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189-015
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,258 feet N/A feet true vertical 7,505 feet 4,087 feet Effective Depth measured 8,050 feet 7,586 & 7,819 feet true vertical 7,326 feet 6,937 & 7,129 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 29# / L-80 / EUE 8rd ±7,845 ±7,151' Otis 'RH' Packers and SSSV (type, measured and true vertical depth)Otis WD Perm Drill N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 110' 1276 Size 110' 4,984' 03000 0 1530 70 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-015 50-029-21914-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047433 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-20 Plugs Junk measured LengthCasing Conductor 8,236' 5,229'Surface Production 13-3/8" 9-5/8" 7' 110' 5,229'6,870psi 8,160psi8,236' 7,486' Burst N/A Collapse N/A 4,760psi 7,020psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:56 pm, Mar 12, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.12 09:57:12 - 08'00' Taylor Wellman (2143) DSR-3/12/24 RBDMS JSB 031424 WCB 2-13-2025 _____________________________________________________________________________________ Revised By: TDF 3/12/2024 SCHEMATIC Milne Point Unit Well: MP C-20 Last Completed: 9/20/1989 PTD: 189-015 TD =8,258’ (MD) / TD =7,505’(TVD) Initial KB Elev.: 45’ (Rig EWS #4) Ground level: 17’ 7” 6 21 14 15 13 18 15 17 9-5/8” 1 4 4 16 20 MIN ID = 2.813” @ 532’ 3-1/2” tubing stub with XN Nipple PBTD =8,050’(MD) / PBTD =7,326’(TVD) 10 Half of D&D hole finder left in well @4,087’ SLM see well file for parts recovered. 13-3/8” 12 2 3 5 7 19 8 11 9 End of 3-1/2” tubing cut w/jet cutter 2/14/90 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8” Conductor 45.9# / H-40 / PELP 12.715” Surface 110’ N/A 9-5/8" Surface 47# / L-80 / BTRC 8.681” Surface 5,229’ 0.0732 7" Production 29# / L-80 / BTRC 6.184” Surface 8,236’ 0.0371 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / 8RD EUE 2.992” Surface ±7,845’ 0.0087 JEWELRY DETAIL No Depth Item 1 532’ 3-1/2” Otis “FMX” SC-SSSV,Min ID= 2.813” GLM Detail – Camco 3-1/2” x 1” stations 1 – 10. Prodcution mandrels are 3 ½” x 1 ½” MMG-2 2 2,121’ST 10: Port= 12 Dev.= 0.7, VLV= GLV, TVD= 2,121’, 5/12/1990 3 2,758’ST 9:Port=0 Dev.= 6, VLV= Dummy, TVD= 2,758’, 10/14/1991 4 3,395’ST 8: Port= 12 Dev.= 12, VLV= GLV, TVD= 3,382’, 5/12/1990 5 4,096’ST 7: Port= 12 Dev.= 29, VLV= GLV, TVD= 4,028’, 5/12/1990 6 4,606’ST 6:Port= 16 Dev.= 32, VLV= GLV, TVD= 4,463’, 5/12/1990 7 5,243’ST 5: Port= 16 Dev.= 34, VLV= GLV , TVD= 4,995’,9/25/2020 8 5,815’ST 4:Port= 18 Dev.= 34, VLV= GLV , TVD= 5,468’, 5/12/1990 9 6,451’ST 3:Port= 20 Dev.= 34, VLV= Orifice , TVD= 5,993’, 9/25/2020 10 6,963’ST 2: Port= 0 Dev.= 34, VLV=Dummy , TVD= 6,421’, 9/14/2020 11 7,411’ST 1: Port= 0 Dev.= 35, VLV=Dummy w/ ext. packing , TVD= 6,792’, 9/23/2020 12 7,548’ Joint with RA Marker 13 7,585’ Baker PBR and Seal Assembly 14 7,586’ Otis “RH” Packer, ID= 2.88” 15 7,643’ Otis X Landing Nipple (Destroyed with a mill) 16 7,675’ 3-1/2” x 1-1/2” Macco ‘MMG-2’ Gas Lift Mandrel ( Open Pocket ) 11/9/89 17 7,715’ 3-1/2” x 1-1/2” Macco ‘MMG-2’ Gas Lift Mandrel ( Open Pocket ) 11/9/89 18 7,819’ Otis WD Pema Drill Packer, ID= 4.00” 19 7,822’ SBE Adapter, ID= 4.00” 20 7,823’ Otis SBE, ID= 4.00” 21 7,835’ Swage 4-1/2” x 3-1/2”, ID= 2.99” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status Size KUP C 7,680’ 7,700’ 7,014’ 7,031’ 20 7/12/1989 Open 4” KUP B Silt 7,722’ 7,730’ 7,049’ 7,056’ 8 7/12/1989 Open 4” KUP B Silt 7,768’ 7,774’ 7,087’ 7,092’ 6 7/12/1989 Open 4” KUP A3/A2 7,866’ 7,940’ 7,169’ 7,232’ 74 7/12/1989 Open 4” OPEN HOLE / CEMENT DETAIL 13-3/8” 355 bbls Permafrost E plus 34 bbls Class G in 30” hole 9-5/8" 477 bbls Permafrost E and 57 bbls Class G in 12-1/4” hole 7” 62.4 bbls Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 2,500’ Max Hole Angle = 34.6° @ 5,400’ Hole Angle thru perforations= 31-35° TREE & WELLHEAD Tree 3-1/8” 5K FMC Wellhead 11” x 7” 5M FMC NSCT, w/ 3.5” FMC Tubing Hanger CIW 3.5” H BPV Profile GENERAL WELL INFO API: 50-029-21914-00-00 Drilled and Completed by Rig EWS 4 – 7/12/1989 Recompleted with GLVs - 9/20/1989 Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 LRS / Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 5/5/2023 - Friday T/I/O = 2075/1690/200 Assist Slickline, Pumped 5 bbls 60/40 down Tubing, Pumped 85 bbls Produced Water down Tubing, Pumped 22 bbls Diesel down Tubing. RAN 3' X 1-7/8'' STEM, 3-1/2 BLB, 2.80'' GAUGE, BRUSH & FLUSH TUBING DOWN TO 7650' SLM. SET 3-1/2 EVO @ 7611' SLM. BLED TUBING & IA DOWN FROM 1700 psi TO 1250 psi. 5/3/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 5/4/2023 - Thursday No operations to report. No operations to report. Freeze Protect Flowline, Pumped 10 bbls 60/40 down Flowline. 5/6/2023 - Saturday No operations to report. 5/9/2023 - Tuesday 5/7/2023 - Sunday No operations to report. 5/8/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Well Supp. / SL 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 No operations to report. No operations to report. 11/25/2023 - Saturday No operations to report. 11/28/2023 - Tuesday 11/26/2023 - Sunday No operations to report. 11/27/2023 - Monday 11/24/2023 - Friday C-20 CMIT-TxIA. Pumped 4 bbls of DSL to pressure up the TBG and IA for a CMIT TxIA MAP @ 2250 psi. Reached test pressure at 2208 psi TBG, and 2250 psi IA. First 15 minutes TBG lost 15 psi, IA lost 17 psi. Second 15 minutes TBG lost 5 psi, IA lost 6 psi. Bled back 4 bbls to FWHPS=0/0/185. PO notified of well status. 11/22/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary CONTINUE WSR & LDR FROM 11-21-23. SIBO, OOH w/ TOOLS, (good data). BEGIN LDFN, SECURE WELL, TREE CAP PT'd, NOTIFY DSO, CLOSE PERMIT. T/I/O = 1500/1500/200 Assist SL with LDL, Bleed Well Pressure down to returns Tank, Pump 3 bbls 60/40 down Tubing returns up IA to tank, Pumped 290 bbls Source Water down Tubing up IA to Tank to fluid pack well, Pumped 275 bbls Source Water down Tubing returns up IA to tank while SL logs LDL, Pumped 80 bbls down Tubing returns up IA to tank, U- Tube TxIA for FP. 11/23/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 MIRU. PT 250/ 2500. PULL HES EVO-TRIEVE PLUG @ 7611' SLM. CORRELATE DEPTH & FLAG WIRE W/ 3--1/2 OK-6 @ STA #1 (7411' MD). SET TOP OF SLIP STOP @ 7445' CORRELATED DEPTH. SET D&D PACKOFF ON LOWER SLIP STOP @7,418' SLM. SET LOWER SPACER PIPE W/ STINGER (=270" OAL) @7,416' SLM. SET UPPER SPACER PIPE W/ STINGER & PACKOFF (=285" OAL) @7,394' SLM. SET TEST TOOL & ATTEMPT CMIT. UNABLE TO PRESSURE UP. TOP SLIP STOP NOT SET FOR TROUBLE SHOOTING AT LATER DATE. WELL SHUT IN UPON DEPARTURE. No operations to report. 12/16/2023 - Saturday No operations to report. 12/19/2023 - Tuesday 12/17/2023 - Sunday No operations to report. 12/18/2023 - Monday 12/15/2023 - Friday No operations to report. 12/13/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/14/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 12/29/2023 - Friday No operations to report. 12/27/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/28/2023 - Thursday No operations to report. No operations to report. WELL SHUT-IN ON ARRIVAL. RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 8' x 1-7/8" ROLLER STEM (2.60" whls), KJT 5' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. LRS TO RIG-UP TO P-SUB AND PT PCE 350L / 3500H (Good). TAG ST#10 AT 6,978' SLM / 6,963' MD. W/ 3-1/2" OK-1, JK. (pins sheared). +15' CORRECTION. SET 3-1/2" D&D HOLEFINDER ON TOP OF PATCH AT 7,413' SLM / 7,428' MD. LRS PERFORMED PASSING MIT-T TO 1000psi (See log). LRS PERFORMED FAILING MIT-IA TO 1000psi (See log). PULL 3-1/2" D&D HOLEFINDER FROM TOP OF PATCH AT 7,413' SLM / 7,428' MD. PULL 3-1/2" PACKOFF, SPACER PIPE, STINGER ASSEMBLY FROM 7,413' SLM (Missing packoff element), PULL SPACER PIPE, STINGER ASSEMBLY FROM 7,437' SLM. PULL 3-1/2" D&D PACKOFF FROM 7,458' SLM.(Missing packoff element), PULL 3-1/2" TUBING STOP FROM 7,460' SLM. TOTAL OF 2 PACKOFF RUBBER ELEMENTS MISSING. 12/30/2023 - Saturday RIG-UP .125 CARBON WIRE. TS = 1.75" TS, 8' x 1-7/8" ROLLER STEM (2.60" whls), KJT 5' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). LRS ON LOCATION AND RIG-UP TO IA. SET 3-1/2" D&D HOLEFINDER ON TOP OF PATCH AT 7,408' SLM. LRS ATTEMPTED CMIT IAxT (fail. see log). PULL 3-1/2" D&D HOLEFINDER FROM TOP OF PATCH AT 7,408' SLM. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 1/2/2024 - Tuesday 12/31/2023 - Sunday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 8' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). RAN 4-PRONG WIRE GRAB TO 7,550' SLM(no recovery, no issues). SET 3-1/2" TUBING STOP (oal - 27") AT 7,467' SLM / 7,452' MD. SET 3-1/2" D&D PACK-OFF (oal - 25") AT 7,465' SLM / 7,450' MD. SET SPACER PIPE W/ STINGER (oal - 270"). AT 7,443' SLM / 7,428' MD. SET SPACER PIPE W/ STINGER (oal - 136"). AT 7,432' SLM / 7,417' MD. SET 3-1/2" D&D PACKOFF, SPACER PIPE W/ STINGER (oal - 285"). AT 7,410' SLM / 7,395' MD. SET 3-1/2" TUBING STOP (oal - 20") AT 7,408' SLM / 7,393' MD. 1/1/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 TUBING & IA BOTH FLUID PACKED. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RAN 3- 1/2 D&D HOLEFINDER SET @ 7459' SLM COULDN'T GET TUBING & IA TO PRESSURE UP, SET @ 7449' SLM COULD'T PRESSURE UP, SET @ 7419' SLM TUBING PRESSURED UP & HELD 500 psi. PULL 3-1/2 AD-2 STOP @ 7459' SLM RAN 3-1/2 D&D HOLEFINDER SET & PRESSURED UP ON TUBING & IA to 300 psi @ 7559, 7549, 7539, 7529, FAIL @ 7519' SLM **POSSIBLE LEAK POINT**. ***HOLEFINDER HUNG UP & SHEARED IN GLM @ 4087' SLM***. WELL S/I ON DEPARTURE. No operations to report. 1/13/2024 - Saturday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H.PULL SPACER PIPE @ 7425' SLM, POOH, HUNG UP 6726' SLM HAD TO JAR FREE. RAN 3-1/2 TEST TOOL, SET @ 7438' SLM, LRS PUMP 17 bbls, COULDN'T GET TO PRESSURE UP, (RECOVERD SPACER PIPE & 3-1/2 D&D PACKOFF) (missing packoff element). RAN 3-1/2 OK- 1, 12'' EXTENSION, JK R/T, TAG AD-2 STOP @ 7459' SLM, LOCATE GLM @ 7429' SLM (AD-2 set 30' below GLM). WELL S/I ON DEPARTURE. 1/16/2024 - Tuesday 1/14/2024 - Sunday No operations to report. 1/15/2024 - Monday 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary POLLARD 58 RIG UP 1/11/2024 - Thursday PULL SLIP STOP @7,357' SLM. PULL UPPER PACKOFF & STINGER ASSEMBLY @7,364' SLM. WELL S/I ON DEPARTURE. Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 No operations to report. No operations to report. 1/20/2024 - Saturday No operations to report. 1/23/2024 - Tuesday 1/21/2024 - Sunday No operations to report. 1/22/2024 - Monday 1/19/2024 - Friday No operations to report. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. MADE 2 RUNS @ D&D HOLEFINDER @ 4087' SLM, JAR @ 1900# FOR 2 HOURS TOTAL, NO MOVEMENT. WELL S/I ON DEPARTURE. 1/18/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-20 Slickline 50-029-21914-00-00 189-015 5/5/2023 2/17/2024 2/16/2024 - Friday WELL S/I ON ARRIVAL. BEGIN R/U 3/16 BRAIDED LINE, 1-7/8'' RS, QC, 5' X 2-1/2 STEM, QC, KJ, 5' X 2-1/8'' STEM, QC, KJ, 5' X 2- 1/8'' STEM, QC, OJ, QC, KL, LSS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULLED FISH NECK OFF OF DART PORTION OF D&D HOLE FINDER. PULLED BODY OFF OF CORE OF D&D HOLE FINDER. 2/14/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/15/2024 - Thursday No operations to report. No operations to report. Work continued from 2/16/2024. FISHED D&D ELEMENT FROM 4061'. UNABLE TO LATCH ONTO CORE OF D&D. WELL S/I ON DEPARTURE. 2/17/2024 - Saturday No operations to report. 2/20/2024 - Tuesday 2/18/2024 - Sunday No operations to report. 2/19/2024 - Monday 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: 11/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-13 50133205250000 203138 11/13/2023 HALLIBURTON RMT3D MPU B-28 50029235660000 216027 11/20/2023 HALLIBURTON LDL MPU B-28 50029235660000 216027 11/21/2023 HALLIBURTON MFC MPU C-20 50029219140000 189015 11/21/2023 HALLIBURTON LDL NS-24 50029231110000 202164 11/20/2023 READ LeakPointSurvey PBU 13-20 50029207050000 182009 11/16/2023 HALLIBURTON WFL-TMD3D PBU L-216 50029232060000 204065 7/20/2023 PROBE MSIL (CBL) PBU S-09A 50029207710100 214097 7/7/2023 PROBE MSIL (CBL) PBU S-32A 50029220990100 212082 7/13/2023 PROBE MSIL (CBL) PBU S-124 50029233230000 206136 7/15/2023 PROBE MSIL (CBL) Please include current contact information if different from above. T38150 T38151 T38151 T38152 T38153 T38154 T38155 T38156 T38157 T38158 11/29/2023 MPU C-20 50029219140000 189015 11/21/2023 HALLIBURTON LDL Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.29 11:22:45 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPC-20 (PTD# 189-015) IA Pressure Over MOASP Date:Tuesday, April 4, 2023 9:08:12 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:22 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPC-20 (PTD# 189-015) IA Pressure Over MOASP Mr. Regg, Producer MPU C-20 (PTD# 189-015) was recently shut in for gas lift redesign evaluation and began to exhibit signs of IA repressurization. Initial bleeds indicate potential failure of the orifice gas lift valve. On March 3, the IA exceeded MOASP to 2017 psi. Initial diagnostics showed a potentially failed OGLV. After being replaced, the well was brought online and failed a warm TIFL. Additional diagnostics have not been completed at this time. The well is now classified as NOT OPERABLE and will be shut in until a repair can be completed. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Monday, March 6, 2023 4:57 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: MPU C-20 (PTD# 189-015) IA Pressure Over MOASP Mr. Regg, Producer MPU C-20 (PTD# 189-015) was recently shut in for gas lift redesign evaluation and began to exhibit signs of IA repressurization. Initial bleeds indicate potential failure of the orifice gas lift valve. On March 3, the IA exceeded MOASP to 2017 psi. The well is now classified as UNDER EVALUATION and will be placed on a 28 day clock for evaluation and repair. Plan Forward: 1. SBHPS 2. C/O OGLV 3. POP well 4. Warm TIFL 5. ENG to evaluate further diagnostics as required. Please respond if there are any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by thecompany in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. 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: Bev~Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd 1 ~ r".t ~ . 89 -0/5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, 07Y" DATE: July 12, 2000 Commissioner O/Ie;/óc.) THRU: Blair Wondzell, Q3~ P. I. Supervisor ef1(c(J FROM: ~ titJ Jeff Jones ~.- SUBJECT: Safety Valve Tests Petroleum' I sp c r Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. ;3)Vt::k r-<..-t:z..7i- 21 well houses were inspected, no failures. - ----Y Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc A- .~ ~ r Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Date: 7/9100 Operator Rep: Larry Niles FieldlUnitlPad: Kuparuk River/MPU/C-Pad AOGCC Rep: Jeff Jones Separator psi: LPS 140 HPS }~ijM.:{MWbïi/fJt¡tí:¡ ,'" ""'Ì'; - /Pilb .. Well J>ermit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE ~ ,<rJ..,O 1.f~'\" 1811430 140 100 95 P P OIL ,/ C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 ' 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day Remarks: Wells # C-O2 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 817100 Page 1 of 1 VI v7irqm.xls Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-In ~ iCurrent Mechanical Condition of Well2 Possibilities3 Comments MPB-O~ Jul-97 A No knOwn'problems I High GOR well, Facilities can not handle gas. Possible production after gas . expansion project.. . MPB-08 May-94 E No known problems 3 Futher use as an in~ector not reqUired MPB-13 Jan-86 B GL well that was shut in due to high 3 Wellhouse and flowlines removed water cut. Possible channel into water zone. '"MPB-17 Jan-96 E No mechanical Problems. Quick 3 Wellhouse and flowlines removed communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 We#house and flowlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems ' 3 Further use as an injector not required while associated producer shut-in MPC-12 / ' Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drifting problems. 12a MPC-16 Aug-93 A High GOR well, perfs and completion 3 We#house and flowlines removed abandoned "MPC-17 May-O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for sOlution to problem. ~P~20~'~:~-i~~ Apr-O0 B High Water cut Well, no mechanical I Evaluating possible plans for solution to problems problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible plans for solution to . problem. "MPD-01 Dec-90 C Dead ESP completion' no support to I Evaluating pos'sible plans for solution to block problem. Possible alternative uses for wellbore MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possibi~ plans. ' 02a cut well MPE-02 Jun-OS C No known problems 2 Recomp'lete to upper Kup zon'e ' ' MPE-19 Aug-99 C Failed ESP on tubing, string 2 Well. brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports ot~er wells I . Eva'l'uating side track possibili, ties MPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities 'MPL-21 0ct-98 ~ E ........... High'pressure'block' 5000 psi, no I i=ossible use for injection when pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP,. no other~ mechanical' I Evaluating Possible side track plans or issuses recompietions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or for it. recompletions , , , , , ? ANNED JUN 2 '4 2002 *Note - Wells were shut in 100% during 2001 Miine Pt Shut In Wells 2001 .xls ~ --- -'~S BEEN ON OR BEFOI . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.77 DATE: July 12, 2000 Commissioner '! I/o/be.) THRU: Blair Wondzell, ~~ P. I. Supervisor ' ef 1(éxJ FROM: ~t!¡ Jeff Jones ,,-"" SUBJECT: Safety Valve Tests Petroleum 'I sp c I r Milne Point Unit B & C Pads July 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. "3 JI-P... r~h5i- --- -r 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-]2-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 BPS 7/9100 ~ ,/ '::(;'~~':-./;.:~1~'\' '~:'r,~~;{''.:' '. -. . . ". . '. .. , '."',., ." ,; "il ;~í"";I.' ,,: ::';is \:T':~; I¡~:~ ~?~ij\ ~~:,;~~¿';: ;~~, '~~ell~,TYþ.e: :,. ' . " '"S~¥li <:::'\"''-':k,Well Data " ~, ',', ;! I. Pilots. ',. ':;" ':p;I :-I. . .' ,... I ~ ,.: . , . I '.' ,".. " . I Well Permit Sepal' Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE . G.}...Q 1:''''\' I~;," / 1811430 140 100 95 P P OIL ; . . . " ',t:t:'. ..' C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 ' 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day We lis: Relllarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7 lOa Page 1 of] V 1 v7irqm.xls RECEIPT UESTED ;':;:..::: '.::.'....'.!..::..',: ,'.::.,: :..:,::.. ;.':.:..',::... , ' '.:i',.~';,,: ',':,k: ~ ,, .~ ,..'.... ,.: ,..-' :.: ? ,.?:,~..... .....,,~ ....., ',,' . ..,, ,,-_ ,,,.' .~.". , u ,.. L '.,~, . ., J ..~';.~. ., . ...,:. ,,....:.....~:'., :..~, .,,,...: .:~-... . .'..~.~:...'...,./?.?',;~ ~ ,..; ].:~:..'~.. :,.,......?,,:.,~. :.'.~:, , ~.~.::,".2..;... ::.'.,.~ ..:._:.:'~..., ;..:..', :~'., ~¥ ~:: ~ :':~; :-,~.~{,:... - ,~, ~' . , . .~, ':".. . . ,.,; ,. ,, · . '..~:.?:,;~:~.,~%,~.b,.:.,,.t~.~.,~.~...~.i,,~=.~!;~,~.,,~.:~.. t' i",;.~),.'i':~.i-'. .... ~ - ~...~ .~ ,,., .. ; ~ ..-. ..,. -, !.¢,,~. ~.~.,... .~p:. ~ ..~ ,~ . ...%...: .,,, . ':.5!,~,...:', ' .~..~ ~,~ .'.., ,~,, ~. ;..~ ..; .,, . ''~;.~.. ~.~.o, : -~.,.,:: 77 - - ~.,,~? ,,,,,--:-, .-, ::, ,:, '.. ,,..,: .-, ,: .,., . .. ,, . ,,. ,, · ,., ::ii. .';,~ :.'..~.~. , .., LLIBURTON lNG S£t~'1C£.~ /NC; FROM: HALLIBURTON LOGGING SERVICES P.O. BOX 250450 ANCHORAGE~ ALASKA 9~525 ALASKA OIL AND GAS CONSERVATION COMMISSION 5001 PORCUPINE DRIVE ANCHORAGE, ALASKA ~501 ATTN: JOHN BOYLE TO: POSTMASTEr: CONTENTS FIRST CLASS MAIL Form HL$-768! 1. Operations pedormed: STATE OF ALASKA At 'A OIL AND GAS CONSERVATION COMM~¢ '-ION REPOR, OF SUNDRY WELL CPL..ATIONS Operation shutdown M Stimulate -X. Plugging M Pedorate __ ~ ~ Pull tubing __ Alter casinc~ ~ 2. Name of Operator CONOCO INC. 3. Acldress 4. Location of well at surface 906' FSL, 2138' FEL, At top of productive interval 1921' FSL, 13'- FWL, At effective depth NA At total depth 2009' FSL, 1912' Repair well __ '.45. Type of Well: SEC 10, T13N, RIOE, U.M. SEC. 11, T13N, RIOE, U.M. FWL, SEC. 11, T13N, RIOE 12. Present well condition summary Totaldepth: measured 8503' true vertical 7600' Other Development --X- Exploratory __ Stratigraphic __ Service __ 6, Datum elevation (DF or KB) KB 45 7. Unit or Property name Mi!ne .Point Unit 8. Well number 9. Permit numbedapproval number gq- 1 6,./'¢Z'-, 10. APl number 50-- 029-21914 11. Field/Pool Kuparuk Rivet' Field Form 10-404 Rev 06/15/88 Effective depth: measured true vertical NA feet Plugs (measure(I) NA feet feet Junk (measured) feet NA Casing Structural Conductor Surface Intermediate Production Liner Pedoration depth: Length Size Cemented Measured depth True vertical depth 13 3/8 No Change No Change 9 5/8 No Change No Change 7" Substitute No Change Dead Oil for measured7680'-7700'; 7722'-7730 ; 7768-7 "7866'-7900'; 7906'-7940' trueve~ca)7016'-7032'; 7051'-7057'; 7088'-7093'; 7170'-7233' Tubing (size, grade, and measured depth) 3 1/2, 9.3 lb/ft. L-80, ~ 8100' Packers and SSSV (type and measured depth) Otis "WD" perma-drill pkr 9819'; Otis "RH" w/PBR 7586' pk! 13. Stimulation or cement squeeze summary See attached J~ [~ C ~ !V ~ ~ Intervalstreated(measured) 7680'-7700'; 7722'-7730'; 7768'-7774' .!\IFY, ! ,,,~,~ 2 0 I§87 Treatment description including volumes used and final pressure See attached · "'"'; & das []OP.% r, · · 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data ".,; ,~llC,~10ra~3 OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 0 0 0 1200 150 82 34 1200 180 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ._~ Gas __ Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. / SUBMIT IN DUPLICAIE feet C-20 Acid StinTulation (or how to acidize at -30 c~eg. F) Nove~Tber 12, 1989 Rig Up Ha ve Dowe I 1: bring all fluids out at 100 deg. F bring out MSDS sheets on all ~tls. bring out at least 12 sacks of Soda Ash. Have a Tioga avail, to heat transport valves Load I500 gal (35. 7 Bbl) of diesel into the DowelI Tanker with the 150 gal of Mutual Solvent already on board. Make sure this ~ixture is at 100 deg. Load HBR with 80 bbls of diesel, heat to 100 deg. F Spot and rig up Coil tubing unit with 2. 4" bull nose (previously used for reversing on cleanouts) Spot the three Dowel I tankers (Acid, Diesel w/ MuSol, and A~:~oniu~ Chloride) and HBR all to feed the suction of the Dowe l l pu~p. Roll all tanks while the hardline is laid etc. Tie the pu~p discharge into the filter pod and fro~ there to the Frac~aster ~anifold. Tim the oil soluble resin divertmr pu~,~p into the line downstrean~ of the filters and upstrea~ of the frac~aster ~ani fold. Insure the line fron~ the well to the 400 bbl tank Hold a ~afet~ ~eeting w/ all personnel Pickle Coil Fill Coil and surface lines w/ diesel and pressure test to 4500 psig. PuMp 3 bbls of A~loloniu~ Chloride at .25 Bpo~ Pu~lp 150 gal (3. 6 bbls) of 7. 5% MSR-iO~ at . 25 Bp~ Pu~p 24 Bbls of straight diesel from HBR at .25 BPM Take returns fro~ above to the 400 BbI tank RIH w~ Col 1 RIH w~ Coil to 7784' RKB (Approx. 7771 CTM) Pu~p down coil w~ diesel to insure for~lation will take fluids and at what pressure and rate. Change to other filter Note tubing and annulus pressures. Reverse w~ A~n~oniu~ Chloride at ~ax rate until 100% A~oniu~ Chloride is returning. Returns can be taken into the 400 bbl tank. Sa~ple returns to deter~ine when clean brine is co~ing, back. Note coil and annulus voluble = 85 bbls total. P~unlp Acid Staqe POOH w~ Coil to 7675' RKB (Approx. 7662' CTM) Pu~p down coil w~ 24 bbls of 7. 5% MSR-I00 at i BPM while taking returns to tank. Fill surface piping w/ diesel, bullhead 10 bbl diesel into the annulus, keep annulus pressure below 2000 psi. Shut in return line and allow acid to soak across perfs. Pun~p Rmn~aining acid at .25 to .5 bpn~ (Start diverter once 500 gal of acid has been pun~ped, since well was shut in) Start diver~er a~ 1% to 3% depending on treating pressure. Over fl ush Switch Filters Again PunTp 1500 gal of diesel w~ Mutual Solvent at .25 to .5 BPM Pu~Tp 24 BBLs of diesel fro~7 HBR Shut down put, ps and observe annulus pressure for 15 ~in. Flow Well POOH w~ coil while flowing well at 50% of shut-in pressure. Gradually increase the choke setting to 64/64 over a 2 hour p~r i od. Once pH of returning fluids has returned to nor~ai flow well to ~ani fold building and through the test separator. Initiate gas lift while flowing the well on a 209 choke and record flow rates. ,Riq Down and Clean Up RDMO, have a vac truck reprove the fluid fro~ the 400 bbl tank. Take a sa~ple of the fluid in the truck. Separate the water phase fro~ the oil using a centrifuge. Pipette the water phase into a beaker but through a piece of filter paper. Check the pH of the water phase and add enough soda ash to the vac truck to bring the pH up to at least 5. Place the fluid in the ORT. · . [ i. . ~ . ~. . ": , : · · . - ~ ~6~ - 7 ~7~ ............................................. ................................................ .......... ............... ............ ..... ,";' ' t ~ , . ..... .._ d ~%_ .~~.~__ 8 :, ~~_ ................................. ....................................... Checked By Date P~'tge of T~lle CCI%CCC 6aloulation F;e.J Conoco, Inc. Daily Well Activity Report Alaska Activin: ~~~ ~~ ~~ ~ Zone(s) O~n: ~, . Weather: Wind: ~ Kts.; Gusts To: Kts.; Temp: OF/ oF WC; Visibili~: Mi. From To Daily O~rations .... Well Bore Fluid, Pretties: Type D/~ ~I/C~~ Weight: Total Fluid Pr~uced: Last 24 Hrs. BBLS, Cum. BBLS, Ty~ , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. Sec. BPV: In~ SSS~Clos~ Downhole Plug:~ Depth 7~~~Type~~ /No Se e. rson e : . Rig: ~ ~ ,' ~//'g ~, Zz ~ ~_ i Supe~isor: Daily Cost Estimate: $ ~~ ] Cum. Woll/Activi~ Cost: $ ~~ I Auth. Amt: $ Conoco, Inc. __ Daily Well Activity Report Alaska w~,: c - ~c I ~,e:/,//?~/~ Activin: ~1'~ ~/'~/~/~ Zone(s)Open: Weather: Wind: ~ ~ /~ Ets.; Gusts To: Kts.; Temp: -- /~ OF/- ~ ~ oFWC; Visibili~: Mi. From To Daily O~rations . u , I / ~ ' / i ~ 23 q~ ~ r Well Bore Fluid, Pro~ies: Type Weight: Total Fluid Pr~uc~: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Ty~ , Weight PPG, Visc. Sec. Se~ice P er~nnel:~~; ~, ~ ~~ ] ~' Rig: Su~i~r: ~,, co, ~s,,~,e:, q~. OO ~ I Cum. We,,, Conoco, inc. Daily Well Activity i__port ~.y~ Alaska , , Well: ~- ~-~ C) I Date: /7/b__~/(c:~ (~ ! Cum. Days for Activity: / Activity: Zone(s) Open: ~"~ ~, Z ? (A~c_ ~u/~ ) Weather: Wind: ~ Kts., Temp: °FI °F WC Visabilit~: Mi FromTo Hrs.Daily Opera/ohs _ ~/o6 ~/~ 661~ ~,~ ~ ~ 7~ " " ~3~ ~ " " " - .. ~/~o ~/~ p~ ~F~ ~ ~o '~. " ~ ~ ~ """ " ~/~0 ' o . ,, ,, ~q Ot) u .... ~ - -/ ~D~ ~7 cow ~/ ~ ~'p.~ .. ~-~Y~ ~ z ~ ~ ~ - Well Bore Fluid, Properties: Type Weight: Total Fluid Pr~uced: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, V/sc. Sec. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, V/sc. Sec. BPV: In/Out SSSV: Open/Closed Downhole Plu~: Yes Depth T~pe INo Se~ice Personnel: Rig: ~ Supe~isor: Daily Cost: Cum. Well Cost: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. 3. Address 3201 C St #200, Anchorage 4. Location of well at surface 906' FSL, 2138' FEL, At top of productive interval 1921' FSL, 13' FWL, At effective depth N/A At total depth 2009' FSL, 191' FWL, Operation shutdown __ Re-enter suspended well __ v Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance __ Perforate __ Other __ 5. Type of Well: Development X Exploratory __ Stratigraphic __ 99503 Service __ Section 10, Section 11, Section 11, T13N, R10E, UM T13N, R10E, UM T13N, R10E, UM 6. Datum~l~v~n (DF or KB) Unit or Properly name MILNE POINT UNIT 8. Well number C-20 9. Permit number 89-15 10. APl number 50-- 029-21914 feet 11, Field/Pool Kuparuk River Field 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 8503 ' feet Plugs (measured) N/A 7600 ' feet N/A feet Junk (measured) N/A feet Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 13-3/8" 110 ' 9-5/8" 5229' 7" measured 7680'-7700'; 7722'-7730'; 7906'-7940' truevedica17016'-7032'; 7051'-7057'; 8236' 7768'-7774'; 7088'-7093'; True vertical depth 7866'-7900'; 7170 '-7233 ' Tubing (size, grade, and measured depth) 3-1/2", 9.3#/Ft, L-80 @ 8100' Packers and SSSV (type and measured depth) Otis "WD" Perma-Drill Pkr 9819'; Otis .,RH" W/PB; 7586' Pkr; otis "FMX" SCSSV @532' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation November 9, 1989 16. If proposal was verbally approved Oil ___X N/A Name of approver Date approved Service 17. I hereb, y certify tha--'~foregoing is true and correct to the best of my knowledge. Signed 15. Status of well classification as: Gas __ Suspended __ Title Senior Production Foreman 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- Original Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STIMULATION PROCEDURE Acidize Well C-20 Milne Point Unit ' r TI3N RIO[ UM Surface Location: 897' FSL, 2,152' FEI_, ..,ac. 10, , , D_ep.~hs- All depth: are measured from KB datum. C~sing-. Surface-9 5/8", 36#/fL, L-80 btrs., set at 5,179' Production- 7" 26#/ft L-80 btrs set at 8,498'. Capacity: 3.82 bbl/]O0' Burst Pressure- 7~240 psig 3 1/2", 9.20~/ft., L~80, btr$ .Fa 7,586' Capacity' (].8700 bbl/lO0' Capacity of tubing/casing annulus- 2.64 bbl/lO0' Burst Pressure: I0~160 psis/ (no sat=eLy factor) Present_C_qmpletion- Middle Kuparuk: 7)680'-7,700'~ 7~722'-7,730', 7,768'-7,774 Lower. Kuparuk' 7,866'-7,g00' , 7,906'-7 ,940' Objective: Acidize the Middle Kuparuk to remove mud damage. ~ ~ ~ i~'.,:~'. Recommended Procedure~ 1) Hold a meeting with all contractors to discuss job requirements and safety prior to the job. 2) The well contains an Otis FMX $CSSV. Malntaln sufficient control line pressure to keep the valve open throughout the job. 3) Run in the hole with wireline and set tubing plug in the X-N nipple located at 7,643'. Also set dumm~ valves in the 1 1/2" mandrels located at 7,675' and 7,714', Pressure te~t the tubin~ to ~0n psig ~or 10 minutes. If the tubing does not hold pressure, contact chorage office before pro- ceeding, Retrieve the dummy valves and leave the X-N nipple plugged during the acid job. Move in two 400 bbl. tanks to hold clean ammonium chloride water and retu~-ns. Inspect on~ Lank for cleanliness. The other tank will be used to hold returns. Distribution' TRP) JDC~ PJG (2)~ HPU Senior Foreman Acidize Well C-20 November 1, !989 Page 2 5) Rig up service company to pump acid solutions, diesel and ammonium chloride through coiled tubing. Install a dual man~fold high pressure (5,000 psig) filter unit downstream of the injection pumps. Filter all fluids to two microns, AQueous fluids and the diesel should be filtered through separate sections of the unit to minimize contamination of the treating fluids. Install a high pressure pump downstream of the filters for continuous injection o~ the oil soluble resin divertin9 agent. Three samplin~ points should be available. One should be located immediatels upstream of the filter unit. Another should be located downstream of the filters. The third sampling point should be located downstream of the diverter pump. An injection manifold should be used to tie into the coiled tubing, 3 tubing and flowline to the return tank. Install m pressure recorder on the coil X 3 1/2" annulus for continuous monitoring of surface pressure. A turbine meter should be installed to monitor injection r~te. Pickle the coil tubing with the following treatment then pressure test to the maximum working pressure. Blow down the lines to the holding t~nk. a) 3 bbls. ammonium chloride brine. b) 150 gal. HCL Follow with a coil tubing volume of ammonium chloride brine. 7) R'IH to approximately 7,784'(10' below bottom MK perfs). Open the manifold to begin taking returns through the coil into the holding tank. Reverse circulate clean an~onium chloride water down the 3 1/2" tubing taking returns through the coil. Pump at the maximum rate (Reduce rate if fluid is bein9 lost to the perfs), Sample the returns for brine concentration. Continue circulating until returns are 100% clean mmmonium chloride water. 8) Pull up to 7,670' (10'* above the top perfs), Pump the following acid treatment while closely monitoring and recording the ~nnulus pressure (coil X 3 1/2"), The annulus pressure will not be influenced by friction pressure. ~racturing should not occur at pressures below 2,000 psig. Maximum allowable treatln~ pressure is 4~000 psig. Primary Acid Stag~ a) Circulate a coiled tubing volume of ? 1/2% MSR ]00 (~pproximately 537 gal.) to 7,670' at ! BPM. Shu~ down and shut-in the ~nnulus. Continue pumping 3,400 gal. 7 1/2% HSR 100 (See Materials Detail for recommended additives). Pump at a rate of 1/4 to 1/2 BPM at a pressure not to exceed frac pressure (Determined by monitoring coil x 3 1/2" annulus pressure). NOTE: Oil soluble resin diverting agent should be added to acid stage down stream of the ~iltration unit at ~ tale of 1% to 3%. Actual diverter concentration should be based on pressure response observed during the job. Do not begin addlng dlverter until $00 gal. of acid solution has been d~splaced into the perfs. Acidize Well C-20 November ], I989 Page 3 Overflush: c) Follow with 1,500 gdl. diesel containing 10% mutual solve~lt, Displace to the p~rF$ with a coiled tubing volume of 3% ammonium chloride water. Shut down and continue to monitor annulus pressure for 15 minutes then open the well for flow back. Pull out of the hole with coiled tubing while flowing the well. 10) Bring the well on Initially at 50% of shut-in wellhead pressure. Over a 2 hour period gradually increase the choke to 64/64, initiate gas lift and flow the well at maximum rate attainable for 24 hours. Report stabilized flow tests to th~ Anchorage office. Material Qetail · 7 I/2% HSR-]O0 Corrosion Inhibitor (A-250) Non-emulsion agent (as per pre-job test) Anti-sludge agent (as per pre-job test) Diesel (Includes Exce~s) Mutual Solvent (~GMBE) Oil Soluble Resin Diverter 3,400 gal. 4 gal. 2,000 gal. 150 gal. ]02 ~al. NOTE: 1) The recommended acid system should be tested with a MPU crude s~mple in accordance with API RP-42 prior to the job. The emulsion tests should be conducted using both live and spent acid. The results of the testing and service company recon~nendations for the non-emulsion and ant-sludge agents should be sent to Anchorage for review at least one week prior to the job. In addition, a s~mple of the mud used to kill well C-~O should be tested for solubility with proposed ~cid system prior to the job. 2) Hix all chemicals on location. Begin rolling the tanks 45 minutes pr~or ~o the job and continuously throughout the job to insure proper mixing. 3) Run pH tests on the returning fluid and indicate the pH on the morning report. 4) Onsite titration of the acid is required to insure proper concen- tration, Acidize Well C-20 ~November ], !gSg Page 4 5) Periodic spot checks of the treatment Fluid _~hould b~ made buth upstream and downstream of the filter~ during the job (Primarily to determine filter effectiveness). 6) Service company should provide a strip chart showing rate and pressure for the entire job, ¢oi 1 ed Tubing spec_s~ O. D I. D. Capacity Wall Displacement Total Displacement Yield Strength (tensile) Burst Pressure (test) Collapse (Max Working) ! .31" 70.03 gal ./1 ~000' 0.52 bbl s/1 ~000' 2.18 bbls./1,000' 29,350 lbs. 7,640 p.sig ],500 psig Prepared By: neer l / Approved By' Supervising Production Engineer Field Superintendent 1. Operations performed: STATE OF ALASKA /' '-' 'SKA OIL AND GAS CONSERVATION COM' '- 'SION REPOh, OF SUNDRY WELL OP,-.P, TIONS Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing L Alter casing __ Repair well __ Other X_.fr a c 2~ ~f ~)~r.ator 3. Address 3201 C ST,, STE. 200, ANCHORAGE, AK 5. Type of Well: Development X.~ Exploratory __ Stratigraphic ~ Service __ 4. Location of well at surface . 900' FSL, 2161' FEL, SEC 10, T13N, RIOE, U.M. At top of productive interval 2080' FSL, 5180' FEL, SEC. 11, T13N, RIOE, U.M. At effective depth NA 2LC~2~mlc~jLh, 4912' FEL, SEC. 11, T13N, RIOE 6. D~n ~[~vation (DF or KB) 7, Unit or Propedy name Milne Point Unit 8. Well number C-20 9. Permit number/approval number 89-15/9-717 10. APl number 5o- 029-21914 11'Fiel~°tl'uk River Field feet 12. Present well condition summary Total depth: measured 8503 ' true vertical7 600 ' Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet feet measured feet true verticalNA feet Length Size Plugs (measured) NA Junk(measured) NA Cemented Measured depth 13 3/8 No Change No Change 9 5/8 No Change No Change 11 measuredTO be determined aftr Substitute No. Change Dead Oil for o rCtjc Pak {60 bbls)* gg~ng True vedical depth true vertical Tubing (size. grade, and measured depth)3 1/2, 9.3 lb/ft. L-80, ~ 8100' Packers and SSSV (type and measured depth)Otis "WD" perma-dril 1 pkr 7819'; Otis "RH" w/PBR 7586' Otis "FMX" SCSSV @ 532' 13. Stimulation or cement squeeze summary NA Intervals treated (measured) Treatment description including volumes used and final pressure NA 14. Representative Daily Average Production or Injection Data Ar~Ch0ra¢-9 Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl CasingPressure ~bingPressure 776 59 48 0 220 720 102 49 870 240 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X_ 16. Status of well classification as: Oil X Gas~ Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. ~igned (~~~' .. Title Form 10-404,,¢(ev 06/15/88 SUBMIT IN DUPLICATE Conoco, inc. Daily Well Activity F, ort Alaska Well: ~_-- ~, 0 I Date: ~ /ICI / ~ I AFE/Facility: Activity: ~--/-_-¢¢_-"C0~ ~TI~,,~,~J~'"T"~-, Zone(s)Open: Ltd-- I ['0t'7 I Cum. Days for Activity: '/g~(o - --fq~-O Weather: Wind: EI~ @ ~ Kts.; Gusts To: Kts.; Temp: OF/ [~ oF WC; Visibility: ~5 Mi. Daily Operations -~b O,~ 'Oo~e.o.. O~ Lo(_~-no~ ~ ,5 ,z t'z.o 4,0 5o33 ~0~- (o,0 4q45 iol 9,5 ~.0 4q150 f- Well Bore Fluid, Properties: Type ~ ~-~0 -"~i ¢_.15~L Weight: Total Fluid Produced: Last 24 Hrs. (~ BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. ~) Sec. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi,sc. BPV: In/~'~ SSSV:(~Closed Downhole Plug: Yes Depth Type Service Personnel: Daily Cost Estimate: $ /No HAD F"ROB._..EMS K]:Li....i'NG WEL. L W'J:'T'H THE': .'.L2,,-':::'; i'qAE:l.....,'"i'.-.iA)?,i::;;,., HA;t;) 'f'O i"i ]: X .'L 3 ~ 5 F'F'G h'iU D i"Z:, ..., i::: i i...i_i:.:.':i]) Wr.'E L L ,, RL! ".,¢'.j];REi ?.hie Ai'"-.iD i:-:,'.)]H W]:'TH '-' ' ....i'"i T i...i_f"~; i"~' E:.; X TENS T F'ilq i."~: ' :]!; .mi../' '7'" i:::'i It::' i:.~:] !"'-.i i'"..i T i:::'!:::'i....iiii] r_ X T i!.:i.': iq:.E; ]; E) N ~ ...................... ..., ........... , ..... :t.':}' 3 :L/2:'" PUF' AND SHEAR 6 ~ Si:::. ! F:AC KEF-:.: AT 78 ;i.'::?" ,, 'f'C) i....OWER PA:i'..'.k;ER, DROPPED BAL..L, i:::'RE:i:;.'S.jI:.i:Ef.} UP Ah. ID :i31E"l .... i"(]i:::' i'"lr"~'"'t'"'t'~ ~'"1! .... F':"A(]:i'::;!ER, I-l-',..~..:.~.::.':LJi-',..l:::. UP Ai"qD Si'-t.EAR (3U]' 9 ,, R :[ H Ai',.!.f.) SET PLUG 'i.~ ix! X i"4 'J: F:'i::'i....E ,, iL.i.., S.PACE OUT AND ]'iqSTALL '~'":' L(][].'k: D('-)Wi'"4 H;ABiGER 'i"ES''~' BACK S:[)"Di:.Z "rf'i .'_i.F:~,:")(") i:::' !iii!; I ? ...... .................. T ix!:E;'T A t.... i .... );;') i:::' V .'L !;'", .-. i::"RAC"FLJRE"' S'T' ]: ?ii. iL. ATE ,, Co ,,~ ~ CC) V ORIGINAL Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 August 19, i989 Alaska O-;_ _~ ar:d Gas ~,~_~.~'mn~er,:.~ t-'.,_._ ...~ on Co'.qFm~; ssion Dear Hro Chatterton- Re: n~o~,~=e~ ~'ion,_. Report Conoco MPU C-20 {~'?-~'i,~.seci you ~.~ ] ] ~i nd eh~ .........- _ .,_. , .... comr~ietion_ _ report_ 'Fo~.~ = the Conoco Ni.~_~'ne Po~ nt Unie n-20 we] i ~ ~ s,~se enc osed is a summary ef '~-he daily ~ .~ ~ ~ ~ ~ ,~ __ dri..~ ~ .... ~ and ~v ' rv ~s r~no~. e ro su ey T~ have ~ you any ~Dieas~.~ ca;~ me or Bob Soptei a2 ~59-632~.~ , . Hal Stevens Safety &" ~ ; ~omp, 3 anco Coordinator cc ~:~or ..... ~ ..... ~ Specialist Production Specialist Senior Foreman ' '-:J" STATE OFALASKA ~' ~ ALASN. ;ILAND GAS CONSERVATION t..,/IMISSION ~ ~ ! C ! IA~ .~ L WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number CONOCO INC. 89-15 3'. Address 8. APl Number P.O. Box 340045, Prudhoe Bay, AK 99734 50-029-21914 4. Location of well at surface 9. Unit or Lease Name 906' FSL, 2138' FEL, Sec 10, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 1921' FSL, 13' FWL, Sec 11, T13N, R10E, U.M. C No. 20 At Total Depth 11. Field and Pool 2009' FSL, 19i' FWL, Sec 11, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Field KB = 45 MSLI ADL 47433 12. Date Spudded 06/26/89 13. Date T.D. Reached 07/07/89 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 07/12/89 N/A feet MSL One I ' 17. Total Depth (MD+TVD) 18~Plu_oB_ack De~th (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21 Thickness of Permafrost 8258'MDRKB,7506'T~D 2~ ~ YES~] NO~] 496 MDRKB feetMD 1900 RKB 22. Type Electric or Other Logs Run ~se~ HoleT%Compensated Neutron Log MWD: Electromagnetic Wave Re- sistivity (EWR), Dual Gamma Ray (DGR), Compensated Neutron Porosity (CN¢) 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" 45.9 H-40 Surfacel ii0'RKB 30" Cold set to surface NA 9 5/8" 47 L-80 Surface 5229'RKB 12 1/4" 2680ft3 Perm. E,320 fl.3G NA 7" 39 L-80 Surface 8236'RKB 8 1/2" 350 ft~ Class G NA 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) 3 1/2" 7948' RKB 7620' RKB 7680'-7700' MDRKB (7016'-7032' TVD) 7722'-7730' MDRKB (7051'-7057' TVD) 7768'-7774' MDRKB (7088'-7093' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7866'-7940' MDRKB (7170'-7233' TVD) DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED All intervals were shot @ 12 JSPF w/Vann Sys 25 GM. Deep penetrating charges (0.46" EHD) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} 07/15/89 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. . CORE DATA None . :..-~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~'~ 29. 30. GEOLOGIC MARKERS NAME Stratigraphic ToF Kup Interval Middle Kup (MK) Laminated Zone (I Lower Kup 1 (LK1) Lower Kup 2 (LK2) Base Lower Kup 2 31. LIST OF ATTACHMENT~ MEAS. DEPTH lv~)RKB 7576' 7680' 7694' 7880' 7908' 7938' Daily Drilling Reports, 32. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH! TVDRKB 6928' 7014' 7026' 7180' 7204' 7229' GOR, and time of each phase. None Tested Gyro Directional Survey I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 CHRONOLOGICAL WELL HISTORY Kuparuk River Field - North Slope Borough, Alaska W.I.72.14934% Milne Point C No. 20 (P) CONFIDENTIAL (8,498'-Kuparuk River) AFE 10-61-1197 API No. 50-029-21914 Ak. Permit No. 89-15 RKB: 29.5' Location: 2080' FSL, 5180' FEL, Sec. 11, T13N, R10E, U.M. 06/25/89 Accept Rig at 2200 hours. Continue to mix spud mud. P/U HWDP. Daily Mud Cost: $ -0- Cumulative Mud Cost: $ -0- Daily Cost: $164,157 Cumulative Cost: $ 164,157 06/26/89 P.U. BHA. RIH tag bottom at 106'RKB. Function test diverter system - OK. Displace wellbore with mud. Drilling F/106' to 2091'. Repair rotary table drive system. MWD DIRECTIONAL SURVEYS DEPTH INCLINATION AZIMUTH 380 0.5 N 3.2 1017 0.4 N40.0 1696 0.6 N61.2 1941 0.8 N60.2 Daily Mud Cost: $ 5,421 Cumulative Mud Cost: $ 5,421 Daily Cost: $ 38,972 Cumulative Cost: $ 203,149 06/27/89 Continue repair of rotary table drive system. Drilling with packed hole assembly F/2091' to 2600'. Circulate and condition hole. Pump pill and POOH. Change BHA to Navidrill system (1 degree bent sub). RIH to 2600'. Navidrill F/2600' to 3511'. MWD DIRECTIONAL SURVEYS DEPTH INCLINATION AZIMUTH 2350' 0.8 2660' 2.6 2908' 8.8 3156' 13.7 3409' 16.7 S17.6 S72.8 N84.4 N64.2 N62.6 Daily Mud Cost: $ 2,600 Daily Cost: $ 30,149 Cumulative Mud Cost: $ 8,021 Cumulative Co~ .'~ _~ E 1~3~ ~8 Ar~chomge 06/28/89 Continue drilling F/3511' to 4294'. Spot pill short trip to 2600'. Drilling F/4294' to 4922'. MWD DIRECTIONAL SURVEYS DEPTH INCLINATION AZIMUTH 3659' 21.0 N66.3 3908' 26.8 N66.3 4159' 30.2 N64.0 4440' 31.7 N62.8 4723' 32.9 N64.5 4881' 33.5 N66.3 Proposed EOB = 4043' Proposed Axe Angle = 33-1/2" Proposed Direction = N62 Degrees E Daily Mud Cost: $ 2,556 Daily Cost: $ 28,695 Cumulative Mud Cost: Cumulative Cost: $ 10,577 $ 261,993 06/29/89 Continue drilling F/4922' to 5247'. Circulate and condition hole. Pump pill and short trip to 4300' - no fill encountered. Circulate and condition hole to run casing. Pump pill POOH to 1450'. RIH 12 stds to wipe borehole over ratty interval. POOH, lay down BHA. R.U. casing crew. Run 133 joints of 9-5/8', 47#/ft, L-80, BTRS casing. MWD DIRECTIONAL SURVEYS DEPTH INCLINATION AZIMUTH 5175' 33.9 N67.9 Daily Mud Cost: Daily Cost: $ 5,046 Cumulative Mud Cost: $ 15,623 $199,735 Cumulative Cost: $ 461,728 CASING TALLY NO. PIECES SIZE-WEIGHT-GRADE-THREAD-ETC MAKEUP SETTING LENGTH DEPTH 1 2 1 131 1 Halliburton Superseal II Float Shoe 9-5/8", 47#/ft, L-80, BTRS, Casing Halliburton Superseal II Float Shoe 9-5/8", 47#/ft, L-80, BTRS, Casing Tankco 9-5/8" Fluted 1.42 5227.77 77.56 5150.21 1.07 5149.14 5112.62 36.52 06/29/89 (Continued) Centralizers and Spacing: 1/Jt - first 13 Jts. 1/2 Jts-Jts 1 through 125, 1/3 Jts-Jts 125 to 133. Total = 72. Halliburton 12- 1/4" x 9-2/3" S-4 Centralizers. Preflush: 60 BBLS of 11.0 PPG Sepiolite. Cement (Stage I): 477 BBLS of 123 PPG Perma Frost 'E'. Cement (Stage II): 57 BBLS of 15.8 PPG Class G without 2% CFR-3, Salt - 3% BWOW and 0.09% LWL. Disp. Fluid: 378 BBLS of 9.4 PPG Mud (Gel/Extend-Spud). (06/30/89) TIME STARTED TIME COMPLETED RATE (BPF) PSI (MAX) Circulation 0030 0213 7 400 Pre-Flush 0215 0231 4 300 Stage I 0240 0418 7 800 Stage II 0418 0429 4 1600 Displacement 0429 0538 6 2250 Recip. Pipe 0345 Unable to Recip. Why Stopped Excess PU WT Bottom Plug: No Top Plug: Yes Bumped Top Plug: Yes 1000 psi Total Pumped Disp.: 378 BBLS Floats Held: Yes Full Returns: No Full returns for first 475 BBLS Cement Returns to Surface: No Initial String Weight: 250K Pounds Final Landing Weight: 300K Pounds Service Company: Halliburton Performance: Fair Supervisor: Jim Fox 06/30/89 Land 9-5/8" casing R.U. circulating/cementing head. Circulate and condition mud. Rate = 7 BPM. Pressure = 450 psi. Pump 5 BBLS fresh water spacer. Pump 60 BBLS 11 PPG Sepiolite Preflush. Cement 9-5/8" casing with 1360 sks Permafrost 'E' and 280 sks class "G" (w/0.2% CFR-3, 3% BWOW Salt and 0.09% LWG). Lost circulation after lead and ± half of the tail volume. Assuming 14" ave. hole size-estimated TOC = ~ 3900' (3850' TVD). Displaced cement with 378 BBLS mud. Bumped plug with 2700 psi (1000 psi over final circulating pressure). Floats holding pressure. N.D. diverter stack. Run (132' RKB) 100' of 1/2" conduit along side casing. Hanger and circulate 8 BBLS of Permafrost "C" cement. No Permafrost cement (15.6 PPG) and circulate to surface. Total Annular volume = ± 390'. Recover conduit. N.U. well~~&~ 06/30/89 (Continued) Daily Mud Cost: $ 1,952 Daily Cost: $129,000 Cumulative Mud Cost: $ 17,575 Cumulative Cost: $ 590,728 07/01/89 Modify flow NPL. M.U. test equipment. Pressure test/function test BOPD - OK. Dart valve failed. R.D. test equipment. Install wear bushing. M.U. bottom hole assembly. TIH tag float at 5148'. Pressure test casing to 1500 psi for 30 minutes - OK (no leakoff). Circulate and condition mud. Drilling float shoe and 10' of new hole. Perform EMW test to 850 psi with 8.8 PPG mud and 850 psi applied pressure. No leakoff at EMW of 12.1 PPG - OK. Drilling F/5247' to 5918'. MWD DIRECTIONAL SURVEYS DEPTH INCLINATION AZIMUTH 5362' 34.7 N65.2 5612' 34.3 N63.3 5768' 34.5 N61.7 Daily Mud Cost: $ 1,160 Daily Cost: $ 72,896 Cumulative Mud Cost: $ 18,735 Cumulative Cost: $ 663,624 07/02/89 Continue drilling F/5913' to 6192'. Circulate hole 15 minutes, pump pill short trip to casing shoe. Drilling F/6192' to 7194'. Pump pill and short trip to 6190'. Drilling f/7194' to 7508'. DEPTH MWD DIRECTIONAL SURVEYS INCLINATION 6112' 34.5 6488' 34.2 6956' 34.3 7333' 34.5 N60.5 .... '~ .. N59.4 Daily Mud Cost: $ 5,364 Daily Cost: $ 60,139 Cumulative Mud Cost: $ 24,099 Cumulative Cost: $ 723,763 07/03/89 Continue drilling F/7508' to 7586'. Encountered slight drilling break. Gas cut mud and oil to surface. S/I, check for flow - OK. Drilling 7586' to 7602'. Gas cut mud to surface. Circulate and raise mud Wt. to 10.2 PPG. Pump pill. Short trip to casing shoe (4980'). No implux. Slip and cut drilling lime. RIH to 7602. Drillin~ F/7602' to 7696'. Encountered drilling break and 25 bbl gain in pit volume. Well flowing. S/I well. Weight up mud to 07/03/89 (Continued) 10.8 PPG. Circulate 10.8 PPG mud. Mud returns still gas cut. S/I well for new readings. Continue to circulate while increasing mud Wt. to 11.2 PPG. Circulate 11.2 PPG mud. Daily Mud Cost: $ 11,847 Daily Cost: $ 58,725 Cumulative Mud Cost: $ 35,946 Cumulative Cost: $ 782,488 07/04/89 Continue to circulate 11.2 PPG mud. Maintaining D.P. pressure (± 450 psi at 30 SPM) by circulating through choke line. Mud returns are gas cut and oil cut. S.I. well. SIDPP = 175 psi, SICP = 170. Build mud weight to 11.7 ppg. Circulate 11.7 ppg mud at 30 SPM and D.P. pressure = ± 450 psi. Continue to see slow gains in mud volume. Casing pressure fell to 0 psig. Check for flow - still flowing. Shut well in. SIDPP = 80 psig. SICP #16 psi and building. Build mud weight up to 11.9 psig. Mud returns are still gas cut. Circulate 11.9 PPG mud at 30 spm. Open annular preventer and circulate through flowline. Wellbore periodically takes fluid but still shows some gas cutting at times and continues to be oil cut. S.I. pumps - slight flow. Mud weight of returns increasing. Circulate well with 11.9+ ppg at 35 spm. 11.8 returns. S.I. pumps - still slight flow. Start building mud weight to 12.0 ppg and circulate at 45 SPM. Daily Mud Cost: $ 26,697 Daily Cost: $ 69,946 Cumulative Mud Cost: $ 62,643 Cumulative Cost: $ 798,434 07/05/89 Circulate & build mud wt. to 12.1 ppg. Well still flows weakly w/pumps off. Build Barite plug of 34 bbl @ 21 ppg (~200' in length). Spot plug in open hole. POOH 4 stands, slow. Circulate drill string to clean S/D pumps & observe well - no flow for 5 min. Begin POOH, slow. Daily Mud Cost: $ 9,522 Daily Cost: $ 60,250 Cumulative Mud Cost: $ 72,165 Cumulative Cost: $ 867,684 07/06/89 L/D turbine, RLL tool, MWD directional & Monels. M/U packed hole assby. RIH to 7500', slow (hole stable). Wash & ream f/7500' to 7720'. Drlg f/7720' to 7946'. Short trip f/7946' to 7000' & RIH (clean trip). S/D check for flow, none observed in 5 min. Drlg f/7946' to 7974'. By ROP log top LK1 appears @ ~7884' MD (7171' TVD) . Daily Mud Cost: $ 8,329 Daily Cost: $ 42,000 Cumulative Mud Cost: $ 80,494 Cumulative Cost: $ 909,684 RECEIVED · ,:.?~ i ~'~, -- .... 07/07/89 Drlg. f/7974' to 8097'. Pump pill, POOH f/8097' for 10 std wiper grip. Drlg f/8097' to 8258'. Circ & observe returns, S/D check for flow - well stable. Short trip 10 stds. Daily Mud Cost: $ 5,850 Daily Cost: $ 21,250 Cumulative Mud Cost: $ 86,344 Cumulative Cost: $ 928,643 07/08/89 Complete short trip to 8258'. Circ & condition mud (gas & oil on bottoms up). Short trip to shoe @ 5227' & RIH. Pulled 25k to 30k over @ 7563'-7590' & 7044' Circ & condition (gas & oil on , · bottoms up). POOH, tight @ 6985'-6930' & 6567'. RIH, slow. Circ bottoms up, POOH - clean trip. Preparing to run csg. Daily Mud Cost: $ 4,979 Daily Cost: $ 7,102 Cumulative Mud Cost: $ 91,323 Cumulative Cost: $ 935,745 07/09/89 POOH. Pull wear bushing, test 7" csg. rams to 500 low/3000 high, test hydril 500 low/2000 high. R/U to run csg. Conduct safety meeting. Run 130 jnts of 7", L80, 29 lb/ft csg. (Running speed - 2 min/jnt). Circ. bottoms up @ 9 5/8" csg. shoe. Continue running csg. Dropped ball to deactivate differential fill float equipment @ 5328' (running time 1 min/jnt, through Kup). Total Ran - 212 jnts. Float Shoe @ 8236' Flaot Collar @ 8153' R.A. Marker @ 7537' As of 0500 cement in place. Daily Mud Cost: $ 3,349 Daily Cost: $194,987 Cumulative Mud Cost: " 3 Cumulative Cost: $1,130,733 07/10/89 Finish running 212 jnts of 7" 29 lb/ft L-80 csg. w/BTRL thds Full returns while running pipe (31 how cents? 1/80' on #1-#62; 36 standoffs #133-#206). Circ. & condition mud @ 5 BPM, max press 800 psi. Circ. BU, S/D for 15 min to allow any trapped gas to migrate. Continue circ. until no gas is seen. Pump a 40 bbl pill of 13.3 ppg Sepiolite followed by 5 bbl H20. Pump 62.5 bbl of 15.8 ppg class G (297 sks) w/0.2% CFR-3, 0.2% Halad 344, 0.9% LWL and 0.07% Gas Ban. Full returns while pumping @ 6 BPM. Max press 1200 psi. Displace cmt w/12.3 ppg mud, (302 bbls) 2917 stks @ 6 BPM, bump plug & press up to 1450 psig. Full returns, floats held. R/D Howco, install 7" packoff & test to 5000 psi. L/D DP using mouse hole. R/U & run HLS CNL & GR, CCL from 8050' to 7450' - 4 passes. ,. (7866~ go 79oow), g~2 (79o6w ~ 794o~). ~ ~/ga~ge z~9 & 3~ b~e~. ~eg ~ ~ 8050w (5.9" OD ~ge z~9). ~00~ & ~/U ~o z~ Gyro. NOTE: Injected 500 bbl of mud into 7" x 9 5/8" annulus @ 2 BPM. Broke down @ 800 psi, injected @ 50 to 200 psi. Daily Mud Cost: $ 2,819 Daily Cost: $ 56,195 Cumulative Mud Cost: $ 97,512 Cumulative Cost: $1,186,928 07/11/89 Complete gauge ring & junk basket run. R/U & run gyro, tool malfunctioning, POOH Run gyro to 4630' cannot get down POOH Run gyro to 4000', tool not transmitting. POOH. Found broken connector. Run gyro w/3 1/2" wt bars & centralizers from 8000' to surface. At MK interval: MD Ind. Az. TVD Lat. Dep. 7600 33.94 61.9© 6950.11 993.89N 7700 35.27 62.3© 7032.45 1020.45N 2110.48E 2160.63E Install 3 1/2" pipe rams & test to 5000 psi & 500 psi. R/D test tool, pull wear bushing. Repair lock on traveling block. P/U Vann guns w/time delay firing head & mech type II firing head, isolation tool, Champ III packer, hydraulic jars, safety joint & 3 1/2" tbg, 9.3 lb/ft, L-80, EUE 8RD, RIH. Daily Mud Cost: $ Daily Cost: $ 62,422 Cumulative Mud Cost: $ 97,512 Cumulative Cost: $1,326,509 07/12_/89 Continue running completion string in the hole withing 10' of PBTD. Displace wellbore to a depth of 7733' RKB with 15 BBL high viscosity gel sweep. 10 BBLS water and 325 BBLS NaCl/NaBr (10.3 PPG) brine. Run GR/CCI correlation log. Space out and rerun correlation log. Relocate Pup joints 1 full joint below TBG HMG. M/U and land TBG hng. P/U 6.75' to pu PKR and perf assembly on depth. Rerun correlation log - verified guns are on depth. R/D HLS. Displace TBG w/ 66 BBLS of diesel then over displace 20 BBLS. Rotate TBG 2 full turns and set down ±35K pounds to set PKR at 7620'. Guns are located at 7680'-7700' RKB (MK), 7722'-7730' RKB (L-8), 7768'-7774' RKB (LK-1) and 7866'-7940' RKB (LK-2). Guns are loaded at 12 JSPF w/ 25 gm D.P. charges. Land TBG HMG and lock down. Pressure test PKR w/ 1500 PSIG on annulus - ok. L/D landing Jt., install BPV. Install variable rams in top set. N.D. BOPE. N.U. wellhead. Injected 490 BBLS mud and 10 BBLS diesel down 7" x 9-5/8" annulus at 2-1/2 BPM and 1000 PSIG. Note: Pup joints (10' 4' and 8') are located 1 vt below TBG HMG) 07/12/89 Continued Daily Mud Cost: Daily Cost: $ $140,065 Cumulative Mud Cost: Cumulative Cost: $ 97,512 $1,466,574 0 I:! I I--I--I ~ G SEFt~Ir'E S Mr. Steve Brady Conoco, Inc. Milne Point Pouch 340045 Prudhoe Bay, Alaska 99503 July 12, 1989 Re: Our Boss Gyroscopic Survey Job No. AK-BO-90064 Well: C-20 Milne Pt., Alaska Survey Date: July 11, 1989 Operator: T. McGuire Mr. Brady: Please find enclosed original and one copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Kon Broussard District Manager Directional Services RECEIVED 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 0 .00 -45.00 100 100.00 55.00 290 200.00 155.00 300 299.99 254.99 400 399.99 354.99 COURSE DIRECTION DEGREES 0 0 N .00 0 20 N 26.10 0 24 N 27.0C 0 25 N 8.60 0 21 N 5.60 DATE OF SURVEY: JULY 11, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. E .00 .00 .00 .00 E .34 .27N .13E .23 E ,07 .~3N .42E .75 E .13 1.53N .64E 1.24 E .06 2.21N .73E 1.60 500 499.99 454.99 600 599.99 554.99 700 699.99 654.99 800 799.98 754.98 900 899.98 854.98 0 25 0 16 0 21 0 25 0 8 N 78.80 E .47 2.59N 1.12E S 60.60 E .28 2.55N 1.70E S 86.70 E .17 2.42N 2.22E N 73.90 E .14 2.50N 2.88E S 80.50 E .30 2.58N 3.36E 2.13 2.63 3.04 3.68 4.14 1000 999.98 954.98 1100 1099.98 1054.98 1200 1199.98 1154.98 1300 1299.98 1254.98 1400 1399.98 1354.98 1500 1499.97 1454.97 1600 1599.97 1554.97 1700 1699.97 1654.97 1800 1799.96 1754.96 1900 1899.95 1854.95 0 23 0 6 0 19 0 6 0 20 0 28 0 22 0 36 0 39 0 51 N 49.60 N 83.50 N 76.90 S 42.60 S 7.30 N 77.70 S 64.10 S 89.10 S 43.20 S 65.60 E .32 2.78N 3.74E E .31 3.01N 4.08E E .22 3.09N 4.44E W .41 3.09N 4.65E E .29 2.73N 4.63E E .61 2.52N 5.08E E .30 2.47N 5.78E E .31 2.32N 6.59E E .49 1.90N 7.50E E .36 1.18N 8.58E 4.57 4.98 5.33 5.53 5.35 5.67 6.28 6.95 7.59 8.25 2000 1999.94 1954.94 2100 2099.93 2054.93 2200 2199.92 2154.92 2300 2299.92 2254.92 2400 2399.91 2354.91 0 54 S 49.30 0 46 S 29.50 0 34 S 32.80 0 32 S 20.10 0 58 S .50 E .26 .35N 9.86E E .32 .76S 10.80E E .20 1.78S ll.41E E .13 2.65S 11.84E W .51 3.94S 12.00E 9.06 9.43 9.55 9.57 9.16 2500 2499.89 2454.89 2600 2599.86 2554.86 2650 2649.83 2604.83 2700 2699.76 2654.76 2750 2749.58 2704.58 1 13 S 4.00 1 40 S .30 1 55 S 52.60 3 51 S 83.90 5 47 S 88.90 E .27 5.86S 12.07E E .45 8.39S 12.15E E 3.21 9.63S 12.82E E 4.85 10.32S 15.16E E 3.95 10.55S 19.36E 8.40 7.39 7.47 9.29 12.98 2800 2799.25 2754.25 2850 2848.82 2803.82 2900 2898.32 2853.32 3000 2997.06 2952.06 3100 3095.30 3050.30 7 15 7 43 8 26 9 47 11 36 S 88.30 E 2.94 10. N 87.10 E 1.51 10. N 83.90 E 1.70 10. N 78.10 E 1.63 7. N 72.00 E 2,14 2. 69S 25.04E 61S 31.55E 05S 38.55E 52S 54.17E 66S 72.06E ,t ! ,~. 18.06 23.97 30.54 45.74 63.99 SPERRY-SUN DRILLING SERVx-£S ANCHORAGE ALASKA PAGE 2 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3200 3192.88 3147.88 13 41 N 63.10 E 2.84 3300 3289.89 3244.89 14 22 N 64.20 E .74 3400 3386.27 334%.27 16 28 N ~2.80 E 2.12 3500 3481.94 3436.94 17 23 N 63.70 E .97 3600 3577.00 3532.00 18 43 N 63.60 E 1.33 5.81N 16.57N 28.45N 41.55N 55.32N 92.18E 85.80 113.92E 110.05 ]37.71E 136.63 163.72E 165.75 191.50E 196.76 3700 3670.89 3625.89 21 30 N 65.80 E 2.87 3800 3763.24 3718.24 23 33 N 65.20 E 2.07 3900 3853.97 3808.97 26 9 N 65.70 E 2.61 4000 3943.10 3898.10 27 45 N 67.00 E 1.70 4100 4031.22 3986.22 28 40 N 66.70 E .93 69.97N 85.87N 103.32N 121.49N 140.08N 222.61E 231.14 257.46E 269.44 295.70E 311.47 337.22E 356.78 380.68E 404.01 4200 4118.23 4073.23 30 22 N 63.90 E 2.19 4300 4203.86 4158.86 31 47 N 62.10 E 1.70 4400 4288.78 4243.78 31 58 N 63.10 E .56 4500 4373.53 4328.53 32 8 N 63.20 E .18 4600 4458.07 4413.07 32 26 N 64.00 E .52 4700 4542.34 4497.34 '32- 42 N 65.00 E .60 4800 4626.28 4581.28 33 8 N 65.90 E .65 4900 4709.80 4664.80 33 34 N 66.80 E .66 5000 4793.11 4748.11 33 34 N 67.60 E .44 5100 4876.36 4831.36 33 42 N 68.90 E .73 160.69N 425.42E 453.26 184.13N 471.40E 504.85 208.44N 518.29E 557.63 232.41N 565.64E 610.68 256.16N 613.49E 664.09 279.33N 662.08E 717.93 301.91N 711.52E 772.28 323.97N 761.89E 827.24 345.40N 812.88E 882.50 365.93N 864.33E 937.78 5200 4959.31 4914.31 34 12 N 69.50 E .60 5300 504'2.05 4997.05 34 9 N 69.60 E .08 5400 5124.60 5079.60 34 34 N 69.10 E .51 5500 5207.01 5162.01 34 25 N 68.90 E .19 5600 5289.64 5244.64 34 8 N 65.10 E 2.16 385.76N 916.53E 993.45 405.38N 969.17E 1049.42 425.29N 1021.98E 1105.67 445.58N 1074.85E 1162.14 467.57N 1126.67E 1218.39 5700 5372.39 5327.39 34 10 N 64.60 E .28 5800 5455.06 5410.06 34 17 N 64.30 E .21 5900 5537.76 5492.76 34 6 N 64.00 E .25 6000 5620.47 5575.47 34 17 N 63.40 E .38 6100 5702.99 5657.99 34 30 N 63.30 E .22 491.44N 1177.50E 1274.54 515.70N 1228.26E 1330.80 540.21N 1278.85E 1387.02 565.12N 1329.24E 1443.21 590.46N 1379.73E 1499.69 6200 5785.47 5740.47 34 20 N 62.60 E .42 6300 5868.09 5823.09 34 14 N 62.10 E .30 6400 5950.84 5905.84 34 4 N 61.70 E .28 6500 6033.82 5988.82 33 46 N 61.30 E .37 6600 6117.03 6072.03 33 36 N 60.70 E .37 616.17N 1430.08E 1556.20 642.31N 1479.99E 1612.49 668.76N 1529.51E 1668.57 695.38N 1578.55E 1724.29 722.27N 1627.07E 1779.65 SPERRY-SUN DRILLING SERVI~£S ANCHORAGE ALASKA PAGE 3 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6700 6200.47 6155.47 33 16 N 60.50 E .35 6800 6284.23 6239.23 32 57 N 60.70 E .35 6909 6368.23 6323.23 32 45 N 60.70 E .].9 7000 6451.72 6406.72 34 0 N 60.10 E 1.29 7100 6534.56 6489.56 34 7 N 60.00 E .12 749.33N 776.15N 802.70N 829.88N 857.84N 1675.08E 1834.62 1722.68E 1889.12 1769.99E 1943.24 1817.83E 1998.11 1866.36E 2053.94 7200 6617.39 6572.39 34 2 N 60.10 E .09 7300 6700.24 6655.24 34 2 N 60.50 E .22 7333 6727.57 6682.57 34 8 N 60.70 E .44 7400 6782.91 6737.91 34 28 N 61.00 E .57 7500 6865.41 6820.41 34 20 N 62.00 E .58 885.82N 913.56N 922.65N 941.04N 968.01N 1914.92E 2109.80 1963.56E 2165.63 1979.67E 2184.08 2012.66E 2221.76 2062.32E 2278.18 7600 6948.18 6903.18 33 56 N 61.90 E .40 994.40N 7700 7030.48 6985.48 35 16 N 62.30 E 1.35 1020.97N 7800 7112.88 7067.88 33 44 N 63.20 E 1.61 1046.91N 7900 7197.04 7152.04 31 37 N 64.60 E 2.25 1070.67N 8000 7282.66 7237.66 30 34 N 65.20 E 1.09 1092.59N 2111.85E 2334.24 2162.03E 2390.97 2212.38E 2447.58 2260.85E 2501.56 2307.62E 2553.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2553.21 FEET AT NORTH 64 DEG. 39 MIN. EAST AT MD = 8000 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 64.66 DEG. SPERRY-SUN DRILLING SERVIu£S ANCHORAGE ALASKA PAGE 4 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION O .00 -45.00 1000 999.98 954.98 2000 1999.94 1954.94 3000 2997.06 2952.06 4000 3943.10 3898.10 .00 .09 .00 2.78 N 3.74 E .02 .02 .35 N 9.86 E .06 .04 7.52 S 54.17 E 2.94 2.89 121.49 N 337.22 E 56.90 53.96 5000 4793.11 4748.11 6000 5620.47 5575.47 7000 6451.72 6406.72 8000 7282.66 7237.66 345.40 N 812.88 E 206.89 149.99 565.12 N 1329.24 E 379.53 172.64 829.88 N 1817.83 E 548.28 168.75 1092.59 N 2307.62 E 717.34 169.06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVIu~S ANCHORAGE ALASKA PAGE 5 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -45 00 45 45.00 .00 145 145.00 100.00 245 245.00 200.00 345 345.00 300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .01 N .01 E .00 .00 .51 N .25 E .00 .00 1.14 N .56 E .00 .00 1.86 N .69 E .01 .00 445 445.00 400. 545 545.00 500. 645 645.00 600. 745 745.00 700. 845 845.00 800. 00 2.48 N .77 E 00 2.65 N 1.45 E 00 2.45 N 1.89 E 00 2.41 N 2.50 E 00 2.59 N 3.19 E .01 .00 .01 .00 .01 .00 .02 .00 .02 .00 945 945.00 900. 1045 1045.00 1000. 1145 1145.00 1100. 1245 1245.00 1200. 1345 1345.00 1300. 00 2.58 N 3.47 E 00 2.97 N 3.96 E 00 3.02 N 4.17 E 00 3.14 N 4.67 E 00 3.02 N 4.60 E .02 .00 .02 .00 .02 .00 .02 .00 .02 .00 1445 1445.00 1400. 1545 1545.00 1500. 1645 1645.00 1600. 1745 1745.00 1700. 1845 1845.00 1800. 00 2.48 N 4.68 E 00 2.59 N 5.44 E 00 2.35 N 6.05 E 00 2.29 N 7.06 E 00 1.53 N 7.87 E .02 .00 .03 .00 .03 .00 .03 .01 .04 .01 1945 1945.00 1900. 2045 2045.00 2000. 2145 2145.00 2100. 2245 2245.00 2200. 2345 2345.00 2300. O0 O0 O0 O0 O0 .89 N 9.19 E .12 S 10.39 E · 29 S 11.10 E · 17 S 11.65 E .07 S 11.98 E .05 .01 .06 .01 .07 .01 .08 .01 .08 .00 2445 2445.00 2400. 2545 2545.00 2500. 2645 2645.00 2600. 2745 2745.00 2700. 2846 2845.00 2800. O0 O0 O0 O0 O0 4 6 9 10 10 · 72 S 12.00 E · 85 S 12.13 E .53 S 12 · 69 E · 54 S 18.89 E .64 S 31.03 E · 10 .01 .12 .02 .17 .04 .40 .23 1.14 .74 2947 2945.00 2900. 3048 3045.00 3000. 3150 3145.00 3100. 3253 3245.00 3200. 3356 3345.00 3300. O0 O0 O0 O0 O0 9 5 1 11 22 · 25 S 45.51 E · 70 S 62.38 E · 11 N 82.05 E · 56 N 103.60 E · 91 N 126.90 E 2.20 1.06 3.68 1.48 5.83 2.15 8.66 2.83 11.97 3.31 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3461 3445.00 3400.00 3566 3545.00 3500.00 3672 3645.00 3600.00 3780 3745.00 3700.00 3890 3845.00 3800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 36.43 N 153.34 E 50.49 N 181.78 E 65.83 N 213.53 E 82.53 N 250.24 E 101.53 N 291.73 E MD-TVD VERTICAL DIFFERENCE CORRECTION 15.29 4.32 21.21 4.92 27.25 6.04 35.10 7.84 45.03 9.93 4002 3945.00 3900.00 4115 4045.00 4000.00 4231 4145.00 4100.00 4348 4245.00 4200.00 4466 4345.00 4300.00 121.88 N 338.14 E 143.06 N 387.61 E 167.59 N 439.51 E 196.04 N 493.96 E 224.32 N 549.64 E 57.15 12 · 12 70.71 13.56 86.03 15.32 103.40 17.37 121.30 17.90 4584 4445.00 4400.00 4703 4545.00 4500.00 4822 4645.00 4600.00 4942 4745.00 4700.00 5062 4845.00 4800.00 252.52 N 606.02 E 139.51 18.21 280.06 N 663.63 E 158.16 18.65 306.91 N 722.68 E 177.36 19.20 333.17 N 783.37 E 197.25 19.89 358.40 N 844.81 E 217.30 20.05 5182 4945.00 4900.00 5303 5045.00 5000.00 5424 5145.00 5100.00 5546 5245.00 5200.00 5666 5345.00 5300.00 382.35 N 907.42 E 406.08 N 971.04 E 430.30 N 1035.11 E 455.05 N 1099.07 E 483.46 N 1160.69 E 237.69 20.39 258.57 20.88 279.78 21.21 301.04 21.26 321.89 20.85 5787 5445.00 5400.00 5908 5545.00 5500.00 6029 5645.00 5600.00 6150 5745.00 5700.00 6272 5845.00 5800.00 512.73 N 1222.08 E 542.36 N 1283.26 E 572.61 N 1344.20 E 603.46 N 1405.49 E 634.96 N 1466.10 E 342.82 20.93 363.74 20.92 384.69 20.95 405.97 21.28 427.07 21.10 6392 5945.00 5900.00 6513 6045.00 6000.00 6633 6145.00 6100.00 6753 6245.00 6200.00 6872 6345.00 6300.00 666.88 N 1526.03 E 698.97 N 1585.11 E 731.37 N 1643.28 E 763.69 N 1700.49 E 795.38 N 1756.95 E 447.95 20.88 468.45 20.50 488.59 20.14 508.24 19.65 527.38 19.13 6991 6445.00 6400.00 7112 6545.00 6500.00 7233 6645.00 6600.00 7354 6745.00 6700.00 7475 6845.00 6800.00 827.62 N 1813.90 E 861.38 N 1872.49 E 895.13 N 1931.10 E 928.43 N 1989.98 E 961.46 N 2050.00 E 546.89 19.51 567.60 20.72 588.33 20.72 609.06 20.73 630.28 21.22 SPERRY-SUN DRILLING SERVx~£S ANCHORAGE ALASKA PAGE 7 CONOCO INC. C-20 MILNE POINT ALASKA COMPUTATION DATE: 7/12/89 DATE OF SURVEY: JULY 11, 1989 JOB NUMBER: AK-BO-90064 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICALVERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7595 69~.5.00 6900,.00 7717 7045.00 7000.00 7838 7145.00 7100.00 7956 7245.00 7200.00 7980 7265.44 7220.44 993.39 N 2!09.96 E 1025.74 N 2171.13 E 1056.58 N 2231.53 E 1083.23 N 2287.39 E 1088.32 N 2298.39 E 651.17 20.89 672.78 21.61 693.62 20.84 711.23 17.61 714.56 3.32 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SP, E RFY-SUN DRL G.--- SVCS, C-20 MILNE POINT ALASKA JULY 11, 1989 HORIZONTAL PROJECTION START TVD '-' 0 FTNTSH TVD = 7282.66 SCALE ZS 500 FEET/TN 3000 2500 20001 Ltl :::) tSO0 I-- H I-* ~ooo4 500 Oi 8000 soho DEPARTURE SPERRY-SUN DRLG. SVCS, C-20 MILNE POINT ALASKA JULY 11, 1989 VERTICAL PROJECTION FINISH SCALE IS START TVD = 0 TVD -- 7282.66 1500 FEET/IN 0 1500 oooo J 4500 - 6OOO 7500 - 0000 8000 (~ 15~)0 ~ ' ~ oooo 4s~)o ,o~o 7soo 0ooo VERTICAL SECTION OXf~Cl'XON - 0.00 Bob Soptei (~COi'tOCO~ Aoecc Date Oo/i b/~3q ,.,SION 'PROVALS suspended well __ Stimulate __ erforate __ OtherX (Frac) 6. Datum elevation (DF or KB) KB 45 7. Unit or Property name Milne Point Unit 8. Well number C-20 9. Permit number 89-15 10. APl number 50-- 029-21914 11. Field/Pool Kuparuk River Field 7/^ ured depth 10' 29' 36' True vertical depth posed) 3~/~', 9.3#/Ft, L-80, 7575' PackersandSSSV(typeandmeasureddepth) (Proposed) Otis WD Pkr, 7820'; Otis WD Pkr 7520'; Otis TRDP SSSCV, 13. A~achments Oescriptionsummawofpropo~l__ Oetailedoperationsprogram~;_ 500' BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: August 28, 1989 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ N/A Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Senior Production Foreman Plug integrity BOP Test __ Location clearance . Mechanical Int--egrity Test __ Subsequent form required 1-'~'/Zt ~ ZI Conditions of approval: Notify Commission so representative may witness Original Signed By David W. Johnston Commissioner Approved by order of the Commission I Approval NO. 9 ~ ~/ &pproved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL C-2 0 PROPOSED OPEP, ATIONS PROGRAM 1. MI, RU, test BOP's and choke manifold. 2. PU and open bypass on pkr, kill well with 12.5 ppg Nacl/NaBr brine. 3. POOH with tbg and pkr. 4. RU wireline and RIH with otis WD pkr with 5' seal bore extension, 5' millout extension, 8' 3-1/2" pup, XN nipple, 10' 3-1/2" pup and shear out sub. 5. Set pkr at 7820'. 6. R/H with 6' seal assembly with locator and muleshoe on BTR, 3-1/2" tbg, 1-1/2" GL mandrel, 3-1/2" tbg, 1-1/2" GLM, 3- 1/2" tbg, x nipple, jt 3-1/2" tbg, Otis RH pkr, 20' SBR 1" GLM balance of pinned for 30,000 # shear, jt 3-1/2" tbg, , 3-1/2" tbg and GLM's, SSSCV. 7. Space tubing out so top pkr is set at 7520' stab into lower pkr, drop ball, pressure up and set top pkr, pressure up and shear out sub. 8. R/H set plug in x nipple. 9. PU and shear off SBR, circ out 12.5 ppg brine with 9.6 ppg brine. Send 12.5 ppg brine to baroid. 10. Space out and install hanger, set back over SBR. 11. Lock down hanger test back side to 1500 psi, install BPV. 12. ND BOP's, NU tree, move off rig. 13. Pull plug from x nipple. Space out 1" GLM mandrels to TVD's. All mandrels to have dummies. 14. Frac well. D I::t I I--I-- I N [3 SEPIVI C I:: S TO: Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: July 11, 1988 TRANS.#: 89711MPT-SSDS REFERENCE: CONOCO Milne Point C-20 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad.~ ENCLOSED INFORMATION SUMMARY Submittal C-20 1 Set C-20 Bluelines; 1 each 1 Set C-20 Sepia; 1 each 1 1 LIS Tape 1 1 LIS Tape Verification Received By: A.O.G.C.C. / Date 8537 Corbin Drive (99507) · P.O. Box 231649 ,, Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company 07×0~×89 22:53 .,~leco~ter ?02 : ;.~ CONOCO MILNE POINT RIG 141 ,, 002 STATE; OF ALASKA ? ALASKA OiL Al~ C~A~ r~NSERVATION .... Reserve pi~ ~ AnnU1eP prsven~eP ~ke line v~lve~ HC~ valve Kill line velve~ C~s~k valve _ ION Num~mr vA!vet Nldrfl~Hlr ft angel A~j u~tab I e " 0?/03/89 01:12 CONOCO MILNE POINT RIG 141 001 Mag~ By Oh('.okod By Date. Conoco Inc. Calculation Sheet RECEIVED J u L o 3 1989 _,~a,~ Oil & Gas Cons, Commission , Anchorage ,Job N(:. Fie:id Slat(.~ June 2, 1989 Conoco Inc, Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Application for Sundry Approval Attached please find an Application for Sundry Approval for the Milne Point Unit Well C-20. The revisions have been verbally approved by Mr. L. C. Smith. If you should have any questions, please contact Bob Soptei or Hal Stevens at (907) 659-6327. Yours very truly, D. F. Rainwater/E. L. Robinson Senior Production Foreman RJS Attachments STATE OF ALASKA AL,-,SKA OIL AND GAS CONSERVATION COMI¥ .... JION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator Conoco Inc. Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program .X_ Operation shutdown ~ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate __ Other __ 3. Address 3201 C St., Suite 200, Anchorage, AK 9950 4. Location of well at surface Revise Surface Location 906' FSL, 2138' FEL, Sec. At top of productive interval No Change At effective depth N/A At total depth No Change 10, T13N, R10E, UM, 5. Type of Well: Development _X_ Exploratory __ Stratigraphic __ Service __ NSB, AK 6. Datum elevation(DForKB) KB 28 l UnitorPropedyname Milne Point Unit 8. Well number C-20 9. Permitnumber 89-15 10. APInumber 50-- 029-21914 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured 8402* true vertical 7600* (Revisions) Effective depth: measured true vertical N/A feet feet feet feet Plugs (measured) Junk (measured) N/A N/A Casing Structural- No Conductor Surface Intermediate Production Liner Perforation depth: To be (Revisions) Length Changes 5194 8374' measured determined after true vertical Size 9-5/8" 71! logging. Cemented No Changes Measured depth 5222' · True vedical depth No Changes Tubing (size, grade, and measured depth) Reminder tc 3-1/2", L80, 9.2# determined Packers and SSSV (type and measured depth) a lat er dar 7" x 26 lb~ Halliburton Champ III 13. Attachments Description summary of proposal _X. Detailed operations program __ I~OP sketch 14. Estimated date for commencing operation 6/8/89 16. If proposal was verbally approved Oil ~ Gas __ Mr. L. C. Smith 6/2/89 Name of approver Date approved Service 17. I hereby cedify t~t) the foregoing is true and correct to the best of m,/ knowledge. Signed Title Senior Production Foreman F--~S~ ~NLY 15. Status of well classification as: Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH I Approval No.¢ ... ,~.~'"'"~"- Approved COPY Returned . Commissioner Date ~____~ '--~-'~32 be Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · SUPPLEMENTAL DATA SHEET APPLICATION FOR SUNDRY APPROVAL CONOCO MILNE POINT UNIT WELL C-20 Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 Reason for Change: Increase distance from closest wellbore. Additional Revisions: a. Move KOP from 3057' TVD/MD to 2700' TVD/MD. b. Closest wellbore is still C-13, but closure is now 52' at 2800 TVD instead of 11' at 3350' TVD. c. Maximum angle from 37 degrees to 34 degrees. * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. 1000 .. 2000. ~000 _ 4000 5000 KOP 1o 2o TVD=2?O0 TMD~2700 DEP=O 25 ;~o EOB PER ! GO Fl' TVD"3967 THD=4043 OEP=)82 9 5/8" CO0 PT TVD=4900 THD=$222 DEP=I034 O000 AVERAGE ANGLE 33 DEO 34 HI N 7000 8000 1000 2000 VERTICAL SECTION TAROET TVD=T200 TMD-7922 DEP=2527 (TOP LOWER KUPARUK) EIASE LOWER KUPARUK TVD=?~)40 THD-B090 DEP-2620 TD / )'" LINER TVD=?800 TMD=8402 DEP=2793 3000 CONOCO, !.,. Ped C, ~ell No, 20 Rev l~,d Pr.~,,a.el North Slope' A/eeke ~000 2000 1000 1000 1000 i WEST-EAST 0 1000 2000 mil 9URF. A~ 3000 ! TO, LOOAT[ON, TAROET DEP-a$2? NORTH 1 !11'4 ~'AST 2239 ~URF^OE LOOATZOH~ gO6' FSL, 2135' FEL SEO. !0, Tt3N, alOE TAROET LOOATION ~ P~O80' FILL, 100' FWL SEO, 11, T13N, RIO, E N 62 DEO 19 HI N E 2527' [TO TARI3ET) Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 17, 1989 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive, Anchorage, Alaska 99501 RE: Sundry Notices for Milne Point Unit Wells Dear Mr. Chatterton: Please find attached Sundry Notices for the following Milne Point Unit Wells: B-23, C-20, E-3, and CFP-1. These notices have all been verbally reviewed by members of your staff. Should you have any questions, please contact either Roy Robinson or Doug Rainwater at 659-6323. Thank you for your time and consideration. D. F. Rainwater/E. L. Robinson Senior Production Foreman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program --X- Operation shutdown m Re-enter suspended well ~ Plugging ~ Time extension __ Stimulate __ Pull tubing Variance ~ Perforate __ Other 2. Name of Operator CONOCO INC. 3. Address 3201 C ST., STE 200, 4. Location of well at surface 900' FSL, 2161 FEL, SEC 10, T13N, RIOE, U.M. At top of productive interval 2080' FSL, 5180' FEL, SEC 11, T13N, RIOE, U.M. At effective depth N/A At total depth 2220' FSL, 4912' FEL, SEC 11, T13N, RIOE ANCHORAGE 99503 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB 28 7. Unit or Properly name MILNE POINT UNIT 8. Well number C-20 9. Permit number 89-15 10, APl number 50- 029-21914 11. Field/Pool Kuparuk feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8503' 7600' Length N/A Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured To be determined after logging true vertical feet feet feet feet Size 13 3/8" 9 5/8" 7" Plugs (measured) N/A Junk (measured) N/A Cemented Measured depth True vertical depth No Change No Change No Change No Change Substitute No Change Dead Oil for Arctic Pak (60 bbl s)* Tubing (size, grade, and measured depth) 3 1/2, 9.3 Packers and SSSV (type and measured depth) lb/ft. L-80, ~8100' HB Champ III, dpth to be dtrmnd, SSSV-Otis Series 10 @ 500' 13. Attachments Description summary of proposal __ Detailed operations program __ *Only change is Dead Oil in place of Arctic Pak BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved 05/09/89 Oil x- C. V. Chatterton Name of approver Date approved Service 17. I hereby certify thct.,th¢ foregoing is true and correct to the best of m,f knowledge. Signed U//~/,~,'~ Title Sen i or Prod, Foreman FOR COMMISSION USE ONLY 15. Status of well classification as: Gas __ Suspended Date ,,f'""/C://o~,f'' Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical IntegrityTest ~ Subsequent form required 10- Approved by order of the Commission Approval No. ?. ¢'~,2~- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE March 6, 1989 Telecopy: (907)276-7542 D. F. Rainwater Senior Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. C-20 Conoco Inc. Permit No. 89-15 Sur. Loc. 900'FSL,2161'FEL, Sec. 10, T13N, R10E, UM. Btmhole Loc. 2220'FSL,4912'FEL, Sec. 11, T13N, R10E, UM. Dear Mr. Rainwater 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface easing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Con~nission may witness testing before drilling below the shoe of the conductor pipe. Ver~ tru!v y=ours, : / ~ / / ~./ ~ . / 1'~ / i .z !// _...' / / .... . / i !I / L/! ~-?: ..... ~.--V. ' Cha~~on' ~ ~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COb~/~ISSION dif Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviror~nental Conservation w/o encl. ? .... STATE OF ALASKA ALA, A OIL AND GAS CONSERVATIO,. COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen . Se~ice [] Developement Gas [] Single Zone [] Multiple Zone "2. Name of' Operator 5. Datum Elevation (DF or KB) 10'. Field an~l Pool CONOCO, INC. KB 28 feet 3. Address 6. Property Designation 3201 C St. Suite 200, Anchorage, AK 99503 ADL 47433 Kuparuk River Field 4'. Lo'cation of weil at su~f'ace "' 7. Unit or property N~me 11. Type ~ondlsea ~'~c 25025) 900'FSL,2161'FEL,Sec. 10,T13N,RIOE,U.M. ,NSB,AJ Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 8086-15-54 2080'FSL,5180'FEL,Sec. ll,T13N,R10E C-20 At total depth !9/Appro~(imate spud date -- Amount $200,000 2220'FSL,4912'FEL,SEc.ll,T13N,RlOE May 24, '1989' ,, , 12. Distance to n~arest 13. Disia'nc'e to nearest well 14. Nur~ber of acres in Pro-p'~rty 15'. Proposed depthiMo property line at target 100 feet 11' from C-13 3350 feet 2560 7600'TVD/8503'KD feet .,, 16. To be completed for deviated wells 17. Anticipated pressure Isee ~ A^C 25.035 Kickoff depth 3057 feet Maximum hole angle37 o Maximum surface 3200 psig At tolal deplh (TVD) 3800 psig "'18. ~asing program " _ S(~ttin~l Depth ..... size Specifications Top Bottom Quantity of cement "' H~le casing Weight Grade Coupling Length MD T~/D MD T~/D (include stage data) "30" 13-3/8" 48# H_-40 WELD 80.' 2'8" 28' 108' 108' +485 .sks Permaf. ro.st C 12-1~4" 9-5/~i' 47# L-80 BTRS 5153' 28' 28' 5181' 4950' +1487 sks Permafrost E -+272 sks Class G 8L1/2'' ~" '"29# IL-_80 BTRS 8475'" 28'"' 28' 8503' 7600' +33'0 sks ClaS's G _+180 sks Permafrost C 19. To be completed fc~r Redrill, Re-entry, and Deepen Operations. "' .i. 6'0 Bbl'~ Arctic Pak Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate - Production ~ t 6 Liner Perforation depth: measured ~$k~, 0~1 & G~S Cu0~.~. true vertical 20. Atiachments Filing f'e~ ~ Property plat ..~ BOP Sketch , Diverter Sk'~ich ~ Drilling I~r~gram ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report .'~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~. 7 ~,~¢~i ,4'~ Title -.~'-'/~//~;;,~ ,~ J_~.~x.'/..~.,.~ Date Commission Use Only permit NUmber j' ~,~1 number . J Ap..p,.,ro,v..al..d,a,.te-- J See cover I~tt~r' .~C~.../i_,~ ., J 50--..0.2.¢_2/~/~/~.~ J U.J/Ub/~J forotherrequirements CondJt[ons ot approval Samples required ~ Yes ,~No Mud log required ~ Yes ~No Hydrogen sulfide measures [] Ye~s. ~ No Directional.survey required .~"Yes [] No Required working,C~ssure fe~.IDO'PE) ',,~M;~ 3M; ,~ 5M; [] 10M; ~ 15M Other: J_~~ ~~,~~~"-'~~~~Co,. _ _ ' by order of Approved b mmissioner the commission Date Form 10-401 Rev. 12-1-85 SUPPLEMENTAL DATA SHEET Amah,,/. "' APPLICATION FOR PERMIT TO DRILL ..... CONOCO.MILNE POINT UNIT C-20 Conocot Inc, 3201C Street~ Suite 200 Anchorage~ AK 99503 I. Casing and Cementing Program Ae The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with ±485 sacks permafrost type "C". B, The 9-5/8" surface casing will be cemented with ±1487 sacks of Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top Job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of ±330 sacks of Class "G" cement pumped around the casing shoe. The secondary cement Job will consist of ±180 sacks of permafrost type "C" cement followed by ~60 barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. II. B, Ce D~ III. Drilling Fluid Program 0-500' 9.0 ppg %reshwater spud mud. 500'-5000' 9.0 ppg-9.8 ppg freshwater spud mud. 5000'-8000' 9.0 ppg-9.5 ppg dispersed. 8000'-TD 10.4 ppg dispersed. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field. The mud system will be Iow solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T>D> will be 10.4 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 test will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is C-13 with 11' of closure at a depth of 3350'. As a precaution the C-13 well will have production shut in and the gaslift pressure bled off of the annulus when drilling within 400 feet either side of this point. The wellbore will also be 60 feet from the C-14 wellbore at surface. Arctic pack will be placed in the 7" x 9-5/8" annulus after disposing of test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. Ae Be Ce Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ±4950' TVD (5181' MD) and set 9-5/8" casing. Drill a 8-1/2" production hole to 8503' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' 0' Gravel ' 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3864' 3951' "K" Sands 1-1-4 9.2 25 15 65 14 4125' 4217' "M" Sands 1-1-4 9.4 25 15 65 13 4379' 4478' "N" Sands 1-1-4 9.4 25 15 65 12 4498' 4613' "O" Sands 1-1-4 9.4 25 15 65 12 6693' 7362' Sea Bee 1-1-4 10.2 8 12 40 10 6915' 7640' Kup Top 1-1-6 10.2 8 12 35 5 7026' 7779' MK 1-1-6 10.2 8 12 35 5 7039' 7795' L.K. 1-1-6 10.2 8 12 35 5 7200' 7997' b K (1) 1-1-6 10.2 8 12 35 5 7219' 8020' L K (2) 1-1-6 10.2 8 12 35 5 7340' 8172' B L K 1-1-6 10.4 6 12 35 5 7600' 8498' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. --2-- CONOCO. I~. P,d C. W,I I No~ or. , ope, Ale.ke 0 . RKB ELEVATION~ 28' 1000_ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7'000 _ 8000., KOP $ 10 15 TVD=305T TMD=3057 DEP=O BUILD 2.5 DEO PER 100 FT 25 3O 35 EOB TVD=4439 TMD=4540 DEP=463 9 5/8' CSO PT TVD=4g50 TMD=5181 DEP=B50 AVERAGE ANGLE 37 DEO 5 MI N TARGET TVD=7200 TMD=8001 DER=2550 (TOP LOWER KUPARUK) BASE LOWER KUPARUK TVD=T340 TMD=81T7 DEP=265i TD / ?' LINER TVD=7600 TMD=8503 DEpI2853 i 1000 VERTICAL I 2000 SECTION I 3000 HOR ;~'~ONTAL PROJECT I ON ~.,,ALE 1 IN. = 1000 FEET CONOCO. Inc. Ped C. Well Not HI Ina Pomn~ Nor'~h ope, Alaska z lO00 0 ;5000 2000 1000 1000 SURF~._~ SURFACE' LOOAT I ON ' mO' FSL. 2161' FEL SEC, 10. TI,IN. R IOE WEST-EAST 1000 2000 I I 3000 I 4000 I TARGET TVD=?200 TI'ID=8001 DEP=2550 NORTH 1180 EAST 2261 TARGET LOCAT [ ON' 2080' FSL. 100' FWL SEC. 11. T13N. RiOE TD LOCATION' 2220' FSL. ,3~8' FWL S~EC. II. T13N. RI OE N 62 DEG 26 MI N E 2550' (TO TARGET) 300 200 100 O0 O0 _ O0 _ O0 >.00 _ k1400 - ~000 I X~°° I ~,ooo I I I I I ;~400 300 200 4000 3800 3600 3200 ?g°og I 100 6000 6200 6400 6600 22O0 3600 100 2OOO 2000 0 1800 ~00 lO0 200 I ~00 4000 ~0 300 -'*~200 I 200 300 400 500 600 700 I I I ~ __ ..._ 400 ... , 300 '"' 4400 -'"~600 400 1 5O0 I 60O )0 '/ 700 200 _ 100 _ 100 _ 200 TIME ESTIMATE Hours Days Cum. DaVs A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 8 0.33 3.66 C. Run Surface Casing and Cement 34 1.42 5.08 D. Drill Out and Test 8 0.33 5.41 E. Drill Production Hole 90 3.75 9.16 F. Log Open Hole 30 1.25 10.41 G. Condit'ion, POOH, L.D. 14 0.58 10.99 H. Run-Production Casing 16 0.67 11.66 I. Cement Production Casing 10 0.42 12.08 J. Run Cased Hole Logs & Perf 36 1.50 13.58 K. Run Completion EQ 12 0.50 14.08 L. Move Rig 8 0.33 14.40 TOTALS 346 14 . 40 14.40 LLI :~ -1 -2 -3 -4 -5 -6 -7 -8 -g MILNE POINT UNIT WELL C ...... 20 Rote ve.depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 RIG DAYS .. $1MPSOF-* LAGOON N MILN[ PT. UNIT bOue;DAqY · ................ r ........................... :~;~'~ ' .~..~ , c [_ .. ....................... : ..... ,,.. , .,.. .... ,.~_ sca~E m ~s CONOCO MILN/ POINT UNIT ~OTES: . L ST&TE PLANE EO-0ROlNATES ~RE ZONE . N.A.D. ~. O~5[~S ~O ~[C~IO~ LI~[~ ~[ E0~P~I[O B~SED ON PROTRACTED V~LUES OF . , ~[L[ ~0~.,,Ll~ ~ [. U~[ ~I~S I · [~S~I~S [~TIT~O[ ~ - [O~l~ff~[I ~[ ~[C~[~ ~I[L~ 8~ff, .. . · . , . .... ,. . C ' 3 ] 1395' 2326' 6,0~ ,671.~ 558,131 ~6 ~029' 30. IO~N. 149031' 29.137"W. ' ' C- 4 ~ 1344' 2494' 6,029,624.~ 557,963.~ ~' 29. 598"N. 149° 31' 34.~3"W. ' ' . C'5 ~ 551' 2254' 6,028,834~7 558,211 .74 ~°29' 21.807"N ...... 14~ 31' 26.~7.'W. 3.18,~ J.B~ 22 C- 6 ~5' 2Z89' 6 ,028,~7.80 ~8 , 175.18 ~029'~ .929~ 1490 31' 28.~7'W. ' ' C ' ? 1009' ~96' 6 ,029,290. ~ 558 , ~.~ 70029' ~. ~N 149° 31' 51. 162 'W. ' ' C-~ 7~' 2325' 6,029,~2.~ 558,138.49 ~0e29' 24. O~ ~. 149° 31' 29.060' W. ' ' . C *g [ lil4' 242e' 6,0~ ,395.~ 558,031.~ ~°29' 27.340',. 149° ~' 32.125"w. 6. i, ~ d.D.S. 22 C-lO I 894' 2~6d 6,02g, 176.~ S~, I01.82 70°29'25.184"~ t4g°~' ~. 115'W. ' ' " , , . , , , ~ ' , _. ~ ~F ~ ~'~ P A D r. ~-' · ~ ~ I MT SUP[NVISIOrl. ['JO THAT ALL D'MENSIO'JS ~_'~),lll L.S.~3798S ,,~/ SCALE :! SHEET: AND OTHER ~TAIL~ ARE CORNECT.~b"~<~p.eeee-ee .... e. ~' ~ ENGINE[ HS ~ ~ t:'O~Ess~oN ~t ~ ,. o c o ~ ~ E N T S: i · . ' i i I T 13 N R 9 E T 13 N R 10 E T 13'N R 1 1 E MILNE POIN' I II II III III j I I I i I i I I cH~v.o.<~co.oco E~ AL ® '~' --- CONOCO ET AL (~) CONOCO ET AL (~ (~Denotal tract. ADL-31971~' 1265 AC · '" 1 ADL CONOCO ET AL ]. 8 ~ ADL-255Og 2533J~C ADL-47434 2560 AC 433 ADL-47 2~60 AC . ® co. ® 15 + + -- m._ ADL-25516 l~ ADL-47439 ADL-3 1584 .OL-3,,e4e 4~ ~ADL-25514 2560 AC ADL-25515 2544 AC 12e0 AC 1280 AC ADL-47437 2560 AC ADL-4743o 254 C 1280 AC 1260 AC ~.°. @ .~c°-~°. @ ® c.~v.o. ..co-~xxo.~ . 30 29 28 2T 26 25 30 29 EXl- 3~ 33 34 Baled on Umla i 35 36 31 32 0 2235 AC 2 .ADL-25g<:H~ 12560 AC ADL-25518 2560 AC ADL-28231 2555 AC -- ~T I I I IIII I II UNIT numbefa 35,]'44 ACrel CHEV. ~RCO &OHIO 0/84 A UNIT AREA Merldlin.Alalke I 2 Scale -55 · Fu II I. I. ! I CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FILL-UP LINE FLOW LINE ANNULAR PREVENTER is IA ii' APl SO004 R&M BOP I~ S/t" APl SO00 lit , t L I$%' AP~ 5000~ ~ I~S/~' APl 5000~ ~ '- I~/$- APl $000~ ~ '11= APl 5000 ) TBG ' / il' APl 5000~ 5000 . . B.O.P. stack size rating meets API RP 53 & spec 6A for class 5R with clamp & hub connectors all hydraultcelly operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote vith 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds sho~m separately to meet APl RP 53 c]ass 5H requirements. CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318'.CONDUCTOR ,, FILL UP LINE FLOW LINE NIPPLE ZO~ APl ZOO0 pli ANNULAR PREVENTER RELIEF VALVE DIVERTER OUICK CONNECT ASSEMBLY START lNG HEAD FEB 1 6 l~B9 f~sl~ Oil & C,~s Co~s,. Commission 1. The hydraulic control system will be in accordance with APl specifications a~d AOGCC ~equi~e~ents. 2. The HCR valve will open ~hen the preventer closes. A single lO" r~iief iin~ ~il1 ~un off of ~he dpillin§ spool HCR valve and will have a targeted do~stream tee for downwind dive.sion. Valves on both sides of the tee will be full opening a~d linked together to e~able o~ to always be open a~d the other to be ~losed. BA ~_L VA[V~ fR£SERV~ PIT ~ALL VALVE PIPE HOUSE bLANK 5CK)O PSi I~ANUAL CHOKE 5O00 lo, ooo HYD C HOI~_ Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-63OO February 13, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Attn. Mr. Mike Minder COMM RES ENG SR ENG SR ENG ENG ASST ENG ASST -SR GEOL GEOl. ASSTI GEOl. ASSTI STAT TECHI STAT TECHI , FILE _ RE: Revisions to Permit to Drill Applications Dear Mr. Minder: Please find attached three (3) copies each of revisions for Conoco's Milne Point Unit B-23, C-20, and E-3 Permit to Drill. We have addressed your three concerns and have made the appropriate changes as discussed with you on the telephone on February 10, 1989. Should you have any more questions, please contact Roy Robinson or Doug Rainwater at 659-6323. Thank you very much, D. F. Rainwater/E. L. Robinson Senior Foreman RECEIVED FEB 1 6 1989 A!aska Oil & 6~s Cons. C~mmlssio~ Anchorage Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 January 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 RE- REQUEST FOR PERMIT TO DRILL MILNE POINT UNIT WELLS B-23, C-20 AND E-3 Dear Mr. Chatterton' In accordance with AAC 25.005, Conoco Inc. hereby submits applications for permit to drill wells B-23, C-20 and E-3 in the Milne Point Unit, North Slope Borough, 'Alaska. Attached is a check for $300 payable to the State of Alaska, Department of Revenue to cover the required permitting fees. Well B-23 is tentatively scheduled to spud in early May and will be followed by wells C-20 and E-3. Conoco Inc. is covered under a $200,000 blanket bond for drilling (Number 8086- 15-54), filed with the AOGCC and approved December 22, 1980. Wells B-23 and C-20 are development wells in the Kuparuk reservoir. Well E-3 is a gas injection/storage well. Drilling the subject wells will increase re- covery from the Kuparuk reservoir and provide a necessary gas injection point; therefore, Conoco Inc. contends that drilling these wells is in the best interest of the Milne Point Unit Owners and the State of Alaska. Questions of a technical nature can be directed to Mr. Paul Grimmer in Conoco's Anchorage office at 564- 7635. Division Manager RSR/cl Att RECEIVED File- 500.21 JAN 2 7 J3Jl & Gas Cons. Oommissio~ -~-~i~,,-'-~cli0rage ,-- STATE OF ALASKA Jib AND GAS CONSERVATION t. CMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~,. Redrill~1 lb. Type of well. Exploratory [] Stratigraphic Test [] DeveloPment Oil f~, Re-Entry []"%Deepen Service [] Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator '~%. 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO, INC. -'~ KB 28 feet 3. Address ~ 6. Property Designation 3201 C St. Suite 200, Anchd~age~ , AK 99503 ADL 47433 Kuparuk River Field 4. Location of well at surface '% 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 900'FSL,2161'FEL,Sec.10,T13N,~0E,U.M.,NSB,~J' Milne Point Unit Blanket At top of productive interval % 8. Well nu,mber Number 8086-15-54 2080' FSL, 5180' FEL, Sec. ll,T13N,R10E~ C-20 At total depth '"% 9. Approximate spUd date Amount $200,000 2220' FSL, 4912' FEL, SEc. ll,T13N,R10E ~. Mav 24, '1989 % , 12. Distance to nearest 13. Distance to near~'s~t well 14. Number of aCres in property 15. Proposed depth(MD and TVD) property line at target '5. 100 feet ll' from C-13 3350'~J'~eet 2560 7600'TVD/8503'MD feet ,, 16. To be completed for deviated wells % 17. Anticipated pressure (see 2o AAC 25.035 (eX2)) % · Kickoff depth 3057 feet Maximum hole angle37 o~ Maximum surface: 3200 p,~ At fetal depth (TVD) 3800 ,. · 18. Casing program ':~ Settling Depth size Specifications ~-?op ~' Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD1-, TVD MD TVD (include stage data) 30" 13-3/8"' 48# H-40 WELD 80' 28' '~_~8' 108' 108' _+485 sks Permafrost C 12-1/4" 9-5/8" 36# J755 BTRS 5153' 28' ::" 2~' 5181' 4950' _+1487 sks Permafrost E ;~- ~?~',~. +272 sks Class G 8-1/2" ~" 29# L-80 BTRS 8475' 28'? 289;"8503' 7600' -+330 sks Class G ..~? ~-~ -+180 sks Permafrost C 19. To be completed for Redrill Re-entry, and Deepen Opera'tions. '~ + 60 Bbls Arctic Pak Present well condition summary ./' Total depth: measured feet Plugs (measur"~d) true vertical f e"'e t /feet Junk (measured) ". Effective depth: measured ? true vertical feet \ Casing Length Siz~ Cemented Measured,depth True Vertical depth Structural .~.--'; Conductor ' Surface ...... ~ ~ ~ Intermediate . Production .- Liner _ Perforation depth: measUred.--~ _.-!~$J<'r5 _0il & U~-"-~ (;OHS, . true vertical r ...... · . . 20. Attachments Filing fee;/~ Property plat ~ BOP Sketch ~.. Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Tithe,. v..s.~'t'l~lot~ ~ Refraction analysis ~ Seabed report ,~ 20 AAC 25.050 requirements 21. I hereby certify~ f..ofegoing i.,s/trp,6 and~ccorrect to the best of my knowledge Signe Title M'. " Date ./-~._~2~) Commission Use Only ~:'~'~'--/_5'- 50-- O' 2. '~ - 2/~/~z for other requirements Conditions of approval Samples required l'q Yes ~ No Mud Icg requ'i'red E} Yes /~ No Hydrogen sulfide measures ,.m, Yes /~'No Directional survey required /~Yes F'] No Required working pressure for BOPE ,~2M; ~ 3M; ~ 5M; [] 10M; C, 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT C-20 Conoco, inc. 3201 C Street~ Suite 200 Anchorage, AK 99503 Casing and Cementing Program ao The 13-3/8" conductor will be set at 80' below the. surface then cemented to the surface with ±485 sacks permafrost type "C". B. The 9-5/8" surface casing will be cemented with ±1487 sacks oi Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The first stage will consist of ±330 sacks of Class "G" cement pumped around the casing shoe. The secondarv cement job will consist of ±180 sacks of permafrost type "C" cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. ii. Drilling Fluid Program A. 0-500' 9.0 ppg freshwater spud mud. B. 500'-5000' 9.0 ppg-9.8 PPO freshwater soud mud. C. 5000'-8000' 9.0 ppg-9.5 ppg dispersed. D. 8000'-TD 10.4 ppg dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T>D> will be 10.4 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 test will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is C-13 ~zith I1' of closure at a depth of 3350'. Arctic pack will be placed in the 7" x 9- 5/8" annulus after disposing of test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. B. Co Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. _ ° /4" ' ' Drill a !~-! surface hole to ±4650 TVD (5179 MD) and set 9-5/g" casing. Drill a 8-!/2" production hole to 8498' MD and set 7" casing. TVD 0 5OO 3864 4125 4379 4498 6693 6915 7026 7039 7200 7219 7340 7600 MD FORMATION BIT MUD WT YP PV YIS FL 0 5OO 3951 4217 4478 4613 7362 7640 7779 7795 7997 8020 8172 8498 Gravel !-1-4 9.0 32 20 90 15 Sand/Clay 1-1-4 9.0 25 20 65 !5 "K" Sand. s 1-1-4 9.2 25 15 65 ].4 :~ Sands 1-1-4 9.4 25 15 65 13 "N" Sands 1-1-4 9°4 25 15 65 12 "O" Sands 1-1-4 9.4 25 15 65 12 Sea Bee 1-1-4 I0.2 8 12 40 10 Kup Top 1-1-6 10o2 8 12 35 5 MK 1-1-6 10.2 8 12 35 5 L.K. 1-1-6 10.2 8 12 35 5 L K (I) 1-1-6 10o2 8 12 35 5 L K (2) 1-1-6 10.2 8 12 35 5 B L K 1-1-6 10.4 6 12 35 5 TD 1-1-6 10.4 6 12 35 5 C-20/WP4A 3/88 CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' -CONDUCTOR FILL UP LINE ~( (~ FLOW LINE · I L NCR VALV~ - H CR VALVE ( .~~'"~1 O' RELIEF VALVE BELL NIPPLE 20' &PI ~000 I~1i ANNULAR PREVENTER -- . o DIVERTER QUICK CONNECT ASSEMBLY I · I SAVER 'SUB ASSEMBLY STARTING HEAD I3 3/8" CASING Relief lines from the drilling spool will be rot, ted for downwind diversion. e Hydraulic control system will be in accordance with APl specifications and AOGCC regulations. Both HCR valves will open when the preventer closes, then either one may be closed. BOTE: Depending on rig contracted, the two 6" relief lines may be replaced by a single 10" line with a downstream tee. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (2 fhru 8) ' (8) (9 thru ? 9. (10 and 13) 12. 13. (4) Casg ~.~.~ (14 thru 22) (~) ~OPE ~6f~-4 ~-~-~ (23 thru 28) Company ~ ~.~ ~ C-o), Lease & Well No. /--//~,,V~ /~, YES NO Is the permit fee attached .......................................... ~ -- REMARKS 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 this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. ~--- 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 conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to 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 to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached.~ Does BOPE have sufficient pressure rating - Test to o-~Ooo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER /f~ (29 th~u 31) Aaa: . ffzf Geology: Engineering: · gw/' 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 shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,l Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' ,. No special'effort has been made to chronologically organize this category of information. **** LIS READ **** (NOTE: ** REEL HEADER ** MAXIMUM RECORD LENGTH - 8192 BYTES.)-~ .......................... ~. REEL SEQUENCE # 1 PETROLEUM COMPUTING INC.- LIS FORMAT SERVICE NAME: SSDS DATE: 89/07/11 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 89/07/11 ORIGIN OF DATA: C-20 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** Aric,hoj-a§o ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/11 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# L0G TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRA MWD AAPI 0 0 0 0 1 4 0 1 68 GRB MWD AAPI 0 0 0 0 1 4 0 1 68 GRC MWD AAPI 0 0 0 0 1 4 0 1 68 CNF0 MWD COUN 0 0 0 0 1 4 0 1 68 CNF1 MWD COUN 0 0 0 0 1 4 0 1 68 CNN0 MWD COUN 0 0 0 0 1 4 0 1 68 CNN1 MWD COUN 0 0 0 0 1 4 0 1 68 CNPS MWD P. U. 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 TVD SPERRY FT 0 0 0 0 1 4 0 1 68 NDIS SPERRY FT 0 0 0 0 1 4 0 1 68 EDIS SPERRY FT 0 0 0 0 1 4 0 1 68 DEVI SPERRY DEG 0 0 0 0 1 4 0 1 68 CALI MWD INCH 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 TYPE SIZE REP CODE 4 1 66 0 1 66 ** DATA FORMAT SPECIFICATION ** ~iL. ,~ '~ ?~J,,,:.~ ENTRY BLOCKS ~iaska~ii&GasCons~Comrr~issio~-~ ENTRY DESCRI~]~~ 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRA MWD AAPI 0 0 0 0 1 4 0 1 68 GRB MWD AAPI 0 0 0 0 1 4 0 1 68 GRC MWD AAPI 0 0 0 0 1 4 0 1 68 CNF0 MWD COUN 0 0 0 0 1 4 0 1 68 CNF1 MWD COUN 0 0 0 0 1 4 0 1 68 CNN0 MWD COUN 0 0 0 0 1 4 0 1 68 CNN1 MWD COUN 0 0 0 0 1 4 0 1 68 CNPS MWD P.U. 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 ROP ~4WD FT/H FXE MWD HOUR TVD SPERRY FT NDIS SPERRY FT EDIS SPERRY FT DEVI SPERRY DEG CALI MWD INCH RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 ** 429 DATA RECORDS ** FROM 5000.00 TO ** FILE TRAILER** FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/11 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 89/07/11 ORIGIN OF DATA: C-20 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT 8000.00 FT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 89/07/11 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
