 16 Jan 98 17 Jan 98 18 Jan 98 19 Jan 98 18:30-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-22:00 22:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-12:30 12:30-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-08:30 08:30-13:30 13:30-14:30 14:30-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-01:30 01:30-04:30 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-00:00 00:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-13:00 13:00-17:00 17:00-18:00 18:00-06:00 Duration 11-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr lhr 2-1/2 hr 8hr 1/2 hr 11-1/2 hr 1/2 hr 9-1/2 hr 1-1/2 hr 1/2 hr 1/2hr 6hr 1-1/2 hr lhr 3hr 1/2 hr 1/2 hr 2hr 5hr lhr lhr 2hr 2-1/2 hr 5hr lhr 15-1/2 hr 1/2 hr 5-1/2 hr lhr 2hr lhr lhr ilar 1/2 hr 7hr 3hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 4hr 4-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 2hr 4hr lhr 12hr Activity Drilled to 16037.0 ft Held safety meeting Drilled to 17064.0 ft Circulated at 17064.0 ft Held safety meeting Pulled out of hole to 14500.0 ft R.I.H. to 17064.0 ft Drilled to 17448.0 ft Held safety meeting Drilled to 18340.0 ft Held safety meeting Drilled to 19040.0 ft Circulated at 109040.0 ft Pulled out of hole to 18000.0 ft Held safety meeting Pulled out of hole to 250.0 ft Pulled BHA Installed BOP test plug assembly Tested BOP stack Held safety meeting Installed Wear bushing Made up BHA no. 5 R.I.H. to 9545.0 ft Serviced Block line Circulated at 9545.0 ft R.I.H. to 13000.0 ft R.I.H. to 19040.0 ft Circulated at 19040.0 ft Functioned downhole tools at 19040.0 ft Drilled to 20233.0 ft Held safety meeting Drilled to 20420.0 ft Circulated at 20420.0 ft Pulled out of hole to 19000.0 ft R.I.H. to 20420.0 ft Functioned downhole tools at 20420.0 ft Drilled to 20533.0 ft Held safety meeting Drilled to 21118.0 ft Circulated at 21118.0 ft Drilled to 21281.0 ft Held safety meeting Drilled to 21780.0 ft Held safety meeting Circulated at 21780.0 ft Pumped out of hole to 19000.0 ft Pulled out of hole to 9545.0 ft Serviced Block line Held safety meeting R.I.H. to 21719.0 ft Washed to 21780.0 ft Circulated at 21780.0 ft Flow check Pulled out of hole to 250.0 ft Facility M Pt F Pad Progress Report Well MPF- 17 Rig Nabors 27E Page Date 4 23 June 98 Date/Time 20 Jan 98 21 Jan 98 22 Jan 98 06:00-06:30 06:30-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-21:00 21:00-22:00 22:00-06:00 06:00-10:00 10:00-15:00 15:00-16:00 16:00-19:00 19:00-19:30 19:30-23:00 23:00-01:30 01:30-02:30 02:30-04:30 04:30-06:00 Duration 1/2hr 3hr lhr 1-1/2 hr 1/2hr 8-1/2 hr lhr 8hr 4hr 5hr lhr 3hr 1/2 hr 3-1/2 hr 2-1/2 hr lhr 2hr 1-1/2 hr Activity Held safety meeting Pulled BHA Rigged up Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 9545.0 ft (7in OD) Circulated at 9545.0 ft Ran Casing to 17000.0 ft (7in OD) Ran Casing to 21749.0 ft (7in OD) Circulated at 21749.0 ft Held safety meeting Mixed and pumped slurry - 70.000 bbl Tested Casing Wait on cement Bleed down well Installed Wellhead integral components Installed Tubing head spool Rigged up BOP stack Facility M Pt F Pad Progress Report Well MPF-17 Page 1 Rig Date 23 June 98 Date/Time 22 Jan 98 23 Jan 98 24 Jan 98 25 Jan 98 26 Jan 98 27 Jan 98 28 Jan 98 29 Jan 98 06:00-07:00 07:00-08:00 08:00-19:00 19:00-21:30 21:30-00:00 00:00-02:00 02:00-06:00 06:00-09:00 09:00-10:00 10:00-17:00 17:00-00:00 00:00-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00-13:00 13:00-14:00 14:00-01:00 01:00-02:00 02:00-06:00 06:00-10:30 10:30-11:30 11:30-20:00 20:00-20:30 20:30-21:30 21:30-06:00 06:00-08:30 08:30-09:00 09:00-10:30 10:30-13:00 13:00-15:00 15:00-17:30 17:30-20:00 20:00-02:00 02:00-04:30 04:30-06:00 06:00-12:30 12:30-16:30 16:30-19:00 19:00-04:30 04:30-05:30 05:30-06:00 06:00-11:30 11:30-20:00 20:00-23:00 23:00-01:00 01:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-16:30 16:30-18:00 Duration liar liar llhr 2-1/2 hr 2-1/2 hr 2hr 4hr 3hr lhr 7hr 7hr lhr lhr lhr 3hr 7hr lhr llhr lhr 4hr 4-1/2 hr lhr 8-1/2 hr 1/2 hr lhr 8-1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr 2-1/2 hr 2hr 2-1/2 hr 2-1/2 hr 6hr 2-1/2 hr 1-1/2 hr 6-1/2 hr 4hr 2-1/2 hr 9-1/2 hr lhr 1/2hr 5-1/2 hr 8-1/2 hr 3hr 2hr 2hr lhr 2hr 1/2 hr lhr lhr 8hr 1-1/2 hr Activity Rigged up BOP stack Serviced Drillfloor / Derrick Laid out 5in drill pipe from derrick Repaired Handling equipment Serviced BOP stack Serviced Drillstring handling equipment Tested BOP stack Tested BOP stack Serviced Drillfloor / Derrick Laid out 5in drill pipe from derrick Repaired BOP stack Tested BOP stack Installed Wear bushing Rigged up Drillstring handling equipment Singled in drill pipe to 1500.0 ft Singled in drill pipe to 6100.0 ft Serviced Block line Singled in drill pipe to 13900.0 ft Repaired Top drive Singled in drill pipe to 18700.0 ft Singled in drill pipe to 21663.0 ft Reverse circulated at 21663.0 ft Pulled out of hole to 0.0 ft Held safety meeting Rigged up sub-surface equipment - Other sub-surface equipment R.I.H. to 15100.0 ft R.I.H. to 18585.0 ft Circulated at 18585.0 ft Rigged up Rigging equipment R.I.H. to 18585.0 ft Retrieved Cable head Serviced Cable head R.I.H. to 18585.0 ft Conducted electric cable operations Retrieved Setting tools Pulled out of hole to 13600.0 ft Pulled out of hole to 0.0 ft Repaired Top drive Rigged up sub-surface equipment - Gun assembly Ran Drillpipe to 20929.0 ft (3-1/2in OD) Functioned TCP Circulated at 20655.0 ft Circulated at 20655.0 ft Pulled out of hole to 611.0 ft Rigged down sub-surface equipment - Gun assembly Made up BHA no. 2 R.I.H. to 8200.0 ft Serviced Block line R.I.H. to 15600.0 ft Serviced Drillfloor / Derrick R.I.H. to 19926.0 ft Reverse circulated at 19830.0 ft Pulled out of hole to 151.0 ft Pulled BHA Facility M Pt F Pad Progress Report Well MPF-17 Page 2 Rig Date 23 June 98 Date/Time 30 Jan 98 31 Jan 98 18:00-19:00 19:00-21:00 21:00-22:00 22:00-23:30 23:30-00:00 00:00-06:00 06:00-19:30 19:30-20:30 20:30-00:30 00:30-02:30 02:30-04:30 04:30-05:00 05:00-06:00 06:00-08:00 08:00-14:30 14:30-15:30 15:30-16:30 16:30-17:00 17:00-19:00 19:00-06:00 Duration lhr 2hr lhr 1-1/2 hr 1/2 hr 6hr 13-1/2 hr lhr 4hr 2hr 2hr 1/2 hr lhr 2hr 6-1/2 hr lhr lhr 1/2 hr 2hr llhr Activity Serviced BOP test plug assembly Serviced BOP stack Tested BOP stack Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 5650.0 ft (4-1/2in OD) Ran Tubing to 19548.0 ft (4-1/2in OD) Installed Bore protector Serviced BOP stack Removed BOP stack Installed Xmas tree Rigged down B ore protector Circulated at 19548.0 ft Circulated at 19548.0 ft Set Permanent packer at 19522.0 ft with 3000.0 psi Tested Tubing Tested Permanent packer Installed Hanger plug Rigged up Drillstring handling equipment Laid out 3-1/2in drill pipe from derrick Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 001 Client: BP Exploration (Alaska) Inc. Field: Milne Point Well Name: MPF-17 Permanent datum Mean Sea Level Depth measured from Drill Floor Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination 27.81 DEG Grid Convergence 0.00 DEG Total Correction 27.81 DEG 45.60 FT 46.60 FT 12.70 FT TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ye for W) 33.00 FT 33.00 FT 0.00 FT 0.00 FT Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 11.23 DEG Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 33.0 0.00 33.00 0.00 0.00 0.0 0.00 0.00 0.00 0.00 0.00 196.7 163.70 196.70 0.15 0.11 20.7 0.15 0.06 0.16 20.70 0.07 296.0 99.30 296.00 0.49 0.29 28.1 0.46 0.21 0.50 24.39 0.18 475.1 179.10 475.10 1.53 0.46 44.3 1.37 0.92 1.65 33.93 0.11 563.5 88.40 563.49 2.21 0.55 37.0 1.97 1.43 2.43 35.98 0.12 654.4 90.90 654.39 3.00 0.68 52.6 2.64 2.12 3.39 38.72 0.23 744.3 89.90 744.27 4.33 1.20 19.6 3.85 2.86 4.80 36.57 0.81 835.0 90.70 834.92 7.28 2.54 9.9 6.73 3.52 7.59 27.63 1.51 924.8 89.80 924.61 11.71 3.12 8,4 11.10 4.22 11.88 20.81 0.65 1019.8 95.00 1019,48 16.83 3.07 5.6 16.19 4.85 16.90 16.66 0.17 1113.4 93.60 1112.94 21.87 3.13 8.1 21.22 5.45 21.91 14.41 0.16 1206.7 93.30 1206.06 27.60 3.91 11.9 26.85 6.47 27.62 13.54 0.87 1298.4 91.70 1297.45 35.08 5.45 13.0 34.16 8.09 35.10 13.33 1.68 1393.4 95.00 1391.85 45.69 7.41 16.4 44.43 10.83 45.73 13.71 2.10 1485.4 92.00 1483.04 57.77 7.80 19.7 56.00 14.61 57.87 14.63 0.64 1578.7 93.30 1575.53 69.90 7.29 19.0 67.56 18.68 70.09 15.45 0.56 1672.7 94.00 1668.61 82.93 8.75 16.1 80.06 22.60 83.19 15.76 1.61 1766.3 93.60 1760.82 98.93 10.99 14.8 95.53 26.85 99.24 15.70 2.40 1859.9 93.60 1852.61 117,26 11.62 13.7 113.32 31.37 117.58 15.47 0.71 1953.4 93.50 1943.83 137.71 13.70 15.1 133.16 36.48 138.06 15.32 2.25 2045.9 92.50 2033.15 161.57 16.38 19.0 156.07 43.58 162.04 15.60 3.10 2138.7 92.80 2121.51 189.65 19.20 19.3 182.85 52.89 190.34 16.13 3.04 2232.2 93.50 2209,17 221.81 21.50 19.9 213.47 63.80 222.81 16.64 2.47 2326.2 94.00 2295.96 257.64 23.66 16.0 247.81 74.87 258.87 16.81 2.79 2420.6 94.40 2381.60 297.24 26.09 15.0 286.07 85.46 298.57 16.63 . 2.61 2516.3 95.70 2466.62 341.05 28.54 15.3 328.46 96.94 342.46 16.44 2.56 2607.3 91.00 2545.75 385.88 30.64 14.9 371.84 108.64 387.39 16.29 2.32 2700.6 93.30 2624.90 435.16 33.28 15.0 419.55 121.38 436.76 16.14 2.83 2794.9 94.30 2702.32 488.85 36.32 15.1 471.51 135.36 490.56 16.02 3.22 2890.4 95.50 2777.79 547.25 39.24 14.1 528.13 150.09 549.04 15.86 3.12 2980.3 89.90 2846.13 605.57 41.80 14.4 584.73 164.47 607.42 15.71 2.86 Page 1 ORIGINAL Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 3076.2 95.90 2916.02 671.13 44.62 14.0 648.38 180.57 673.06 15.56 2.95 3170.0 93.80 2981.30 738.42 47.17 13.2 713.85 196.39 740.37 15.38 2.79 3266.1 96.10 3045.37 809.99 49.19 13.5 783.52 212.93 811.94 15.20 2.11 3361.2 95.10 3105.73 883.41 52.01 13.4 854.99 230.02 885.39 15.06 2.97 3453.1 91.90 3160.84 956.90 54.29 13.2 926.55 246.94 958.89 14.92 2.49 3544.5 91.40 3212.37 1032.32 57.06 13.8 999.94 264.56 1034.35 14.82 3.08 3638.7 94.20 3261.58 1112.56 59.95 13.4 1078.00 283.44 1114.64 14.73 3.09 3733.6 94.90 3306.84 1195.89 63.07 13.8 1159,06 303.06 1198.02 14.65 3.31 3826.0 92.40 3346.64 1279.17 65.90 14.3 1239.94 323.30 1281.40 14.61 3.10 3919.3 93.30 3382.97 1364.97 68.27 14.4 1323.19 344.60 1367.33 14.60 2.54 4017.9 98.60 3417.82 1457.04 70.33 4112.5 94.60 3447.68 1546.59 72.87 4207.7 95.20 3473.55 1637.92 75.59 4302.0 94.30 3495.66 1729.22 77.28 4396.4 94.40 3516.29 1820.71 77.48 14.8 1412.44 367.85 1459.56 14.60 2.12 15.4 1499.10 391.24 1549.31 14.63 2.75 16.0 1587.29 416.03 1640.90 14.69 2.92 16.7 1675.25 441.84 1732.53 14.77 1.93 19.1 1762.90 470.15 1824.52 14.93 2.49 4491.4 95.00 3535.71 1912.81 78.93 4583.0 91.60 3552.66 2001.63 79.75 4676.5 93.50 3570.20 2091.67 78.62 4770.8 94.30 3588.60 2182.14 78.88 4863.1 92.30 3606.00 2270.90 79.39 19.2 1850.75 500.65 1917.27 15.14 1.53 21.9 1935.03 532.25 2006.89 15.38 3.03 23.4 2019.81 567.54 2098.03 15.69 1.90 23.1 2104.82 603.98 2189.76 16.01 0.35 22.8 2188.29 639.32 2279.77 16.29 0.64 4959.2 96.10 3624.64 2363.03 78.24 5051.9 92.70 3644.10 2450.94 77.53 5146.2 94.30 3664.24 2539.84 77,80 5239.2 93.00 3683.59 2627.77 78.18 5334.4 95.20 3702.83 2718.01 78.50 24.1 2274.78 676.83 2373.33 16.57 1.79 26.5 2356.71 715.56 2462.95 16.89 2.64 26.4 2439.19 756.60 2553.84 17.23 0.30 25.7 2520.92 796.54 2643.76 17.54 0.84 25.9 2604.86 837.12 2736.06 17.82 0.39 5426.1 91.70 3720.93 2804.92 78.74 5518.4 92.30 3738.56 2892.52 79.23 5614.1 95.70 3756.49 2983.54 79.17 5707.3 93.20 3774.19 3072.26 78.94 5801.1 93.80 3791.95 3161.58 79.23 26.2 2685.62 876.60 2825.06 18.08 0.41 25.8 2767.05 916.32 2914.82 18.32 0.68 25,6 2851.76 957.08 3008.08 18.55 0.21 25.2 2934.42 996.33 3098.95 18.75 0.49 25.5 3017.65 1035.77 3190.46 18.94 0.44 5893.9 92.80 3810.32 3249.93 77.94 5987.8 93.90 3830.43 3339.07 77.33 6089.7 101.90 3853.29 3435.60 76.74 6186~3 96.60 3875.32 3527.54 76.89 6279.7 93.40 3895.95 3617.10 77.60 24,5 3100.09 1074.21 3280.92 19.11 1.75 25.2 3183.32 1112.75 3372.20 19.27 0,98 24.4 3273.46 1154.41 3471.05 19.43 0.96 22.4 3359.77 1191.76 3564.88 19.53 2.02 21.1 3444,38 1225.51 3655.90 19.59 1.56 6373.9 94.20 3916.74 3707.92 76.90 6466.2 92.30 3937.85 3797.13 76.66 6558.8 92.60 3958.91 3886.88 77.04 6654.0 95.20 3978.86 3979.70 78.77 6748.3 94.30 3997.37 4071.96 78.59 18.7 3530.76 1256.78 3747.77 19.59 2.59 17.4 3616.19 1284.62 3837.59 19.56 1.40 16.1 3702.54 1310.61 3927.65 19.49 1.43 15.0 3792.21 1335,56 4020.52 19.40 2.14 15.1 3881.51 1359.57 4112.73 19.30 0.22 6839.2 90.90 4015.15 4160.95 78.86 6933.9 94.70 4033.54 4253.70 78.74 7028.9 95.00 4052.02 4346.73 78.83 7123.8 94.90 4070.14 4439.79 79.15 7218.9 95.10 4088.26 4533.09 78,88 14.2 3967.75 1382.12 4201.58 19.21 1.02 14.7 4057.71 1405.30 4294.17 19.10 0.53 14.4 4147.91 1428.71 4387.06 19.01 0.32 13.1 4238.39 1450.85 4479.83 18.90 1.39 13.1 4329.32 1472.01 4572.72 18.78 0.28 Page 2 Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7312.7 93.80 4106.33 4625.09 78.91 13.1 4418.96 1492.87 4664.32 18.67 0.03 7407.0 94.30 4123.93 4717.72 79.58 10.6 4509.63 1511.89 4756.31 18.53 2.70 7498.1 91.10 4140.54 4807.29 79.41 11.3 4597.57 1528.90 4845.12 18.39 0.78 7592.4 94.30 4157.68 4900.02 79.64 11.6 4688.45 1547.31 4937.18 18.26 0.40 7685.5 93.10 4174.39 4991.60 79.69 11.8 4778.14 1565.88 5028.18 18.14 0.22 7778.9 93.40 4190.86 5083.53 79.99 12.2 4868.06 1585.00 5119.59 18.03 0.53 7873.7 94.80 4207.44 5176.87 79.87 11.3 4959.45 1604.01 5212.38 17.92 0.94 7967.1 93.40 4224.24 5268.74 79.40 11.8 5049.46 1622.40 5303.70 17.81 0.73 8061.8 94.70 4242.01 5361.76 78.97 10.9 5140.66 1640.71 5396.14 17.70 1.04 8154.4 92.60 4259.62 5452.67 79.11 11.8 5229.79 1658.60 5486.50 17.60 0.97 8248.3 93.90 4277.63 5544.82 78.77 8339.9 91.60 4295.36 5634.68 78.91 8432.9 93.00 4314.09 5725.77 77.86 8526.6 93.70 4333.65 5817.41 78.04 8621.4 94.80 4354.38 5909.90 76.69 10.3 5320.23 1676.26 5578.06 17.49 1.61 11.3 5408.51 1693.10 5667.32 17.38 1.08 11.8 5497.76 1711.34 5757.95 17.29 1.25 10.5 5587.66 1729.06 5849.07 17.19 1.37 10.4 5678.63 1745.84 5940.94 17.09 1.43 8716.2 94.80 4376.44 6002.10 76.40 8808.2 92.00 4398.33 6091.45 76.07 8902.3 94.10 4420.72 6182.84 76.40 8996.5 94.20 4442.90 6274.39 76.37 9090.4 93.90 4465.29 6365.56 76.05 11.1 5769.21 1763.03 6032.58 16.99 0.78 11.3 5856.87 1780.39 6121.49 16.91 0.42 9.9 5946.70 1797.20 6212.34 16.82 1.49 12.6 6036.48 1815.06 6303.46 16.74 2.79 12.1 6125.57 1834.57 6394.39 16.67 0.62 9184.4 94.00 4487.99 6456.75 75.99 9278.5 94.10 4510.80 6548.00 75.96 9371.6 93.10 4533.83 6638.18 75.40 9465.2 93.60 4557.31 6728.76 75.54 9657.0 191.80 4604.77 6914.58 75.81 13.3 6214.55 1854.62 6485.39 16.62 1.24 12.5 6303.54 1875.00 6576.49 16.57 0.83 12.6 6391.59 1894.60 6666.48 16.51 0.61 12.6 6480.02 1914.37 6756.88 16.46 0.15 10.2 6662.17 1951.09 6942.00 16.32 1.22 9749.7 92.70 4628.05 7004.30 75.10 10.2 6750.48 1966.98 7031.22 16.25 0.77 9843.8 94.10 4652.38 7095.16 74.93 9.2 6840.08 1982.30 7121.53 16.16 1.04 9939.5 95.70 4677.68 7187.39 74.42 8.9 6931.23 1996.82 7213.13 16.07 0.61 10033.2 93.70 4703.45 7277.39 73.65 8.4 7020.29 2010.37 7302.47 15.98 0.97 10128.8 95.60 4730.10 7369.14 73.98 10.1 7110.90 2025.12 7393.65 15.90 1.74 10222.6 93.80 4755.48 7459.44 74.62 12.0 7199.52 2042.43 7483.63 15.84 2.07 10316.7 94.10 4781.18 7549.95 73.68 11.2 7288.19 2060.64 7573.90 15.79 1.29 10411.4 94.70 4808.29 7640.69 73.05 10.7 7377.28 2077.87 7664.32 15.73 0.84 10504.5 93.10 4835.78 7729.64 72.61 11.2 7464.61 2094.77 7752.96 15.68 0.70 10598.5 94.00 4863.62 7819.42 72.93 10.9 7552.73 2111.98 7842.46 15.62 0.46 10692.2 93.70 4891.45 7908.89 72.51 11.6 7640.48 2129.43 7931.67 15.57 0.84 10787.4 95.20 4920.02 7999.70 72.57 12.1 7729.35 2148.08 8022.29 15.53 0.50 10879.2 91,80 4947.55 8087.26 72.53 12.5 7814.92 2166.74 8109.73 15.50 0.42 10972.4 93.20 4974,87 8176.33 73.37 12.9 7901.84 2186.32 8198.73 15.47 0.99 11067.1 94.70 5000.84 8267.33 74.80 14.0 7990.41 2207.51 8289.74 15.44 1.88 11161.4 94.30 5026.22 8358.06 73.98 11255.6 94.20 5052.38 8448.50 73.77 11349.8 94.20 5078.47 8538.96 74.07 11443.8 94.00 5104.88 8629.16 73.29 11537.9 94.10 5130.93 8719.57 74.57 13.4 8078.65 2229.02 8380.52 15.42 1.06 13.3 8166.69 2249.92 8470.95 15.40 0.25 12.8 8254.87 2270.35 8561.39 15.38 0.60 11.6 8343.04 2289.42 8651.46 15.34 1.48 12.4 8431.49 2308.22 8741.73 15.31 1.59 Page 3 Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 11631.5 93.60 5156.43 8809.63 73.82 11727.4 95.90 5183.00 8901.77 74.01 11822.0 94.60 5209.06 8992.71 74.00 11915.3 93.30 5235.41 9082.20 73.20 12009.5 94.20 5261.48 9172.72 74.66 N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 11.3 8519.63 2326.72 8831.63 15.28 1.39 11.2 8610.00 2344.69 8923.55 15.23 0.22 10.7 8699.28 2361.97 9014.23 15.19 0.51 10.4 8787.27 2378.35 9103.45 15.14 0.91 11.3 8876.17 2395.39 9193.71 15.10 1.80 12103.7 94.20 5287.18 9263.34 73.68 12195.4 91.70 5313.18 9351.27 73.38 12288.8 93.40 5339.87 9440.78 73.41 12381.9 93.10 5366.68 9529.93 73.11 12475.3 93.40 5393.63 9619.36 73.35 10.3 8965.19 2412.38 9284.08 15.06 1.46 10.7 9051.65 2428.40 9371.74 15.02 0.53 11.2 9139.53 2445.40 9461.03 14.98 0.51 11.2 9226.99 2462.72 9549.99 14.94 0.32 11.0 9314.74 2479.94 9639.22 14.91 0.33 12568.3 93.00 5420.42 9708.42 73.17 12662.8 94.50 5447.42 9798.97 73.62 12756.7 93.90 5474.63 9888.84 72.70 12850.8 94.10 5502.64 9978.66 72.66 12944.4 93.60 5529.47 10068.32 74.03 11.0 9402.16 2496.93 9728.07 14.87 0.19 10.9 9491.07 2514.13 9818.42 14.84 0.49 10.3 9579.41 2530.67 9908.05 14.80 1.15 10.0 9667.84 2546,50 9997.59 14.76 0.31 11.4 9755.95 2563.15 10087.03 14.72 2.05 13036.4 92.00 5554.12 10156.96 74.89 13130.3 93.90 5579.05 10247.48 74.31 13223.6 93.30 5604.33 10337.29 74.25 13316.7 93.10 5628.31 10427.24 75.90 13411.5 94.80 5651.47 10519.13 75.81 11.8 9842.77 2580.97 10175.54 14.69 1.02 11.6 9931.42 2599.33 10265.94 14.67 0.65 11.8 10019.36 2617.54 10355.64 14.64 0.22 12.3 10107.34 2636.32 10445.50 14.62 1.85 13.0 10197.03 2656.46 10537.37 14.60 0.72 13505.8 94.30 5674.91 10610.44 75.41 13599.3 93.50 5698.07 10701.01 75.90 13693.9 94.60 5720.40 10792.91 76.80 13786.0 92.10 5741.74 10882.49 76.41 13880.5 94.50 5764.32 10974.25 75.94 12.4 10286.14 2676.54 10628.66 14.59 0.75 12.4 10374.61 2695.99 10719.18 14.57 0.52 12.6 10464.37 2715.81 10811.05 14.55 0.96 12.1 10551.91 2734.89 10900.57 14.53 0.60 11.4 10641.75 2753.58 10992.23 14.51 0.87 13975.6 95.10 5787.90 11066.38 75.34 14070.4 94.80 5812.30 11157.98 74.83 14165.0 94.60 5837.39 11249.19 74.42 14260.0 95.00 5863.28 11340.57 73.95 14356.4 96.40 5889.28 11433.38 74.75 11.4 10732.06 2771.79 11084.22 14.48 0.63 10.7 10821.97 2789.35 11175.66 14.45 0.89 10.1 10911.68 2805.81 11266.65 14.42 0.75 9.8 11001.71 2821.61 11357.78 14.38 0.58 10.7 11093.05 2838.13 11450.36 14.35 1.22 14449.1 92.70 5914.06 11522.69 74.24 14540.9 91.80 5939.13 11610.98 74.06 14633.4 92.50 5965.07 11699.77 73.38 14728.0 94.60 5992.42 11790.32 73.00 14825.2 97.20 6021.38 11883.09 72.34 9.8 11180.95 2854.02 11539.46 14.32 1.09 10.6 11267.87 2869.66 11627.54 14.29 0.86 10.6 11355.14 2885.99 11716.15 14.26 0.74 10.5 11444.17 2902.57 11806.52 14.23 0.41 9.6 11535.53 2918.77 11899.06 14.20 1.11 14914.5 89.30 6048.94 11967.99 71.70 15010.9 96.40 6078.88 12059.59 72.12 15105.9 95.00 6108.63 12149.79 71.38 15201.4 95.50 6138.57 12240.46 72.08 15295.3 93.90 6167.54 12329.77 71.97 9.4 11619.30 2932.79 11983.72 14.17 0.75 10.1 11709.61 2948.31 12075.08 14.13 0.82 9.7 11798.49 2963.82 12165.06 14.10 0.88 11.3 11887.65 2980.35 12255.56 14.07 1.75 11.9 11975.15 2998.30 12344.79 14.06 0.62 15387.7 92.40 6196.07 12417.65 72.07 15481.8 94.10 6224.18 12507.41 73.16 15570.2 88.40 6250.56 12591.72 72.12 15663.9 93.70 6278.11 12681.18 73.68 15757.7 93.80 6303.36 12771.41 75.09 12.5 12061.05 3016.88 12432.64 14.04 0.63 13.2 12148.60 3036.85 12522.42 14.03 1.36 13.7 12230.66 3056.47 12606,78 14.03 1.29 14.1 12317.59 3077.99 12696.34 14.03 1.71 13.9 12405.24 3099.84 12786.67 14.03 1.52 Page 4 Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 005 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 15851.2 93.50 6327.90 12861.56 15947.5 96.30 6354.26 12954.13 16041.6 94.10 6381.27 13044.23 16137.2 95.60 6408.57 13135.79 16230.5 93.30 6434.93 13225.22 STATION INCLN. DEG 74.48 73.74 72.90 73.92 73.26 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 13.2 12492.95 3120.98 12876.89 14.03 0.97 13.0 12583.16 3141.97 12969.50 14.02 0.79 12.9 12671.01 3162.18 13059.62 14.01 0.90 13.5 12760.21 3183.10 13151.23 14.01 1.22 13.6 12847.21 3204.07 13240.73 14,00 0.71 16322.6 92.10 6460.90 13313.51 16415.5 92.90 6486.78 13402.68 16507.0 91.50 6512.86 13490.36 16601.8 94.80 6540.33 13581.07 16695.3 93.50 6566.76 13670.72 73.98 73.67 73.20 73.12 74.04 13.4 12933.13 3224.69 13329.09 14.00 0.81 12.8 13020.03 3244.92 13418.30 13.99 0.70 12.4 13105.62 3264.05 13505.98 13.99 0.66 12.6 13194.21 3283.69 13596.68 13.98 0.22 13.4 13281.59 3303.86 13686.35 13.97 1.28 16789.0 93.70 6593.15 13760.57 16882.2 93.20 6620.69 13849.57 16975.5 93.30 6647.82 13938.83 17074.7 99.20 6676.04 14033.91 17169.0 94.30 6702.88 14124.29 73.24 72.38 73.82 73.12 73.81 13.0 13369.12 3324.39 13776.25 13.96 0.95 12.4 13455.98 3343.97 13865.26 13.96 1.11 12.3 13543.18 3363.06 13954.50 13.95 1.55 11.7 13636.20 3382.83 14049.54 13.93 0.91 13.0 13724.51 3402.17 14139.90 13.92 1.51 17263.8 94.80 6729.98 14215.10 17360.1 96.30 6757.08 14307.46 17451.1 91.00 6781.74 14395.04 17546.8 95.70 6807.25 14487.27 17640.0 93.20 6831.91 14577.14 72.97 74.34 74.21 74.87 74.45 12.8 13813.06 3422.45 14230.73 13.92 0.91 13.1 13903.11 3443.16 14323.12 13.91 1.45 11.7 13988.66 3461.97 14410.69 13.90 1.49 12.1 14078.92 3480.99 14502.87 13.89 0.80 11.2 14166.94 3499.14 14592.68 13.87 1.03 17735.3 95.30 6857.91 14668.83 17828.0 92.70 6883.76 14757.84 17922.2 94.20 6909.26 14848,52 18016.1 93.90 6934.25 14939.03 18107.2 91.10 6959.27 15026.63 73.89 73.72 74.87 74.26 73.86 11.0 14256.91 3516.79 14684.25 13.86 0.62 10.4 14344.38 3533.32 14773.14 13.84 0.65 11.2 14433.46 3550.31 14863.69 13.82 1.47 10.9 14522.29 3567.66 14954.10 13.80 0.72 10.8 14608.32 3584.15 15041.58 13,79 0.45 18201.9 94.70 6985.26 15117.69 18295.2 93.30 7011.14 15207.32 18389.0 93.80 7036.85 15297.52 18483.9 94.90 7062.69 15388.83 18577.8 93.90 7089.01 15478.95 74.28 73.51 74.67 73.74 73.70 10.8 14697.77 3601.22 15132.52 13.77 0.44 10.3 14785.89 3617.63 15222.02 13.75 0.97 10.7 14874.59 3634.07 15312.08 13.73 1.30 10.3 14964.38 3650.71 15403.25 13.71 1.06 10.2 15053.07 3666.75 15493.23 13.69 0.11 18672.0 94.20 7114.97 15569.49 18765.1 93.10 7140.60 15658.99 18857.9 92.80 7165.71 15748.32 18952.6 94.70 7191.15 15839.54 19005.7 53.10 7206.08 15890.48 74.30 73.74 74.87 73.96 73.39 10.6 15142.13 3683.09 15583.63 13.67 0.76 11.1 15230.04 3699.94 15673.02 13.65 0.79 10.6 15317.78 3716.76 15762,25 13.64 1.32 10.5 15407.45 3733.46 15853.34 13.62 0.97 9.8 15457.61 3742.44 15904,20 13.61 1.66 19099.2 93.50 7232.99 15979.98 19196.0 96.80 7260.83 16072.62 19290.1 94.10 7287.13 16162.88 19383.1 93.00 7311.98 16252.39 19478.3 95.20 7336.47 16344.25 73.15 73.42 74.13 74.87 75.32 9.0 15545.95 3757.06 15993.50 13.59 0.86 8.9 15637.53 3771.49 16085.91 13.56 0.30 8.6 15726.83 3785.23 16175.95 13.53 0.81 8.1 15815.50 3798.25 16265.20 13.50 0.95 8.1 15906,58 3811.21 16356.79 13.47 0.47 19568.9 90.60 7359.04 16431.86 19663.3 94.40 7382.10 16523.26 19757.1 93.80 7404.80 16614.10 19849.1 92.00 7427.02 16703.31 19944.7 95.60 7450.67 16795.94 75.82 75.91 76.08 75.97 75.38 8.2 15993.44 3823.65 16444.16 13.45 0.56 7.8 16084.09 3836.39 16535.29 13.42 0.42 7.7 16174.27 3848.66 16625.86 13.38 0.21 10.9 16262.36 3863.08 16714.89 13.36 3.38 10.2 16353.42 3880.04 16807.41 13.35 0.94 Page 5 Survey_PROJ.ASCII_FILE Schlumberger ANADRILL Survey Report 18-JAN-98 20:00:56 Page 006 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 20036.0 91.30 7474.56 16884.02 74.29 20132.3 96.30 7499.13 16977.08 76.14 20226.1 93.80 7519.78 17068.54 78.42 20319.7 93.60 7536.48 17160.60 81.03 20433.5 113.80 7554.08 17273.01 81.17 N/-S E/-W CEMENT DEG FT FT FT 9.1 16440.29 3894.82 16895.35 9.6 16532.16 3909.95 16988.23 9.8 16622.34 3925.36 17079.54 10.1 16713.05 3941.28 17171.48 9.9 16823.77 3960.80 17283.72 DEG D/HF 13.33 1.67 13.31 1.99 13.29 2.44 13.27 2.81 13.25 0.21 20523.9 90.40 7568.00 17362.30 81.12 20618.2 94.30 7583.05 17455.35 80.52 20712.8 94.60 7599.07 17548.53 79.99 20805.2 92.40 7615.16 17639.47 79.96 20900.0 94.80 7631.14 17732.89 80.63 9.8 16911.78 3976.08 17372.89 9.1 17003.60 3991.36 17465.78 9.3 17095.64 4006.27 17558.79 9.8 17185.36 4021.36 17649.59 9.9 17277.43 4037.35 17742.88 13.23 0.12 13.21 0.98 13.19 0.59 13.17 0.53 13.15 0.71 20994.8 94.80 7645.54 17826.55 81.89 21087.8 93.00 7657.31 17918.70 83.57 21181.8 94.00 7666.46 18012.08 85.26 21275.4 93.60 7673.66 18105.22 85.92 21368.0 92.60 7679.44 18197.45 86.92 9.3 17369.81 4052.98 17836.40 8.0 17461.01 4066.85 17928.36 7.6 17553.70 4079.54 18021.51 7.6 17646.20 4091.89 18114.41 7.5 17737.82 4104.03 18206.40 13.13 1.47 13.11 2.28 13.08 1.85 13.06 0.71 13.03 1.09 21460.4 92.40 7683.74 18289.58 87.74 21555.2 94.80 7688.87 18384.07 86.06 21648.9 93.70 7695.58 18477.33 85.72 21680.6 31.70 7697.94 18508.87 85.74 8.1 17829.26 4116.55 18298.32 7.6 17923.03 4129.48 18392.60 7.3 18015.70 4141.60 18485.63 7.3 18047.06 4145.62 18517.09 13.00 1.10 12.97 1.85 12.95 0.48 12.94 0.06 Survey Projected to TD: 21781.0 100.40 7705.40 18608.75 85.74 7.3 18146.37 4158.34 18616.73 12.91 0.00 Page 6 ORIGINAL B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Gyro Continuous Muitishot Survey Inside 5" DRILL PIPE Survey date: 10 -JANUARY, 1998 Job number :A0198GCE438 CONTENTS JOB NUMBER :A0198GCE438 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER: A0198GCE438 Tool 777 was run in WELL# MPF-17 on ATLAS 5/16" wireline inside DRILL PIPE. The survey was run without problems. Both the inrun and the outrun showed a tvd discrepancy of approximately 30' in the build. This difference could be attributed to a wireline or a mwd measured depth error. SURVEY CERTIFICATION SHEET JOB NUMBER: A0198GCE438 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the odginal data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A01c,:,:JSGCE438 CLIENT: B.P. EXPLORATION RIG: NABORS 27E LOCATION: F PAD, ALASKA WELL: MPF- 17 LATITUDE: 70.507 N LONGITUDE: 149.5 W SURVEY DATE: 10- JANUARY, 1998 SURVEY TYPE : GYRO CONTINOUS MULTISHOT IN 5" DRILL PIPE DEPTH REFERENCE: ROTARY TABLE ELEVATION 45.7 MAX. SURVEY DEPTH: 11700' ' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-11700' APl NUMBER: 050-029-228 TARGET DIRECTION: 11.23 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN/OUTRUN SURVEY LISTING A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Run Date: 10-Jan-98 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 45.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 11.230 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t i on a i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 100.0 200.0 300.0 400.0 0.00 0.00 0.0 .12 57.89 100.0 .16 92.45 200.0 .29 23.84 300.0 .51 42.15 400.0 0.0 0.00 0.0 0.0 .1 .12 .1 57.9 .2 .09 .3 71.8 .4 .27 .6 59.5 1.0 .26 1.3 47.1 0.00 N 0.00 E .05 N .09 E .10 N .31 E .32 N .55 E .88 N .95 E 500.0 600.0 700.0 800.0 900.0 .42 82.62 500.0 .39 38.40 600.0 .62 44.48 700.0 1.85 15.59 800.0 2.89 9.79 899.9 1.5 .33 2.0 52.0 2.0 .31 2.7 54.2 2.7 .24 3.6 51.2 4.8 1.34 5.5 40.7 8.9 1.06 9.3 28.5 1.26 N 1.61 E 1.57 N 2.19 E 2.23 N 2.78 E 4.18 N 3.60 E 8.22 N 4.46 E 1000.0 1100.0 1200.0 1300.0 1400.0 3.11 9.21 999.7 3.10 10.70 1099.6 3.56 11.05 1199.4 5.32 15.23 1299.1 7.17 18.35 1398.5 14.2 .22 14.4 21.7 19.6 .08 19.7 18.5 25.4 .47 25.5 16.8 33.1 1.79 33.2 16.0 43.9 1.88 44.1 16.3 13.37 N 5.32 E 18.70 N 6.26 E 24.40 N 7.35 E 31.92 N 9.17 E 42.32 N 12.35 E 1501.0 7.67 17.13 1498.7 1600.0 7.39 20.76 1596.8 1700.0 8.79 16.21 1695.8 1800.0 11.16 14.26 1794.3 1900.0 11.82 15.58 1892.3 56.9 .52 57.1 16.6 69.7 .56 70.1 17.0 83.7 1.54 84.1 17.2 101.0 2.39 101.4 16.9 120.8 .71 121.4 16.6 54.74 N 16.32 E 67.01 N 20.52 E 80.36 N 24.93 E 97.08 N 29.45 E 116.32 N 34.58 E 2000.0 14.48 18.55 1989.7 2050.0 16.04 19.59 2037.9 2100.0 17.13 20.27 2085.8 2200.0 19.73 19.82 2180.7 2300.0 22.31 17.95 2274.0 143.4 2.74 144.1 16.7 156.5 3.18 157.2 16.9 170.6 2.20 171.5 17.1 201.8 2.61 203.1 17.6 237.4 2.66 238.9 17.8 138.04 N 41.31 E 150.47 N 45.62 E 163.89 N 50.48 E 193.59 N 61.31 E 227.53 N 72.89 E A Gyro da t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2400.0 2500.0 2600.0 2700.0 2800.0 24.89 15.43 2365.7 27.62 14.86 2455.3 29.87 14.82 2543.0 32.53 14.96 2628.5 35.71 15.08 2711.3 277.2 2.77 278.9 17.6 321.3 2.75 323.1 17.3 369.3 2.25 371.2 16.9 421.0 2.66 423.0 16.7 477.0 3.18 479.0 16.5 265.88 N 84.34 E 308.57 N 95.88 E 355.06 N 108.20 E 405.13 N 121.51 E 459.30 N 136.05 E 2900.0 3000.0 3100.0 3200.0 3300.0 38.81 14.36 2790.9 41.64 14.03 2867.2 44.57 13.87 2940.2 47.43 13.85 3009.7 49.47 13.77 3076.0 537.4 3.12 539.5 16.3 601.9 2.84 604.1 16.1 670.2 2.93 672.3 15.9 742.0 2.87 744.2 15.7 816.8 2.04 819.0 15.5 517.85 N 151.42 E 580.45 N 167.24 E 646.76 N 183.71 E 716.59 N 200.94 E 789.26 N 218.80 E 3400.0 3500.0 3600.0 3700.0 3800.0 52.02 13.54 3139.3 54.58 13.78 3199.0 57.78 14.24 3254.7 60.77 14.12 3305.8 64.58 14.15 3351.7 894.1 2.56 896.4 15.3 974.2 2.56 976.6 15.2 1057.2 3.22 1059.6 15.1 1143.0 3.00 1145.6 15.0 1231.7 3.80 1234.4 15.0 864.50 N 237.08 E 942.41 N 256.01 E 1023.00 N 276.12 E 1106.34 N 297.18 E 1192.47 N 318.87 E 3900.0 4000.0 4100.0 4200.0 4300.0 66.87. 14.21 3392.8 69.12 14.65 3430.3 71.26 15.40 3464.2 74.10 15.93 3493.9 76.44 16.69 3519.3 1322.8 2.30 1325.5 14.9 1415.3 2.28 1418.2 14.9 1509.2 2.25 1512.3 14.9 1604.4 2.89 1607.7 14.9 1700.7 2.45 1704.4 15.0 1280.85 N 341.20 E 1370.63 N 364.30 E 1461.49 N 388.69 E 1553.40 N 414.47 E 1646.21 N 441.62 E 4400.0 4500.0 4600.0 4700.0 4800.0 77.26 18.41 3542.1 78.57 19.04 3563.0 79.63 20.91 3581.9 78.65 22.79 3600.8 78.78 22.86 3620.3 1797.5 1.87 1801.7 15.2 1894.4 1.44 1899.3 15.3 1991.5 2.12 1997.2 15.6 2088.0 2.09 2094.8 15.9 2184.1 .15 2192.2 16.2 1739.06 N 470.98 E 1831.66 N 502.37 E 1923.94 N 535.92 E 2015.09 N 572.47 E 2105.48 N 610.51 E A Gyro d a t a D i r e c t i on a i S u rv e y B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 4900.0 5000.0 5100.0 5200.0 5300.0 79.17 22.70 3639.5 2280 77.79 24.22 3659.4 2376 77.39 26.18 3680.9 2470 77.87 25.89 3702.3 2565 78.21 25.77 3723.1 2659 .2 .0 .8 .2 .9 41 2289.7 16.5 02 2387.0 16.7 96 2483.7 17.1 55 2580.2 17.4 37 2677.0 17.7 2195.98 N 648.52 E 2285.86 N 687.52 E 2374.22 N 729.10 E 2461.99 N 771.98 E 2550.04 N 814.61 E 5400 5500 5600 5700 5800 .0 .0 .0 .0 .0 78.75 25.49 3743.0 2754 78.69 25.52 3762.6 2849 78.71 25.60 3782.2 2944 78.54 25.39 3801.9 3039 78.91 25.11 3821.5 3135 .8 .8 .8 .8 .0 60 2774.1 18.0 07 2871.3 18.3 08 2968.6 18.5 27 3066.0 18.7 46 3163.4 18.9 2638.38 N 2726.89 N 2815.36 N 2903.85 N 2992.55 N 857.00 E 899.23 E 941.53 E 983.73 E 1025.56 E 5900 6000 6100 6200 6300 .0 .0 .0 .0 .0 77.84 24.56 3841.6 3230 77.08 24.50 3863.3 3325 76.45 23.97 3886.2 3420 76.61 21.88 3909.5 3515 77.51 20.71 3931.9 3611 .2 .2 .0 .2 .2 . 21 3260.8 19.1 76 3358.0 19.3 81 3455.0 19.4 05 3552.1 19.5 45 3649.5 19.5 3081.44 N 3170.24 N 3259.00 N 3348.57 N 3439.37 N 1066.70 E 1107.23 E 1147.18 E 1185.06 E 1220.45 E 6400 6500 6600 6700 6800 .0 .0 .0 .0 .0 77.00 18.53 3954.0 3707 76.74 17.12 3976.7 3804 77.46 15.47 3999.1 3901 78.50 14.97 4019.9 3999 78.64 14.66 4039.7 4096 .7 .4 .5 .1 .9 . 1. 1. 1. 19 3747.0 19.5 40 3844.4 19.5 77 3941.7 19.4 15 4039.2 19.3 34 4137.0 19.2 3531.24 N 3623.94 N 3717.50 N 3811.88 N 3906.63 N 1253.21 E 1283.02 E 1310.36 E 1336.03 E 1361.09 E 6900.0 7000.0 7100.0 7200.0 7300.0 78.91 14.26 4059.2 78.69 14.38 4078.6 78.77 12.86 4098.1 78.59 12.61 4117.8 78.96 12.58 4137.2 4194.8 4292.8 4390.8 4488.8 4586.9 47 4234.7 19.1 25 4332.5 19.0 48 4430.1 18.9 30 4527.6 18.7 36 4625.2 18.6 4001.61 N 4096.66 N 4191.97 N 4287.61 N 4383.34 N 1385.59 E 1409.85 E 1432.94 E 1454.56 E 1475.95 E A Gyroda t a Di re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7400.0 7500.0 7600.0 7700.0 7800.0 79.70 11.81 4155.7 4685 79.35 11.45 4173.9 4783 79.48 11.34 4192.3 4881 79.62 11.33 4210.4 4980 80.07 11.35 4228.1 5078 .1 .4 .7 .1 .5 1.06 4722.8 18.5 .49 4820.5 18.3 .17 4918.1 18.2 .13 5015.7 18.1 .46 5113.5 17.9 4479.39 N 1496.70 E 4575.71 N 1516.52 E 4672.07 N 1535.95 E 4768.49 N 1555.27 E 4865.00 N 1574.63 E 7900 8000 8100 8200 8300 .0 .0 .0 .0 .0 80.12 11.19 4245.3 5177 79.27 11.19 4263.2 5275 78.83 11.06 4282.2 5373 79.02 10.91 4301.4 5471 78.85 10.63 4320.6 5569 .0 .4 .6 .7 .9 .17 5211.3 17.8 .85 5309.1 17.7 .45 5406.6 17.6 .24 5504.1 17.5 .33 5601.6 17.3 4961.61 N 1593.88 E 5058.13 N 1612.97 E 5154.46 N 1631.92 E 5250.80 N 1650.63 E 5347.21 N 1668.96 E 8400 8500 8600 8700 8800 .0 .0 .0 .0 .0 78.93 10.51 4339.8 5668 77.53 10.43 4360.2 5765 77.16 10.41 4382.1 5863 76.86 10.30 4404.6 5960 76.26 10.29 4427.8 6058 .0 .9 .4 .9 .1 · 14 5699.1 17.2 1.40 5796.3 17.1 · 37 5893.2 17.0 · 32 5990.0 16.9 · 60 6086.6 16.8 5443.67 N 1686.96 E 5539.94 N 1704.75 E 5635.90 N 1722.39 E 5731.76 N 1739.90 E 5827.45 N 1757.28 E 8900 9000 9100 9200 9300 .0 .0 .0 .0 .0 76.55 10.33 4451.3 6155 76.46 10.73 4474.7 6252 76.02 12.75 4498.5 6349 76.02 12.63 4522.6 6446 76.12 12.33 4546.7 6543 .3 .5 .6 .6 .7 .28 6183.2 16.7 .40 6279.9 16.6 2.01 6376.7 16.5 .12 6473.5 16.5 .31 6570.4 16.4 5923.08 N 6018.68 N 6113.78 N 6208.44 N 6303.21 N 1774.67 E 1792.45 E 1812.22 E 1833.54 E 1854.51 E 9400 9450 9500 9550 9600 .0 .0 .0 .0 .0 75.83 12.17 4570.9 6640 75.38 12.01 4583.4 6689 75.25 11.92 4596.0 6737 76.19 11.84 4608.4 6785 75.96 11.71 4620.4 6834 .7 .1 .5 .9 .5 .33 6667.1 16.3 .95 6715.4 16.3 .30 6763.7 16.3 1.88 6812.0 16.2 .52 6860.4 16.2 6398.02 N 6445.37 N 6492.69 N 6540.11 N 6587.62 N 1875.09 E 1885.23 E 1895.26 E 1905.23 E 1915.13 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 9650.0 9700.0 9750.0 9800.0 9850.0 76.27 11.24 4632.4 75.81 10.87 4644.5 74.91 10.59 4657.1 75.22 10.18 4670.0 75.00 9.94 4682.8 6883.0 6931.5 6979.9 7028.2 7076.5 1.10 6908.7 16.2 1.17 6957.1 16.1 1.87 7005.2 16.1 1.00 7053.3 16.1 .63 7101.3 16.0 6635.18 N 1924.79 E 6682.81 N 1934.09 E 6730.34 N 1943.10 E 6777.86 N 1951.80 E 6825.44 N 1960.24 E 99 99 100 100 101 00 50 00 50 00 .0 .0 .0 .0 .0 74.97 9.48 4695.8 74.61 9.25 4708.9 74.00 8.93 4722.4 74.03 8.55 4736.2 73.41 8.42 4750.2 7124 7173 7221 7269 7317 .8 .0 .1 .1 .1 .89 7149.3 16.0 .84 7197.3 15.9 1.36 7245.1 15.9 .75 7292.8 15.8 1.26 7340.4 15.8 6873.04 N 1968.39 E 6920.64 N' 1976.24 E 6968.17 N 1983.85 E 7015.68 N 1991.15 E 7063.15 N 1998.23 E 101 102 102 103 103 50 00 50 00 50 .0 .0 .0 .0 .0 73.88 9.91 4764.3 7365 73.82 10.37 4778.2 7413 74.24 11.86 4792.0 7461 74.45 11.78 4805.5 7509 73.70 11.53 4819.2 7557 .0 .0 .1 .2 .3 3.01 7388.0 15.8 .88 7435.8 15.7 2.99 7483.7 15.7 .44 7531.8 15.7 1.58 7579.7 15.6 7110.51 N 7157.79 N 7204.95 N 7252.08 N 7299.17 N 2005.88 E 2014.34 E 2023.60 E 2033.46 E 2043.18 E 10400 10450 10500 10550 10600 .0 .0 .0 .0 .0 73.27 11.19 4833.4 7605 73.03 10.85 4847.9 7653 72.23 10.50 4862.8 7700 73.18 11.38 4877.7 7748 73.03 11.48 4892.2 7796 .3 .1 .8 .6 .4 1.07 7627.5 15.6 .81 7675.2 15.6 1.73 7722.8 15.6 2.54 7770.4 15.5 .35 7818.1 15.5 7346.16 N 7393.13 N 7440.03 N 7486.90 N 7533.79 N 2052.62 E 2061.76 E 2070.60 E 2079.66 E 2089.14 E 10650 10700 10750 10800 10850 .0 .0 .0 .0 .0 72.90 11.01 4906.9 7844 72.57 10.85 4921.7 7892 72.93 12.30 4936.5 7939 72.92 12.28 4951.2 7987 72.43 12.10 4966.1 8035 .2 .0 .7 .5 .2 .94 7865.8 15.5 .72 7913.4 15.4 2.86 7961.0 15.4 .05 8008.7 15.4 1.04 8056.4 15.4 7580.68 N 7627.56 N 7674.34 N 7721.04 N 7767.70 N 2098.46 E 2107.51 E 2117.09 E 2127.26 E 2137.34 E A Gyro d a t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: 438IN Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 10900.0 72.15 12.23 4981.3 10950.0 73.81 13.02 4996.0 11000.0 73.21 12.79 5010.1 11050.0 73.19 12.75 5024.6 11100.0 74.83 13.26 5038.4 8082.8 8130.6 8178.6 8226.4 8274.4 .62 8103.9 15.4 3.65 8151.7 15.3 1.29 8199.6 15.3 .08 8247.4 15.3 3.42 8295.4 15.3 7814.26 N 2147.38 E 7860.91 N 2157.83 E 7907.64 N 2168.54 E 7954.33 N 2179.11 E 8001.16 N 2189.93 E 11150.0 74.34 13.16 5051.7 11200.0 73.93 13.11 5065.3 11250.0 73.44 12.76 5079.4 11300.0 74.38 13.09 5093.2 11350.0 74.26 12.86 5106.8 8322.6 8370.7 8418.6 8466.7 8514.8 1.00 8343.6 15.3 .82 8391.7 15.3 1.19 8439.6 15.3 1.98 8487.6 15.3 .51 8535.7 15.2 8048.08 N 2200.94 E 8094.92 N 2211.87 E 8141.69 N 2222.62 E 8188.51 N 2233.36 E 8235.42 N 2244.17 E 11400.0 73.94 12.45 5120.5 11450.0 73.32 12.08 5134.5 11500.0 73.19 11.66 5149.0 11550.0 74.07 12.08 5163.0 11600.0 74.22 12.18 5176.7 8562.9 8610.8 8658.7 8706.7 8754.8 1.02 8583.8 15.2 1.43 8631.7 15.2 .84 8679.5 15.2 1.94 8727.4 15.2 .35 8775.4 15.2 8282.34 N 2254.70 E 8329.22 N 2264.89 E 8376.07 N 2274.74 E 8423.02 N 2284.60 E 8470.04 N 2294.71 E 11650.0 73.86 11.85 5190.5 11700.0 74.07 11.71 5204.3 8802.8 8850.9 .96 8823.4 15.1 .50 8871.4 15.1 8517.06 N 8564.11 N 2304.71 E 2314.52 E Final Station Closure: Distance: 8871.35 ft Az: 15.12 deg. A Gyroda t a D i re c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: SUBI438 Run Date: 10-Jan-98 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 45.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 11.230 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: SUBI438 Page SUBSEA DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -45.7 100.0 200.0 300·0 400.0 .00 0.00 0.0 .14 73.68 145.7 .22 61.10 245.7 .39 32.21 345.7 .47 60.65 445.7 0.0 .1 .3 .7 1.3 0.00 0.0 0.0 .10 .3 64.2 .17 .6 66.1 .26 1.3 53.8 .29 2.0 49.3 0.00 N 0.00 E .08 N .19 E .20 N .42 E .58 N ·73 E 1.05 N 1.25 E 500. 600. 700. 800. 900. .41 62.41 545.7 .50 41.18 645.7 1.19 31.27 745.7 2.33 12.94 845.7 2.99 9.52 945.7 1.7 2.3 3.7 6.7 11.3 .32 2.7 53.0 .27 3.6 52.9 .74 5.5 46.4 1.21 9.3 35.1 · 68 14.4 25.4 1.40 N 1.87 E 1.88 N 2.46 E 3.12 N 3.15 E 6.03 N 3.99 E 10.58 N 4.85 E 1000. 1100. 1200. 1300. 1400. 3.10 9.90 1045.7 3.31 10.86 1145.7 4.38 12.99 1245.7 6.19 16.70 1345.7 7.41 17.78 1445.7 16.6 22.2 29.0 38.2 50·0 .16 19.7 20.2 .26 25.5 17.7 1.08 33.2 16.4 1.83 44.1 16.1 1.24 57.1 16.4 15.82 N 5.75 E 21.33 N 6.76 E 27.89 N 8.19 E 36.79 N 10.66 E 48.17 N 14.22 E 1500. 1600. 1700. 1800. 1900. 7.54 18.87 1545.7 8.08 18.51 1645.7 9.99 15.22 1745.7 11.50 14.95 1845.7 13.28 17.21 1945.7 63.0 76.6 92.4 111.4 133.2 .54 70·1 16.8 1.04 84.1 17.1 1.97 101.4 17.1 1.51 121.4 16.7 1.83 144.1 16.6 60.62 N 18.33 E 73.60 N 22.70 E 88.83 N 27.22 E 107.17 N 32.14 E 128.23 N 38.27 E 2000. 2100. 2200. 2300. 2400. 16.22 19.70 2045.7 18.77 19.98 2145.7 21.53 18.52 2245.7 24.33 15.98 2345.7 27.33 14.92 2445.7 158.8 190.3 226.6 268·5 316.6 3.02 171.5 16.9 2.46 203.1 17.4 2.64 238.9 17.7 2.75 278.9 17.6 2.75 323.1 17.3 152.65 N 46.41 E 182.63 N 57.32 E 217.23 N 69.37 E 257.52 N 81.84 E 303.98 N 94.64 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: SUBI438 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 2600.0 2700.0 2800.0 2900.0 29.96 14.83 2545.7 33.19 14.98 2645.7 37.05 14.77 2745.7 40.84 14.12 2845.7 44.79 13.87 2945.7 371.0 2.26 423.0 16.9 432.6 2.77 479.0 16.7 503.1 3.16 539.5 16.4 583.7 2.92 604.1 16.1 675.8 2.93 744.2 15.8 356.64 N 108.62 E 416.36 N 124.53 E 484.60 N 142.69 E 562.79 N 162.78 E 652.25 N 185.06 E 3000 3100 3200 3300 3400 .0 .0 .0 .0 .0 48.54 13.81 3045.7 782.6 2.42 819.0 15.6 52.30 13.56 3145.7 902.7 2.56 976.6 15.3 57.26 14.17 3245.7 1043.8 3.12 1059.6 15.1 64.08 14.14 3345.7 1220.2 3.70 1234.4 15.0 70.09 14.99 3445.7 1458.1 2.27 1512.3 14.9 756.04 N 872.86 N 1009.97 N 1181.24 N 1412.02 N 210.63 E 239.11 E 272.87 E 316.04 E 375.41 E 3500 3600 3700 3800 3900 .0 .0 .0 .0 .0 77.48 18.52 3545.7 1814.2 78.74 23.18 3645.7 2310.1 78.74 25.50 3745.7 2767.7 77.70 24.55 3845.7 3248.0 77.19 19.35 3945.7 3671.4 1.79 1899.3 15.2 .92 2387.0 16.5 .53 2871.3 18.0 1.12 3358.0 19.1 1.91 3747.0 19.5 1754.98 N 2224.02 N 2650.40 N 3098.06 N 3496.69 N 476.38 E 660.69 E 862.73 E 1074.29 E 1240.89 E 4000 4100 4200 4300 4400 .0 .0 .0 .0 .0 78.72 14.54 4045.7 4127.1 79.29 12.22 4145.7 4631.8 80.10 11.19 4245.7 5179.4 78.53 10.49 4345.7 5696.2 76.48 10.32 4445.7 6132.0 .38 4234.7 19.2 .68 4722.8 18.5 .18 5309.1 17.8 .51 5796.3 17.2 .36 6183.2 16.7 3935.94 N 4427.32 N 4963.97 N 5471.43 N 5900.12 N 1368.65 E 1485.45 E 1594.34 E 1692.09 E 1770.50 E 4500 4600 4700 4800 4900 .0 .0 .0 .0 .0 76.11 12.34 4545.7 6539.7 75.72 10.84 4645.7 6936.2 73.61 8.46 4745.7 7301.6 73.06 10.90 4845.7 7645.8 72.93 12.28 4945.7 7969.5 .30 6570.4 16.4 1.24 7005.2 16.1 1.09 7340.4 15.8 .85 7675.2 15.6 1.11 8008.7 15.4 6299.28 N 6687.42 N 7047.79 N 7385.98 N 7703.46 N 1853.64 E 1934.96 E 1995.94 E 2060.37 E 2123.43 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: SUBI438 Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 74.56 13.20 5045.7 8301.0 2.08 8343.6 15.3 5158.6 74.07 11.71 5204.3 8850.9 .50 8871.4 15.1 8027.00 N 8564.11 N 2196.00 E 2314.52 E Final Station Closure: Distance: 8871.35 ft Az: 15.12 deg. A Gyro d a t a D i r e c t i o n a I S u rve y for B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Run Date: 10-Jan-98 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 45.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 11.230 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 100.0 .12 57.89 100.0 200.0 .16 92.45 200.0 300.0 .29 23.84 300.0 400.0 .51 42.15 400.0 0.0 0.00 0.0 0.0 .1 .12 .1 57.9 .2 .09 .3 71.8 .4 .27 .6 59.5 1.0 .26 1.3 47.1 0.00 N 0.00 E .05 N .09 E .10 N .31 E .32 N .55 E .88 N .95 E 500.0 .42 82.62 500.0 600.0 .39 38.40 600.0 700.0 .62 44.48 700.0 800.0 1.85 15.59 800.0 900.0 2.89 9.79 899.9 1.5 .33 2.0 52.0 2.0 .31 2.7 54.2 2.7 .24 3.6 51.2 4.8 1.34 5.5 40.7 8.9 1.06 9.3 28.5 1.26 N 1.61 E 1.57 N 2.19 E 2.23 N 2.78 E 4.18 N 3.60 E 8.22 N 4.46 E 1000.0 3.11 9.21 999.7 1100.0 3.10 10.70 1099.6 1200.0 3.56 11.05 1199.4 1300.0 5.32 15.23 1299.1 1400.0 7.17 18.35 1398.5 14.2 .22 14.4 21.7 19.6 .08 19.7 18.5 25.4 .47 25.5 16.8 33.1 1.79 33.2 16.0 43.9 1.88 44.1 16.3 13.37 N 5.32 E 18.70 N 6.26 E 24.40 N 7.35 E 31.92 N 9.17 E 42.32 N 12.35 E 1501.0 7.67 17.13 1498.7 1600.0 7.39 20.76 1596.8 1700.0 8.79 16.21 1695.8 1800.0 11.16 14.26 1794.3 1900.0 11.82 15.58 1892.3 56.9 .52 57.1 16.6 69.7 .56 70.1 17.0 83.7 1.54 84.1 17.2 101.0 2.39 101.4 16.9 120.8 .71 121.4 16.6 54.74 N 16.32 E 67.01 N 20.52 E 80.36 N 24.93 E 97.08 N 29.45 E 116.32 N 34.58 E 2000.0 14.48 18.55 1989.7 2100.0 17.21 20.26 2085.9 2200.0 19.84 20.20 2180.7 2300.0 22.18 18.19 2274.0 2400.0 24.87 15.58 2365.7 143.4 2.74 144.1 16.7 170.5 2.77 171.4 17.1 201.8 2.63 203.1 17.6 237.3 2.45 238.9 17.8 277.0 2.89 278.8 17.7 138.04 N 41.31 E 163.77 N 50.41 E 193.58 N 61.39 E 227.44 N 73.15 E 265.64 N 84.69 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F'PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 27.49 14.86 2455.4 2600.0 29.87 14.92 2543.2 2700.0 32.53 14.92 2628.7 2800.0 35.66 15.10 2711.5 2900.0 38.79 14.37 2791.1 321.1 368.9 420.6 476.6 536.9 2.63 322.9 17.3 2.38 370.8 17.0 2.66 422.6 16.8 3.13 478.6 16.6 3.16 539.1 16.4 308.20 N 96.26 E 354.58 N 108.59 E 404.63 N 121.93 E 458.76 N 136.45 E 517.26 N 151.82 E 3000.0 41.61 13.99 2867.5 3100.0 44.55 13.88 2940.5 3200.0 47.55 13.88 3009.9 3300.0 49.58 13.86 3076.1 3400.0 52.21 13.53 3139.2 601.4 669.6 741.5 816.4 893.9 2.83 603.6 16.1 2.94 671.8 15.9 3.00 743.8 15.7 2.03 818.7 15.5 2.65 896.2 15.4 579.83 N 167.62 E 646.11 N 184.07 E 716.00 N 201.34 E 788.77 N 219.31 E 864.16 N 237.68 E 3500.0 54.59 13.78 3198.8 3600.0 57.70 14.25 3254.5 3700.0 60.82 14.11 3305.6 3800.0 64.26 14.15 3351.7 3900.0 66.75 14.23 3393.2 974.1 1057.0 1142.9 1231.5 1322.3 2.39 976.5 15.2 3.14 1059.5 15.1 3.12 1145.4 15.1 3.44 1234.2 15.0 2.49 1325.1 14.9 942.17 N 1022.73 N 1106.05 N 1192.09 N 1280.30 N 256.64 E 276.75 E 297.80 E 319.45 E 341.76 E 4000.0 69.10 14.57 3430.7 4100.0 71.25 15.40 3464.7 4200.0 74.00 15.90 3494.5 4300.0 76.17 16.66 3520.3 4400.0 77.25 18.33 3543.2 1414.9 1508.7 1603.9 1700.1 1796.9 2.37 1417.8 14.9 2.29 1511.9 14.9 2.80 1607.3 15.0 2.29 1703.9 15.0 1.94 1801.1 15.2 1370.05 N 1460.92 N 1552.80 N 1645.55 N 1738.37 N 364.81 E 389.14 E 414.90 E 441.99 E 471.25 E 4500.0 78.44 19.02 3564.3 4600.0 79.52 20.82 3583.4 4700.0 78.68 22.75 3602.3 4800.0 78.86 22.90 3621.8 4900.0 79.17 22.69 3640.9 1893.8 1990.8 2087.3 2183.4 2279.6 1.38 1898.7 15.3 2.07 1996.5 15.6 2.07 2094.2 15.9 .23 2191.6 16.2 .37 2289.1 16.5 1830.97 N 1923.25 N 2014.43 N 2104.83 N 2195.33 N 502.55 E 536.00 E 572.44 E 610.49 E 648.53 E A Gy r o d a t a D i r e c t i o n a i Survey B.P. EXPLOP~ATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 77.60 24.18 3661.0 5100.0 77.31 26.16 3682.7 5200.0 77.78 25.88 3704.3 5300.0 78.09 25.75 3725.2 5400.0 78.68 25.52 3745.3 2375.3 2.14 2386.4 16.7 2470.1 1.95 2483.0 17.1 2564.5 .55 2579.5 17.4 2659.1 .33 2676.2 17.7 2754.0 .63 2773.3 18.0 2285.20 N 2373.54 N 2461.28 N 2549.32 N 2637.63 N 687.48 E 728.99 E 771.83 E 814.41 E 856.78 E 5500.0 78.70 25.48 3764.9 5600.0 78.72 25.60 3784.5 5700.0 78.60 25.39 3804.2 5800.0 78.86 25.12 3823.7 5900.0 77.80 24.59 3844.0 2849.0 .05 2870.5 18.3 2944.0 .12 2967.8 18.5 3039.1 .24 3065.2 18.7 3134.2 .37 3162.6 18.9 3229.4 1.18 3260.1 19.1 2726.13 N 2814.62 N 2903.11 N 2991.81 N 3080.67 N 899.00 E 941.28 E 983.48 E 1025.32 E 1066.49 E 6000.0 77.15 24.48 3865.6 6100.0 76.40 24.05 3888.5 6200.0 76.51 21.95 3911.9 6300.0 77.34 20.77 3934.6 6400.0 76.92 18.60 3956.8 3324.4 .67 3357.2 19.3 3419.2 .86 3454.2 19.4 3514.4 2.04 3551.3 19.5 3610.3 1.42 3648.6 19.5 3706.7 2.15 3746.1 19.5 3169.48 N 3258.22 N 3347.70 N 3438.42 N 3530.21 N 1107.03 E 1147.04 E 1185.02 E 1220.50 E 1253.33 E 6500.0 76.71 17.18 3979.6 6600.0 77.33 15.51 4002.1 6700.0 78.43 14.90 4023.1 6800.0 78.56 14.63 4043.1 6900.0 78.89 14.21 4062.6 3803.4 1.40 3843.4 19.5 3900.5 1.74 3940.7 19.4 3998.0 1.25 4038.2 19.3 4095.8 .30 4135.9 19.2 4193.7 .53 4233.6 19.1 3622.86 N 3716.36 N 3810.71 N 3905.46 N 4000.44 N 1283.24 E 1310.66 E 1336.31 E 1361.28 E 1385.70 E 7000.0 78.97 14.19 4081.8 7100.0 78.72 12.84 4101.2 7200.0 78.57 12.53 4120.9 7300.0 78.98 12.48 4140.3 7400.0 79.65 11.79 4158.9 4291.7 .08 4331.4 19.0 4389.7 1.35 4429.1 18.9 4487.8 .34 4526.6 18.7 4585.8 .41 4624.1 18.6 4684.1 .95 4721.8 18.5 4095.58 N 4190.97 N 4286.62 N 4382.38 N 4478.45 N 1409.77 E 1432.71 E 1454.24 E 1475.48 E 1496.14 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7500.0 79.35 11.38 4177.1 7600.0 79.44 11.25 4195.5 7700.0 79.56 11.26 4213.7 7800.0 80.07 11.26 4231.4 7900.0 80.04 11.12 4248.7 4782.4 4880.7 4979.0 5077.4 5175.9 .51 4819.4 18.3 .16 4917.0 18.2 .12 5014.6 18.1 .51 5112.3 17.9 .15 5210.1 17.8 4574.77 N 1515.89 E 4671.15 N 1535.18 E 4767.58 N 1554.36 E 4864.11 N 1573.58 E 4960.74 N 1592.70 E 8000.0 79.22 11.11 4266.7 5274 8100.0 78.84 10.97 4285.7 5372 8200.0 78.93 10.84 4305.0 5470 8300.0 78.81 10.54 4324.3 5568 8400.0 78.85 10.39 4343.7 5666 .3 .5 .6 .7 .8 .83 5307.9 17.7 .40 5405.4 17.6 .16 5502.9 17.4 .31 5600.3 17.3 .15 5697.7 17.2 5057.26 N 1611.66 E 5153.62 N 1630.46 E 5249.97 N 1649.02 E 5346.38 N 1667.22 E 5442.86 N 1685.04 E 8500.0 77.56 10.34 4364.1 5764 8600.0 77.14 10.32 4386.0 5862 8700.0 76.81 10.20 4408.5 5959 8800.0 76.36 10.21 4431.8 6056 8900.0 76.41 10.26 4455.3 6154 .7 .2 .7 .9 .1 .29 5794.9 17.1 .42 5891.8 17.0 .35 5988.6 16.9 .45 6085.2 16.8 .07 6181.8 16.7 5539.14 N 1702.66 E 5635.13 N 1720.16 E 5731.00 N 1737.52 E 5826.73 N 1754.75 E 5922.38 N 1772.02 E 9000.0 76.37 10.59 4478.8 6251 9100.0 75.96 12.67 4502.7 6348 9200.0 75.98 12.55 4527.0 6445 9300.0 76.11 12.27 4551.1 6542 9400.0 75.72 12.13 4575.4 6639 .3 .4 .3 .4 .3 .32 6278.4 16.6 .07 6375.2 16.5 .12 6472.0 16.4 .30 6568.8 16.4 .41 6665.5 16.3 6017.96 N 1789.60 E 6113.06 N 1809.17 E 6207.74 N 1830.36 E 6302.52 N 1851.22 E 6397.32 N 1871.71 E 9450.0 75.32 11.95 4588.0 9500.0 75.11 11.85 4600.7 9550.0 76.24 11.74 4613.1 9600.0 75.80 11.64 4625.2 9650.0 76.22 11.18 4637.2 6687.8 6736.1 6784.5 6833.1 6881.6 .88 6713.8 16.3 .45 6762.0 16.2 2.25 6810.3 16.2 .89 6858.7 16.2 1.23 6907.0 16.1 6444.67 N 1881.81 E 6491.97 N 1891.78 E 6539.40 N 1901.68 E 6586.91 N 1911.51 E 6634.47 N 1921.11 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 9700.0 9750.0 9800.0 9850.0 9900.0 75.70 10.77 4649.4 75.03 10.52 4662.0 75.02 10.10 4674.9 74.72 9.83 4688.0 75.08 9.44 4701.0 6930.1 6978.5 7026.7 7075.0 7123.3 1.32 6955.3 16.1 1.41 7003.5 16.1 .82 7051.5 16.0 .79 7099.5 16.0 1.04 7147.5 16.0 6682.08 N 6729.63 N 6777.15 N 6824.69 N 6872.28 N 1930.35 E 1939.29 E 1947.93 E 1956.28 E 1964.36 E 9950 10000 10050 10100 10150 .0 .0 .0 .0 .0 74.47 9.18 4714.1 74.15 8.78 4727.7 73.78 8.47 4741.5 73.17 8.31 4755.7 73.82 9.74 4769.9 7171 7219 7267 7315 7363 .5 .6 .6 .5 .4 1.31 7195.4 15.9 1.01 7243.2 15.9 .95 7290.9 15.8 1.26 7338.4 15.8 3.03 7386.0 15.7 6919.89 N 6967.44 N 7014.95 N 7062.37 N 7109.72 N 1972.16 E 1979.67 E 1986.88 E 1993.87 E 2001.39 E 10200 10250 10300 10350 10400 .0 .0 .0 .0 .0 73.68 10.22 4783.9 74.14 11.75 4797.7 74.29 11.74 4811.3 73.56 11.48 4825.2 73.34 11.16 4839.4 7411 7459 7507 7555 7603 .3 .4 .5 .5 .5 .97 7433.8 15.7 3.07 7481.7 15.7 .31 7529.7 15.6 1.55 7577.6 15.6 .76 7625.4 15.6 7156.99 N 7204.15 N 7251.26 N 7298.32 N 7345.32 N 2009.71 E 2018.87 E 2028.66 E 2038.33 E 2047.73 E 10450 10500 10550 10600 10650 .0 .0 .0 .0 .0 72.87 10.78 4854.0 72.17 10.44 4869.0 72.88 11.30 4884.0 72.90 11.45 4898.7 72.99 10.98 4913.4 7651 7699 7746 7794 7842 .3 .0 .7 .5 .3 . 18 7673.1 15.5 54 7720.6 15.5 18 7768.1 15.5 28 7815.8 15.5 91 7863.5 15.4 7392.28 N 7439.16 N 7485.99 N 7532.84 N 7579.73 N 2056.84 E 2065.62 E 2074.61 E 2084.04 E 2093.33 E 10700.0 10750.0 10800.0 10850.0 10900.0 72.43 10.77 4928.2 72.59 12.23 4943.3 72.83 12.27 4958.1 72.32 12.07 4973.1 72.16 12.15 4988.3 7890.0 7937.7 7985.4 8033.1 8080.7 . 19 7911.1 15.4 80 7958.7 15.4 47 8006.3 15.4 08 8054.0 15.4 35 8101.5 15.3 7626.62 N 7673.35 N 7720.00 N 7766.63 N 7813.19 N 2102.34 E 2111.85 E 2121.98 E 2132.03 E 2142.02 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-17 MILNE POINT FIELD, ALASKA Job Number: A0198GCE438 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 10950.0 73.56 12.92 5003.1 8128.5 11000.0 73.06 12.74 5017.4 8176.4 11050.0 73.03 12.62 5032.0 8224.2 11100.0 74.52 13.16 5046.0 8272.2 11150.0 74.35 13.21 5059.4 8320.3 3.16 8149.2 15.3 1.06 8197.1 15.3 .23 8244.8 15.3 3.15 8292.8 15.3 .35 8340.9 15.3 7859.83 N 2152.39 E 7906.53 N 2163.02 E 7953.19 N 2173.52 E 7999.99 N 2184.23 E 8046.89 N 2195.21 E 11200.0 73.98 13.06 5073.0 8368.4 11250.0 73.42 12.80 5087.1 8416.4 11300.0 73°92 12.92 5101.1 8464.3 11350.0 74.38 12.92 5114.8 8512.4 11400.0 74.00 12.43 5128.4 8560.5 .80 8389.0 15.2 1.21 8437.0 15.2 1.01 8484.9 15.2 .93 8533.0 15.2 1.22 8581.0 15.2 8093.73 N 8140.50 N 8187.28 N 8234.16 N 8281.10 N 2206.14 E 2216.88 E 2227.56 E 2238.32 E 2248.87 E 11450.0 73.49 12.03 5142.4 8608.5 11500.0 73.22 11.68 5156.7 8656.4 11550.0 73.63 11.90 5171.0 8704.3 11600.0 74.36 12.16 5184.8 8752.4 11650.0 73.95 11.81 5198.4 8800.5 1.28 8629.0 15.2 .85 8676.8 15.2 .90 8724.6 15.1 1.56 8772.6 15.1 1.07 8820.6 15.1 8328.01 N 8374.89 N 8421.81 N 8468.81 N 8515.86 N 2259.04 E 2268.88 E 2278.68 E 2288.69 E 2298.68 E 11700.0 74.08 11.78 5212.2 8848.5 .27 8868.6 15.1 8562.92 N 2308.50 E Final Station Closure: Distance: 8868.64 ft Az: 15.09 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0198GCE458 TOOL NUMBER: 777 MAXIMUM GYRO TEMPERATURE: 74.8C MAXIMUM AMBIENT TEMPERATURE: 44.34 C MAXIMUM INCLINATION: 80.25 AVERAGE AZIMUTH: 15.12 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2040 CALIBRATION USED FOR FINAL SURVEY: 2040 PRE JOB MASS BALANCE OFFSET CHECK: .10 POST JOB MASS BALANCE OFFSET CHECKt: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES .18 UPON ARRIVAL AT RIG: OFF UPON COMPLETION OF SURVEY: OFF UPON RETURN TO ATLAS OFF BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 11349 74.50 12.82 5078 8254 2271 INRUN 11350 74.26 12.86 OUTRUN 11350 74.38 12.92 5106 8235 2244 5114 8234 2238 FUNCTION TEST JOB NUMBER: A0198GCE438 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2000 14.48 14.48 14.48 14.48 14.48 M.D. ft I 2 3 4 5 2000 18.61 18.55 18.55 18.55 18.61 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER' A0198GCE438 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0112 COMPUTER A0433 POWER SUPPLY PRINTER A0079 INTERFACE A0143 A0085 BACKUP TOOL No. 742 GYRO SECTION DATA SECTION POWER SECTION A0124 C0089 C0086 COMPUTER A0349 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0107 WIRELINE COMPANY' ATLAS CABLE SIZE · 5/16" RUNNING GEAR 2.5" HOUSING W/ECCENTRIC BAR AND CENTRALIZERS TOTAL LENGTH OF TOOL ' 33' MAXIMUM O.D.' 2.5 INCHES TOTAL WEIGHT OF TOOL' 220 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0198GCE438 FRIDAY,01/09/98 15:00 FLY TO DEADHORSE 19:00 CHECK TOOLS, STANDBY SATURDAY,01/10/98 10:00 11:20 13:00 14:00 14:15 15:40 17:15 19:30 20:00 21:30 23:00 TO LOCATION ARRIVE LOCATION MU TOOL, RU ATLAS PU GYRO. START INRUN SURVEY PUMP TOOL SURVEY INRUN TO 11700' OUTRUN CONTINUOUS TO 2000' LD TOOL, BD TOOL RETURN TO ATLAS CHECK TOOL, PROCESS SURVEY SUNDAY,01/1 01:00 02:00 11:00 14:00 17:00 1/98 RETURN TO RIG W/RESULTS RETURN TO ATLAS REPROCESS RESULTS. CHECK INRUN VS OUTRUN TO VERIFY TVD DISCREPANCY, RECHECK TOOLS. RETURN TO RIG W/RESULTS RETURN TO ATLAS MONDAY, OIl12~98 09:15 FLY TO ANCHORAGE STATE OF ALASKA ALASKA u-IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I--]Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [~Service 4. Location of well at surface 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 3101' NSL, 1282' EWL, SEC. 20, T14N, R10E, UM At effective depth 3999' NSL, 1413' EWL, SEC. 20, T14N, R10E, UM At total depth 4113' NSL, 1427' EWL, SEC. 20, T14N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 21,781 feet 7,734 feet 21,664 feet 7~725 feet Length Size 80' 20" 9512' 9 5/8" 21717' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx) 2650 sx Permafrost 'E', 1100 sx 'G' 170 sx 'G', 185 sx 'Foamed G' 6. Datum Elevation (DF or KB) Plan KBE = 45.7' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-17 9. Permit Number 97-196 10. APl Number 50- 029-22823 11. Field and Pool Milne Point Unit / Kuparuk River Sands MD TVD 112' 112' 9544' 4641' 21749' 7732' Perforation depth: measured true vertical 20950' - 21020', 21080' - 21540' (Subsea) 7622' - 7632', 7639' - 7671' OR GINAL Tubing (size, grade, and measured depth) 4 1/2" 12.6 ppf, L-80 tubing to 19,548' Packers and SSSV (type and measured depth) 7"x 4.5" Baker'S-3' Packer at 19,522' Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 18, 1998 16. If proposal was verbally approved Blair Wondzell Name of approver 5/18/98 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/Number: Sampson Ning, 564-5696 Prepared By Name/Number: Jeanne L. Haas 564-5225 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~a%,~s~ ~ Title Staff T echnicalAssistant Commission Use Only Date '.5~/~,c/~",.~--- Conditions of Approval: Notify Commission so representative may witness I Approval (~,~,(~,, {~,j~,~ Plug integrity BOP Test Location clearance f'(~'~ lh¢~,~_~-,~l,i;~ Mechanical Integrity Test ~ Subsequent form required 10- 0avid W. johnston Approved Copy Approv~ by order of the Commission Ret. r,ed Commissioner Date Milne Point Well MPF-17 Request for Variance MPF-17 is an injector and has a robing leak. Lan3, Niles discussed the situation with Blair Wondzell and a path forward was put in place. The 7" liner was tested with a plug in the 4 ½" robing on May 16, 1998 and passed the mechanical integrity test. John Spalding witnessed the test. Therefore, it was agreed that a form 10-403 to request approval to resume injection with a hightened level of monitoring could be submitted. The hightened level of monitoring includes an MIT every 2 years with a plug in the 4 ½" tubing to demonstrate 7" integrity and a report of monthly average robing, IA, OA and injection rate submitted to the Commission. .._ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: !-'i Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 3101' NSL, 1282' EWL, SEC. 20, T14N, R10E, UM At effective depth 3999' NSL, 1413' EWL, SEC. 20, T14N, R10E, UM At total depth 4113' NSL, 1427' EWL, SEC. 20, T14N, R10E, UM 12. Present well condition summary Total depth: measured 21,781 feet true vertical 7,734 feet Effective depth: measured 21,664 feet true vertical 7,725 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 80' 20" Surface 9512' 9 5/8" Intermediate Production 21717' 7" Liner Cemented 250 sx Arcticset 1 (Approx) 2650 sx Permafrost 'E', 1100 sx 'G' 170 sx 'G', 185 sx 'Foamed G' 6. Datum Elevation (DF or KB) KBE = 46' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-17 9. Permit Number 97-196 10. APl Number 50- 029-22823 11. Field and Pool Milne Point Unit/Kuparuk River Sands MD TVD 112' 112' 9544' 4641' 21749' 7732' Pedoration depth: measured true vertical 20950'-21020',21080'-21540' (Subsea) 7622'-7632',7639'-7671' RECEIVED Tubing (size, grade, and measured depth) 4 1/2" 12.6 ppf, L-80 tubing to 19,548' /:,,,u0 07 1'398 Packers and SSSV (type and measured depth) 7"x 4.5" Baker 'S-3' Packer at 19,522' Alaska 0il & Gas Cons. C0mmis: Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation December, 1998 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Name of approver Date approved Contact Engineer Name/Number: Sampson Ning, 564-5696 Prepared By Name/Number: Jeanne L. Haas 564-5225 17. I hereby cert~ that the foregoing is true and. correct to the best of my knowledge · Signed ~?~_~"g.4L. ~. J~fe L. Haas -~ T~le Staff Technical Assistant Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date Approval No,._ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form Approved by order of the Commission 0&Vid W. *~¢ c~ ,mmissioner Johnston Date Milne Point Well MPF-17 Change of Approved Program MPF-17 is an injector and has a tubing leak. A 10-403 for a variance was submitted and approved May 28, 1998 due to a known and demonstrated pressure migration from the tubing to the 7" inner annulus. This required that a monthly pressure report would be filed each month. Since that time it was decided to workover the well and make it an oil producer. This work should be completed by the end of 1998. The well is presently shut in and freeze protected. There will be no further need to file a monthly pressure report at this time. A 10-404 will be submitted after the workover is completed. Field Fac~ty 15:48 I Miln¢ Point M PtF Pad 907-344-2L6.0 ANADRILL DPC .- Target Analysis Report Well MFF-17 Target lVlP Fl7 B PAGE Page 1 Date 22:19, 17 Nov 97 Formation Tv~ (ss) Projection · Datum Kupamk Rivm' 7490,00 ft TMALSK4F NAD27Atrr Latitude Longitude Dip. 0.000 deg Dip Azimuth i80.000 deg 70 33 12.058 N Easting (ft) 149 37 30.493 W Northing (ft) Geological Easting (It) 545714.00 545809.66 545890.76 545944.95 545963.98 545944.95 545890.76 545809,66 545714.00 545618,34 545537.24 545483.05 545464.02 545483.05 545537.24 545618,34 Target Northing (ft) 6052406,98 6052387.95 6052333.76 6052252,66 6052157,00 6052061,34 6051980.24 6051926.05 6051907,02 6051926.05 6O51980,24 6052061,34 6052157.00 6052252.66 6052333.76 6052387,95 TVDSS fit) 7490,00 7490.00 7490,00: 7490.00 7490.00 7490.00 7490.00 7490.00 7490,00 7490.00 7490.00 7490.00 7490,00 7490.00 7490.00 7490.00 Distance (f0 Bearing (deg) 250.00 0.000 250.00 22,500 250,00 45,000 250.00 67,500 250.00 90.000 250,00 112,500 250.00 135,000 250.00 157.500 250,00 180,000 250.00 202,500 250.00 225.000 250.00 247.500 250.00 270,000 250,00 292,500 250.00 315.000 250,00 337,500 Driller's Target Boundary Easfing(ft) 545744.85 545794.95 545807.50 545820. I0 545820.42 545783.09 545758.I5 545683.15 545633.05 545620.50 545607.90 545607.58 545644.91 545669,85 Northing fit) 605225O.87 6052226.09 6052213.64 6052188,70 6052113,71 6052076.05 6052063.45 6052063.13 6052087.91 6052100.36 6052125.30 6052200.29 6052237.95 6052250.55 TVDSS (ft) 7490.00 7490.00 7490.00 7490,00 7490.00 7490.00 7490.00 7490.00 7490.00 7490.00 7490.00 7490.00 7490.00 7490.00 Dbtanee (it) 98,82 106.43 109,33 110,75 114,90 106.43 103,45 98,82 106.43 '109,33 110.75 114.90 106.43 103,45 Bearing (deg) 18.190 49.518 58.791 73.365 112,135 139.518 154,738 198,190 229.518 238.791 253.365 292.135 319.518 334.738 wrtGRIDNorth 545714.00 6052157.00 Survey Programme Section Details No Instrument Run Type 1 Gyrodata small ID csg mshot -continuous 2 MWD + In-Hole Reference (corrected data) Start Depth (it) 33.00 10520.00 EndDepth (It) 10520,00 21525.00 STATE OF ALASKA ALASK~ ,.)IL AND GAS CONSERVATION CO,v~MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] SuSpend [] Plugging []Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Producer 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [] Development [] Exploratory I-q Stratigraphic [~ Service 4. Location of well at surface 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 3101' NSL, 1282' EWL, SEC. 20, T14N, R10E, UM At effective depth 3999' NSL, 1413' EWL, SEC. 20, T14N, R10E, UM At total depth 4113' NSL, 1427' EWL, SEC. 20, T14N, R10E, UM 6. Datum Elevation (DF or KB) KBE = 46' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-17i 9. Permit Number 97-196 10. APl Number 50-029-22823 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 21780 true vertical 7705 Effective depth: measured 21664 true vertical 7697 Casing Length Structural Conductor 80' Surface 9512' Intermediate Production 21717' Liner feet feet feet feet Size 20'1 9-5/8" 11 Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 2650 sx PF 'E', 1100 sx 'G', 160 sx PF 'E' 170 SX IG', 185 sx Foamed 'G' MD TVD 112' 112' 9544' 4641' 21749' 7732' Perforation depth: measured true vertical 20950'-21020',21080'-21540' (Subsea)7622'-7632',7639'-7671' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 19548' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker S-3 Packer at 19522' Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation October 5, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: F-] Oil [] Gas [~ Suspended Service Water Injection Contact Engineer Name/Number: Bob Laule, 564-5195 Prepared By Name/Number: 17. I hereby certify~regoing is~'~an~orrect to the best of my knowledge Signed " .... ~ T.~~~/~-.~./~/~/~'.ZC--~ltle Dr ng Engineering Supervisor onditLqr~~proval: Commission Use Only Kathy Campoamor, 564-5122 Date I Approval N°..~Ol~---~/'/ C, Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test ~__ Subsequent form required 10-/'{ O ~ David W. Johnston Approved by order of the Commission Commissioner Date Submitln Tri¢icate Form 10-403 Rev. 06/15/88 %ar@d rvlcos rillin SUMMARY OF PROCEDURE, MPF-17i APPLICATION FOR SUNDRY - CHANGE WELL STATUS FROM INJEOTOR TO PRODUCER Purpose of Work Well MPF-171 will be converted from a Kuparuk injector to a Kuparuk producer. The well was originally intended to support MPF-34 and MPF-78, but the well is too distant from MPF-78 and has direct communication with MPF-34 via a fault. Pre-rig work on MPF-17i conversion: 1. Chemically cut 4-1/2" tubing above the packer 2. Set BPV MIRU Rig Pull BPV with lubricator Circulate well dead Set TWC NU tree, NU and test BOP Pull 4-1/2" completion Re-complete well with 2-7/8" ESP completion Land tubing with new hanger Set TWC ND BOP and NU new adapter flange and tree and test Pull TWC with lubricator and set BPV Tree: 4-1/16".?~-M FMC --ORIG. KB. ELEV = 45.60' (N 27E) Wellhead:Il /16" 5MFMCGen5MPU F-17i RIG. GL. ELEV = 12.70 '(N 27E) FMC Tubing I-..,er, 4.5" nsct top, 4.5" , ~'"~--['-~'~ ~T To Tbg. Spool = 31.64' mod butt. btm. CIW 4" H BPV profile , I 20"91.1ppi, H-40 I 112'I ]l--I 4.5" HES X-Nipple ( 3.813" id )1 2,219' 9 5/8", 40#If t, L-80 Btrc. Ii I KOP @ 800' i : I MAX HOLE Angle 80~ @ 7,900' +70° 4.000' to 20.000' +80 from 20,000 to 21,780 pdtd ' ' ': I i 7" 26 ppf, L-80, NSCC production casing ( ddft ID = 6.151", cap. = 0.0383 bpf ) 4.5", 12.6 ppf, L-80 Btrc. tubing (cap. = 0.0152 bpf, ddft = 3.958") i , I i I 9 5,8". 40#,ft.I I L-80 Btrc. Float Shoe. 9,544', · , ~ 7"x 4.5" Baker'S-3" Packer I 19,522' J 4.5" HES 'XN' Nipple 1 9,536' Minimum tubing restriction = 3.725" ( MIN. ID 3.725") "XN" profile @ 19,536' md. i d i 4.5"WLEG I 19,548'1 Perforation Summary Ref log: Cement USIT-GR-CCLU 01-27-98 SIZE SPF INTERVAL (TVD) 3-3/8" 4 20,950'-21,020' 7,638'-7,649' 3-3/8" 4 21,080'-21,540' 7,656'-7,687' 3-3/8" Alpha Jet charges @ 60 deg. phasing Floal Shoe , , DATE ,REV' BY , COMMENTS, MILNE POINT UNIT 02 / 03 / 98 MDO Cased Hole, perf & Completion 27 E WELL MPU F-17i BP EXPLORATION i i Tree: Cr~'~L',n29/16"5M MPU F-17 -_Orig. OFElev.= 45.6' (N 27E) rig. GL Elev. = 12.7' (N 27E) Wellhead. I" x 7 1/16" 5M FMC ' ~ ,'~T To Tbg. Spool = 31.64' Gen 5A, w/2 7~8" FMC tbg. hng., 3" LH acme on top and 2 7~8" EUE 8 rd on bottom, 2.5" CIW BPV profile ~ i Camco 2 7/8" x 1" I 120' KBMM ! I GLM ~OP @ 600' MAX HOLE Angle 80 deg @ 7,900' +70 deg 4,000' to 20,000' +80 deg fr/20,000' to 21,780' . _ . · L-80 Btr¢.-Float Shoe. Camco 2 7~8" x 1" sidepocket KBMM GLM 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 2-7/8" HES XN-Nipple 7" 26 ppf, L-80, Mod. Btrc. prod. casing (2.205" id ) ( drift ID = 6.151", cap. = 0.0383 bpf ) Centrilift GC 1700 ESP, series 513, GPMTAR 1:1, 151 Stg. Type #1 Cable - 19520' Centrilift GRSXTBARH6 separator Centrilift GSB3UT/LT AFLAS/HSN, series 513 seal section NOTE: Baker packer to be left Centrilift KME 562 series, J in the hole if tubing cut is ~ ~ 190 hp motor, 2390 v. / 44 cleanIi I amps. r_,~- -,~ Centrilift PHD I II I 7"x 4.5" Baker 'S-3" Packer I 1 9,522' Perforation Summary Ref lo.q: Cement USIT-GR-CCLU 01-27-98 ~ ~ 4.5" HES 'XN' Nipple Size SPF Interval (TVD) i 4,5" WLEG J 19,548' 3~3/8" 4 20,950'-21,020' 7638' - 7649' ! 3-3/8' 4 21,080'-21,540' 7656' - 7687' PROPOSED CONVERSION COMPLETION FROM INJECTOR TO PRODUCER 7" Float Collar (PBTD) 2~,664' mm~d~ i~/~ 7" float shoe [21,749' DATE REV. BY COMMENTS MILNE POINT UNIT 08/21'/98 DKJ PROPOSED COMPLETION WELL F-17 PROPOSED COMPLETION BP EXPLORATION (AK) I IIII 1/30/98 / GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11767 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Color Well Job # Log Description Date Print RF Sepia LIS Tape MPF-17 98044 CEMENT ADVISOR 9801 27 1 : PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 :..: ,,--: ,. R e ce ,ve d b ~;~,~r)~--~> TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19. 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99~; 19-661 '~ Milne Point Unit MPF-17 Rev. BP Exploration (Alaska), Illc. Permit No. 97-196 Sur Loc 1808'NSL. 2731'WEL. Sec. 6. T13N, R10E. UM Btmhole Loc 3797'NSL, 3776'WEL. Sec. 20, T14N. R10E. UM Dear Mr. Alvord: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated October 16. 1997. are in effect for this revision. , David W. Johnston \ ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 12/10/97 la. Type of work [] Drill [] Redril'l Ilb. Type of well []Exploratory F-IStratigraphic Test [] Development Cell [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone.. 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and P°ol BP Exploration (Alaska) Inc. Plan KBE = 45.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355016 i4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit , At top of productive interval 8. Well Number Number 2S100302630-277 2843' NSL, 3969' WEL, SEC. 20, T14N, R10E, UM MPF-17 At total depth 9. Approximate spud date Amount $200,000.00 3797' NSL, 3776' WEL, SEC. 20, T14N, R10E, UM 12/24/97 12. Distance to nearest property line113. Distance to near~st well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) ADL 355017, 3797'I No Close Approach 5071 21466' MD / 7672' TVD .... 16. To be completed for deviated wells 17. Anticipated pressure {see 2o AAC 25.035 (e) (2)} Kick Off Depth 700' Maximum Hole Angle 82° Maximum surface 3046 psig, At total depth O'VD) 7630' / 3809 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of. Cement Hole Casing Weight Grade coupling Length MD TVD MD TVD (include stage data) , 24" 20". 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 9489' 31' 31' 9520' 4556' 1815 sx PF 'E', 1087 sx Class 'G' , 8-1/2" 7" 29# L-80 Btrc-Mod 21436' 30' 30' 21466' 7672' 271 sxClass '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 V Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented TVD Structural , Conductor Surface Intermediate Liner Production R'ECEIVED Perforation depth: measured DEC l 2 true vertical Alaska Oil & Gas Cons. 6orr~mission A-c,h0rage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling ~rogram [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAO 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 ~21. I hereby certify that the foregoing is true and correct to the best of my knowledge.. Signed ChipNvord,-~" ~". ~-~ Title Senior Drilling Engineer Date Commission Use Only Permit Number i APl Number I ApprovalDato I See cover letter 97-196 50-029-22823 10/16/97 for other requirements Conditions of Approval: Samples Required [] yes I:~ No Mud Log Required [] Yes 'J~ No Hydrogen Sulfide Measures I-lYes ~1 No Directional Survey Required ,~ Yes E] No Required Working Pressure for BOPE [] 2M; [] 3M; [~ 5M; [] 10M; [] 15M Other: Original Sigr~ed By by order of Approved By D~vid W. Uohrls'torl Commissioner the commission Date ~-~1~'/ Submit In Triplicate BP EXPLORATION December 4, 1997 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Before Spud Changes to Approved Application for Permit to Drill//97-196 on Nov. 26, 1997 Dear Mr. Johnston, In order to increase the length potentially productive pay interval in the Kuparuk A Sands, minimize future close approaches and minimize the risks associated with hydraulic fracturing and proppent placement it is requested that the well trajectory be modified from the one submitted and approved in the Permit to Drill ~97-196 on October 16, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.016 Changes to the Drilling Permit, (a) For a proposed change in a drilling permit ..... before the start of actual drilling operations. It is requested that the directional profile be changed from that already approved in order to move the well bore roughly 300 feet to the west to provide additional stand-off from and avoid intersecting a fault in the target interval. The directional plan will still begin at the same proposed surface location but intersect a new target and bottom hole location. As a result of this proposed change in the well bore trajectory the following changes are requested: 1. The directional well plan be changed. (ATTACHED) 2. The location At Top of Productive Interval be changed to 2843' NSL, 3969 WEL, Sec. 20, T14N, R10E, UM. 3. The location At Total Depth be changed to 3797' NSL, 3776 WEL, Sec. 20, T14N, R10E, UM 4. The production casing Setting Depth Bottom be changed to 21,466' Md(7627' Tvd~). 5. The production casing Quantity of Cement be changed to 271 sxs Class 'G'. Thank-you for your consideration in this matter and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill //97-196 please contact me in Anchorage at 564-5042. Respectfully, Lance Spencer Drilling Operations Engineer BPX-Shared Services Drilling Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Lance Spencer I MPF-17 Well Plan Summary 564-5042 I Kuparuk Producer Surface Location: 1808' NSL, 2731' WEL, Sec. 06, T13N ,R10E, UM., AK Target TKUA3 2843' NSL, 3969' WEL, Sec. 20, T14N, R10E, UM., AK Bottom Hole Location: 3797' NSL, 3776' WEL, Sec. 20, T14N, R10E, UM., AK I AFE Number: I 337109 I Estimated Start Date: I Rig: I Nabors27-E 124 Dec 97 I I Operatin~l days to complete: IUD: 121,466' I I TVD: 17,672' Bkb I Ii<BE: I45.7, I Well Desitin: Ultra Slim Hole Long String HAW I 9-5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1853 1846 8.4 ppg 806 psi NA Top Schrader Bluff 7030 4041 8.4 ppg 1765 psi OB Base Schrader Bluff 8655 4356 8.4 ppg 1903psi Top HRZ 19180 7226 8.8 ppg 3307 psi Base HRZ 19216 7237 8.8 ppg 3312 psi TKLB(MK-19) 19324 7266 9.2 ppg 3476 psi TKUD 19722 7376 9.2 ppg 3529 psi TKUC 20168 7486 9.6 ppg 3737 psi TKUB 20183 7489 9.6 ppg 3738 psi TKUA3/Target 20483 7536 9.6 ppg 3762 psi TKUA1 20771 7576 9.6 ppg 3782 psi Miluveach 21166 7631 9.6 ppg 3809 psi Total Depth 21466_+ 7672_+ 9.6 ppg 3830 psi · *These are estimated maximum pressures and the actual pressures may be lower. Casinq/Tubing Pro~ ram: Hole S~-ze C-sg/ - Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/I'VD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 9489 31/31 9520/4556 8-1/2" 7" 29# L-80 Mod. 21436 30/30 21466/7672 btrc The internal /ield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _+ 7,630 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,630 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,609 psi is 3,046 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-17 (ERD A) Revised Drilling Permit 1 0il & Gas 0o~s. 6off~iss~of~' Anchorage 12/10/97 Cementinq Program: Halliburton Cementing Services Hole '-~ Ca~ing Interval Volume~ Spacer Type of Cement Propertiesz Cate~lory Size/Depth Surface Lead~ Lead Lead Lead First Stage 9-5/8" @ 2054-6530' 840 sx 70 bbls Permafrost "E" Den 12.0 ppg 9,520' 325 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 6530-9520' Tail5 Tai~l Tai~l 1087 sx Premium Class "G" w/ Den 15.8 ppg 223 bbls 0.2 %Halad 344, 0.2% CFR-3 Yield 1.15 ft 3/sx 0.15 #/sk Flocele Water 4.9 gps T-I- 4.0 hrs ............................................................................................ Second Sta~je [.'~1~ ............. i'~'~J~ ..................... i"~l ...................................... i"~'~l ........................................................ Stage collar° @ 0-1853' 975 sx 75 bbls Permafrost "E" Same as above 2,053' 1853-2054' 377 bbls Fresh water Production 7" @ 19,167- Lead" Lead Lead Den 15.0 ppg First Stage 21,466' 21,466' 271 sx 50 bbls. Foamed Premium Yield 1.46 ft 3/sx 71 bbls Alpha Class "G" w/ Water 5.0 gps Spacer 0.2% LWL + 25% by TT 3.5-4.5 hrs @ 140° F 50 bbls volume of water FL 30-40cc/30 min Foamed FDPC-552 Foaming @ 140° F Alpha agent + Nitrogen Spacer 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,053'MD+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,054-6,530' md. The estimated first stage lead cement volume from 2,054-6,530' md and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,054' md which is 200 ft md below Base of the Permafrost at 1,853' md (1,845 TVD bkb) to 6,530' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 6,530-9,520' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 6,530-9520' (500' md above the NA top) to surface TD at 9,520' md (4,556' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,054' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,054' MD (2,052' TVDbkb) to surface. From 1,853' to surface include 250% open hole excess and from 1,854-2,054' use 30% open hole excess. 7. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from 7,030-9,520' of 9-5/8" casing to cover the top of the NA to Base OB. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 19,167-21,446' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 19,167' which is 1000'_+ above the Kuparuk C Sand to TD at 20,466' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint for the first 10 joints and ONE per joint from to 240' above any potential hydrocarbon bearing sands. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk C sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no~t necessary. MP F-17 (ERD A) Revised Drilling Permit 2 12/10/97 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ Cased Hole Logs: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Seawater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-10.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 <4 Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP F-17 (ERD A) Revised Drilling Permit 3 12/10/97 Directional: KOP1 Tangent Hole Angle Final Build Section Tangent Section Maximum Hole Angle Close Approach Wells Survey Program 700' Start Variable @ 1.0°- 3.0 °/100 and Az 15.4°. EOB @ 6232' md. 78.8° from 6,232-19,847' Start Final Curve 19,847 @ 1.5°/100 to 82° incl. and 11.23 Az o EOB 20,383' md 82° incl. and 12.77 Az o from 20,383-21,466' md 82° from 20,383-21,466' All wells may remain flowing while drilling F-17 and no shut-ins are required. 1. Surfaceto 9,520' MWD surveys. 2. 9,520-11,520' GYRO to surface 3. 11,520'-TD MWD with in hole reference. 4. DMOwi~hN aborS 27E. Disposal: No "Drilling Wastes" will be injected or disposed into F-17 while drilling this well. Cuttinqs Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPF-17 is planned as a high angle, 82°; high departure, 18,300'; ERD, 21,466'; Kuparuk River A Sand producer. The HAW Slant shaped well profile with a final angle of 82°, will intersect the target objectives and provide optimum inclination for fracture stimulation. The surface casing will be deep set below the Schrader Bluff at 9,520'md (4,556' bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval which should not be abnormally pressured by area injection. Geolo_clv The primary targets are the Kupauuk A3, A2 and A1 sands but has some potential in the Kuparuk B and C sands.. The deepest known oil in the area is at F-74i to a depth of 7,472 tvd ss. No water contact is expected at the F-17 location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 100-~_ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this producer are estimated at 4.1 MMBO assuming a 120 acre drainage area. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted and not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP F-17, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. MP F-17 (ERD A) Revised Drilling Permit 4 12/10/97 Water~ Gas and WAG Iniection Formation pressures are expected to be partially depleted at a maximum of 9.6 ppg EMW pore pressure in the Kuparuk while drilling F-17. The Kuparuk may be partially pressure due to nearby production from F78, F-53 and possibly F-66a and F-38. Injection support for the fault block in which the F-17 well path intersects in the target interval is provided by F-70i and the fault block to the east contains injector F-74i. Abnormally Iow pressures caused by production and high pressure due to area injection are not expected while drilling F-17. The injectors F- 701 and F741 areexpected to be in communication with the proposed F-17 BHL but the injection is not expected to have abnormally pressured the reservoir due to offtake for producers F-78, F-53, F-66a and F-38. Annular Iniection Currently annular injection is not permitted on F-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. With the possibility that the HRZ will be truncated or absent the potential for stuck pipe the transition interval from Colville(SeeBee) to Kulubik is recognized. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurrence has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK A1 SAND 7630' TVDss 3809 PSI 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at -,- 7,630 TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_7,630' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,809 psi is 3,046 psi. The maximum expected pore pressure for this well is 9.6 ppg EMW (3,809 psi @ 3,046' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. MP F-17 (ERD A) Revised Drilling Permit 5 12/10/97 MP F-17 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. Run 9-5/8" casing. Space out ES Type H Cementer to 2,054' md. Perform Two Stage Cement Job. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk C sand and PBTD before running the 7" casing. 11. Run 7" casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). Test casing to 3500 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. . , 14. 15. 16. MP F-17 (ERD A) Revised Drilling Permit 6 12/10/97 Anadri31 Schlumberger Alaska District 31£1 Hast 80th Avenue Anuhorage, AK 99518 (907) 349-45l[ ~aK 344-2160 DIRECT]0NALWELL PLA~ for SHARED SBRVfC~S DR[[LING Well ......... : MPP-17 (PLO) Field ........ : Milne Point Co~putatiom..~ Minimu~ Curvature Units ........ , F~ET Surface hat..: 70.50724921 N Surface Long.: 149.65773654 W hegak Description Surface ...... : k808 PSt 2731 PHL 906 T13N R108 UM Target ....... : 2843 PS~ 3969 8H5 .......... : ~797 PS[ 3776 LOCATIONS - ALASKA Zone: 4 X-Coord ¥-Coord 541833.61 6035260.38 545714.00 6052157.00 545898.09 6063LL~.37 STATXON £DHNT~FICATION KO~/CU~VS 1.oo/1oo PROPOSHDWEhh PRO~ILH Prepaxed ..... : 17 ~ov £997 Vert sect az.: KB elevation., 45.70 ft Magnetic Ocl~: +27.8~6 Sca~e Pactor.= 0.99990199 Convergence..: +0,32264662 ANAl)RILL AKA-DPC M~ASURHD ]NChN DIRHCTION V~RTICAL-DEPTHS ~ECTION TOOL Dh/ DHPTH A~G'I.,H AZE~4tPI~ TVD SUB-S~A DSPART PACH 100 0.00 0.00 0.00 0.00 -45.70 0,00 15R 0,00 700.00 0.00 [5.40 700.00 654.30 0,00 15R 0.00 800.00 ~.00 15.40 799.99 754.29 0,87 iSR 1.00 90~,00 2,00 15.40 899.96 854,26 3.48 [SR 1,00 1000.00 3.00 1~.40 999,86 954-16 7.83 ]SR [.00 APPROVED FOP, PERMITTING ONLY GOONDINA~HS-FRO~ ALASKA Zone 4 0.O0 H D.00 H 541833.61 6035260.38 0.00 N 0.00 H 541833.6~ 6035260.38 0.8{ N 0,23 E 54~533.84 603526[.22 3,37 N 0.93 E 541834.52 603H263.75 7,57 N 2-09 H 541835,65 60~5267.96 1100.00 4.00 15.40 L099.68 1053.98 13.92 13.46 N 3.7l E 54L837.R4 6035273.86 L5R 1.00 1200.00 5.00 15.40 1399.37 3153.67 21.75 2[.02 N 5.79 E 541839.28 6035281.43 HS L.00 1300,00 6,00 15.40 1298.90 1253,20 31.30 30.26 N 8.33 H 54184L.77 6035290.68 RS 1,00 1400.00 7-00 15.40 1398.26 1352-56 42.59 41.17 N £[.34 H 541844.72 603~301.61 HS 1.00 1500.00 8.00 15.40 1497.40 [451.70 55.63 53.76 N 14.8l E 541848.~1 6035314-22 HS 1.00 Z 1600.00 9.00 35.40 1596.30 1550.60 70.35 68.0L N L8.73 H 54185L.96 6035328.49 HS 1.00 1700,00 [0,00 15.40 1694,93 1649.23 86,81 83.92 N 23.11 E 541856.25 6035344-42 HS 1.00 (Anadrill (c) 97 MPF17PlU ~.20.2 L:$4 ~,] P; ............................................................................................................................................... (~ Mp~-i7 {Pao) &'TAT ION H HASURItD 1 NCI_~ IDENTIFICATION DEPTH ~O~ LBO0.00 L1.00 1,00/L00 ~ X612.68 Ll,13 ~E PH~FROST 1853.45 11.13 ~V~ 2.~5/L00 ~8~3.83 11.13 1900.0~ 11.85 2000.00 14.60 2100.00 17.35 2200.00 20.10 2300.00 22.85 2400.00 25.60 2500.00 28.35 2600.00 31.10 2700,00 33.85 2800.00 36.60 2900,00 39.35 3000.00 42.10 3100.00 44.85 3200.00 47.60 3300.00 50.35 3400.00 53.10 3500.00 55,85 3600.00 58.60 3700.00 61.35 3800.00 64,10 3900.00 66.85 PROPOSBDWIiILL PROPlhB DXRHCTION VHRT [CAb- DH~I~S AZIMUTH TVD SUB - S*ttA [5.40 L'793.26 1747.56 15.40 L805,70 1760.00 15.40 L845.70 1800.00 15,40 1865.70 [820.00 15,40 189[.35 ~845.65 17 Nov L997 Page 2 BECTION C00ROINATBfl-FROM DEPART WHIX.IiRAD 104.99 101.49 ~ 27.95 [09.62 103.64 N 28.60 115.26 11[.42 N 30.69 119,19 1LS,2L N 31.73 124,38 120.24 N 33.[2 15.40 1988.69 1942,99 147.19 L42.29 L5.40 2084.82 2039.E2 174.63 168.82 L5.40 2[79.52 2133.82 206.64 199.95 L5.40 2272.5'7 2226.87 243.15 235.04 15.40 2363.76 2318.06 284.06 274.~9 15.40 2452.69 2407.17 329.29 3L8.31 15.40 2539.71 249.4..01 378.73 366.11 15.~0 2624.06 257~-36 %32.27 417.~6 15..40 2705.7~ 2660.05 489.79 473.46 15.40 2784.57 273~.87 5SE.k5 532.77 15.40 2860.35 2814.65 6L6.21 595.66 ~5.40 2932.92 2887.22 684.82 661.99 £5.40 3002.10 2956.40 756.82 731-59 /5.40 3067.74 3022.04 832.05 804.31 L5.40 3129.68 3083.98 9~0,34 879,99 ALABKA Zone 4 X Y 54L860.99 6035362.02 HS 543861.62 6035364.36 HS 541063.67 6035371.96 HS 541864.69 6035375.76 HS 541866.04 6035380,79 HE TOOL Ob/ PACE ~00 i .00 1 .O0 0,00 0.00 2 39.19 g 541871.99 6035402.87 46.49 E -541879.15 6035429.43 55.02 8 541887.19 6035460.42 64,73 B 541897.01 6035495,76 75.63 H 541907.68 60355~5.36 87.67 ~ '100.83 1~ 115.09 E ,75 H$ 2 .';5 H$ 2.75 S4L919.48 6035579.15 HS 2.75! 54L932.37 6035627.O[ H$ 2.75 541946.33 6035678.64 HS 2,75 130.40 E 543961.33 603~734.52 HS 2.75 [46.73 E 541977.33 6035793-92 ~S 2.75 [64,06 ~ HS 2.75 182,32 ~ I~g 2.75 201,49 H HS 2.75 221.52 H Ha 2.75 541994.29 6035856.90 5420L2.18 6035923.32 542030.96 6035993.02 542050.58 6036065.85 242.36 E 542070.99 6036141.63 HS 2.75 15.40 5187.78 3L42-08 991.50 958.44 N 263.97 E 542092.16 6036220.20 HS 2.75 15.40 324L.92 3~96.22 1075.34 [039.49 N 286.29 15.40 329L.96 3246.26 1161.68 1122.95 N 309.28 H 542136.53 6036384.95 ~S 2.75 15,40 3337.78 ~292.08 1250.32 1208.63 ~ 332.88 R 542159.65 6036470.95 ~Lg 2-75 15,40 3379.30 ~333.60 134L.05 1296.34 N 359.03 H 542L83.30 6036558.58 HS 2.75 .! 4000.00 69.6O 4L00.00 ?2.35 4200.00 75.10 15.40 34L6.39 337~.69 1433.66 1385.86 N 381.69 ~ 542207.45 6036648,23 HS 2.75 15.40 3448.99 ~403-29 L527.93 1476-99 N 406.79 H 542232.04 6036739.49 RS 2,75 15.40 3477,02 343L.32 1623,66 1569.53 N 432.28 E 542257.00 6036832.16 H$ 2.75 (Anadrill (c) 97 MPP17P20 3.2b.2 L:54 PM P) STATION D~FPI FICATION CURVE 2.$0/100 PROPOSHD ~HLL PP./)FILH ~To 2.5o/~oo CURVE cuav~ 3.00/L00 NEASORHD INCLN DI~CTION V~RTICAL-DBPTHS SHCTION DEPTH A~GhE 4300.00 77.85 ~S.4O 3500.41 3~54.7L ~720.62 4346.86 79.f4 15.40 3509.76 ~46~.06 ~7~6.42 ~400,00 79.02 ~6,75 ~St9.83 3474.t3 ~818,40 450~.00 78.83 19.29 35~9.O4 3493.34 4600.00 78.66 21.B~ 3558.56 35k2.86 20t2.6~ I~ND 3,00/100 cul{~m 4700.00 78.51 24.38 3578.36 3532.66 2L08.53 4800.00 78.38 26.92 3590.40 3552.70 2203.41 4818.98 70.36 27.41 3602.23 3556.53 2221.28 5753.09 78.36 27.41 3790.75 3745.05 3099,94 5800,00 78.37 25.97 3800.2L 3754.5] 3144.22 NA OA OB BASE OB CURVB 2.00/L00 5900.00 78.42 22.91 3820.33 3774.63 3239.58 6000.00 78.51 19.85 3840.33 3794.63 3336.01 6100.00 78.62 L6.79 3g60.L7 3814.47 3433.26 6200.00 78.77 13.73 3879.77 3834,07 3533.07 6231-70 78.82 12.77 3885.93 3840.23 3562,t4 END 2.00/100 CDRTH 9-5/8a CASING POINT >>TOP HRZ<< 7030.15 78.82 12.77 4040.70 3995.00 4345.16 7958.76 78.82 12,77 4220.70 4175.00 5255.83 8500.40 78.82 12.77 4325,70 4280.00 5787.06 8655,21 78.82 12.77 4355.70 4310.00 5938.04 9000.00 78.82 12.77 4422.53 4376.83 6276.96 17 Nov 1993 Pa~e 3 COORDINATeS-FRO{4 ALASKA Zone ~HL,I.~[EAD X Y FACE 1663.25 N 458.09 E 542282.28 6036926.02 HS 2.75 1707.52 N 470.28 H 542294.22 6036970.36 95R 2.~5 £757.66 ~ 484.73 H ~42308.~0 6037020.57 9~R 2.50 ~850.98 N 515,08 H 542338.21 6037114.04 94H 2.50 ~942.80 N 549.5~ H 542372.12 6037206.05 94R 2,~0 2032.95 N 58'7.97 E 542410.07 6037296.41 2121.26 N 630.3~ H 542451.97 6037384.95 2~3~.80 N 638.86 H ~42460.36 6037~01,53 2950.00 ~ 1060,00 H 542876.88 6038216,01 2991.05 N 1080.63 H ~42~97.28 6030257.17 3080.21 N 1121.16 E 542937.30 6038346.56 3171.44 ~ 1156.07 B 542972.49 6038437.97 3264.48 N L/87.67 H 543002.76 6038531,17 3359.07 N L233.48 H 543028.04 6038625.90 33~9.33 ~ £220,60 H 54303~.99 6038656.20 4153.27 N 1393.69 E S43203.75 6039421.03 5041.75 N 1594.99 E 543400.03 6040310.54 5560.03 N 1712.42 ~ 543514.52 6040829.42 5708.11 N 1745.97 H 543547.24 6040977.67 6038.00 N 1820.71 H 543620.11 6041307.94 9~00.00 76.91 12.17 4443.55 4397.85 6374,70 6133.45 N 1841,82 9200.00 75.00 LL.56 4467.82 4422,12 6471.70 6228.39 N 1861.77 9254.61 73.95 11.23 4482.44 4436.74 6524.32 6279,96 N 1072.£6 9519.68 ?3.95 2~,23 4555.70 4~10.00 6779.06 6529.83 N 192~.77 19179.72 73,95 15.23 7225.70 7180.00 16062.70 15635.82 ~ 3729.63 543640.68 6041403-51 543660.09 6041498.54 543670.20 6041550.17 543718.39 6041800.29 545~74.76 6050915,43 93R 2.50 L63L 2-00 HS 2.00 HS 0.00 HS O.O0 >>BASE HP.Z<< 192L5.90 73.95 11.23 7235.70 7190.00 L6093,55 35669.93 ~ 3336.40 ~ 54548i.34 6050949.57 [~S 0.00 P~K-19 19324.44 73,95 11.23 7265.70 7220.00 16201.86 ~5772.24 N 3756,72 ~ 545501-08 6051051-98 ~ O.00 TKb'D 19722.41 73.95 1~.23 7375.70 7330.00 16584,33 16147.39 N 3831,20 E 545573.44 6051427.51 HS 0.00 LAnadrtlf [g) 97 MPF17P10 3.2b.2 1:54 P~ P) ...~ PROPOS HD WELL STATI0~ M~ASORBD INCLE XDRNTIFICATION DEPTH At~GLE CURVE 1.5/L0p [9847.07 73.95 19900.00 20000.00 76.25 20100.00 97.75 TKUC 20167.46 78.76 DIRBCTIOE VERTICAL-DEPTHS AZIM1FTH T~D ~UB-SHA EECT£ON DEPART 17 Nov 1997 Page 4 OOORDINATE$-FROM HHLLI{EI%D [1.23 7410.15 7364.45 16704.13 [6264.90 3].22 7424.45 7378.73 16755.10 ]6314.89 11,23 7449.47 7403.77 16851,91 16409.85 11,23 747£.97 7426,27 [6949.35 16505.42 11.23 7485.70 7440.00 L7015.40 16570.20 TKUB 20183.01 78.99 11.23 7488.70 7443,00 L7030.66 20200.00 79.25 1L.23 7491.91 7446.21 17047.34 20300.00 80.75 1l.~3 7509.27 746].5~ 17145.8£ ~NI] 1.5/100 L-'~RVH 20283.42 82.00 1[.23 7521.78 7476.08 17228.29 TKUA 20433.~2 82.00 1L.23 7528.70 7483.00 17277.50 TARGRT ******'*'***~ 20483.42 82.00 [L.23 7535.70 7490.00 17327.31 TKA3 20483.~2 82-00 1[.23 7535.70 7490.00 1732g.3] TKA2 2059£.20 82-00 lf-23 7550.70 7505.00 17434-04 TKA1 20770.03 82.00 ~l.23 7575.70 7530.00 17611.93 TMLV 21166.02 82.00 l~.23 7630.70 7585.00 18003.27 TD / 7" CASINO E~OINT 21466.02 82.00 LL.23 7672.45 7626.75 18300.35 · /LL~SKA Zone 4 TOOL Dh/ X ¥ ~ACB 100 3854.52 E 545596.L0 605L545.13 HS 0.00 3864.45 E 545605.74 605L595.18 HS i.50 3883.30 E 545624.06 605169~.23 HS L.50 3902.28 H 545642.49 6051785.90 H$ ].$0 ~9£5.14 H 545654.99 6051850.75 HS 1,50 16585.17 N 3918.11 16601-S3 N 3921.36 16698.12 N 39~0.54 16779.02 N 3956.60 16827,29 N 3966.18 545657,86 6051865.73 ~S 1.50 545661.O3 6051882.[1 HS 1.50 545679,66 6051978.80 HS 1.50 545695.27 6052059.77 ~L~ 1.50 545704,58 6072108.10 HS 0.00 16876,15 N 3975.88 L6876.15 N 3975.88 [6980.84 N 3996.66 ~7155.3L N 4031.30 L7539.[7 N 410~.51 545714.00 6052L57.00 HS 0.O0 545714.00 6052L57.00 HS 0.00 545'/34.L9 6052261 ."/9 545767.85 6052436,45 1(8 0.00 54584l. 88 6052820.69 }[S 0.00 17830.56 N 4L65.36 H 5~5898-09 6053~12.37 0.00 ANADRILL ............ AKA-DPC APPROV£D PERMITTING PLaN Z lc/ 'U SHAREb i Vii~ SER CES ii i ! ii i i i i i i Marke~' £de.ti[ic~tion ND 8KB SECrN INCLN A) ~(B 0 0 0 0,00 B) KOP/CURVE l.O0/tO0 700 700 0 0,00 C] ENO ]).00/t00 CURVE IB13 lB06 107 ii.t3 D) CURVE 2.75/i00 i874 t866 i19 11.13 E) C~VE 2,50/100 4347 3510 1766 79.t4 F) END 2,§0/t00 CURVE 4619 3608 222t 78.35 G] CURVE 3,00/tO0 5753 3791 3100 78.35 HI END 3,00/100 C~RVE 6232 3866 3~62 78.82 I) CUI:IVE 2.00/100 9000 4423 6277 78.G2 J) END 2.00/tO0 CURVE 9255 4482 6524 73.95 K) -q-5/6" CASING POINT 9520 4556 6779 73.95 L) CURVE 1.5/~00 ~9847 7410 t§704 73.95 I~1 END 1.5/tO0 CURVE 20383 1522 17228 82.00 N) TAgGE¥ I,xw)~,~ 20483 7536 17327 I~..00 O) i'D / 7' CASI~ PD£NT 2(466 7672 [8300 8~.00 D.R,,..,]:LL:[ NG ...... I ii i i ii ii /4nadc j I ] Sch ] u~berge~ imll i ira m 4PF- 7 VEFIT:[CAL SEC~ T_ON ~1.23 ~ inch = 2400 feet ~ ~nch = 2400 feet ~7 Nov ~997 Section a~: TVD Scale · Dep Scale · Dr'a~ln · ANADRILL AKA-DPC · . .. ' APPROVED FOR ~ERM~TTING ONL'_f ...... > ~ PLAN~ //___~ ~ ,- .... t~ '" ~---' ..... ~,~- ~ ~J~ ......... t- .- ~ ....... ............ , .... ~ .... :--:- ....~ ..... -- ~ o ........ ' ....... ~ ' ............ t ............................ L ....................... ~ ............ ~ ...................... 0 t200 2400 350U 4600 bOVU /~0u, ~4u';J ~bu-d ,,~b~d ~.~,~,-~,. ,,,~.v~, ~ -.._-_ .,_--;-.- ....... ' '" Sect ion Oeparture I/mdt'ill (c)97"'I~,F17P'IO 3.~.03 1:54 INI Iai ....... m 'SRAREDSERVTCES DRZLLIN6 i iii iiii i m I I I I II #arker Identification MD BKB SEETN ZNCLN A) CURVE t.S/lO0 1§847 7410 16704 73,95 8] END i.5/t00 CtlttVE 203B3 7522 i7228 82.00 C) TARGET xx~xm~x)~xxx~ 204B3 7536 i7327 I~..00 II I I II I I AnadriJ] Schlumberger I , ,, II ! I 4PF- 7 (P O) VERTICAL SECTION VZE~ D) fO / 7' CASING POINT 2t456 7672 t8300 a2.00 iOll at: 1i.23 io.p Scale.: ! inch = 200 leer - ^v A rN )i"" I--%" ~ a,,,,' ANAL)i~tLt. · A __ ~^m ~co~,, ITT! ~l~ ON -Y . [ ~r'~;,,~ ~ .... .~,...- ..... ., f ~-~~~~ .................. ~j:~ ..... ~ ~-~ ~~ ..... , . ................................... ' .................' ......................................... ' ' ................. ~ .................................. 2 ................................................................... i (Aha(ifil] lc)97 NPFI7PI0 3,~D.HZ !: 59 R4 P) zGyou )uuuU tb~u 1/out) t/)ut) t/~oD ~/JUO t/400 !)'bO0 1/riO0 t Ii00 17800 17900 18000 tBtO0 t8200 t~O0 18400 IUSO0 Sect kon DepaPture I I I I1! 1i/17/1997 15:40 907-344-2!_G~0 ~ · ~NADRILL DPC _ ~ pAs~ u~ , A1 K6 0 0 N 0 E V EW ENO i.O0/~O0 CUnVE 18~3 i04 N ~g E , · CuRvE 2.75/~00 ~874 ~5 U 3~ E: - '' ...... J3.~i'--'" ~i CURVE ~.50/~00 4347 170B N 470 E ~ CLOSURE ..... : ~83J~ feet at Azkmuth DECLINATION.' +27.836 (E) ~ 1221E 1821E i872 E 1922 E 3855 E 3957 E 3976 E 4165 E G) CURVE 3.00/100 5?53 2950 N H) END 3,00/100 CURVE 6232 338g N I) CURVE 2.00/~00 9000 6038 N J) END 2.00/~00 CURVE 9255 6280 N K) 9-5/B" CASING POINT 9520 6530 N L) CURVE ~.5/~00 ~9847 1G2G5 N M) ENO 1.5/100 CURVE 20383 t677g. N N) TARGET ~*~**~ 20463 16876 N O) TO / 7' CASING POINT 21466 17831N SCALE · ~ inch : 3000 feet DRAWN ....... ' ~7 Nov ~997 m Anadri 11 Schlumberger ~.0500 9000 7500 6000 (Ana~r~;H {¢)g7 )4PF~7Pl0 ~.2b.02 1:55 p)4 p) 4500 3000 1500 0 1500 3000 4500 6000 7500 <- WEST · EAST -> go00 '0500 m Fidd Fac~ i i Miln¢ Point M Pt F Pad 987-344-2.1-68 ~NADRILL DPC ._ I Target Analysis Report Well MPF-17 Target MP Fl7 B Page Date PAGE 18 : · 2 , 22:19, 17 Nov 97:. I · Well Data at Interse~ti°n of WDF on target plane MD 20525.0O ft Highside Random 16.06 Bias 0.00 Semi-Major Axis Uncertainty Uncertainties at 1-sigma = 68 % Confidence Xnelination lateral (f0 83.85 0.00 83,86 ft 82.000 deg 15.45 0.00 Magnitude Azimuth 0.00 ft 11,745 deg 400 -2OO 0 East fit) 2OO d. JI I ' - C-,ological Target 99.00% inclusion contour Driller's Target 90.0O% Inclusion contour SHARED SERVZCES DRTLLIN -MPF-'I7 (P10) :! "'~"'"'~"~""°" '~ ~ · B) KOP/CURVE ~.00/~00 700 0 E C) END 1.00/100 CURVE $8~3 29 E D) CURVE 2.75/~00 ~87~ 32 E · E) CURVE 2.50/~00 4347 470 E F) END 2.50/)0o CURVE 48~9 639 E G) CURVE 3,00/~00 5753 ~060 E H) END 3.00/100 CURVE 6232 ~22! E I) CURVE 2.00/~00 9000 ~8~ E J) END 2.00/~00 CURVE 9255 1872 C K) 9-5/B' CASING POINT 9520 J922 E L) CURVE ~.5/~00 ~9847 3855 E M) END $,5/J00 CURVE 20383 $6779 N 3957 E N) TARGET ~NNN~ 20483 ~6876 N 3976 E D) TD / 7' CASING POINT 2J466 ~783~ N 4565 E 3500 3600 3700 3800 3900 4000 4~,00 . 4200 4300 - 4400 4500 4600 4700 4600 !~00 EAST -> (Anodril) (c)g7 NPFJ7PlO 3.~,5 ?.02 PH P) TONY KNOWLE$, GOVEF~NOR OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 14, 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-17 BP Exploration (Alaska) Inc. Permit No. 97-196 Sur Loc 1808'NSL, 273 I'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc 3790'NSL, 3540'WEL, Sec. 20, T14N, R10E, UM Dear Alvord: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated October 16, 1997, are in effect for this revision. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 11/12/97 la. Type of work l~ Drill I--IRedrill Ilb. Typeofwell []Exploratory I--IStratigraphicTest I~DevelopmentOill [] Re-Entry [] DeepenI [] 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 KBE = 45.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355016 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2841' NSL, 3669' WEL, SEC. 20, T14N, R10E, UM MPF-17 At total depth 9. Approximate spud date Amount $200,000.00 3790' NSL, 3540' WEL, SEC. 20, T14N, R10E, UM 11/16/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355017, 3790'I No Close Approach 5071 21524' MD / 7672' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 Mc 25.035 (e) (2)} Kick Off Depth 700' Maximum Hole Angle 82° Maximum surface 3046 psig, At totaldepth ('I'VD) 7630' / 3809 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stagedata) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8"' 40# L-80 Btm 9489' 31' 31' 9520' 4556' 1815 sx PF 'E', 1087 sx Class 'G' 8-1/2" 7" 29# L-80 Btrc-Mod 21494' 30' 30' 21524' 7672' 271 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 M D TVD Structural Conductor Surface Intermediate Production : '. ~'' : .... .i:'. ~.' ' i '.. Liner -' Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAO 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Carnpoarnor, 564-5122 21 I hereby certify that · the f,,or,cegoing,~ true a~d correct to the best of my knowledge Signed ChipAIvord ( . Title Senior Drilling Engineer Date ~-~ - L.~. ~-'~o~Commission Use Only Permit Number I APl Number I Approval Date See cover letter 97-196I 50-029-22823I 10/16/97 for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes ~No Hydrogen Sulfide Measures [] Yes 1~ No Directional Survey Required [~ Yes I-I No Required Working Pressure for BOPE El2M; []3M; ]~[5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By David W. J0hnst0ri Commissioner the commission Date Form 10-401 Rev. 12-01-85 -' Submit In Triplicate BP EXPLORATION November 12, 1997 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 SubjeCt: Before Spud Changes to Approved Application for Permit to Ddll //97-196 Dear Mr. Johnston, In order to increase the length potentially productive pay interval in the Kuparuk A Sands, minimize future close approaches and minimize the dsks associated with hydraulic fracturing and proppent placement it is requested that the well trajectory be modified from the one submitted and approved in the Permit to Drill 897-196 on October 16, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.016 Changes to the Drilling Permit, (a) For a proposed change in a drilling permit ..... before the start of actual drilling operations. It is requested that the directional profile be. changed from an S-Shaped profile to a Slanted-Build and Hold High Angle profile. The directional plan will still begin at the same proposed surface location and- intersect the same proposed target location, however the bottom hole location will change because of the requested change to the hole geometry. As a result of this proposed change in the well bore trajectory the following changes are requested: 1. The directional well plan be changed. (ATTACHED) 2. The location At Total Depth be changed to 3790' NSL, 3450 WEL, Sec. 20, T14N, R10E, UM. 3. The surface casing Setting Depth Bottom be changed to 9520' Md(4556' Tvd). 4. The surface casing Quantity of Cement be increased to 1815 sxs PF 'E', 1087 sxs Class 'G'. 5. The production casing Setting Depth Bottom be changed to 21,524' Md(7673' Tvd). 6. The production casing Quantity of Cement be increased to 271 -sxs Class 'G'. Thank-you for your consideration in this matter and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill ~J7-196 please contact me in Anchorage at 564-5042. Respectfully, Lance Spencer Drilling Operations Engineer BPX-Shared Services Drilling Shared Services Drilling Contact: I Well Name: Lance Spencer I MPF-17 ] Well Plan Summary Type of Well (producer or injector): 564-5042 I Kuparuk Producer Surface Location: 1808' NSL, 2731' WEL, Sec. 06, T13N ,R10E, UM., AK Target TKUA3 2841' NSL, 3669' WEL, Sec. 20, T14N, R10E, UM., AK Bottom Hole Location: 3790' NSL, 3450' WEL, Sec. 20, T14N, R10E, UM., AK I AFE Number: I 337109 ] Rig: I Nabors 27-E I Estimated Start Date: I 15 Nov 97 I I Operating days to complete: IUD: 121,524' I IT VD= 17,672'Bkb I I KBE= Well Design: Ultra Slim Hole Long String HAW Formation Markers: ]22 ] 45.7' 9-5/8", 40# Surface X 7", 26# Longstring Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1853 1846 8.4 PPg 806 psi NA Top Schrader Bluff 7030 4041 8.4 ppg 1765 psi OB Base Schrader Bluff 8655 4356 8.4 PPg 1903psi Top HRZ 19234 6660 8.8 ppg 3047 psi Base HRZ 19271 6720 8.8 ppg 3075 psi TKLB(MK-19) 19380 6825 9.2 ppg 3265psi TKUD 19780 6990 9.2 ppg 3344 psi TKUC 20226 7486 9.6 ppg 3581 psi TKUB 20241 7489 9.6 ppg 3738 psi TKUA3/Target 20542 7536 9.6 PPg 3762 psi TKUA1 20829 7576 9.6 ppg 3782 psi Miluveach 21224 7630 9.6 ppg 3809 psi Total Depth 211524+ 7672+ 9.6 ppg 3830 psi · *These are estimated maximum pressures and the actual pressures may be lower. ~as,ng/~ uD,ng Fro~. ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/'rVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 9489 31/31 9520/4556 8-1/2" 7" 29# L-80 Mod. 21494 30/30 21524/7672 btm The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 7,630 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7,630 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,809 psi is 3,046 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-17 (ERD A) Revised Drilling Permit 1 11/12/97 Cementing Program: Halliburton Cementing Services Hole ~ Ca~ing Interval Volume~ Spacer Type of Cement Propertiesz Category Size/Depth Surface Lead4 Lead Lead Lead First Stage 9-5/8" @ 2054-6530' 840 sx 70 bbls Permafrost "E" Den 12.0 ppg 9,520' 325 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 6530-9520' Tails Tail Tail 1087 sx Premium Class "G' w/ Den 15.8 ppg 223 bbls 0.2 % CaCl, 0.15 #/sk Celoflakes Yield 1.15 ft 3/sx Water 4.9 gps 'iT 4.0 hrs ............................................................................................. Second Sta~je ~'~s ............. i'~'~J~ ..................... .~'~1 ....................................... ~ ........................................................ Stage collar" @ 0-1853' 975 sx 75 bbls Permafrost "E" Same as above 2,053' 1853-2054' 377 bbls Fresh water Production 7" @ 19,226- Lead" Lead Lead Den 15.0 ppg First Stage 21,524' 21,524' 271 sx 50 bbls. Foamed Premium Yield 1.46 ft 3/sx 71 bbls Alpha Class "G" w/ Water 3.95 gps Spacer 15%Silicate, TT 3.5-4.5 hrs @ 140° F 50 bbls 0.45% Halad 344 FL 30-40cc/30 min Foamed 0.1% CFR-3 @140° F Alpha 2 gps Latex 2000 Spacer 0.Sps C434B 0.1 gps D-Air-# 0.1% HR-5 1. Volumes are rounded u :) to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,053'MD-J: 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,054-6,530' md. The estimated first stage lead cement volume from 2,054-6,530' md and is equivalent to the annular volume calculated from the 9-5/8' ES Cementer at 2,054' md which is 200 ft md below Base of the Permafrost at 1,853' md (1,845 TVD bkb) to 6,530' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 6,530-9,520' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 6,530-9520' (500' md above the NA top) to surface TD at 9,520' md (4,556' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,054' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,054' MD (2,052' TVDbkb) to surface. From 1,853' to surface include 250% open hole excess and from 1,854-2,054' use 30% open hole excess. 7. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from 7,030-9,520' of 9-5/8" casing to cover the top of the NA to Base OB. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 19,226-21,524' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 19,226' which is 1000'_+ above the Kuparuk C Sand to TD at 20,226' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint from 120' below to 120' above any potential hydrocarbon bearing sands. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk C sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurdes in the surface and production holes on the fly - batch mixing is no~t necessary. MP F-17 (ERD A) Revised Drilling Permit 2 11/12/97 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ Cased Hole Lo~ls: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM/in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Seawater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-10.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 <4 Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP F-17 (ERD A) Revised Drilling Permit 3 11/12/97 Directional: KOP1 700' Start Variable @ 1.0°- 3.0 °/100 and Az 12.77°. EOB @ 6232' md. Tangent Hole Angle 78.8° from 6,232-19,912' Final Build Section Start Final Curve 19,912 @ 1.5°/100 to 82° incl. and 12.77 Az o EOB 20,442' md Tangent Section 82° incl. and 12.77 Az o from 20,442-21,524' md Maximum Hole Angle 82° from 20,442-21,524' Close Approach Wells Survey Program All wells may remain flowing while ddlling F-79 and no shut-ins are required. 1. Surface to 9,520' MWD surveys. 2. 9,520-11,520' GYRO to surface 3. 11,520'-TD MWD with in hole reference. 4. 2~E. Disposal: No "Drilling Wastes" will be injected or disposed into F-17 while drilling this well. Cuttings Handlin_~: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPF-17 is planned as a high angle, 82°; high departure, 18,381'; ERD, 21,524'; Kuparuk River A Sand producer. The HAW Slant shaped well profile with a final angle of 82°, will intersect the target objectives and provide optimum inclination for fracture stimulation. The surface casing will be deep set below the Schrader Bluff at 9,520'md (4,556' bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval which should not be ...... abnormally pressured by area injection. Geolo_clv The primary targets are the Kupauuk A3, A2 and A1 sands but has some potential in the Kuparuk B and C sands.. The deepest known oil in the area is at F-74i to a depth of 7,472 tvd ss. No water contact is expected at the F-17 location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 100-~-_ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this producer are estimated at 4.1 MMBO assuming a 120 acre drainage area. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted and not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP F-79, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. MP F-17 (ERD A) Revised Drilling Permit 4 11/12/97 Water, Gas and WAG Iniection Formation pressures are expected to be partially depleted at a maximum of 9.6 ppg EMW pore pressure in the Kuparuk while drilling F-17. The Kuparuk may be partially pressure due to nearby production from F78, F-53 and possibly F-66a and F-38. Injection support for the fault block in which the F-17 well path intersects in the target interval is provided by F-70i and the fault block to the east contains injector F-74i. Abnormally Iow pressures caused by production and high pressure due to area injection are not expected while drilling F-17. The injectors F- 701 and F741 areexpected to be in communication with the proposed F-17 BHL but the injection is not expected to have abnormally pressured the reservoir due to offtake for producers F-78, F-53, F-66a and F-38. Annular Iniection Currently annular injection is not permitted on F-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. With the possibility that the HRZ will be truncated or absent the potential for stuck pipe the transition interval from ...... Colville(SeeBee) to Kulubik is recognized. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurrence has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK A1 SAND 7630' TVDss 3809 PSI 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at +_. 7,630 TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __7,630' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,809 psi is 3,046 psi. The maximum expected pore pressure for this well is 9.6 ppg EMW (3,809 psi @ 3,046' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. MP F-17 (ERD A) Revised Drilling Permit 5 11/12/97 MP F-17 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,054' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk C sand and PBTD before running the 7' casing. 11. Run 7" casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP F-17 (ERD A) Revised Drilling Permit 6 11/12/97 DZRECTIONAb WBLL PLAN for SHARHD 9~.RVICF~ DRI[LD~G Well ......... : MPF-17 (PO9) Field ........ : Milne PoinL Com~u~aClon..: Minimum Curvature Unite ........ : PE~T Surface Lat..~ 70.50724922 Surface Lone.: 149.65773654 becjal Description Surface ...... : 1808 PS5 2731 PHL S06 T13N RIOE UM Te_T~et ....... : 284[ ~SL 3669 PHi S20 T14N R20E UM BEL .......... : 3790 PSi 3450 F~ S20 T14N ESOB UM .. LOCATIONS -ALAS~Zone: 4 X-Coord Y-Coord 541833,61 6035260.~8 5~60t4.00 6D52157,00 546223,64 6053107,09 PROPOSHD ~Hbh PROFrLa STATX0N [DE[tTXF[CAT[ON ~/cu~ ~.oo/~oo 'DEPTH ANG~B 0.00 0.00 700.00 0.00 80~.00 L.O0 900.00 2-00 lO00,0O 3.00 DIi~C?~ON ¥~T£CAL- Dgt~J~S &Z l MIJTH '.?VD 0.O0 0.00 ~45;70 15.40 T00.00 654,30 25.40 .?99.99 15.40 899~96 854~26 15.40 999,86 954.16 SECT/ON DHPART 0,00 .0,87 ? .85 Prepared ..... : l0 Nor.t99? Ve=~-sec% az.: 14.22 K~ e[evat£ou.~ 45.70 MagueClc Dcln: +27.846 Scale Pactor; .' ..0..9999Q].99 Convergence..: +0.32264662 , __ ANADRIL[ AKA-DPC. APPROVED. FOP, PERMITTING 'ONLY eo0~ox~A:~s-r~o, mas~ ~.0~, 4 TOOZ~ Dr,/ WHL~}[~AD X Y FAC~ 100 mmm mmmmm J ~ llmmm mmmll !mmmmmmmm mmammma~ma mmma mmmm O,00 H 0.00 ~ 54,1833,61 6035260;38 1SE 0.00 ,0,00 N 0,00 E 5i1833,61 .6015260,38 . . 0.84 N 0.23 ~ 541833,84 6035261,22 =SR 0,00 'lsR L.00 3,37 N 0.93 ~ 541834.52'6035263,75 1SR L~O0 ?,.57 N 2.09 E 5~1835.65 6035267,96 15~ 1,00 1L00.00 4, GO L200.00 5. O0 [300,00 6,00 /400.00 7.00 iS00,00 8.00 i600-O0 9,00 [?00.,00 10.00 (Anadr£1l (c) 99 HPF17P09 3.2b. 2' 5:1.1 PM P'J ,, 15:40 1099,68 15,40 1199,37 L5,%0 1298,90 /5,%Q t396.26 L5.40 £497,40 15,40' '.1596 ~30 .15,40 1694,93 1053.98 L153,67 £253,20 L352,56 ~451,90 ..1550.60 2649~23 13,95 '33,46 N 21,80 21.02 N 31,36 30,26 N 8.33 42,?0 4'1,[? N 55,75 53,76 N 14,81 . , 70.53 68,01'N 18,73 ,, 3,7~ g 54L837,24 5.79 ~ 541839,28 60352?3.86 LSR 1.00 6035281.43 ~ ~,.00 54184[.?? 6035290.68 aS ~.00 5¢~844,72 603530L~6L 'H~ '1,~0 541848,11 6035314.22 IlS 1,00 ,. , 5%1852,96'60'3S328.49 HS' .[,'00 54[656,25 60355~4,42 [~S ~3.00 , . '.. PROPOSHD'WE~b pROFILE S~AT ION ~UR~D ~NCLN O l ~ON IDH~fFX~T~O~ DH~ ~GLH ., 18OO. O0 11,00 ~ .40 ~793.26 ~D 1.00/100 CUR~ 1812,68 1L,~ 1~.40 ~ PE~OST 185] ,4~ CURVE 2.75/~00 1873 . 8~ Eg00.0O E~.85 15.40 ~8~1.35 V.RrXCA.U-Or.~'T~S ~U~-SEA 1747.56 1060.00 LBO0.00 ~820.0.0 ~845.65 2000.00 14','60 2100.00 37 2200.00 20. LO 2300.00 22 2400.00 25.60 2500.00 28.35 .'2600.00 31.20 2700.00 33.85 '2800.00 36.60 2900.00 39.35 3000.00 42.10 3L00.00 44.85 3200,00 47.60 3300.00 50.35 3400,00 53.10 3500.00 55.85 3600.00 58.60 3700.00 61.35 3800.00 64,10 3900.00 66.85 15,40 15.40 15.40 15.4o is .4o 15.40 15.40 L5.40 LS.40 ~s.4o L5,40. 15.40 15.40 15.40 15.40 1988.69 1942.99 2064:82' 2039.'t2 21'79.52 ,2272,57 2362.% .76 2452.87 '2539.'71 · . 2624.06 27'05.75 2784.57 2133.82 2226.87 2318,06 2407.17,'. 2494.'01 2578;36 2660,05 2938.89 2932.~2 2ee'7,22 3002,,'t0 2956.40. 306?.94 3022.04 31.29.68 '~083,96 4000.00 69.60 4100.00 92.35 4200,00 75.10 , ,10 }~ov 1999 · ... . SECTION OOORDZNATHS-FRO~ D~PART . ~T~Z~4HAD . . . L05.25 101.49 N 2~.95 307,..68 ,L03..84 ~ 2&,60 135.54 LX1.42 N 30,69 119.48 115.21 ~ 32,~3 t24.69 120,14 N 33.12 L47.$5 L75.06 207~15 243.74 284.95 . .. 330.09 379:66' 433.33 490,98 S52.49 686.49' a34.08 9 L2 · 56 Page 2 · -ALASKA Zone 4 ~O0~ Db/ .. X y. PAC8 ~00 mmmmml~=m m mmmm mm xm I I ~41860.~9 6035362.02 H$ 1.00 S41863.62 6035364.)6 ~$ L.00 541863.69 603~3~L.'96 ~S 0.00 543064.69 6035595.76 HS 0.00 543866.04 6035380.79 HS 2.75. 142'.29 N 39;19 168'.$1 N 46.49 199.75 ~ 55.02 235.04 N 64.73 274.59 N 75.63 3'18.3X N 366..L2 N 417.6.6 N 473,46 'N $32,97 N 595.66 N 661.99 N ~31.59 N 804.3~ N 879.99 N 15,40 3~87.'78 3142.08 993.92 958.44 R 15.40 3241.92 3196.22 1077.9'7 1039.49 N IS.40 3291.96 3246.26 1164,52 1122~95,N 15.40 3337.78 3292.08 1253.37 1208'.63 N 15.40 3'379.30 3333.60 L344.32 L296.34 N 15.40 3416,39 3370.69 1437.15 L385.86 N L5,40 3448,99 3403.29 3533.66 L4~6.99 N L5.40 34~7,02 3431.32 ~627.62 £569,53 N 54t871,99 6035402r87 ~ 2.75 541679.'15 6035429.43 H8 2.'75" 541087.49 60354~0,42 ~S' 541897.01 6035495.76 H~ 2.75 54~90q.E8 6035535~3~ HS 2.75 8~.6~ S $419X9,48 60355~.g..lS ILg .2,~5 100.83 H 541932,.37 6035627..'0t ng 2.75 225.09 S $4~945..33 6035678.64 ~9 2.75 . . 130.40 ~ 54196~.23 6035?34.52 HS 2.75 i46.73 ~ 541977,33 6035?93,92 ES 2,75 . . 164:06 E 541994.29 6035856..90 182.32 B 542012,10 6035923.32 201.49 H 542030,96 60359~3.02 H$ '2.~,5 222.52 H 542050,58 6036065.85 NS 2,75 2~2.36 ~ 542070.99 603614~.63 263.97 H S42092,16 6036220.20 KS 2.75 286.29 ~ 542L34.02 6036301.37 HS 2.75 309.28 E 542136.53 60363g4.95 HS 332.88 E S42159.65 60364?0.75 HS 2,75 357.03 · 542~83.30 6036558.58 BS 2.75 381.69 B 542207.45 6036648,23 H$ 2.75 406.99 H 54~232.04 6036739.49 H~ 2.75 432.28 H 542257.00 6036832,16 HS 2.95 (_A~.aCrikL..(c.) 9.? ..~.[,L.?E.o.9 3..2b......2...5:1_]. g'J,t p) STAT:O~ l DBbP~I F~CAT ION CURVE 2.50/100 ~D 2,50/100 CURVE CURV~ 3.00/100 ~ND 3.00/X00 CORV~ OA OB 8ASR OB cuRv~ 2,00/100 ~ND 2.00/L00 CURVB g-S/8" CASING ~OZNT >>TOP HR~ < < NHASURED I~CLN D~RHCTION DE~TK ANGLE AZ l MUTH 4300,00 77.B5 L5.40 4346.86 79.14 ~S.40 4400.00 79.02 16.7S 4S00.00 78.83 19.29 4600.00 78.66 21.83 %700,00 78.5L 24.39 %800,00 98.38 26.92 4818.98 78.36 27.41 $753.09 78.36 27,41 S800.00 78.37 25,97 $900.00 78,42 22.9L 6000.00 78.SL 19.85 6L00.00 78.62 6200.00 78.77 6231,70 78.82 [2.77 7030.15 78.82 12.77 7958.76 78.82 52.77 8500.44 78.82 12.77 8655.21 78,82 12.77 9000.00 78,82 12.77 gL00.00 76.82 t2.77 9200.00 74.82 L2.77 9238,79 74.05 .L2.77 9519.59 T4.05 L2.77 [9234,29 74.05 12.77 X0 Nov L997 Page 3 ~. P~OPOSHD ~HL~ PROF:LH ~' '' · . . . 'V~RTI CAb-DEPTHS SECTION ' ~OoRD/NAT~S-~ROM T'VD SUR-SHA DEPART .~ELLER~ 3~00.43 3454.71 1724.82 .[663.~ 3509.76 3464.06 L770.73 ~707.$2 3519,83 3474,13 1822.87 1757,66 3539.04 3493,34 1920,79 1850,98 . 3558,$6 3512,86 2018.25 1942,80 3820.33 .377~.63 3840.33 3794.63 3860.L7 3814.47 3879,77 3834,07 3885,93 3840,23 III liIIIil I IIII ALASKA Zone % Y i~=~l ~Ii 458.09 Z -54~2~2.28'6a~6926.02 470.2~ z 5422~4.~2'6o36~7o.36 4~4.73 B 542308.38 6037020.57 515,08 B 542338.21 6037'11~.04 549.St E $42372.12'6037206.05 · . 4040.70 3995.00 '4220.70 4175,00 4325.70 %280,.00 4355.70 t310.00 4422.53 4376.83 4443.62 4397.92 4466.12 4422.42 4478.52 4432.82 4555.70 4510.00 7225.70 7180.00 i TOOL Ob/ PAC~ 100 95R 2.75' 9SR 2.50 94R 2.50 94R 2,50 3578,36 3532,66 2L~S.09 2032,95 N 587.97 E S42410:0.7 6037296,41 93~ 2.50., 3598.40 3552.~0 ~2~L.11 2L2i.26 .N 630.~7 . S424~1.97 6037~84,95 93R =~'$0[I iII 3800.2l 3754,51 3164',85 2991,05 ~ 'L080,63 R 542897,28 $038257,t7 69b 3,00 :' 3201.24 3080;21 . lX2Z.L6.S 542937.'30 6038346.56 aass:'44. , .. 317i.44 a 11s6.87 E S4297~..4~. '~01843T.97 ]S54.23 ~359.07 N 12L3.~S H S43028;0~ 60~8625.90 5.2~9'.07 504L.75 N L59%.99 ~ 543'400,03 60~0310.54 ~ . N ~712.42 B 60!0a29.42 5962.L0 5.708.1L N 1745.99 · 5435i~.24 6~4097~.67 6300.24 603a.00 N ~a20.73 ~ 5436~0.~ 6~41~07,94 6397.95 6133.33 ~. ta42..SZ S S13~4~.Z7 604L403.38 ~ 2.00 6494.8~ 6227.88 N 1863.73 8 543~62.06 ~04~Sa.0S ~S 2,00 6532.22 6264.32 ~ ta~.V9 ~ 543670.11 6041534.53 ~ 2.00 6802.~3 6527.64 N L9~1.65 ~ 543~28.~8 6043798.16 ~ 0.00 i~lB.70 15637.33 N 3995.6L B 545~40.71 6050918.43 ~ 0.00 >>BASE ~Z<< 19270,67 74.05 12.77 MK-~9 19379.83 74.05 12.77 TKUD lg~80.06 74.OS 12.77 7235.70 7190,00 16174,67 15671,45 fl ~003.34 E S457¢8,24 6050952.59 1[8 O.00 7265.70 7220.00 162~9,$9 15773,8L ~ 4026.53 B 545770.85 6051055~07 RS 0.00 7375,70 7330,00 16664,29 16149.L~ M 41LL,56 B 545853',76 6051430,81 KS 0.00 (~..a.~.L.i! ..(,.c)97 .~.F.~7~Lo~...}...2.b...2 5 =..%[. ~ ..p) ............ . .... MPF-17 .. CURV~ 1.5/100 19911.62 74.05 20000'.00 qS.37 20100.00 76.89 20200.00 78.~7 T~C 20~25.83 TKUB 20242.38 78.99 20300.00. 79.87 20400.00 81.37 END 1,S/L00 CU~Vil 20441.79 82,00 TKUA 20491.49 82.00 TARGHT ~***~'****~* 20541.79 82.00 TEA3 20541.79 82.00 TKA2 206~9.$~ 82.00 TKA1 20829.2D 82.00 THLV 21224.39 82.00 TD / 7* CASt}~G PT 21524.39 82.00 10 ~ov ~997 ~age 4 " ~. PRO~SED WRbb ~ROPILII D£RECTIO~ V~RTI CA~- DEPTHS sECTIoN AZIMUTH TVD SUB -$HA DEPART . . 12.77 7411.66 7366.t6 16790.73 L6272.'47 N L2.77 7459.LS t2.77 7460.58 L2.77 7485.70 ,' . ':O00RDI~ATES-FRO~ 74t3.45 16973.01 16450.30 N 7434.88 LT0q0.6$ '16545.56 N 7440.00 ,L7095..96. 16570~'25 N 4].39.52 4 L.%8 ..,%S 4L79.00 4201.39 4206.98 A/d~SKA zone. 4 TOOL X' Y FACE . : S45881..02 6051554.32 HS - S~5899.38 60.51~3~.S6 HS 545920.30 6051732.35 ~S 5459(L.34 6os].82~.72 es 545946.~0 6051852.~4 HS Dh/ lO0 .o..0o t.50 L.5O 2.50 '3'.S0 12.77 7468.70 7443.00 L7111.22 1658S.13 N 4210.35 12.77 ~499.45 7453,75 17168.'82 16641.33 N 422~.09 g 545962.50 605~923.60 HS' 1,50 12.77 7515.74 7470,04 17267.4~ 167,37.SS N' 4244.89 ~ S459B~.~6 .6052019.94 HS 1.50 12,77 7521,'78 7476,O8 17308.76 ~6777.88 N 4254.02 E S45992.66'6052060.3~ ES 1.50 12.77 7528.70 7483,O0 1~357.99 ~6825'.88 N 4264.90 g 546003.2~ 6052108.37 HS 0.'00 12.77 7535.70 7490,00 17407.78 L6874.46 N ~275.90 H 546014.00 6052157.00 ~S .0.0O ~2.77 7535.~0 ~490.00 1740~.70 '£6874,46 N 4275.90 H 546014.00 605~LS7.00 HS 0.00 L2.77 7SSD.?0' 7505.00 ].75~4.47 L6978.55 N 4299.49 H 5~6037.00 605226L.21 HS 0.00 L2.77 7575.~0 ~530.00 L7692.30 17152~04 N 4338.80 il 546075.32 6052434.90 HS 0.00 L2.77 7630.70 ]585.00 L8083.52 17533.71 E 4425.2~ H 546159.64 60528L7.02 HS 0d00 12..77 7672.45 7626.~5 LB380.~O 17823.'45 N 4490,91 ~ 546223.64 6053107..0g 0.00 _ - . ANADRILL A?PROV'ED FOR PERMITTING ONLY _- PLAN. (Anadr/LL (c) 97 MPFL7P09 3.2b.2 5:'].L PM P) SHARED SERVICES DRILLING"." ,4nadr.i]]"Sch]U~ber'ger. t4arker Identification 140 BKB SECfN ,NCLN MPF--~7 (P09)' ,I ~o,/~u,~ ,.,o/,oo ,~,oo oo.o, VERTICAL' SECT'ION VIEW . 0] CURVE 2.75/~00 1874 t866 lib 1i.13 Section at: 14.2~. ' · . · E] CURVE 2.50/t00. 4347 35~0 1771 79.14- TVD Scale ' i inch = 2400.feet. F} E~ 2.50/100 ~mVE 48iS 360~ 2229 78.~ · - SI CURVE 3.00/100 5~53 ~791 3~20 ~.36 Dap Scale.' I ..loch . 2400 feet H1 E~ 3.00/100 C~VE 6232 3886 3585 78.~ Drawn · t0 Nov.lg97 - Il CURVE ~.00/I00 ~00 4423 ~300 78.82 ~) Em ~.00/~00 ~VE m3S 4479 6~3e 74.05 ..,, K) 9-5/8" C~SZ~6 P0[~T m20 45~ 6~2 74.0~ ' '~ L) C~VE i.5/100 1991~ 7412 16791 74.05 ANADRILL A~.DpC ... ,~ ~,,~r-.-.-..,- ~o~ ~ ~,o, ,~.oo APPROVED "' -" .. :-" ''-' o) ~0/~' c,sz,~ ,~ ~ ~7~ ~a~ ,~.0o 'FOR' PERMITTING " '~''- - " " PLAN-~ '. L ~ ".'.. D SectiOn De ture ' I~td¢iLl bl97 ~FIT~ 3.2a.OZ ~ t3 PH P) SHARED SERV.T.CES' "DR Z ELAN. G"" ..... .sr m ¢¢rger . · CURVE t.5/t00 t9§127412 16791 74.05 m ~,o,.,/,ooou,,,,. ~o,~,~ ~,~ ,~o, ,~.oo .. -: VERTICAL SEC'ffON VIEW 'fAFIGET xx~x)~x-xx~)~xx 205427536 I f0 /7' CASIN6 PT 2t524 7672 11~38t ~.0, ANADRJLL ' '. AKA-DPt't' JseCt~on at: ~4..22.' .. · ..ADDDAWC~ : ". .. .JTVD. Scale,-:' 1' inch =.'200 feet .. ·- -----------. . .'lDep Scale,: 4. ~nch'''= 200 .fee[ 'FOR PERMITTING." jOra.n..'...: 10. Nov:'i997 . "ONLY'..'..'"- . ' ........ " ..'. ... -,- , pLAN'"~ .'.c/ .... .. , . · · · . . ..., · · . , · , , . ~(._'.__r~ "'r~K . :. : .... ' . . . , ,,... .. ,. i ,,,, , , , ...... . , '..,:~1. Il' ' f~l ............ .......... '"='' ''""' ...... ... ...... ~ ~=, d,i~J~'-2-O0, feet J . ~~, '-,--- ._., ..... :__-=~_ ...... . '¢,.~['" - ~ ' ' '~r- ~......................... ,., ...... :.' .... ; , , , , , , , , , , , , , , ., , .. . , , ,. , , . L ,. ............. , ....... , ........ . . ___'." ....... -- . . . ' , .......... ~. ....... _ -_ _:__.._ '-_,:: i (Afledrlll k)cJ7 ,~FITK)9 3.Zb.n~ ~f;ZI I~1 Pi Section DepartUre : .'' '., " " · i ! iiii -- . ., . . . ,. . . . 1i/18/1997 18:22 987-344-?!&8 AN~DRIII DPC PAGE 88 , r SHARED SERVICES 470 E N/S ON ON 104 N ~15 N ~708- N 2138 N 2950N 3389.N .6038 N 6264 N '6528'N. 16272 N 16778 N- 4254 N-- 4276 E- N' 449t-E · 639 E tO60 E .1221 E t82! E 1872 E .-~932 E 4ta0 E 700 ~8i3 CURVE 2.75/100 2874 CURVE 2.50/t00 4347 END 2.50/t00 CURVE 4819 CURVE 3.00/100 ·5753 END 3.00/100 CURVE 6232 CURVE 2.00/100 9000 END 2.00/100 CURVE- 9239 9-5/8' CASING POINT 9520 CURVE ~,5/t00 END 1.5/100 CURVE '20442 Marker Identification A) 'KB 8) KOP/CURVE J.00/J.00 C) ENO-1.00/100 .CURVE O) E) F) I). J) K) L) N) N) DRILl ,ING t' i i MPF-17 (PO9) . PLAN VIEW · i CLOSUREi,..,:'18381 feet at Azimuth 14.1'1 DECLINATION --+27.846 SCALE. ' ~ inch = 2800 feet DgA~N · ~0 Nov ~§§7 4200 2800 1400 0 1400 2800 4200 5600 7000 8400 ; 800 <- WEST · EAST -> - 9800 8400 7000 . 5600 (~nadrlll (¢)9'/ I, IPF3?P09 3.g:~.;~ 5:;~4 FN P) . ~ . .. . I et (R~dius 20( .feet . ' . . ,, ' - "- f. ^~,,,DmLL ~ . AKA- )p~- / . . ,~,PpRt)V. Eii: ~ :.. ' FORPER}41ITTJ.NG -- ",-- - ' ' ' 'iONL¥ .... .. · _-.~_:- , · . - , ..~ -o,. . ~' .. . . · , .... . · . I' . ~ - , -.. . -. . . . . - . : ,. : . - . - . . . , . .. . . . . . -- . .. . . I . . _ · . · .... - ,~d~ill · ,-,_ TD-/ 7" CASING PT 21524. ' 17823 ......... j,__ BP EXPLORATION November 12, 1997 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Before Spud Changes to Approved Application for Permit to Drill ¢:j7-196 Dear Mr. Johnston, In order to increase the length potentially productive pay interval in the Kuparuk A Sands, minimize future close approaches and minimize the risks associated with hydraulic fracturing and proppent placement it i8 requested that the well trajectory be modified from the one submitted and approved in the Permit to Drill #97-196 on October 16, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.016 Changes to the Brilling Permit, (a) For a proposed change in a drilling permit ..... before the start of actual drilling operations. It is requested that the directional profile be changed from an S-Shaped profile to a Slanted-Build and Hold High Angle profile. The directional plan will still begin at the same proposed surface location and intersect the same proposed target location, however the bottom hole location will change because of the requested change to the hole geometry. As a result of this proposed change in the well bore trajectory the following changes are requested: 1. The directional well plan be changed. (ATTACHED) 2. The location At Total Depth be changed to 3790' NSL, 3450 WEL, Sec. 20, T14N, R10E, UM. 3. The surface casfng Setting Depth Bottom be changed to 9520' Md(4556' Tvd). 4. The surface casing Quantity of Cement be increased to 1815 sxs PF 'E°. 1087 sxs Class 'G'. 6. The production casing Setting Depth Bottom be changed to 21,524' Md(7673' Tvd). 6. The production casing Quantity of Cement be increased to 271 sxs Class Thank-you for your consideration in thls matter and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill ¢¢97-196 please contact me in Anchorage at 564-5042. Respectfully, Lance Spencer Drilling Operations Engineer BPX-Shared Services Drilling :!0'7 I:. 199 0il & 6as Cons, Anchorag~ 0 Z Suzfac. e ...... : %90B Pgr. 3'731 Feb ~;0(; 'EL1N RLOIB Uti B~r, .......... : .3?)0 ~SL 3450 ~ S2O TiL'~N* B:IOn: UM I,~O~RT[~ -,lkI. d~F.,Ik ZoNe: 4 SQ1833.EI 6035260,]q ~]6Olq.00 60~2167.00 ~U~ elevati~,~ 46.30 ~t Scale Factor.: O.999~0L99 ANADR1LL AKJ~DPC APPROVHD FOP, PERMITTING ONLY - O~ ~~ X y F~ 1o0 O.OO 0.00 ~ 0,00 8 54~B33.~1 60353E0,~8 15~ O.O0 O.O0 O.00 ~ G.O0 ~ 5~1933.~1 6035960.3~ ~SR ?.B5 7.ST ~ 2-09 B 5(1835.6S G0352~7.96 1S~ l.O0 11041'.00 4.00 tS.4O 1099-68 1053,98 13.95 E/O0.e0 ~_00 lS.40 1199-39 LZ53.67 21.~0 L900.O0 6.00 L~.(O 12~B.~O L2~3.20 31.18 La00-00 ?,00 IS,iQ 1398,26 L35~.$6 A1.70 lSO0_O0 8,00 LS. aO L497.40 14~1.7Q 55,75 1600.00 9.00 ~5.40 %59&.30 1SS0.SO ?0-S~ 53 (amacTrkll~..{.~,l,~,9 M~rI?P09 3.2b.2 5:tl ]~ eJ 13.46 ~ 3.71 ~ 56LB~?.2A. 6035293.G6 ~SR 1,O0 21,02 U ~.7S S 5~1839,g6 60352al.43 ll~ 1.O0 30.26 ~ 8.33 8 54]$~1.77 6035~90,6q I~ 1.00 41.19 N ~,34 B 5(1a44.72 603530L.6L H8 i.0O 83.92 N 23.2~ B 641~56.15 60353~4,43 I~ ~.00 10 W or 1997 Ha~e 2 '. C~ ~.T5/2~0 16T3.8~ LL-13 ' 1~.40 ]OGS.~O 1920.0~ 119,4B 11~.~ ~ 33.73 a ~418G~.69 603S3~5.76 HS 2000.~0 ltiG0 2260,00 2O.LO 2400.00 2S,EO 2SOO.OO 3600.00 3L.10 2700.00 2900.0D 36,60 290B.00 99.35 3000.06 ~2-10 3LO0.~O 4~.85 320~.fi0 :LlOO.fiO 50~35 3GOE~ .00 3"/00.00 6L.35 3600,00 64 3~00 66.85 ,~.o~ ~.~o 4[00.00 ~2,35 q200.O0 75, ..~7~.~ ~..~:.,~. 15.40 2064.82 ~03~12 LVS.Og ~68.B1 H 46.q9 ~ 54LG79.1S 603~&2~.43 HR 2.TS IS.40 22~2.57 2226.87 243~4 235,04 H E4.?~ g 5~LBg?.oL 6035a.,95.?$ R8 2-TS ~S.4O ~J6],?~ 2.,,319.0~ ~84.~5 274.5~ N 75.63 B 5419OT.E8 ~035535.35 .Hg 3,75 15.40 2452,87 2407.17 3~0. D9 328.31 ~ 67.67 B 54J919.48 60~SS~.I~ HS 2.75 1.S,40 2~39,?L ~494.01 3~9.6g 366-[~ ~ 30Q.83 S ~41932.37 $035627.0t HS 2.75 [~.%O 266~.35 2814,65 6~.~1 ~gS,6& H 164.06 ~ 54L99~.29 6035956,~0 ~S ~S.4O 300~.10 ~9S6.40 7~8.67 731.~9 ~ 201.%9 H ~42Q30.96 60~%993,~2 X~ 15,40 3187.?e )142.00 993.92 93B.44 N 263,97 E 542092,16 6036220.20 P~ 1S,¢D 32(2.92 3196.22 1077.97 1019.49 ~ 26~.~9 ~ SA2L]4,02 6G~6~0[.$7 MS ~-7S LS_%0 34~6.39 3370,69' 1~3~.15 L305.56 ~ 36L.$9 B 542207.]5 60366(8.23 H8 2.~5 L5.~0 3446.99 3403.29 ~53].66' [476.99 ~ 406.~ B ~42~32.0~ 6036~39.49 H5 2.75 L5.40 )4~7.02 3&31.32 ~627.62 L569.53 ~ 412.~0 ~ 542257.00 lo ~'ov L~97 Pac,~ 3 · C'NJRV'~ 2, S0/300 mo~.::-me:m ~fmmmmm:;=ummmmmm ~::~t~mm mmn~:mmmml2fmmmQ~:~ mmuw~=m N mum m mm~..~G ~ ~ D~RH~L-'TIO~ VBRTZCU~-D~P'['~S 9g-,C'~lO~ ~O~S-P~ A~ 7~ne 4 ~0~ ~l~ ~O gU~-~ DBP~T ~LLX~ - X Y F~ . L5.40 ~O~-~ 34S4,71 472~,8~ L~G3.2S ~ 4~0,09 ~ 5q~2~2.28 ~03~92G.02 ~ IS.lO 3~09.76 34~A.06 ~770.~3 L707,52 H ~70.2G E 54229~.2~ 6~3697G,)6 9~R 2.75 ~6.75 )519.~3 ~47~.~ )822,8q 1~.~6 ~ 484.~3 ~ 5'(2306.38 6037~20.G~ 95R 2.50 is3m 2.5o/1o0 CORV'~ O.,~VI! 3.00/100 ,1.~'00 ,oo 480G.00 '/(] -38 i 818 . 98 79 ~36 $7.5'3 .~19 78.36 .SFI 00. mO 'TB. 3*J 2~,&1 37~0.~5 37~5.05 3119.99 2~.9.7 36~0,2l 3.754.S~ 3364~B5 20~2.95 ~ 567.97 ~ S424J~:07 603.729g.&] ~121,26 ~ 630.3~ E 5~2~51~)q G0373~4.95 212.7.00 ~ G~B.B6 ~ $~24E0~~ 603q40~.53 2950.00 ~ 1050.00 ~ 552876.88 60~G216.0~ 2991.05 ~ tOSO,E3 g 552697.2E 6038357,1~ 6000.00 (.D ELO0.O0 7B,~2 I---I 6200 ,gO ~G, 77 · __1 ~IrD 3.00/100 CUR~B 62~1 90 76.a2 I-4 22"9L ~620.3] 3775.b-"3 326L.24 · 9.85 36(0.33 3794.g3 3358,44 L6.39 3eGG.L7 3e14,47 3456.L9 L3.73 3e7~.77 ~034.0~ 35;¢.2~ CD ~A 7030.1.5 78,.92 '12.`7T b.I (.2 OA q)SB.76 "/8.82 ~2 ,'77 4220..7t'0 ~. OB eSOO.44 '78.82 22 . 77 4325 .'70 I,I BAS'R OH 96.55.21 711.82 12,77 CURVE- 2 ,(]O/.LO0 9000.00 '78 ,B2 1.2..7'3 ~22.S3 O~ ~,1,00 . nto 7E .G2 L2."/'7 CD 9200.00 '/e, , K2 ~ B1~ID 2.GO/LO0 OJ'RVPl 92.38.79 7,~.05 CL[ ~.~-9-S/B· C.~]NG ~0'1~1~ 9519.59 74.05 ~ · ~- ~ >>RJ~B HR~P~-'~ 1~270.6'7 74.05 32 77 · ~ ~ co ":]L"L,q~-' ~ Xg'tt]O.06 7~ .0~ 12.'7'7 ~ , 30B0.21 ~ ~2l,L$.~ 542937.30 3471.4~ ~ 1156.e7 E S42972.49 ~038437,99 32~4.4R M ~87.6~ ~ 5~300Z.~6 &~lO.O0 SgG2.LO 5460.03 ~ 3712.42 E S435)4,$2 6040~29.42 RS STOe.~L ~ 1745.97 C 5~5tq.24 60t0977.67 N9 603~-00 ~ 1820.3~ ~ 54~62Q.LL ~O&~o?.g& ~a. 4$E6.X2 4422.~2 45~$,70 4530.~0 ~225.70 ?lBO.GO 6397.95 5133-33 H 1642.31 [] 5436aL.17 604L403,38 6494.G~ ~22T.G6 ~ 1~63.73 8 543662.06 6G~Lq98.OS 68Q2,13 652'7,6~ H ~1,6S g 5(3726.28 6041796.16 [613S,~0 25637.33 N 3995,6L ~ ~4S740,~ 60S091E.43 72~5,9~ 7190,00 16174.67 15671.45 ~ 4003.34 E 5457(8.24 6050952,59 I~ O.00 7375.?0 ~30.00 16G~4.29 16149.L~ ~ iLLL.56 B 555853,qG 605~4~0.8~ ~5 O,0O 14PF-Yt (PO'~ 10 ~qov 't997 Page PROL:O~E;D 1~1.I. I?ROla I t,g 20100.00 12.77 7468.~e 7443.00 %?~11.22 1~585,13 B 4210,35 g 54S950.§9 605LSgT.34 tLS 12,97 ?~99.45 7453.7~ 1~16~-82 16651.33 ~ 4223.09 ~ 545962,~0 605~23.60 HS 1.50 W r~ W > 0 7- ?D [ 7* O___~S:I~G p'f* '21524'.39 a2.00 12.77 953S.T0 7490.00 17407.?8 L~8~4.45 ~ &RTg.9O B 5460~4.00 60S~1S7.D0 KS 0.00 L2-77 ~5SD.~O 7505,0a t?SLL.Lq LGg?B.SS'~ 4299.4S B 546031.00 6052~&L,~ HS O.OO · . AKA-DPC ANAORtt APPROVED FOR PERMITTING ONLY- PLAN ~._~____- . .____-~ , , ._.___~..~,, _..,~...~.~_...? ~. ·. HAREB- SERVICES DRIL'[ING -- il i --,, . A) KB 0 0 o O,UO 8 ~ 2.50/100 434? 351~ · 1771 ~.i4 Fl ~2.50/100~VE 4Btg 360? 2~Z9 78.~ ~ EB 3,601100 C~VE 6232 ~88G 9585 78.~ ~.E~ 2 00/I00 ~VE ~39 4~79 653~ 74.05 _ , _ ~ 9-5/B" C~SIN0 ~tNT ~ aS~ ~ 7a.~ ,) E~ 2.51i~ C~ ~, ~152~ ,7~0g,7,08 ,2.00,~.00 767~ t~8~ 82,00 N) TARGET '~XXXXNI~XXX~.~, Z054~ AKA-DPC FOR PERMITTING. ONLY ' PLAN # c~ Iml mm ~lnadr J] ] Schlumberger i iiiii ii I _ Pr-17 [PO9) VERT I CAL. SEC f-I ON V l Eld TVO Scale ' 1 inch = 2400 feet · Oep Scale.' I ~nth = 2400 feet Brawn ..... ' tO Hov lgB7 m . , ' E -- -- ~N 0 ........... ~ ............. I_% ..' ................................... g ....... : ...... L ..... .'.~.'1 ....... L ............... I ~ -t~ 24~ 350~ 469~ 6fX~ 7L;q~ B4OO '9699 l~lllg~ ~ZOUU I¢¢U ~q~ zubgv )66~ ~6~ ~2bO 2w.u Section Oepar tore m _ m m . . I~r)li ~1 ~ ~Fi?~ ~.2~,e2 ~ 13 FH e) · _ mi il il i . .:,... MPF- 17 " . ,:,~,-,' VERIICAL SECTION VIEVl _ ' -" R'i~"D _ [_ SHA SERvICEs ~V W · W w 7680 ITVO Scale,: I inch: 200 feet ~,ROV~ IDeP Scale,: ,'l. tach 200 feet 'FOP,'~[RI~I~G,~ .b~¥c.~:,. . ¢~ . IDra~n ..... : ]0 NOv 1997 ,: , ...... PLAN .. ~ _ .... r........ ~:~ ........... B ..... :~ ~.._. ...... ~ ~ ............. . ~T-~ , - ~ ....................................................... ,. - ......... ' ............................. [ ....... , . . ~ - t . '" $~cti~n C~ur~ A~ KB 0 ON KOP/CURVE t,00/loo 700 0 N C) ~-~,o0/100 ~Rv~ t8t3 tO~ N DI CURVE 2.75/[0e ~874 3~5 N El CURVE 2.50/~00 4347 t70~ N F) END ~.SO/tO0 CURVE 48~9 2338 N 6} CURVE 3.ao/~oO 5753 2~0 ~ ioEo E H] ~D 3.00/~0~ CURVE 6~32 3~9 N ~22~ E ~) CURVE'2,00/$00 aO00 603~ N J82~ E, J) E~ m. O0/~O0 CURVE ~23g 6264 N S873 E K] g-5/8' CAS~N6 POINT 95~0 6528 N ~932 E L) CURVE ~,~/jO0 Jgg]2 36272 N 41~0 E N) END t,5/$oo cuRvE 80442 ~677B N 4~54 E o} ~ / 7' CA~NG PT 2i524 t7~3 N 449~ E 470 E 639 E MPF- (PO9) , PLAN VIEW · ~lI,=II i ii CLOSURE ' 1838~ ~eet at Azimuth ~4.1'] DECLINATION ' +27,845 (E) SCALE ...... ' ! ~nch ~ 2800 feet ORANN ' lO NOV J997 I Ill "~ IBIll -Anadr i.]_ /,. Sch lumoengen , 1 et [R ~dius 201 feet ) FOR PER-- JT3 ONLY I ala~ ka Oil & Gas Cot s. Comr~ ~nchora m ._ -- 7000 5600 4200 2800 t~oo 0 fa00 2800 ~800 (= WEST · EIST ~> a,m.~~i DHIq3I~G S3DIA~2S G3~UHS NdEE:EO Z6, TI AOH J ~GPf-./. F'- I I BP EXPLORATION · BP Explorati6n (Alaska) Ino. P.O. Box 196612 Anchorage, Alaska 99519-6612 TELECOPY TO.' Name: Company: Location: FROM: Name & Ext.: Department: SATELLITE UNIT Fax # R[¢EIVED PAGES TO FOLLOW cover~'$'~(~i!o,,-o,i- '& Gas Cons. Co,~r~' (Do not include ~ch_o_rag~. SECURITY CLASSIFICATION II I PRIVATE _ · III i SECRET SATELLITE FAX MACHINE FAX# 564-5193 CONFIRM# CONFIDENTIAL ss4-s!8_9_ ......... ',~".t:_.,_ I1~ ,,[t i i ~/T.'A ~HIq-]I~I S33IA~35 ~3~HS N~0~:£0 2.6, ~Y AOH ' TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16. 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPF- 17 BP Exploration (Alaska), Inc. Permit No 97-196 Sur. Loc.' 1808'NSL, 2731'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc: 3074'NSL, 3615'WEL, Sec. 20, T14N, R10E, UM Dear Mr. Alvord: 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 la~v from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling belo~v the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Joh.,.nston Chairman BY ORDER OF THE COMMISSION dlf/enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. -" STATE OF ALASKA ALASKA L~,-AND GAS CONSERVATION COM,,,,SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill I--IRedrill Ilb. Typeofwell I--IExploratory I--IStratigraphicTest [~ Development Oil [] Re-Entr7 [] Deepenl [] 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 KBE = 45.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355016 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1808' NSL, 2731' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2841' NSL, 3669' WEL, SEC. 20, T14N, R10E, UM MPF-17 Attotal depth 9. Approximate spud date Amount $200,000.00 3074' NSL, 3615' WEL, SEC. 20, T14N, R10E, UM 10/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355017, 3074'I No Close Approach 5071 21187' MD / 7876' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 700' Maximum Hole Angle 78.8° Maximum surface 3046 psig, At total depth (TVD) 7630' / 3809 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' _~50 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 8814' 31' 31' 8845' 4394' 1813 sx PF 'E', 851 sx Class 'G' 8-1/2" 7" 29# L-80 Btrc-Mod 21157' 30' 30' 21187' 7876' 192 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured)0R:I61NAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor ISn~erframCeediate ~ ~.~ !..V ~ b Production Liner0(~T 15 1997 Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,,~ ChipAlvord ~J~4.~, '~. ~'-"-'/.,..,-~; Title Senior Drilling Engineer Date f¢(I ~'/)y / Commission Use Only ~;;~t,~lum ~/(~ I APINumb,~r I App,ovalDate I See cover letter Per - L - ;z2 8 for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log RequirSd [ []Yes [~No Hydrogen Sulfide Measures ~[Yes []No Directional Survey Required [~'Yes []No Required Working Pressure for BOPE I-I2M; 1-13M; ~[5M; I-I 10M; I'"115M Other: Original Signeo ' by order of Approved By David W, Johnston Commissioner the commission Date / Form 10-401 Rev. 12-01-85 Submit ~riplicate Shared Services Drilling Contact: I Well Name: I Type of Well (producer or injector): Lance Spencer I MPF-17 Well Plan Summary 564-5042 I Kuparuk Producer Surface Location: 1808' NSL, 2731' WEL, Sec. 06, T13N ,R10E, UM., AK Tar~let TKUA3 2841' NSL, 3669' WEL, Sec. 20, T14N, R10E, UM., AK Bottom Hole Location: 3074' NSL, 3615' WEL, Sec. 20, T14N, R10E, UM., AK I AFE Number: 1337109 I Estimated Start Date: 121 Oct 97 I I Operatin~l days to complete: IUD= 12 ,187' I I TVD= 17,87 'Bkb I I KBE= I Well Design: Ultra Slim Hole Long String HAW IRis: I Nabors27-E I 9-5/8", 40# Surface X 7", 26# Longstring 122 I 45.7' Formation Markers: Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1853 1845 8.4 ppg 806 psi NA Top Schrader Bluff 7023 4040 8.4 ppg 1765 psi OA Base Schrader Bluff 8645 4355 8.4 ppg 1902psi Top HRZ 2042 7232 8.8 ppg 3310 psi Base HRZ 20414 7242 8.8 ppg 3314 psi TKLB(MK-19) 20450 7272 9.2 ppg 3479psi TKUD 20585 7382 9.2 ppg 3532 psi TKUC 20719 7492 9.6 ppg 3740 psi TKUB 20723 7495 9.6 ppg 3742 psi TKUA3/Target 20771 7535 9.6 ppg 3762 psi TKUA1 20820 7575 9.6 ppg 3781 psi Miluveach 20887 7630 9.6 ppg 3809 psi Total Depth 21187_+ 7876_+ 9.6 ppg 3932 psi · *These are estimated maximum pressures and the actual pressures may be lower. Casing/Tubing Pro~ ram: Hole Size Csg/ ' Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/I'VD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 8814 31/31 8845/4394 8-1/2" 7" 29# L-80 Mod. 21157 30/30 21187/7876 btm The internal field pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _. 7,630 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ,-7,630 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,809 psi is 3,046 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-17 (ERD A) Drilling Permit 1 ,, :~ :;,..,, t, %' '~/ ,.,, '.' ,. ;'" ;"¢¢'"~'.':': ~iii/, 10/13/97 Cementing Program: Halliburton Cementing Services Hole v Ca'~ing Interval Volume'~ Spacer Type of Cement Propertiesz Category Size/Depth Surface Lead" Lead Lead Lead First Stage 9-5/8" @ 2053-6523' 839 sx 70 bbls Permafrost "E" Den 12.0 ppg 8,845' 324 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 6523-8845' Tail5 Tai~l Tail 851 sx Premium Class "G" w/ Den 15.8 ppg 174 bbls 0.2 % CaCI, 0.15 #/sk Celoflakes Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs .............................................................................................. Second Sta~je [.'~1'~ ............ i'~'~a .................... i"~'~J~l ..................................... i'~'~ ........................................................ stage collar° @ 0-1853 974 sx 75 bbls Permafrost "E" Same as above 2,053' 1853-2053 376 bbls Fresh water Production 7" @ 19,585- Lead" Le.ad Lead Den 15.0 ppg First Stage 21,187' 21,187 192 sx 50 bbls. Foamed Premium Yield 1.46 ft 3/sx 50 bbls Alpha Class "G" w/ Water 3.95 gps Spacer 15%Silicate, TT 3.5-4.5 hrs @ 140° F 50 bbls 0.45% Halad 344 FL 30-40cc/30 min Foamed 0.1% CFR-3 @140° F Alpha 2 gps Latex 2000 Spacer 0.5ps C434B 0.1 gps D-Air-# 0.1% HR-5 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,053'MD+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,053-6,523' md. The estimated first stage lead cement volume from 2,053-6,523' md and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,053' md which is 200 ft md below Base of the Permafrost at 1,853' md (1,845 TVD bkb) to 6,523' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 6,523-8,845' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 6,523-8,845' (500' md above the NA top) to surface TD at 8,845' md (4,394' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0~2,053' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,053' MD (2,052' TVDbkb) to surface. From 1,853' to surface include 250% open hole excess and from 1,853-2,053' use 30% open hole excess. 7. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from 7,023-8,645 of 9-5/8" casing to cover the top of the NA to Base OB. 10. The production hole will be cemented in a singte stage. The Cement Volume covers the interval from 19,585~21,187' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 19,585' which is 1000'+_ above the Kuparuk D Shale to TD at 18,783' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint from 120' below to 120' above any potential hydrocarbon bearing sands. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk C sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no~t necessary. Logging/Formation Evaluation Program- Anadrill Schlumberger I Open Hole Logs: I None MP F-17 (ERD A) Drilling Permit 2 10/13/97 Surface-12-1/4" Intermediate Final Production 8-1/2" Cased Hole Logs: Mud Logging 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. N/A 1. M10 Power Plus MWD Directional 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ N/A Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during] all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Seawater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTH P Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-10.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 <4 Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP F-17 (ERD A) Drilling Permit 3 10/13/97 Directional: KOP1 Tangent Hole Angle Drop Section Tanget Section Maximum Hole Angle Close Approach Wells Survey Program 700' Start Variable @ 1.0°- 3.0 °/100 and Az 12.78°. EOB @ 6220' md. 78.8° from 6,220-18,650' Start Drop 18,650 @ 2.5°/100 to 36° incl. and 12.78 Az o EOB 20,402' md 35° incl. and 12.78 Az o from 20,402-21,187' md 78.8° from 6,220-18,650' All wells may remain flowing while drilling F-79 and no shut-ins are required. 1. Surface to 8,845' MWD surveys. 2. 8,845-10,845' GYRO to surface 3. 10,845'-TD MWD with in hole reference. 4. R'DMO~:w~h:'.Nabo rS:: 27E. Disposal: No "Drilling Wastes" will be injected or disposed into F-17 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handlin_~: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPF-17 is planned as a high angle, 79°; high departure, 17,646'; ERD, 21,187'; Kuparuk River A Sand producer. The S-shaped well profile with a final angle of 35°, will intersect the target objectives and provide optimum inclination for fracture stimulation. The surface casing will be deep set below the Schrader Bluff at 8,845'md (4,394' bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval which should not be abnormally pressured by area injection. Geolo_clv The primary targets are the Kupauuk A3, A2 and A1 sands but has some potential in the Kuparuk B and C sands.. The deepest known oil in the area is at F-74i to a depth of 7,472 tvd ss. No water contact is expected at the F-17 location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 100-~_ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this producer are estimated at 4.1 MMBO assuming a 120 acre drainage area. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted and not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP F-79, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. MP F-17 (ERD A) Drilling Permit 4 10/13/97 .Water~ Gas and WAG Injection Formation pressures are expected to be partially depleted at a maximum of 9.6 ppg EMW pore pressure in the Kuparuk while drilling F-17. The Kuparuk may be partially pressure due to nearby production from F78, F-53 and possibly F-66a and F-38. Injection support for the fault block in which the F-17 well path intersects in the target interval is provided by F-70i and the fault block to the east contains injector F-74i. Abnormally Iow pressures caused by production and high pressure due to area injection are not expected while drilling F-17. The injectors F- 701 and F741 areexpected to be in communication with the proposed F-17 BHL but the injection is not expected to have abnormally pressured the reservoir due to offtake for producers F-78, F-53, F-66a and F-38. Annular Injection Currently annular injection is not permitted on F-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. With the possibility that the HRZ will be truncated or absent the potential for stuck pipe the transition interval from Colville(SeeBee) to Kulubik is recognized. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurrence has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK A1 SAND 7630' TVDss 3809 PSI 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _ 7,630 TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,630' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,809 psi is 3,046 psi. The maximum expected pore pressure for this well is 9.6 ppg EMW (3,809 psi @ 3,046' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. MP F-17 (ERD A) Drilling Permit 5 10/13/97 MP F-17 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,053' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk C sand and PBTD before running the 7" casing. 11. Run 7" casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP F-17 (ERD A) Drilling Permit 6 10/13/97 ~nadrtlX SchLumberger A1 a-~ka DLs~ric~ Anchorage, AK ~9518 (907) 349-4511 FB~( 344~2L60 D~RP~i'TIONiM~N~L~ PLAN ~or SPAN/ID SERVICHS DR£bL~NG ANADR1L,". AKA-DPC APPROVED FOP., PERMITTING ONLY LAN .......... WeLL ......... ~ MPF-17 I4PF-g78JLD-A (P05) ~£eld ........ : M£Lne Po£nt Co~utat£on...: Minimum C~rva~ure U~s ........ = FSET S~rface Lat..: 70.5072495~ N ~r~ace ~ng.: 149.657~3~08 W I~SaL Descrip~Lou Surface ...... : ~808 FSL 2731 ~L 806 T13~ R10~ UM Tax-jet ....... : 2841 PSL 3669 PBL 820 TL4~ RiOH BHL .......... : 3074 PSL 3615 PHL S20 T£4N LOCATIONS - ALASK~ Zone: 4 X-Coord Y-Coord 543833.9L 6035260.49 546014.00 6052~57,00 546065.44 '6052389.96 Prepared ..... : 12 Aug 1997 Vert 8ec~ .az.: ~.22 KB e~evahion., 4~.00 ~t Magnetic Dcln: +27.9~ ScaLe PacCor.: 0.99990199 Convergence..: ~0.52264894 STAT£ON CAT I ON 00/~00 DRPTH ANDI.w. 0.00 0.00 900,00 0.00 800.00 1.00 900.00 2.00 1000.00 3.00 1~00.00 4.00 £200.00 [$00.00 6.00 ~400.00 7'.00 1500.00 8.00 1600.00 9.00 1700.00 10.00 DIRECTIO~ VIIRTI CAh- DRDTHS A~IMUT8 TVD SUB- SHA 0.00 0.00 -45.00 L5,40 700,00 655,00 £5.4~ 799,99 754.99 15,40 899.96 85~.96 35.40 999.86 954.86 · lS.40 1099.68 1064.68 15.40 1199.37 1154.39 L5.40 12S8.90 1253.90 L~.40 1398.26 ~5.~0 149~.~0 14~2.40 SRCTION DEPART 0.00 0,00 0.89 3.49 7,8~ 13,95 2L.80 3L,38 4:> .'70 55 15.40 L596.30 L551.30 15.40 L694.93 1649.93 70.53 87.03 CK)OP~INAT~S-PROM PJ~ASKA Zone 4 ~OOL Db/ ~LH]~AD X Y FAC~ 100 0.00 ~ 0.00 ~ $*~B~.~L 6035260.4~ ~ o.oa 0.00 ~ 0.00 ~ 54~B33.~L 6035~60.4~ 15~ '0.00 0.84 B 0.~ B 5~£B~.~ G0~5~61.~3 ~SR £.00 ?.57 ~ 2.OB B ~B~5.B5 6055~68.07 ~S~ ~.00 L3.40 N 3.?L E 541837.54 6035273.97 1SR 1.00 2L.02 N 5.79 E 54L839,58 603528i.54 HS 1.00 30.26 N B.33 E ~4L8~2.07 6035290.79 HS L.00 4~.IT N [i.34 H 54L845.02 6035~0~.72 }tS L.00 53.76 N L4.81 E 5~848.41 6035314,33 HS 1.OD 68.01 N 83.92 N 18.73 H 541852.2S 6036328.60 H$ l. O0 23.LL g 54L856.55 6035344.53 HS L.O0 Z (AnadrllL (c)97 MPFI'IP05 3.0C 2:07 PM P) I~a MPP-L7 NPF-97ERD-A (POS) STATION D ~ L'~ ~ F1 CAT ~ON CURVE CURVE~,TS/i00 DEPTH ANGLE 1800.00 21.00 LSL%.g7 11.12 £052.?3 1£.£2 1900.00 L/.e6 20QO.O0 14,61 2100,00 17.36 2200,00 20.11 2300.00 22.86 2400.00 25.6[ 2SO0.00 28.36 2600.00 3L.31 2700.00 33-86 2800.00 36.61 2900.00 39-36 3000.00 42.11 3100.00 44.86 3200.00 47.6L 3300.00 50.36 3400.00 53.L1 3500.00 55.86 3600.00 58.61 3700.00 6L.36 3800.00 64.11 3900.00 66.86 4000.00 69.61 4100.00 72.36 4200,00 75.1L ':(AnaH~il.l {~.)'~7 MPr3?g05 3.0C 2:07 PROL=OSED WELL PROPILB D[RKC"~ION VERT~CAL-DEPT'HS A~]MUTH TVD SUB -SEA L5.40 1793.26 1748.26 L5.40 1805,00 1760.00 L5.40 1845.00 1800.00 ]5.40 1865.00 1820.00 3~ .40 £89L.35 L846.35 12 Aug 1997 Page 2 SF~Z~£ON COORD/~AT~S-FROM DEPART W~LJ~H~AD 105.25 10/.49 N 27.95 ~07.54 L03.70 N 28.56 LL5.40 Lil.28 N 1~9.33 135.07 ~ 124.69 120.24 ~ AI~ Zone 4 X Y PACE 100 541861.29 6035362.13 HS. 541861.88 6035364.34 HS 1.00 ~0.65 E $4L863,93 60~5371.93 ~S O.O0 ~1.69 ~ 54~864,~ 60353~5.7~ HS 0.0~ 33.11 H 541866.34 6035380.90 ~S 2.75 1S.40 L988.68 1943.68 147.57 142.30 N 39.19 15.40 2084.8L 2039.81 175.10 168.85 N 46.50 L5.40 2379,50 2134.~0 207.21 L99.8l ~ 55.03 15.40 2272,54 2227.54 243.~2 235.12 N 64.75 [5.40 2363.72 23£8.72 204.85 274.69 N 75.65 15.40 24~2.63 2407.83 330.21 318.43 ~S.40 ,2539.65 2494.65 379,80 366.24 15,40 2624.00 2579.00 433.49 418.02 15,40 2905.67 2660.67 491.L6 47~.63 15.40 2784.48 2739.48 552.69 532.96 15.40 2860.25 2815.25 6L7.92 595,8? 15.40 2932.80 2883.80 686.71 662.21 15.40 3001.96 2956.96 758.91 73L.82 L5.40 3067.58 3022.58 834.34 804.56 15.40 3L29.51 3084.S£ 912.83 880.25 15.40 3L87.60 3A42.60 15.~0 3241.71 3196.73 15.40 3291.73 3246.93 15.40 3337,54 3292.54 15,40 3~79,03 3334.03 994,20 1078.26 1164.82 1253-69 L344.64 958.72 1039.78 1123,25 L208,94 L296,65 S41872.30 6035403.00 HS 2.75 541879.46 6035429,58 }LS 2,75 541887.8l 6035460.59 HS 2.75 54~897.33 6035495.95 HS 2.75 54~908.00 6035535.5~ ~S 2.75 87.70 ~ 541919.80 6035579,38 }iS 2.75 100.86 ~ 541932.70 6035627.26 HS 2175 llS.f2 H 541946.6~ 6035679.1L ~S 2,75 130.44 E 54L96~,6~ 6035734.80 HS 2,75 L46.70 E 54~977.67 6035794.~2 HS 2.75 L64.10 B 541994.64 6035857.21 HS 2.75 382,37 H 542012.53 6035923.65 HS 2_75 201.55 H 54203L.31 6035993.37 HS 2.75 221.58 ~ 542050.93 6036066.21 HS 2,75 242-42 H 542071,35 6036142.0[ HS 2,75 15.40 3416,L1 3371.11 L437-48 ~386,L8 15.40 3448.69 3403.69 L5~2.00 1497.32 15.40 3476.69 34~1.69 ~627.97 1569.86 264.03 E S42092,5L 6036220.58 HS 2.95 286.36 E S42114.38 6036301.76 HS 2.75 309-35 B 542136.90 6036385.36 HS 2.75 332.94 ~ 542160.01 603647].17 ~ 2.7~ 357.10 B 542183.67 6036559.01 ]~S 2.75 381.76 H 542207.82 6036648.66 HS 2.75 406.86 H 542232,40 6036739.93 HS 2.75 432.34 R 542257,36 6036832.6~ HS 2.75 Z "O G') rtl MPP-17 M. PF-gTRRD-A (P05) PRO~OSEDWEhL PROPlkE m~mmmmmmmmm{m{¢;~=~ {mmmm {m{ mmmmmm STATION IDSNTIFICATiON CURV$ 2.50/100 {;=~r~mm{ mmmmmmmmm{mmmm~ ~RASURBD INCI.~ DIRSCTIO~ VHRTICAL-DSPTHS 'D~PTH ANIt~.~. AZ£/4L~TH TUT) S~-SBA mmmmmmmm mmmm=z =:~=m=mr mmmmmmm{ 4300.00 ~,86 15.40 1500.06 432L.38 ~8.45 ~5.10 3504,45 3459.45 4400;00 ~8,tL [~.40 3520,22 4500.00 98,]9 ~9.9g 3540.33 3495.33 4600-00 ~8.39 22.5L 3560,4g 3515.45 Aug 1997 Page 3 BKD 2,50/100 CURVB CURVB 3.00/100 4900.00 78.41 25.06 3580.56 3535-56 4779.28 78.45 27.08 3596.47 3551.47 5752.40 78.45 27.08 379L.36 3746.36 5800.00 78.45 25.63 3800.89 3755.89 5900.00 78.48 22.56 3820.89 3775.89 ~ECTZ0~ COORD[NATSS-F'RiX~ DHPAI~T WELbHHAD 1725.17 1663.60 N 458,t6 L746.08 1683.77 ~ 463,7£ £82~,05 ~757.65 N 485.46 1920,,70 L850.44 N 516.83 2017.9L 1941,74 N 552.30 aDrD 3.00/].00 CuRva NA 6000,00 98.55 19,50 3840.81 3795.81 6100.00 78.64 16.44 3B60.58 38L5.58 6200,00 78,77 13.39 3880,17 3835.19 6'220.04 78.80 12.78 3884.07 3839.07 7022.82 78.80 12.78 4040,00 399f,00 2114,50 2031.37 N 59~.80 2190.51 210l.~3 N 625.93 3119.99 2950.00 N 1060.00 3165.58 2991,78 N 1080.70 3269.09 308[.22 N 1120.70 OA BASH OS CURVH 2.50/£00 7949.$L 78,80 12.98 4220.00 4£95.00 86~4.53 98.80 12.78 4355.00 4310.00 18649.51 78.80 12.78 6298.36 6253.36 18700.00 77.54 £2.78 6308.71 6263.71 18800.00 75.04 12.78 6332.41 6287.41 18900.00 92.54 32.78 6360.33 19000.00 ~0.04 32.78 6392.41 19100.00 67.54 12,78 6428.59 19200.00 65.04 12,~8 6465.80 19300.00 62.54 32,98 6512.97 ~9400.00 60.04 12.w8 6561.01 19soo.00 59.54 ~2.78 66~2.82 19600.00 55.04 12.78 6668.32 ]359.38 3457,19 3555,23 3574.89 4362.12 5270.88 5952.44 15763.76 15813.16 159t0.27 6315.33 16006.26 6349.41 16L00.93 6383.59 16194.12 6423.80 16285.6~ 6467.97 ~6375.32 (Anadr/.L1. (c)97 K4Pl~17PO5 3.ac 2:07 PM P] 6516.O1 16462.99 6567.82 16548.48 6623,32 £6631.63 AI.,A~KA ~one ~ TOOb Dh/ X Y FACE 100 542282.65 6036926.~ ~ 2.95 542288.09 6036946.67 9iR 2.75 542309.42 6037020.68 9LR 2.S0 542340.26 60371~3.63 90R 2.S0 542375.21 6037205.12 90R 2.50 31.72.67 N 3265.90 N 3360.65 N 3379.80 N 4'147.79 N 5034.33 N 1590,95 B 5699.23 N 1741.71 H 15270.~0 N 3911-99 E 15318.89 N 3922-91 E 15413,63 N 3944.39 E 542414.2£ 6037294.96 542447.94 6037364.91 542877.18 6038216.12 54~897.64 6038258.02 54293~.13 603834~.67 543396-33 6040303,21 RS 543543-33 6040968,88 HS 545659.46 6050551,48 ~S 545670.11 6050599.73 LS S45691.05 6050694.58 bS HS ' 2 9o~ o 90k 3 89b 3.0[ 1155.86 E 542971.78 6038439.31 88L 3.0( 1/86-1'1 Ii/ 543001.49 6038532.70 88~. 3.0( 1211.35 B 543026.19 6038629.58 87h 3.0( 12:15,79 ~ 543030.54 6030646.75 ~ 3.0( 1389.93 H 543200.33 60394L5.64 l-L9 O.O( 0,0~ o.o~ 0 llmll Z L5507.27 N 3965.63 L5599.63 N 3986.57 L5690.S4 N 4007.18 15779.82 N 4027.43 15867.31 N 4049.26 545711.76 6050788.33 bS 2.50 545732.18 6050880.80 L~ 2.50 545752.28 605097L.81 I.,S 2.50 545772.02 6051061,20 kS 2.50 54579L.36 6051L48.79 LS 2.50 15952.84 N 4066.66 36036.24 N 4085.57 16117.36 N 4103.96 5458L0.27 6051234.41 kS 2.50 545828.71 605L317,91 bS 2.50 545846,64 6051399.t2 LS 2.50 Z m MPF-~7 NPP-97~.RD-A (P09) 12 Aug 1997 Page 4 STATXON MHA$OREO INCL~ I OHNTI FI CATEON O~PTH ANGLH ~9700.00 52,54 £9800.00 90.04 ~9900.00 47.54 20000.00 45.04 20100.00 42.54 20200.00 40.04 20300.00 37.'54 20E00.O0 35.04 2040L.50 39.00 2040£'.50 35.00 >>]~%S~ BRZ<¢ 20423.71 35.00 MK-19 20450.33 35.00 TKUD 20584.62 35.00 TKUC 20738.90 35.00 TKUB 20722,56 35.00 TAR~HT *'~**~******~ 20771,40 35.00 TKA3 20731.40 35.00 TKUA 2078L.L6 35.00 TKA2 20789.7L 35.00 TKAL 20820.25 35,00 T~.V 20887.37 35.00 TD 21L87,37 35.00 (Anadrill '~(C)97 MI~PI~PO'~:? 3.0C 2:07 ~ P) ,,;£~ ' ~, ,*, , ,. D~RHCT~ON VH~TICAL-DHPTHS AZ]MUTH TVD SUB-SBA 6682.40 6744 . 93 6810.81 L2.78 6727.40 12.78 6789.93 12.78 6855.81 12.78 6924,91 1~.78 6997.[0 DHPART ~6712.29 16790.20 16865.48 6879.91 16937.73 6952.10 t7006.91 L2.78 7072.23 7027.23 17072.86 /2,78 7150,17 7105.17 ~7139.48 12.78 7230,77 7185.77 17194.64 A2.70 7232.00 7187.00 17L95.9'0 ~2.~8 ~232.00 ~187.00 17i95.50 12.78 ?242.00 7197.00 ~7202.50 12.78 7272.00 7227.00 17223,50 12.78 7302,00 7337,00 17300.50 L2.78 7492.00 7447.00 ]7377.50 £2.78 7495,00 7450.00 17379.60 L2.78 7535.00 7490.00 17407.60 ~2.78 7~35.00 7490.00 17407.60 ~2.78 7~43.00 7498.00 [7433,20 ~2.78 7550.00 7505.00 ~7410.10 12.78 7575.00 7530.00 17435.60 12.78 7630.00 ~589,00 17474.L0 12.78 7875.75 7830.75 lq646.L2 COORD3~ATHS-FRO~ ALASKA Zone 4 TOOL D~/ WEhhHBAD X Y FACH 100 16396.03 N 4121,80 H 545864.03 60H1477.90 LS 2.50 16272.13 N 4139-05 H 545880.86 6051~54.08 L~ 1.50 16345.49 N 4~55.69 E 545897.08 605L627.~2 LS 2.50 164~5.97 N 4~71,67 H ~45912.66 6051698.09 LS 2.50 ~6483,45 N 4186.97 H ~45927.58 6051765.65 LS 2.50 36547,80 ~ 420L.56 B 545941.80 605L830.07 L5 2.50 16608.89 N 42£5.41 g 545955.31 605L891.23 L9 2.50 16666.60 N 4228.50 E '545968.07 6051949.0L hS 2.50 16667.44 N 4228.69 B 545968.25 6051949.85 HS 2.50 16667.44 ~ 4228.69 H 545968.25 6051949.85 HS 2.50 L6674.27 N 4230.24 H 545969.~6 605L956,69 HS 0.00 16694.75 ~ 4234-88 E 545974,29 6051977.20 HS 0.00 16769.87 ~ 4251.9~ E 545990,90 6052052.40 HS 0.O0 16844.9'9 N 4268-95 ~ 546007.5£ 6052127.60 HS 0.00 16847.03 N 4269.41 B 546007.96 6052129.65 HS 0,00 16874.39 N 4275.60 B 5460~4.G0 6052L57.00 HS 0.00 L6874.35 N 4275.60 E 546014.00 6052157.00 HS 0.00 16879.8L N 4276-84 E 546015.2L 6052162.47 HS O_0O 16884.59 N 4277.93 E 546016.26 6052167.26 HS 0.00 ~690~.66 N 428~,80 H 546020.04 6052£84.35 ~$ 0.00 16939.22 N 4290.3£ H 546020-34 6052221.95 HS 0.00 L7107.04 N 4328.36 B 546065.44 6052389.96 0.00 ANADRILL : APPROVED --FOR PERMITTING ONLY PLAN S AKA-DPC "'0 I> Frl SHARED ..... 'SERV' CES m Marker IUentifica~ion MD ~B SECIN INCLN A) KB .0 0 0 O.O0 B) CIJflVE l.O0/iO0 700 ·700 0 0.00 C) END i. O0/iOO CURVE 1812 t805 108 ',1.12 D) CURVE 2.75/i00' i873 1865 1~9 ~i.i2 . E) CURVE 2.50/i00 43Pl 3504 1746 78.45 F) END 2.50/i00 CURVE 4779 3596 2t91 78.45 G) CURVE 3.00/100 5752 379i 3i20 78.45 H) END 3,00/iOO-CURVE 6220 3B84 3575 7B.80 I) CURVE ;'..50/100 i8650 6;'98 15764 76,80 J) END 2.50/100 CURVE 20402 7232 i7t96 35,00 KI 1ARGEI ~x)i)]iM,~{x{l~-x 2077i 7535 i740B 35,00 LI lO 2it87 7876 17646 35.00 DR]'Lj'IIING ii i i _ il ' ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ii! Ulll i i MPF-17 MPF-97ERD-A (PO5) VERTICAL SECTION VIE~ · Section al; TVD Scale.: Dep Scale.: Drawn ..... : 14.22 inch = 2400 feet inch = 2400 feet Aug 1997 · · . , . -- , ' ....... .:--.-_-_-:: -- ,, ,, \ [[mml liiiI mllI'~ ........ I~ mi m~ .... ' .... lllljm ........... L 0 1200 2400 3600 4800 6000 7;~00 8400 9~0 )0800 12000 ~3200 ~14400 15600 16800 i8000 ~9200 ~0400 Section Departure Unadril] (c197 NPFITP05 3,0C 2109 Pit P) ' , , 08/12/1997 i6:54 907-344~-~-160 ANADRILL DPC PAGE 07 ii i Marker Identification MO BKB SECTN INCLN A) END 2.50/100 CURVE 20402 7232 t7196 35.00 B) TARGET ,~,~,~x,,x~,~ 20771 7535 17408 35.00 ANADRILL AKA-DPC " HARED SERVICES DRIf['ING " i qPF-17 MPF-g7ERD-A (PO5) VIEW VERTICAL SECTION i Section at: 14.22 TVD Scale.' 1 inch : 100 feet Bep Scale,' I inch = ~00 feet Drawn ' 12 Aug ~g97 APPROVED FOR PERMITTING' ONLY PLAN #__ ,~ i Anadr~ ]] $ch]umberger . ', ~:~''' ~. ...... Tar.. (Radius 200 fee_ . . -. ~ · ';~ ~ , . 17000' 17050 17100 t7~50 17~00 17250 17300'' 17350 J7400 17450 17500 17550 ~7600 J7650 17700 Section De ~arture (An~drill (~i 97 KaFiTP05 3.0C Z ~4 I~ pi 88 [ " - SHARED SERVICES DRILLING "~"""" ~"""":'~'~o"' ""~ "'/~ ~/'" MPF- ~.7 MPF-97ERD-A (PO5) A] KB o ON 0E ,I cu~v~ ~.oo/~oo ~oo o. o ~ PLAN VIEW CURVE 2.75/100 1873 115 N 32 E ' · ~I CURVE 2.50/100 4321 t68~ N a64 E ~LosuRE ' 17646 feet at Azimuth 14.20 F] END 2.§0/100 CURVE 4779 2101 N 626 E 6) CURVE 3.00/100 5752 2950 N t0§0 E DECLINATION.' +27.gll (El H) END 3.oo/~00 CURVE 6220 3380 N t216 E SCALE ' 1 inch = 3000 feet I) CURVE 2.50/100 18650 15271 N 3912 E J) END 2.50/100 CURVE 20a02 16657 N 4229 E DRAWN ....... · 12 Aug t997 K) TARGET ~~ 20771 ~6874 N 4276 E L) TD 2~187 17107 N 4328 E llnadrj ]] SchYumbergen 19500 " ' , ANAl)RILL AKA-DPC ' , , ~8ooo "' A ~P'RClVED ,,get {Race,us 200 :eet ) I:'OR i~ER/vlTTiNG ,- - _ ~soo - ON-I.Y 'I # '1§000 .... - ......... -- ' ,~3500 ..... l~O00 .... - · 10500 I 9000- 7500 '- ' .. 6000 · -' " . - 4500 ' ~ :- · 3000 . . : ~ - I,-- - ' ~ . ,,~ · ' 0 ...... .. '~:~ .' .- -r- C:) - , C~ - . 4, t§0o .... 10500 9000 7500 6000 4500 3000 l§O0 0 t500 3000 4500 6000 7500 9000 10500 <- WEST - EAST '--> ...... ~naarlll {c197 MPFiTP05 3.0C Z25 PM P) H 28355 VENDOR /~! A~KAST 14 O0 DATE INVOICE / CREDIT MEMO I DESCRIPTION GROSS DISCOUNT NET 1001c~7 CKlO01C~7 100. O0 100. O0 PYMT :OMMENTS: peenit to drill application HANDL[N~ INST: s/h Kathy Campoanoe, x5122 THE A"I-'rACHED CHECK ~$ IN PAYMENT FOR ITEMS DES~RIBEO ABOVE. ~ I OO. OO I dd dd H · WELL PERMIT CHECKLIST COMPANY FIELD & POOL '~;~ -,--~--'--~ / _fF~ INIT CLASS WELL NAME ///,~-~'"-' /'-,.~... ? GEOL AREA PROGRAM: exp [] dev,~redrll [] serv [] wellbore seg E.; ann. disposal para req [3 ~O UNIT# ,,/?._&]~,') ~ ON/OFF SHORE O,,,~ ADMINISTRATION A~PR DA~-E ; 1 ENGINEERING APPR D/~TE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. . 6. 7. 8. 9. 0. 1. 2. 3. Well located proper distance from drilling unit boundary .... j' Y Well located proper distance from other wells .......... I Y Sufficient acreage available in drilling unit ............ Y If deviated, is wellbore plat included ................ !I~ Y N Operator only affected party ................... :1 y N Operator has appropriate bond in force ............. '!~ Y N Permit can be issued without conservation order ........ I Y N Permit can be issued without administrative approval ...... i Y N Can permit be approved before 15-day wait ........... t~ Y/ N ' z'. ~ ) ' ~ ', ' t . 14. Conductor string provided ................... N~ 15. Sudace casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor &sud 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 rese~e pit ................. ~N 21. If a re-drill, has a 10-403 for abandonment been approved... N 22. Adequate wellbore separation proposed ............. N 23. 24. N BOPEs, do they meet regulation ................. BOPE press rating appropriate; test to ~~ psig. .. 25. 26. 27. 28. 29. If diver[er required, does it meet regulations .......... N Drilling fluid program schematic & equip list adequate ..... N N Choke manifold complies w/APl RP-53 (May 84) ........ N Work will occur without operation shutdown ........... N Is presence of H2S gas probable ................. N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~ "~Y .,?'L 31. Data presented on potential overpressure zones ....... Y / ~ 32. Seismic analysis of shallow gas zones ............. Y/~'" ~ ' ' "' 33. Seabed condition survey (if off-shore) /Y N A,/A~ DATE 34. Contact name/phone for we.eklyprogress rep?ts ./-: Y N /-Y' ~..-' ~'/~b'~fi~'~.T" ,exploratory on,yj .... ~-- .... GEOLOGY: RP ,/C~., ENGINEERING: COMMISSION: RNC~ CO ~o Comments/instructions: HOW/lit - A \FORMS\chekhst rev 09197 · WELL PERMIT CHECKLIST COMPANY __/~¢ WELL NAME FIELD & POOL . ~'~"/~::~ INIT CLASS _/~ //-<:2,'/ OEOL AREA PROGRAM: exp [] dev.,~redrll [] serv [] wellbore seg C ann. disposal para req [] UNIT# ,///'~,_"~_,~__ _~ ON/OFF SHORE d;:3),,t.J ADMINISTRATION APPR D~TE , 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 .... N ~- ~. 6. Well located proper distance from other wells .......... ~ ~ 7. Sufficient acreage available in drilling unit ............ N ,~_.~.,,-~..,..,.,~¢ .__ _ __, _.. 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... %.J4 N ~,~ ~.~,.// ~';".w~_,¢--., ,,. ~ ,-.,, J,, ~/ 10. Operator has appropriate bond in force ............. ~ N ' ' /- -' ~' -' z2' - ' 1 1. Permit can be issued without conservation order ........ L'~ N 12. Permit can be issued without administrative approval ...... (~ N 13. Can permit be approved before 15-day wait ........... N ENGINEERING ~;~.~ DATE GEOLOGY APPR 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... (~f-J N 17. CMT vol adequate to tie-in long string to surf csg ........ ,.~ N 18. CMT will cover all known productive horizons .......... ~.2 N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... (~ N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to ~""OOO psig.~;~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ,,~, N..~ 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... Y,,N'/ 32. Seismic analysis of shallow gas zones ............. /Y/' N 33. Seabed condition survey (if off-shore) ............ ./Y N 34. Contact name/phone for we_eklyprogress reports ......./Y N lexploratory only] GEOLOGY: ENGINEF_~ING: JDH COMMISSION: RNC co Oo Comments/Instructions: HOW/lit - A \~ORMS\cheklist rev 09/97 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'-~ ,~"'/(~ (~ INIT CLASS F 'P )(''' WELL NAME ~)k/~ ~ F- ~-) O~ ~/ /' '" ~ [ ,) GEOL AREA PROGRAM: exp [] dev ,6~,redrll [] serv [] wellbore seg D ann. disposal para req [] 0 UNIT# / [ 3 ~._f~ ON/OFF SHORE ~[ H ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11 I~TE 12. I~ L~'") 13. Permit fee attached ....................... Lease number appropriate ................... ~~N Unique well name and number .................. N Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... ~i~ NN Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. (~N · Permit can be issued without conservation order ........ ~_. N Permit can be issued without administrative approval ...... ~ N Can permit be approved before 15-day wait ........... ~ N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... - N Adequate wellbore separation proposed ............. ~ ) N If diverter required, does it meet regulations .......... ) N Drilling fluid program schematic & equip list adequate ..... ) N BOPEs, do they meet regulation ...... ;,~.;~% ..... BOPE press rating appropriate; test to .~'-2 c¢~,, c.,, psig. (~) N Choke manifold complies w/APl RP-53 (May"84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY A~,R DATE 30. Permit can be issued w/o hydrogen sulfide'measures ..... Y N 31. Data presented on potent~essure zones ....... Y N 32. Seismic analysis of~atf6w gas zones ............. Y N 33. Seabed co?,¢jI~erf-survey (if off-shore) ............. Y N 34. Co__me/phone forwe/e,:,k?r,/OnrrO~ress re~)o, rts ....... Y N [exploratory on~yj REMARKS RPC .t24r~ ENGINEERING: COMMISSION' B EV~.j,' ~/'~ DWJ~ JUN ~L~'~. RNC~ CO CO Comments/Instructions: HOWlljt - A:\FORMS\cheklist rev 09~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : MPF-17 FIELD NAME : MILNE POINT UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292282300 REFERENCE NO : 98086 LI,~ Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/11 ORIGIN · FLIC REEL N~E : 98086 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, MPF-17, MILNE POINT UNIT, API #50-029-22823-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 98/08/11 ORIGIN · FLIC TAPE NAME : 98086 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~IENT : B.P. EXPLORATION, MPF-17, MILNE POINT UNIT, API #50-029-22823-00 TAPE HEADER MIL~.~E POINT LSVIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NIIM~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 98086 ST AMOUR PYRON WELL CASING RECORD 1ST STRING 2ND STRING MPF-17 500292282300 BP EXPLORATION SCHLUMBERGER WELL SERVICES lO-AUG-98 BIT RUN 2 BIT RUN 3 6 13N iOE 45.60 12.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 9540.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 3RD STRING 8.500 PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED LWD CDR AND ADN DATA AQUIRED ON BP EXPLORATION'S MPF-17 WELL. THIS DATA HAS NOT BEEN DEPTH SHIFTED PER KATIE NITZBERG. THE DATA WAS AQUIRED 02-JAN-98 THROUGH 20-JAN-98. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUNk4ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5990.0 21800.0 BASELINE DEPTH $ I~ERGED DATA SOURCE LDWG TOOL CODE .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE 1 5990.0 8746.0 2 8677.0 9560.0 3 9395.0 19040.0 4 18888.0 21800.0 No depth adjustments were applied, as per K. Nitzberg. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/PEL/PER. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0I{~q4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0P~4~4000193 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~I4000193 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD 0HFi~4000193 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 ~ G/C3 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 M~rD G/C3 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 ~ G/C3 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 ArRATMWD 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 4000193 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14:05 PAGE: ** DATA ** DEPT. 5990.000 FET.~fD -999.250 RA.MWD -999.250 RP.~fD VRA.MWD -999.250 VRP.MWD -999.250 ROP.~D -999.250 GR.~D RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.~fWD -999.250 PEF.MWD -999.250 NRAT.MWD -999.250 NPHI.MWD DEPT. 21779.500 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MIVD -999.250 ROP.~WD 71.700 GR.MWD RHOi.~fD -999.250 RH02.~'~ -999.250 RH03.~,~'~ -999.250 RHO4.MWD DRHO.~gD -999.250 PEF.MI'~ -999.250 NRAT.MWD -999.250 NPHI.~D -999.250 36.540 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TP=AILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE · 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lqU~IBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 5990.0 8746.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14:05 PAGE: LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOF~gARE VERSION: DATA TYPE (M~ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: ~AXI~f~?4 A~¥GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE ~P CASI~,~.G DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 20-JAN-98 5.36 4.1 MEMORY 21781.0 5990.0 21780.0 65 76.8 77.3 TOOL NUMBER CDR 8039 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.3 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 1400 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 000 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): O. 000 MUD CAKE AT (MT): O. 000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) 20000 REMARKS: *** RUN1 6059' - 8747' CDR *** *** RUN2 8747' - 9560' CDR *** *** RUN3 9560' - 19040' CDR *** *** RUN 4 19040'- 21780' CDR/ADN *** GR CORRECTED FORMUD WT. AND HOLE SIZE ULTRASONIC CALIPER FAILED ON ADN RUN 4 CALIPER DATA NOT PRESENTED. $ LIS FORMAT DATA 0.0 0.0 0.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14:05 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NU~4B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUT4B S~P ELEM CODE (H£X) DEPT FT 4000193 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 0H~4000193 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 0H~4~4000193 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 4000193 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 4000193 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 4000193 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 4000193 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5990. 000 ATR. LW1 1. 241 PSR. LW1 1. 557 ROPE. LW1 - 999. 250 GR. LW1 3 6. 544 TABR. LW1 O. 000 TAB. LW1 O. 002 DEPT. 8746.500 ATR.LW1 3.322 PSR.LWl 2.792 ROPE.LW1 GR.LW1 116.085 TABR.LW1 4321.156 TAB.LW1 1.362 63. 408 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14:05 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SU?~fARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8678.0 9560.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ 20-JAN-98 5.36 4.1 MEMORY 21781.0 5990.0 21780.0 65 76.8 77.3 TOOL NUMBER CDR 8039 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14: 05 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 12. 250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.4 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 1200 FLUID LOSS (C3): RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED T~,IPERATURE (MT): O. 000 MUD AT MA~ CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): O. 000 MUD CAKE AT (MT): O. 000 NEUTRON TOOL MATRIX: f,~ATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN1 6059' - 8747' CDR *** *** RUN2 8747' - 9560' CDR *** *** RUN3 9560' - 19040' CDR *** *** RUN4 19040'- 21780' CDR/ADN *** GR CORRECTED FOR MUD WT. AND HOLE SIZE ULTRASONIC CALIPER FAILED ON ADN RUN 4 CALIPER DATA NOT PRESENTED. $ LIS FORMAT DATA 0.0 0.0 0.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 9 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHF~I 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~I 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 GR Lr,~,r2 GAPI 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR 4000193 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8677. 500 ATR. LW2 3. 501 PSR. LW2 2.537 ROPE. LW2 - 999. 250 GR. LW2 93. 714 TABR. LW2 O . 000 TAB. LW2 0. 00! DEPT. 9560. 000 ATR. LW2 2. 447 PSR. LW2 2. 707 ROPE. LW2 GR.LW2 106. 022 TABR.LW2 2176. 000 TAB.LW2 O. 706 103. 448 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SO?.~.L~Y VEA~OR TOOL CODE START DEPTH STOP DEPTH MWD 9395.0 19041.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFI~¢ARE VERSION: DO?~HOLE SOFT?;ARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 20-JAN-98 5.36 4.1 MEMORY 21781.0 5990.0 21780.0 65 76.8 77.3 TOOL NUMBER CDR 8039 12. 250 112.0 LSND 9.3 550 LI$ Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 11 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1. 690 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.240 MUD CAKE AT (MT): 2.210 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN1 6059' - 8747' CDR *** *** RUN2 8747' - 9560' CDR *** *** RUN3 9560' - 19040' CDR *** *** RUN4 19040'- 21780' CDR/ADN *** GR CORRECTED FOR MUD rifT. ~ HOLE SIZE ULTP~SONIC CALIPER FAILED O?I ADN R~I 4 CALIPER DATA NOT PRESENTED. $ LIS FORMAT DATA ** DATA FORI,fAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 12 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000193 ATR LW3 OH~4~ 4000193 PSR LW3 OH~I~ 4000193 ROPE LW3 F/HR 4000193 GR LW3 GAPI 4000193 TABR LW3 4000193 TAB LW3 HR 400 O193 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9395. 000 ATR.LW3 O. 176 PSR.LW3 1 . 354 GR.LW3 38. 630 TABR.LW3 O. 000 TAB.LW3 O. 016 DEPT. 19040. 500 ATR. L~W3 3. 411 PSR. LrW3 4. 271 GR.LW3 127.079 TABR.LW3 1618.938 TAB.LW3 0.502 ROPE. LW3 ROPE. LW3 -999.250 107.845 ** END OF DATA ** **** FILE TP~AILER **** FILE Z-I~]E : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 LI,g Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14:05 PAGE: 13 DEPTH INCREMENT: 0.5000 FILE SURff~Y VENDOR TOOL CODE START DEPTH ~4~q9 18888.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOF~¢ARE VERSION: DOr"H~HOLE SOFT~gARE VERSION: DATA TYPE (M2~4ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) I.iINI~.Fu?4 ~hYGLE : i.£~Sf Ii.F~,I ~2,1GLE : STOP DEPTH .......... 21780.0 20-JAN-98 5.36 4.1 MEMORY 21781.0 5990.0 21780.0 65 76.8 77.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ TOOL NUMBER CDR 8039 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 12. 250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.3 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 550 FLUID LOSS (C3): RESISTIVITY (OH~k~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 050 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 730 MUD CAKE AT (MT): 2.510 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 6059' - 8747' CDR *** *** RUN2 8747' - 9560' CDR *** LI~ Tape Verification Listing Schlumberger Alaska Computing Center il-AUG-1998 14: 05 PAGE: 14 *** RUN 3 9560' - 19040' CDR *** *** RUN 4 19040'- 21780' CDR/ADN *** GR CORRECTED FOR MUD WT. AND HOLE SIZE ULTRASONIC CALIPER FAILED ON ADN RUN 4 CALIPER DATA NOT PRESENTED. $ LIS FOPJ, LAT DATA ** DATA FOR2.iAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 92 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ATR LW4 0P~4~4000193 O0 000 O0 0 5 1 1 4 68 0000000000 PSR LW4 0H~4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ROPE LW4 F/HR 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 TAB LW4 HR 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 TABD LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ROBB LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ROBU LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ROBL LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ROBR LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 DRHB LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 DRHULW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DRHL LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 DRHR LW4 G/C3 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 PEB LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 PEU LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 PEL LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 PER LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH LW4 PU 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA LW4 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 RPM LW4 RPM 4000193 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 18887. 500 ATR. LW4 3. 523 PSR. Lr,~4 4. 024 ROPE. GR. LW4 102.3 66 TABR. LW4 0. 000 TAB. LW4 0. 000 TABD. LW4 RO~B. L?~4 2. 455 ROBU. LW4 2. 232 ROBL. L?,r4 2. 083 ROBR. L~;~4 DRHB.LW4 -0.001 DRHU. LW4 0.111 DRHL.LW4 0.076 DRHR.LW4 PEB.LW4 3. 745 PEU. LW4 10.247 PEL.LW4 11.597 PER.LW4 TNPH. LW4 35. 715 TNRA. LW4 22. 002 RPM. LW4 O. 000 DEPT. 21779. 500 ATR. LW4 9. 687 PSR. LW4 10. 347 ROPE. LW4 GR.LW4 80.185 TABR.LW4 5134.594 TAB.LW4 1.678 TABD.LW4 ROBB. LW4 2. 424 ROBU. LW4 2. 305 ROBL. LW4 2.246 ROBR. LW4 DRHB. LW4 0. 000 DRHU. LW4 0.120 DRHL. LW4 0.120 DRHR. LW4 PEB.LW4 2.988 PEU. LW4 6.967 PEL.LW4 7.93~ PER.LW4 TNPH. LW4 33.144 TNRA . LW4 21.040 RPM. LW4 65.545 -999.250 0.000 2.3~1 0,070 5.822 71. 700 8015. 344 2. 404 0.044 3. 592 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LI~ Tape Verification Listing Schlumberger Alaska Computing Center Il-AUG-1998 14:05 PAGE: 16 **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE · 98/08/11 ORIGIN · FLIC TAPE NAME · 98086 CONTINUATION # : 1 PREVIOUS TAPE : CO~.~4ENT · B. P. EXPLORATION MPF-17, MILNE POINT UNIT, API #50-029-22823-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 98/08/11 ORIGIN : FLIC REEL NAME : 98086 CONTINUATION # : PREVIOUS REEL : CO~4ENT : B.P. EXPLORATION MPF-17, MILNE POINT UNIT, API #50-029-22823-00