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Home My WebLink About190-086MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC H-01 MILNE PT UNIT H-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/11/2025 H-01 50-029-22061-00-00 190-086-0 N SPT1900860 2500 0 200 150 100 OTHER P Guy Cook 11/5/2025 Resevoir plug/casing MIT to 2500 psi per Sundry 325-665. Tubing pulled; 7" 26ppf casing in the hole for the test performed by Doyon 14. They used a chart recorder that was currently calibrated. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT H-01 Inspection Date: Tubing OA Packer Depth 0 2700 2626 2610IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251105132611 BBL Pumped:2.9 BBL Returned:3 Thursday, December 11, 2025 Page 1 of 1         Test chart attached   Well is 1-Oil producer MPU H-01 (PTD 1900860) Test Chart – 7-inch Casing Plug AOGCC Insp # mitGDC251105132611 11/5/2025 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 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: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT H-01 JBR 12/30/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2 7/8", 4/5" and 7" test joints used for testing. Good test with no issues. 18 charge bottles ranging from 950 psi to 1010 psi. Test Results TEST DATA Rig Rep:S. Tower/J. CharlieOperator:Hilcorp Alaska, LLC Operator Rep:S. Heim/J. Vanderpool Rig Owner/Rig No.:Doyon 14 PTD#:1900860 DATE:11/6/2025 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC251106145317 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1395 Sundry No: 325-677 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 7" Solid P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"X 5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1700 200 PSI Attained P37 Full Pressure Attained P167 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P15 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2         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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored); DOA AOGCC Prudhoe Bay Subject:202511052 2138 MPU H-01 (PTD# 190-086) operating under Sundry# 325-677... Date:Thursday, November 6, 2025 11:36:06 AM For the records. From: Rixse, Melvin G (OGC) Sent: Wednesday, November 5, 2025 9:38 PM To: Erik Nelson <Erik.Nelson@hilcorp.com> Subject: Re: MPU H-01 (PTD# 190-086) operating under Sundry# 325-677... Erik, Plan approved as described. Mel Rixse On Nov 5, 2025, at 20:36, Erik Nelson <Erik.Nelson@hilcorp.com> wrote: Mel, After communicating our Approved Sundry #325-677 to the rig team this evening I was informed that when we nippled up the BOPs during our initial rig up we put an adapter flange in below the single-gate to make up to the wellhead. That adapter flange has a 6.125-in ID through it. In order to proceed ahead with our cut and pull of the 7”, 26# csg we’ll need to pull it. We currently are isolated from the Schrader Bluff formation with a cement plug that passed a pressure test this morning witnessed by Guy Cook. We have also observed the well is static throughout all of our follow-on logging runs after placement of cement on 04 Nov at 1330 hrs. Our plan is proceed with the following steps above that tested cement plug and a static column of fluid: 1. ND 13-5/8” BOP 2. ND 7” x 11” Adapter Flange w/ reduced ID 3. Pull False Bowl from CT ESP Completion 4. Install Test Plug 5. NU 13-5/8” Spacer Spool and 13-5/8” BOP 6. Open up the upper ram of the double-gate above the flow cross and replace 2-7/8” x 5” VBRs w/ 7” Pipe Rams 7. Button everything back up and commence w/ planned full BOP test per 7-day RWO BOP Test schedule (Guy Cook already let us know that he plans on witnessing this test) If you could review and provide approval of our plan forward I would appreciate it. Q Erik Q. Nelson Milne Point OE O (907) 777 - 8353 C (907) 903 – 7407 Erik.Nelson@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage 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 phonenumber 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Alter Casing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to WSW 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): 5,250' N/A Casing Collapse Conductor N/A Surface 2,020psi 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 WSW 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 Erik.Nelson@hilcorp.com 907-564-5277 See Schematic See Schematic 2-7/8" Haliburton: BWD Sump & VTL and N/A 4,620 MD/ 3,972 TVD & 4,740 MD/ 4,073 TVD and N/A Erik Nelson 80' 13-3/8" 9-5/8" 7" 2,758' 5,187' N/A 3,520psi 7,240psi 2,491' 4,479' 2,793' 5,222' Length Size Proposed Pools: 105' 105' 5.46# / HS-70 / CT TVD Burst 4,555' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-086 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22061-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/5/2025 Perforation Depth MD (ft): 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 MILNE PT UNIT H-01 MILNE POINT SCHRADER BLUFF OIL Prince Creek Tertiary 4,493' 5,146' 4,415' 1,395 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 4:16 pm, Nov 03, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.11.03 15:25:48 - 09'00' Taylor Wellman (2143) 325-67 10-404 SFD 11/5/2025 * BOPE test to 2500 psi. 24 hour notice to AOGCC. MGR04NOV2025 SFD 11/5/2025 SB Oil Pool: JLC 11/5/2025 11/05/25 Well Name: MPU H-01 API Number: 50-029-22061-00-00 Current Status: LTSI ESP Prod Rig: Doyon 14 Estimated Start Date: 05 Nov 2025 Estimated Duration: 9 days Regulatory Contact: Tom Fouts Permit to Drill Number: 190-086 First Call Engineer: Erik Q. Nelson (907) 777 8353 (O) (907) 903 7407 (C) Second Call Engineer: Taylor Wellman (907) 777 8449 (O) (907) 947 9533 (C) Geologist: Katie Cunha (907) 564 4786 (O) (907) 802 0078 (C) Current Bottom Hole Pressure (BHP): Schrader Blu (N-sands) (to be abandoned during RWO) 1798 psi @ 4690-ft MD (4031-ft TVD) (TOP) SBHP 10 Sep 2025 | 8.58 EMW (8.8 KWF) Max Potential Surface Pressure (MPSP): 1395 psi Gas Column Gradient (0.1 psi/ft) Current Bottom Hole Pressure (BHP): Tertiary Undef WTRSP (525130) (to be recompleted as WSW) 1194 psi @ 3074-ft MD (2718-ft TVD) (Planned TOP) 9-5/8 Surf Csg Shoe at 2793-ft MD (2491-ft TVD) From o set WSW | 8.45 EMW (8.5 KWF) Max Potential Surface Pressure (MPSP): 922 psi Gas Column Gradient (0.1 psi/ft) Max Deviation: (for entire wellbore relevant to Pre-RWO wellwork and RWO) 37.6° @ 4054-ft MD Max Dogleg: (for entire wellbore relevant to Pre-RWO wellwork and RWO) 4.0°/100-ft @ 1018-ft MD Min ID: (for entire wellbore relevant to Pre-RWO wellwork and RWO) 2-7/8, 5.46# HS-70 CT Completion (2.49-in ID) 2-7/8, 6.5# Tbg Pup Jt at Hanger = 2.44-in ID 7, 26# Csg (6.276-in ID) No ID restriction RKB: 35.0-ft (Nabors 27E) Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 Brief Well Summary: MPU H-01 was drilled and cased by Nabors 27E in Oct 1990 as a Schrader Blu producer. The well was drilled and cased but then sat until Nabors 4ES perforated and ran a Frac-Pak lower completion into the Schrader Blu N sands in September/October 1994. Post Frac-Pak completion, Nowcam CT Unit 4907 was brought in to run a 2-7/8 CT ESP Completion. The well produced until October 1998 when the ESP failed. MPU H-01 has been shut-in since then. This COP is being submitted to address the AOGCCs request that there be isolation from surface in the 7 x 9-5/8 annulus above the requested perforations in the Tertiary Undef WTRSP (525130) below the 9-5/8 casing shoe MPU H-01. Notes Regarding Current Wellbore Condition: Were anticipating that Doyon 14 has pulled the 2-7/8 CT ESP completion, acceptably P&Ad the existing Schrader Blu perforations, and evaluated the 7 csg string by the start of this proposed procedure - 10 Sep 2025 Run SBHP survey - 06 Sep 2025 Verify open OA - 04 Sep 2025 Pulled SOV from GLM #1 and left open Objective: Hilcorp Alaska, LLC proposes performing reservoir abandonment of the Schrader Blu N sands and to re- complete the well into the Tertiary Undef WTRSP (525130) formation as a high-volume freshwater source well. This procedure details the below outline of the scope of this project: - Pull the existing 2-7/8, 5.46# HS-70 CT ESP completion - Set 7 cement retainer and pump Class G neat cement to abandon the Schrader Blu N perforations - Cut/Pull 7 csg from above the 9-5/8 shoe assembly and install a 7 x 9-5/8 Liner Top Packer above a 7 Casing Patch (Overshot) - Perforate the Tertiary Undef WTRSP (525130) formation and install a Cased Hole Gravel Pack (CHGP) lower completion - Install a 4-½ tubing ESP completion above the Cased Hole Gravel Pack Well:MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 Verbal/Written Approval to Proceed received 28 Oct 2025 for Steps #1 - #35 on originally submitted Sundry# 325-665 Install Mechanical Isolation in 7 x 9-5/8 Annulus: 36) MU 7 Mechanical Cutter BHA: a) Centralizer b) Multi-String Cutter setup for 7, 26# csg c) Bumper Sub d) Jars e) XX Jts 4 XT-39 DP to surface 37) TIH to cut 7 csg mid-jt per prod csg tally at +/- 2639-ft MD (targeted to be in the 2nd full jt above the 9-5/8 shoe assembly) NOTE: At this point we are isolated from the Schrader Blu perforations with a tested cement retainer and cement in place across the retainer. After cutting the 7 csg we are open to the Tertiary Undef WTRSP (525130) through the open shoe in the 7 x 9-5/8 annulus. 38) Circulate w/ heated 8.5# source wtr down the DP taking returns from the 7 x 9-5/8 annulus. Circulate x2 BU (+/- 170 bbls). Take all returns to an open top tank outside of the rig. NOTE: Dead crude was the last uid pumped in the OA for annular injection 39) TOOH w/ 4 XT-39 DP and lay down MSC Assy 40) Prep rig oor to pull 7, 26# csg 41) TOOH kicking out same NOTE: Inspect cut csg stub retrieved for possible dress o run 42) MU 9-5/8 Cleanout BHA: a) +/- 15-ft 7 washpipe w/ no cut rite b) Smooth OD String Mill or Csg Scraper setup for 9-5/8, 36# csg c) 9-5/8 Test Pkr d) 4 XT-39 DP to surface 43) TIH to washover 7 csg stub. Reverse circulate x2 BU (+/- 55 bbls) once over 7 csg stub 44) Set 9-5/8 Test Pkr and perform MIT-IA (1500 psi) of 9-5/8, 26# csg for 30-min charted 45) Release test pkr and TOOH laying down 9-5/8 Cleanout BHA 46) MU 7 x 9-5/8 LTP Assy: a) 8-3/8 OD Logan Pkr Csg Patch (5K psi WP) w/ 7 BTC b) 7 BTC x 7-5/8 BTC X-over Pup c) 7-5/8 x 9-5/8 ZXP Lnr Top Pkr d) Baker Pusher Tool e) 4 XT-39 DP to surface 47) TIH to overshot 7, 26# csg stub. PT down 4 DP to 1500 psi to con rm integrity of Csg Patch. NOTE: Testing against cmt in the 7 csg below the Csg Patch 48) Set 7 x 9-5/8 LTP per Baker recommended procedure 49) Perform MIT-IA (1500 psi) of 4 DP x 9-5/8 annulus for 30-min charted to ensure mechanical isolation of the Tertiary Undef WTRSP (525130) 50) Release Baker Pusher Tool and TOOH 51) MU 9-5/8 Storm Pkr w/ reqd pipe weight below 52) TIH to set 9-5/8 Storm Pkr +/- 50-ft below WH and PT to 1500 psi to ensure isolation. Observe the well for static conditions for 30 mins. MIT-IA (1500 psi) of 9-5/8, 26# csg for 30-min charted Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 NOTE: Our barriers in place at this point in the program: Schrader Blu 1) Mechanical barrier (cmt retainer) and cement pressure tested from above to 2500 psi 2) Storm Pkr set and tested from above to 2500 psi which gives us a 2nd barrier to the Schrader Blu perfs Tertiary Undef WTRSP (525130) 1) Mechanical barrier (LTP) tested from above to 1500 psi 2) Storm Pkr set and tested from above to 2500 psi which gives us a 2nd barrier 53) ND 13-5/8 BOPE stack. ND WKM spool. NU FMC spool. NU 13-5/8 BOPE stack. Test break to 250/1500 psi. 54) TIH to remove 9-5/8 Storm Pkr 55) TOOH laying down 9-5/8 Storm Pkr and 4 XT-39 DP as needed 56) Prep rig oor for TCP operations Perforate Tertiary Undef WTRSP (525130): 57) MU 4-½ 12spf SBH RDX TCP Guns w/ spacers as reqd 58) TIH on 4-½, 12.6# IBT-Mod workstring to bump the sump pkr and tie-in to perforate the below selected intervals: NOTE: Maintain hole ll while TIH. We should be slightly overbalanced with 8.5 #/gal brine in the hole. 59) Con rm well is dead after perforating. Bullhead 8.5 #/gal source wtr as reqd. 60) TOOH and lay down TCP assy. Ensure all shots red. 61) Prep rig oor for cleanout run Contingency Perf Surge Run: NOTE: Well determine the need for this on how the well behaves after perforating 62) MU Perf Surge BHA: a) Junk Mill w/ ports smaller than 1-¼ OD b) Spacer X-over pup c) DLT Compression Set Retrievable Pkr setup for 7, 26# csg Top MD Base MD Total MD Top TVD Base TVD Total TVD Inc at Top interval Inc at base interval Zone H-01 3074 3123 49 2718 2759 41 35 35 UG4 H-01 3200 3244 44 2820 2857 37 36 36 UG4 H-01 3362 3396 34 2952 2980 28 36 37 UG3 H-01 3515 3604 89 3077 3148 71 37 37 UG3 H-01 3646 3679 33 3182 3209 27 37 37 UG3 H-01 3713 3758 45 3236 3272 36 37 37 UG3 H-01 3786 3891 105 3294 3378 84 37 37 UG3 H-01 TOTAL 399 324 Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 d) Spacer X-over pup e) XX jts 3-½, 4 XT-39 DP f) 3-½ Spacer X-over pup g) 3-½ Glass Burst Disc Assembly (+/- 470-ft MD from Junk Mill) h) 3-½ Spacer X-over pup i) 4 XT-39 DP to surface as reqd 63) TIH to place Junk Mill at +/- 2750-ft MD (review logs to ensure were not set across a collar) 64) Set DLT Compression Set Retrievable Pkr and con rm with backside PT to 1500 psi 65) MU FOSV to 4 XT-39 DP 66) MU 4 XT-39 DP pup on top of FOSV 67) Close FOSV and place 5-ft (1.25-in OD) Drop Bar in workstring pup above FOSV 68) MU Top Drive to 4 XT-39 DP pup 69) MU Kelly Hose to top drive and ensure it is fully open to the pits and the poor boy degasser is bypassed 70) Open ¼ turn valve and allow bar to drop 71) Once glass burst disc has been ruptured and the initial surge has subsided, PU on workstring to unseat pkr 72) Begin reverse circulating x2 workstring volume (+/- 60 bbls) at max rate w/ 8.5 #/gal source wtr 73) Once circulation is complete, monitor well for ow before TOOH 74) TOOH laying down pkr and ensuring Drop Bar is recovered from above Junk Mill 75) Prep rig oor for cleanout run Cleanout Run: 76) MU Cleanout BHA: a) 2-7/8 pup w/ muleshoe (+/- 5-ft) b) X-over c) Smooth OD String Mill for 7, 26# csg (6.276-in ID) d) 4-¾ String Magnet e) X-over f) XXX jts 4 XT-39 DP to surface 77) TIH to TOP 78) Cleanout 7 csg by rotating/circulating while RIH 79) Carefully enter seal bore of 7 Permapak Seal Bore Pkr to ensure it is clear for Snap Latch 80) PU so muleshoe is just above pkr and circulate a 20-bbl gel pill surface to surface with 8.5 #/gal source wtr (+/- 135 bbls) 81) TOOH laying down Cleanout BHA. Note any debris recovered on magnets. 82) Prep rig oor for lower completion run Lwr Completion Run: 83) MU GP Screen Assy on the screen table as follows: Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 NOTE: Screen section should start +/- 10-ft below lowermost perfs and stop +/- 10-ft above uppermost perfs a) Snap-Latch for 7 Permapak Seal Bore Pkr b) 2-7/8, 6.5 L80 EUE-8rd spacer pipe as needed for positioning of btm of screens +/- 10-ft below btm perforations c) X-over 2-7/8, 6.5# EUE-8rd pin x 4, 9.5# JFE Bear box d) +/- 20 jts 4, 9.5# L80 JFE Bear basepipe screens BxP R3 NOTE: Screen Properties: 3.548-in ID 4.400-in screen OD 3/8 holes drilled at 48 holes/ft 0.012-gauge wire wrap (90S) / 90V screen ribs 6.026-in OD 4-blade centralizer on pin end e) +/- 8 jts 4, 9.5# L80 JFE Bear basepipe NOTE: Recommended torque for 4, 9.5# JFE Bear: Minimum 3465 ft-lbs Optimum 3745 ft-lbs Max 4025 ft-lbs 84) RU false rotary table and change handling equipment out to accommodate 2-7/8 washpipe 85) PU, MU, and RIH w/ 2-7/8, 6,4# L80 H511 washpipe inside of GP Screen Assy NOTE: Recommended torque for 2-7/8, 6,4# L80 H511: Minimum 700 ft-lbs Optimum 800 ft-lbs Max 1200 ft-lbs 86) PU the HES GP Pkr Assy. MU the 2-7/8 washpipe to the HES Running Tool and MU the blank basepipe to the HES GP Pkr per HES Tool Supervisors direction 87) RD false rotary table and change handling equipment out to accommodate 4-½, 12.6# L-80 TXP-BTC tbg NOTE: Recommended torque for 4-½, 12.6# L-80 TXP-BTC tbg: Minimum 5550 ft-lbs Optimum 6170 ft-lbs Max 6790 ft-lbs 88) TIH maintaining hole ll to just above 7 Permapak Seal Bore Pkr. Obtain PU and SO weights. NOTE: Space out should take into consideration the height of the 4-½, 12.6# L-80 TXP-BTC tbg on the rig oor for rigging up the GP pumping kit 89) SO into 7 Permapak Seal Bore Pkr until stack out is noted. PU to snap out and con rm latch. 90) Re-engage snap latch and PU to neutral pipe weight 91) Set HES HES VCA Pkr as per HES Tool Supervisors direction NOTE: VCA Pkr set depth is targeted to be 2764-ft MD 92) Perform GP operations as per HES Tool/Pumping Supervisors directions a) General Steps: i) Manipulate HES GP Tool Assy in order to pickle workstring with 15% HCl (+/- 10 bbls) and displace it to the HES GP Tool Assy w/ 8.5 #/gal source wtr ii) Reverse circulate pickle from the workstring taking returns to an open top tank NOTE: Ensure neutralizing agent is on location Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 iii) Manipulate HES GP Tool Assy to perform step rate injection test at 1, 2, 4, and 6 bpm w/ 8.5 #/gal source wtr. Shut down pumps and record tbg/csg pressures iv) Pump GP w/ +/- 15K lbs 20/40 Carbolite 93) Upon successful placement of GP shutdown pumps and monitor well for static conditions. Circulate 8.5 #/gal source wtr as required. 94) TOOH and lay down the HES running tools 95) Change handling equipment out to accommodate 2-7/8 washpipe 96) TOOH 2-7/8 washpipe 97) Prep rig oor for 4-½, 12.6# L80 TXP-BTC Upper ESP completion run Upper ESP Completion Run: 98) Ensure handling equipment is on-hand for running 4-½, 12.6# L-80 TXP-BTC completion 99) MU Spooler to run ESP power cable 100) PU ESP assembly and RIH on 4-½, 12.6# L-80 TXP-BTC tbg, making electrical checks on the cable every 1,000-ft. Install cross-coupling clamps on the rst 10 jts then every other jt to surface. a) Motor Centralizer Target set depth at +/- 2700-ft MD NOTE: This set depth is +/- 60-ft inside of the 7 and inside the LTP. We will evaluate the ESP set depth on the results of the high resolution gyro survey b) ACE DH Gauge c) 562 ESP Mtr d) Lower Seal e) Upper Seal f) Intake g) 538 ESP pump h) 538 ESP pump i) Bolt-on Discharge head w/ 4-½, EUE 8rd box up j) X-over 4-½, 12.6 EUE 8rd pin x 4-½, 12.6# TXP-BTC box k) (1) jt 4-½, 12.6# L-80 TXP-BTC tbg l) (1) 4-½ XN nipple pro le (3.813-in Bore, 3.725 No-Go) w/ 10-ft 4-½, 12.6# L-80 TXP-BTC handling pups m) XX jts 4-½, 12.6# L-80 TXP-BTC tbg to surface n) Tbg Hgr X-over 4-½, 12.6# L-80 TXP-BTC pin x 4-½, 12.6# AB TC-II box 101) PU and MU the tbg hgr. Make nal splice of the ESP cable to the penetrator, MU control line to the tbg hgr and dummy o any additional control line ports if necessary. NOTE: Use caution when landing the tbg hgr so as to avoid damaging the ESP cable or penetrator. 102) Land tbg hgr and record PUW and SOW on tbg tally 103) RILDS and lay down landing jt 104) Set BPV. ND BOPE. Set CTS Plug. 105) NU tbg head adapter. PT tbg hgr void to 500/5000 psi. 106) NU new 4-1/16 5M tree. PT tree 500/5000 psi. Well: MPU H-01 PTD: 190-086 API: 50-029-22061-00-00 Date: 03 November 2025 107) Pull CTS plug and BPV 108) Install gauges. Secure tree and cellar. 109) RDMO Doyon 14 Post-Rig Procedure: 1) Turn well over to Ops via handover form 2) RU well house and owlines 3) POP per HES Summit Startup Procedure Attachments: 1) Current Wellbore Schematic 2) Proposed Wellbore Schematic 3) BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 9/10/2025 SCHEMATIC Milne Point Unit Well: MPU H-01 Last Completed: 10/6/1994 PTD: 190-086 TD =5,645(MD) / TD = 4,529(TVD) 13-3/8 RA Tag @ 4,613 7 8 9 7 9-5/8 10 PBTD =5,634(MD) / PBTD =4,541(TVD) Est TOC @ 3,600 1 3 5 4 2 6 Orig. KB Elev.:35 (Nabors 27E) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / Welded N/A Surface 105' 9-5/8 Surface 36 / K-55 / BTRC 8.921 Surface 2,793 7" Intermediate 26 / L-80 / BTRC 6.276 Surface 5,222 TUBING DETAIL 2-7/8 Coil Tubing 5.46 / HS-70 / CT 2.49 Surface 4,491 2-7/8 Tubing 6.5 / L-80 / EUE 8Rd 2.44 4,491 4,555 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 4,494 CAMCO KBMG Gas lift Mandrel w/ 1 Pocket 2 4,514 Centri-Lift Check Valve 3 4,515 Discharge Head: Bolt On 4 4,516 Pump Intake 5 4,532 Seal Section 6 4,544 Motor Section 7 4,553 Pressure Gauge Btm @ 4,555 8 4,620 Haliburton VTL Packer 9 4,637 Seal Bore (3.88 ID) 10 4,740 7 Haliburton BWD Sump Packer OPEN HOLE / CEMENT DETAIL 13-3/8" 500 sx of Permafrost C in 30 Hole 9-5/8" 282 BBLS ArcticSet IV, 52 BBLS ClassG in 12-1/4 Hole 7 89 BBLS Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 37.6 deg @ 3,929 MD WELLHEAD Tree 2-9/16, 5M WKM Wellhead 11 5M WKM GENERAL WELL INFO API: 50-029-22061-00-00 Drilled and Cased by Nabors 27E 10/9/1990 Frac Pack 9/16/1994 ESP Completion By Nowcam 4907 10/6/1994 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Note: Two runs of 6 SPF perf guns required in the same interval. FRAC STIMULATION DETAIL Stimulation: Frac Pack 225M lbs of 16/20 Carbo-Lite. _____________________________________________________________________________________ Revised By: TDF 11/3/2025 PROPOSED Milne Point Unit Well: MPU H-01 Last Completed: 10/6/1994 PTD: 190-086 TD =5,645(MD) / TD = 4,529(TVD) 13-3/8 RA Tag @ 4,613 7 14 15 9 9-5/8 12 16 4 PBTD =5,634(MD) / PBTD =4,541(TVD) Est TOC @ 3,600 3 4 11 13 10 2 8 Orig. KB Elev.:35 (Nabors 27E) 6&8 Prince Creek TOC @±4,520 Casing Cut @ ±2,639 1 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / Welded N/A Surface 105' 9-5/8 Surface 36 / K-55 / BTRC 8.921 Surface 2,793 7" Intermediate 26 / L-80 / BTRC 6.276 Surface 5,222 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / TXP BTC 3.958 Surface ±X,XXX 4 Screens 9.5 / L-80 / JFE Bear 3.548 ±2,764 ±3,911 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 ±X,XXX 7 X 9-5/8 LTP 2 ±X,XXX 7 Overshot 3 ±X,XXX Discharge Head: 4 ±X,XXX Pump: 5 ±X,XXX Gas Separator: 6 ±X,XXX Upper Tandem Seal: 7 ±X,XXX Lower Tandem Seal: 8 ±X,XXX Motor: 9 ±X,XXX Sensor w/ 6 Fin Centralizer Bottom @ ±2,700 10 ±2,764 7 Packer 11 ±X,XXX Screens Btm @±X,XXX 12 ±3,911 7 Packer 13 ±4,600 CICR 14 4,620 Haliburton VTL Packer 15 4,637 Seal Bore (3.88 ID) 16 4,740 7 Haliburton BWD Sump Packer OPEN HOLE / CEMENT DETAIL 13-3/8" 500 sx of Permafrost C in 30 Hole 9-5/8" 282 BBLS ArcticSet IV, 52 BBLS Class G in 12-1/4 Hole 7 89 BBLS Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 37.6 deg @ 3,929 MD WELLHEAD Tree 4-1/16, 5M FMC Wellhead 11 5M WKM GENERAL WELL INFO API: 50-029-22061-00-00 Drilled and Cased by Nabors 27E 10/9/1990 Frac Pack 9/16/1994 ESP Completion By Nowcam 4907 10/6/1994 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±3,074 ±3,123 ±2,718 ±2,759 ±49 Future Future ±3,200 ±3,244 ±2,820 ±2,857 ±44 Future Future ±3,362 ±3,396 ±2,952 ±2,980 ±34 Future Future ±3,515 ±3,604 ±3,077 ±3,148 ±89 Future Future ±3,646 ±3,679 ±3,182 ±3,209 ±33 Future Future ±3,713 ±3,758 ±3,236 ±3,272 ±45 Future Future ±3,786 ±3,891 ±3,294 ±3,378 ±105 Future Future Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Note: Two runs of 6 SPF perf guns required in the same interval for Schrader Bluff. FRAC STIMULATION DETAIL Stimulation: Frac Pack 225M lbs of 16/20 Carbo-Lite. Isolated SFD Isolated Kill Line Ram Size: 2-7/8" X 5" VBR Ram Size: Blind Rams Top of Cellar Box Choke Line 2-7/8" X 5" VBR Doyon 14 13 5/8" 5000# 13 5/8" 5000# HYDRIL 13 5/8" 5000# 13 5/8" 5000# Mud Cross HYDRIL HYDRIL 13 5/8" 5000# 13 5/8" 5000# Hydril "GK" 11", 5000# 13 5/8" 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# HCRHCR 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: Convert to WSW 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): 5,250' Casing Collapse Conductor N/A Surface 2,020psi 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 WSW 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 H-01 MILNE POINT SCHRADER BLUFF OIL Prince Creek Tertiary 4,493' 5,146' 4,415' 1,395 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): 10/31/2025 Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-086 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22061-00-00 Hilcorp Alaska LLC C.O. 477B Length Size Proposed Pools: 105' 105' 5.46# / HS-70 / CT TVD Burst 4,555' MD N/A 3,520psi 7,240psi 2,491' 4,479' 2,793' 5,222' 80' 13-3/8" 9-5/8" 7" 2,758' 5,187' Erik.Nelson@hilcorp.com 907-564-5277 See Schematic See Schematic 2-7/8" Haliburton: BWD Sump & VTL and N/A 4,620 MD/ 3,972 TVD & 4,740 MD/ 4,073 TVD and N/A Erik Nelson 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 1:42 pm, Oct 24, 2025 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2025.10.24 14:58:15 - 05'00' Scott Pessetto (9864) 325-665 10-404 * BOPE test to 2500 psi. 24 hour notice to AOGCC. * CBL to AOGCC upon completion of running the log. * State to witness pressure test of SB reservoir cement abandonment plug (cement retainer) to 2500 psi. 24 hour notice. DSR-10/28/25SFD 10/27/2025 * Approved to perform work through step #36. Work after that will require an additional 10-403 to proceed with planned perforations to be isolated isolated from the OA annulus. MGR28OCT25 Yes 28-Oct-2025 Mel Rixse 10/29/25 - - - - - - - AOGCC to witness pressure test to 2500 psi. - mgr CBL to AOGCC upon completion. - mgr End of approved sundry. Additional 10-403 required to proceed from step #36.- mgr Stopping point step #36. Requires 10-403 Requires 10-403 Requires 10-403 Requires 10-403 _____________________________________________________________________________________ Revised By: TDF 9/10/2025 SCHEMATIC Milne Point Unit Well: MPU H-01 Last Completed: 10/6/1994 PTD: 190-086 TD =5,645(MD) / TD = 4,529(TVD) 13-3/8 RA Tag @ 4,613 7 8 9 7 9-5/8 10 PBTD =5,634(MD) / PBTD =4,541(TVD) Est TOC @ 3,600 1 3 5 4 2 6 Orig. KB Elev.:35 (Nabors 27E) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / Welded N/A Surface 105' 9-5/8 Surface 36 / K-55 / BTRC 8.921 Surface 2,793 7" Intermediate 26 / L-80 / BTRC 6.276 Surface 5,222 TUBING DETAIL 2-7/8 Coil Tubing 5.46 / HS-70 / CT 2.49 Surface 4,491 2-7/8 Tubing 6.5 / L-80 / EUE 8Rd 2.44 4,491 4,555 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 4,494 CAMCO KBMG Gas lift Mandrel w/ 1 Pocket 2 4,514 Centri-Lift Check Valve 3 4,515 Discharge Head: Bolt On 4 4,516 Pump Intake 5 4,532 Seal Section 6 4,544 Motor Section 7 4,553 Pressure Gauge Btm @ 4,555 8 4,620 Haliburton VTL Packer 9 4,637 Seal Bore (3.88 ID) 10 4,740 7 Haliburton BWD Sump Packer OPEN HOLE / CEMENT DETAIL 13-3/8" 500 sx of Permafrost C in 30 Hole 9-5/8" 282 BBLS ArcticSet IV, 52 BBLS ClassG in 12-1/4 Hole 7 89 BBLS Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 37.6 deg @ 3,929 MD WELLHEAD Tree 2-9/16, 5M WKM Wellhead 11 5M WKM GENERAL WELL INFO API: 50-029-22061-00-00 Drilled and Cased by Nabors 27E 10/9/1990 Frac Pack 9/16/1994 ESP Completion By Nowcam 4907 10/6/1994 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Note: Two runs of 6 SPF perf guns required in the same interval. FRAC STIMULATION DETAIL Stimulation: Frac Pack 225M lbs of 16/20 Carbo-Lite. 9/16/1994 SFD _____________________________________________________________________________________ Revised By: TDF 9/26/2025 PROPOSED Milne Point Unit Well: MPU H-01 Last Completed: 10/6/1994 PTD: 190-086 TD =5,645(MD) / TD = 4,529(TVD) 13-3/8 RA Tag @ 4,613 7 12 13 7 9-5/8 10 14 4 PBTD =5,634(MD) / PBTD =4,541(TVD) Est TOC @ 3,600 1 3 9 11 8 2 6 Orig. KB Elev.:35 (Nabors 27E) 4 & 5 Prince Creek TOC @±4,520 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / Welded N/A Surface 105' 9-5/8 Surface 36 / K-55 / BTRC 8.921 Surface 2,793 7" Intermediate 26 / L-80 / BTRC 6.276 Surface 5,222 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / TXP BTC 3.958 Surface ±X,XXX 4 Screens 9.5 / L-80 / JFE Bear 3.548 ±2,764 ±3,911 2-7/8 Tubing 6.5 / L-80 / EUE 8Rd 2.44 4,491 4,555 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 ±X,XXX Discharge Head: 2 ±X,XXX Pump: 3 ±X,XXX Gas Separator: 4 ±X,XXX Upper Tandem Seal: 5 ±X,XXX Lower Tandem Seal: 6 ±X,XXX Motor: 7 ±X,XXX Sensor w/ 6 Fin Centralizer Bottom @ ±2,700 8 ±2,764 7 Packer 9 ±X,XXX Screens Btm @±X,XXX 10 ±3,911 7 Packer 11 ±4,600 CICR 12 4,620 Haliburton VTL Packer 13 4,637 Seal Bore (3.88 ID) 14 4,740 7 Haliburton BWD Sump Packer OPEN HOLE / CEMENT DETAIL 13-3/8" 500 sx of Permafrost C in 30 Hole 9-5/8" 282 BBLS ArcticSet IV, 52 BBLS Class G in 12-1/4 Hole 7 89 BBLS Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 37.6 deg @ 3,929 MD WELLHEAD Tree 2-9/16, 5M WKM Wellhead 11 5M WKM GENERAL WELL INFO API: 50-029-22061-00-00 Drilled and Cased by Nabors 27E 10/9/1990 Frac Pack 9/16/1994 ESP Completion By Nowcam 4907 10/6/1994 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±3,074 ±3,123 ±2,718 ±2,759 ±49 Future Future ±3,200 ±3,244 ±2,820 ±2,857 ±44 Future Future ±3,362 ±3,396 ±2,952 ±2,980 ±34 Future Future ±3,515 ±3,604 ±3,077 ±3,148 ±89 Future Future ±3,646 ±3,679 ±3,182 ±3,209 ±33 Future Future ±3,713 ±3,758 ±3,236 ±3,272 ±45 Future Future ±3,786 ±3,891 ±3,294 ±3,378 ±105 Future Future Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Schrader Bluff 4,690 4,735 4,031 4,069 45 1994 Open Note: Two runs of 6 SPF perf guns required in the same interval. FRAC STIMULATION DETAIL Stimulation: Frac Pack 225M lbs of 16/20 Carbo-Lite. 9/16/1994 SFD Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i (~ 0 -' (~ ~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~Bren [] TO RE-SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 LSa December 30, 2011 waien\: Igo- Mr. Tom Maunder �, n �. Alaska Oil and Gas Conservation Commission ►� lr 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal - "'--->. MPH - 01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH-02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH -04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA _ 2.6 9/4/2011 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27 2000 E E C:LORlXMFILM.I:K)C PL E W M A T E R IA L U N D ER THIS M A.R K E R STATE OF ALASKA AL, .A OIL AND GAS CONSERVATION COMMIS$,,..,,I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .. Stimulate x Plugging Pull tubing Alter casing ... Repair well x Perforate Other x Reclassify status 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2542' SNL, 4070' WEL, SEC. 34, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 35 feet 7. Unit or Property n,~me Mi/ne Point Unit 8. Well number MPH-O 1 At top of productive interval 3950' SNL, 2750' WEL, SEC. 34, T13N, RIOE At effective depth At total depth 4322' SNL, 2400' WEL, SEC. 34, T13N, RIOE 9. Permit number/approval number 90-86/94-245 10. APl number 50- 029-22O61 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 115' Surface 2828' Intermediate Production 5257' Liner Perforation depth: 5242 feet 4506 feet 5146 feet 4489 feet Size Plugs (measured) Junk (measured) Cemented 13-3/8" To Surface 9-5/8" To Surface 7" T0C@3600' measured 4711'-4735', 4690'-4711' true vertical 4069'-4088', 4051'-4069' Measured depth True vertical depth 80' 2793' 80' 2491' 5222' 4489' Tubing (size, grade, and measured depth) 2-7/8", HS-70 Coil tubing to 4555' MD Packers and SSSV (type and measured depth) Halliburton 'VTL' Packer @ 3811' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure FFIVF_D Gas Cons. Commission Anch0r;..J 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well O,~erations .. x J Oil x Gas Suspended 17. I hereby certify that th~. foreoo',ag i~ true and/J:orrect to the best of my knowledge. Sicjned'-~;~77-- ~'~/~7~~/("-'"rF/~//~-- Title Drilling Engineer Supervisor Form 10-404 Rev 06/15/8~8 Service SUBMIT IN DuPt' ICATE MP H-01 09/14/94 5,250' MOVE RIG FROM H-04 AND SPOT OVER WELL H-01. NIPPLE DOWN TREE AND NIPPLE UP BOP AND INSTALL 3 1/2" PIPE RAMS. PULL HGR AND SET TEST PLUG. ACCEPTED RIG @2300 HR'S ON 09/13/94. 09/15/94 5,250' CHANGE OUT TEST PLUG AND TEST JT. TEST BOP'S AND SET WEAR RING. TEST CSG. MU BHA #1. ALIGNMENT PIN IN TBG SPOOL DAMAGED W/TEST PLUG. ATTEMPT TO BACK OUT ALIGNMENT PIN. NIPPLE DOWN BOP'S AND CHANGE OUT ALIGNMENT PIN AND PU BOP'S. TEST BREAK ON BOP'S. RIH TO 169' UNABLE TO RIH WITH OUT PUMPING. CIRC AND WASH OUT ICE PLUG F/169-571'. DISPLACING ALL RETURNS TO TIGER TANK. CONTINUE PICKING UP 3 1/2" DRILL PIPE 149 JTS. 09/16/94 5,250' SERVICE RIG. CONTINUE PICKING UP 3 1/2" DP. TAG PBTD @5146'. RIG UP TO REVERSE CIRC. CLEAN SOURCE WATER. DROP RABBIT, POH. TEST CASING, OK. RIG ATLAS AND RIH W/GR/CCL TO 5137. LOGGED UP TO 4500'. POH. MU HES BWD PKR W/4" I.D. AND RIH WITH GR/CCL AND BAKER MODEL 20 SETTING TOOL TO 4870'. LOGGED UP TO 4590 RA TAG CORRECT DEPTH SET PKR @4740'. LOG OFF PKR, POH. NIPPLE UP SHOOTING FLG AND TEST LUB. RIG ATLAS BIG HOLE 3 3/8" JUMBO JET. POH AND RIG DOWN ATLAS. NIPPLE DOWN FLG AND NIPPLE UP FLOW NIPPLE. RIH WITH HOWCO SEALS + JB + MULE SHOE STINGER TO SUMP PKR @4740'. STING IN AND SET DOWN WITH SEAL AND CONFIRM PKR HOLDING. PICK UP AND REVERSING DP VOLUME. 09/17/94 5,250' REVERSE CIRC. POH 100' AND WAIT. RIH 100' AND STING INTO SUMP PKR @4740' (NO FILL). POH AND LAY DOWN BHA. RIG UP HES WELL SCREENS 80' + VTL PKR ASSY, ETC. RIH WITH FRAC-PAC ASSY. TAG SUMP PKR @4740' STING INTO PKR AND SET DN AND PU AND SPACE OUT. DROP 1 5/16" BALL. SET PKR. ATTEMPT TO TEST PACKER. PULL OUT WITH RUNNING TOOL. EXPEND BALL F/DP. RIG UP BJ AND TEST LINES. PERFORM FRAC. UNABLE TO CIRC THROUGH MPT. RIG DN BJ. SET TOOL IN REVERSE CIRC. POSITION CIRC AND ESTABLISH CIRC AND DEBRIS OF SOME UNKNOWN SOURCE PREVENTED CIRC. RE DO CIRC. TEST IN NEUTRAL POSITION. RE-STRESSED SCREENS. BLEED DOWN AND PU AND REVERSE OUT. REVERSE 2 X DP VOLUME. WELL FLOWING BACK. BLEED. DATA FRAC FLUID TO TIGER TANK. CONTINUE TO BLEED OFF WELL FOR KILL. EC'EIVED 09/18/94 5,250' CONTINUE TO FLOW BACK FRAC PAC THROUGH CHOKE. FLOWED A TOTAL OF 224 BBL. SMALL AMOUNT OF OIL AND GAS TO SURFACE. KILL WELL. MONITOR WELL BORE HAD SMALL AMOUNT OF FLOW F/ANNULUS. DISPLACE WELL WITH 9.0 PPG BRINE W/8% MEOH. RIG DOWN BJ. FRAC HEAD. POH LAYING DOWN DP AND HES FRAC TOOLS. PULL WEAR RING AND SET FMC FALSE BOWL W/BPV FOR CTU COMPLETION. NIPPLE DOWN BOP'S. 09/19/94 5,250' NIPPLE DOWN BOPS. NIPPLE UP ADAPTER FLG AND 1 7" FULL BORE VALVE. TEST ADAPTER FLANGE WITH COOPER. SECURE WELL. RELEASE RIG @0900 HR'S ON 09/18/94. RECEIVED NOV ~,la~t~a. (.ii~ & Gas Cons. ('.;o~nmissiort A~chor: Page I brand fe.x transmittal memo 76'71 I# o, pages, ~ Post-Ir' I Dept. lah~ne ~, [I~ax ~ JFax .~ BP EXPLORATION (ALASKA) INC. PRUDHOI~ BAY PRODUCTION ENGINEERING I;)EPARTMENT TO: PHILLIPS FROM: MELVAN / IBE / CHAN DATE: 9116/94 RE= MPH-01 DATA FRAC AND FRAC ("N" SAND) SERVICE CO'S.: BJ, Peak JOB SUMMARY ~l ' ' ~ , ,111 . I ' , , INJ ECTIVITY TEST Design Re're, ab'la Mat Rate, Final STPZ, ISlP2', Nwa Treat grad'~ _. BPM, Pu, mped .bpm .... psi PSI frictionr psi ps, lift ., 15 , 93 31.5 2138 1789 .77 DATA FRAc #1 Bbls 'BblS XL"'gel Time XL gel Final S~"P, 'ISIP, ps'l Nwa' Treat grad, Pump.ed to Parrs on perfs psi f..rlction, ps! psl/ft 25,0 247 16.47 2400 1200 .7~; DATA FRAC #~ Bbis Bbl~ XL gel Time XL gel FIn'RI STP, iSIP, psi ' NWB Treat grad, Pumped to Perfs on parrs psi friction, psi psl/ft 200 147 . ' 7.9 3750 ' '1230 1789 .77' , ., Sa, nd Lead prop Tall pro~ Design total pumped, behind behind behind pipe, Liner Job was M# piper M# piper M# M# Sand~ M# Talloffr M# Flushed ". 225,000. 223,400 N,A "223~5400' .., 1600 .... , Pt of Estimated Final ISiP, psi ISIP Incr " Actual TSO,' TS0, sand In sand top $'[P, over sand:pad design, rain Nolte PI po., psi dst a/r a c ratio Plot Rev. No~le 2344 NA NA 54.8 .... 9.84 · O[3erational problems Crossover tool did not quite function as espected. Either trash around it or malfunction prevented from circulating when it was slacked off onto the packer. When picked up to neutral weight, normal circulatoJn down dp and into the annulus via. the gravel pack screen was achieved (circulating position,. No problems observed in the tool's VED 'reversing' position. Too, will be examlnecl after being pulled out of the hole for final determination. R E C E I ?"",",/ - 2 1994 . Gas Cons. C0~Jssi0 Anchor: Page Comments A second dat~ frac was pumped @ 25 bprn based on the result.¢ of the first. The two data frac5 indicate treat more than 15 bpm may be required to breach shale stringers for a muki-zone frac, Reservoir was severly pumped up after the job which made it irnlDossible to kill w/9 ppg brine again. Well had to be bled back to tl~e pi[s to remove the frac energy around the wellbore before the 9 ppg brine could be ci,'culted back In. " Ot~.ERA~iONS" ,.~., , ,, __ .. SUMMARY L_ DATEI~'IME ~' ,', ,', . ......... ,,, ......... 09/16194 PRE-FRAC M, IRU frae, vaeLpump. A,,MBIENT..=.(-28), SIWHP= 0~ lAP= 0, CAP= 0, 09:00 PU Screen & HALCO Packer. RIH w/3-1/2 DP 15:30 Tag sump packer @ 4628, String wt 75,000#. Pull out of sump packer and space out for rig floor. ,. ~,tin,g back In. RI.I B,J .frac iron to rig floor, Set .p. acker. , ..... 17:00 P.T csg. i~ol~tion ball sheared out @ ,3600 PSt-900 PSi ~arly. Pull res[ on pa, cker. PU to .~ reverse positio, n. Hold?nfety mtg. . , , , 18:00 Picle DP @ 2 BPM W/11 .B BIlL 15% liCE Reverse back acid to rig slop tank using riD mud pump. Pump 30 BBL slick water b~ck awn DP to save 9 PPG brine. Set dwn into inj/circ position., , ,. 18:53 Regin XL breakdwn & inj te~t. Discovered crossover [ool to annulus plugged. Cont. w/data -, collection, T,,r¥ to uplu9 tool with, out success. , ..... 22.00 Frz prtoect BJ. PU in reverse position. Circ DP to brine-monitor returns. Discovered circ possib!.,e, with weight off of seal assem, bly locater, Circulates fine. .. ~01,22 . Proceed w/second data frac .~ 25 bpm,,. ........ d§/17/~4 FI:lAC ~--~, , , 11, ..... _. ~.-. ..,,,, ,=, ..... 02.16 pump frac .as per rev.!s0d TSO. Well ch~rgecl up after frac-flowed beck hard. T~ to bleed. , ..-.. 05.30 ,,SECURE WELL. S! ,W. HP= Rig.bleecling back.. I^P= NA. CAP-- O. RDMO frac, vac, pu .rap. 09/'1 6/94 XL Breakdown DISPLACEMENT = 31 BBLS i i .~1 il i i ....... , Ul, 18.53 0/ 0 0 Esta,,bli~h Rat, e, Start XL. ,, 18.53 22.8 . NA ...... 31'98 . 15/0 15 StageXL 18.57 27.1 4031 1B.57 60~O 75 .-,Stage flush w/30# 1--8.58 . 31 .... 4,396 31 106 Linear gel @ pars. Proc_e. ed to injectivily test,. 0/ 0 I Smr,t,inioetiuit~ to~t w/30# ~9:00 ~5 2200 55 .... Slow to 15 bp.,m ,,, 1~.0~ ,,, 15 ,,, 2200 70 .,176 ,, Sd. ,,Monitor WHP, ,,~SlP = !,~,2S psi,"~:~l~a ~'r~c t~, ~ 4 , ,~40 022 ...... End monitor WHP. Crossover tool plugged? 1~. ~ 4 .,2 10 12~ 0 Purer in circulation p~,Fltion. 19.16 2 " 1236 Cross.er looks plugged. Use rig pump and pressure .., csg to 1800 p~i-very little clrcu~.t!on bk up dp., 2 1994 Con,~. C0mmissi~ 10r~ : 9.41 4/0 10 1450 17.8 194 Stop pumping-still looks restricted 19.46 MIN 2000 0 Rig pump dwn annulus again-very little circulation. Cycle Drilq31pe .............. ~' _~ .... ;~-- 20,04 2 1138 .... ._C__i.r_c_u_late_d_.w...n.,d, p egaln,-se, me restr, lctlon. DIscuss. DATA FRAC#1 ~ 7- .~ 7 '- ............ , ................. - .... 20.2,3 0/ 387 2197 0 194 ,,Est rate w/404f gel 20.2,* 15. t ,*62 2167 15/0 209 .. Stg 3.0. ~..XL gel pad 20.26 15,5 973 2099 31 Pad @ perfs 20,31 15,0 1102 2109 100 20,36 15 1092 2079 175 , 20,41 15,1 1007 2100 250/0 459 Stage flush w/30# linear gel. 20,43 " " 28 487 SD pumps, I$1P--1200 Monitor WHP. Useable SW on site-- 1120 bbls Closure time 4.2 min. STEPRATE TEST DISPLACEM'£NT = 3X BBLS 21.18 0/1,5 968 1167 0/ Start slap rate test w/30# gel 21.21 2 978 1187 6/0 493 Inc rate 21.23 2.5 981 1236 4/0 497 lac rate ~1.~5 3 976 1275 5/0 502 Inc rate 21.;~7 3.5 981 1324 6/0 506 Inc rate .21,.29 4 988 1354 7/0 5!_15. ......... !n_~.._r_a_t@_.. 21.31 4.5 1012 1403 I~/0 523 Inc rate 21.33 5,0 t034 1462 9/0 532 Inc rate 21.35 6 1054 1540 10/0 542 lac rate 21.38 7 1073 1628 12/0 554 lac rate , 21.40 8 1080 1687 14/0 568 21,41 8 1044 1148 16/0 584 Shutdown. iSIP psi ............... 21.49 2 ........ ,0.,._ 1250 3 587 Attempt circ throul3h rev too,!_._e_galn,?,s, till restricted. DATA FRAC #2 01 .:::'2 O/ 0 587 Est rate w/40# ,q$1 ............. .-.- 01,24 19,6 1105 3041 15/0 602 Stg 30~ XL gel pad !01,25 25,2 1134 3531 31 Pad @ parrs i01.27 25,1 1212 3492 100 01.31 25.1 1141 3521 200/0 $02 Stage flush w/30~ linear gel, · .............................. 01.32 25.0 1144 3776 27.3 829.3 SD pumps. ISIP-- 1230psi. MonitorWHP, Useable SW on site = 960 bbls. Closure time 3.5 rain ECEIVED ,.,"~' ,"',,.., 9 'i994 · . ~,. ,;.~,, ,,,~ & Ga.,; Cor~s. Commission Armhor: Page 4 FRAC I I II II .l ,lllq . I 02,16 15 1068 3100 0 829 Establish rate with 40¢ gel :1 .1 I , O2.17 14.9 . 1006 2952 i5/0 844 Sta§e pad ...... __ 02.24 ". .... 95/0 939 Stage 1 ppg 16/20 CL ..... 02.26 14.8 1148 2079 31 __ 02.26 14,6 1161 g040 36/0 975 Stage 2 ppg , i02.27 14.7,, 1163,, 202i. 5/0 , 980 3 ppg. .-. 02.27 14,6 1173 1981 10/0 .990 4 ppg ..... !02.2,7 14.6 1!7,3 1981 15,/0 ?95 5 ppg ....... 02,28 14,6 1185 2109 '20/0 1015 6 pp.q - i i Iii i0~.81 1190 ~236 26/0 1041 7 ;02.34 , 1197 2:~85 31/0 1072 8 ppg ..... 02.35 , 14.5 , 1182 2285 31 ,._ 8#qn pads ...... 02.36 1190 2285 35/0 1107 9 02.38 ,,, 1182 2.276 31 . 9# On peas , 02,39 1182 2286 39/0 1146 10 ppg 02.41 , 1122 2256 31, , t0# on parts , ,. 02.4'1 , 1 t 85 2236~ 43/0 1.189 1'1 ppg , 02.44 " " 31 11# on perfs I ,. I Ii ,1 ii 02.,45 1187 2246 46/0 1235 12 . i I I ii I It 02.4,7, 1190 2256 31~ ,, 12# on parts 02,50 1197 2276 , 75 02.52 14.4 1202, 2258 1 oo 02. 55 1212 2276 150 02.59 _ 1221 2256 . 200. _, _E, xceedin~;I origins! design ., 03.02 1231 2266 250 103.05 1246 2285 300 03, O 9 1268 2305 350 · iii . II 03.12 1287 2315 400 o3:1,7 n2,ee 22,,,95 4To cut king. Pump.!.,0bbl non ,"XL" 12 ppg. ,,. 03.18 1319 2344 486/0 ._ 1721 Stage flush 03.20 2 1324 28 Reduce rate. Prep to gravel p.,,ack. 03.23 0 400 2600 ,,, 31 Shut dwn after dp pressure rise. Monitor bleed off 03.27 Nil 3300 31.2 1752 Pressured up immediately. Try to bleed off iA. Well flowing back hard through screen & pack due to being charged up.., !03,45 6 800 , ,, Reve..rse out ~ to slop t,ank with rig pump 04.00 0 Well ~till flowin~ baok hard. 04.30 Bleed casing off ag~zin. Gassing a little. Continue to bleed off. , , Gas 6on~. 6ommissior~ Anchor: Page 5 FLUIDS PUMPED .DOWNflOLE 'XL' BREAK DWN: 106 BBL INJ TEST: 194 BBL STEPRATE TEST: 94 DATA FRACs 1 &2: 535 BBL FRAC: 923 BBL 1852 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 0 100 Diesel to IA, tubing, or, GC Diesel Recovered (not downhole) Total Diesel , _ , i~ETRE~AT Wi'NDOw ...... , .... INO'NE · , . , ..,r ' ~EL' QUALITY' CONTROL CHECK lift II H20 H20 30~ GEL' 30# GE'L P I ~ E X L ' ~ L pH TEMP pH VISCOSITY. TIME TIME pH D F/FRAC... 7.S6 10~ "'7.81 28/32 " 2.07 9.59 ii i I. i ' 'l il FLUID ADDITIVES BJ SPECTRA FRAC G3000 FLUID SYSTEM WITH .5-1 GPT BF-7L BUFFER, 2-3 GPT GBW-12 BREAKER, 1-2 GPT NE-18 NON EMULSIFIER NO ESL PUMPED. RECEIVED NOV -2 OJJ & 6as Co,~. C~mmJssion Anchor: To: From: Well: ROSSBERG ROBERTSON / FOX / WHITLOW / CRAWFORD Location' ANCHORAGE Date: 10-06-94 MPU H-01 Operation: 2 7/8" COILED TUBING ESP COMPLETION W/HEAT TRACE I Main CategorT: DRLG - AFE330045 wellStatus: Shutln IWHP(psi) 0 I IAP(psi) Sub Category: CTU COMPLETION ! ]GLP(psi) NA ]OAP(psi) 0 IWHT(°F) +5 ITM I OPERATION I 10-06 RIG UP NOWCAM 4907. SET 7 1/16" BOP AND CT WINDOW SECTION WITH PBU 90 TON CRANE. WORK 14.00 WINDOW NOW HAS 2 SUPPORT LEGS IN FRONT. 2" LINES TO 2 TIGER TANKS. SET 16 K. "DEADMEN" IN BACK, 10 K IN FRONT AND STRING GUY WIRES. SPOT UNIT AND INSTALL COIL TUBING REEL # 2143 WITH 8018 FT OF 2 7/8", 0.190" WALL, 5.46 LB/FT HS-70 CT. SPOT ACCUMULATOR DSR SKID AND GENERATOR. RUN LINES TO BOP. 10-07 TEST BOPE. STATE INSPECTOR ON LOCATION, TEST PIPE RAMS,TO 300 PSI AND 3000 PSI. TEST 03.30 HYDRIL TO 300 AND 1500 PSI. CHANGE LOCATION OF 2" CHOKE LINE. TEST CHOKE LINE AND CHOKE MANIFOLD~ TEST LOWER BLIND/SHEAR RAMS W/300 AND 3000 PSI. 09.30 TEST UPPER BLINDS - OK. BOPE FINALLY PASSED STATE INSPECTION. 11.10 WRAP TARP AROUND BOPS AND HEAT ALL RETURN LINES FOR BRINE / MEOH RETURNS [5 DEG FRZ] 12.00 PICK UP PRESS-GAUGE, MOTOR, AND INTAKE. PERFORM ALL MOTOR Q/A ON FLOOR. PU PUMP SECTION & BOLT ON SAME. 15.10 PREP CT REEL AND PICK UP 54" SHEAVE FOR CENTRILIFT ESP POWER CABLE. 16.21 M/U FLATELEC. POWER CABLE TO MOTOR. 18.00 BEGIN MU 2' PUP, CENTRILIFT CHECK VALVE, 2' PUP, 10' PUP, 2' PUP, XO, CAMCO GAS LIFT MANDREL, XO, 2' PUP AND CT CONNECTOR, ALL CONN. MADE UP TO 1700 FT-LBS. WITH HYD RAMS. 19.44 FINISH PUMP BHA M/U. PULL CT THRU INJ HEAD WITH INTERNAL CONN. SET INJ HEAD ON WORK WINDW. 23.42 RU 1502 CONN ON COIL. [NOT ENOUGH ROOM AT CT REEL 1502 CONN. TO MAKE UP HARDLINE.] - HOT WORK PERMIT, HEAT AND BEND CT END. BEGIN RU LINE TO TANK TO PURGE COIL. 10-08 PUMP 70 BBLS (20 BBLS OVER COIL VOLUME) METHANOL INTO COIL 2.4 BPM 575 PSI, W/LITTLE RED. 00.50 02.07 PRESSURE TEST COIL TO 4000 PSI. OK. RU CTC. 03.51 PULL TEST COIL TO 28,000 LBS. OK. PRESSURE TEST COIL TO 2000 PSI. HOLD FOR 5 MINUTES 03.56 GOOD TEST. EASE TOP OF CTC TO TOP OF SLIP BOWL 04.17 BEGIN TIH AND BANDING ESP CABLE AND COIL EVERY 20', WITH AIR BANDER. 05.25 1000' OF COIL IN WELL. NO FLUIDS RETURNED UP ANNULUS. ESP RESISTANCE TEST - OK. 06.48 2000' OF COIL IN WELL. NO FLUID RETURNS UP ANNULUS, ESP RESISTANCE TEST - OK. 07.20 PICK UP SECOND 54" SHEAVE FOR HEAT TRACE, SHEAVED WAS JAMMED, REPAIR SHEAVE AND INSTALL AT TOP OF WORK WINDOW. TEMP AT -2 DEG F. HEAT REEL OF HEAT TRACE [-20 F RATED]. 10.00 RIH TO 2190 F r CT MEAS. [PUMP AT 2257 FT CTD]. START BANDING HEAT TRACE TO CT. 11.10 AT2221 FT. CONT. RIH. NOANNULAR RETURNS [PERFS TAKING FLUID-BALANCED]. 13.52 AT 2510 FT. [AVE OF 2 FPM LAST 2.5 HRS~ SHUT DOWN FOR 30 MIN. TO TEST LINES]. 14.23 AT 2616 FT. [AVE OF 3.5 FPM LAST 30 MIN.]. WT CELL IS NOT WORKING [SHOWS 2900 LBS1 CALC =15K] 14.50 AT 2671 i- I1 TEST HEAT TRACE CABLE - OK. CRANE HOLDING 6000 LBS UP WT. 15.40 AT 2822 FT~ AVE OF 3 FPM LAST 50 MIN. BAND ESP EVERY 3 TRAYS [18 F-i-]. 16.35 AT 3000 FT. ESP AND HEAT TRACE RESISTANCE TESTS - OK. AVE HEAT TRACE SPEED = 2.2 FPM. 17.35 AT3140Fl'~ AMBIENT= 10 DEG. 18.41 AT 3430 FT, LAST HR RATE = 4.3 FPM, USING 3.5" DP WIPER AS HOLE COVER, WORKS WELL. 18.55 AT 3500 FT~ RES. TEST HEAT TRACE [EVERY 500 F-I-] - OK. 19:50 BEGIN TIH 21.30 AT 4000'. TEST WIRES. OK. 23.50 AT 4421' CTD. INSTALL SLIP BOWL. MEASURE TUBING HANGER AND PUP AND COILED TUBING CONNECTOR FOR SPACING OUT 10-09 UNABLE TO PICKUP. TROUBLE SHOOT HYDRAULIC PROBLEM TO BRAKE, SAME LOCK UP PROBLEM 02.00 AS ON LAST JOB. NEED TO FIND SOLUTION. TEXAS EQUIP. IS LOOKING AT PROBLEM. 03.31 REPLACE HYDLINES. PU TO SPACE OUT. CUT COIL. MU CTC. 5' PUP, TBG HGR, LANDING.JT_.A._ND CT. MPU H-01, CTU ESP COMPLETION W/ HEAT TRACE RECEIVE[ PAGE 1 NOV -'2 199z~ (1[I & Gas Con~. Commission 'j'""TIME I OPERAT, ON 08.36 PT TO 3000 PSI. OK. BEGIN MAKE UP HEAT TRACE CONNECTION TO TBG SPOOL PENETRATOR.- OK. 09.50 START ESP SPLICE FOR PLUG BELOW TBG HANGER. 13.09 M/U SPLICED ESP PLUG TO BTM OF PENETRATOR. TEST RESISTIVITY. OK. 13.30 RIH THRU BOPS WITH TBG HGR, NO PROBLEM. 13.40 LAND TBG HANGER ON DEPTH [22 FT BELOW HAND SLIPS]. 14.00 UNABLE TO SET FMC HOLD DOWN SCREWS. PU ASSEMBLY AND DETERMINE HGR BODY IS 1/4" LONG 14.40 BEGIN GRINDING ON SET DOWN RING ON TUBING HANGER. GRIND 1/4" OFF FULL 360 DEG. 15.02 TIH 15.06 LAND HANGER, HOLD DOWN SCREWS SET OK. 16.20 PRESS TEST TBG HANGER, LOCK DOWN SCREW LEAKING, RE-P/T, HARDLINE LEAKING, RE-P/T, REPAIR SAME, RE-P/T, HARDLINE LEAKING, RE-P/Tt HELD 2000 PSI FOR 15 MIN. -OK. NO PRESS LOSS 18.52 BLEED DOWN BOPS, CUT CT AND BACK OUT LANDING STRING. 20.00 INSTALL 2 WAY CHECK VALVE [ 2 1/2" TYPE"H" PROFILE]. NO PROBLEM. 20.25 RIH WITH CT AND CLOSE ANNULAR. BLOW CT DRY WITH N2 BOTTLES TO TANKS USING FOAM PLUG. 22.00 GIVE UP ON DISPLACING WITH N2 FROM BOTTLES. RIG DOWN 4907 CTU. PICK INJ. HEAD. 23.30 PICK WORK WINDOW AND LOAD ON TRAILER 10-10 03.00 PICK UP BOP STACK AND LOAD ON SKID. LOAD SKID AND DSR SKIDS ON BED TRUCKS. LOAD 4907 ON PEAK SQUAW. LOAD TWO NOWCAM DEADMEN AND HAUL TO NOWCAM. LEAVE TWO 16000 LB DEADMEN ON H PAD. 03.30 ND 7 1/16 WORKING VALVE~ NU FMC 2 9/16" PENETRATOR SPOOL~ PRESS TEST 5000 PSI~ 20 MIN. OK. 04.30 N/U 2 1/2" TREE. 05.30 LEAVE LOCATION. WELL SHUT IN WITH 2 WAY CHECK VALVE. RECEIVED ~.lasi~a. (iii & Gas Cons. Commission Anchor: ,, MPU H-01, CTU ESP COMPLETION W/ HEAT TRACE PAGE 2 MPU H-01: OPERATIONS SUMMARY 10-06-94 1. R/U 4907 CTU AT 1400 HRS, 7 1/16" DSR BOPS, WORK WINDOW WITH SUPPORT LEGS, USING PBU 90 TON CRANE. SPOT DSR SKID AND GENERATOR. RUN BOP HOSES AND GUY WIRES TO 4 DEADMEN. 10-07-94 2. PRESS TEST BOPS WITH 300 AND 3000 PSI. FINALLY PASSED BOPE TEST. SLIGHT LEAK DOWN THRU 7 1/16" WORKING VALVE. 3. RAN CENTRI-LIFT TYPE F0-650 SERIES 513 PUMP W/MODEL KME, SERIES 562, 65 H.P. MOTOR SECTION AND CENTRILIFT CHECK VALVE, 2 FT ABOVE PUMP DISCHARGE. RAN CAMCO TYPE KBMG-M GAS LIFT MANDREL W/1" POCKET AND DCK GAS LIFT VALVE IN PLACE [SET TO SHEAR AT 3500 PSI DIFF PRESS.], 14 FT ABOVE CHECK VALVE. RAN FULL BHA WITH 90 TON CRANE. STAB 2 7/8" CT INTO INJECTOR AND LAND INJECTOR ON WORK WINDOW WITH 90 TON CRANE. 10-08-94 4. PURGE CT W/70 BBLS MEOH/WTR, P/T CT WITH 4000 PSI. R/U CT CONNECTOR, PULL TEST 28K. 5. RAN 2 7/8", 5.46~, HS-70 CT, BANDING ESP NO. 2 CABLE [1.22" OD] EVERY 20 FT. . STOP AFTER RUNNING 2190 FT OF CT IN WELL. R/U RAYCHEM HEAT TRACE EQUIP. AND RANFLAT [ 3/8" X 1 1/8" ] HEAT TRACE CABLE INSIDE [5/8 X 1.5 "] CABLE GUARDS. BAND CABLE GUARDS AT 3 BANDS PER 6 FT GUARD. INCLUDING FLAT GUARD BANDS. RAN PREFORMED BANDS TO FASTEN CABLE/GUARDS TO COILED TUBING. CONT. TO BAND ESP CABLE EVERY 18 FT AND HEAT TRACE WITH GUARDS EVERY 2 FT. RIH BANDING HEAT TRACE GUARDS AT 2.2 FPM AVE. RATE. STOP AT END OF HEAT TRACE. 10-09-94 7. SPACE OUT FOR TBG HGR. UNABLE TO PICK UP. INJECTOR BRAKE LOCKED AGAIN. REPAIR INJECTOR. 8. MAKE UP PUP, TBG HANGER AND LANDING STRING, CONNECT TO CT. M/U HEAT TRACE AND TEST OK. MAKE SPLICE FOR ESP PLUG CONNECTOR BELOW TBG HGR AND TEST OK. . LAND IN FMC 7 1/16" X 2 7/8" TUBING HANGER. BOTTOM OF PUMP ASSEMBLY AT 4555 FT BKB (LANDING NIPPLE IS 33' BKB, 2265' (RAYCHEM FOOTAGE NUMBER) COIL BANDED WITH HEAT TAPE AND ESP CABLE, THEN 2190' (CTMD) OF COIL BANDED WITH ESP CABLE AND 67' OF BHA. TOP OF TBG HGR 1/4" HIGH FOR TBG HOLD DOWN SCREWS, POOH AND REDUCE TBG HANGER COMPRESSION SLEEVE BY 1/4". RE-LAND TUBING HANGER OK. PFF TBG HANGER WITH 2000 PSI [15 MIN], AFTER SEVERAL SURFACE LEAKS. BACK OUT LANDING STRING. INSTALL 2 WAY CHECK VALVE. 10. ATTEMPT TO BLOW CT DRY WITH N2 FROM BOTTLES. USE VAC TRK TO SUCK DOWN BOPS, HARDLINE AND TIGER TANKS. RIG DOWN INJ HEAD, WORK WINDOW, BOP STACK, 7 1/16" WORK VALVE. R E C E! 11. N/U FMC PENETRATOR SPOOL, P/T FLANGE AND TBG HGR - OK, N/U 2 1/2" TREE. NOTES: ED 1. 7" CASING FILLED WITH 9.0 PPG BRINE / 8% MEOH GOOD TO +5 DEG F FRZ POINT. HEAT 2" RETURINncho LINE AND BOPE WITH HEATERS AND TARPS TO PREVENT FREEZE UP OF DISPLACED BRINE. 2. CAMCO DCK GAS LIFT VALVE SET TO SHEAR AT 3500 PSI DIFF, SET IN CAMCO KBMG-M 2 7/8" MANDREL. 3. CALCULATED BOTTOM OF PUMP BHA AT 4,555 FT BKB. [ 67 FT BHA, 2190 FT CT W/ESP, 2265 FT CT W/ HEAT TRACE, + 33 FT BKB BTM OF TBG HANGER = 4,555 FT BKB ]. MPU H-01, CTU ESP COMPLETION W/ HEAT TRACE PAGE 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: DATE: David J~ Chairma~.-.~--~ Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi,~ SUBJECT: Petroleum Inspector FILE NO: October 7, 1994 AW9JJGBD.DOC BOP test Nowcam CTU #4907 BPX well # H-1 Milne Point Unit PTD #.94~2'45 ~ ~ "- ~ ~"" (~ Friday, October 7,1994: I traveled to BPX's well # H-1 in the Milne Point unit to witness the BOP test on Nowcam's coil tubing unit # 4907 which was preparing to run the tubing completion on this well. The rig was ready to test when I arrived. I made a cursory inspection of the equipment and found a fairly solid rigup although there was no protection of the BOPE from the weather. I inquired what the completion fluid in the well was and I was informed that it was a 9.0 brine with a freeze point of 5 deg. F. The ambient temp was 7 deg. F and the outlook was for as cold or colder temperatures. I required that the entire BOPE including the choke and lines to the tank be shrouded and heated with a spare heater to be on location. During the test one of the heaters went down of its own accord and the spare was brought in. The test went slowly due to the 7" master valve on the bottom of the stack that they were testing against would not hold pressure from the top and although the decline in pressure was small it necessitated a visual observation of all the possible leak points. There was 1 failure, this being the Blind Shear rams, there was a set of blind rams above these that tested "OK". The rest of the BOPE tested out good. I discussed possible problems encountered if the assembly had to be pulled out and the procedures for strapping the pump conductors and heat trace to the coil tubing. SUMMARY: I witnessed the BOP test on Nowcam's coil tubing unit # 4907 which was preparing to run the tubing completion on BPX's well # H-1 in the Milne Point unit. Test time 6 hours, 1 failure. Attachments: AW9JJGBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: Completi X Drlg Contractor: Nowcam Rig No. 4907 PTD# Operator: BPX Milne Point Rep.: Well Name: H-1 Rig Rep.: Casing Size: 7+ Set @ Location: Sec. Test: Initial X Weekly Other q~'~° DATE: 10/7/94 94~5 Rig Ph.# Rick Whitlow/Dan Robertson 34 T. 13N R. 10E Meridian Umiat Test MISC. INSPECTIONS: Pressure P/F Location Gen.: Well Sign OK 0 Housekeeping' (Gen) Drl. Rig Reserve Pit BOP STACK: Annular Preventer Pipe Rams Blind Shear Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Methane Gas Det. H2S Detectors FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP N/A Lower Kelly / IBOP N/A Ball Type N/A Inside BOP N/A Test Quan. Pressure P/F Test 1 300/3000 P Pressure 3 300/3000 1 300/3000 P 1 300/3000 F 1 300/3000 P 1 300/3000 P 1 300/3000 P Visual Alarm CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 8 3OO/3OOO P 1 N/A Functioned Functioned P/F P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Four bottles 2500 Average 3000 I P 1950 P minutes 20 sec. minutes 55 sec. X Remote: N/A Psig. Number of Failures 1 Test Time 6 Hours Number of valves tested ,5 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Blind/Shear rams failed pressure test. Maintain equipment above freezing temperature. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AW9JJGBD.XLS Louis R Grimaldi LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 September 1994 RE: Transmittal of Data ECC #: 6272.00 Sent by: U.S. MAIL Data: PL Dear Sir/Madam, Reference: MPH-01 MILNE POINT (SCHRADER BLUFF) NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/GR/CCL FINAL BL Run # 1 1 GR/CCL FINAL BL Run # 1 1 PFC/GR/CCL RF SEPIA Run # 1 1 GR/CCL FINL.RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Att R ney D. Paulson Received b STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing Repair well x Plugging __ Time extension__ Stimulate x Change approved program __ Pull tubing __ Variance __ Perforate __ Other x __ Reclassify 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 35 feet 7. Unit or Property name Mi/ne Point Unit 4. Location of well at surface 2542' SNL, 4070' WEL, SEC. 34, T13N, RIOE At top of productive interval 9. 8. Well number MPH-O 1 Permit number 9O-86 10. APl number 5O- 029-22061 3950' SNL, 2750' WEL, SEC. 34, T13N, RIOE At effective depth At total depth 4322' SNL, 2400' WEL, SEC. 34, T13N, RIOE 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5242 feet 4506 feet 5146 feet 4489 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 115' 13-3/8" To Surface Surface 2828' 9-5/8" To Surface Intermediate Production 5257' 7" TOC @ 3600' Liner Perforation depth: measured Not perforated true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) None ORIGINAL Measured depth 80' 2793' 5222' True verticalde~h 80' 2491' 4489' SEP-9 1994 0il & Gas CoDs. Commission Anchorage 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 9/10/94 16. If proposal was verbally approved Oil__ Gas__ Name of approver Date approved Service Test Well 17. I hereby certify~at the., foregoingjs true and correct to the best of my knowledge. Signed 74\/t',~. (~; L~-,;'-¥~_ Title Drilling Engineer Supervisor 15. Status of well classification as: Suspended Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ff o ~ Original Signed BT. IApproval No. ~ c~ ._ 2_ ~ ~ Approved by order of the Commission David W. Johnston Commissioner Date ~/ ~)//4;~/,~ SUBMIT IN TI~PLI6ATE ~ Form 10-403 Rev 06/15/88 Approved Copy Returned MPU H-01 RWO and Frac-Pak Objective: The objective of this workover will be to perforate the "N" sands and perform a Work Outline: 1. MIRU Nabors 4ES. N/D tree. N/U and test BOPE. 2. RIH with bit and scraper on drillpipe to PBTD. The well was suspended with a 22 bbl diesel cap and 9.2 ppg NaCI brine (approx. 175 bbl). Isolate the diesel cap from brine as returns are taken from the well. Fill pits and remainder of hole to 9.2 ppg NaCI brine. Filter all brine in wellbore and pits. POOH 3. R/U E-line. Perform junk basket / 6" gauge ring run to PBTD. Set sump packer at 4740' MD. 4. RIH and perforate "N" sands at 4-1/2" gun @ 12 spf from 4690' - 4735' MD. 5. RIH with wash extension. Tag packer, check for fill and wash through packer. POOH and L/D wash extension. 6. RIH with gravel pack assembly on drillpipe to sump packer. 7. Test lines to 6500 psi. Perform data frac, sand frac and gravel pack on "N" sands per procedure. Displace sand with 9.2 ppg NaCI brine and 20 bbl diesel. 8. RDMO Nabors 4ES. 9. R/U Coiled Tubing Unit. Run new ESP and heat trace on 2-7/8" tubing. N/U and test tree. 10. R/D Coiled Tubing Unit. RECE'IVED SEP --~9 1994 /~lask~ 0ii & Gas Cons. Commission Anchorage, SCHLUMBERGER WELL SERVICES A DIVISION OF ~-..HLUh4BERGF_R TECHNOL(X~Y COR~RATION ~USTON. TEXAS 77251-2175 ~E REPLY TO ~ouch 340069 ~=udhoe ~ay, A~ 99734-0069 CONOCO, Inc. 3201 i'C" Street, Suite 200 Anchorage, AK 99503 A, Hention: .Marc Sha~lnon Gentlemen: Enclosed ore 2 P,l. prints of the. Company CONOC.Q,. Inc. Well Milne Point Unit H-1 Field Milne Poi nt /Schrader B1 ;,fl_. County Ad<Jitionol prints ore being ~ent to: 1 BL prints CONOCO, Inc,. ..... 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER DIT-E, NGR, CNL (RAW/PORO), Run 1, 9/12/90 .on: North Slope State, Alaska ..... _l_BL_prints, 1 RF Sepia CONOCO. Thc_ 1000 South Pine Ponca City, OK 74603 ..Attn: Log Library /" OXY U.S.A., Inc. ,' 6 Desta Drive '. ~, Midland. TX 79710 'x ....... At,n:, John Carr01 · _l~rints, 1RF Sepia Chevron U.S.A. 6001Bollin[er Canyon.Road San Ramon, CA 94583-0943 Attn: .Priscilla MacLeroy *(415/842-1OOO) 1 BL prints, 1RF Sepia Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: John Boyle The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Alaska 0il j Gas Cons. - ,~,unOmm~"s'-n Anchor~o Received by; Very truly yours, SCHLUMBERGER WELL SERVICES Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 8, 1993 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: H-l; WELL COMPLETION OR RECOMPLETION REPORT AND LOG Dear Mr. Johnston, Pursuant to a recent conversation with Mr. Steve McMains, attached are two copies of Well Completion or Recompletion Report and Log, Form 10-407, and associated information for Milne Point Unit Well H-1. Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist attachments CC: BGA, TJY H-1 Well File Chevron Occidental RECEIVED DEC 1 0 199¢] Alaska U~ & 8as Cons. ComrnisSlOll Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] sUSPENDED [] ABANDONED [] SERVICE j~ .......... Equipment Testing 2. Name ~)f Operator .... ~~i 7. Permit Number Conoco Inc. .~"~lJl~---'-- ~i 9(~-R¢; ~ __ 3. Address j.~{,**,,~,~,~...., 8. APl Number 4. Location of welt at surface ~ '"" ; ~dN ~ 9. Unit or Lease Name ~ '.-~'~'; ~ Milne Point Unit . At Top Producing Interval ~? ~:,,,~i[~i_-i~:~,:~,~ ~ ~ 0. Well Number 3950'FNL, 2750'FEL, Sec.34, T13N, R10E, U.M. NSB, AK ~' ....... -~ ' i '- At Total Depth '.~ ........ i~ ............ ~ i 1. Field and Pool 4322'FNL, 2400~Fel: Sec.34. T13N. R1.)E. U.M. NSB; AK 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri~er 35' KB ADL - 25906 Schrader Bluff , 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 9-10-90 9-23-90 N/AI N/A feet MSL[ 0 , , , 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 5250' MD 5146' MD YES ~ NO [] N/A feet MDI ±1800' 22. Type Electric or Other Logs Run MWD, DIL; LDT. CNT. NGT: BGT 23. CASING, LINER AND CEMENTING RECORD ! SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 54.5 K-55 35 115 30 " 500 Sacks Permafrost C None 9 5/8" 36 K-55 35 2793 12 1/4" 334 BBLS None 7 " 26 L-80 35 5222 8 1/2" 89 BBLS Class G None ,,, _ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD .,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE I~ELL NOT PERFORATED 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED NONE ....... 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) N/A .I N/A Date of Test 'Hours Tested pRoDuCTION FOR 01L~-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A TEST PERIOD ~l~ / , Flow Tubing Casing Pressure CALCULATED ",.~ OIL-BBL GAS-MCF WATER-BB'L OIL GRAVITY-APl (corr) Press. .24-HOUR RATE I~ 28. CORE DA-iSA _ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R EC E IV E D DEC 1 0 199,t Alaska Oil & Gas Cons. Commission Anchorage .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME NA NB NC NE OA OB 31. LIST~ ATTACHMENT~ GEOLOGIC MARKE,,v MEAS. DEPTH TRUE VERT. DEPTH 4661' 4687' 4726' 4747' 4837' 4908' 3969 ' 3991 ' 4023 ' 4041 ' 4117' 4177 ' JRMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 32. I hereby certify that the foregoing s true and correct to the best of my knowledge Signed ~_ o1~ ...... _L (~.~.~_ T i t I e<~~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this forrn and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation` Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 WELL No. H-1 CASING SKETCH MILNE POINT UNIT APl No.: 50-029-22061 PERMIT No.: 90-86 DRILLED: 9/25/90 ARCTIC PACKED: OPEN (P) OPERATOR: CONOCO INC. SURFACE LOCATION: .3542' FNL, 4070' FEL, SEC 34, T15N, RIOE U.M. BOTTOM HOLE LOCATION: 4522' FNL, 2400' FEL, SEC. 34, T13N, RIOE, U.M. SPUD DATE: 9/10/90 RKB 34' 22 BBLS DIESEL 175 BBLS / 9.2 PPG NaCl WKM CSG SPOOL 15 3/8", 54.5#, K-55, WELD SET @ 105' CEMENT DATA: 500 SKS PERMAFROST "C" @ 14.8 PPG ARCTIC PACK DATA: 51BBLS, 15.6 PPG, PERMAFROST "C", 60 BBLS DEAD CRUDE 9 5/8", 36#, K-55, BTRC, SET @ 2793' CEMENT DATA: 282 BBLS ARCTIC SET IV @ 12.3 PPG, 52 BBLS OF CLASS "O" @ 15.8 PPG W/ 0.2% D-046 & 3.0% S-001 EST TOC @ 3600' RA TAG @ 4615' PBTD 5146' TD 5250' CONOCO INC. ANCHORAGE DIVISION 7", 26#, L-80, BTRC SET @ 5222' CEMENT DATA: 89 BBLS (4,34 SKS)"G" CMT @ 15.8 PPG W/ 0.2% D-046, 0.8% D-127 & 1.0% S-001 RECEIVED DEC 1 0 199~ Alaska 0il & Gas Cons. Commission Anch( APPROVED BY: HDS DATE: 7/7/92 DRAFTED BY: SJN/CFP CAD FILE: WCAH1 PETROLEUM TESTING, SERVICE, INC. COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: NICROFILH D WELL : H-1 FI ELD : MI LNE POINT COUNTY: NORTH SLOPE STATE : AK ONAL CORE ANALYSIS PAGE : 1 FILE MO.: 70080 DATE : NOVEMBER 21, RESULTS i I I I I I .,~PLE I DEPT, IPER.EABILITYI INU"BERI ft I md I I I I , ~. /~ ...., I.,. ,% ~- - ~ Ui~ I~L,~ I__~ I I[ ' r - r--- sATUrATION I I I I GRAIN POROSITY I O/W I OIL uATER TOTAL I DENSITY I RATIO I (PERCENT PORE VOLUME)I g/cc I ICorE NO. 1 : 4649.00 - 4675.10 I COMMENTS CUT 26.10' REC 26.10' LITHOLOGICAL DESCRIPTION 1990 1 4649.25 4.3 2 4650.20 110' 3 4651.10 22 4 4652.10 8.7 5 4653.00 31' 6 4654.00 21 7 4655.10 6.9 8 4656.20 6.7 9 4657.00 9.4 10 4658.10 40* 11 4659.00 3.4 23.6 0.0 0.0 93.4 93.4 2.71 30.5 0.0 0.2 94.3 94.5 2.68 32.1 0.0 0.0 77.9 77.9 2.68 26.3 0.7 37.7 56.1 93.8 2.69 27.1 0.0 0.0 95.7 95.7 2.65 26.3 0.0 0.7 92.2 92.9 2.65 22.3 0.0 0.0 97.0 97.0 2.69 23.5 0.0 0.0 96.3 96.3 2.69 21.8 0.0 0.0 95.9 95.9 2.~ 22.6 0.0 0.0 97.6 97.6 2.68 22.1 0.0 0.0 97.6 97.6 2.67 *Fractured Ka *Fractured Ka *Fractured Ka Sttst, gry, shty, mcd cmt, carb, n odr, n stn, n fluor sltst, gry, shty, mod cmt, carb, fnt odr, strkd It stn, gld fluor Sttst, gry, shty, n~xJ cmt, n cdr, n stn, n fluor Sttst, gry, shly, mod cmt, fnt cdr, sptd m stn, gld fluor Sltst, gry, shty, mod cmt, carb, n cdr, n stn, n fluor Sst, gry, fsd shty, mod cmt, fnt cdr, sptd It stn, gtd fluor Sh, gry, slty, mod cml, n cdr, n stn, n fluor Sh, gry, stty, n~)cl cmt, n cdr, n stn, n fluor Sltst, gry, shly, mod cmt, n cdr, n stn, n fluor · Sttst, gr¥, shly, mod cmt, n odr, n stn, n fluor Sltst., gry, shly, mod cmt, n cdr, n stn, n fluor 12 4(>60.10 7.5 22.7 0.0 0.0 95.8 95.8 2.68 Sttst, gry, shty, ~ cmt, n odr, n stn, n fluor COHPANY : CONOCO AK INC CORE TYPE: 4 INCH HUD TYPE : WATER BASE FORNAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-! FIELD : HILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 2 FILE NO.: 70080 DATE : NOVEHBER 21, lggo RESULTS I I I I I I I I I I I ~...dPLE I DEPTH IPER"EAaILITYI INUMBER I ft I md I I I I I SATURATION I I I I ORAIN POROSITY I o/~ I 01L WATER TOTAL I DE,SITY % I RATIO I(PERCENT PORE VOLUME)I g/cc 1 [CORE NO. 1 : 4649.00 - 4675.10 I 13 4661.10 1.8 21.8 0.0 0.0 92.2 92.2 2.68 14 4662.00 4.0 22.4 0.0 0.0 94.4 94.4 2.68 15 4663.00 6.9 22.8 0.0 0.0 91.5 91.5 2.67 COHMENTS CUT 26.10' REC 26.10' 16 4664.00 13' 21.0 0.0 0.0 98.9 98.9 2.65 *Fractured Ka 4665.00 6.5 20.5 0.0 0.0 96.3 96,3 2.64 4666.10 22 23.5 0.0 1.1 89.7 90.8 2.63 19 4667.10 22 22.0 0.0 0.3 93.4 93.7 2.61 20 4668.00 49* 20.6 0.0 0.0 92.9 92.9 2.75 *Fractured Ka 17 21 4669.00 8.4 22.9 1.2 52.6 43.4 96.0 2.63 22 4670.10 1.7 5.7 0.0 0.0 49.5 49.5 2.75 23 4671.00 6.1 24.1 0.0 1.0 92.8 93.8 2.64 LITHOLOGICAL DESCRIPTION SLtst, gry, shty, mod cmL, n odr, n stn, n fluor Sttst, gry, shLy w/Lam, mod cml, n odr, n stn, n fluor Sttst, gry, shty, mod cmt, carb, n oclr, n stn, n fluor Sh, gry, stty, mod cmt, n ocir, n stn, n fluor Sh, gry, stty, mod cmt, n odr, n stn, n fluor Sst, gry, fsd shLy, mod cmt, fnt odr, sptd [t stn, gtd fluor Sst, gry, msd shty w/Lam, mod cmt, fnt odr, sptd tt stn, gtd fluor Sh0 gry, sity, mod cmL, n odr, n stn, n fluor Sst, gry, vfsd shty, mod cmt, fr odr, [t stn, gtd fluor · Sst, gry, vfsd shty, w[ cml, ca[c, n Ddt, n stn, n fluor Sst, gry, vfsd shLy, mod cmt, fnt odr, strkd tt-med stn, gLd fluor 24 4672.00 7.9 25.2 0.0 0.9 89.5 90.2 2.66 Sst, gry, fsd shty, nx~cl cmt, fnt odr, strkd tt stn, gld COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORNATION: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 3 FILE NO.: 70080 DATE : NOVEMBER 21, lggo CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I I I I I I .4PLE IDEPT, IPER"EAaILITYIPOROSITY I o/u I NU,,ER I ft I "~ I X I RATIO I I I I I I SATURATION I I I GRAIN I OIL UATER TOTAL I DENSITY I COMMENTS (PERCENT PORE VOLUME)I g/cc I CORE NO. 1 : 4649.00 - 4675.10 CUT 26.10' REC 26.10' 25 467"5.10 6.8 23.9 0.0 26 4674.00 15 27.1 0.0 1.8 94.4 96.2 2.64 3.4 90.3 93.7 2.65 27 4675.00 89 30.3 0.0 3.8 86.1 89.9 2.64 LITHOLOGICAL DESCRIPTION fluor Sltst, gry, shty, wi cml, fnt odr, sptd tt stn, gtd fluor Sst, gry, fsd shty, mod cmt, carb, fnt odr, sptd tt stn, gtd fluor Sst, gry, fsd stty, mod cmt, fnt odr, sptd tt stn, gtd fluor CONPANY : CONOCO AK 1NC CORE TYPE= 4 INCH HUD TYPE = WATER BASE FORNAT I ON = PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : NILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 4 FILE NO.: 70080 DATE : NOVENBER 21, RESULTS 1990 I I I I I I I I I I I 1 ,PLE I DEPTH IPERMEABILITYI I WU. BEN I ft I I I I I I I I I I I saturation I I I I ORAIN POROSITY I O/W I OIL ~ATER TOTAL I DENSITY % I RATIO I(PERCENT PORE VOLUME)I g/cc ICORE NO. 3 : 4689.00 - 4704.00 I COMHENTS CUT 15.00' REC 15.00' LITHOLOGICAL DESCRIPTION 28 ,4689.25 16 22.7 0.0 0.0 97.4 97.4 2.66 Sttst, gry, stty, mod cmt, carb, n odr, n stn, n fluor 29 4690.05 8.1 22.4 0.0 0.0 93.0 93.0 2.66 Sh, gry, st stty, mod cmt, n odr, n stn, n fluor 30 4691.10 46* 21.6 0.0 0.0 93.2 93.2 2.66 *Fractured Ka Sh, gry, st stty, mod cmt, n odr, n stn, n fluor 31 4692.10 5.3 20.2 0.0 0.0 97.4 97.4 2.63 Sh, gry, st stty, mod cmt, pyr, n odr, n stn, n fluor 32 4693.10 26 21.0 0.0 0.0 93.2 93.2 2,64 33 4694.00 59* 15,9 0.0 0.0 87.9 87.9 2.79 *Fractured Ka ,, 34 4695.10 45* 23.4 0.0 0.0 99.5 99.5 2.61 *Fractured Ka Sh, gry, st stty, mod cmt~ n odr, n stn~ n fluor SItst, gry, shty, mod cmt, n octr, n stn, n fluor Sst, gry, fsd shty, ~ cmt, carb, n odr, n stn, n fluor 35 4696.00 24 24.3 0.0 0.0 96.8 96.8 2.60 Sst, gry, fsd shty, nv~cl cmt, carb, n odr, n stn, n fluor 36 4697.00 21 21.7 0.0 0.0 97.2 97.2 2.61 Sst, gry, fsd shly, ~ cmt, carb, n odr, n stn, n fluor 37 4698.10 8.7 25.9 0.0 2.4 94.0 96.4 2.62 38 4699.00 4.8 3.2 O. 1 5.5 54.4 59.8 2.68 Sttst, gry, shty, mod cmt, n odr, sptd tt stn, gtd fluor · Sst, gry, fsd-msd, v wt cmt~ catc, fnt odr, strkd m stn, g[d fluor 39 4700.00 2.0 3.8 0.1 6.2 47.8 53.9 2.66 Sst, gry, fsd-msd, v wi cmt, calc, n odr, sptd It stn, gtd fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELO: MILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 5 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I .,,PLE I DEPTH IPER.EABILITYI POROSITY I o/~ I ,UMBER I ft I md I x I RATIO I SATURATION I I GRAIN OIL WATER TOTAL I DENSITY (PERCENT PORE VOLUME)I g/cc I CORE NO. 3 : 4~9.00 - 4704.00 CUT 15.00' CC~4MENTS REC 15.00' LITHOLOGICAL DESCRIPTION 40 4701.25 9.9* 3.5 41 4702.10 0.6 10.2 42 4703.00 845 29.5 0.1 4.0 44.2 48.2 2.65 0.2 5.2 33.6 38.8 2.69 0.4 18.8 48.1 66.9 2.62 *Fractured Ka Sst, gry, fsd-msd, v w[ cmt, catc, n odr, sptd m-dk stn, gtd ftuor Sst, gry, msd crssd, v w[ cmt, catc, fnt odr, strkd m-dk stn, gtd ftuor Sst, tan, fsd-msd, prty cmt, gd edr, ev m-dk stn, brt gtd ftuor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY.' NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 6 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 I I I I I I I I I I I .aPLE IDEPTH IPER.EAalLIT¥1 I NU.aER I ft I .,d I I I I I I I I I I SATURATION I I I I ~RAI. POROSITY ! o/u I OIL WATER TOTAL I DeNSiTY I RATIO I (PERCENT PORE VOLUME)I g/cc I JCORE NO. 4 : 4717.00 - 4736.90 COHHENTS CUT 19.90' REC 19.90' 43 4717.35 14 23.0 0.0 0.0 88.0 88.0 2.65 44 4718.00 13 18.8 0.0 0.0 97.3 97.3 2.62 45 4719.00 4.0 19.4 0.0 0.0 91.1 91.1 2.71 46 4720.25 176' 25.1 0.2 15.0 65.2 80.2 2.70 *Fractured Ka 47 4721.00 3.9 19.6 0.0 0.0 98.3 98.3 2.65 48 4722.00 ~ 27.2 0.2 11.6 75.0 86.6 2.~ 49 4723.10 99* 26.6 0.1 10.4 74.9 85.4 2.71 *Fractured Ka 50 4724.00 17 25.8 0.0 0.0 97.7 97.7 2.72 51 4725.00 28* 22.8 0.0 0.0 84.4 84.4 2.72 *Fractured Ka 52 4726.10 1.8 23.0 0.0 0.0 96.1 96.1 2.72 53 4727.05 1.6 23.7 0.0 0.0 97.0 97.0 2.76 LITHOLOGICAL DESCRIPTION Sttst, gry, shty, mod cmt, n odr, sptd Lt stn, gtd fluor Sttst, gry, shty, mod cmt, fnt odr, sptd It stn, gtd fluor Sttst, gry, shly, mod cmt, n odr, n stn, n fluor Sst, gry, vfsd shty, nx)cl cmt, fr odr, ev lt-m stn, g[d ftuor Sh, gry, stty, mod cmt, fnt odr, sptd tt stn, gld fluor Sst, gry, vfsd w/shty tam, mod cmt, fnt odr, strkd It stn, gtd fluor Sh, gry, stty w/Lam, ~)d cmt, fr odr, ev Lt stn, gtd fluor Sh~ gry, stty w/tam, mod cmt, n odr, n stn, n fluor Sttst, gry, shty, mod cmt, n odr, n stn, n fluor · Sh, gry, si slty, mod cmt, n odr, n stn, n fluor Sh, gry, st slty, mod cmt, fnt odr, spt It stn, gtd fluor 54 4728.05 8.2 23.2 0.0 0.8 96.8 97.6 2.69 Sttst, gry, shly, mod cmt, fnt odr, spt tt stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: · PETROLEUM TESTING SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 7 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 I DEPTH IPERMEABILITYI 55 4729.10 <0.1 56 4730.00 <0.1 57 4731.00 <0.1 58 4732.20 4. ? 59 4733.00 61 4735.20 9.9 62 4736.15 1.0 I I I I I I SATURATION I I I I I GRAIN I POROSITYI o/uI OIL UATER TOTAL I DENSITY I % J RATIO J (PERCENT PORE VOLUME)I g/cc I I COMMENTS ICORE NO. 4 : 4717.00 - 4736.90 CUT 19.90' REC 19.90' I 25.0 0.0 1.9 86.6 88.5 2.67 22.7 0.0 0.0 96.7 96.7 2.68 16.7 0.0 0.0 84.4 84.4 2.83 25.9 0.1 4.4 79.0 83.4 2.70 23.5 0.0 0.0 94.5 94.5 2.6~ **Fractured, Estimated Ka 24.4 0.0 3.7 76.3 80.0 2.66 21.4 0.0 0.3 86.0 86.3 2.70 20.9 0.0 0.0 92.4 92.4 2.66 LITHOLOGICAL DESCRIPTION Sh, gry, st stty, ~ cmt, n odr, n stn, n fluor Sh, gry, st stty, mod cmt, n odr, n stn, n fluor Sh, gry, st stty, mod cmt, n odr, n stn, n fluor Sttst, gry, shty, mod cmt, fr odr, ev It stn, gtd fluor Sltst, gry, shty, mod cml, n odr, n stn, n fluor Sttst, gry, shty, mod cmt, fnt odr, strkd tt stn, gtd fluor Sttst, gry, shly, mod cmt, n odr, sptd it stn, gtd fluor Sh, gry, st stty~ nxxl cmt, n odr, n stn, n fluor 63 4736.90 58 23.2 1.0 32.8 33.4 66.2 2.7'5 Sst, gry, vfsd stty, prty cmt, fr odr, ev m stn, gtd fluor COMPANY .' CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATI ON: PETROLEUM TESTING SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 8 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 [ I I I I I I I ,MPLEI DEPTH IPERHEABILITYi I NUMBER I f t I md I ! I I I 64 4747.45 4580 65 4748.15 5720 66 4749.00 4500 67 4750.15 1500' 68 4751.10 121' 69 47~2.00 1.1 70 4753.00 81' 71 4754.00 56* 72 4755.00 109' 73 4756.00 17' 74 4757.00 16 I I I I I I SATURATION I I POROSITY I O/WI OIL UATER TOTAL I DENSITYI X {RATIOI (PERCENT PORE VOLUME)I g/cc I COMMENTS I ICORE NO. 5 : 4747.00 - 4763.50 CL~16.50' 47.4 0.0 0.2 81.7 81.9 2.73 46.2 0.0 0.4 93.3 93.6 2.55 m 45.6 0.0 0.6 93.4 93.9 2.31 46.7 0.0 0.0 91.0 91.0 2.59 *Fractured Ka 35.5 0.0 0.0 93.9 93.9 2.69 23.3 0.0 0.0 86.2 ~.2 2.71 *Fractured Ka 29.1 0.2 13.0 58.3 71.3 2.71 *Fractured Ka 24.'9 0.0 0.9 74.1 75.0 2.71 *Fractured Ka 31.6 0.1 8.5 82.0 90.5 2,66 *Fractured Ka 24.2 0.0 0.0 90.6 90.6 2.67 *Fractured Ka REC 16.70' 24.0 0.0 2.4 81.4 83.8 2.64 LITHOLOGICAL DESCRIPTION Sst, gry, crssd-v crssd sh pbt, prty cmt, fr odr, sptd tt stn, gtd fluor Sst, gry, v crssd sh pbt, prty cmt, fnt odr, sptd tt stn, gtd fluor Sst, gry, v crssd sh phi, prLy cmt, fnt odr, sptd it stn, gtd fluor Sst, gry, vfsd stty, prty cmt, fnt odr, sptd Lt stn, gtd fluor Sh, gry, stty, mod cmt, n odr, n stn, n fluor $h, gry, stty, mod cmt, n odr, n stn, n fluor Sst, gry-tan, shty, mod cmt, fr odr, ev m stn, gtd fluor Sttst, gry, shty, mod cmt, fr odr, sptd Lt stn, gtd fluor SLtst, gry, shty, mod cmt, ir edt, sptd tt-m stn, gtd fluor Sh, gry, st stty, mod cmt, n odr, n stn, n fluor Sst, gry, fsd v shty, mod cmt, fr Ddt, sptd Lt stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH HUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : HILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 9 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 CONVENTIONAL CORE ANALYSIS. RESULTS ! I I I I I I' I I I I I SATURATION I I I I I I I I ORAl, I ,.,POE I DEPTH IPERMEABILITYI POROSITY I O/W I OIL WATER TOTAL I DENSlTY I NUMBER J ft J md I I RATIO I(PERCENT PORE VOLUME)I D/cc I I,, I I I I J ! I JCORE NO. 5 : 4747.00 ' 4763.50 CUT 16.50' I COMMENTS REC 16.70' j I ; 75 4758.00 71' 16.5 ! 76 4759.50 99* 24.7 0.0 1.5 64.8 ~.3 2.77 0.2 14.6 62.5 77.0 2.69 *Fractured Ka *Fractured Ka 4760.15 106' 27.4 0.1 9.0 68.9 77.9 2.69 *Fractured Ka 78 4761.00 12' 25.8 0.2 14.1 67.3 81.5 2.71 *Fractured Ka 79 80# 4762.15 284 41.5 0.7 26.8 40.8 67.7 2.67 4763.20 #Fai Led LITHOLOGICAL DESCRIPTION Sh, gry, sLty, mod cmt, fr odr, sptd It stn, gLd fluor Sh~ gry, stty, mod cmt, fr odr, ev tt stn, gLd fluor Sh, gry, sLty, mod cmL, pyr, fr odr, strkd tt stn, gLd fluor Sttst, gry, shLy, mod cmL, fr odr, ev Jt stn, gtd fluor Sst, gry, vfsd sLty, prLy cmt, gd odr, ev m stn, gLd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING. SERV!CE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 10 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 RESULTS I I I I I I I I I I I I ~^.PLE I DEPTH JPERMEABILITYI I NUMBER I ft I md I I I I I 81 4765.15 <0.1 82 4766.10 108 83 4767.00 182' 84 4768.15 14 85 4769.05 86 4770.00 I I I I I I SATURATION I I I I I GRAIN I POROSITY I O/W I OIL WATER TOTAL I DENSITY I % J RATIO I (PERCENT PORE VOLUME)I g/cc J JCORE NO. 6 : 4765.00 - 4784.70 3.2 0.0 0.0 62.8 62.8 87 4771.25 20 88 4772.00 7.6 89 4773.00 13' 90 4774.00 6.6 91 4775.05 20 92 4776,00 13 33.6 0.9 40.1 43.0 83.2 2.67 COMMENTS CUT 19.70' REC 19.60' 29.7 0.5 25.6 54.6 80.2 2.65 *Fractured Ka 27.9 0.3 20.3 71.7 92.0 2.63 9.4 26.7 0.1 12.3 82.4 94.6 2.64 6.9 22.1 0.5 23.6 45.6 69.3 2.74 28.9 0.8 34.6 41.2 75.8 2.60 26.4 0.3 17.7 67.6 85.:5 2.6:5 26.8 0.4 23.4 54.2 77.6 2.64 *Fractured Ka 28.4 0.2 12.2 62.0 74.1 2.62 27.0 0.4 24.4 64.9 89.2 2.62 29.8 0.2 12.4 74.4 86.8 2.67 LITHOLOGICAL DESCRIPTION I Sst, gry, vfsd, v wL cml, calc, fnt odr, n stn, n fluor Sst, gry, fsd s[ty, pr[y cmt~ gd odr, ev m stn, gtd fluor Sst, gry, fsd shty, mod cml, gd odr, ev m stn, gtd fluor Sst, gry, vfsd shty, mod cmt, fr odr, ev [t m stn, gtd fluor S[tst, gry, shty, mod cmt, n edr, strkd Lt stn, gLd fluor Sh, gry, s[ty, mod-wt cml, pyr, fnt odr, ev [t stn, gLd fluor Sst, gry, vfsd shty, mod cml, fr odr, ev Lt stn, gld fluor Sh, gry, s[ty, mod cmt, fnt odr, ev Lt stn, gtd fluor Sh, gry, s[ty, mod cmt, fnt odr, ev [t stn, g[d fluor Sh, gry, stty, mod cmt, fnt ~x:lr, strkd [t stn, g[d fluor Sst, gry, vfsd sh[y, mod cml, fnt odr, ev Lt stn, gLd fluor Sst, gry, vfsd sh[y, mod cml, n odr, strkd [t stn, g[d fluor COHPANY : CONOCO AK INC CORE TYPE: 4 INCH HUD TYPE : WATER BASE FORHAT!ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 11 FI LE NO.: 70080 DATE : NOVENBER 21, 1990 RESULTS I I I I I I I I .4PLE I DEPTH IPERMEABILITYI I NUMBER I ! I I 93 4777.00 16 94 4778.00 53* 95 4779. O0 8.8 96 4780.15 13 97 99 4781.00 7.1 4782.00 16 4783.00 43 I I I I I I SATURATION I I I I I GRAIN I POROSITY I O/U I OIL WATER TOTAL I DENSITY I I RATIO I (PERCENT PORE VOLUME)I g/cc I ICORE NO. 6 : 4765.00 - 4784.70 I COHMENTS LITHOLOGICAL DESCRIPTION CUT 19.70' REC 19.60' 27,5 0.3 16.7 60.5 77.1 2.67 Sst, gry, vfsd shLy, mod cmt, fnt odrw ev tt stn, gLd fluor 31,2 0.2 11.3 ~.0 77.3 2.67 *Fractured Ka Sst, gry, vfsd shty, mod cmt, n odr, strkd m stn, gtd fluor 25.4 0.1 6.9 91.1 98.0 2.65 Sst, gry, vfsd shLy, mod cmt, n odr, sptd m stn, gLd fluor 26.2 0.2 15.5 77.0 92.5 2.65 Sst, gry, vfsd shty, mod cmt, n odr, strkd tt stn, gtd fluor 23.0 0.5 29.1 58.9 88.0 2.64 25.2 0.2 13.6 ?3.2 86.8 2.65 SLtstw gry, shty, mod cmt, fnt Ddt, strkd Lt stn, gtd fluor Sttst, gry, shty~ mod cmt, fr odr~ strkd It stn, gLd fluor 34.3 0.3 22.2 64.7 86.9 2.68 Sst, gry, vfsd st shLy, mod cmt, fnt odr, ev tt stn, gtd fluor 100 4784.00 9.6 20.2 0.0 2.9 80.6 83.4 2.74 Sh, gry, stty, w[ cmt, n oclr, sptd It stn, gLd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: · PETROLEUM TESTING,.SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 12 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I I I I I SATURATION I I I I I I I I GRAIN I I ..~PLE IDEPT~ IPER~EABILIT¥1POROSITY I 0~ I OIL ~ATER TOTAL I DENSIT~ I I NUHBER I ft I md I X I RATIO I tPERCENT PORE VOLU.E)I g/CC I I ICORE NO. 9 : 4814.00 - 48~2.50 CUT 28.50* I COMMENTS REC 28.40' LITHOLOGICAL DESCRIPTION 101 4839.25 39* 25.9 0.0 1.7 97.4 99.1 2.67 *Fractured Ka 102 4840.00 18 24.8 0.0 0.6 98.2 98.8 2.65 · 103 4841.00 65* 25.3 0.0 3.7 87.7 91.4 2.75 *Fractured Ka 104 4842.40 30* 25.2 0.0 3.4 95.1 98.5 2.68 *Fractured Ka Sh, gry, slty, wE cmt, n odr, sptd m stn, gld fluor Sh, gry, slty, nK)cl cmt, n odr, sptd m stn, gld fluor Sh, gry, slty, mod cmt, n odr, sptd It stn, gld fluor Sttst, gry, shty, mod cmt, n odr, sptd tt stn, gld fluor COMPANY : CONOCO AK INC CORE TYPE= 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 13 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 RESULTS I I DEPTH IPERMEAaILITYI ft I ~ I I I I I I I I SATURATION I I I I ~R^IN POROSITY I 0/" I OIL "ATER TOTAL I DENSITY I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 10 : 4839.00 - 4852.80 I COMMENTS CUT 13.80' AEC 13.80' 101 4839.25 39* 25.9 0.0 1.7 97.4 99.1 2.67 *Fractured Ka 102 4840.00 18 24.8 0.0 0.6 98.2 98.8 2.65 103 4841.00 65* 25.3 0.0 3.7 87.7 91.4 2.75 *Fractured Ka 104 4842.40 30* 25.2 0.0 3.4 95.1 98.5 2.68 *Fractured Ka 105 06 107 108 109 110 111 4843.00 23 26.7 0,0 1.9 97.3 99.2 2.69 4844.00 50 27.0 0.3 22.9 73.4 96.4 2.64 4845.15 43 32.1 0.4 28.1 68.9 97.0 4846.05 29* 22.6 0.7 31.7 42.8 74.5 2.66 *Fractured Ka 4847.00 8.6 26.5 0.6 34.0 56.4 90.5 2.62 4848.15 13 28.9 0.4 26.4 61.3 87.7 2.62 4849.00 170' 31.7 0.5 26.9 57.1 84.0 2.65 *Fractured Ka LITHOLOGICAL DESCRIPTION Sh, gry, s[ty, wt cmt, n oclr, sptd m stn, gtd fkuor Sh, gry, stty, mod cmt, n odr, sptd m stn, gtd fluor Sh, gry, stty, mod cmt, n odr, sptd [t stn, g[d fluor S[tst, gry, shty, mod cml, n odr, sptd It stn, g[d fluor Sltst, gry, shly, mod cmt, n odr, sptd [t stn, gtd fluor Sst, gry, vfsd stty, mod cmt, n odr, strkd tt stn, gtd ftuor Sst, gry, vfsd stty, mod cmt, fnt odr, ev Lt stn, gLd fluor SLtst, gry, shLy, wL cml, fnt odr, ev Lt stn, gLd fluor Sttst, gry, shty, mod cmt, fnt odr, ev[t stn, gtd fluor S[tst, grym shtym mod cmt, n. odr, ev[t stn, g[d fluor Sst, gry, vfsd s[ty, pr[y-mod cmt, fnt odr0 ev It stn, g[d fluor 112 4850.10 507 36.8 0.6 25.1 44.0 69.2 2.60 Sst, gry, vfsd-fsd, prey cmt, fr odr, ev[t stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 14 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I I I I I SATURATION I I [ I I I I I I ORAIN I ~ ,PLE IDEPT, IPER.E^BILITYIPOROSITY I O/W I OIL WATER TOTAL I OENSZTY I I NU"BER I ft I md I x I RATIO I(PERCENT PORE VOLU"E)I g/cc I I I I I I I I I ICORE NO. 10 : ~839.00 - ~852.80 CUT 13.80' l CC)MHENTS REC 13.80' LITHOLOGICAL DESCRIPTION 113 4851.25 15 27.3 0.0 4.3 91.2 95.5 2.75 Sh. gry, st sdy, mod cmt, n odr, sptd tt stn, gtd ftuor 213# 4852.00 #No Sampte COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATI ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : HILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 15 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 19g0 Il ~LE I DEPTN IPER.EABILITYI INUMBER I ft I md ! I I I 114 4859.15 5.5 115 4860.00 3.1 116 4861.00 5.4 117 4862.15 11 118 120 4863.05 22 4864.00 22 4865.15 7.3 121 4866.0O 7.3 122 4867.00 15 123 4868.10 103 124 4869.10 11' 125 4870.00 200 126 4871.40 166 I I I I I SATURATION I I t I ~RAI, POROSITY I O/W I OIL WATER TOTAL I DENSITY I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 11 : 4859.00 ' 4881.80 I CONMENTS CUT 22.80' REC 22.90' 24.4 0.6 31.3 54.0 85.2 2,62 23.5 0.5 26.6 51.0 77.6 2.62 24.1 0.5 27.6 55.1 82.7 2.62 26.7 0.4 25.5 57.2 82.7 2.64 30.1 0.4 25.3 66.1 91.4 2.65 30.9 0.4 26.0 65.2 91.2 2.65 28.0 0.0 1.2 96.4 97.7 2.68 20.5 0.2 12.6 80.1 92.8 2.90 28.8 0.1 6.4 83.7 90.1 2.68 32.8 0.2 14.8 72.5 87.3 2.65 16.3 0.0 2.6 83.5 86.1 2.86 *Fractured Ka 33.4 0.1 10.1 75.6 85.8 2.64 32.7 0.1 11.0 75.0 86.0 2.65 LITHOLOGICAL DESCRIPTION Sttst, gry, shty, mod cmt, fnt cdr, ev it stn, Ltd fluor Sttst~ gry, shty, mod cmt, fnt cdr, ev It stn, Ltd fluor Sttst, gry, shty, mod cmt, fnt cdr, ev It stn, Ltd fluor Sttst, gry, shty, mod cmt, n cdr, ev It stn, Ltd fluor Sttst, gry, shty, mod cmt, fnt odr, ev tt stn, Ltd fluor Sttst, gry, shty, mod cmt, n cdr, ev tt stn, Ltd fluor Sttst, gry, shty, mod cmt, n cdr, sptd tt stn, Ltd fluor Sh, gry, slty, mod cml, pyr~ n cdr, strkd [t stn, gld fluor Sttst, gry, shty, mod cmt, fnt cdr, strkd [t stn, Lid fluor Sst~ gry, vfsd, mod cmt, fnt cdr, ev tt stn, Ltd fluor Sh, gry, vfsd, mod-u[ cmt, pyr, n cdr, sptd tt stn, Ltd fluor Sst, gry, vfsd, prty-mod cmt, n odr, ev tt stn, Ltd fluor Sst, gry, vfsd st shty, prty-mcd cmt, n cdr, ev tt stn, Ltd COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 16 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS lggo I I I I I I I I o-.PLE IDEPTH IPER.EABILITYI I NUMBER J ft J ~ I I I I I I POROSITY I O/W % I RATIO I ! SATURATION I I GRAIN OIL WATER TOTAL I DENSITY (PERCENT PORE VOLUHE)I g/cc I COHMENTS 130 CORE NO. 11 : 4859.00 - 4881.80 CUT 22.80' REC 22.90' 127 4872.00 180 32.3 0.1 10.0 77.6 87.6 2.67 128 4873.00 271 34.3 0.1 8.5 75.3 83.8 2.63 129 4874.20 2.2 18.6 0.0 3.5 85.2 88.8 2.69 132 133 134 135 4875~00 4.0 24.5 0.1 8.6 82.5 91.1 2.66 4876.00 25 29.9 0.2 17.3 78.8 96.1 2.64 4877.20 12' 25.0 0.0 3.8 76.6 80.4 2.72 *Fractured Ka 4878.20 25* 25.8 0.0 0.9 92.0 92.9 2.71 *Fractured Ka 4879.00 2.2 20.5 0.1 5.3 77.6 82.8 2.80 4880.00 47* 24.5 0.0 1.2 86.2 87.4 2.73 *Fractured Ka LITHOLOGICAL DESCRIPTION fluor Sst, gry, vfsd st shty, prLy-mod cmt, n odr, ev tt stn, gtd fluor Sst, gry, fsd, prty-mod (mt, n odr, ev It stn, gid fluor Sst, gry, fsd stty, mod-wL cmt, cat(, n odr, sptd tt stn, gtd fluor Sttst, gry, shty, mod(mt, n odr, strkd tt stn, gtd fluor Sst, gry, vfsd-fsd stty, mod (mt, fnt odr, ev tt stn, gtd fluor Sttst, gry, shty, mod (mt, pyr, n edr, strkd tt stn, gtd fluor Sttst, gry, shly, mod cmt, pyr, n edr, sptd tt stn, gtd fluor Sh, gry, st slty, mod (mt, pyr, n odr, strkd tt stn, gld fluor Sh, gry, st sLty, mod (mt, pyr, n edr, sptd tt stn, gld fluor CONPANY : CONOCO AK INC CORE TYPE: 4 INCH HUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : HILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 17 FILE /JO.: 70080 DATE : NOVEHBER 21, 1990 RESULTS I I I I I I I I I I I I I i SATURATION I I I~ I I I I t I ~RAIN I I'- .... ?LEI DEPTH IPERHEABILITYIPOROSITY I o/. I OIL WATER TOTAL l DENSITY I J NUMBER I ft J mci J % I RATIO I(PERCENT PORE VOLUME)I g/cc I I ICONE NO. 11 : 4859.00 - 4881.80 CUT 22.80~ CONMENTS REC 22.90' 214# 4881.00 #No Sampte LITHOLOGICAL DESCRIPTION COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 18 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 RESULTS I I I I I I I I Ii ?LEI DEPTH IPERME^alLITYI J NUHBER J ft J md J I I I I I I I I I I SATURATION I I I I I GRAIN I POROSITY I O/W I OIL WATER TOTAL I DENSITY I % I RATIO I (PERCENT PORE VOLU. E)! g/cc I COMMENTS ICORE NO. 12 : 4882.00 - 4909.40 CUT 27.40' REC 27.60' I 136 4882.25 23* 26.4 0.0 2.3 85.3 87.5 2.72 *Fractured Ka 137 4883.00 3,8 20.5 0.0 3.0 82.5 85.5 2.80 138 4884.25 8.3 23.5 0.0 1.8 86.9 88.7 2.76 139 4885.30 11 27.5 0.2 16.7 67.8 84.5 2.72 140 4886.00 10 24.7 0.1 9.6 73.0 82.6 2.70 141 4887.00 6.2 26.3 0.1 7.5 82.1 89.6 2.69 142 4888.00 19 27.6 0.0 1.4 96.8 98.2 2.69 143 4889.00 35* 28.9 0.2 15.0 80.1 95.0 2.68 *Fractured Ka 144 4890.00 14 28.5 0.2 16.6 72.4 89.0 2.73 LITHOLOGICAL DESCRIPTION Sh, gry, sL sLty, mod cmt, pyr, n odr, sptd Lt stn, gLd fluor Sh, gry, sL sLty, mod cmt, pyr, fnt odr, sptd [t stn, gLd fluor Sh, gry, sL stty, mod cmt, pyr, n odr, sptd tt stn, gtd fluor Sltst, gry, sdy shLy, mod cmt, pyr, fnt odr, ev Lt stn, gld fluor Sttst, gry, sdy shLy, mod cmt, pyr, n odr, strkd It stn, gtd fluor Sttst, gry, sdy shLy, mod cmt, pyr, n odr, strkd Lt stn, gtd fluor Sst, gry, vfsd-msd shty, mod cmt, pyr, n odr, strkd tt stn, gtd fluor Sst, gry, vfsd-fsd shty, mod cmt, fr odr, ev dk stn, br gld fluor Sst, gry, vfsd-fsd shty, mod cmt, pyr, fnt odr, ev tt stn, br gLd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : lg FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 I I I 1 I~ ?LEI DEPTH IPERMEAB[LITYI INUMBER Ift I md I I I I I I I I I I I SATURATION I I I I I GRAIN I POROSITY I O/U I OIL UATER TOTAL I DENSITY I % J RATIO j (PERCENT PORE VOLUME)I g/cc I ! ICORE NO. 12 : 4882.00 - 4909.40 I CONMENTS CUT 27.40' REC 27.60' LITHOLOGICAL DESCRIPTION 145 4891.05 12 146 4892.00 13 147 4893.00 35* 148 4894.15 4.9 49 4895.00 4.7 150 4896.00 29* 151 4897.10 9.0 152 4898.00 195 153 4899.00 47 154 4900.15 26.1 0.1 9.7 77.3 87.0 2.71 29.0 0.3 19.9 70.6 90.5 2.71 25.0 0.1 10.0 77.4 87.4 2.69 19.4 0.0 1.8 83.6 85.4 2.77 18.6 0.1 9.9 71.7 81.6 2.73 23.2 0.2 15.8 66.3 82.1 2.70 26.9 O. 1 9.5 75.8 85.3 2.70 23.5 0.4 24.8 63.0 87.8 2.73 24.4 0.1 6.1 79.4 85.5 2.69 9.7 22.7 0.0 1.6 83.1 84.6 2.72 *Fractured Ka *Fractured Ka Sst~ gry, vfsd shty, mod cmt, pyr, fnt odr, ev Lt stn, br gtd fluor Sst, gry, vfsd shty, ~x)cl cmt, fnt edr, ev tt stn, br gLd fluor Sst, gry, vfsd shty, nx)cl cmt, fnt odr, ev Lt stn, gtd fluor Sttst, gry, shty, mod cmt, pyr, n odr, ev [t stn, gtd fluor Sttst, gry, shty, mod cmt, pyr, fnt odr, ev tt stn, gtd fluor Sttst, gry, shty, mod cmt, fnt odr, ev tt stn, br gLd fluor Sttst, gry, shty, mod cmt, pyr, fnt odr, ev tt stn, gtd fluor Sttst, gry, shLy, nx~cl cmt, pyr, n odr, strkd tt stn, gld fluor Sttst, gry, shLy, mod cmt, n odr, ev tt stn, dk gtd fluor Sltst~ gry, shty, mod cmt, pyr, n odr, strkd tt stn, gLd fluor COHPANY : CONOCO AK INC CORE TYPE: 4 INCH HUD TYPE : NATER BASE FORHAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 20 FILE NO.: 70080 DATE : NOVENBER 21, 1990 RESULTS i ..... I I I I I I I I, I I 1 Ii ?LE] DEPTH IPERHEABILITYI I .U. SERI it I md I 155 4901.00 1.2 156 4902.05 2.4 157 4903.10 17' 158 4904.00 90* 159 4905.00 2.1 160 4906.10 7.5 161 4907.00 14' 162 4907.75 29* 163 4908.10 87* I POROSITY % I RATIO I I SATURATION I I CRAI, OIL WATER TOTAL I DENSITY (PERCENT PORE VOLUME)I g/cc I CORE NO. 12 : 4882.00 - 4909.40 CC~4MENTS CUT 27.40' REC 27.60' 22.5 0.0 1.3 84.7 85.9 2.72 19.2 0.0 0.4 87.8 88.1 2.86 22.7 0.0 1.9 91.2 93.1 2.75 *Fractured Ka 38.9 0.2 11.9 79.3 91.2 2.72 *Fractured Ka 25.8 0.4 26.0 63.5 89.4 2.71 28.9 O. 1 8.6 83.3 92.0 2.69 27.3 0.1 7,7 82.5 90.2 2.69 *Fractured Ka 30.7 0.1 10.7 82.1 92.8 2.68 *Fractured Ka 28.8 0.0 2.6 96.8 99,3 2.~ *Fractured Ka LITHOLOGICAL DESCRIPTION Sttst, gry, shty, mod cmt, pyr, fnt odr, sptd tt stn, gtd fluor Sttst~ gry, shly, mod cmt, pyr catc, n odr, sptd tt stn, gtd fluor Sttst~ gry, shty, mod cmt, pyr, fnt odr, sptd It stn, gld fluor Sst, gry, vfsd shty, prty cmt, pyr, fr odr, ev tt stn, gtd fluor Sttst, gry, shly, mod cmt, pyr, fnt odr, ev [t stn, gtd fluor Sttst, gry, shty, mod cmt, fnt odr, ev [t stn, gtd fluor Sttst, gry, shty, mod cmt, fnt ocir~ strkd It stn, gtd fluor Sttst~ gry, shly, mod cmt, fnt odr, ev tt stn, gld fluor Sltst, gry, shly, mod cmt, fnt odr, sptd It stn, gtd fluor 164 4909.05 24* 23.0 0.0 0.0 87.5 87.5 2.71 *Fractured Ka Sttst, gry, shty, mod cmt, pyr, n ocir, n stn, n fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 21 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 I I I I I I I I I ....-,PLEI DEPTH IPERI~EABILITYI I NUMBERI f t I md I I, I I I I POROSITY I % I RATIO I SATURATION I I OIL WATER TOTAL I DENSlTY (PERCENT PORE VOLUHE)I g/cc I COMMENTS CORE NO. 13 : 4912.00 - 4931.10 CUT 19.10' REC 19.00" 165 4912.65 1.8 14.4 0.0 0.0 80.6 80.6 3.08 166 4913.05 309* 24.8 0.0 0.0 92.4 92.4 2.68 *Fractured Ka 167 4914.00 2.4 21.2 0.0 3.1 83.6 86.7 2.69 168 4915.05 66 39.7 0.3 15.1 57.3 72.3 2.70 169 170 171 172 174 175 4916.00 54 33.2 0.3 18.3 72.1 90.4 2.68 4917.00 93* 31.8 0.2 15.1 71.7 86.8 2.68 *Fractured Ka 4918.05 138 41.5 0.1 11.9 80.6 92.5 2.67 4919.00 17 29.3 0.3 18.0 68.7 86.6 2.69 4920.00 119' 32.5 0.2 14.5 78.0 92.5 2.67 *Fractured Ka 4921.05 89 35.1 0.1 12.0 84.7 96.7 2.70 4922.00 75 35.4 0.2 14.3 74.5 88.8 2.69 LITHOLOGICAL DESCRIPTION Shl gry, shtyl v wt cmt~ pyr, n edr, n stn, n fluor Sh, gry, slty, mod cmt, n odr, n stn, n fluor Sh, gry, stty, mod cmt, fnt odr, sptd tt stn, gtd fluor Sst, gry, vfsd, prty cmt, fr odr, ev tt stn, gld fluor Sst, gry, vfsd shty, prty cmt, fnt odr, ev tt stn, gtd fluor Sst, gry, vfsd shly, nxxJ cmt, fnt odr, ev[t stn, gtd fluor Sst, gry, vfsd stty~ prty cml, fnt odr, ev tt stn, gtd fluor .Sst, gry, vfsd shty, mod cml, fnt odr, ev tt stn, gtd fluor Sst, gry, vfsd shty, mod cml, fnt odr, ev It stn, gtd fluor Sst, gry, vfsd stty, prty cml, fnt odr, ev It stn, gtd fluor Sst~ gry, vfsd stty, prty cmt~ fnt odr~ ev It stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING. SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 22 FILE NO.: 70080 DATE : NOVEMBER 21, RESULTS 1990 I I I "LEI NU.BER I 1 i I I DEPTH IPERMEABILITYJ ft I m~ I I I 176 4923.15 19 177 4924.05 40 178 4925.00 36 179 4926.00 54 --80 4927.00 78* 181 4928.00 60* 182 4929.05 23 183 4930.00 1090' i i i I I I SATURATION I I I I I GRAIN I POROSITY I 0/" I oil WATER TOTAL I DENSITY I J RATIO I (PERCENT PORE VOLUME)J g/cc J I COHMENTS JCORE NO. 13 : 4912.00 - 4931.10 CUT 19.10' REC 19.00' 30.5 0.2 15.7 68.0 83.7 2.70 33.0 0.1 10.2 80.3 90.5 2.69 32.5 0.1, 10.5 77.2 87.7 2.70 31.5 0.3 15.9 62.2 78.1 2.70 32.7 0.2 11.3 63.1 74.4 2.72 *Fractured Ka 32.0 0.1 8.1 68.2 76.3 2.70 *Fractured Ka 30.8 0.1 8.5 89.3 97.8 2.67 29.9 0.2 12.8 78.7 91.5 2.65 *Fractured Ka LITHOLOGICAL DESCRIPTION Sst, gry, vfsd s[ty, mod cmL, fnt odr, ev It stn, gtd fluor Sst, gry, vfsd sLty, prty-mod cmL, fnt oclr, ev it stn, gtd fluor Sst, gry, vfsd sLty, prLy-mod cmL, fnt odr, ev Lt stn, gLd fluor Sst, gry, vfsd stty, mod cmL, n odr, ev Lt stn, gLd fluor Sst~ gry, vfsd sLty~ mod cmL, n odr, ev Lt stn, gLd fluor Sst, gry, vfsd sLty, mod cmL, n odr, ev Lt stn, gtd fluor Sst, gry, vfsd sLty, mod cmL, n odr, strkd [t stn, gLd fluor Sst, gry, vfsd sLty, prty cmL, n odr, ev Lt stn, gtd fluor 184 4931.00 17 29.3 0.2 11.2 67.1 78.3 2.64 Sst, gry, vfsd stty, mod cmt, n odr, ev Lt stn, gLd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMAT I ON: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 23 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 RESULTS I I I I I/ .'LEI DEPTH IPERHEABILITYI J NU.BER I ft I md I L I I 185 4936.50 21' 186 4937.35 5.9 187 4938.00 71 188 4939.15 33 ~--~9 4940.00 40 190 4941.00 16 191 4942.10 52* 192 4943.00 87* 193 4944.00 12 194 4945.05 27* 195 4946.00 50* I I I I I SATURATION POROSITY I o/u I OIL UATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME) ICORE NO. 14 : 4936.00 - 4964.00 COHMENTS CUT 28.00' AEC 27.60' 33.4 0.0 3.4 90.2 93.6 2.69 *Fractured Ka 23.9 0.0 1.9 87.0 88.9 2.80 36.0 O. 1 6.5 65.0 71.5 2.70 26.1 0.1 6.6 84.8 91.5 2.71 35.0 0.1 7.2 90.9 98.1 2.66 27.7 0.1 5.8 91.7 97.5 2.68 34.2 0.2 14.3 83.1 97.4 2.68 *Fractured Ka 32.1 0.2 11.7 63.9 75.6 2.76 *Fractured Ka 31.5 0.0 2.6 87.4 90.0 2.76 32.9 0.1 10.3 83.8 94.1 2.69 *Fractured Ka 36.5 0.1 5.9 77.7 83.5 2.77 *Fractured Ka LITHOLOGICAL DESCRIPTION Sh, gry, stty, mod cmt, n odr, sptd [t stn, old fluor Sh, gry, stty, mod cmt, pyr, n odr, sptd It stn, gtd fluor Sst, gry, vfsd-fsd stty, prty cmt, n odr, ev tt stn, gtd fluor Sttst, gry, shty, mod cmt, pyr, n odr, strkd tt stn, gtd fluor Sttst, gry, shly, mod cmt, n odr, strkd tt stn, gtd fluor Sttst, gry, shly, ~ cmt, pyr, n odr, strkd [t stn, gld fluor Sttst, gry, shty, mod cmt, n odr, ev tt stn, gtd fluor Sttst, gry, shly, mod cml, n odr, ev It stn, gtd fluor Sltst, gry, shty, mod cml, n odr, sptd It stn, gtd fluor Sltst, gry, shty, mod cml, n odr, ev tt stn, gtd fluor Sttst, gry, sdy shty, mod cmt, pyr, n edr, strkd tt stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : AK CONVENTIONAL CORE ANALYSIS PAGE : 24 FILE NO.: 70080 DATE : NOVEMBER 21, 1990 RESULTS I I I I I I .... PLE I DEPT, IPERMEABILITYI NUMBER I ft I md I I I I I I I I I I SATURATZON I I I I I GRAIN I POROSITY I O/W I OIL ~ATER TOTAL I DENSITY I i RATIO I (PERCENT PORE VOLUME)I g/cc I I ICORE NO. 14 : 4936.00 - 4964.00 I COHMENTS CUT 28.00' REC 27.60' LITHOLOGICAL DESCRIPTION 196 4947.00 7.6 197 4948.00 27* 198 4949.00 23* 199 4950.00 24* 200 4951.05 21' 201 4952.00 18' 202 4953.05 5.5 203 4954.00 569* 204 4955.00 48* 205 4956.00 11 206 4957.00 6.3 20.1 O. 1 5.4 74.9 80.3 2.90 23.0 0.1 10.9 87.4 98.3 2.76 26.6 0.2 16.4 80.1 96.5 2.70 25.9 0.2 15.0 81.5 96.5 2.69 24.7 0.3 21.1 74.1 95.2 2.74 21.0 0.1 6.7 88.9 95.7 2.82 26.3 0.2 12.7 77.6 90.3 2.69 32.4 0.1 10.5 71.8 82.2 2.69 27.2 0.2 12.4 82.7 95.1 2.69 25.3 0,1 5.2 86.6 91.8 2.68 24.0 0.0 2.5 89.0 91.5 2.70 *Fractured Ka *Fractured Ka *Fractured Ka *Fractured Ka *Fractured Ka *Fractured Ka *Fractured Ka Sh, gry, st stty, ~ cmt, n odr, strkd tt stn, gtd fluor Sh, gry, st stty, mod cmt, pyr, n edr~ strkd It stn, gtd fluor Sh, gry, st stty, mod cmt, fnt odr, strkd It stn, gld fluor Sh, gry, st stty, mod cmt, n odr, strkd [t stn, gtd fluor Sh, gry, st stty, mod cmt, fnt (>dr, strkd It stn, gtd fluor Sh, gry, st stty, mod cmt, n odr, strkd tt stn, gtd fluor Sttst, gry, shty, mod cmt, n odr, strkd tt stn, gld fluor Sttst, gry, shty, mod cmt, n odr, strkd [t stn, gld fluor Sttst, gry, shty w/sh lam, mod cmt, n odr, strkd [t stn, gtd fluor Sttst, gry, shty, mod cmt, n'odr, strkd tt stn, gtd fluor Sttst, gry, shly, mod cmt, pyr, n odr, sptd tt stn, gtd fluor 4958.00 9.6 23.2 0.2 14.4 78.8 93.2 2.69 Sttst, gry, shty, mod cmt, n odr, sptd tt stn, gtd fluor COMPANY : CONOCO AK INC CORE TYPE: 4 INCH MUD, TYPE : WATER BASE FORMATION: PETROLEUM TESTING, SERVICE, INC. WELL : H-1 FIELD : HILNE POINT COUNTY: NORTH SLOPE STATE : AK PAGE : 25 FILE NO.: 70080 DATE : NOVEMBER 21, lggo CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I I I I I I SATURATION I I I SRAIN I ?LEI DEPTH IPERHEABILITYI POROSITY I OZW I OIL WATER TOTAL I DENSITY I CGNMENTS J NUHBER I ft J mci J X J RATIO I(PERCENT PORE VOLUHE)I g/cc J ' JCORE NO. 14 : 4936.00 - 4964.00 CUT 28.00' REC 27.60' I LITHOLOGICAL DESCRIPTION 208 4959.00 21' 23.9 0.0 3.3 89.7 93.0 2.75 *Fractured Ka 209 4960.00 11 21.3 210 4961.00 4.8 22.6 0.0 1.3 86.5 87.8 2.77 0.0 2.9 87'.6 90.5 2.75 211 4962.00 24* 22.7 0.0 4.0 90.4 94.5 2.72 *Fractured Ka 212 4963.50 29* 22.7 0.2 11.3 75.0 84.3 2.67 *Fractured Ka SLtst, gry, shLy, mod cmt, n Ddt, sptd it stn, g[d fluor SLtst, gry, sh[y, mod cmt, n odr, sptd [t stn, gtd fluor SLtst, gry, sh[y, mod cmt, pyr, n odr, sptd [t stn, gtd fluor Sttst, gry, shty, mod cmt~ n odr, sptd tt stn, gtd fluor SLtst, gry, shLy, mod cmt, n odr, sptd [t stn, gLd fluor PETROLEUM TESTING SERVICE, INC. POROSITY - PERMEABILITY CROSSPLOT CUENT: CONOCO AK INC STATE: ALASKA WELL: H-1 FIELD: MILNE POINT FILE No.: 70080 DATE: DECEMBER 1990 DEPTH INTERVAL, ft :4649.2- 4963.5 10000 1000 100 10 .1 LEAST-SQUARE REGRESSION EQUATION Permeobility = e( .07 x Porosity - .66) 0 10 20 50 40 50 POROSITY, perce~f, PETROLEUM TESTING; SERVICE, INC. GRAIN DENSITY - POROSITY CROSSPLOT CLIENT: CONOCO AK INC STATE: ALASKA WELL: H- 1 FIELD: MILNE POINT FILE No.: 70080 DATE: DECEMBER 1990 DEPTH INTERVAL, ft :4649.,3- 4963.5 3.50 3.00 2.50 z 2.00 1.50 ~m m m m m ! m m · , o ol: o - i~p a aaa a q~°a - _ o B'~ a a - o , ,, I I I ! ! 10 20 30 40 50 POROSITY, percenf ~ PETROLEUM TESTING SERVICE, INC. PERMEABILITY AND POROSITY HISTOGRAM CLIENT: CONOCO AK INC STATE: ALASKA WELL: H- 1 FIELD: MILNE POINT FILE NO.: 70080 DATE: DECEMBER 1990 DEPTH INTERVAL, ft: 4649.,3- 496,:3.5 100 9O -.'-. 8O ~ 70 >~ 50 Z O' 30 b., 20 10 Cumulat~e Fmquen~j ........ AHthmetic Mean 26.0 ...... Median Value 25.4 I: I: I: I: 'i ! I: I: t: I: I: · · · : I: 0 0 2 ~ 6 8 10 12 14 18 18 20 22 24 28 28 30 32 34 36 38 40 42 44. 46 POROSITY, percenf 100 ~ 9o p 70 >2 Z 60 Ld 50 0 50 ~- 2o <,; 10 ~ 0 0 100 90 ~ 8O o 70 ~ 60 ~ 50 Z ~.~ 40 0 30 ~' 20 10 ,, Cumul~e Frequent/ ........ OeometHc Mean 19. ..... Median Value 17. RECEIVED DEC 1 0 1993 Alaska Oil & Gas Cons. Commission Anchorage 0 PERMEABILITY, millidarcies r 100 ~ 90 80 70 >2 50 ~ 20:5 10 '~ 0 0 .,q 72) . ::<. ~) ff%--(D 0 g~'~'. PETROLEUbi TESTING SERVICE, ~xs SA~mL~NG LIST FILE: COb~/u'qY ' WELL: FIELD: Page / of 1) /-/~,9'q '37) 9'~, ,go° 73) UTV7 109} :2) ggSa .. 38) V~~ 74) .... 5) U~X.5 41) . q 69 ~ 77) .. 6) ~bS~ .. 42) .. ~ 78) .7) 7SXf 43). q&g~ 79) 8) 9a5~ 45) V&~5 ,.80) ..... ~?YY ...... 116) _9) 9gX7 45) q~L ...... 81) ~Tff 117) !0) ~E 46) V&~7 82) 11) ~bf~ 47) V~9~ 83) 13) u&& / 49) .. qT~ 85) 14) W~&~ 50) q7~/ ~86,) ..... 15) q~&3 51) F7:~z , 87) '16) e~&u 52) ~TD~ .... 88.) q'2g~ 12~),. 'i7) U~f '53) U~/? 89) 18) qg~g 54) VT/g ,,. 90) .!9) ~g7 55) 971~ 9i) 20) 9bbg 56) VTZO .~ 92) ,., 22) q~70 58) q?ZL 94) ~7~q. t30). 23) g bTI 59) WTZ. 3 95) 24) ggPZ ..... 60) 97~u .96) ..... ~2~/ . . l%?) 25) V~Tt 6!) 97.~s ...... ~7) s/~2l j3n). ~.6) ~TV 62) vPZ~ ..98) W?~5 .:, , . ],34~ , . , :27) ~ ~ 75 6~) tfTZ7 ~9) 28) q679 64) vTzg ]OO), ,, U¢)5 136) 29) WggO 65) U)F9 101) 977~ 13_7) 30) ~b~f _66) q~59 '[ ,, ]o2) ?77 ._]~a) 31) Va~Z 67) ~7~.! : 103~ 33) 9~ 69) 92¢3 ,,, lO5) ~4) q&~3' 70) qP3q ~ 10~ o 71) , Y735 . t07) . FILE: COb[PAxNY - WELL' FIELD: ,,~, PETROLEUH TESTING SERVICE, IF~-. PKS SAHPLING LIST Page ~ of ~ DA. TE ' ~ 7/9/ , ,. .. 1) z/~ 53... ['37) qg?5 73) V~15 109) .2) q~3~ .. 38).. gg2~ 74) V?f? .110) 3) qgi5 39). q3¢P ....... 75) ~/-~ 1 l 1) 4) qg~ 40) 9g~g ,76) ~q/S 112) ...5) Wg37 4}) . q3~ 77) ~1~ .. ~.) Vg35 ... 43) W~g] ... 79) q9~9 !15) 8) Wgg~3 44)... ~gg~ :-. 80) q~gO 9) ~g,¢t .. ~5).. ?gg5 .... 81) c~gzl 112) 10) ~q~ 46) ¢gfy 82) c~z~ :12) ~gvv 48) ~gg , 845 t~¢zv ..... 13) ~g~ .... ~ . 49) 9,fZ7 ,.$5). o?z7 14) u7¢C 50) vgg8 ~86) 15) ~g~ 7 51) q~9 87) q~Z) .123..) .17) qg'4q ...[ '53) ..... 9J49t 89) 0'220 1255 19) qSX / 55) 4'795 ~91). U {3) 127) ,20) USS } 56) ~Z~W ]92) ~?3g 21) ~ ~.~ ... 57) ~9~ 93) 993 7 22) 9 g~ 0 58) .. qg'9~ .... ~ 993f 230) , , . 23) ~SbJ 59) . Cgq7 95) 99~9 , 131) ...... I ............ .25) V%~ 5 61) qg 9~ .... 97) ~/¢v/ 133) .. 27) Vg~5 63) vga / 99) 9~V3 .... 28) ~g~L ,. 64) v~oz- loo) 97~ ~) '.29) ugg7 65) ~9~3 ._101) 99¢7 137) 31) ~g~9 67) V~3- 103) ~ 'Jb'? 32) '/3' 70 68) 9?o~ 104) vq ~g ]40) 3.4) 9~ 78 70) '/qog .... ].06) t?.7o 35) ~g75 _7~) 9~o9 zo7) v,.~.~ !~ 143) ....... ,, ECEIVED DEC 1 0 199;5 Aias~ Oil&GasCons. Commission DRILLING HISTORY ~chomge Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E objective: 5,131' MD- Schrader Bluff 09-10-90: MIRU. Accept rig at 1000 hrs 09-10-90. Clean rig & install flowline. MU 12 1/4" bit and BHA. spud at 1700 hrs. Drlg. f/ 115' to 383'. Mud wt. 8.9 Viscosity: 95 Cum Cost: $ 209,917 Nabors 27 (0-1-0) Drilling Foreman: Mountjoy 09-11-90: Trip for mud motor. Drlg f/383' to 1233'. Short trip 10 stands. Drlg f/1233' to 1787'. Mud wt. 9.1 Viscosity: 70 Cum Cost: $ 252,561 Nabors 27 (0-2-0) Drilling Foreman: Mountjoy 09-12-90: Drlg f/1787' to 2229'. Short trip 10 stds. 'Drill to 2815'. circ. Short trip. circ. POOH. Log w/ SP-NGT-DIL-SFL- LDT-CNL. $ 291 101 Mud wt. 9.2 Viscosity: 54 Cum Cost: , Nabors 27 (0-3-0) Drilling Foreman: Mountjoy 09-13-90: Finish logging. Wiper trip. Run 71 jts 9 5/8" K-55, 36~, Butt. FS @ 2705'. Circ. & recip, csg. Cement w/ ~82 bbl Artic Set and 52 bbl Class G cmt. Bump Plug. No cmt. returns to surface. Cum Cost: $ 470 680 Mud wt. 9.2 Viscosity: 41 ' Nabors 27 (0-4-0) Drilling Foreman: Mountjoy 09-14-90: PU & RIH w/ csg. cutter. Cut csg. MU spear & retrieve IH w freepoint. POOH. RIH w/ string shot and hanger & csg. R / _ · _ · MU s ear & RIH and 6' POOH w/ wlrellne & csg. P , back off @ 46 . - ..... ~--- ~ and back off @ 543 . POOH · ! ~ W S~I~ ~'~ . ' engage fish @ 466_. RI / .. ~T~ ~n~ R H w/ trlDle connection w/ fish. RIH and circ. POOh screw-in and cutlip OS guide w/ extension. Mud wt. 9.3 Viscosity: 41 Cum Cost: $620,768 Nabors 27 (0-5-0) Drilling Foreman: Mountjoy 09-15-90: Pump 10 bbls. water, 83 bbls. Artic set II, drop plug & displace. MU csg. to 10,000 ft-lbs torque. RD csg. crew & cementers. Cut csg., set out Hydrill and make final csg cut. Weld up and test to 1500 psi. OK. NU BOP & test BOP, choke man. & vlve. to 3000 psi. OK. PU BHA and orient MWD. RIH and tag cmt. @ 197'. Drlng. cmt. F/ 198' to 233'. Mud wt. 9.4 Viscosity: 37 Cum Cost: $688,278 Nabors 27 (0-6-0) D~r,i!liDq FQrema,n: Mountj_~Y 09-16-90: Drld cmt f/ 233' to 522'. Circ. and cond. Drld cmt and FC to 2734'. Test csg to 1500 psi. OK. Drl cmt and shoe to 2815. circ and cond. Drld to 2825' and ran leakoff test. Drld to 3874'. DRILLING HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E Objective: 5,131' MD- Schrader Bluff Short trip 11 stds. Drld f/ 3874' to 4567'. Circ. Mud wt. 9.1 Viscosity: 36 Cum Cost: $752,002 Nabors 27 (0-7-0) Drillinq Foreman: Mountjoy 09-17-90: Drld to 4649'. Circ & short trip to shoe. Disp. well w/ coring fluid. POOH and LD MWD & motor. PU core bbl & RIH to 4649'. Core to 4679'. POOH w/ core. Reload core bbl and RIH & core f/4679' to 4682'. Coring. Mud wt. 9.0 Viscosity: 37 Cum Cost: $784,082 Nabors 27 (0-8-0) Drillinq Foreman: Mountjoy 09-18-90: Cored f/4682' to 4689'. POOH, LD core barrel. RIH, core f/4689' to 4717'. POOH, LD core. RIH, core.~f/4717' to 4747'. POOH, LD core. RIH, core f/4747' to 4765'. Completed coring, prepare to POOH. Cum Cost: $ 853,639 Mud wt. 9.0 Viscosity: 43 Cum Mud Cost:$ 54,402 Nabors 27E(0-9-0) Drillinq Foreman: Mountjoy 09-19-90: POOH w/core #5, LD core, PU core barrel #6, RIH, core f/4765' to 4794'. POOH w/ core #6, LD core, PU core barrel #7, RIH, core f/4794' to 4801'. POOH w/ core #7, LD core barrel, PU core barrel #8, RIH, core f/4801' to 4807', still coring. Cum Cost: $ 897,195 Mud wt. 9.0 Viscosity: 36 Cum Mud Cost:$ 54,939 Nabors 27E(0-10-0) Drillinq Foreman: Polya 09-20-90: Core f/4807' - 4814'. POOH w/core #8 and LD. PU core barrel #9, RIH, core f/4814' - 4839', POOH w/ core #9 and LD. PU core barrel #10, RIH, core f/4839'-4857' Cum Cost~~ $ 939,956 Mud wt. 9.0 Viscosity: 37 Cum Mud Cost:$ 60,742 Nabors 27E(0-11-0) Drillinq Foreman: Polya 09-21-90: Continue coring f/4857' - 4859', POOH w/#10 core, LD core barrel. PU and RIH w/#ll core barrel, core f/4859' - 4882', POOH w/#ll core, LD core barrel. PU and RIH w/#12 core barrel, core f/4882' - 4912', POOH w/#12 core, LD core barrel. Cum Cost: $1,013,319 Mud wt. 9.0 Viscosity: 37 Cum Mud Cost:$ 63,186 Nabors 27E(0-12-0) Drillinq Foreman: Polya 09-22-90: LD core barrel #12. PU core barrel # 13, RIH, core f/4912' - 4936', POOH, LD core barrel #13. PU core barrel #14, RIH, core f/4936' - 4966', POOH, LD core barrel #14 . Pull wear RECEIVED DEC 1 0 199] Alaska Oil & Ba.~ P...o r.-_, ..... - · Y DRILLING HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E Objective: 5,131' MD- Schrader Bluff bushing, Test BOP and choke manifold. Cum Cost: $1,066,532 Mud wt. 9.0 Viscosity: 37 Nabors 27E(0-13-0) Cum Mud Cost:$ 64,090 Drilling Foreman: Polya 9-23-90: RIH w/ Drilling Assembly. Ream f/4870' - 4966'. Drlg f/4966'-5250'. CBU, mix and pump pill, blow down kelly. Wiper trip to 9 5/8" csg shoe @ 2792'. Circ & cond mud for logs. (Catch mud sample for loggers.) Drop single shot, pump pill, & blow down kelly. Pooh for logs. (SLM -- NO CORR.) R/U schlumberger logging unit. Logging: Run #l:Triple combo (Dil, LDT, CNT, NGT). Run #2: 4-Arm caliper (BGT). The single shot survey was unsuccessful -- Will repeat on the conditioning trip. Cum Cost: $ 1,098,106 Mud wt. 9.2 Viscosity: 36 Cum Mud Cost: $ 66,145 Nabors 27E(0-14-0) Drilling Foreman: Polya 9-24-90: Rerun logs. R/D Schlumberger. M/U bit & RIH to 5250' MD. Circ & cond. RIH w/ single shot on W/L w/ monel sensor devices. Unsuccessful. Rerun single shot w/ clocks. Mux & pump pill. POOH L/D DP & BHA. Pull wear bushing. R/U csg. crew and run 68 its of 7", 26#, L-80 Buttress csg. Cum Cost: $ 1,168,714 Mud wt. 9.4 Viscosity: 39 Cum Mud Cost: $ 69,415 Nabors 27E(0-15-0) Drilling Foreman: Polya 9-25-90: Finish running 7" csg. M/U csg. hanger, landing it., & cmt. head. Circ. hole while reciprocating pipe. Drop bottom plug and pump 70 bbls 11.0 ppg spacer, 10 bbls water. Test lines to 3000 psig. OK. Pump 89 bbls 15.8 ppg class g & displace w/ 177 bbls 9.2 ppg brine and 22 bbls diesel. Bump plug w/ 3050 psig and hold for 30 min. OK. Release press, floats held. R/D Dowell, cmt head, and landing joint. N/D BOP's, install pack off & test to 5000 psig. OK. N/U tree. Annular inject 610 bbls inhibited drilling fluid and 65 bbls diesel. Released rig @ 2300 hrs. Cum Cost: $ 1,394,196 Mud wt. 9.4 Viscosity: 39 Cum Mud Cost: $ 69,415 Nabors 27E(0-16-0) Drilling Foreman: Polya RECEIVED DEC 1 0 199 Alaska Oil & Gas Cons. Commission Anchorage DEPTH 0.00 411.00 ~-~,~.~0 650.08 '76S.00 924.8~ I018.00 t15~.~ WELL Si ~RY SUN Page I 9-9-1990 AK-MW-00108 · 7 E.,-,, T I CAL DOG SECT ! ON LEG 0.00 0.00 0.39 ,D. 07 1.98 re,,. 78 r-, 4 -'" o. I .:,. 0,6 ,.,.~ ,-' u 8'7 ~ / -~.. c) ~ .I 5:?8 9'"' D 5 .1 , ,.2 "=' 1 I/ I <:'~., .... ¢7 I . 96 '-' ~a'_ t£) . (~ CD dj ,, '7 ..'L 2011 '-'"' 0 '7 · [J:o. 60 1 98 RECEIVED DEC 1 0 1993 Alaska Oil & Gas Cons. Commission ~ Anchora~Te Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 August 25, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU H-l; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for reclassifying Milne Point Unit well H-1 from an oil well to a service well. As discussed at our August 24, 1993 meeting, MPU H-1 has marginal value as an oil producer, but has considerable value as a service well for testing new completion and production technologies. The H-1 has not been completed because of the lack of productive pay. The 'N' sands are oil-filled, while the 'O' sands are transitionally wet. Log analysis indicates 26 feet of 'N' net sand and 9 feet of 'O' net sand. For comparison, Tract 14 Schrader Bluff wells average 40 feet of 'N' net sand and 40 feet of 'O' net sand. With this pay thickness the H-1 will be a marginal producer. Conoco has been working with several service companies in the development of a coiled tubing deployed ESP system. The design phase of this project is essentially complete and the system is ready for a field test. In its current state, the H-1 wellbore provides an excellent opportunity for testing this, and other, new technologies prior to installation in active wells. Currently, there are no other wells available at Milne Point for this kind of testing. REEEIVED AU G 2 G 199, Alaska 0il & Gas Cons. Commiss[o~ Anchorage Mr. DavJd Johnston.~ August 25, 1993 j Page 2 Please direct any questions regarding this matter to our Senior Production Engineer, Bruce Augustine, at 564-7633. Sincerely, Tom Yeager ~J SHEAR Specialist Attachment CC; BGA, TJY Chevron Occidental H-1 Well File RECEiVeD Alaska Oil & Gas Cons. Oommiss~O~ Anchorage STATE OF ALASKA ALASKA ,.~IL AND GAS CONSERVATION COMMIS~,. N L.,,/X~) APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon__ Suspend Operation shutdown _ Re~nle, suspended well ~/,,~ Alter casing Repair well __ Plugging __ Time extention Stimu a e Change approved program Pull tubing Variance Perforate Other X Reclassify from oil well to service well 5. Type of Well: 6. Datum elevation (DF or KB) Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 Location of well at surface 2542' FNL, 4070' FEL, Sec. 34, T13N, R10E, U.M. At top of productive interval 3950' FNL, 2750' FEL, Sec. 34, T13N, R10E, U.M. At effective depth NSB AK NSB AK At total depth 4322' FNL, 2400' FEL, Sec. 34, T13N, R10E, U.M. NSB AK Development __ Exploratory __ Stratigraphic __ Service X KB 35 (AG[.) 7. Unit or Property name Milne Point Unit 8. Well number H-1 9. Permit number 10. APl number 50-029-22061 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured 5242 feet Plugs (measured) true vertical 4506 feet None Effective depth: measured feet Junk (measured) true vertical feet None Casing Length Size Cemented Structural Conductor 115' 13-3/8" Surface Surface 2828' 9-5/8" Surface Intermediate Production 5257' 7" TOC@ ± 3600' Uner Perforation Depth: measured Not Perforated true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) None Measured depth 80' 2793' 5222' True vertical depth 80' 2491' 4489' RECEIVED AU G 2 6 199;5 Alaska 0il & Gas Cons. commissio~ Anchorage 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation September 15, 1993 16. If proposal was verbally approved 15. Status of well classification as: Oil .... Gas __ Suspended Name of approver 17~l-he~eby certify ~at the foregoing is true and correct to the best of my knowledge. Signe (~=x -'[L°~'?- ¥c.,{"- B. G. Augustine Title Sr. Production Engineer ~ i_~ FOR COMMISSION USE ONLY Date approved Service X Equipment Testin,q Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- .~'~ ! Original Signed By David W. johnston Commissioner Approved by order of the Commission Form 10-403 Rev 06/15/88 Date August 25, 1993 I Approval No.? o~ :q~provccl Copy Returned r ! SUBMIT IN TRIPLICATE WELL No. H-1 CASING SKETCH MILNE POINT UNIT APl No.: 50-029-22061 PERMIT No.: 90-86 DRILLED: 9/25/90 ARCTIC PACKED: OPEN (P) OPERATOR: CONOCO INC. SURFACE LOCATION: 5542' FNL, 4070' FEL, SEC ,34, TI,3N, RIOE U.M. BOTTOM HOLE LOCATION: 4522' FNL, 2400' FEL, SEC. 34, T15N, R10E, U.M. SPUD DATE: 9/10/90 RKB 34' 22 BBLS DIESEL 175 BBLS ~' 9.2 PPG NaCI WKM CSG SPOOL 13 3/8", 54.5#, K-55, WELD SET @ 105' CEMENT DATA: 500 SKS PERMAFROST "C" @ 14.8 PPG ARCTIC PACK DATA: 51 BBLS, 15.6 PPG, PERMAFROST "C", 60 BBLS DEAD CRUDE 9 5/8", 36#, K-55, BTRC, SET @ 2793' CEMENT DATA: 282 BBLS ARCTIC SET IV @ 12.3 PPG, 52 BBLS OF CLASS "G" @ 15.8 PPG W/ 0.2% D-046 & 5.0% S-001 EST TOC @ 3600' --RA TAG @ 4613' PBTD 5146' TD 5250' CONOCO I'NC. ANCHORAGE DI~SION 7", 26#, L-80, BTRC SET @ 5222' CEMENT DATA: 89 BBLS (454 SKS)"G" CMT @ 15.8 PPG W/ 0.2% D-046, 0.8% D-127 & 1.0% S-001 RECEIVED AU 6 2 6 199,~ Alaska Oil & Gas Cons. Oommissio~ Anchorage APPROVED BY: HDS DATE: 7/7/92 DRAFTED BY: SJN/CFP CAD FILE: WCAH1 ALASKA OIL AND GAS CONSERVATION COMMISSION August 2, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Anchorage, Alaska 99503 Re: Milne Point Unit Well H-1 -- Noncompliance Operation Shut Down Dear Mr. Yeager: A. review of our well records and correspondence shows a shutdown of well operations on Milne Point Unit H-1 expired on April 12, 1992. At that time operations were to be resumed or the well was to be plugged and abandoned according to 20 AAC 25.072. By correspondence dated March 1, 1993, (see attached letter) you were notified of the noncompliance condition of the weI1 and afforded the opportunity to apply for suspension of the well under 20 AAC 25.110. To date, no application for suspension has been received. The condition of well H-1 is out of compliance with 20 AAC 25.072, and you must show cause why the well should not be immediately abandoned as required by the referenced regulation. The Commission requests your response to this notice within 15 working days from the receipt of this letter. If no response is forthcoming, the Commission has no choice but to order plugging and abandonment of the well under 20 AAC 25.072. Sincerely, Enclosure 3201 C Street, ,Suite 200 At. borage, AK 99503-3999 (eOT) Decem~r 11, 1992 Mr. David W, Johnston Chairman Ala,ska Oil and Ga= Coneervation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Johnston, In October of 1990, the Commission approved a request from Conoco, inc. to shut down well operations on-~Vlilne Pont Unit well H-I. At the time this shutdown occurred, MPU H-1 had been cased and cemented, but not perforated. The decision to delay completion of H-1 was based on logging results that indicated marginal productivity. Due to the intervention of higher priority projects, a determination on the best course of action for the H-1 well has yet to be made. In addition to completion as a Schrader Bluff 'producer, the options under consideration include completion as a .waterflood injector, utilization as a disposal well and abandonment. In order to have sufficient time to determine the final disposition of this well, we are requesting that the period of shutclown t:)e extenclecl an a(Jclitional 12 months, until December of 1993. Please direct any questions regarding this matter to me at 564-7660. Sincerer, SHEAR Specialist. att: CC: CVL, BGA, FWG/GDF H-1 Well File ~00'3~Ud ~S:S[ C6, S WELL No. H- 1 CASING SKETCH MILNt~ POINT UNIT (P) ~a! No,: 50-029-22051 P£RbllT No,; 90-86 ARCTiC PACKED: OPEN r;,PFRAT,?~- r':.nN(~x9 INC. SURFACE LOCATION: 5542' FNL, 4070' FEL. SEC 54. T15N. RIOE U,M, BOTTOM HOLE LOCATION: 4322' FNL, 2400' FEL, SEC. ,.94, TISN, RIOE, UM. SPuD DA~: g/~O/gO RKE 34' 22 E~IL$ DIESEl. 17~ BE]iLS 9,2 PPg NoCl SPOOL WELD SET g 105' ~;K~ 'I~&'i~MA~RO.~T "C' ~D 14-.8 PPG: ARCTIC PACK DATA: 51 BELLS, 1,5.6 PPG, PERN4^F'ROST '*C". 60 BBLS DEAD CRUDE g 5/8', 36~, K-55, BTRC, :S~:T ~ 2793' CEMENT DATA: :282 BBLS ARCTI~ S~T IV ~ 1~.~ PP~, 52 8~S ~ ~ASS "~ e 15,8 ~G W/ O. 2[ D-O46 · 5-0~ $-001 EST TOC @ 5600' RA TAG ~ 4613' PE~TD 5146' TI) 5250' ...,.....,_.~~ 7". 26i~, L-80, EtTRC SET e 5222' (.,'Ei,,I[N)' DAIA; ~g BELLS (4,94 SKS)'G' CMT ~ 1,9,8 PPG W/' 0,2[ D-046, 0,8% D-127 ~ 1,0% S-'-001 CONOCO INC. ANCHORAGE DIVISION APPEC~VFI1 RY- HITI.~ DRAFTED BY: SJN,/CFP CAD FILE: WCAHl ALASKA OIL AND GAS PETROLEUM WELL RECORD CONSERVATION COMMISSION 06/09/92 90- 0086- 0 0292206100 MILNE POINT UNIT H- 1 ~t01 ADL 2 ~ ............................................ OPER C-ODE , O P ERECTOR NA/~E ,' CODEJ , .......................... GEOLOGIC A/~ E~k '[ ON- $~ORR OFF ~600 CONOCO INC 890 ~CTIC SLOPE ON ...................................................................... FLDPOL FIELD ~D POOL ~ ~LTI - COMP ~ ~MB ~ LOG CODE ~ N~E ~ FLD&POOL ~ FLU&POOL ~ COMP ~ LOCAL oooooo oooooo ........................................................................ I UNIT UNIT I ELEVATIONS I DEPTHS CODE I N~E I CODE I FEET I CODE I FEET I MD I ~D ..... I ................................ I .... I .... I .... I .... I ...... I ...... , 11328 MILNE POINT _~ ....................................................................... SURFACE LOCATION I BOTTOM ~OLE LOCATION { .... I I .... I I---I I .... I I .... I I .... I---I I I .... I I ........................................................................ LATITUDE I LONGITUDE I FOOTAGE DRILLED IPERM ISSSV I IDEGIMINI SEC IDEGIMINI SEC IYEARIFEET IYEARIFEET IYEARIFEET IT~IC~IDmPT~I I I ..... I I---I ..... I .... I ..... I .... I-- I .... I ..... I ..... I ..... I 70 26 15.60 149 32 19. 31 I I .~SSlSTATUSlCLASSlSTATUSlCLASSlSTATUSlSAMPLI MUD I ~R IOT~ERITSTIACCTGI ..... I ...... I .....I ......I .....I ......I .....I .....I-~D-- I ..... I---I ..... I DEV i-OIL YES YES ~ NO 551081 .................................................... % __~ ................. + PERMIT I PERMIT I DATE I DATE I STATUS I RECORD I APPROVED I ISSUED I~ COMP, ETCI DATE I LAST UPD I ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 'i'ELECOPY: (907) 276-7542 March 1, 1993 Tom Yeager Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Dear Mr. Yeager: The provisions of 20 AAC 25.072 allows for shutdown of well operations for a period of 12 months with no provisions for time extension. Therefore the Commission cannot approve your December 11, 1992 request to extend the shutdown of operation for the Milne Point Unit well H-1. However, the Commission would consider an application to suspend the well pursuant to the requirements of 20 AAC 25.110 and any exceptions that may be necessary. If you would care to discuss this further please contact Russ or myself at 279-1433. Chairman ~ prinled on recycled paper b y C.D. December 11, 1992 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 . / . (907) 564-760~f'),,' .'3R ENG '~ SR ENG , ENG ASST I i ENG ASST ! , SR GEOL I GEOL ASSTI ~ILE £ Dear Mr. Johnston, In ®ctober of 1990, the Commission approved a request from Conoco, Inc. to shut down well operations on Milne Pont Unit well H-1. At the time this shutdown eccurred, MPU H-1 had been cased and cemented, but not perforated. The decision to delay completion of H-1 was based on logging results that indicated marginal productivity. Bue to the intervention of higher priority projects, a determination on the best course of action for the H-1 well has yet to be made. In addition to completion as a Schrader Bluff producer, the options under consideration include completion as a waterflood injector, utilization as a disposal well and abandonment. In order to have sufficient time to determine the final disposition of this well, we are requesting that the period of shutdown be extended an additional 12 months, until December of 1993. Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist att: CC: CVL, BGA, FWG/GDF H-1 Well File RECEIVED DEC 1 6 1992 Alaska 0il & Gas Cons. (;0remission' Anchorage WELL No. H-1 CASING SKETCH MILNE POINT UNIT (P) APl No.: 50-029-22061 PERMIT No.: 90-86 DRILLED: 9/25/90 ARCTIC PACKED: OPEN OPERATOR: CONOCO INC. SURFACE LOCATION: 5542' FNL, 4070' FEL, SEC 54, T13N, RIOE U.M. BOTTOM HOLE LOCATION: 4522' FNL, 2400' FEL, SEC. 54, T15N, RIOE, U.M. SPUD DATE: 9/10/90 RKB 34' 22 BBLS DIESEL ~ WKM CSG SPOOL 175 BBLS ~ 9.2 PPG NoCI 13 3/8", 54.5#, K-55, WELD SET @ 105' CEMENT DATA: 500 SKS PERMAFROST "C" @ 14.8 PPG ARCqC PACK DATA: 51BBLS, 15.6 PPG, PERMAFROST "C", 60 BBLS DEAD CRUDE 9 5/8", 56#, K-55, BTRC, SET @ 2795' CEMENT DATA: 282 BBLS ARCTIC SET IV @ 12.3 PPG, 52 BBLS OF CLASS "G" @ 15.8 PPG W/ 0.2% D-046 &: 5.0% S-001 EST TOC @ 3600' --RA TAG @ 4613' PBTD 5146' TD 5250' CONOCO INC. ANCHORAGE DIVISION 7", 26#, L-80, BTRC SET @ 5222' CEMENT DATA: 89 BBLS (4,34 SKS)"G" CMT @ 15.8 PPG W/ 0.2% D-046, 0.8% D-127 &: 1.0% S-001 RE6EIVED DEC 1 6 1992 Alaska Oil & Gas Cons. L;ummismo~' An~horafle APPROVED BY: HDS DATE: 7/7/92 DRAFTED BY: SJN/CFP CAD FILE: WCAH1 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 April 5, 1991 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Wells J-l, J-2, J-3 and J-4 Applications for Sundry Approvals Dear Mr. Smith: Attached are the Applications for Sundry Approvals (Form 403) requesting approval to complete the MPU wells J-l, J-2, J-3 and J-4 with a workover rig. If there are any questions pertaining to these wells please call me at 564-7625. Very truly yours, .~V~n~erge~ Sr. Production Engineer cc: CVL, PMS, Sr. Production Foreman, J-l, J-2, J-3 and J-4 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMIb,,,,JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program m Operation shutdown Re-enter suspended well Plugging __ Time extention Stimulate X Pull tubing Variance Perforate X Other ....X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 LoCation of well at surface 2677' FNL, 3354' FEL, Sec. 28, T13N, RIOE, U.M. At top of productive interval 1940' FNL, 350' FEL, Sec. 28, T13N, RIOE, U.M. At effective depth 5. Type of Well: Development Exploratory Stratigraphic NSB AK At total depth 1798' FNL, 230' FEL, Sec. 27, T13N, RIOE, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35 AGL 7. Unit or Property name Milne Point Unit 8. Well number 9. Permit number 10. APl number 50-029-22061 NSB AK feet Schrader Bluff 12. Present well condition summary Total depth: measured 6205 feet true ver'dcal 4319 feet Effective depth: measured feet flue vertical feet Casing Length Size Structural Conductor 115' 13-3/8" Surface 2955' 9-5/8" Intermediate Pmduction 6214' 7" Liner Perforation Depth: measured flue vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Surface 80' 80' Surface 2920' 2381' T.O.C. @ 4200' 6179' 4300' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation April, 1991 16. If proposal was verbally approved Name ot approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~----_~, ~-------~ Lineberger Tit~e Sr. Production Engineer ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LO~,IE ~. RMITH IApproval No. ~/_ / / ~.~ SUBMIT IN TRIPLICATE MILNE POINT UNIT J-2 WELL PROPOSED COMPLETION PROCEDURE - SUMMARY 4/4/91 - CVL NOTE: Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on J-2 well. Test BOP's. 2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean. · · · · · · · 10. 11. RU electric line. Run Gyro survey (if necessary). Set gravel pack sump packer below the proposed "O" sand perf's. Correlate with open hole logs and perforate "0" sands at 12-24 SPF over 5781'-823' and 5865'-900' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 20 bbls. Kill well and POOH. RD electric line. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. Perforate "N" sands at 12-24 SPF over 5568'-600', 5608'-25', 5645'-55', and 5675'-705' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 2'0 bbls. Kill well and POOH. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. Leave well shut in until surface equipment installation is complete. C. Van Lineb~er Sr. Prod. Engineer November 5, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant' Enclosed are the following data from Conoco's Milne Point Unit H-1 well, which is located in Section 34, T 13N , R 10 E on the North Slope of Alaska. The API number for this well is 50-029-22061. Mudlogs One blueline and one sepia print of the each of the following: Type Scale 1) 2 inches : 100 feet 2) 2 inches : 100 feet Mudlog, Measured Depth Mudlog, True Vertical Depth Depth 1,600' - 5,250' 1,520' - 4,516' Core Data 1) Correlation Core Graph 5 inches = 100 feet 4,600' -4,850' 2) Correlation Core Graph 5 inches : 100 feet 4,850' -5,100' Chips from the 14 conventional cores in this well will be hand delivered by Mr. Don Graika of Petroleum Testing Services. These and all other data from the H-1 well are CONFIDENTIAL and should be handled accordingly. To confirm arrival of these data and samples, please sign the attached copy of this letter and return it to me. Should you have any questions, telephone me at (907) 564 - 7640. Sincerely, Steve Davies Staff Geologist cc: R.F. Wheeler 301.02.07 RECE[VED NOV 0 6 ,,':;,:'~.' ,, Alaska Oil & Gas Cons. Co rnissij~/ Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 October 26, 1990 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are the following data from Conoco's Milne Point Unit H-1 well, which is located in Section 34, T 13N , R 10 E on the North Slope of Alaska. The API number for this well is 50-029-22061. Cuttinq~ 1) Dry well cuttings: 2 boxes Depth range: 1,600' - 3,880' MD. 3,880' - 5,250' MD. Additional Data Chips from conventional cores I through 14 will be delivered by Mr. Don Graika of Petroleum Testing Service, Inc. These and all other data from the H-1 well are CONFIDENTIAL and should be handled accordingly. To confirm arrival of these data and samples, please sign the attached copy of this letter and return it to me. Should you have any questions, telephone me at (907) 564 - 7640. Sincerely, Steve Davies Staff Geologist SFD(lms) cc: R.F. Wheeler 301.02.07 October 10, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE' Milne Point Unit Wells H-1 and H-2 Report of Sundry Well Operations Attached is the Report of Sundry Well Operations (Form 404) and the summary of operations for Milne Point Unit wells H-1 and H-2. Also attached is a copy of the MWD directional survey. A final copy of the gyro survey will be filed with Form 407 when these wells are completed. If there are any questions pertaining to these wells please call me at 564-7637. Very truly Yours, Sr. Drilling Engineer RSR/jcd cc' MPS file # 500.21.08 RECEIVED OCT 1 919. 0 011 & Gas Cons. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performeD: Operation st3utdown ~ Stimulate __ Plugging Pull ruling ~ Alter casing ~ Repar well Pedorate __ Other __ 2. Name of Operator Conoco Inc. 3. A~dress Suite 200 3201 C Street, Anchorage, AK 99503 4, Location pt well at surface 2542' FNL, 4070' FEL, At top of productive interval 3950' FNL, 2750' FEL, At effective depth At total depth 4322' FNL, 2400' FEL, Sec. 34, Sec. 34, Sec. 34, 12. Present well condition summary Total depth: 5242 measured 4506 true vertical 5. Type of Well: Development Exploratory Straugrapnic SerV'ce T13N, RIOE, U.M., NSB, Alaska T13N, RIOE Ti3N, RIOE feet Plugs (measured) feet 6. Datum elevation (DF or KB) KB 35' AGL 7. Unit or Property name Milne Point Unit 8. Well number 9. Permit number/approval number 90-86 10. APl number 50-- 029-22061 11. FielOlPool Schrader Bluff feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Structural Conductor 115 ' 13- 3 / 8" Surface 2828 ' 9-5/8" Intermediate Production 5 2 5 7 ' 7" Liner Perforation depth: measured Cemented Surface Surface TOL 3500' Measureddepth 80' 2793' 5222' ~ue~dicaldepth 80' 2496' 4489' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) RECEIVED 14. Treatment descripti9n including volumf~ used and fiqai pressure Operation shutdown penalng comp±anion. Representative Daily Average ProOuct~on or Injection Data Prior to well operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Subseouent to operation 15. Attachments 16. Status pt well ctass~/icatlon as: Copies of Logs and Surveys run MWD Dally Report of Well Operations ~" Oil, X Gas Suspended 17. I hereOy cert~ly that the foregoing is true and correct to We best of my knowledge. Service Sianed ' Form 10-404 Rev 06115/88 $;' ' ' Title Sr. - 44 - Drilling Engineer Date 10/10/90 SUBMIT IN DUPLICATE DRILLING HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E Objective: 5,131' MD- Schrader Bluff 09-10-90: MIRU. Accept rig at 1000 hrs 09-10-90. Clean rig & install flowline. MU 12 1/4" bit and BHA. Spud at 1700 hrs. Drlg. f/ 115' to 383'. Mud wt. 8.9 Viscosity: 95 Cum Cost: $ 209,917 Nabors 27 (0-1-0) Drilling Foreman: Mountjoy 09-11-90: Trip'for mud motor. Drlg f/383' to 1233'· Short trip 10 stands. Drlg f/1233' to 1787'. Mud wt. 9.1 Viscosity: 70 Cum Cost: $ 252,561 Nabors 27 (0-2-0) Drilling Foreman: Mountjoy 09-12-90: Drlg f/1787' to 2229'. Short trip 10 stds. Drill to 2815'. Circ. Short trip. Circ. POOH. Log w/ SP-NGT-DIL-SFL- LDT-CNL. Mud wt. 9.2 viScosity: 54 Cum Cost: $ 291,101 Nabors 27 (0-3-0) Drilling Foreman: Mountjoy 09-13-90· Finish logging Wiper trip Run 71 jts 9 5/8" K-55 · · · , ~ 36#, Butt. FS @ 2705'· Circ. & recip, csg. Cement w/ 282 bbl Artic Set and 52 bbl Class G cmt. Bump Plug. No cmt. returns to surface· Mud wt. 9.2 Viscosity: 41 Cum Cost: $ 470,680 Nabors 27 (0-4-0) Drilling Foreman: Mountjoy 09-14-90: PU & RIH w/ csg. cutter. Cut csg. MU spear & retrieve hanger & csg. RIH w/ freepoint. POOH. RIH w/ string shot and back off @ 466'. POOH w/ wireline & csg. MU spear & RIH and engage fish @ 466'. RIH w/ string shot and back off @ 543'. POOH w/ fish. RIH and circ. POOH. RU and RIH w/ triple connection screw-in and cutlip OS guide w/ extension. Mud wt. 9.3 Viscosity: 41 Cum Cost: $620,768 Nabors 27 (0-5-0) Drilling Foreman: Mountjoy 09-15-90: Pump 10 bbls. water, 83 bbls. Artic set II, drop plug & displace. MU csg. to 10,000 ft-lbs torque. RD csg. crew & cementers. Cut csg., set out Hydrill and make final csg cut. Weld up and test to 1500 psi. OK. NU BOP & test BOP, choke man. & vlve. to 3000 psi. OK. PU BHA and orient MWD. RIH and tag cmt. @ 197'. Drlng. cmt. F/ 198' to 233'. Mud wt. 9.4 Viscosity: 37 Cum Cost: $688,278 Nabors 27 (0-6-0) Drillinq Foreman: Mountjoy 09-16-90: Drld cmt f/ 233' to 522'. Circ. and cond. Drld cmt and FC to 2734'. Test csg to 1500 psi. OK. Drl cmt and shoe to 2815. Cir¢ and cond. Drld to 2825' and ran leakoff test. Drld to 3874'. Y DRILLING HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E Objective: 5,131' MD- Schrader Bluff /. Short trip 11 stds. Drld f/ 3874' to 4567'. Circ. Mud wt. 9.1 Viscosity: 36 Cum Cost: $752,002 Nabors 27 (0-7-0) Drilling Foreman: Mountjoy 09-17-90: Drld to 4649'. Circ & short trip to shoe. Disp. well w/ coring fluid. POOH and LD MWD & motor. PU core bbl & RIH to 4649'. Core to 4679'. POOH w/ core. Reload core bbl and RIH & core f/4679' to 4682'. Coring. Mud wt. 9.0 Viscosity: 37 Cum Cost: $784,082 Nabors 27 (0-8-0) Drilling Foreman: Mountjoy 09-18-90: Cored f/4682' to 4689'. POOH, LD core barrel. RIH, core f/4689' to 4717'. POOH, LD core. RIH, core f/4717' to 4747'. POOH, LD core. RIH, core f/4747' to 4765'. Completed coring, prepare to POOH. Cum Cost: $ 853,639 Mud wt. 9.0 Viscosity: 43 Cum Mud Cost:$ 54,402 Nabors 27E(0-9-0) Drilling Foreman: Mountjoy 09-19-90: POOH w/core #5, LD core, PU core barrel #6, RIH, core f/4765' to 4794'. POOH w/ core #6, LD core, PU core barrel #7, RIH, core f/4794' to 4801'. POOH w/ core #7, LD core barrel, PU core barrel #8, RIH, core f/4801' to 4807' still coring Cum Cost: $ 897,195 Mud wt. 9.0 Viscosity: 36 Cum Mud Cost:$ 54,939 Nabors 27E(0-10-0) Drilling Foreman: Polya 09-20-90: Core f/4807' - 4814'. POOH w/core #8 and LD. PU core barrel #9, RIH, core f/4814' - 4839', POOH w/ core #9 and LD. PU core barrel #10, RIH, core f/4839'-4857' Cum Cost: $ 939,956 Mud wt. 9.0 Viscosity: 37 Cum Mud Cost:$ 60,742 Nabors 27E(0-11-0) Drilling Foreman: Polya 09-21-90: Continue coring f/4857' - 4859', POOH w/#10 core, LD core barrel. PU and RIH w/#11 core barrel, core f/4859' - 4882', POOH w/#ll core, LD core barrel. PU and RIH w/#12 core barrel, core f/4882' - 4912', POOH w/#12 core, LD core barrel. Cum Cost: $1,013,319 Mud wt. 9.0 Viscosity: 37 Cum Mud Cost:$ 63,186 Nabors 27E(0-12-0) Drilling Foreman: Polya 09-22-90: LD core barrel #12. PU core barrel # 13, RIH, core f/4912' - 4936', POOH, LD core barrel #13. PU core barrel #14, RIH, core f/4936' - 4966' POOH LD core barrel #14 Pull wear Y DRILLING HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point H No. 1 (P) CONFIDENTIAL AFE 10-61-1259 Location: 4070' FEL, 2542' FNL, Sec. 34, T13N, R10E, Umiat Meridian Location: Bottom hole, 2750' FEL, 3950 ' FNL, Sec. 34, T13N, R10E Objective: 5,131' MD- Schrader Bluff bushing, Test BOP and choke manifold. Cum Cost: $1,066,532 Mud wt. 9.0 Viscosity: 37 Nabors 27E(0-13-0) Cum Mud Cost:$ 64,090 Drilling Foreman: Polya 9-23-90: RIH w/ Drilling Assembly. Ream f/4870' - 4966'. Drlg f/4966'-5250'. CBU, mix and pump pill, blow down kelly. Wiper trip to 9 5/8" csg shoe @ 2792'. Circ & cond mud for logs. (Catch mud sample for loggers.) Drop single shot, pump pill, & blow down kelly. Pooh for logs. (SLM -- NO CORR.) R/U schlumberger logging unit. Logging: Run #l:Triple combo (Dil, LDT, CNT, NGT). Run #2: 4-Arm caliper (BGT). The single shot survey was unsuccessful -- Will repeat on the conditioning trip. Cum Cost: $ 1,098,106 Mud wt. 9.2 Viscosity: 36 Cum Mud Cost: $ 66,145 Nabors 27E(0-14-0) Drilling Foreman: Polya 9-24-90: Rerun logs. R/D Schlumberger. M/U bit & RIH to 5250' MD. Circ & cond. RIH w/ single shot on W/L w/ monel sensor devices. Unsuccessful. Rerun single shot w/ clocks. Mux & pump pill. POOH L/D DP & BHA. Pull wear bushing. R/U csg. crew and run 68 jts of 7", 26#, L-80 Buttress csg. Cum Cost: $ 1,168,714 Mud wt. 9.4 Viscosity: 39 Cum Mud Cost: $ 69,415 Nabors 27E(0-15-0) Drilling Foreman: Polya 9-25-90: Finish running 7" csg. M/U csg. hanger, landing jt., & cmt. head. Circ. hole while reciprocating pipe. Drop bottom plug and pump 70 bbls 11.0 ppg spacer, 10 bbls water. Test lines to 3000 psig. OK. Pump 89 bbls 15.8 ppg class g & displace w/ 177 bbls 9.2 ppg brine and 22 bbls diesel. Bump plug w/ 3050 psig and hold for 30 min. OK. Release press, floats held. R/D Dowell, cmt head, and landing joint. N/D BOP's, install pack off & test to 5000 psig. OK. N/U tree. Annular inject 610 bbls inhibited drilling fluid and 65 bbls diesel. Released rig @ 2300 hrs. Cum Cost: $ 1,394,196 Mud wt. 9.4 Viscosity: 39 Cum Mud Cost: $ 69,415 Nabors 27E(0-16-0) Drilling Foreman: Polya TABLE OF C!]!'.FT'EblTS SEC]'It]I'~.! V I SERVICF_ OBJECTIVP'-q~._~.. AND RESULTS RESUL TS: MWD A: DRILL DOWN 'TO 350' MD, AND OR!ENT BENT HOUSING MOTOR ,. ....... I IBL, MO'TOR tiNABLE 1'0 T'AKE ANY WIEGHT TRIF' OUT FOR NEW MOTOR AT 379' MWD B: CONTINUE KICK-OFF~ BUILDING ANGLE -F(] A MAXIMUM OF 37,,;~ DEGREES. ROTARY DRILLED~ WITH SOME ORIENTING "FO A MD 2Bi5'. SET 9 5/~" CASING. LACK OF RETURNS TO THE SUf~FACE ON THE CEMENT JOB CAUSED SOME DELAY. HWD C: DRILLED OUT OF CSG SH(]E T'O A TD (DF 4649' MD. L. AYED THE MUD MOTOR AND MWD "}"00L~ AND PICKED UP A CORE BARREL. THE PLAN IS -FO 'm'-, LL. 300' [.,-~I OF COREC~ AND "rD THE WEL. L A'I' RPF:'ROX IMATELY 5200 ' MD. }'.~ PROBLEMS INVOLVING MWD "FOOL.. WELL SUMMARY RIG ! l-',_~lrERl'i KB ELEVATiOi'I KB REFERENCE SLURFACE LOCA'TION MAGNET iC PARAME'TERS NORT}.:t REF'EREt'4CE GR i D 'T'r'PE DE",.'2L I NAT I ON FO"FAL. CORRECYT i START AND Ft''.lr~ .... I NG .......... u~-~,,' .'.= S'/"ART Ah.iD EIIDI!"-.!G M. D. S"i'AF;:T COC.tRD'.r. NATES ( 0 f: 'f: set ) "f'ARGE F LOCA"f' I (Fr"om We!!head) MWD PLJL. SER SUB C),.D. ? h ¢ F~' T h h'.: ¢-- n"::' f"P,.I ~ F)CAT I (]i,l AK-MW'"' 001 () 8 NABORS 27E GROUND 2542' FNL, 4()7()' FEL SEC 3.4, "r 1 J;l'4 ~. R 1 ,:.)E : TRUE : U 30. '!0 DEGREES C). () 0 DE G REE S 30,, 1() L, Eor~E:,":-) . 9--9'-9() 't. hr u 9-177-..-90 109' to 4,6., 4 9' ( N / S ~ : ( E / W ) : 197.;C) D i ~. i'- ,: ~ ' ' .,~LU S, 1.]:2':") E' S .43 DEG. 9 ftlN E 8" EC MACH II, 1.50EG 6 1,".,:~" El.-: MACI.I I, ...... 54 '~",F(..'.~ DTI...i ROB RODERIC. I< l_.r_. = I E'R RE ,IVED :.:!;-;E[;;T i ON J: i BHA AND BIT DATA MWD RU~ B MWD RUN C BHA: BIT BIT BIT NO. SIZE TYPE SUB/ NMLCI ItMSTAB/ NMD£/ SS MWO NMSTAB/ 3 NMi}C/ STAB/ 2-D£/ STAB JARS/XO/39 HWDP BIT/ EC 1.5 BEG DH MOTOR/ XOIBIT SUB/ HMLC/NMSfAB/ NMDC/SS MWO/NM 3-NMOC/STAB/2-DC/STAB/JARS/XO/3g H~OP BIT/ EC ,54 BEG BTU MOTOR/XD/ NB STABISTABtNMLCINMSTABINMDC/SSMWB XD/ NMSTAB/ 3-NMOC/STAB/XO/ JARS 39 HWOP B STC MAI JSL STC MAI JSL REED HP43WP JET SIZE 2x15~ FOOTAGE START ENO 57~ 2815 TOTAL FOOTAGE 270 24~6 183~ SECTIOtt IV CDHPLETION SUMMARY OF RUNS START DATE/TIME 9-I0/16:30 9-11/01:00 9-15/21:30 END DATE/TIME 9-I1100:30 9-17t11~30 BIT RUN MUD RUN SERVICE MODE OPERATING START END HOURS MO MD FOOTAGE DRILLED AVG GPM 4.9 109 379 270 420 28.2 379 2B15 2438 420 17,2 2815 4649 1834 465 SURVEYS DEIECTED 27 13 fOOLFACES DETECTED 116 1722 308 SECTION III DRILLINB AND MUD DATA MWD RUN A MIdD RUN B MWD RUN C GPM PP6 SAND SOLIDS PV YP AV6 CHLORIDES PROBE TEMP 420 8.9 .25% 4% 10 45 6000 14.1 ,I0% 5.5% 10 20 1875 14.1 420 465 ~.1 .05Z 6% 12 8 1000 25,8 SECTION V H-PAD, 'IE~o,JRED DEPTH 0.00. 277.00 (,7[ 411. ~,:.~ 658. O~d 768.00 924.00 i018 ~0 13:3.00 254.00 2632.00 27-'35.00 291 '~ · .:,0: .'-,. 00 .... :,,",~...,. 00 .,.':t":" 3705 (2.0 4399. DD · 1 m-? ¢? 4-, 7...:,. ¢.% WELL S, _RRY SUN DRILLING SERVICES [_~-, ~ I TUDE DEF'" """'"' '"' '- A t.~ ,- ,_,,,i Nu=~':. D I RECT I "**' . =~. I C~-d_ P'!. f'k t ""-"' DIE. G DEPTH FEET FEET Page 9-9-1990 Al-:::-MW-80108 VERTICAL DOG SECTION LEG D. 00 0.00 0.39 0.87 1 ,, 98 0.78 o. I ...:,. 06 ,,-'1 ,"~ " ~ / ~..'. S7 .:, 6 . ~ · 4'2. S"".~..' 0,,"'?5 '-" 03 '"' 57 1C'D. 102. 16 4.03 .~ .? ..:.. ,::.0 3.89 2 D 63. :'.:-' 6 I. 8 2 ...'. 1. (;'":,:l. aS 1.98 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 September 27, 1990 Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE- Milne Point Unit We!! H-! Application for Sundry Approval Dear Mr. Smith' Attached is the Application for Sundry Approval (Form 403) requesting approval to shutdown operations on MPU well H-1 with rig 27-E, pending completion with rig EWS 4. If there are any questions pertaining to this well please call me at 564- 7637. Very truly Yours, SraK R. S. Rossberg Sr. Drilling Engineer RSR:jcd cc' M. P. Stockinger file # 500.21.08 RECEIVED OCT o 3 ggO STATE OF ALASKA ALAbr'A OILAND GAS CONSERVATION COMMISS,... APPLICATION FOR SUNDRY APPROVALS 11 11 11 11 II I1 II II II II 11 II 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extenmon __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate __ Other __ 2. Name o! Operator Conoco~ Inc. & Address Alaska 99503 3201 C Street, Suite 200, Anchorage 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 2542' FNL, 4070' FEL, Sec. 34, At top of productive interval 3950' FNL, 2750' FEL, Sec. 34, At effective depth T13N, T13N, RIOE, RIOE U.M., NSB, Al'aska 6. Datum elevation (DF or KB) KB 35 AGL 7. Unit or Property name Milne Point Unit 8. Well number H-1 9. Permit number 90-86 10. APl number 50-029-2206] At total depth 4322' FNL, 2400' FEL, 12. Present well condition summary Total depth: measured true vertical 4506 Sec. 34,.T13N~ 5242 RIOE feet feet 11. Field/Pool Schrader Bluff Plugs (measured) feet Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length 115' 2828' 5257' measured true vertical Size 13-3/8" 9-5/8" 7~ Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Surface Surface TOC 3500' Measureddepth 80' 2793' 5222' %ueverticaldepth 80' 2496' 4489' RECEIVED Anchofa~,e 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Shutdown Operations with R±g 27~ Pending ComPletion ui_th ~S 4 14. Estimated date for commencing operation J 15. Status of well Ctassdicati0n as: 12/1/90 ! 16. If proposal was verbally approved I Oil I Name of apDrover Date approved ! Service 17. I hereoy certify that the foregoing ~s true and correct to the best of my knowledge. Signed -~¢~h ...... /~~-4- Title Sr. Drilling Engineer Steve ' Rossberg '~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commissiod so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- .. Date Approved by order of the Commission ORIGINAL. S~GNED BY LONN!5 O Sf~/IITH Commissioner Form 10-403 Rev 06/15/88 43 - Approve,;;: ~ SCHLUMBERGER WELL SERVICES A DIVISION OF ~_HLUMB£RG£R TE::CHNOLO~Y CORPORATION f-fOUSTON. TEXAS 77251-2175 I~F..X&E RElaY TO Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention:. Marc Shannon Gentlemen: DIT,NGT,CNL(RAW), CNL(POR0), Enclosed are_2_BL_printsofthe.. BGT,CTberlook, Run 2, 9/24/90 Cornpony CONOCO, Inc. Well Milne Point Unit H-1 on~ Field MJlne PoJn~ Additional prints ore being sent to' I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX' 77079 Attn: George Lamb - OF 2.01~ PER Counly Nnrth Slope State Alaska _l_BL_prints, 1RF Sepia CONOCO. Tn¢~ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. ._ ~6_ P~_t_a_P~ v e Midland, TX 79710 ... At tn: John Carrol . *(915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. 6001BollJnger Canyon Road San Ramon, CA 94583-0943 ..Attn: Priscilla MacLero¥ *(415/842-1000) An~fhorage, AK 99501 At ~.n: John Boyle The film is returned to Conoco, Log Library. prints prints print~EC E JVE D Alaska Oil & Gas Cons. Com[nisslon Anchoraqe Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT ~ANAG£R $W$-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF .~CHLUMBEROER TECHNOLO(3Y CORPORATION HOUSTON. TEXAS 77251-2 SEP 1 4 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Marc .~honnon SCHLUMBERGER WELL ~ICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen Enclosed ore_2_BL_prints o{ the DIT-F., NCR, CNL (RAW/PORO), Run 1, 9/12/90 Compeny CONOCO, Inc on' Well Milne Point Onit H-! Field .. MJlne Po~nt /Schrmde_r Blnff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX .77079 Attn: George Lamb - OF 2018 PER ... County .Nnrth Slope. State Alaska _l_BL_prints, 1RF Sepia CONOCO. Tnt_ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1 RF Sepia OXY U.S.A.., Inc. 6 D¢~a Drive Mid!and, TX 79710 At,n: John ¢errol *(915/685-5600) _l_]~,_~orints, I RF Sepia Chevron U.S.A. 6001BollJnger Canyon Road _San gamon, CA 94583-0943 Attn: PrSscilla MacLeroy *(415/842-1000) Ale. sC~ 0ii& Oas Conservat~n ~,??: C°mmJ ssi on /~/300i pOrcupine Drive [AnchoraKe, ~ 99501 ~tn: John .~e The film is,,Ieturned to Conoco, Log LSbrary. We appreciate the privilege of serving you. prints .. prints prints RECEIVED , R~e~ v~d~ S E P 1 T 1990 Dar e: ~lo,,b,, .... ~,,,~ u,, & Ga~ Cons. Gomm[ssio~ ~nchomge Ve~ truly yours, SCHLUMBERGER WELL SERVICES David H. Saalwaechter DI~TR ~CT MANAGER SWS-- 1327-F July 27, 1990 Telecopy: (907)276-7542 David L. Mountjoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Mi!ne Point Unit No. H-1 Conoco Inc. Permit No. 90-86 Sur. Loc. 2542'FNL, 4070'FEL, Sec. 34, T13N, R10E, UM. Btn~ho!e Loc. 4322'FNL, 2400'FEL, Sec. 34, T13N, RI0E, UM. Dear Mr. b~ountj oy: Enclosed is the apProved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits 'required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. _. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly yours, David W. Johnston Commis s loner-7 of Alaska Oil and Gas Conservation Co~lssion BY ORDER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " ~ STATE OF ALASKA ...... ALAbKA C AND GAS CONSERVATIt CC ,,IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill .~ Redrill ~1 lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - DeepenEI Service -- Developement Gas ~_ Single Zone~' Multiple Zone 2. Name of Operator CONOCO INC. 3. Address Pouch 340045, Prudhoe Bay, AK 99734 4. Location of well at surface 2542'FNL, 4070'FEL, SEC. 34, T!3N, R!0E At top of productive interval U.M., NSB, AK 3950'FNL, 2750'FEL, $EC.34, T13N, RIOE At total depth 4322'FNL, 2400'FEL, $EC.34, T13N, RIOE 12. Distance to nearest property line 957 feet 13. Distance to nearest well 5. Datum Elevation (DF or KB) KB 35 AGL feet 6. Property Designation ADL-25906 7. Unit or property Name MILNE POINT UNIT 8. Well number H-! 9. Approximate spud date SEPTEMBER 2, !9'90 10. Field and Pool KUPARUK RIVER FIELD 11. ~pe Bond (see 20 AAC 25.025) BLANKET Number 8086-15-54 Amount $200,000 15. Proposed depth ~MD and TVD) 1ST WELL ON PAD 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 360 18. Casing program size Specifications Weight) Grade 1 CouplingI Length 54# IH-401 WFm_D i 80' 36# )J-55) BTRS 12780' ARctIC GI~ADE 15096, 26# /L-80/ BTRS . Hole Casing · 12 !/49 5/8 8.5 7 14. Number of acres in property feeti2560 ACRES ).3!'MD, 4368'TVD*feet ! 17. Anticipated pressure (see 20 AAC 25.035 ! Maximum surface 1900 psig At total depth FFVD) 2000 psio MD 35' 35' 35' )erations. 19. To be completed for Redrill, Re-entry, and Deepen O! Present well condition summary Total depth: measured feet true vertical feet Setting Depth Top Bottom 35' 1"115' I 115' I 35' 12815'1 2500' Plugs (measured) Effective depth: measured feet Junk (measured) true vertical feet Quantity of cement (include stage data) +485 SKS PERMAFROST C ±658 SKS PERMAFROST E +252 SKS CLASS G ±90 SKS PERMAFROST E ±316 SKS CLASS G DOWNSQUEEZE +273 SKS PERMAFROST C +60 BBLS DEAD CRUDE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth PIT SKETCH X 20. Attachments Filigg fee ~ Property pla,,t ~E] BOP Sketch ~E Diverter Sketch X_3 Drilling program ~: Drilling fluid program,l~ Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. ! hereby certify that the foregoing is true and correct to the beSt of my knowledge Signed /Ly ¢,~,.~~~ ., ~-~.,..~-¢ Title SR. DRILLING FOREMAN rsommission Use Only Permit Number ] APl number J Ap r_ov,~_~qtg_ Conditions of-approval Samples required ~'Yes ?:. No Mud Icg required /~Yes ~-J No Hydrogen sulfide.measures ~ Yes .,~Nd' Directional survey required ~ Ybs .._?. No Required working pressure for BOPE '/~2M; ~ 3M; [] 5M; [] 10M; [] 15M Other: £ by order of Approve ~ Commissioner the commission Form 10-401 Rev: lz-178,~ See cover letter for other requirements Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT H-1 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program a. The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±658 sacks of Permafrost "E" cement followed by ±252 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. Co The 7" production casing will be cemented in two stages. The first stage will consist of ±90 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±316 sacks of Class "G" cement. The secondary cement job will consist of +273 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program A. 0' - 2815~9.0 ppg freshwater spud mud. B. 2815~- 3966~9.2 ppg low solids non-dispersed. C. 3955~- TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. . The well will not be completed or tested at this time. A. Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. B. Drill a 12-1/4" surface hole to ±250~iTVD 2815' MD and set 9-5/8" casing. C. Drill a 8-1/2" production hole to 4368' TVD to 5131' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3420 3955 "K" Sand 1-1-4 9.2 25 15 35 10 3670 4265 "M" Sand 1-1-4 9.4 25 15 35 10 3894 4543 "N" Sand 1-1-4 9.4 25 12 35 05 4068 4759 "0" Sand 1-1-4 9.4 25 12 35 05 4368 5131 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. II I II - . I I NOTES: 1. 0TATE PLANE COORDINATES ARE ZONE 4 2, ALL GEODETIC PO,SlTION8 ARE BA6ED ON N.A.D, 1927 OFFSET8 TO SECTION LINE8 ARE COMPUTED BASED ON PROTRACTED VALUE,S OF THE SECTION CORNER POSTION8 290' 30° 40' LOCATION IN ,SEC, WELL H-1 H-2 H-3 H-4 IIIII I I II MILNE POINT UNIT MILNE PT, VICINITY MAP 0 6 t~ MIL Ea 34, T13N, R1OE, UMIAT MERIDIAN , FROM EAST LINE FROM NORTH LINE 4070' 2642' 4083' 2484' 4036° 2426' 4019' 2369' 120' H PAD TYPICAL ,STATE PLANE COORDINATES-ZONE 4 WELL H-'-I H-2 H-4 0,009,889,28' 6,OO9,947,O4' 6,O10, OO4.80' 6,O10, O62.66' 556,676.42' 566,692.64' 556,608.85' $56,625.O7' GEODETIC PO,SITION$ NAD 1927 WELL NORTH LATITUDE WEST LONGITUDE H-1 H-2 H-'4 70' 26'1~.6012" 70' 26't6,1680" 70' 26'16.7350' 70* 26'17,3019' 149' 32'19,309' 149' 32'18.820' 149' 32'18,331' 149' 32'17,843' SECTION ~ NO aCALE 3URVEYED FOR: CC~O} ~~~~~...~ DATE DEC 15 1989 .... CHECKED GIELD BOOK 3CALE !'~2OO' JOB NO. 87033 T 13 N R 9 E T 13 N R 10 E T 13 N R 11 E MILNE PaIN Ill I I ! III I ~ 4~" CONocO .~llll~ I Il '' I ....... Q TO'.'D'~O''' Arel I CONOC~ ET AL t , ,, ~-~55~ 25~3~C ADL'47434, 2500 AC ADL'47433 ~60 AC ~'~D~743~08 A~ ~ CONOCO ET co.o r + + -- ' 23 24 I~ 20 ~I 22 23 24 21 22 Ao~-~e4e ADL-25616 ADL-4743g ADL-3ISe4 ~-25514 25~0 AC ADL-25515 2~4 AC ~280 AC 1280 AC ADL-47437 2500 AC ADL-47438 2 4~C 1280 AC .1280 AC I 30 28 28 aT 2~ · 2S ~0 2g EX~ 3~ 33 34 Baaed on Umlo / 38 30 31 32 0 A~-2~ 17 ~ ~', MIl'' ~lI 2235AC 20 ~DL'25~ 2560 AC ADL'25518 2~60AC ADL'28231 2555 AC - I I I I III I I UNIT numbers t 35.744 0/04 48 UNIT AREA t Merldlan,Aloela 1 Scala SOHIO CONOCO I C,--NA ORS RIG13-5/8" 58885 BOP S¥STFM Fill Line AI~ la--5/e' ~ A~ l~5/B'SM APl 13-~%~8' 5M APl 13-,5/8" ~ x 11' ~l AP1 11' 5H Threaded Connection Flow Line Annular Preventor Ram Ram Ram Tubing Spoo! w/ 2"-5000~t Side Outlets Caslng Spool w/ 3"-5000~t Side Outlets 9-5/8" SurFace Casing 13-3/8" Conductor' Casing Choke Line, 3" 5000~ Manual GaTe VaLve & 3" HCR VALVE Kit[ Line: Two 3" 50004$ Manual Gate VaLves 1, BOP STACK SIZE RATINO MEETS AP] RP53 & SPEC 6A FOR CLASS 5M 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKL'f, 3, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL MAN]FOLD LOCATED REHOTE WITH 160 GALLON ACCUMULATOR, RESERVOIR UN]T, & AUXILIARY ENERGY SOURCE FOR SYSTEH ACT]VAT]ON, ~r, MINIMUM ONE SET BLIND RAMS & TWO SETS APPROPRIATE PIPE RAMS, 5, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY TO MEET APl RP 53 CLASS 5M REOU]REMENTS, KILL BANIFOLD FROM RE~,IOTE HIGH PRESSURE PUMP NOTE: I. NrD~ULrC CCN~L S~ST£W FOR BO~ STACK a CHO~ WA,N:FOLO TO I~CLUDE (5] ST~TI~ CONTROL L~AT[D REFGTELT ~ITH ~0 PSi ACCUMULATOR lBO G~. RESED~R 8 ~UX. ENERGY SOURCE. ST~ ~NTROL W~NIF~ PLUS V~RIABLE CHOKE ~NT~L TO BE ~C~TED ON RI~ FLOOR. Z K~L 8 CNG~ WANIFOLDS ~ ~EET A~ RPS] ]_ KILL U~NIF~D SIZE- RATING 2= - 5000 ~ ~H~[E ~NIFO~ SIZE-R~IN6 ]"-5~0 RE.~OTE PRESSURE G~GE SENS~ HYDRAULIC CONTROLLED REMOTE OPERATED DRILLING SPOOL HYDRAULIC CONTROLLED REWROTE OPE,RATED REMOTE PRESSURE GAGE SENSOR ADJUSTABLE CHOKE ADJUSTABLE CHOKE CHOKE MANIFOLD -- VARIABLE CHOKE RE~,OTE CCNTROL TO SHALE ----,mm, SHAKER 1 BLEED LINE TO PIT 1 TO ATMOSPHERIC MUD/GAS SEPARATOR CHOKE 8 KILL MANIFOLDS FOR cis?8'i ~ 7" OD CASING BOP STXCK BOP UANIFOLD LAYOUT - CONOCO, INC. : CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 318' CONDUC'I'OR , STARTI~O I'qEAO 13 3/a" CA$1hG 1. The hydraulic control syste.~ will be in accordance with AP1 specifications and ~ requirements. 2. Th~ HCR valve will open when the preventer closes. A singl~ I0" ~lief line will ~un off of the drilling spool HCR vnlv~ and will have a targeted do~nstrea~ t~e for downwind diversion. Valves on both side~ of the t~ will be full opentn~ and linked together to enabl~ on~ to always be open and the other to be closed. FROM SALAMANCEqS MUD CLEANER MUO T~OUGH wATLA I)LJ~J) VA L~EG,~ .; 3ER falx/la CM,~qGE PSv SUCTK)N VALVL SUCYtC,~ CR Ot$CHA.~GE ( ~ VALV~ ) _ ,. . NABORS Dq~LL~G LI:,~TEC, FLOw SHEET DEVELOPMEN'!' WEL)b-~ WELL NAME;~SPU 11-Jan-gL CONDUCTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING DEPTH (OR TO): 80 2815 0 5131 DEPTH OPERATION: 0 1 RIG MOVE: 6 0 2 RIG-UP; SET CONDUCTOR: 12 (2,815) 5 DRL/SURVEY SURFACE HOLE: 50 ~ (2,815) 4 SURFACE HOLE LOGGING: 0 (2,815) 5 CONDITIONING TRIP: 5 (2,815) 6 RU/RUN SURFACE CASING: 10 (2,815) 7 RU/CEMENT SURFACE CASING: 6 (2,815) 8 CHNG BOPs; PU BHA; RIH: 9 (2,915) 9 DRL OUT; TEST; TOOH; RIH: 9 (2,915) lO DRILL INTERMEDIATE HOLE: 0 ~ (o~,915) 11 LOGGING OPERATIONS: 0 (2,915) 12 CONDITIONING TRIP: 0 (2,915) 13 RU/RUN INTERMEDIATE CASING: 0 HOUR DAYS O. 25 O. 50 2.07 O. O0 0.12 O. 40 . 25 37 0.58 O. O0 O. O0 O. O0 O. O0 (2,915) 14 RU/CEMENT INTERMEDIATE CASING: 0 <2,915) 15 CHNG BOPs; PU BHA; RIH 0 (2 915) 16 DRL OUT; TEST; TOOH; RIH 0 , (5,131) 17 DRILL PRODUCTION HOLE: 51 (5,131) 18 CORING OPERATIONS: 0 ~ (5,151) 19 LOGGING OPERATIONS (MWD ONLY): 0 (5,131) 20 CONDITIONING TRIP: 9 (5,131) 21 RU/RUN PRODUCTION CASING: 14 (5,131) 22 RU/CEMENT PRODUCTION CASING: 5 (5,131) 23 RD DRLG RIG 12 (5,131) 24 RU COMPLETION RIG: 1°~ (5,131) 25 RD DRLG RIG 12 (5,131) 26 RU COMPLETION RIG: 12 (5,131) 27 CASED HOLE LOGGING: 10 (5,131) 28 PERFORATING: 33 (5,131) 29 DST (IF EXPL. WELL): 0 (5,131) 30 RUN COMPLETION STRING: 7 O. O0 O. O0 O. O0 2.14 O. O0 O. O0 O. 38 O. 60 0.21 0.50 O. 50 O. 50 O. 50 0.42 1.39 O. O0 O. 29 CUM DAYS O. 25 O.75 2.82 2.82 ~. 94 3.34 3.59 3.95 4.34 4.34 4.34 4.34 4.34 4.34 4.34 4.34 6.48 6.48 6.48 6.86 7.46 7.68 8.18 O. 50 1. O0 1.50 1.92 3.31 ~ 31 ._.,. 59 q DRILLING ~"~ '"'"' U~, I .b CONOCO, Ino. Pad H, Nel I No' 1 Revised Pr`oposal MI Ine Point Unit, Nor'th Slope, Alaska 0 ~000 2000 ~000 4.000 _ 5000 RKB ELEVATION, KOP TVD=500 TMD=500 DEP=O 7 14 BUILD 3.5 OEO 21 PER 100 FT 28 35 EOB TVD=1i.67 TMD=1535 DEP=316 AVERAGE ANGLE 36 DEG 14 HI N 9 5/8" CSG PT TVD=2500 THD=2815 DEP=1073 K SNDS TVD=3420 TMD=3955 DEP=1747 TARGET / M SNDS TVD=3670 TMD=4265 DEP=1930 N SNDS TVD=3894 TMD=4543 DEP=2094 0 SNDS TVD=4068 TMD=4T59 DEP=2222 TD / T" LINER TVD=4368 TMD=513I DEP=2441 I I lO00 2000 VERTICAL SECTION I 3000 HORIZONTAL SCALE 1 IN. PROJECTION = 1000 FEET CONOCO, !.~. Pad H. Nell No: 1 I~I! Ine Point: Unit:, Revised Proposal Nor{h Slope, Alaska SURFACE LOCATION, 2542' FNL, 4070' FEL SEC. 34. T13N. RIOE 1000 Z , 1000 2000 _ ~ 3000 NEST-EAST 1000 0 1000 I I SURFACE S 43 DEO 9 MI N E 19;30' (TO TARGET) 2OOO I 3000 I TARGET / H SNDS TVD=3670 THD=4265 DEP=I930 SOUTH 1,I,08 EAST 1320 TARGET LOCATION, 3950' FNL. 2?50' FEL SEC, 34, T13N. RIOE TD LOCATION, 4323' FNL. 2400' FEL SEC, 34. T13N. RIOE CHECK LIST FOR NEW WELL PERMITS IT~ APPROVE DATE (2' thru 8) (8) (3) Admin ~/9~- ~z~m 9. '(9 TIT-- 10. (10 ~d 13) 12. 13. (14 uh~ 22) (5) BOPE ,, (23 thru 28) Company ~~~>-~~, Lease & Well No. //ZgJ YES NO the permit fee attached .......................................... ~- -- 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance' from other wells .................... 5. Is sufficient undedicated acreage available in chis pool ............ 6. Is well to be deviated and is wallbore plat included ................ 7. Is operator the only affected party ......... i ....................... 8. Can permit be approved before fifteen-day wait ...................... ~-- 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24 25 26. 27. 28. Does operator have a bond in force .................................. ~. is a conservation order needed ...................................... Is administrative approval needed ................................... is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... Is cdnductor string provided ........................................ Wi!l surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used co circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well co be kicked off from an existing wellbore ............. Is old we!lbore abandonment procedure included on 10-403 ............ is adequate weilbore separation proposed ............................ Is a diverter system required .................................... an~ ' - Is the drilling fluid program schematic list of equipment adequate Are necessary diagrams and descriptions of dive:ce: and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... (6) /Pc. (29 th rev: 01/30/89 6.011 · For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shailow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ION/OFF POOL CLASS STATUS AREA NO. SHORE , ,,