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Home My WebLink About182-194By Grace Christianson at 8:18 am, Jul 21, 2023 Abandoned 6/29/2023 JSB RBDMS JSB 072623 xGMGR08AUG2023DSR-10/25/23 Drilling Manager 07/19/23 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.20 07:55:00 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 7/19/2023 SCHEMATIC Milne Point Unit Well: MPU C-02 Last Completed: 6/3/2023 PTD: 182-194 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 8,869’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TXP 3.958 Surface 8,144’ JEWELRY DETAIL No Depth Item 1 2,740’ 4.5” GLM w/ BK-2 latch (1” Dummy) 2 5,213’ 4.5” GLM w/ BK-2 latch (1” Dummy) 3 6,730’ 4.5” GLM w/ BK-2 latch (1” Dummy) 4 7,663’ 4.5” GLM w/ BK-2 latch (1” Dummy) 5 7,688’ 3.813” X Sliding Sleeve 6 7,748’ 4-1/2” D&L Perm Hyd ISO Packer 7 8,014’ 3.813”ID X Nipple 8 8,107’ Wireline Entry Guide 9 8,317’ 7” Retrievable Packer w/ Screens PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 8,370’ 8,390’ 6,950’ 6,970’ 20’ 7/1985 Closed 8,546’ 8,558’ 7,126’ 7,138’ 12’ 1982 Closed 8,545’ 8,600’ 7,125’ 7,180’ 55’ 1994 Closed 8,566’ 8,596’ 7,146’ 7,176’ 30’ 1982 Closed OPEN HOLE / CEMENT DETAIL 26" 250 sx of Arcticset I (Approx) 17-1/2" 1300 sx Fondu, 750 sx PF C 8-1/2” 800 sx Class G, 300 sx PF C WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56 deg. @ 4,100’ Max Hole Angle through perforations = 2 deg. TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile STIMULATION SUMMARY C-sand: 11/16/94 51M#, 16/20, 8370’ to 8390’ 01/04/97 – A-sand Frac – proplok and scale inhib. 108M#, 16/20, 17#M proplock 01/07/97 – C-sand re-frac, prolok and scale inhib. 49.5M# 16/20 carbolite, 22.9M# proplok TD = 8,900’(MD) / TD =7,480’(TVD) 20” Orig. KB Elev.: 52’ / Orig. GL Elev.= 17’ (Nabors 27E) 7” 2 4 7 8 13-3/8” 1 9 10 Whipstock set @ 8,242’ 6 5 3 Tubing Tail @~8293’ 7” HES Ret Pkr w/ Screens @ 8317’ – 8634’ PBTD = 8,242’ (MD) / PBTD =6,823’(TVD) 6 GENERAL WELL INFO API: 50-029-20866-00-00 Drilled by Nabors 27E– 12/13/1982 Complete w/ ESP – 5/20/1990 Complete w/ GL – 6/2/1990 Complete w/ ESP – 6/26/1990 Complete w/ ESP by Nabors 4ES – 5/18/1995 & 7/13/1996 Complete w/ ESP by Nabors 5S – 6/28/1998 Convert to Injector by Nabors 4ES – 9/23/1999 A Sidetrack CDR – 6/29/2023 ACTIVITYDATE SUMMARY 6/9/2023 T/I/O = 0/0/300 Freeze Protect, Pumped 35 bbls criesel down Tubing, Pumped 45 bbls criesel down IA, FWP = 1550/1600/350 6/11/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 1-11/16" SWIVEL, 2 X ANTI-ROT CENT, DC MOT, BKR #10, BAKER 450-700 WHIPSTOCK (38' OAL, 3.63" MAX OD) WS ORIENTATION=XX ROH, BOTTOM WS SET DEPTH=8,258', CCL OFFSET=31.5', CCL STOP DEPTH=8,226.5' WS TOP=8240' (7" CASING COLLAR AT 8242'), PINCH POINT=8243' TREECAP INTSALLED & PRESSURE TESTED TREE VALVES RETURNED TO NORMAL ***WELL LEFT S/I*** 6/24/2023 *** WELL SHUT-IN ON ARRIVAL.*** SHIFT XD-SS CLOSED AT 7,687' MD W/ 4-1/2" 42BO. PRESSURE UP IA TO 1000psi (Holding). *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** Daily Report of Well Operations PBU MPC-02 WS TOP=8240' Activity Date Ops Summary 6/27/2023 Install jeeps for road travel. Move both modules from MPB Pad to MPC Pad. Rig arrives MPC Pad. Remove jeeps, spot both modules and set down. 6/28/2023 Rig accepted:03:30. Begin MIRU checklists.Continue with RU checklists. Nipple up BOPE and MPD line. Make up test risers. Make up nozzle. Fluid pack rig for BOPE test. Purge air. Leak tight test tiger tank line to 3500#. Grease stack. Perform Initial BOPE test per Hilcorp / AOGCC Witnessed by Sully Sullivan 7-1/16" 5K : Annular, Blind/ Shear, 2-3/8" Pipe/ Slips, Mud X, 3" Pipe/ Slip, 2-3/8" Pipe/ Slip. Remove FVS. Test Gas Alarms (All pass). Test:1 IRV, Stripper, C7, C9, C10, C11 Pass. Test:2 Blind// Shears, R2, BL2, C15 Pass. Install test joint assembly w/ TIW's. Test :3 Annular (2-3/8") , TIW#1, B1, B4 Pass. Test: 4 Upper 2- 3/8" Pipe / Slip, TIW#2, B2, B3 Pass. Test: 5 Lower 2-3/8" Pipe / Slip, C5, C6, C8, TV2. Test: 6 Choke A, Choke C Pass. Test: 7 C1, C2, TV1 Pass. Test:8 3" Pipe / Slip, C2, C1 Pass. Drawdown test. Rig down test equipment. Blow choke down. Swap out test risers to drilling risers, get RKBs. Install spill collector boot around riser and inflate. M/U wt bar to test PDLs. Pressure test PDLs, risers and T2 break, good. Install floats in UQC, PT is good. Open well, 20 psi. Close SV1, SV2, lift injector off. M/U BHA #1 - Window Mill. Mill, reamer 3.80" Go / 3.79" NoGo. Deploy BHA. Pump 15 bbls MeOH to BHA followed by source water returns to tiger tank. With MeOH at EDC, RIH. Slow past sliding sleeve, no indication it opened. Tie-in depth from 7980' correct -14'. RIH to 8222' finish source water swap well to used mud. Bring ECD to 11.5#, 10 - 20 bbl/hr losses at that ECD. Trap pressure, close EDC. 6/29/2023 Light tag 8248' dry. PU go to 2.6 bpm start milling from 8247.8'. 2.51 / 2.44 bpm In / Out. ECD = 11.5# w/ 517 psi WHP, will slowly increase it to 11.8#. 9.09 / 9.11 ppg.Mill 3.80 window in 7 liner per BOT from 8248 MD to 8251.2' MD. Rate: 2.55 bpm in, 2.54 bpm out. mud Weight: 9.02 ppg in, 9.12 ppg out. DWOB: 1.2 to 3.5 klbs. Circ pressure: 3131 psi. Mill 3.80 window in 7 liner per BOT from 8251.2 md. Motor tried to stall at 8252' . Milled off. Rate: 2.80 bpm in, 2.73 bpm out. mud Weight: 9.06 ppg in, 9.07 ppg out. DWOB: 1.2 to 3.5 klbs. Circ pressure: 3645 psi. Mill 3.80 window to 8255'. WOB fell off. Appears we have exited. Time mill to 8257' MD. Rate: 2.81 bpm in, 2.81 bpm out. mud Weight: 9.05 ppg in, 9.07 ppg out. DWOB: 1.0 klbs. Circ pressure: 3611 psi Maintaining 11.8 ppg ECD at window. Mill 3.80 rathole from 8257' MD to 8266' MD. Rate: 2.86 bpm in, 2.79 bpm out. mud Weight: 9.04 ppg in, 9.06 ppg out. DWOB: 2.3 klbs. Circ pressure: 3668 psi Maintaining 11.8 ppg ECD at window. ROP 5 fph. Let mill off. Pump 10 bbls HiVis. Perform reaming passes. 1st up 140 psi MW 8250.8'. 1st down 90 psi MW 8252.1'. 2nd up 105 psi MW 8250.4'. 2nd down 67 psi MW 8251.5'. 3rd up 75 psi MW 8250.2'. 3rd down 50 psi MW 8251.4'. 4th up 75 psi MW 8249.9'. 4th down 40 psi MW 8251.1'. 5th up 70 psi MW 8249.6'. 5 bbls lo/hi vis. Dry drift is clean, tag end of rathole 8266'. Open EDC, chase sweeps OOH 3.5 bpm on slight losses w/ 11/8# at window. Tie-in depth then CCL across jewelry and liner top area. POOH keep 11.8# EDC on well. Tag up and space out. Undeploy BHA #1 keep 11.8# ECD at window. Mill and reamer are 3.80" Go / 3.79" NoGo. Break down and L/D BTT tools. Purge choke and Out MM w/ air. M/U nozzle, jet stack. Deploy BHA #2 - Build BHA. RIH BHA #2. Run past sliding sleeve slowly at HS toolface, opens inadvertently. Tie-in depth from 7970' correct -14.5'. RIH pass window no issues go to min rate tag 8265' PU go to 2.8 bpm. Drill 4.25" build from 8267'. 2.81 / 2.75 bpm in / Out. 9.03 / 9.08 ppg. Window ECD = 11.80 ppg w/ 610 psi WHP. 50-029-20866-01-00API #: Well Name: Field: County/State: MP C-02A Milne Point Hilcorp Energy Company Composite Report , Alaska 6/29/2023Spud Date: Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/18/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230718 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MP F-92 50029229240000 198193 7/11/2023 READ Caliper Survey MPU C-02 50029208660000 182194 7/11/2023 AK E-LINE Whipstock Setting Record PBU W-210 50029233390000 206185 6/28/2023 AK E-LINE IPROF Please include current contact information if different from above. T37855 T37856 T37857 MPU C-02 50029208660000 182194 7/11/2023 AK E-LINE Whipstock Setting Record Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.18 13:24:05 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230713-2 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 14-6y 50133205720000 207149 4/2/2023 HALLIBURTON TMD3D MPU C-02 50029208660000 182194 4/29/2023 YELLOW JACKET JET CUT SRU 213B-15 50133206540000 215130 5/9/2023 YELLOW JACKET GPT/PERF SRU 213B-15 50133206540000 215130 4/24/2023 YELLOW JACKET PLUG SRU 231-33 50133101630100 223008 4/25/2023 YELLOW JACKET PERF/GPT/PLUG Please include current contact information if different from above. T37845 T37846 T37847 T37847 T37848 YELLOWMPU C-02 50029208660000 182194 4/29/2023 JET CUTJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.13 14:54:16 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230712-2 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-02 50029208660000 182194 4/29/2023 YELLOW JACKET JET CUT SRU 213B-15 50133206540000 215130 5/9/2023 YELLOW JACKET GPT/PERF SRU 213B-15 50133206540000 215130 4/24/2023 YELLOW JACKET PLUG SRU 231-33 50133101630100 223008 4/25/2023 YELLOW JACKET PERF/GPT/PLUG Please include current contact information if different from above. T37840 T37841 T37841 T37842 YELLOWMPU C-02 50029208660000 182194 4/29/2023 JET CUTJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.12 16:00:59 -08'00' 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: CTD Sidetrack Prep 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 8,900 feet N/A feet true vertical 7,480 feet N/A feet Effective Depth measured 8,639 feet 7,748 & 8,317 feet true vertical 7,219 feet 6,330 & 6,898 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6/ L-80/ BTC 8,144' 6,725' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6/ L-80/ BT 8,634' 7,214' Packers and SSSV (type, measured and true vertical depth)D&L PERM. HYD. ISO 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 2,670psi 7,020psi 5,380psi 8,160psi8,869' 7,449' Burst N/A 2,650'Surface Production 20" 13-3/8" 7" 80' 2,650' MILNE PT UNIT C-02 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-194 50-029-20866-00-00 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 & ADL0047434 MILNE POINT / KUPARUK RIVER OIL measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 80' Size 80' 2,338' Casing Conductor 8,869' N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 700 01500 0 00 488 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-226 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 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 3:55 pm, Jun 30, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.30 14:12:22 - 08'00' Taylor Wellman (2143) RBDMS JSB 071123 DSR-7/6/23WCB 2-29-2024 _____________________________________________________________________________________ Revised By: TDF 6/29/2023 SCHEMATIC Milne Point Unit Well: MPU C-02 Last Completed: 6/3/2023 PTD: 182-194 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 8,869’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/BTC 3.958 Surface 8,144 4-1/2” Tubing 12.6 / L-80 / IBT 3.958 8,317’ 8,634’ JEWELRY DETAIL No Depth Item 1 2,740’ GLM #4 w/ BK-2 latch (1” Dummy) 2 5,213’ GLM #3 w/ BK-2 latch (1” Dummy) 3 6,730’ GLM #2 w/ BK-2 latch (1” Dummy) 4 7,663’ GLM #1 w/ BK-2 latch (1” Dummy) 5 7,688’ 3.813” ID X Sliding Sleeve 6 7,748’ 7” x 4-1/2” D&L PERM. HYD. ISO Packer 7 8,014’ X Nipple: Min ID = 3.813” 8 8,107’ WLEG: Btm @ 8,144’ 9 8,317’ 7” HES Retrievable Packer w/ Screens 10 8,632’ WLEG; 8,634’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 8,370’ 8,390’ 6,950’ 6,970’ 20’ 7/1985 Open 8,546’ 8,558’ 7,126’ 7,138’ 12’ 1982 Open 8,545’ 8,600’ 7,125’ 7,180’ 55’ 1994 Open 8,566’ 8,596’ 7,146’ 7,176’ 30’ 1982 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 26” Hole 13-3/8" 1300 sx Fondu, 750 sx PF C in 17-1/2” Hole 7” 800 sx Class G, 300 sx PF C in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56 deg. @ 4,100’ Max Hole Angle through perforations = 2 deg. TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile STIMULATION SUMMARY C-sand: 11/16/94 51M#, 16/20, 8370’ to 8390’ 01/04/97 – A-sand Frac – proplok and scale inhib. 108M#, 16/20, 17#M proplock 01/07/97 – C-sand re-frac, prolok and scale inhib. 49.5M# 16/20 carbolite, 22.9M# proplok TD = 8,900’(MD)/ TD = 7,480’(TVD) 20” Orig. KB Elev.:52’ / Orig. GL Elev.= 17’ (Nabors 27E) 7” 2 4 13-3/8” 1 5 3 PBTD = 8,639’ (MD) / PBTD = 7,219’(TVD) 7 6 8 9 10 GENERAL WELL INFO API: 50-029-20866-00-00 Drilled by Nabors 27E– 12/13/1982 Complete w/ ESP – 5/20/1990 Complete w/ GL – 6/2/1990 Complete w/ ESP – 6/26/1990 Complete w/ ESP by Nabors 4ES – 5/18/1995 & 7/13/1996 Complete w/ ESP by Nabors 5S – 6/28/1998 Convert to Injector by Nabors 4ES – 9/23/1999 CTD Sidetrack Prep by ASR - 6/3/2023 Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 E-Line 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 No operations to report. WELL S/I ON ARRIVAL*** ( JOB SCOPE: CUT 3.5'' TUBING W/ 2.5'' OD JET CUTTER). RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH. RIH W/CH/X2 1 11/16'' WB/ 1 11/16'' CCL/ 2.5'' OD JET CUTTER TO CUT TBG @ 7720' CCL TO CUTTER 2.7', CCL STOP. DEPTH 7717.3'. CCL CORRELATE TO CASING TALLY DATED 9/22/99. JOB COMPLETE. WELL S/I ON DEPARTURE. 4/29/2023 - Saturday No operations to report. 5/2/2023 - Tuesday 4/30/2023 - Sunday No operations to report. 5/1/2023 - Monday 4/28/2023 - Friday No operations to report. 4/26/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/27/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 E-Line 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 Accept rig @ 19:00 hrs. Install 3 1/2" test jt. Shell test BOPs, tighten flanges and nuts ram barrels, function Blind rams. Test BOPs to 250 low/ 3500 high for 5 min each with 3-1/2" and 4-1/2" test joints. Perform Koomey draw down test. Blow down lines and R/D test equipment. No operations to report. 5/20/2023 - Saturday T/I/O=1290/508/305 Well Kill for ASR Pumped 15 bbls of 100* diesel followed by 340 bbls 10.3 ppg brine down TBG up IA taking returns to tank. 268 bbls total returned. Freeze protect surface lines with 5 bbls 60/40. Final Whp's=140/20/368. 5/23/2023 - Tuesday 5/21/2023 - Sunday No operations to report. 5/22/2023 - Monday 5/19/2023 - Friday No operations to report. 5/17/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL SHUT-IN ON ARRIVAL. TAG X-NIPPLE AT 1,841' SLM / 1,861' MD W/ 2.84" NO-GO CENT. RAN SBHPS AS PER PROGRAM (Good data). WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 5/18/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 ASR 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 5/26/2023 - Friday Cont. milling on baker S-3 packer. Pump high vis sweep to clear any cuttings. Sweep returning on time w/ minimal cuttings. Shut down pumps, line up to pump reverse while milling. Milling w/ varying pump rates F/ 0 - 2 BPM, Wt on mill F/ 1- 20k dw, 40 -85 RPM, TQ ranging F/ 2 - 4 K ft-lbs. Continue milling w/ varying pump rates F/ 0 - 5 BPM, Max pump pressure 1100 psi, Wt on mill F/ 1- 30k dw, 40 -85 RPM, TQ ranging F/ 2 - 6 K ft-lbs. While milling observed torque response and weight drop off 3 K. P/U string, pull over 38 K F/ previous P/U wt of 82K. Pull up to 120 K and let jars fire in slips X3. Pipe free w/ P/U wt = 82K. Continue milling w/ varying pump rates F/ 0 - 5 BPM, Max pump pressure 1100 psi, Wt on mill F/ 1- 30k dw, 40 -85 RPM, TQ ranging F/ 2 - 6 K ft-lbs. After time torque reducing in oscillation & reducing in peak TQ. Milling "work" minimal. Stop rotation & pump. Tag top of PKR for total footage gain for all milling of 6". P/U wt = 80 K. L/D kelly hose & B/D pump lines. Monitor well, well taking fluid. Static loss rate = 2 BPH. Prep to POOH. POOH w/ burn shoe milling BHA F/ 7,736' T/ 6,261' P/U wt = 60 K. Well taking correct displacement. Service Rig, check equip. oil levels. POOH w/ burn shoe milling BHA F/ 6,261' T/ 176' Well taking correct displacement. 5/24/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Complete BOPE test. Rig down test equipment. Fill pits with 10.3 fluid. Blow down BOPs. P/U T bar and pull CTS plug. Pressure under BPV. IA was on a vac. Decision was made to use lubricator. Disconnect flow lin. R/D spacer spool and flow spool. Torque up spacer spool and 11"X4" adapter on BOPs. P/U and M/U lubricator and tool. Lubricate out BPV, pull BPV above blinds and shut blinds. 280psi on well, IA still on losses. Trouble shoot hydraulic issues. Found bad solenoid. Replaced and function tested equipment. Circulate with charge pump while slowly bleeding gas form tubing. Fluid returning to surface after 27 bbls. Circulated a tubing volume at 1BPM w/ 200 psi. 80 bbls total pumped. Shut down & monitor pressures. Tubing static. Open IA. IA on vacuum. L/D lubricator & N/D shooting flange. N/U riser & flow spools. Attach flow line. P/U & M/U landing JT & engage hanger. R/U kelly hose to TIW. BOLDS. Pull hanger off seat at 48 K. Free P/U wt = 61 K. No drag or overpull. Pull hanger to floor. Inspect hanger condition (good). B/O hanger. L/D landing JT & kely hose. Change out handling equip. to 3-1/2". POOH w/ 3-1/2" Cut, injection completion. F/ 7,720' T/ 6,759' 31 JTS. P/U WT = 52 K. Pump double displacement for pipe pulled. POOH w/ 3-1/2" Cut, injection completion. F/ 6,759' T/ 3,130' P/U WT = 24 K. Pump double displacement for pipe pulled. 5/25/2023 - Thursday Continue POOH w/ 3-1/2 completion from 3,130' T/ surface. Swap handling equipment. Pull tubing from pipe shed. load pipe shed with BHA and drill pipe. Install wear ring. Wear ring ID 6.875". Water pump went out on Rig. Replace water pump and return back to work. P/U & M/U packer milling BHA. 1 burn shoe, 2x wash pipe extensions, 1 joint of wash pipe, 2x boot baskets, jars, and 6x drill collars. RIH w/ PKR milling BHA, F/ 256' T/ 7,622' P/U WT = 82 K, S/O WT = 42 K. Pump 5 BPH to well during trip. Service rig, check equip. oil levels. RIH w/ PKR milling BHA, F/ 7,622' T/ 7,698' P/U WT = 82 K, S/O WT = 42 K. Tag w/ 5 K on top of tubing stub. Tag at 7,698' w/ 5 K on top of tubing stub 2X. Kelly up, rotate over tubing stub w/ 3x turns. Cont. to swallow over tubing to tag out on PKR at 7,736'. Tag on depth with correct calculated swallow. Obtain parameters & line up to pump for milling. Mill S-3 PKR at 84 RPM w/ 3K TQ, & 3 BPM w/ 650 psi. RF= 30% Cont. to mill working up to 8K dw on PKR & 3.5K TQ. Pump high vis sweep. sweep returning on time. Sweep returning small amount of metal. losses while milling at 10 BPH. Cont. to mill w/ vary pump & RPM to increase milling efficiency. Continue POOH w/ 3-1/2 completion from 3,130' T/ surface Mill S-3 PKR at 84 RPM w/ 3K TQ, & 3 BPM w/ 650 psi. RF= 30% Cont. to mill working up to 8K dw on PKR & 3.5K TQ. Pump high vis sweep. sweep returning on time. Sweep returning small amount of metal. losses while milling at 10 BPH. Cont. to mill w/ vary pump & RPM to increase milling efficiency. Cont. milling on baker S-3 packer. Pump high vis sweep to clear any cuttings. Sweep returning on time w/ minimal cuttings Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 ASR 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 Hilcorp Alaska, LLC Weekly Operations Summary L/D BHA. inspect burn shoe. Burn shoe had significant wear. decision was made to swap burn shoes. Clean and clear rig floor. clean and inspect carriage and swivel. P/U & M/U BHA. Burn shoe, 1 joint wash pipe, 2x wash pipe extensions, 2x boot baskets, jars and 6x drill collars. Check fluids on the rig and equipment. RIH with 3-1/2" workstring and burn shoe milling BHA from 256' T/ 7698' P/U WT = 80 K, S/O WT = 42 K. Tag w/ 5 K on top of tubing stub. Displacement for trip = 14 bbls. Total losses for trip = 15bbls. Tag at 7,698' w/ 5 K on top of tubing stub 2X. Kelly up, rotate over tubing stub w/ 3x turns. Cont. to swallow over tubing to tag out on PKR at 7,736'. Tag on depth with correct calculated swallow. Obtain parameters & line up to pump for milling. Mill S-3 PKR w/ vary pump & RPM from 40 - 85 RPM w/ 3 - 6 K TQ, & 1 - 3 BPM w/ 163 psi max. RF= 15%, & dry mill in time intervals to increase milling efficiency. Dry mill W/ 85 RPM 4 - 6 K TQ & 5 - 20K on mill. Losses while milling at 2 BPH. 5/27/2023 - Saturday RIH w/ 3-1/2" workstring and burn shoe milling BHA F/ 6,824' T/ 7,200' P/U WT = 62 K, S/O WT = 36 K. Crew preform a Kick while tripping drill. 2.5 min. Crew preformed AAR of the Drill. Perform derrick inspection. During derrick inspection hand found superficial crack on the weld for the wear plate for carriage rollers. plan on fixing during rig move. will monitor during well. Continue to RIH F/ 7,200' to 7,698'. swivel up and rotate over tubing stump. RIH to 7,736' and tag top of packer. P/U and get parameters. RT wt 64K up, 56K down, 2BPM 190psi. Tag top of packer and mill. Setting 2-3k down and stated getting weight back. Pulled up, came back down and tagged 5' higher, packer is coming up hole. Rotated down past packer setting depth to 7,766'. op of tubing stump 7,728'.Circulate well volume X1. Rig service, check equip. fluid levels. POOH with 3-1/2" workstring and packer milling BHA from 7,766' T/ 219. Well taking correct displacement. L/D BHA, Intensifier, 4x drill collars, Jars, LBS, 1- boot baskets, 2x wash pipe JTS. Tubing stub & packer wegde in burn shoe mill. Tubing tail tail below packer not present. L/D all. Remove BHA f/ shed, mobilize fishing tools from field (spear) Prep shed & handling equipment for BHA. Perform weekly inspections. Rig service, check equip. fluid levels. P/U fishing BHA, SPEAR w/ 2.949" /3.068" grapple, LBS, JAR, 4X - 4 3/4'' DC'S, INTENSIFIER, XO. RIH with 3-1/2" workstring and fishing BHA from 160' T/ 4,764' P/U WT = 38 K, S/O WT = 25 K. Displacement for trip = 3 bbls. Total losses for trip = 14bbls. 5/28/2023 - Sunday Mill S-3 PKR w/ vary pump & RPM from 40 - 85 RPM w/ 3 - 6 K TQ, & 1 - 3 BPM w/ 163 psi max. RF= 15%, & dry mill in time intervals to increase milling efficiency. Dry mill W/ 85 RPM 4 - 6 K TQ & 5 - 20K on mill. Pump a hi vis sweep. Sweep returned on time with minimal cuttings. Losses while milling at 2 BPH. Come down on pumps, break out of swivel and blow lines dry. Prep to POOH. POOH with 3-1/2" workstring and packer milling BHA F/ 7,636' T/ 4,550'. Service rig . Check fluids on all equipment. Continue POOH with 3-1/2" workstring and packer milling BHA from 4,550' to 256'. L/D BHA as per fishing hand. 6 drill collars, jars, 2 boot baskets 1 joint of wash pipe and extensions, and burn shoe. inspect burn shoe. L/D vendor's equipment from floor. P/U new fishing handling equipment & load new milling BHA in Shed. Strap & tally equip. P/U & M/U BHA. Metal muncher burn shoe, 2x wash pipe JTS, 1- boot baskets, LBS, jars and 4x drill collars, intensifier. Service rig . Check fluids on all equipment. RIH w/ 3-1/2" workstring and burn shoe milling BHA F/ 219' T/ 6,824' P/U WT = 62 K, S/O WT = 36 K. Displacement for trip = 14 bbls. Total losses for trip = 11.7bbls. 5/29/2023 - Monday RIH w/ 3-1/2" workstring and burn shoe milling BHA Mill S-3 PKR w/ vary pump & RPM from 40 - 85 RPM w/ 3 - 6 K TQ, & 1 - 3 BPM w/ 163 psi max. RF= 15%, & dry mill in time intervals to increase milling efficiency. Dry mill W/ 85 RPM 4 - 6 K TQ & 5 - 20K on mill. Losses while milling at 2 BPH. POOH with 3-1/2" workstring and packer milling BHA from 7,766' T/ 219. Well taking correct displacement POOH with 3-1/2" workstring and packer milling BHA F/ 7,636' T/ 4,550 Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 ASR 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH with 3-1/2" workstring and fishing BHA from 4,764' to 7,766 P/U WT = 76 K, S/O WT = 45 K. RIH with 3-1/2" workstring and fishing BHA from 7,766' to 8,255' P/U WT = 84K, S/O WT = 48K. tagging top of tubing stump Set 33K down and observed spear going into placing bottom of spear 8,259'. observed overpull. set jars off @135K X5, fish free. P/U WT 85K. L/D 2 joints. Preform derrick inspection after jarring. POOH w/ 3-1/2" workstring and fishing BHA from 8,259' T/ 160'. Well taking correct displacement. L/D Fishing BHA. XO, INTENSIFIER,4X - 4 3/4'' DC'S, JARS, LBS, SPEAR. No Fish, Spear grapple missing. Wear on mandrel of spear indicating entering tubing fish. P/U fishing BHA, Re-bait spear w/ 2.881" / 3.001" grapple, LBS, JAR, 4X - 4 3/4'' DC'S, INTENSIFIER, XO. RIH with 3-1/2" workstring and fishing BHA from 160' T/ 3,762' P/U WT = 38 K, S/O WT = 25 K. Service rig, Check equip. fluid levels. RIH with 3-1/2" workstring and fishing BHA from 3,762' T/ 8,255' P/U WT = 84 K, S/O WT = 48 K. Displacement for trip = 17 bbls. Total losses for trip = 14bbls. Tag top of tubing stump at 8,255'. Set 15K down P/U no overpull line up to wash down to fish. Wash dw at 1.5 BPM w/ 350 psi, Tag top of fish at 8,255'. P/U rotate string for full mule shoe turn. Wash dw to fish set dw 38K. Observed string wt increase. Slack back off setting 38K dw. P/U string P/U wt 85 K. Pump pressure 410 psi at 1.5 BPM. Possible fish on. Tag 3X more. No over pull observed. 5/30/2023 - Tuesday RIH with 3-1/2" workstring and fishing BHA from 7,766' to 8,255' P/U WT = 84K, S/O WT = 48K. tagging top of tubing stump Set 33K down and observed spear going into placing bottom of spear 8,259'. observed overpull. set jars off @135K X5, fish free. Well Name Rig API Number Well Permit Number Start Date End Date MP C-02 ASR 50-029-20866-00-00 182-194 4/29/2023 6/3/2023 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. RIH with 4-1/2" 12.6# L-80 BTC F/ 2,915' T/ 5,820 as per tally. P/U WT = 56 K, S/O WT = 39 K. Losses for trip = 20 bbls. Service rig equip. fluid checks. RIH with 4-1/2" 12.6# L-80 BTC F/ 5,820' T/ 8,033 as per tally. P/U WT = 90 K, S/O WT = 57 K. Losses for trip = 10 bbls. M/U 10 ' space out pup & JT #190. M/U XO pup. P/U landing JT XO hanger to string. Prep hanger. Center stack. P/U wt = 91 K S/O wt = 58 K Land Hanger, wt dropping off during landing on profile, no compression in string. RILDS. Line up to pump dw tubing, taking returns from IA. Pump 25 bbls of 10.4 PPG CI brine, chase w/ 124 bbls of clean 10.4 PPG brine to spot CI on back side around PKR & SS. Drop ball and rod. Allow to travel on seat while, lining up to pump to set PKR & pressure test. Pressure up tubing for MIT & PKR set at 3,800 PSI. Hold for 30 charted mins. (Good test) Bleed tubing dw to 1,100 psi & pressure up IA to 3,600 PSI for MIT. Hold for 30 charted mins. (Good test) Bleed off. R.D test lines. L/D landing JT & P/U dry rod. Install BPV in hanger. Secure floor. L/D dry rod. Remove well equipment f/ rig floor. Remove bails & elevators. Empty pits of brine & transport to L-pad for re-use. Remove mud pump #2 transport trailer. Remove Pipe Shed. Disconnected fire & gas. Rig released at 6/4/23 06:00. 6/3/2023 - Saturday No operations to report. 6/6/2023 - Tuesday 6/4/2023 - Sunday No operations to report. 6/5/2023 - Monday rop ball and rod. Allow to travel on seat while, lining up to pump to set PKR & pressure test. Pressure up tubing for MIT & PKR set at 3,800 PSI. Hold for 30 charted mins. (Good test) RIH with 4-1/2" 12.6# L-80 BTC F/ 2,915' T/ 5,820 as per tally. Land Hanger Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728 MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230525 1531 APPROVAL for Gas Lift MPC-02 (PTD 182-194 _ Sundry 323-226) Completion Change Date:Thursday, May 25, 2023 3:32:22 PM From: Rixse, Melvin G (OGC) Sent: Thursday, May 25, 2023 3:29 PM To: Todd Sidoti <Todd.Sidoti@hilcorp.com> Subject: RE: MPC-02 (PTD 182-194 / Sundry 323-226) Completion Change Todd, This email is sufficient. Thanks. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Thursday, May 25, 2023 12:09 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPC-02 (PTD 182-194 / Sundry 323-226) Completion Change Hi Mel, We are going to run 4 gas lift mandrels in our C-02 well in the case that we are not able to run a jet pump. The only other change to the completion is removal of a downhole gauge as we can not fit the cap string past the mandrels that we have (29# casing). Please see attached and let me know if you need any further information. Thanks, Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. May 21, 2023 5.5.2023 323-269 By Kayla Junke at 1:06 pm, May 05, 2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.05.05 10:35:07 -08'00' Monty M Myers DSR-5/9/23 10-404 24 hour notice to AOGCC to witness BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) approved for alternate plug placement when CTD liner is fully cemented to isolate parent wellbore. MGR22MAY23 SFD 5/5/2023JLC 5/24/2023 GCW 05/24/23 05/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.24 17:49:25 -05'00' RBDMS JSB 052523 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 4, 2023 Re: MPU C-02 Sundry Request Sundry approval is requested to set a whipstock and mill a window in MPU C-02, as part of the pre-rig and drilling/completing of the proposed MPU C-02A CTD lateral. Proposed plan for MPU C-02A Producer: Prior to drilling activities, the well will be worked over to remove the 3-1/2" tubing and the lower 4-1/2" completion. A 4-1/2" tubing string will be installed (see preceding Sundry for RWO) and MIT. Post RWO screening will be conducted to drift for whipstock. E-line will set a 4-1/2"x7" whipstock and coil will mill a 3.80" window + 10' of formation (the rig will set whipstock/mill the window if needed). See MPU C-02A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 3-1/2"x3- 1/4”x2-7/8" L-80 solid liner and cemented. This completion WILL abandon the parent Kuparuk perfs. The well will be perforated post rig (see future perf sundry). This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start end of May 2023): 1. RWO: Pull 3-1/2” tubing and lower 4-1/2” completion and run 4-1/2” tubing. MIT. (see preceding RWO Sundry) 2. Slickline: Dummy WS drift a. Drift past whipstock setting location 3. E-line: Set 4-1/2”x7” whipstock a. Top of whipstock set at 8,430’ MD b. Oriented at 20° LOHS c. Top of window (whipstock pinch point 5’ down from top) at 8,435’ MD 4. Service Coil: Mill Window a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 3,200 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 7” liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference MPU C-02A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 3,200 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Set Whipstock (only if not done pre-rig) 3. Mill Window (only if not done pre-rig) 4. Drill Build and Lateral 5. Run and Cement Liner* 6. Perforate (only if not done post-rig) 7. Freeze Protect and RDMO 8. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Sundry 323-269 pp p completion WILL abandon the parent Kuparuk perfs. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x MPU C-pad is an H2S pad. MPU C-pad is not considered a high H2S pad. o The highest recorded H2S well on the pad was from MPU C-14 (19.8ppm) in 2009. o No recorded H2S on C-02. Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,900 psi at 7,000’ TVD (10.72 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 3,200 psi (from estimated reservoir pressure). x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 MPU C-pad is an H2S pad. M Coiled Tubing BOPs Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips _____________________________________________________________________________________ Revised By: TDF 4/14/2023 PROPOSED Milne Point Unit Well: MPU C-02 Last Completed: 9/23/1999 PTD: 182-194 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 8,869’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TXP 3.958 Surface ±8,335 JEWELRY DETAIL No Depth Item 1 ±8,024’ 3.813” X Sliding Sleeve 2 ±8,084’ Gauge Mandrel 3 ±8,144’ 7” x 4-1/2” Packer 4 ±8,210’ 3.813” X Nipple 5 ±8,300 Wireline entry guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 8,370’ 8,390’ 6,950’ 6,970’ 20’ 7/1985 Open 8,546’ 8,558’ 7,126’ 7,138’ 12’ 1982 Open 8,545’ 8,600’ 7,125’ 7,180’ 55’ 1994 Open 8,566’ 8,596’ 7,146’ 7,176’ 30’ 1982 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 26” Hole 13-3/8" 1300 sx Fondu, 750 sx PF C in 17-1/2” Hole 7” 800 sx Class G, 300 sx PF C in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56 deg. @ 4,100’ Max Hole Angle through perforations = 2 deg. TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile STIMULATION SUMMARY C-sand: 11/16/94 51M#, 16/20, 8370’ to 8390’ 01/04/97 – A-sand Frac – proplok and scale inhib. 108M#, 16/20, 17#M proplock 01/07/97 – C-sand re-frac, prolok and scale inhib. 49.5M# 16/20 carbolite, 22.9M# proplok TD = 8,900’(MD) / TD = 7,480’(TVD) 20” Orig. KB Elev.: 52’ / Orig. GL Elev.= 17’ (Nabors 27E) 7” 2 4 13-3/8” 1 5 3 PBTD = 8,639’ (MD) / PBTD = 7,219’(TVD) GENERAL WELL INFO API: 50-029-20866-00-00 Drilled by Nabors 27E– 12/13/1982 Complete w/ ESP – 5/20/1990 Complete w/ GL – 6/2/1990 Complete w/ ESP – 6/26/1990 Complete w/ ESP by Nabors 4ES – 5/18/1995 & 7/13/1996 Complete w/ ESP by Nabors 5S – 6/28/1998 Convert to Injector by Nabors 4ES – 9/23/1999 _____________________________________________________________________________________ Revised By: JNL 5/3/2023 PROPOSED Milne Point Unit Well: MPU C-02 Last Completed: 9/23/1999 PTD: 182-194 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 8,869’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TXP 3.958 Surface ±8,300 JEWELRY DETAIL No Depth Item 1 ±8,024’ 3.813” X Sliding Sleeve 2 ±8,084’ Gauge Mandrel 3 ±8,144’ 7” x 4-1/2” Packer 4 ±8,210’ 3.813” X Nipple 5 ±8,300 Wireline entry guide 6 8,430’ Whipstock PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 8,370’ 8,390’ 6,950’ 6,970’ 20’ 7/1985 Open 8,546’ 8,558’ 7,126’ 7,138’ 12’ 1982 Open 8,545’ 8,600’ 7,125’ 7,180’ 55’ 1994 Open 8,566’ 8,596’ 7,146’ 7,176’ 30’ 1982 Open OPEN HOLE / CEMENT DETAIL 26" 250 sx of Arcticset I (Approx) 17-1/2" 1300 sx Fondu, 750 sx PF C 8-1/2” 800 sx Class G, 300 sx PF C WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56 deg. @ 4,100’ Max Hole Angle through perforations = 2 deg. TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile STIMULATION SUMMARY C-sand: 11/16/94 51M#, 16/20, 8370’ to 8390’ 01/04/97 – A-sand Frac – proplok and scale inhib. 108M#, 16/20, 17#M proplock 01/07/97 – C-sand re-frac, prolok and scale inhib. 49.5M# 16/20 carbolite, 22.9M# proplok TD = 8,900’ (MD) / TD = 7,480’(TVD) 20” Orig. KB Elev.: 52’ / Orig. GL Elev.= 17’ (Nabors 27E) 7” 2 4 13-3/8” 1 Whipstock set @ 8,430’ 5 3 PBTD = 8,639’ (MD) / PBTD = 7,219’(TVD) 6 GENERAL WELL INFO API: 50-029-20866-00-00 Drilled by Nabors 27E– 12/13/1982 Complete w/ ESP – 5/20/1990 Complete w/ GL – 6/2/1990 Complete w/ ESP – 6/26/1990 Complete w/ ESP by Nabors 4ES – 5/18/1995 & 7/13/1996 Complete w/ ESP by Nabors 5S – 6/28/1998 Convert to Injector by Nabors 4ES – 9/23/1999 _____________________________________________________________________________________ Revised By: JNL 5/3/2023 PROPOSED Milne Point Unit Well: MPU C-02A Last Completed: TBD PTD: TBD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 8,435’ 3-1/2” Liner 9.3 / L-80 / STL 2.992 8,270’ 8,425’ 3-1/4” Liner 6.6 / L-80 / TCII 2.805 8,425’ 8,800’ 2-7/8” Liner 6.5 / L-80 / Hyd 511 2.441 8,800’ 11,265’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TXP 3.958 Surface ±8,300 JEWELRY DETAIL No Depth Item 1 ±8,024’ 3.813” X Sliding Sleeve 2 ±8,084’ Gauge Mandrel 3 ±8,144’ 7” x 4-1/2” Packer 4 ±8,210’ 3.813” X Nipple 5 ±8,300 Wireline entry guide 6 8,430’ Whipstock 7 8,425’ 3-1/2” xo 3-1/4” 8 8,800’ 3-1/4” xo 2-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands OPEN HOLE / CEMENT DETAIL 26" 250 sx of Arcticset I (Approx) 17-1/2" 1300 sx Fondu, 750 sx PF C 8-1/2” 800 sx Class G, 300 sx PF C 4-1/4” 181 sx Class G WELL INCLINATION DETAIL KOP @ 8,435’ 90 deg Angle = 8,685’ TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile TD = 11,265’ (MD) / TD = 7,120’(TVD) 20” Orig. KB Elev.: 52’ / Orig. GL Elev.= 17’ 7” 2 4 13-3/8” 1 Whipstock set @ 8,430’ Top of Window @8,435’3-1/4” xo 2-7/8” 8,800’ 2-7/8” 8 7 5 3 Top of Cement / Liner @ 8,270’ 3-1/2” xo 3-1/4” 8,425’ PBTD = 11,245’ (MD) / PBTD = 7,120’(TVD) 6 GENERAL WELL INFO API: 50-029-20866-01-00 Drilled by Nabors 27E– 12/13/1982 A Sidetrack: 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTD Sidetrack Prep 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,900'N/A Casing Collapse Conductor N/A Surface 2,670psi Production 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13-3/8" 7" 2,650' 8,869' Perforation Depth MD (ft): MD N/A 5,380psi 8,160psi 2,338' 7,449' 2,650' 8,869' Length Size Proposed Pools: 80' 80' TVD Burst PRESENT WELL CONDITION SUMMARY 7,480' 8,639' 7,219' 3,367 N/A 80' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 182-194 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-20866-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL C.O. 432E MILNE PT UNIT C-02 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2# / L-80 / BTS 7,782' 5/4/2023 7" Baker S-3 & 7" HES Retrievable and N/A 7,758 MD/ 6,340 TVD & 8,317 MD/ 6,898 TVD and N/A See Schematic See Schematic 3.5" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.14 11:56:48 -08'00' David Haakinson (3533) * BOPE test to 3500 psi. Annular to 2500 psi. 3 ram stack required for MPSP> 3000 psi. * Reservoir pressure > 8.55 ppg equivalent mud weight. *Not approved to POP with jet pump. & ADL0047433 10-404 MDG 4/20/2023 DSR-4/14/23 3367 MGR28APR2023JLC 4/28/2023 04/28/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.28 11:40:50 -08'00' Well: MPC-02 PTD: 182-194 API: 50-029-20866-00-00 Well Name:MPC-02 API Number:50-029-20866-00-00 Current Status:WAG Injector Rig:ASR Estimated Start Date:5/4/2023 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:182-194 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 4,081 psi @ 7,138’ TVD Surface Inj Pressure |11.0 PPGE Maximum Expected BHP: 4,081 psi Max Potential Surface Pressure: 3,367 psi Gas Column Gradient (0.1 psi/ft) Max Angle:52° @ 4,900’ MD Brief Well Summary: Well MPC-02 was drilled and completed across the Kuparuk A sand in December of 1982. In 1984 a recompletion opened up the C-sand. The C-sand was frac’d in 1994 and the A-sand was frac’d in 1998 along with a re-frac of the C-sand. The well was believed to be completed in a fault causing severe sand and proppant production issues. A screen was set across the perforations in June of 1998 rendering the well ineffective as a producer. The well was converted to injection after the screens were set in September of 1999. A CTD sidetrack out of MPC-02 is planned to improve the economic viability and convert it to a production well. Objectives: 1. Cut and pull 3-1/2” tubing 2. Retrieve Baker S-3 Permanent Packer 3. Run tubing and a production packer setting up the well for a CTD sidetrack. Notes Regarding Wellbore Condition: MIT-IA on 9/21/2019 to 2,400 psi. The 7” HES packer and 4.5” Proplus screens will be left in the well. Well has been on lean gas injection. Planned to WAG to water 4/14/2023 to push gas away from wellbore. Pre-Rig Procedure (No Sundry Required) Slickline 1. MIRU SL, PT PCE to 250 psi low / 3,500 psi high 2. RIH to 8,546 MD (7,126' TVD) or deep as possible for 30 minute station stop 3. Pull up hole 200' TVD for 15 minute gradient stop. 4. Confirm good data. 5. Run memory caliper to WLEG at 7,782’ MD. 6. RIH with tubing hole punch 7. Tag X- nipple at 7713’ MD. 8. Punch hole in first full joint above X-nipple. 9. RDMO. E-Line (Approved Sundry Required) 1. MIRU EL, PT PCE to 250 psi low / 3,500 psi high 2. RIH with jet cutter A CTD sidetrack out of MPC-02 is planned to improve the economic viability and convert it to a production well. Well: MPC-02 PTD: 182-194 API: 50-029-20866-00-00 3. Cut 5’ below collar on first full joint of 3.5” 9.2# L-80 NSCT above the packer. Estimated cut depth ~7720’ RKB. 4. RDMO Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 11.2 ppg brine down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 11.2 ppg brine prior to setting CTS. 3. Test BOPE to 250 psi low/ 3,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. MU landing joint or spear, BOLDS, PU on the tubing hanger. 6. Confirm hanger free, lay down tubing hanger. 7. POOH and lay down the 3-1/2” tubing. Number all joints. a. Pre-rig caliper to inform on whether to keep 3-1/2” tubing. b. Note any sand or scale inside or on the outside of the tubing on the morning report. c. Fill with 2x displacement while pulling tubing. 8. PU burn over shoe and sufficient wash pipe to mill and free the S-3 packer located at 7,758’ MD a. Milling BHA to be finalized with fishing company and OE. b. Packer will need to be fished out of the well. 9. RIH with burn over shoe on 3-1/2” workstring. 10. Before milling, establish milling parameters. mgrIf indications show pressure underneath BPV, lubricate out BPV. Well: MPC-02 PTD: 182-194 API: 50-029-20866-00-00 a. Build high viscosity fluid to carry cuttings out of the well. b. Maintain sufficient pump rate to prevent depositing debris on top of BHA. 11. Mill Baker S-3 until confirmed free. 12. Once packer is free, close annular and circulate conventionally (down tubing, up annulus) out at least one well volume to remove packer gas from the well. 13. POOH with fishing assembly while filling hole with 2x pipe displacement. 14. RIH with fishing BHA and spear the 3-1/2” tubing stub. 15. POOH with packer fish, while filling hole with 2x pipe displacement. 16. RIH with Halliburton 7” packer retrieval tool. (plan to mill and spear if tool not available) 17. HAL tool hand to advise on retrieving packer. 18. POOH with packer. 19. If packer does not release, do not exceed 90% of string rating. Move forward with setting completion above the packer. Consult with OE prior to setting packer up hole. a. Screen liner will be cemented post-RWO. 20. RIH with new 4-1/2”, 12.6# L-80 completion to +/- 8,300’ and obtain string weights. a. Note PU and SO weights on tally. b. Photograph packer prior to running Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 4-1/2” WLEG L-80 Place at ±8,300’ md. Planned window 8,435’. 4.5''2 Joints 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 4.5''X Nipple 12.6 L-80 RHC Profile Installed 4.5''10'Pup Joint 12.6 L-80 4.5'' 1 joint 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 7'' 7” x 4-1/2” Packer 12.6 L-80 ~8,144’ MD 4.5''10'Pup Joint 12.6 L-80 4.5'' 1 joint 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 Gauge 4.5''10'Pup Joint 12.6 L-80 4.5'' 1 joint 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 4.5''3.813” X Sliding Sleeve 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 Well: MPC-02 PTD: 182-194 API: 50-029-20866-00-00 4.5''Joints 12.6 L-80 4.5''Space out PUPS 12.6 L-80 4.5'' 1 joint 12.6 L-80 4.5''Tubing Hanger 12.6 L-80 21. Space out and land hanger. RILDS. 22. Spot corrosion inhibited brine in the sump between the packer and the sliding sleeve. a. Surface to sliding sleeve annular volume: 141 bbls b. Sliding Sleeve to Packer annular volume: 2 bbls c. Surface to 2,100’ for Annular Freeze Protect: 39 bbls 23. Drop ball and rod. Complete loading FP and hydraulically set the packer per the manufacturer's setting procedure. 24. Pressure up and test the tubing to 3,000 psi for MIT-T with positive pressure on the IA. Bleed off the tubing to 1,000psi. Test the IA to 3,600 psi for MIT-IA. Record all pressure tests (30 minutes) on chart. 25. Lay down landing joint. 26. Set BPV. 27. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic DATE REV. BY COMMENTS ORIG.KB.ELEV = 52'(Nabors 27E) ORIG.GL.ELEV = 17'(Nabors 27E) TREE: 4-1/16" - 5M MCEVOY WELLHEAD:11" 5M FMC w/ 4-1/16" FMC Tubing Hanger NSCT 4" CIW H BPV PROFILE MILNE POINT UNIT WELL C-02i API NO: 50-029-20866 13 3/8" 72 ppf L-80 BTS HILCORP ALASKA LLC 7" 29#, L-80, BTRS 2650' 8639' 8869' 20" 94 ppf Grade B 115' 12/82 DBR DRILLED 5" 12DP 8370' - 8390' (6950' - 6970') 33/8" 6BH " " " 5" 12DP 8546' - 8558' (7126' - 7138') 3 3/8" 6 BH 8545' - 8600' (7125' - 7180') 5" 12DP 8566' - 8596' (7146' - 7176') SIZE SPF INTERVAL PERFORATION SUMMARY REF LOG: 7/12/82 DIL SFL (TVD) Stimulation Summary: Frac - 11/16/94, 51 M# 16/20 mesh, "C" Sand 8370' to 8390' 05/17/95 JBF ESP RWO / MPU C-02i 07/13/96M.Linder ESP RWO PBTD KOP @ 500' Max. hole angle 56 deg. @ 4100’ Angle through perfs. 2 deg. 7" 29 ppf, L-80, Btrc. production casing (driftID=6.151",cap.=0.0371bpf) 3.5" 9.2 ppf, L-80, NSCT tbg.. ( drift ID = 2.441", cap. = 0.0087 bpf ) 01/04/97 “A” sands Frac proplok & scale inhib. treatment. 108 M# 16/20 carbolite 17 M# of which was proplok. 01/07/97 “C” sands re-frac proplok & scale inhib. treatment. 49.5 M# 16/20 carbolite 22.9 M# of which was proplok. 7” HES Retrieveable pkr. w/screens. 4.5” Proplus screens 4.5” Spacer pipe 4.5” Proplus screens 4.5” Tail pipe 8317’ 8634’ 07/01/98 MDO Added scabscreens & ESP Completion 5-s 3.5” X Nipple (HES) (2.81”ID) 3.5” X Nipple (HES) (2.81”ID) 3.5” XN Nipple (HES) (2.81”ID w 2.75” No-go) 7” Baker S-3 packer w/ 3.875” ID. WLEG 09/22/99 M.Linder Conversion to injector 4-ES 7714’ 7758’ 7770’ 7782’ 1861’ _____________________________________________________________________________________ Revised By: TDF 4/14/2023 PROPOSED Milne Point Unit Well: MPU C-02A Last Completed: 9/23/1999 PTD: 182-194 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / Grade B / N/A N/A Surface 115' 13-3/8" Surface 72 / L-80 / BTS 12.347 Surface 2,650’ 7" Production 29 / L-80 / BTRS 6.184 Surface 12,717’ TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TXP 3.958 Surface ±8,335 JEWELRY DETAIL No Depth Item 1 ±8,024’ 3.813” X Sliding Sleeve 2 ±8,084’ Gauge Mandrel 3 ±8,144’ 7” x 4-1/2” Packer 4 ±8,210’ 3.813” X Nipple 5 ±8,300 Wireline entry guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 8,370’ 8,390’ 6,950’ 6,970’ 20’ 7/1985 Open 8,546’ 8,558’ 7,126’ 7,138’ 12’ 1982 Open 8,545’ 8,600’ 7,125’ 7,180’ 55’ 1994 Open 8,566’ 8,596’ 7,146’ 7,176’ 30’ 1982 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 2,199 sx PF “E”, 550 sx Class “G” in 12-1/4” Hole 7” 275 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56 deg. @ 4,100’ Max Hole Angle through perforations = 2 deg. TREE & WELLHEAD Tree 5M McEvoy 4-1/16” Wellhead 11” 5M FMC w/ 4-1/16” FMC Tubing Hanger NSCT 4” CIW H BPV Profile STIMULATION SUMMARY C-sand: 11/16/94 51M#, 16/20, 8370’ to 8390’ 01/04/97 – A-sand Frac – proplok and scale inhib. 108M#, 16/20, 17#M proplock 01/07/97 – C-sand re-frac, prolok and scale inhib. 49.5M# 16/20 carbolite, 22.9M# proplok TD =8639’(MD) / TD =’(TVD) 20” Orig. KB Elev.:52’/ Orig. GL Elev.= 17’ (Nabors 27E) 7” 2 4 9-5/8” 1 5 3 PBTD =8869’ (MD) / PBTD =’(TVD) 6 7 GENERAL WELL INFO API: 50-029-20866-00-00 Drilled by Nabors 27E– 12/13/1982 Complete w/ ESP – 5/20/1990 Complete w/ GL – 6/2/1990 Complete w/ ESP – 6/26/1990 Complete w/ ESP by Nabors 4ES – 5/18/1995 & 7/13/1996 Complete w/ ESP by Nabors 5S – 6/28/1998 Convert to Injector by Nabors 4ES – 9/23/1999 Updated 6/21/18 11” BOPE 11'-5000 11" - 5000 2-7/8" x 5" VBR Blin d 11'- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManualManualManual Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 5/24/2022 2-3/8" Pipe Ram MEMORANDUM State of Alaska Permit Number: 182"194-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg �(��4�(cl 2 DATE: Monday, September 23, 2019 P.I. Supervisor (� SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial Hilcorp Alaska LLC Well C-02 FROM: Guy Cook MILNE PT UNIT C-02 Petroleum Inspector Tubing 1760 Ste: Inspector 1758 " Reviewed By: -- , �tVr`— P.I. Supry —IFR— PTD NON-CONFIDENTIAL NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT C-02 API Well Number 50-029-20866-00-00 Inspector Name: Guy Cook Permit Number: 182"194-0 Inspection Date: 9/21/2019 Insp Num: mitGDC190921155355 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-02 Fype Inj 11 w TVD 6340 Tubing 1760 1762 1758 " 1756 -- PTD F 1821940--lType Test SPT Test psi 1585 IA 650 2419 - 2382 2380 ' BBL Pumped: Pumped: I 1.3 " BBL Returned: 1.4 OA 569 - sz3 - s7z ' sz3 ' Interval 4vRTST P/F P Notes: Testing completed with a Little Red Services pump truck and calibrated gauges. Monday, September 23, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,October 09,2015 TO: Jim Reggr P.I.Supervisor ` ,? t I CD 1 I S SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-02 FROM: Jeff Jones MILNE PT UNIT KR C-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .T> — NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-02 API Well Number 50-029-20866-00-00 Inspector Name: Jeff Jones Permit Number: 182-194-0 Inspection Date: 9/29/2015 Insp Num: mitJJ151005104831 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-02 = Type Inj W-TVD 6340 - Tubing 1182 - 1185 • 1185 . 1186 . PTD i _ 1821940 " Type Test SPT Test psi 1585 - IA 103 2041 - 2014 - 2003 - Intervall4vRTST P/F P OA 519 - 520 • 521 523 , 1 Notes: 1 well inspected,no exceptions noted. SCANNED t - Friday,October 09,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 04, 2011 TO: Jim Regg (? P.I. Supervisor ' �6 I �j SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C -02 FROM: Bob Noble MILNE PT UNIT KR C -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J�P -- NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR C - 02 API Well Number: 50 029 - 20866 - 00 - 00 Inspector Name: Bob Noble - Insp Num: mitRCN111003061627 Permit Number: 182 - 194 - Inspection Date: 10/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-02 - 1 Type Inj. W ' TVD 6340 - IA 575 2030 - 2010 2010 - P,T'.D 1821940 - TypeTest SPT Test psi 1585 . OA 230 330 330 330 Interval 4YRTST p/F P - Tubing 2673 2673 2674 2674 Notes: Tuesday, October 04, 2011 Page 1 of 1 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ gright Water Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ PerForate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~ Exploratory ~~ 182-1940 / 3. Address: P.O. Box 196612 StPBtlgfBphlC ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20866-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 52 KB MPC-02 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-047434 ~ MILNE POINT Field/ KUPARUK~I~'Et~, ~NC~a~~Ziil~ % 11. Present Well Condition Summary: ;: : /v ,;:~~ ~ ~ ` Total Depth measured ~869 feet (~/~ Plugs (measured) None ~ , true vertical 7 feet 9/' ( Junk (measured) Nor-~, :-_.? :. Effective Depth measured 8639 feet true verticai 7219 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" 94# H-40 Surface - 115 Surface - 115 1530 470 SURFACE 2615' 13-3/8" 72# L-80 Surface - 2650 Surface - 2338 4930 2670 PRODUCTION 8834' 7" 29# L80 Surface - 8869 Surface - 7449 8160 7020 7 ~ ~J .~~. ~E~~4`v~~. Perforation depth: Measured depth: SEE ATTACHED - _ _ "` - ! _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 SURFACE - 7782' 0 0 - qy,~ Packers and SSSV (type and measured depth) 7"x3-1/2" S-3 BAKER PACKER 7758' ~-~---~ ~'~ ~ 7"X3-1/2" HES RETRIEVABLE PACKER 8317' W/SCREENS TO 8634' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1028 1604 Subsequent to operation: 1048 1589 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~"'" Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas 1~ WAG ~: GINJ r WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre e Title Data Management Engineer Signature Phone 564-4944 Date 9/10/2009 Form 10-404 R~vised 04/2006 ~~~'~~ ~~'~ _~a~; ~ ~ ~~~1~ ~SubmitOriginal Onl ~"`kt > ~~~Y~~ M PC-02 182-194 PERF ATTACHMENT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-02 7/24/85 PER 8,370. 8,390. 6,950.66 6,970.65 MPC-02 7/24/85 PER 8,546. 8,558. 7,126.5 7,138.49 MPC-02 7/24/85 PER 8,566. 8,596. 7,146.49 7,176.47 MPC-02 7/25/85 PER 8,545. 8,600. 7,125.5 7,180.46 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ ~ MPC-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/24/09 - 8/9/09 ~Bright Water pump operations. Began EC9360A (surfactant) pre-flush injection ~on 7/21/09 with a water injection rate of 1068 BWPD and injection pressure of ~ 1788 psi. Began EC9378A (polymer) injection on 07/24/09 with a water injection rate 925 BWPD and injection pressure of 1712 psi. Finished pumping EC9378A ~ 08/08/09 with a water injection rate of 1028 BW PD and injection pressure of 1604 ~ psi. Finished pumping EC9360A on 08/09/2009 with a water injection rate of =1048 BWPD and injection pressure of 1589 psi. Total EC9378A injection volume ~ 11943 gallons. Total EC9360A injection volume 3900 gallons. i ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 08, 2007 To: Jim Regg '°~7 ~~~~~ ~lr~~lt~~(7 ~ SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC C-02 FROM: LOU CYTlm31C11 N(ILNE PT UNIT KR C-02 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv '-.1~~ Comm MILNE PT CINIT KR C-02 API Well Number: 50-029-20866-00-00 Well Name: Inspector Name:. Lou Grima{di mitLG07 100 5 1 2 3004 Permit Number 182-194-0 Insp Num: Ioi5~2oo7 Inspection Date: Rel Insp Num: ~;34C Packer De th Pretest Initial P 15 Min. 30 Min. 45 Min. 60 Nlin. - ~ ~---~ Well ~, C-02 ~~TYPe Inj. ~ ~' ~ TVD ~ i iA ~ ~ I9s I9zo ~ I9oo !~ I~oo ~ P.7+. ~ 1821940 ~TypeTest ~ SPT'~ Test pSl ~~ 1920 ~ QA~ 320 320 ~'~ 330 ~ 330 , Interval P~F ,~ Tubin ~ 2440 2440 I 4YRTST P g _~ 2440 ' 2440 - - - NOteS: Observed pretest conditions for 15 minutes, "OK"..7 Bbl's pumped. ~+cic~,- t V`~~ Cc~F~~'~-~~es (34e rt ~ ~ j y~~p~~ r+~ ' - '^ t7j1 .3~"'~C V (~~~~p`y~/p~q) !(~;~)p ~~pA }j~~ !/~]n~]^'~/j O Ul:3~W.+' ~V T M V 4VV0 /1 ~J~ y //n, .{.., ( ; S r..l~~ `..T ;.J-ll~~~~• `1 V V±WI V~~TL `v~F1~ ' \ L~ J ~ ` V ~'L~~C C~.i "..Gizcv~ ~Zv^a2 ~ -gvli-~ C'tis.-!r'tJ Z~ z7~ Z%=~~ Z ~ti~ .. ~,+.au~.+e.I4.,.~a. ,:... Page I of 1 Monday, October 08, 2007 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim~Regg. P.I. ~uperv~sor DATE: October 14, 2003 ('~'' ~10-5 s u BJ EcT:~c'I BPxMechanical Integrity Test MPU C Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL P.T.D.I 182-194 Packer Depth Pretest Initial 15 Min. 30 Min. I I I I I I I Type testI P I Testpsil 1585 I CasingI 0 I 2500 I 2450 I 2450 I Notes: I P'T'D' I I Notes: P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: C-08 185-014 C-28 196-029 TypetestI, P ITestpsil 1660 I Casingl 0 I 24401 24201 2410l P/F I -P I I I Type,nj.I G I T.V.D. 16779 I T,bing13600 I 36OO 13600 13600 I,.~,~,1 4I I Type testI P I Testpsil 1695 I CasingI 0 I 25001 24001 24001 P/F I PI IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU C Pad and witnessed the routine 4 year MIT on well C-02, C-08 and C-28. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: _3 Number of Failures: 0 Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. 2003-1014 MIT MPU C-28 cs.xls 10/23/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X WAG SWAP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 52 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Miline Point Unit 4. Location of well at surface 4051' FNL, 2458' FEL, Sec. 10, T13N, R10E, UM (asp's558000, 6029509) MPC-02 At top of productive interval 9. Permit number / approval number 4020' FNL, 3856' FEL, Sec. 11, T13N, R10E, UM (asp's561881, 6029571) 182-194~(,~ At effective depth 10. APl number 4029' FNL, 3850' FEL, Sec. 11, T13N, R10E, UM (asp's 561888, 6029562) 50-029-20866-00 At total depth 11. Field / Pool 4036' FNL, 3847' FEL, Sec. 11, T13N, R10E, UM (asp's 561891, 6029555) Miline Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 8869 feet Plugs (measured) true vertical 7449 feet Effective depth: measured 8639 feet Junk (measured) true vertical 7219 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" To Surface 115' 115' Surface 2615' 13-3/8" 750 sx Permafrost 'C' 2650' 2338' Production 8834' 7" 800 sx Class 'G' 8869' 7449' Perforation depth: measured Open Perfs 8370' - 8390', 8546' - 8558', 8545' - 8600', 8566' - 8596' truevertical Open Perfs 6950'-6970', 7126'-7138', 7125'-7180', '" '- RECEIVED Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 NSCT to 7782' MD. ~[-'_B 2~ ~/ ~t~? Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker Packer @ 7758', 7" x 3-1/2" HES Retrieveable Packer @ 8317' w/Screens to 8634'._ . ^.,,, NiiS~. GasCons. C0mmissi0n 13. Stimulation or cement squeeze summary ~' ........ ~- Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mc! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/20/2002 832 2059 Subsequent to operation 02/26/2002 1837 3506 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,~"~/'~4:,,~'~~'--~---/~ ',~'C/'~¢7~ Title: TechnicalAssistant Date February27, 2002 DeWayne R. Schnorr-- ~"'- Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE~ MPC-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/25/2002 WAG SWAP FROM WATER TO GAS INJECTION EVENT SUMMARY O2/25/O2 PJSM. MIRU HB&R. PT'd TO 4000 PSI. PUMPED 22 BBLS METHANOL DOWN THE TUBING AT 1.75 BPM, 3300 PSI & 1 BBL METHANOL DOWN THE FLOW LINE TO FREEZE PROTECT. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUED TO SPEC. AND PT'd FLANGES. FLUIDS PUMPED BBLS DISCRIPTION 23 METHANOL 23 TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~"///~/'"~c.~ Blair Wondzell, P. I. Supervisor . FROM: Jeff JoneS' ~c/--Petroleum I SUBJECT: DATE: July 12, 2000 Safety Valve Tests 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. ~ ~.~. £~---~->~- 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 7-12-00 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: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE C-01 ::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 ~t842430 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 _11951980 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 ~~~ 1821940 4000 1900 P P WAG , ,, C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%~] o0 oar Remarks: 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. o/,Trna Paae 1 of 1 V 1 v7irqm.xls ~ STATE OF ALASKA '-~- ALASKa. ~L AND GAS CONSERVATION CG,.,,vllSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging i--] Perforate [] Pull Tubing []Alter Casing I--I Repair Well [] Other Convert to Injector Type of well: 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 5. [~ Development [] Exploratory [] Stratigraphic [~Service 4. Location of well at surface 1229' NSL, 2459' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 1259' NSL, 1423' EVVL, SEC. 11, T13N, R10E, UM At effective depth 1250' NSL, 1429' EWL, SEC. 11, T13N, R10E, UM At total depth 1243' NSL, 1432' EWL, SEC. 11, T13N, R10E, UM 8. Well Number MPC-02 9. Permit Number / Approval No. 82-194 399-140 10. APl Number 50-029-20866 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8869 feet true vertical 7449 feet Effective depth: measured 8639 feet true vertical 7219 feet Casing Plugs (measured) Junk (measured) Length Size Cemented M D TVD Structural Conductor 80' 20" To Surface 115' 115' Surface 2615' 13-3/8" 750 sx Permafrost 'C' 2650' 2338' Intermediate Production 8834' 7" 800 sx Class 'G' 8869' 7449' Liner Perforation depth: measured 8370' - 8390', 8546' - 8558', 8545' - 8600', 8566' - 8596' true vertical (subsea) 6899' - 6919', 7074' - 7086', 7073' - 7128', 7094' - 7124' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, NSCT to 7782' Packers and SSSV (type and measured depth) Baker 'S-3' Packer at 7758'; 7" HES Retrievable Packer at 8317' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Naska Oil & Gas Cons. [;ommis Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I r-] Oil I-I Gas I~ Suspended [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Terrie Hubble Title Technical Assistant III Prepared By Name/Number: Service Water & Gas Injector Date I (~ "" (~ ~?? Submit In Duplicate Form 10-404 Rev. 06/15/88 Facility Date/Time 20 Sep 99 21 Sep 99 M Pt C Pad Progress Report Well MPC-02 Page 1 Rig Nabors 4ES Date 06 October 99 00:00-06:00 00:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-11:00 08:00-11:00 11:00 11:00-13:00 11:00-13:00 13:00 13:00-21:00 13:00-16:00 16:00 16:00-21:00 21:00 21:00-22:30 21:00-21:30 21:30 21:30-22:30 22:30 22:30-01:00 22:30-01:00 01:00 01:00-04:00 01:00-04:00 04:00 04:00-05:00 04:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-16:00 06:00-16:00 16:00 16:00-17:00 16:00-17:00 17:00 17:00-05:30 17:00-18:00 Duration 6hr 6hr 2hr 2hr 3hr 3hr 2hr 2hr 8hr 3hr 5hr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 2-1/2 hr 3hr 3hr lhr lhr lhr lhr 10hr 10hr lhr lhr 12-1/2 hr lhr Activity Move rig Rig moved 80.00 % Rig is over well and setting in pits etc. started move @ 0300 hrs. 9/20/99 At well location - Slot Move rig (cont...) Rig moved 100.00 % At well location - Slot Wellhead work Retrieved Hanger plug Equipment work completed Derrick management Rigged down Flowline clean iron from flow line from last two section milling operations estimate 800 lbs. + Equipment work completed Well control Circulated closed in well at 8050.0 ft circ. influx from well bore with seawater & shut in well sitp=lg0 sicp=300 Hole displaced with Seawater - 150.00 % displaced Circulated closed in well at 8050.0 ft circ. & raise brine wt. to 9.0 ppg. & shut dn & monitor same (well slight vacumn on both sides.) Influx Out of hole Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack test waived by Chuck Sheve with AOGC Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Rig Lubricator & pull twc. Equipment work completed Derrick management Rigged up Tubing handling equipment crew change. Stopped · To hold safety meeting Run Single completion, 2-7/8in O.D. Laid down 8161.0 ft of Riser Completed operations Well control Worked on BOP - Lubricator Equipment work completed Electric wireline work Tested Lubricator TEST LUB TO 500 PSI. Facility Date/Time 22 Sep 99 M Pt C Pad Progress Report Well MPC-02 Page 2 Rig Nabors 4ES Date 06 October 99 18:00 18:00-23:00 23:00 23:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-15:00 06:00-14:00 14:00 14:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-18:00 16:00-18:00 18:00 18:00-19:30 18:00-19:30 19:30 19:30-23:00 19:30-23:00 23:00 23:00-01:00 23:00-01:00 23 Sep99 01:00 01:00-06:00 01:00-02:00 02:00 Duration 5hr 6-1/2 hr 1/2 hr 1/2 hr 9hr 8hr lhr lhr lhr 2hr 2hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 2hr 2hr 5hr lhr Activity Pressure test completed successfully - 500.000 psi Conducted electric cable operations RAN 6.02" GR/JB. TWICE TO 8295' REC. RUBBER ON FIRST RUN SECOND CLEAN. Completed run with Junk basket/gauge ring from 0.0 ft to 8295.0 ft Conducted electric cable operations CEMENT CLEAN TOP @ 3700' (7720' TO 7820' ) CEMENT SHOWED GOOD BOND. Completed logging run with Cement bond log from 8295.0 ft to 3500 Well control Worked on BOP - Lubricator NIPPLE DOWN LUBRIATOR & SHOOTING FLG. Stopped: To hold safety meeting CRREW CHANGE Run Single completion, 3-1/2in O.D. Ran Tubing to 7782.0 ft (3-1/2in OD) Rig up & mu Baker S-3 pkr. & rib. At Setting depth: 7782.0 ft Installed Tubing hanger Tie-down bolts energised Wellhead work Installed Hanger plug Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree test to 5000 psi. Equipment work completed Fluid system Freeze protect well - 55.000 bbl of Diesel ig lines to tree & Tst to 4500 psi., & pump 200 bbl. h20 treated wit nalco corrission inhib. & follow with 55-bbl. diesel& u-tube to tbg. Completed operations Run Triple completion, 3-1/2in O.D. Functioned Permanent packer drop ball & set pkr. per. program. & AOGC Test Waived by Lew Grimmaldi Test psi. 4400 psi. OK. Equipment work completed Wellhead work Installed Hanger plug Rig lubricator & set bpv & secure tree & cellar al-ea. Equipment work completed Rig Released @ 0200 Hrs. 9/23/99 RECEIVEE 'Alaska Oil & Gas Cons. Commiss~o,~ Anchorage Oft re.d .r?.ce r, ll ng To: From: Blair Wondzell - AOGCC Michael Triolo Subject: MPC-02 Application for sundry permit - recompletion operations Date: 23 July 1999 Reference: A_PI//50-029-20866 MPC-02 was drilled and completed across the Kuparuk A sand in December 1982. In 1984 a recompletion opened up the C sand. The C sand was frac'd in 1994 and the A sand was frac'd in 1998 along with a re-&ac of the C sand. The well is believed to be completed in a fault causing severe sand and proppant production problems. A screen set across the perforation intervals in June 1998 has rendered the well ineffective as a producer. Due to the wells location, conversion to an injector for support of MPC-14 has become a better option than pursuing restoration as a producer. The MPC-02 conversion is currently scheduled for Nabors 4ES following the MPK-13 ESP pump change out. The rig is expected to finish operations on MPK-13 on the 21~ of August. The pre-rig work for the MPC-02 conversion is planned to begin around the middle of August pending Sundry approval. Pre Rig Work: 1) Obtain pressure survey. 2) Pull dummy valve from lower GLM. 3) Set BPV. Rig Operations: MmU. 2) Pull BPV. 3) Circulate well. 4) Set TWC ND tree NU and test BOP. 5) Pull existing completion. 6) Run Bond log. 7) Make GR/JB run to below packer setting depth. 8) Run 3-1/2" premium tubing and permanent packer completion. 9) Set TWC,ND BOP ,NU and test tree, Pull TWC. 10) Freeze protect well and set packer. 11) Test packer. Packer test to be witnessed by AOGCC. 12) Bullhead tubing freeze protection and set TWC. 13) Rig down and move off. ~-~ STATE OF ALASKA "- ALASKA · -,IL AND GAS CONSERVATION COM~ISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Injector 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1229' NSL, 2459' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 1259' NSL, 1423' EWL, SEC. 11, T13N, R10E, UM At effective depth 1250' NSL, 1429' EWL, SEC. 11, T13N, R10E, UM At total depth 1243' NSL, 1432' EWL, SEC. 11, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory ~1Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-02 9. Permit Number 82-194 10. APl Number 50-029-20866 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8869 feet true vertical 7449 feet Effective depth: measured 8639 feet true vertical 7219 feet Casing Plugs (measured) Junk (measured) ORIG NAL Length Size Cemented MD TVD Structural Conductor 80' 20" To Surface 115' 115' Surface 2615' 13-3/8" 750 sx Permafrost 'C' 2650' 2338' Intermediate Production 8834' 7" 800 sx Class 'G' 8869' 7449' Liner Perforation depth: measured 8370' - 8390', 8546' - 8558', 8545' - 8600', 8566' - 8596' true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8161' Packers and SSSV (type and measured depth) 7" H ES Retrievable packer at 8317' (subsea) 6899'-6919', 7074'-7086', 7073'-7128', 7o94'-7~?~C~!VF / U6 03 1999 Alaska Oil &.G.~ Cor~. C0mmissi0n 13. Attachments [] Description summary of proposal 14. Estimated date for commencing operation August 15, 1999 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Michael Trio/o, 564-5774 ,P'uluJJuJ'.a~8 Detailed operations program [] BOP sketcff'i 15. Status of well classifications as: [] Oil I~l Gas I--I Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that t,b9 fo~)going is~j,~ and correct to the best of my knowledge Signed k.~°J~,~ ' Charles Mallary// '~"~ ~ ,.~-~)~'/ Title Senior Drilling Engineer (/ Commission Use Only Conditions of Approval: Notify Commission so r- ' --epresentative may witness Plug integrity__ BOP Test ¢,"' Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approval No: '3,~, '" / Approved by order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNEDBY Commissioner Date Robert N. Chdstenson Submit In Triplicate TREE: 2-9/16"-5M MCEVOY WELLHEAD: 11" 5M FMC (Phase 1&2) w/2-7/8" FMC ESP Tubing Hanger EUE 2.5" CIW H BPV PROFILE 20" 94 ppf Grade B KOP @ 500' Max. hole angle 56 deg. @ 4100' Angle through perfs. 2 deg. I115' MPU C-02 ORIG. KB. ELEV = 52' (Nabors 27E) ORIG. GL. ELEV = 17' (Nabors 27E) HES 3.5' X Nipple I'22°° I 13 3/8" 72 ppf L-80 BTS 2,650' Note: Minimum id 2.205" @ 8,161' 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 3.5" Premium Tubing for IWAG Injection PROPOSED COMPLETION Stimulation Summary: Fmc - 11/16/94, 51 M# 16/20 mesh, "C" Sand 8370' to 8390' 01/04/97 "A" sands Fmc proplok & scale inhib, treatment. 108 M# 16/20 carbolite 17 M# of which was proplok. 01/07/97 "C" sands re-frac proplok & scale inhib, treatment. 49.5 M# 16/20 carbolite 22.9 M# of which was proplok. PERFORATION SUMMARY REF LOG: 7/12/82 DIL SFL SIZE SPF INTERVAL ('rVD) 5" 12DP 8370' - 8390' [6950' - 6970') 3 3/8" 6 BH " " " 5" 12DP 8546' - 8558' 7126' - 7138') 3 3/8" 6 BH 8545' - 8600' (7125' - 7180') 5" 12DP 8566' - 8596' [7146' - 7176') HES 3.5' X-Nipple 3.5 x 7' HES Retdeveable pkr. HES 3.5" XN nipple I I I -8100 I I I w / screens. 4.5" Proplus screens 4.5" Spacer pipe 4.5" Proplus screens 4.5' Tail pipe I8'634' I PBTD I 8,639' 7" 29#, L-80, BTRS I 8,869' DATE 7/22/99 REV. BY MDK COMMENTS Proposed Completion MILNE POINT UNIT WELL C-02i BP EXPLORATION (AK) < - TREE: 2-9/16"-5M MCEVOY WELLHEAD: 11" 5M FMC (Phase 1&2) w/2-7/8" FMC ESP Tubing Hanger EUE 2.5" CIW H BPV PROFILE MPU C-02 ORIG. KB. ELEV = 52' (Nabors 27E) ORIG. GL. ELEV 17' (Nabors 27E) 20" 94 ppf Grade B I 115' KOP @ 500' Max. hole angle 56 deg. @ 4100' Angle through perfs. 2 deg. Camco 2 7/8" x 1" I KBMM2 GLM 144' 13 3/8" 72 ppf 1-80 BTS I 2,650' I Note: Minimum id 2.205" @ 8,161' 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151" cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( ddft ID = 2.347", cap. = 0.00592 bpf ) Stimulation Summary_: Frac- 11/16/94, 51 M# 16/20 mesh, "C" Sand 8370' to 8390' 01/04/97 "A" sands Frac proplok & scale inhib, treatment. 108 M# 16/20 carbolite 17 M# of which was proplok. 01/07/97 "C" sands re-frac proplok & scale inhib, treatment. 49.5 M# 16/20 carbolite 22.9 M# of which was proplok. PERFORATION SUMMARY REF LOG: 7/12/82 DIL SFL SIZE SPF INTERVAL (TVD) 5" 12DP 8370' - 8390' (6950' - 6970') 3 3/8" 6 BH " " " 5" 12DP 8546' - 8558' (7126' - 7138') 3 3/8" 6 BH 8545' - 8600' (7125' - 7180') 5" 12DP 8566' - 8596' (7146' - 7176') Camco 2 7/8" x 1" KBMM2 GLM 2-7/8" HES XN-Nipple (2.205"id) Centrilift GC 1700 ESP, series 513, GPMTAR 1:1,151 Stg. Intake'l'VD I 6706' I Tandem Centrilift Gas Separator Centrilift GST3 DB HL seal section Centrilift KMH 562 series, 152 hp motor, 2325 v. / 40 amps. Centrilift PHD 7" HES Retrieveable pkr. w / screens. 4.5" Proplus screens 4.5" Spacer pipe 4.5" Proplus screens 4.5" Tail pipe PBTD 7" 29#, L-80, BTRS 8,051' I 8,099' I 18~112' I I 8,'i27' I I 8,133' I I e,154' I 8,161' I I 8,317' I 8,634' I 8,639' I 8,869' DATE 12/82 REV. BY DBR COMMENTS DRILLED 05/17/95 JBF ESP RWO/ M. Linder 07/13/96 ESP RWO 01/15/98 MDC Re-Frac w/proplok & ESP Comp. 5 - S 07/01/98 MDC Added scab screens & ESP Completion 5-s MILNE POINT UNIT APl NO: 50-029-20866 BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [~Pull Tubing [--IAIter Casing [] Repair Well [~Other ESP Changeout 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1229' NSL, 2459' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 1259' NSL, 1423' WEL, Sec. 11, T13N, R10E, UM At effective depth 1245' NSL, 1933' EWL, Sec. 11, T13N, R10E, UM At total depth 1245' NSL, 1933' EWL, Sec. 11, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-02 9. Permit Number / Approval No. 82-194 10. APl Number 50- 029-20866 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 8869' feet Plugs (measured) true vertical 7449' feet Effective depth: measured 8869' feet Junk (measured) true vertical 7449' feet Casing Length Size Cemented Structural Conductor 80' 20' To surface Surface 2615' 13 3/8" 750 sx Permf 'C' Intermediate Production 8834' 7' 800 sx Class 'G' Liner MD TVD 115' 115' 2650' 2337' 8869' 7449' Perforation depth: measured 8370'-8390', 8546'-8558', 8545'-8600', 8566'-8596' true vertical (Subsea) 6899'-6919', 7074'-7086', 7073'-7128', 7094'-7124' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 8112' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary ORIGINAL RECEIVED JUL ,~ i i998 Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Dai_ly Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge .. ,~'~~~ ~ ~~/ S~ ~~X~'~'~ ~ Date Signed,~ T~le ~ ~ Prepared By Name/Number: S-~ T~n '~u plicatl~~ Form 10-404 Rev. 06/15/88 Facility M Pt C Pad Progress Report Well MPC-02 Page 1 Rig '~ ~//0/30~ .fix Date 15 July 98 Date/Time 24 Jun 98 25 Jun 98 26 Jun 98 27 Jun 98 28 Jun 98 06:00-06:15 06:15-21:00 21:00-00:30 00:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-07:30 07:30-08:30 08:30-12:00 12:00-12:30 12:30-14:00 14:00-00:30 00:30-03:00 03:00-06:00 06:00-06:15 06:15-09:15 09:15-12:30 12:30-16:00 16:00-21:00 21:00-02:30 02:30-05:00 05:00-06:00 06:00-06:15 06:15-13:30 13:30-15:30 15:30-16:30 16:30-21:00 21:00-02:30 02:30-06:00 06:00-06:15 06:15-08:30 08:30-09:30 09:30-11:30 11:30-12:30 12:30-15:00 15:00-16:00 16:00-18:00 Duration 1/4 hr 14-3/4 hr 3-1/2 hr 1-1/2 hr lhr 2hr lhr 1/4 hr 3/4 hr 1/2 hr lhr 3-1/2 hr 1/2 hr 1-1/2 hr 10-1/2 hr 2-1/2 hr 3hr 1/4 hr 3hr 3-1/4 hr 3-1/2 hr 5hr 5-1/2 hr 2-1/2 hr lhr 1/4 hr 7-1/4 hr 2hr lhr 4-1/2 hr 5-1/2 hr 3-1/2 hr 1/4 hr 2-1/4 hr lhr 2hr lhr 2-1/2 hr lhr 2hr Activity Held safety meeting Rig moved 100.00 % Fill pits with Brine Removed Hanger plug Bleed down well Circulated at 8145.0 ft Circulated at 8145.0 ft Held safety meeting Installed Hanger plug Removed Xmas tree Rigged up BOP stack Tested BOP stack Retrieved Tubing hanger Rigged down sub-surface equipment - Hanger assembly Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 8520.0 ft Washed to 8622.0 ft Reverse circulated at 8618.0 ft Pulled BHA Conducted electric cable operations Installed Packer & tailpipe assembly Ran Tubing in stands to 2000.0 ft Held safety meeting Ran Tubing in stands to 8634.0 ft Set packer at 8317.0 ft with 2500.0 psi Reverse circulated at 8300.0 ft Pulled Tubing in stands to 0.0 ft Serviced ESP Ran Tubing in stands to 4500.0 ft Held safety meeting Ran Tubing in stands to 8139.0 ft Installed Tubing hanger Functioned ESP Installed Tubing hanger Serviced Annular preventor Removed BOP stack Installed Xmas tree RECEIVED JUL 51 1998 Alaska Oil & C~ C0n~. Commls.qior~ Anohor~g~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh DATE: June 25, 1998 Chairman THRU: Blair Wondzell, FILE NO: aw91fyfe.doc P. I. Supervisor 7l, Confidential: Yes No X FROM: John SpauldingSUBJECT: BOPE Test Nabors 5S Petroleum Insp MPU / C-02 / PTD 8 - ( '� -1-7 June 25, 1998: 1 witnessed the BOPE Test on Nabors 5S located at BPX's Milne Point Field well C-02. The AOGCC BOPE Test Report Form is attached for reference. As noted on the report form no failure were observed and the test went well. Summary: I witnessed the BOPE Test on; Nabors 5S, 3 hours, 0 failures Attachments: aw91fyfe.xls OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: I nitia STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Workover: X Nabors Rig No. BPX C-02 Set @ X Weekly Other �-L- M DATE: 6/25/98 5S PTD # -8- -t44 Rig Ph.# 659-4456 Rep.: Marc Babineaux Rig Rep.: Darrell Schwindt Location: Sec. 10 T. 13N R. 10E Meridian Umiat REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI -021 L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding Aw91fyfe.x1s TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: Well Sign ok Upper Kelly / IBOP 1 250/5,000 P Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly / IBOP 1 250/5,000 P PTD On Location ok Hazard Sec. yes Ball Type 1 250/5,000 P Standing Order Posted yes Inside BOP 1 250/5,000 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/5,000 P No. Valves 14 250/5,000 P Lower Pipe Rams 250/5,000 No. Flanges 31 250/5,000 P Blind Rams 1 250/5,000 P Manual Chokes 1 Functioned P Choke Ln. Valves 1 250/5,000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 250/5,000 P Kill Line Valves 1 250/5,000 P ACCUMULATOR SYSTEM: Check Valve na 250/5,000 System Pressure 3,000 P Pressure After Closure 1,500 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 18 sec. Trip Tank ok ok System Pressure Attained 1 minutes 13 sec. Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: X Flow Indicator ok ok Nitgn. Btl's: 5 @ 2100 avg. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok TEST RESULTS Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI -021 L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding Aw91fyfe.x1s STATE OF ALASKA ALASK,,-, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Exchange 2. Name of Operator BP Exploration, Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1229' NSL, 2459' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 1259' NSL, 1423' EWL, Sec. 11, T13N, R10E, UM At effective depth 1282' NSL, 1429' EWL, Sec. 11, T13N, R10E, UM At total depth 1275' NSL, 1432' EWL, Sec. 11, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KBE) KBE = 52' 7. Unit or Property Name MPU 8. Well Number MPC-02 9. Permit Number / Approval No. 82-194 10. APl Number 50- 029-20866 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 8869' feet true vertical 7397' feet Effective depth: measured 8639' feet true vertical 7167' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented 80' 20" To surface 2615' 13 3/8" 750 sx Permf 'C' 8834' 7" 800 sx Class 'G' '"'!GINAL MD TVD 115' 115' 2650' 2337' 8869' 7397' Perforation depth: measured 8370'-8390', 8546'-8558', 8545'-8600', 8566'-8596' true vertical 6950'-6970',7126'-7138',7125'-7180',7146'-7176' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 8217' Packers and SSV (type and measured depth) None RECEIVED ,~,:.,.:-~ 2 5 1998 Alaska Oil & Gas Cons. Cor~;alsslon Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Frac 51 M# 16/20 Mesh 'C' Sand 8370-8390 Treatment description including volumes used and final pressure Attachment 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~' ~ Title L~,'tl~,3 ~,~...~.~. Date ~Prep~red By Narne/Nurnber: /~Rfy~ / '-~Submit In Duplicate Form 10-404 Rev. 06/15/88 Facility M Pt C Pad Progress Report Well MPC-02 Page Rig Nabors 5S Date 1 17 February 98 Date/Time 29 Dec 97 30 Dec 97 31 Dec 97 O1 Jan 98 02 Jan 98 03 Jan 98 04 Jan 98 05 Jan 98 06 Jan 98 21:30 00:00 06:00 06:30 09:30 13:00 18:00 20:00 22:00 06:00 06:30 10:00 15:00 17:30 22:00 06:30 20:00 00:00 00:30 04:30 05:30 07:00 11:00 12:30 17:00 17:30 02:00 06:30 18:00 23:00 01:00 04:30 05:00 06:00 06:30 07:00 10:00 11:30 14:00 18:00 20:00 21:30 03:00 06:00 06:30 18:00 18:30 06:00 08:00 10:00 12:30 14:30 21:00 Duration Completed Completed Completed Completed Completed On bottom Activity Began precautionary measures Completed operations Hole displaced with Brine - 100.00 % displaced Completed operations Completed operations Function test completed satisfactorily Pressure test completed successfully - 5000.000 psi Function test completed satisfactorily Equipment work completed Stopped: To hold safety meeting Completed operations operations run with Junk basket/gauge ring to 8647.0 ft run with Junk basket/gauge ring to 8647.0 ft operations operations Packer set at 8425.0 fi Completed operations Completed FRAC job Stopped: To test equipment Aborted FRAC Job Additional services failed - Abort operation Obtained clean returns - 50.00 % hole volume Obtained req. fluid properties - 100.00 %, hole vol. Completed operations Completed run with Cleaning / Investigation tools from 8450.0 ft to 8 ft Began precautionary measures Resumed operations Observed pressures - string: 0.000 psi, annulus: 0.000 psi 20.000 bbl of treatment mixed Stopped: To hold safety meeting Completed operations Began precautionary measures Completed operations Aborted mixing of treatment Stopped: To flowcheck well Began precautionary measures Stopped: To pick up/lay out tubulars Shut in well at 360.0 psi Shut in well at 0.0 psi Shut in well at 60.0 psi Observed well static Observed well static Completed operations R E C E!V Stopped: To hold safety meeting Completed operations !~:~.~.~,'.., ~ ?, ~£r' ~ ~ Stopped: To hold safety meeting Work completed, equipment laid out COilS Equipment work completed Alaska Oil & ga3 · Equipment work completed Anchorage Equipment work completed Pressure test completed successfully - 5000.000 psi 615.0 Facility M Pt C Pad Progress Report Well MPC-02 Page 2 Rig Nabors 5S Date 17 February 98 Date/Time 07 Jan 98 08 Jan 98 09 Jan 98 10 Jan 98 11 Jan 98 12 Jan 98 13 Jan 98 14 Jan 98 15 Jan 98 01:00 03:00 06:00 08:00 10:30 16:00 17:30 19:30 01:00 03:00 06:00 13:30 14:00 15:30 18:00 21:00 01:00 04:30 06:00 07:30 09:00 12:00 16:00 18:00 02:00 04:00 06:00 07:00 09:00 11:00 15:30 18:00 01:00 06:00 18:00 21:00 06:00 10:00 14:00 18:00 20:00 22:30 06:00 11:00 16:00 17:00 18:00 03:00 06:00 09:00 18:00 19:00 01:30 03:30 Duration Activity Stopped: To circulate Obtained req. fluid properties - 50.00 %, hole vol. Stopped: To hold safety meeting On bottom Stopped: To hold safety meeting 344.000 bbl of treatment mixed 452.000 bbl of treatment mixed Stopped: To flowcheck well Stopped: To flowcheck well Stopped: To flowcheck well Stopped: To hold safety meeting Stopped: To flowcheck well Observed well static Stopped: To circulate Stopped: To hold safety meeting At Surface: 0.0 ft Stopped: To circulate Hole displaced with Brine - 55.00 % displaced Stopped: To hold safety meeting Stopped: To circulate Hole displaced with Brine - 10.00 % displaced Stopped: To change handling equipment Work completed - Swivel in position Stopped: To hold safety meeting Stopped: To service drilling equipment Equipment work completed Stopped: To hold safety meeting Got stuck whilst pipe moving Pipe came free Began precautionary measures Obtained clean returns - 100.00 % hol, e volume Stopped: To hold safety meeting Hole swept with slug - 100.00 % hole volume Stopped: To hold safety meeting Stopped: To hold safety meeting Began precautionary measures Observed pressures - string: 93.000 psi, annulus: 91.000 psi Observed pressures - string: 90.000 psi, annulus: 90.000 psi Observed pressures - string: 20.000 psi, annulus: 20.000 psi Observed pressures - string: 0.000 psi, annulus: 0.000 psi Stopped: To service drilling equipment Stopped: To flowcheck well Stopped: To hold safety meeting Pressure test completed successfully - 2500.000 psi Pressure test completed successfully - 5000.000 psi Pressure test completed successfully - 0.000 psi Stopped: To hold safety meeting At Top of fill: 8639.0 ft Obtained clean returns - 100.00 % hole volume 20.000 bbl of treatment mixed 160.000 bbl of treatment mixed Observed pressures - string: 0.000 psi, annulus: 0.000 psi Completed operations Equipment work completed Facility M Pt C Pad Progress Report Well MPC-02 Rig Nabors 5S Page Date 3 17 February 98 Date/Time 16 Jan 98 17 Jan 98 06:00 14:30 16:30 17:30 21:30 00:30 05:00 06:00 11:00 06:00 Duration Activity Stopped: To hold safety meeting Stopped: To splice cable Equipment work completed Equipment work completed Completed operations Stopped: To circulate Completed operations Stopped: To hold safety meeting Rig off station Rig off station SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-2 Rig Name: N-4ES AFE# 339017 Accept Date: 7/9/96 Spud Date: - Release Date: 7/13/96 JULY 9, 1996 RIG ACCEPTED @ 0630. JULY 10, 1996 SPOT & BERM RIG RAISE & SCOPE DERRICK. TAKE ON WATER, RIG UP HARDLINE TO TREE RIG UP LUBRICATOR PULL BPV RD LUBRICATOR, SET & BERM TIGER TANK RIG UP HARDLINE TO TIGER TANK MIX 40 BBLS XANVIS & LIQUID CASING PILL TAKE ON 11.6 PPG BRINE & CUT BACK TO 10 PPG BRINE W/8.4 SOURCE WATER. SITP 2920 PSI - SICP 2930 PSI. BULLHEAD 40 BBL XANVIS & LIQUID CASING PILL DOWN TUBING TO PERFS ATTEMPTED TO SQUEEZE PILL INTO PERFS SHUT DOWN & MONTIORED WELL 650 PSI ON TUBING & 3350 PSI ON CASING DISPLACED ANNULUS W/10 PPG BRINE, PUMPED GAS & PRODUCED FLUIDS TO TIGER TANK CIRCULATED BU THRU OPEN CHOKE MONITORING PIT LEVEL 4 BPM @ 600 PSI NO GAINS OR LOSSES. SHUT IN WELL & MONITOR PRESSURE WELL PRESSURED UP TO 90 PSI ON BOTH TBG & CASING UNABLE TO BLEED OFF PRESSURE WEIGHT UP BRINE TO 10.5 PPG. CIRC 10.5 PPG BRINE THROUGH CHOKE @ 3 BPM @ 560 PSI TUBING PRESSURE MONITOR WELL 0 PSI ON TUBING & 20 PSI ON ANNULUS. WELL OUT OF BALANCE. CIRCULATED 10.5 PPG BRINE THRU OPEN CHOKE MONITORING PIT LEVEL. CIRCULATED @ 6 BPM @ 1100 PSI. NO GAINS OR LOSSES, SHUT IN & MONITOR WELL 0 PSI ON TUBING & CASING. CHECK FOR FLOW & NO FLOW, RIGGED DOWN & BLOW DOWN LINES. SET TWC & ND TREE. NU ADAPTER FLANGE & NU BOPS. JULY 11, 1996 NU BOPS TEST BOPS TO 250 LOW & 5000 HIGH. RU FLR FOR 2 7/8" & PULL TWC MU LANDING JT BOLDS PULL HANGER FREE WI80 K OVER PU & FILL HOLE WI6 BBL 10.6 PPG BRINE CIRC & WT UP TO 10.6 PPG. PULL HANGER TO FLOOR & LD HANGER & LANDING JT & RIG UP TO PULL ESP COMP POOH W/ESP COMP & INSP. ESP ASSY FOUND PUMP HARD TO TURN & BROKE FREE & ROTATE SAME. LEFT IN HOLE 12 FLAT BANDS. REC 6 FLAT GUARDS - 523 PREFORMED BANDS & 24 FLAT BANDS. CHG RAMS TO 3 1/2" & TEST SAME TO 250 & 5000 PSI. MU BHA #1 ECEIVED Page Alaska 0il & ~as Cons. Anchorage JULY 12, 1996 REPAIR CAMERA & MONITOR FOR PIPE SHED PICK UP 3 '~/~" DP & RIH W/BHA TO 8639' (4ES KB) REV CIRC HI - VIS SWEEP @ 5 BPM LOSS RATE OF 12 BPH DISPLACE WELL W/CLEAN FILTERED 10.6 PPG BRINE POOH LAYING DOWN DP. JULY 13, 1996 TOH LD DP CHG RAMS TO 2 7/8" & TEST TO 250 & 5000 PSI. MU & SERVICE ESP ASSY RIH W/ESP ASSY & MU HANGER & LANDING JT SPLICE ESP @ HNG & LAND ND BOPS & NY TREE & TEST TO 5000 PSI & PULL TWC & SET BPV FREEZE PROTECT WELL W/DIESEL TO 2000' RD LINES TO TREE & SECURE WELL. RIG RELEASED @ 0600. Page 2 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-02 Rig Name: N-4ES AFE# 330146 Accept Date: 5/12/95 Spud Date: - Release Date: 5/17/95 MAY 13, 199_~' ACCEPT RIG 1800 5/12/95. SCOPE DOWN DERRICK, BRIDLE UP. LAY DERRICK OVER. WAIT ON PEAK. TRUCK BROKE DOWN. MOVE RIG TO C-2. SPOT IN RIG, BERM EQUIPMENT, RAISE & SCOPE DERRICK. PU LUBRICATOR. PULL BPV, LAY HARDLINE TO TREE & KILL TANK. TAKE ON 750 BBLS 8.7-//' NACI H20. HEAT TO 140o. SITP: 350 PSi; CP: 620 PSI. BLEED GAS OFF WELL. CIRC DOWN TUBING @ 3BPM W/560 PSI. RETURNS TO KILL TANK. MAY 14, 1995 CIRC 8.7# NACI BRINE HEAT FLUID TO 110o MONITOR WELL OK. SET BPV ND TREE NU BOPE PULL BPV SET TWC. TEST BOPE TO 250/5000 PSI ANNULAR TO 250/3000 PSI OK WITNESSING WAIVED BY DOUG AMOS - AOGCC FIELD INSPECTOR PULL TWC. MU LANDING JT BOLDS CLOSE ANNULAR UNSET PACKER W/44K OVER. CBU THRU CHOKE & GAS BUSTER CIRC OUT GAS BUBBLE OPEN ANNULAR & WORK PACKER TO RELAX RUBBERS. MONITOR WELL FOR LOSS STATIC LOSS RATE 12 BPH SPOT 40 BBLS XANVIS PILL ON BO'I-I-OM. PULL & LD HANGER PULL TO SSSV LD SSSV PACKER & GLM. CONTINUE POH STANDING BACK. SLM & DRIFT. MAY 15, 1995 SERVICE RIG, FINSH POH W/2 7/8" COMPLETION. SLM & DRIFT. RECOVERED 531 PREFORMED BAN DS, 41 FLAT BANDS & FLAT GUARDS. INSTALL 3.5" PiPE RAMS TEST TO 300/5000 PSI OK. INSTALL WR. RU FLOOR TO RUN 3.5" DP. STRAP & MU FTA #1, PU 3.5" DP SLM & DRIFT. CBU @ 4 BPM WI600 PSI. PU WT: 160K, SO WT: 85K. MILL PKR F/8240'~4.3' PACKER DROPPED. RIH W/SINGLES. TAG PACKER TOP @ 8608' TBG TAIL @ 8638'. CBU. MAY 16, 1995 SERVICE RIG, MONITOR WELL, OK POH W/FTA #1 LD SAME. MU FTA #2 RIH TO 8585' BREAK CIRCULATION WASH OVER FISH TO 8611' CBU MONITOR WELL OK. POH LD FTA #2, PACKER & GRAVEL PACK SCREEN. MU FTA #3 RIH TO 5400'. CUT 114' & SLIP 42' DRLG LINE. FINISH RIH TO 8575' WASH & REAM F/8610'.--4.8'. UNABLE TO GO DEEPER. PU WT: 154K, SO WT: 95K. REVERSE CIRCULATE XANVlS SWEEP AROUND. MONITOR WELL OK. SPILL DRILL PITS: OS--4.8 SEC. POH LD DP. MATERIAL MIXED: 5 SXS XANVlS. Page I MAY 17, 1995 SERVICE RIG, FINISH LDDP & BHA. PULL WR. D1 DRILL: OS--60 SEC. INSTALL TEST PLUG. OPEN & CLEAN BLIND & PIPE RAM POCKETS. INSTALL 2 7/8" RAMS. TEST PIPE RAMS & RAM DOORS TO 250/5000 PSI. LD TEST JT & TEST PLUG. RU TO RUN 2 7/8" ESP COMPLETION. MU & TEST ESP ASSEMBLY. RUN ESP ON 2 7/8" TUBING. MAY 18, 1995 CONT RIH W/2 7/8" TBG. & ESP COMPLETION MU HANGER & LANDING JT SPLICE ESP CABLE & LAND TBG. RILDS. INSTALL TVVC & NIPPLE DOWN BOP'S & NU TREE. TEST TREE & SURFACE LINE TO 5000 PSI. & PULL TWC. DISP. ANN W/65 BBL DIESEL TAKING RETURNS UP TBG. & BULL HEAD 12 BBL DIESEL DOWN TBG. INSTALL BPV & SECURE WELL RIG DOWN CELLAR & CLEAN SAME. RIG RELEASED @ 1800. Page 2 DEc 01:49PM ~:P__~ EXPLORRTION MILNE POINT STATE OF A~ , ctfl -~ ¢3,",~ ~, AM~ OIL AND GAB CONSERVATION COMMI~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abendon ff,~spen(i ___. Alter ~lng ~. R~pair ~ll i Charge ~rovad program __ PUll tLeing__ Variance ..3.-. 'i' 5. TYPe of Well: Exploratory __ B1r~jgmp~io 2. Name o{ Operator e~' ExpIo~n (Ala _~fa) inc. , 3. Addreaa P. O, Box 1~$12, Anchorage, A/ask, a ~519.6612 n 4. Location 01 well at surface 1~ FSL 24~g FEL Se~ 10 TlSN RIOE UM At top of productive Interval 12Eg FSL 1423 FWL Sec 11 T1$N RIOE UM At effective depth At total depth 1245 FNL 14,33 FI/VL SEC, 11 TlSN, R10E UM 12. Present Well conclitlon summarY Total depth', measured true vertical OperaJion Sh~down __ Re-enter suspended well Plu~girlg Time extension_ SIImulate Pe~,.'ate Other ~ Datum eie~;ation (pi= or KB) 7'. Unit or Property name Mi/ne Point Unit 8. Well numbe~ C-02 MPU ! 9. Permit number 82.194 10. APt number 50.0£g-20866 11, Fial~P°°l Kuparuk River Pool iiii Plu~ (measured) Junk (measured) Effective depth: measured true vertical i[ 666~ feet 7449 feet 8681 feet 7261 feet ORIGINAL i feet Cueing Length Size Cemented Structure[ Concluctor 80 20" To Surface Surface 261~' 13 ~" 7~0 ax Perm C Intermediate Production 8834' 7" 800ex Claes Liner Perforation depth; measured 8370.23g0, 8646-8600 true ve~cal 8950-6970, 712-5.7179 Measured ~ 11~' 2650' Tru~/~ffical depth 115' 2337' 744~' RECEIVED Tubing (size, grade, and measured depth) 3 1/'2; 9.2#, L-80 tubing tp 8270 MD Packers and SSSV (type and measured depth) ~akerESP dualpa~er @ 5,95 MD 2 7/8" TR$SV ~ $$7 MD 13. Attachments Description summary of proposal -x-- Detailed operations program. i _ . 11 _ 14. E~tmated date for ~mmeneln~ operation Decernber2, 1994 16, If pr~ooeal was verball~ approved ...... Name ot appmver amir Wondzell Oeo, ~ Date approved 15. Status of Well clarification aa: DEC -5 i994 Alaska 0ii & Gas Cons. Commission Anchora~e i . BOP sketch __ Oil _X Ga~ Suspended_.___ · Service produ_oer · FOR COMMIe81 ,~JSE , . , ~ _. ONLY Condition, of approval: Notify'~.,ommlasion so representative may withes..4 J_~_-pproval No. f,,/_~ Plug integrity.___. BOP Test__ Loe.,ation olearance Mechanical Integrity Teat Su~uentformrequiredlO-0riginal Signea By Approved by order of the Commission ..David W. Johnstgn Commlsslune/ GaLe o40' oe/ /ss DEC 05 '94 01:~9PM B.P. EXPLORATIOM MILME POIMT · P.1 Miine Point_Unit Well C-02 Reaues_t for SSV Rule Variance Request: A variance to produce Well C-02 without a SSSV for one month. Reason for Request: A rig workover/frac was just completed on Well C.02. After the rig left it was discovered the hydraulic lines to the TRSSV had been crimped or plugged leaving it inoperable. The well is currently loaded with kill fluid. The well needs to be prodUced to determine the post rig workover/frac production rates. If the well continues to produce at pre- frac water cuts of 70% a "No Flow" test will be conducted. If the post frac water cuts are lower, a wireline retrievable valve will be run as the subsurface safety valve. It is anticipated that the well will cleanup to a stable producing rate in two weeks. However some wells have taken as long as one month to completely cleanup. RECEIVED DEC 05 1994 Oil & Gas Oons. Go~15q°i~' , memo 7671 # of I~S ~, .~ I~st. lt'~ brand fax transmittal , ] ~ , ~ i __ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: MPC-02 MILNE POINT NORTH SLOPE, AK Date: RE: 29 November 1994 Transmittal of Data ECC #: 6302.00 Sent by: MAIL Data: PFC/PERF Enclosed, please find the data as described below: Prints/Films: 1 PFC FINAL BL + RF Run # 1 Please sign and retu~~o: Atlas Wireline~ices A/n/o~r age ~ --~ /~ttn. Rodney D. Paulson_~. ~ ~ o~~ ~o (~0~) ~-~0~ ~ Received b~~~~~~~- D~~~~~% Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 June 5, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Report of Sundry Well Operations; Reservoir Pressure Reports Attached please find a Report of Sundry Well Operations for Well C-2 and Reservoir Pressure Reports for Wells G-1/2/3/4, H-2/3/4, I-1/2/3/4, and L-2/4/5/6/7. All these wells are at the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(jcd) Attachments cc Well Files RECEIVED JUN 11 t99] 0il .& Gas Cons. ~ch_0.rage STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate _X_ Pull tubing __ Alter casing __ 2. Name of Operator Conoco Tnc 3. Address 320!i'iC'- Str. eet~ Suite 200 Anchorage, AK 4. Location of well at surface 99503 1229 FSL 2459FEL Sec 10 T13N R10E UM At top of productive interval 1259 FSL 1423 FWL Sec 11 T13N R10E UM At effective depth 1250 FNL 1430 FEL Sec 11 ~totaldepth 1245 FNL 1933 FtC, Smc ]] 12. Present well condition summary Total depth: measured true vertical T13N R10E UM T1 qN 8869 7449 feet feet Effec.tive depth: measured true vertical 8681 7261 feet feet Casing Length Structural Conductor 80 Su trace 2 615 Intermediate Production 8834 Liner 13 Size Plugging __ Perforate __ Repair well __ Other __ 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) 52 Kg 7. Unit or Property name Milne Point Unit 8. Well number . C-2 ¢'~ 9. Permit numbedapproval number 82-194 10. APInumber 50--029-20866 11. Field/Pool Kuparuk River Field Junk(measured) 8681 Perf guns Cemented Measured depth True vertical depth 20" To surface 115 3/8" 750 sx Permf C 2650 411 bbl ARCO Fondu 7" 800sx Class G 8869 115 2337 7449 feet Perforation depth: measured 8370-8390, trueve~cal 6950-6970, Tubing (size. grade, and measured depth) 2 7 / 8 Packers and SSSV (type and measured depth) Otis 85~6-8558, 8566-8596 7126-7138, 7146-7176 L-80~ 8333 TRSC FMX SCSSV &. 537' REE. EIVED JUN 1 1 i99! Alaska OiJ & Gas Cons. Commission Ar~ch0rage Otis HCM Pkr @ 8272 13. Stimulation or cement squeeze summary At tachment Intervalstreated(measured) 8350, 8550, 8600 Treatment description including volumes used and final pressure Attachment, 150 psi 14. Production declined Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 836 ×/ 237 305 1132 746 <~ 267 '~ 190 '- 1033 Tubing Pressure 192 192 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. Signed ¢¢~., O P ~,,~-'~--~ Form 10-404 Rev 06/15/88 Title Senior Production Fore~ Date G J ~1 R. ~ , ,~.,, SUBMIT IN DUPLICATE CONOCO ~LNE POINT UNiT C-2 ACRID JOB ACTIVITY REPORT APRIL 19t 1991 HRS 0600 - 0000 * MIRU Pr.mjob safety meeting. * Fill lines and equipment with warm diesel and pressur.m test at 4000 PSI. * RIH w/coiled tubing to 8596. * Pickle .coiled tubing by pumping 6 bbls 15% HCl- inhibitor solution, followed with 20 bbls diesel. * Attempt to reverse pickle solution from tubing. Pumped 105 bbls NH4Cl solution with limited returns. * Pump 30 bbls pad acid. * Pump 18 bbls, 10% HCl, 0.3% HAI 85, 0.1% Lo Surf 300, 1.2% Claysta XP, 40~/MGal Fercheck A. * Pump 2 bbl spacer, 5 bbl diverter pill, 2 bbl spacer POOH to 8350. * Pump 18 bbls 10% HC1 solution. * Pump 2 bbl spacer, 5 bbl diverter pill, 2 bbl spacer RIH to 8550. * Pump 18 bbls 10% HCl solution. * Pump 12 bbls xylene. * RIH to 8600. * Pump 20 bbls diesel to displace. * POOH 8/10 FPM while pumping 6 bbls diesel. * POOH, flush lines and equipment. RECEIVED * Rig down. JUN 77 ~99~ A~s~ Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extention Stimulate x Change approved program __ Pull tubing __ Variance __ Perforate __ Other .. Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 1229' FSL, 2459' FEL, Sec. 10, T13N, R10E, U.M. At top of productive interval 1259' FSL, 1423' FWL, Sec. 11, T13N, R10E, U.M. At effective depth 1250' FNL, 1430' FEL, Sec. 11, T13N, R10E, U.M. At total depth 1245' FNL, 1433' FWL, Sec. 11, T13N, R10E, U.M. 5. Type of Well: Development X Exploratory Stratigraphic 6. Datum elevation (DF or KB) ,~2' KDB feet 7. unit or Property name Milne Point Unit 8. Well number C-2 9. Permit number 82-194 10. APl number 5O- 029-20866 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 8869' feet 1]'ue vertical 7449' feet Effective depth: measured 8681' feet true vertical 7261' feet Casing Length Size Structural Conductor 80' 20" Surface 2615' 13-3/8" Intermediate Production 8834' 7" Uner Perforation Depth: measured tree vertical Tubing (size, grade, and measured depth) Packem and SSSV (type and measured depth) Plugs (measured) Junk (measured) 8681' PERF GUNS Cemented Measured depth True vertical depth To Surface 115' 750 SX PERMF C 2650' 411 BBL ARCO FONDU 800 sx CLASS G. 8869' 8370-8390'; 8564-8558'; 8566-8596' 6950-6970'; 7126-7138'; 7146-7176' 2-7/8", L-80, 8333' 115' 2337' 7449' RECEIVED FEB 2 o ]991 Alaska.Oil & Gas Cons. '_Anch0rag OTIS TRSC FMX SCSSV @ 537' OTIS HCM Pkr. @ 8272' 13. Attachments Description summary of proposal X. Detailed operations program BOP sketch 14. Estimated date for commencing operation March 1, 1990 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby ce~fy that ~e foregoing is true and correct to the best of my knowledge. / /I., Signed I__)l/~ /~0~tJ J.H. Andrew 'Frae Production Engineer FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended__ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY IO_NNIF C. SMITH Commissioner IApproval No. Aoprovect G?P~' ~ Returneu Date Date February/11, 1990 SUBMIT IN TRIPLICATE MPU C-2 Acid Stimulation Procedure Summary 1. RU wireline. GIH and set PX plug in Otis X nipple at 8269'. · Pressure up against plug to 3500 psig. Monitor tubing and casing pressures for indications of leaks. Pull and replace gas lift valves, if necessary. 3. GIH and pull PX plug. RD wireline. · RU coiled tubing unit. Pressure test surface lines and equipment to 4000 psig. Pickle coil with 500 gal inhibited 15% HCl. Se GIH with coiled tubing to top of MK perforations at 8370', circulating hole full of 3% NH4Cl while TIH. 6. Close backside and establish injection with 3% NH4Cl. · Mix and pump the following acid stimulation treatment squeezing into the formation: a. 500 gal wellbore sweep (Xylene, mutual solvent, acetic acid) b. 1000 gal 15% HCl + additives Ce g. h. i. j. k. 3 bbl NH4Cl pad 5 bbl NH4Cl + diverter 3 bbl NH4Cl pad 1000 gal 15% HCl + additives 3 bbl NH4Cl pad 5 bbl NH4Cl + diverter 3 bbl NH4Cl pad 1000 gal 15% HCl + additives 500 gal Xylene overflush 8. Displace treatment with NH4Cl and diesel. POOH. 9. RD coiled tubing unit. 10. Return well to gas lift production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receip following m~terial which was transmitted via QUANTITY DESCRI PT ION Copy sent to sender YES NO STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMM!SSION ' APPLICATION FOR SUNDRY A/PPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown ~ Re-ether suspended well ~ , Alter casing __ Repair well ~ Pluggi0g:-- Time ext_e.J~_.bn __ Stimulate __ Change approved program __ Pull tubing ~ Variance _.¢¢~,~erforate __ Other_ 2. Name of Operator I' 5. Type of Well: ¢- 6. Datum elev~t.~n~ (D~:r~B) CONOCO INC. I Development ~ KDB I Exploratory __ - ~ Add r I a'graphic __ 7,. Uni[ or h'ro er[ name 3. e~.o. BOX 340045, PRUDHOE BAY, AK 99¢~Service MILNE ~~ UNIT 4. Location of well at surface 1229' FSL, 2459 FEL, SEC 10, T13, R10E, UM. At top of productive interval 1261' FSL, 1422, FWL, SEC 11, T13N, R10E, UM. At effective depth 1247' FSL, 143~, FWL, SEC 11, T13, R10E, UM. At total depth 1245' FSL, 1433, FWL, SEC 11, T13, R10E, UM. 8. Well number C -. 2 9. Permit number 82-3.94 10. APl number 50-- 029 - 20866 11. Field/Pool KUPARUK RIVER feet 12. Present well condition summary Total depth: measured true vertical 8900 ' feet Plugs (measured) 7311 ' feet NONE Effective depth: measured true vertical 8786 ' feet Junk (measured) 7230 ' feet NONE Casing Length Structural Conductor 80 m Surface 2 615 ' Intermediate Production 8438' Liner Perforation depth: measured true vertical Size 20" 13 3/8" 8370' - 6950' - 83 Cemented Measured depth True vertical depth TO SURFACE 115' 115' 900 SKS ARCO FONDU 750 SKS PERMAFROST C 2650' 2337' 800 SKS CLASS 'G' 8868' 7145' 300 SKS PERMAFROST C 200 BBL ARCTIC PACK 90m 8546 - 8558' 8566' - 8596' 6970' 7126' - 7138' 7146' - 7176' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", L-80, 9.2#/FT BTRS TO 8066' RKB 7" RDH DUAL STRING PACKER @ 577' RKB 2-7/8" OTIS FMS SCSSV @ 556' RKB .... Detailed operations program __ 15. Status of well classification as: "z4 ~,~ 13. Attachments Description summary of proposal __ X 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved Oil-Z- Service Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/,_~~?~t,/,~'.~,..,_~ Title Serl'io:r l:':rochlct.iorl FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Foreman Dare /D/Z I Approval No. I/ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- .,~oZ-/ ORIGINAL SlClV~9 BY '..;- .-.: :: LONNIE C. SMITH Approved by order of the Commission Approved Copy I Form 10-403 Rev 06/15/88 Commissioner Date SUBMIT IN TRIPLICATE MPU C-2 Workover Procedure Summary. m 2. 3. 4. 5. . 7~ 10. HIRU EWS workover rig on well. Kill well with 9.8 ppg NeC1 brine. ND tree, NU BOP's. PU to release Otis RDH packer at B77'. POOH with packer, production string and ESP. PU storm packer on workstrtng and set in production casing. ND BOP stack. Remove FMC tubing head from wellhead. NU BOP's on original Cameron tubing head. TIN with 2-7/8" production string with XN nipple, Otis HCM permanent packer,~Seoi 15ore~p~¢l~_ ~, gas lift mandrels, Otis FMX SC$$V, and Cameron tubin~/a-~er. Run tubing to set packer near 8270' and SCSSV near 550' MD. Land hanger and set packer. PU tubing to free production seal assembly from packer. Space out tubing, land and lock down Cameron hanger. ND BOP's. NU tree. . i i i I i i 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging __ X Pull tubing __ Alter casing __ Repair well __ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS0 Perforate ~ Other 2. Name of Operator CONOCO INC. 3. A~d~s.s BOX 340045 PRUDHOE BAY AK · ! , 9973~ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of Well at surface 1229'FSL, 2459'FEL, SECTION 10, T13N, RIOE, UN At top of productive interval 1261'FSL, 1422'FWL, SECTION 11, T13N, RIOE, UN At effective depth 1247'FSL, 1432'FgL, SECTION 11, T13N, RIOE, UH At total depth 1245'FSL, 1433'FNL, SECTION 11, T13N, RIOE, UH 8. Well number C-2 9. Permit number/approval number 82-194/¢~-,./? ? 10. APl number 50- 029-20866 11. Fi~AO~OK RIVER feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8900 ' feet Plugs (measured) 7311' feet 8786 ' feet Junk (measured) 7230' feet NONE NONE Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 20" TO SURFACE 115' 115' Surface 2615' 13-3/8" 900 SKS ARCO FONDU Intermediate 750 SKS PERHAFROST C 2650' 2337' Production 8834' 7" 800 SKS CLASS G 8869' 7145' 300 SKS PERNAFROST C Liner 200 BBL ARCTIC PACK Perforation depth: measured 8370'-8390' 8546'-8558' 8566'-8596' true vertical 6950'-6970' 7126'-7138' 7146'-7176' Tubing (size, grade, and measured depth) 3-1/2", L-80, 9.2#/FT BTRS TO 8066' RKB Packers and SSSV (type and measured depth) PACKER - 7" RDH DUAL STRING PACKER ~ 577' RKB. 2-7/8" OTIS FHS SCSSV ~ 556' RKB R"-EIVE 13. Stimulation or cement squeeze summary ANNULAR VENT VALVE e 576' RKB ~ ~ ~-.;, Intervalstreated (measured) NOT APPLICABLE Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure /~llch0ra~}e Tubing Pressure 1331 650 65 995 225 (NELL IS STILL UNLOADING) 971 248 420 45 216 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations__'X- 16. Status of well classification as: Oil ~ Gas_ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. IS,gn,d 0J-IA, Title PR0.UCTION FORE.AN Form 10-404 Rev 06/15/88 Date 07/03/90 SUBMIT IN DUPLICATE Kuparuk River- North Slope Borough, Alaska Milne Point C No. 14 CONFIDENTIAL (6115'-Kuparuk Oil Sands) AFE 10-61-1283 JUNE 15, 1990 BLEED DOWN ANNULUS AND TBG GAS. INSTALL BPV. MOVE FLOWLINES AND WELL HOUSE. MIRU RIG. BULLHEAD 75 BBLS OF SOURCE WATER DOWN THE TBG. JUNE 16, 1990 FILL ANNULUS WITH 167 BBLS OF SOURCE WATER. N/D PRODUCTION TREE. N/U BOP STACK. BUILD SPOOL FOR CHOKE LINE. TEST BOPE - OK. BLEED OFF GAS BUBBLE FROM UNDER THE TWO-WAY CHECK VALVE. UNLAND TBG. PICK UP TBG HNG, UNSET PACKER. CIRCULATE 312 BBLS OF SOURCE WATER DOWN THE TUBING. STARTED SEEING RETURNS AFTER 29 BBLS. TBG WENT ON A VACUUM WHEN CIRCULATION WAS STOPPED. POOH WITH TEMPORARY GAS LIFT STRING. L/D GLMS AND SCSSV. JUNE 17, 1990 CONTINUE TO POOH. L/D RTTS PKR. M/U SBR OVERSHOT, BUMPER SUB, OIL JARS, 6 - 4-3/4" x 2-3/16" DRILL COLLARS. RIH ON 4" 14#/FT DRILL PIPE. WITH 260 JTS IN THE HOLE, REVERSE CIRCULATE AT 1-1/2 BPM AND 150 PSIG. RETURNS WITH 15 BBLS AWAY. REVERSE TOTAL OF 52 BBLS. RIH 3 MORE JOINTS. TAG PKR. OVERSHOT IS NOT ENGAGING PKR LUGS. CIRCULATE WELL TO FLUSH OIL OUT OF ANNULUS IN PREPARATION OF POOH. JUNE 18, 1990 COMPLETE CIRCULATION OF OIL OUT OF ANNULUS. POOH WITH SBR OVERSHOT ON 4" DP. WITH 218 JTS OUT OF THE HOLE, THE WELL STARTED GETTING GASSY. CIRCULATE WATER DOWN THE TBG - RETURNS ARE PRIMARILY GAS CUT OIL. BULLHEAD 60 BBLS OF WATER DOWN THE ANNULUS. POOH. L/D OVERSHOT. FILL HOLE WITH 15 BBLS WATER. P/U BOWEN 5-3/4" OVERSHOT WITH 4.375" GRAPPLE. RIH ON BUMPER SUB, JARS, 6 DCS AND 26 JTS DP. REVERSE CIRCULATE THE WELLBORE TO CLEAN IT UP. RIH AND TAG THE TOP OF THE SBR. SET DOWN AND ATTEMPT TO ENGAGE THE GRAPPLE. GRAPPLE WILL NOT ENGAGE. RIG UP POWER SWIVEL. JUNE 19, 1990 COMPLETE RIG UP OF POWER SWIVEL. RIH TO JOINT NO 263 AND ATTEMPT TO LATCH ONTO SBR. RIH AND SET DOWN. PICK UP - PULLING WEIGHT. 50 PSIG PRESSURE ON DRILL PIPE. REVERSE CIRCULATE 150 BBLS OF WATER. TOOK 20 BBLS TO FILL. WELL DEAD RIH LATCH BACK INTO LOWER PACKER "K" ANCHOR. PICK UP AND ROTATE OUT OF THE ANCHOR. LAY DOWN POWER SWIVEL. CONTINUE TO POOH 86 STANDS. WELL STARTING TO FLOW. REVERSE CIRCULATE 360 BBLS SHUTTING DOWN PERIODICALLY TO MONITOR PRESSURE AND OR WAITING. NET PIT VOLUME DECREASED BY ONLY 18 BBLS HOWEVER +_172 BBLS OF HIGH OIL CUT (80% OIL) WATER WAS CIRCULATED OUT. IT APPEARS THAT ONE FORMATION MAY BE TAKING WATER WHILE THE OTHER IS GIVING UP OIL. SHUT WELL IN - MONITOR PRESSURES. DILUTE 10.3 PPG NaCI/NaBr BRINE TO 8.9 PPG. JUNE 20, 1990 BLEED OFF GAS PRESSURE. WELL DEAD. PUMP 70 BBL PILL DOWN DP. MIX UP AN ADDITIONAL 70 BBLS OF 9.1 PPG BRINE AND PUMP DOWN DRILL PIPE. GETTING STRONG OIL RETURNS. S/D PUMP. WELL DEAD. CONTINUE TO POOH. BULLHEAD 5 BBLS OF 10.3 PPG NaCI/NaBr BRINE DOWN THE DP AND 15 BBLS DOWN THE ANNULUS. WELL DEAD, DP STILL GASSY. PUMP 15 BBLS 10.3 BRINE NaCl/NaBr DOWN DP AND 135 BBLS DOWN ANNULUS - MONITOR - NO GAS. POOH WITH DCS, PKR, BLAST JTS AND LD 190.18' MU CJ PKR RETRIEVAL TOOL, MILL. SET WEAR BUSHING. RIH WITH CJ PKR MILL, DCS, DP - TAG TOP OF PKR AT 8430' RKB SLM. MU POWER SWIVEL. JUNE 21, 1990 REVERSE CIRCULATE 34 BBLS SOURCE WATER. RIH ROTATING LATCH INTO PKR. BEGIN MILLING OUT PKR. MIX 5 BBLS 3.5#/GAL HEC PILL AND PUMP DOWN DP. PUMP HEC PILL DOWN DP WITH 90 BBLS SOURCE WATER - BREAK OUT SWIVEL. POOH - PKR HANGING UP. JARRING. MU SWIVEL AND ROTATE DP. PKR HANGING UP IN FIRST CSG COLLAR. WELL FLOWING - HAUL 10.3 BRINE OUT FROM CFP PUMP 35 BBLS DOWN DP AND 65 BBLS DOWN ANNULUS. JUNE 22, 1990 PUMP ADDITIONAL 3.5 BBLS 10.3 BRINE DOWN ANNULUS 15 BBLS DOWN DP. JAR UP 250K- 100K OVER STRING WT. POOH-PAST RESTRICTION - LD POWER SWIVEL. POOH SLOWLY FILLING HOLE. LD PKR, RETRIEVER, JARS, BUMPER SUB. MU 6" BIT W/O NOZZLES, SINGLE 7" CSG SCRAPER, BUMPER SUB, JARS, 6 DCS. RIH WITH BIT AND SCRAPER - TAG FILL AT 8665' RKB SLM. REVERSE CIRCULATE WITH SOURCE WATER TO CLEAN OUT FILL DOWN TO TOP OF VANN GUN AT 8681' RKB. S/D PUMPING WEIGHT UP SOURCE WATER TO 9.5# AND RESUME PUMPING. JUNE 23, 1990 CONTINUE TO WEIGHT UP FLUID AND MIX UP CHEMICAL SWEEP. PUMP CHEMICAL SWEEP AS FOLLOWS: 25 BBLS PILL 3.5#/BBL HEC, 50 BBLS PILL WITH I DRUM DIRT MAGNET, 25 BBLS PILL 3.5#/BBL HEC. BRINE WAS WEIGHTED UP TO 9.7#. CIRCULATE SWEEP AROUND - PUMPED 408 BBLS. PUMPING 9.7 BRINE AROUND. WELL DEAD. POOH AND LD 4" DP. REPAIR SKATE. CONTINUE POOH WITH DP AND LD. JUNE 24, 1990 CONTINUE POOH AND LD, DP, DCS, SCRAPER, BIT. MU/SERVICE ESP ASSBLY. RIH WITH ESP ON 3-1/2" TBG. WELL STARTED FLOWING UP TBG - BULLHEAD 50 BBLS 9.7 NACL/NABR DOWN ANNULUS - CIRCULATE 30 BBLS - WELL STILL FLOWING - BULLHEAD 70 BBLS 10.3 NACL/NABR DOWN TBG - CIRCULATE 30 BBLS DOWN ANNULUS AND UP TBG - CHECK FOR FLOW - WELL DEAD. CONTINUE RIH. WELL STARTED FLOWING UP TBG - CAN NOT PUMP DOWN TBG DUE TO CHECK VALVE - BULLHEAD 100 BBLS 9.8 NACL/NABR DOWN ANNULUS THEN CIRCULATE 40 BBLS DOWN ANNULUS AND UP TBG THEN BULLHEAD 40 BBLS DOWN ANNULUS. CONTINUE RIH - MAINTAIN HOLE FULL MU OTIS RDH DUAL HYDRAULIC PKR. JUNE 25, 1990 MAKE CABLE SPLICE TO BOTTOM OF OTIS PKR. RIH WITH RDH PKR, OTIS TRSV (SCSSV), 3-1/2" TBG - 17 JTS 3-1/2" L-8 BTRC, LAND TBG HGR, PUMP 20 BBLS DIESEL DOWN ANNULUS, RU S/L TO RUN XX PLUG. RIH WITH 2-3/8" XX PLUG AND SET IN X NIPPLE BELOW PKR AT 576' WLM - POOH. PRESSURE UP ON TBG TO 3500 PSI TO SET PKR. PRESSURE UP ON ANNULUS TO 500 PSI TO TEST PKR - 10 MINUTES - GOOD TEST. RIH AND RETRIEVE XX PLUG. ND BOPE, NU TREE - TEST TREE - TEST ON TEST PORT ON ADAPTOR FLANGE WILL NOT TEST - PRESSURED UP TO 5000 PSI - BLEEDS OFF TO 1000 PSI - TOOK TREE OFF AND CHANGED SEALS ON TOP OF PENETRATOR AND TBG HGR TO TREE ADAPTOR SLEEVE - REPLACED TREE - STILL WOULD NOT HOLD 5000 PSI - BLEEDS DOWN TO 1000 PSI. INJECTED +_125 IN 3 OF PLASTIC/TEFLON SEALANT. PRESSURED UP TEST PORT TO 5000 PSI - BLED OFF TO 1300 PSI. INSTALL SWAB VALVE - RU TO RUN TWO WAY CHECK. JUNE 26, 1990 RU BP LUBRICATOR. SET TWO WAY CHECK VALVE - PRESSURE UP FROM WING VALVE TO TBG HNGR WITH 4000 PSI - OPEN TEST PORT ON ADAPTOR FLANGE TO CHECK FOR PRESSURE COMMUNICATION - NO COMMUNICATION NOTED - TBG INTEGRITY GOOD FROM PKR TO WING VALVE - LEAVE TWO WAY CHECK IN TREE - BLEED OFF PRESSURE ABOVE - 300 PSI GAS PRESSURE UNDER TWO WAY CHECK. RDMO. TO: THRU: FROM: MEMORAhOUM S' ate of Alaska ALASKA OIL AxND GAS CONSERVATION CO~4ISSION Lonnie C. Smi~,r~:~_,j_ _ C ommi s s ioner DATE: FILE NO: June 29, 1990 JT.BF.629.4 TELEPHONE NO: Boboy D. roste~- ~ Petroleum Ins~-~r SUBJECT: Walk Thru BOP Inspections Conoco MPU C-2 Kuparuk Rv Field Saturd~ay June 16, 1990: I traveled to Conoco's MPU C-2 and made a ~aik-~ro~ugh inSPection of E.W.S. rig 4. The equipment was installed properly and appeared to be in working order. 02-OOLA (Rev. 6/89) 20/11/MEMO1.PM3 ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ ~ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging __ Time extension __ Stimulate ~ Change approved program ~ Pull tubing -X- Variance __ Perforate ~ Other 2. Name of Operator CONOC0 INC. 3. Address P.O. BOX 340045. 4. Location of well at surface 1229' FSL, 2459' FEL, At top of productive interval 1261' FSL, 1422' FWL, At effective depth 1247' FSL, 1432' FWL, At total depth 1245' FSL, 1433' FWL, PRUDHOE BAY. AK SECTION 10, SECTION 11, SECT I ON 11, SECTION 11, Type of Well: Development -X- Exploratory ~ Stratigraphic __ Service __ T13N, R10E, UH T13N, R10E, UH T13N, R10E,' UH T13N, R10E, UH 6. Datum elevation (DF or KB) KDB 52' NSL feet 7. Unit or Property name H_~LNE P_n!NT UN.!T 8. Well number C-2 9. Permit number 82-194 10. APl number 50-- 029-20866 11. Field/Pool KUPARUK 12. Present well condition summary Total depth: measured true vertical Plugs(measured) NOT APPLICABLE 8900' feet feet 7311' Effective depth: measured 8786 ' feet Junk (measured) true vertical 7230' feet APPROX 42 CABLE BANDS ON TOP OF SBR @ 8168' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 20" TO SURFACE 115' 115' Sudace 2615' 13-3/8" 900 SKS ARCO FONDU Intermediate 750 SKS PERNAFROST C 2650' 2337' Production 8834' 7" ~J88 ~J~ J~J~J~J/~FJ~osT C 8869' 7145' Liner 200 BBL ARCTIC PACK Perforationdepth: measured 8370'-8390' 8546'-8558' 8566'-8596' R E¢ E IV E D truevertica16950'-6970' 7126'-7138' 7146'-7176' JUN 20 1990 Tubing(size, grade, and measured depth) 3-1/2", g.2#/FT, L-80, BTRS Alaska 0ii & Gas Cons. commission Anchorage PackersandSSSV(typeandmeasureddepth~'lALLIBURTON RTTS PKR W/BYPASS SUB e 8103' RKB, CAMCO TRDP- I AENC SCSSV e 515' RI(B 13. Attachments Description summary of proposaj(~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation ~UNF 16: 19gl3 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oilx__ Gas __ Suspended __ Service 17. I hereby certify_that the foregoing is true and correct to the best of my knowledge. Signed ~ ,¢~"), ~ ~y{h,,,,.~ Title ¢~, ¢0)~~ - FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ ~¢ ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH J Approval No. ~,,¢ ,..- ~/v/<7' / - Approved Copy Returned _ Commissioner Date ~:::~/2~ 90 Form 10-403 Rev 06/15/88 SUB M IT IN TRIP LICATE MPU KUPARUK RESERVOIR RECOMMENDED ESP RUNNING PROCEDURE 1) 2) 3) 4) Obtain a stabilized well test {oil, water and gas). RIH with pressure gauge on wireline and measure flowing well pressure with gauge set at the perforation mid-point. Shut-in well at the surface and record a 12 hour pressure buildup survey to determine reservoir pressure. Report the pressure data to engineering. Kill fluid density will be designed based on the measured pressures to provide balanced conditions, all kill fluid should be filtered to two microns and stored in clean tanks. Shut-in offset injection wells. Move in and rig up workover rig, filter units and clean brine tanks. Bullhead brine down tubing to kill the well (see attached wellbore diagrams). Nipple down wellhead and nipple up BOPs. Pressure test BOPs to 5,000 psig. a) b) c) Pick up tubing and shear out of the PBR assembly. Circulate brine to maintain the hole full. POOH with tubing. Cir bottoms up for good kill fluid consistency. PU drill pipe and GIH with packer retriever. Reverse circulate debris from top of packer at maximum pump rates prior to retrieving. Latch packer and zonal isolation assembly. POOH and L/D packer assembly. NOTE: If well exhibits high fluid loss tendency, spot a 5 bbl HEC pill (3.5 #'s HEC/bbl of brine) above packer and allow pill to fall across perfs. NU bit w/o jets and tandem full gauge casing scrapers on production tubing. GIH and tag sump packer. While reciprocating (maximum stroking capability of rig) and rotating pipe, reverse circulate the following cleansing pill at maximum pump rates. 1) 2) 3) 4) Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbls of brine + 1 drum of surfactant/dispersant (Safe-Kleen, Dirt Magnet, etc.) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - 2 complete circulations with filtered brine (2 microns) at maximum rates. NOTE: a) RECEIVED b) JUN 2 0 ~990 Alaska Oil & Gas Cons. uomm~S'~o~) Anchorage Safety and environmental precautions must be taken when handling brines and chemicals. Review MSDS sheets prior to handling. Chemicals must be mixed and maintained above 70 degrees F. Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. RECEIVED 5) JUN 2 0 1990 d) POOH and L/D bit and scrapers..~,[a$/~.Oji & GasCons. Commission Anchor. age Hake up ESP assembly as illustrated on the attached completion guiae. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 26 lb/ft casing on the bottom of the motor (refer to the attached table containing pertinent ESP data and Centrilift quotations). 6) RIHwith ESP no faster than 30' per minute. Maintain sufficient hydraulic pressure on the control line while running to maintain the valves in the open position. Attach 2 cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at depths specified in the attached ESP data table. 7) Locate packer and control valves at 500'. Packers should be pinned to begin setting approximately 1,100 psig. 8) RIH with tubing plug on wireline and set in the "X" nipple located below the packer and pressure up to 1,000 psig. Set packer by gradually pressuring up the tubing from 1,000 psig to 2,500 psig in 500 psig intervals. Retrieve the plug and POOH. 9) Bleed off the control line pressure to close the annular vent valve and TRSCSSSV. Pressure up the annulus to 500 psig for 10 minutes to test the packer and annular vent valve. If pressure holds, proceed to Step 10. If pressure does not hold, retrieve the packer/SCSSV system and repair or replace. RIH and retest. lo) Nipple down BOPs, nipple up tree, rig down and move to the next well. Make up surface electrical connections at the vent box, transformers and controller. ll) Start ESP and set frequency of controller to establish an initial rate equal to 75% of the previous rate. Allow well to unload and stabilize for 3 days at this rate. NOTE: a) Closely monitor sand production and report to engineering with the other parameters described in Step 12. b) Insure all valves are open to production prior to starting ESP. 12) With the choke fully open, allow production to stabilize for approximately 3 days at the 60 hz setting. Monitor production (oil, water and gas), FBHP, current and frequency. Report this data to engineering on a daily basis. Do not adjust controller frequency, unless the well pumps off, until these parameters stabilize. 13) NOTE: As rate is gradually increased, continue to monitor well for sand production. Do not increase rate if sand cut increases. 14) Shut-in the ESP and the TRSCSSSV. Observe for leakage of the SCSSSV. If liquid leakage in excess of 200 cc per minute or gas leakage greater than 5 SCF per minute is observed, the valve must be repaired or replaced (as per MMS, API 14A Section 250.124 al-9, Production Safety System Testing and Records). Note: A representative of the AOGCC must be present during Steps 9 and 14 to witness testing of the sub-surface safety system. 15) Apply sufficient control line pressure to open the safety valves and return the well to production. REC',EIVED JUN 2 0 1990 Alas~.OJJ & Gas Cons. Commission ;Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIV,,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Pull tubing ~ Alter casing __ 2. Name of Operator / 5. Type of Well: CONOCO INC Development X · I Exploratory __ 3. Address Stratigraphic m P.O. BOX 340045, PRUDHOE BAY, AK 9973 Service__ Stimulate __ Plugging __ Perforate __ Repair well __ Other 4. Location of well at surface 1229' FSL, 2459' FEL,SECTION lO,T13N,R10E,UM At top of productive interval 1261'FSL,1422'FWL,SECTION 11,T13N,R10E,UM At effective depth 1247' FS L, 1432' FWL, SECT I ON 11, T 13N, R 10E, UN At total depth 1245'FSL, 1433' FWL,SECTION 11,T13N~R10E~UM 12. Present well condition summary Total depth: measured 8900 ' feet true vertical 73 ! 1 ' feet Effec!ive depth: measured 8786 ' feet true vertical feet 6. Datum elevation ('DF or KB) KDB 52' MSL 7. Unit or Property name MILNE POINT UNIT 8. Well number C-8 9. Permit number/approval number 82-194/'~ -~._~" 10. APl number 50- 029-20866 11. Field/Pool KUPARUK RIVER feet Plugs (measured) NOT APPL I CABLE Junk (measured) 7230' APPROX 42 CABLE BANDS ON TOP Casing Length Size Cemented Measured depth Structural Conductor 80' 20" TO SURFACE 115' Surface 2615' 13-3/8" 900 SKS ARCO FONDU Intermediate 750 SKS PERMAFROST C 2650' Production 8834' 7" 800 SKS CLASS G 8869' 300 SKS PERMAFROST C Liner 200 BBL ARCTIC PACK Perforation depth: measured 8370'-8390' 8546'-8558' 8566'-8596' OF SBR 0 8168' True vertical depth 115' 2337' 7145' true vertical 69S0'-6970' 7126'-7138' 7146'-7176' JU(',[ 18 !990 Tubing (size, grade, and measured depth) 3-1/2", 9.2#/FT, L-80, BTRS . .;o.~l.al0jJ.t~[ Gas Cons. C0mr~issiop, Anch0rag~ Packers andSSSV(typeandmeasureddepth~HALLIBURTON RTTS PKR W/BYPASS SUB e 8103' RKB, CAMCO TRDP- 1 AENC SCSSV e 515' RKB 13. Stimulation or cement squeeze summary Interv~streated(measumd) NOT APPLICABLE Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1331 650 65 995 225 Subsequent to operation 1502 1004 210 1174 228 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: OilX_ Gas __ Suspended __ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed /"~.,,_~. C0?,,~_~_._ Fo rm 10-404 Rev f06/15/88 Date b-~J-~JD SUBMIT IN DUPLICATE KUPARUK RIVER FIELD - NORTH SLOPE BOROUGH, ALASKA MILNE POINT C NO. 2 - CONFIDENTIAL MAY 27, 1990 SET BPV. PREPARE FOR RIG MOVE. MAY 28, 1990 MIRU, PROBLEMS WITH GENERATOR DELAYED RU. PULL BPV. BLEED GAS OFF TBG - INTITAL PRESSURE 925 PSI. DROP BALL DOWN TBG TO SEAT ON CIRCULATING SUB. PRESSURE UP ANNULUS TO 2800 PSI AND SHEAR VENT VALVE. PUMP 60 BBLS WATER DOWN TBG TAKING DIESEL RETURNS FROM ANNULUS. NO INDICATION OF SHEARING OF CIRCULATION SUB. RU SLICKLINE TO RIH WITH BLIND BOX TO BEAT DOWN ON BALL AND SHEAR CIRCULATION SUB. MAY 29, 1990 RIH WITH 1.75" BLIND BOX. SAT DOWN HARD AT 586' WLM. WIRE PARTED. POOH WITH WIRE MU FISHING TOOL STRING - RIH - COULD NOT LATCH FISH - POOH - RU LIB 1 RIH - INDICATES BALL ON TOP OF TOOL STRING. MU OVERSHOT, RIH SET DOWN ON FISH - JAR - MU LIB RIH. FISH IS AT OR JUST ABOVE CIRCULATING SUB. IMPRESSION INDICATES ROPE SOCKET. RIH WITH JUS - LATCH FISH - ATrEMPT POOH. CANNOT POOH - BEAT DOWN IN ATTEMPT SHEAR CIRCULATING SUB - BEAT UP TO SHEAR OFF FISH - POOH. RD SLICKLINE. PUMP DOWN TBG 2 BPM AND 110 PSI. TAKING RETURNS FROM ANNULUS - DIESEL, CRUDE OIL, WATER. VOL PUMPED 368 BBLS. VOL RETURNED 290 BBLS. PUMP AN ADDITIONAL 32 BBLS DOWN TBG UNTIL CLEAN RETURNS ON ANNULUS - ALLOW TO EQUALIZE - MONITOR PRESSURES. SET BPV, ND TREE, NU BOPE AND TEST. POOH WITH TBG, PKR, SCSSV. MAY 30, 1990 CONTINUED TO POOH TO SURFACE WITH ESP STRING. 133 CABLE BANDS AND SADDLES LOST IN THE HOLE. ESP CABLE ARMOR PARTIALLY DAMAGED IN 3 LOCATIONS AND MOTOR FLAT CABLE DAMAGED. PUMP SECTION WAS FROZE UP, POSSIBLE "SLOP" IN SEAL SECTION DRIVE SHAFT AND NO APPARENT DAMAGE TO MOTOR OR GAS SEPARATOR. ALSO LOST 3 MOTOR FLAT GUARDS IN THE HOLE. R/U SLICKLINE UNIT. RECOVER SEVERAL BROKEN BANDS AND ONE MOTOR FLAT GUARD INSIDE THE BOP STACK AND WELLHEAD. R/U SCHLUMBERGER CONDUCTOR LINE UNIT AND JUNK BASKET WITH 6" GAUGE RING. RIH (@ +400'/MIN) ON FIRST RUN TO 1150' WHERE TOOL STRING WOULD FALL NO KUPARUK RIVER FIELD - NORTH SLOPE BOROUGH, ALASKA MILNE POINT C NO. 2 - CONFIDENTIAL MAY 30, 1990 (CONTINUED) FURTHER. FIRST RESTRICTION SEEN AT +._980'. RECOVERED APPROXIMATELY 10 BANDS. WORKED JUNK BASKET FROM 1150' TO 1385' ON SECOND RUN - RECOVERED +._8 BANDS. MAY 31, 1990 CONTINUE RUNNING JUNK BASKET/GAUGE RING ON SCHLUMBERGER E-LINE. MADE A TOTAL OF 7 RUNS. R/D SCHLUMBERGER WIRELINE UNIT. RECOVERED TOTAL OF APPROX. 91 BANDS. R/U SLICKLINE UNIT. RIH WITH 4.4" OD IMPRESSION BLOCK TO 8198' WLM. LIB HAD SLIGHT IMPRESSION OF JUNK - NO INDICATION OF TOP OF SLICK STICK. FREEZE PROTECT HOLE BY PUMPING 70 BBL OF DIESEL DOWN THE WELLBORE. MAKE TWO RUNS WITH 2-1/2" OD WIRELINE GRAPPLE TO 8198' WLM - NO RECOVERY. RIH WITH 4.0" OD LIB. IMPRESSION BLOCK SHOW EVIDENCE OF JUNK IN THE HOLE AND NO SBR SLICK STICK. RIH WITH 3-1/2" OD SKIRTED MAGNET TO 8198' WLM. POOH - ONLY RECOVERY WAS A SMALL AMOUNT OF METAL FILLINGS. JUNE 1, 1990 RIH WITH CENTER SPEAR ON SLICKLINE TO A DEPTH OF 8198' WLM AND SET DOWN. POOH - NO RECOVERY. RIH WITH 1.875" OD B SHIFTING TOOL WITH INVERTED ROPE SOCKET IN AN Aq-FEMPT TO WORK INSIDE THE SBR SLICK STICK. UNABLE TO GET PAST 8198' WLM. RIH WITH 5" OD HYDROSTATIC BAILER TO 8198' WLM - NO RECOVERY. RIH WITH 5" OD PUMP BAILER TO 8198' WLM - NO RECOVERY. RIH WITH 2.75" OD TAPERED SWEDGE - UNABLE TO GET PAST 8198' WLM. RIH WITH 2.0" LIB TO 8198' WLM, POOH. IMPRESSION INDICATES EDGES OF METAL BANDING. R/D SLICKLINE UNIT. M/U HALLIBURTON RTTS PKR AND EQUALIZING VALVE. RIH ON 3-1/2" L-80, 9.2#/FT, BTRS TBG WITH 6 GLMS SPACED OUT IN THE STRING. JUNE 2, 1990 CONTINUE TO RIH WITH TEMPORARY GASLIFT STRING ON 3-1/2" BTRS TBG. LAND TBG PUMP 7 BBL Of DIESEL DOWN ANNULUS. UNLAND TBG, SET PKR. LAND TBG. PRESSURE TEST ANNULUS - WOULD NOT HOLD PRESSURE DUE TO ROLLED HANGER SEALS. REPLACE SEALS. RESET PKR. PRESSURE TEST ANNULUS TO 3000 PSIG - OK. PUMP 3 BBL DIESEL DOWN TUBING. BACK OUT LANDING JOINT. N/D BOPE. N/U TREE. RDMO. REMOVE BPV. STATE OF ALASKA 0 ~ ALASKA OIL AND GAS CONSERVATION CO~v,MISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation,~utdown m Pull tubing __ Alter casing __ 2. Name of Op. erator CONOCO INC. 3. Address P.O. BOX 340045, PRUDHOE BAY, AK 99734 4. Location of well at surface 1229' FSL, 2459'FEL,SEC.lO,T13N,R10E,UH. At top of productive interval 1261' FSL, 1422'FWL,SEC.11,T13N,R10E,UN. At effective depth 1247' FSL, 1432' FilL, SEC. 11 ,T13N, RIOE,UH. At total depth 1245' FSL, 1433' F~L, SEC. 11,T13N, RIOE,UH. 12. Present well condition summary Total depth: measured true vertical Stimulate ~ Plugging __ Repair well __ 5. Type of Well: X Development __ Exploratory ~ Stratigraphic ~ Service _~_ 8900 ' feet Plugs (measured) NONE 7311' feet Pedorate ~ Other 6. K~~a~I.(DF or KB) 9. ~r_n~t~m~er/approval number ""'"'-' / APl nu r lo. 50- ~J~¢-20866 11. Fl~l¢~ftljK RTVER Effective depth: measured 8786 ' feet Junk (measured) NONE true vertical 7230 ' feet Casing Length Size Cemented Measured depth Structural Conductor 80' 20" TO SURFACE 115' Surface 2615' 13-3/8" 900 SKS ARCO FONDU Intermediate 750 SKS PERHAFROST'C' 2650' Production 8834' 7" 800 SKS CLASS G 8869' Liner 300 SKS PERHAFROST'C' Perforation depth: measured 8370'-8390' 200 "~4~,_C~.~8~ACK 8566'-8596' ~ue vertical depth 115' 2337' 7145' true vertical 6950'-6970' 7126'-7138' 7146'-7176' Tubing (size, grade, and measured depth) 3-1/2",L-80,9.2#/FT. BTRS. TO 8143' Packers and SSSV (type and measured depth) PACKER - 7" RDH DUAL STRING PACKER 8572' RKB. 2-7/8" OTIS FHS TRSV SCSSV e570' RKB 13. Stimulation or cement squeeze summary ,. Intervals treated (measured) N/A Treatment description including volumes used and final pressure ANNULAI( JUN 0 4 ]9? · .. ' -~,:':ska tjjj feet 14. Prior to well operation Subsequer~t to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1331 650 65 995 1536 312 155 231 Anch0ra~ Tubing Pressure 225 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run .~._ I Daily Report of Well Operations ~ Oil~X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 231 Service Form 10-404 Rev 06/15/88 Title SENIOF~ FOREfffAIV SUBMIT IN DUPLICATE Kuparuk River- North Slope Borough, Alaska Milne Point C No. 2 CONFIDENTIAL (6115'-Kuparuk Oil Sands) MAY 15, 1990 MIRU. OPEN THE SURFACE SAFETY VALVE. R/UW/L UNIT. PUMP 125 BBLS FRESH WATER DOWN THE TBG - O PSIG WHP. FILL BACK SIDE. RIH AND PULL THE G/L VALVE IN GLM #10 @ 8152'. VENTED 600 PSIG OF GAS OUT TBG. R/U HOT OIL TRUCK AND PUMP 100 DEGREE H20 AT 1.5 TO 2 BPM FOR 80 BBLS DOWN TUBING. R/U RIG PUMP ON BACK SIDE AND FILL CASING UNTIL RETURNS! CONTINUE HOT OIL DOWN TBG AND SHUT DOWN RIG PUMP. MONITOR TBG AND CSG = 0 PSIG. MAY 16, 1990 CONTINUE TO FILL BACKSIDE WITH INJECTION WATER USING HOT OIL TRUCK. PUMP DOWN TBG WITH HOT OIL UNIT--NO RETURNS AT 1 BPM. SHUT-IN WELL. MONITOR PRESSURES--BOTH SIDES ON VACUUM BULLHEAD 100 BBL WTR (175 DEGREES) DOWN BACKSIDE @ 2 BPM--HAVE 150 PSI ON TBG. STOP PUMP. ATTEMPT TO INSTALL TWO WAY CHECK VALVE IN TBG--UNABLE TO GET THROUGH MASTER VALVE DUE TO INCORRECT VALVE TIMING REMOVE MASTER VALVE. INSTALL TWO-WAY CHECK VALVE. ND TREE AND NU BOPE. CONSTRUCT A SPACER SPOOL FOR CHOKE LINE. PRESSURE TEST BOPE TO 3000 PSIG--OK. MAY 17, 1990 RETRIEVE TWO WAY VALVE. PUMP 18 BBLS OF WATER DOWN TUBING. POOH 2 STANDS. MAKE UP HALLIBURTON 7" RTTS PKR AND STORM VALVE. RIH ONE STAND AND SET PKR. BACK OFF AT STORM VALVE AND POOH. N/D BOPE, N/U NEW FMC TBG SPOOL ON TOP OF EXISTING CAMERON TBG SPOOL AND N/U BOPE. PRESSURE TEST-OK. RIH AND RETRIEVE RTTS PKR AND STORM VALVE. BLEED OFF GAS BUBBLE ON BOTH THE ANNULUS AND TBG. FILL TBG. VERIFY THAT SCSSV IS OPEN. CONTINUE TO POOH. SLM. MAY 18, 1990 CONTINUE TO POOH WITH GAS LIFT COMPLETION. WITH 104 STANDS OUT~ CIRCULATE 40 BBLS OF METHANOL WATER (25% METHANOL, 75% INJECTION WATER) DOWN THE BACKSIDE. CONTINUE TO POOH. L/D. PBR AND GLMS. P/U, ASSEMBLE AND SERVICE ESP. RUN PUMP IN HOLE ON 3-1/2", 9.2#/FT N-80 BTRS TBG. INSTALL OTIS RDH PKR/SAFETY VALVE. BEGIN PIG TAIL SPLICE FOR PKR. MAY 19, 1990 COMPLETE PKR PIG TAIL SPLICE. CONTINUE TO RIH WITH ESP (17 JTS). SPLICE IN HMG PIGTAIL. SPLICE IN EXTRA CABLE. PUMP 37 BBL OF DIESEL DOWN CSGAND 14 BBLS DOWN TBG FOR FREEZE PROTECTION. R/U. SLICKLINE UNIT. RIH WITH 1.875 "XX" PLUG TO THE "X" NPL (BELOW THE PKR) AT 581/RKB AND SET. PKR USING 3000 PSI TUBING PRESSURE. T/PKR = 577' RK~o PRESSURE TEST PACKER BY PRESSURING UP TO 600 PSI- WOULD NOT HOLD PRESSURE. RETRIEVE X-X PLUG F/581'. REPRESSURE TEST PKR-STILL UNABLE TO HOLD PRESSURE. PREPARE TO MOVE RIG. INSTALL TWO WAY CHECK VALVE IN HMG. NOTE: SCSSV SET AT 550.8' RKB. CIRC SUB SET AT 8056' RKB. TOP OF ESP AT 8094.38' RKB. BTM OF ESP AT 8143.04' RKB. ORIGINAL RKB = 30.21' WITH NEW TBG SPOOL ADDED = 27.79'. MAY 20, 1990 N/D BOPE. MOVE RIG. INSTALL PRODUCTION TREE. RETRIEVE BPV. ANNULAR VENT VALVE POSSIBLY STICKING OPEN. WILL PRODUCE WELL SEVERAL DAYS AND RE-TEST PKR. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION ~"~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Alter casing __ Repair wellL Change approved program ~ BAY= AK 2. Name of Operator CONOC0 INC. 3. Address P.O. ROX 34004~;. PRuDHoF Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Pull tubing "X-- Variance __ Perforate __ Other __ J 5. Type of Well: Development -Z-- Exploratory __ Stratigraphic __ gg73 Service __ Location of well at surface 1229' FSL, 2459' FEL, Sec 10, T13N, At top of productive interval 1261' FSL, 1422' FWL, SEC.11, T13N, At effective depth 1247' FSL. 1432' FWL, SEC.11, T13N, At total depth 1245' FSL, 1433' FWL, Sec 11, T13N, 13. 12. :8900' 7311' 8786' 7230' Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical RIOE, UN RIOE, UN RIOE, UM RIOE, UN Casing Length Size Structural ConductOr 80' 20" Sudace 2,615' 13 - 3/8" Intermediate Production 8834 ' 7" Liner feet feet feet feet . , Plugs (measUred): ' Junk (measured) Pedoration depth: measured 8370'-8390', true vertical 6950'-6970', Tubing (size, grade, and measured depth) 3-1/'2", 6. Datum elevation (DF or KB) KDB 45' MSL 7. Unit or Property name MILNF pnTNT llNTT 8. Well number C-2 ~. Permit number 82-194 10. APl number 5o- 029-20866 11. Field/Pool Kuparuk River Cemented Measured d~pth True vertical depth TO SURFACE 115' 8869' feet , 115' 2337' 7145' 7126 -7138 7146 -7176' '" :' "' '" £',71' ,_ ~ ,~,? ,,,' L-80, 9.2g/FT. BT.RS. T0 8143' goe~ ,~ PackersandSSSV(typeandmeasureddepthPACKER.7,,RDH DUAL STRING PACKER 9572'RKB. 2-7/8" OTIS FMS TRSV SCSSV $570'RKB. ANNUALR VENT VALVE 9570 RKB Attachments X Description summary of proposaY~__ Estimated date for commencing operation Detailed operations program ~ BOP sketch 14. MAY 2R_ lggO 16. If proposa~ was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m,f knowledge. Signed ~ ~'"¢'~ Title SENIOR FORENAN ~ FOR COMMISSION USE ONLY 15. Status of well classification as: Oil)I_ Gas __ Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ..';re, /./L- ORIGINAL SIGNED BY LONNIE C. Appr_ oveo Approved by order of the Commission Return~ed Form 10-403 Rev 06/15/88 ~: Date [Approval NO. ¢~_ ,.~ ~ Commissioner Date ~ lslqo SUBMIT IN ~RIPLICATE Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. LONNIE SMITH STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE'DRIVE ANCHORAGE, AK 99501 DEAR MR. SMITH, CONOCO IS REQUESTING TO CONDUCT WORKOVER OPERATIONS TO PULL THE ELECTRIC SUBMERSIBLE PUMP ON THE C-2 WELL. THE ESP OPERATED FOR THREE DAYS AND THEN FAILED. INDICATIONS SHOW THAT THE PROBLEM IS IN THE DOWNHOLE ELECTRIC SUBMERSIBLE PUMP. FOLLOWING IS THE OPERATIONS PROGRAM WE ARE SUBMITTING FOR YOUR REVIEW AND APPROVAL: LOCK OPEN THE SCSSV AND SSV (FUSE CAP) AND INSTALL A BPV IN THE WELLHEAD. 2. MIRU WORKOVER RIG. 3, N/D WELLHEAD TREE AND N/U AND PRESSURE TEST BOP's TO 3000 PSIG. m UNSEAT PACKER AND KILL WELL WITH 8.4 PPG SOURCE WATER (CALCULATED KILL FLUID DENSITY IS 7.85 PPG). 5. POOH WITH ELECTRIC SUBMERSIBLE PUMP AND INSPECT. THE PROCEDURE AT THIS POINT WILL BE DETERMINED BY WHAT WE FIND TO BE THE CAUSE OF THE PUMP FAILURE; HOWEVER, CONOCO WILL NOTIFY AOGCC OF ANY DEVIATION FROM THE FOLLOWING OPERATIONS. 7. RIH W/ ELECTRIC SUBMERSIBLE PUMP, PACKER, AND SCSSV -- TEST SCSSV TO 5000 PSIG. m N/D BOP's, INSTALL A DOUBLE CHECK VALVE, N/U AND TEST WELLHEAD TREE TO 5000 PSIG, AND MOVE RIG OFF WELL. 9. RETURN THE WELL TO PRODUCTION. EOR RESPECTFULLY, J.D. POLYA DRILLING FOREMAN ALASKA OIL AND GAS CONSERVATION Uppe~ Ke11~ L~er Kelly 1411 Iht(d, BOP /'~ Chokl mnnlfold Number flnnge~ ~ . ,, AdJustable OhO~e~ ~. Xyde&ultos11~ ope(~ied choke ~ TII~ prellurl ,_ , ----_-- Test pressure ....... - Test prosturl :__. ~~--- Al, .. _- ...... - ~ " , . - -_ ~_~ _ -. _ , CEIVED Oil & Gas Cons. Anchora~ Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL FOR WHICH I RECIEVED VERBAL APPROVAL FROM YOU ON 5/14/90. WE ARE CONVERTING THE PRODUCTION TECHNIQUE ON THE C-2 FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESP_ECTFULLY, 4- D. P~LYA DRILLING FOREMAN STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well ~ Change approved program __ Pull tubing -X- Variance __ J ' 2. Name of Operator 5. Type of Well: CONOCO INC Development-X- ' Exploratory __ 3. Address Stratigraphic_ ... P.O. BOX 340045, PRUDHOE BAY, .~.K 9973. Service__ 4. Location of well at surface Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate __ Other --X- 6. Datum elevation (DF or KB) KDB 52' 7. Unit or Property name M_TI_NE POTNT I_IN_TT 8. Well number feet 1229' FSL, 2459' FEL, Sec 10, T13N, RiOE, UM At top of productive interval At effective depth At total depth 1245' FSL, 1433' FWL, Sec 11, T13N, RIOE, UM 12. Present well condition summary Total depth: meaS'ured 8900 ' feet Plugs (measured) true vertical feet 7311' Effective depth: measured 8786 ' feet Junk (measured) true vertical feet 7230' Casing Length Size Cemented Structural Conductor 80' 20" N/A Sudace 2,615' 13-3/8" Intermediate Production 8834' 7" Liner Perforation depth:measured 8370'-8390' 8546'-8558' 8566'-8596 true vertical 6950, -6970', Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 BUTT C-2 9. Permit number 82-194 10. APl number 50-- 029-20866 11. Field/Pool Kuparuk River' Measured depth True vertical depth 115' 2650' 115' 2337' 8869' 7126'-7138', 7146'-7176' 7145' .0il .& Gas Cons. Comrnissm~ Packers and SSSV (type and measured depth)BAKER FML @8195'-BAKER SAB @8417'-CAMC0 TRDP SCSSV @1938' 13. Attachments X Description summary of proposalX__ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation MAV 1~ lqqf'l 16. Ii i~:(~po~s~.l'wa.~,~r-bally approved NIV]a~of ~¢~)o~ ! MAY.J3, 1990.1 ua[e approveo I 15. Status of well classification as: Oil-X-- Service 17. I hereby certify,t,hat the f~regoing is true and correct to the best of my knowledge. Signed ~'?, ~~~.,~ Title (;FN T dl~ FrII~ FM/~N - : FOR COMMfS'SION USEON LY Gas __ Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ /---./¢- /--/- Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED ¢~ LONNIE C. SMITH Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner ~ Re,tu ~ ~'-¢'-:~ [Approval No. Date ~2~qO SUBMIT IN TRIPLICATE NPU KUPRRUK RESERVOIR PROCEDURE FOR CONVERSION OF BRS LIFT WELLS TO ELECTRIC SUBMERSIBLE PUMP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) C-2 7151 2732 1194 7.85 C-3 7017 2570 1548 7.54 C-7 7192 2370 1240 6.84 C-14 7050 3580 1432 10.3 C-16 7050 3600 1225 10.5 (NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. 8.33 PPG SOURCE WATER WILL BE USED AS KILL FLUID FOR C-2, C-3, AND C-7. C-14 AND C-16 WILL BE KILLED WITH 10.3 AND 10.5 PPG NABR BRINES, RESPECTIVELY. CURRENTLY, 450 BBLS OF 10.3 PPG AND 450 BBLS OF 10.5 PPG NABR BRINE ARE BEING STORED IN TWO 500 BBL TIGER TANKS ON C PAD. THERE IS ENOUGH DRY BULK BEING STORED AT MILNE POINT ON C PAD TO MIX AN ADDITIONAL 600 BBLS OF 10.3 PPG AND 600 BBLS OF 10.5 PPG NABR IN THE EVENT THAT WE ARE WORKING ON EITHER C-14 OR C-16 DURING BREAKUP. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES AT BUT NOT LESS THAN 500 FT. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NE×T WELL. /o MILNE P?'~'T UNIT C-2 ACTUAL COMPLETION SKETCH RE-COMPLETED ON 7-21-85 FMC TUBING HANGER u/ 3 ~/t' 'H' BPV PROFILE NOTES: All meiouremlnta Itl from KDB of Kabor$ R,g 2. KDB - SL = 52' ~. KDB - GL : 4. MIX. Ingle 5~°~4100' MD ~.~OP 500' 6.S-lyDe hole T.Ml~ angle 2.0~ ~ TD FMC ~ 1/8' APl ~000~ tree w~h 3 1/2' 8 rd. troetoo connoction Mi~ restriction Il 8456'--Otis 'X*N' Nipple w/2.75' no-~ 10. APl NO. 50- 029 - 20866 cement lnformltlon luppllld ----- 3 I/?', 9.2W L-BO bu.rees fub,ng (2.~92' ID, 2 867' drill) ..... 195B' CAMCO TRDP- IAENC SCSSV (Z.BI2' ID) ---- 2350 GLV *~ '\ 3~,09' GLV~ ~. \ .. \ ----- 5760' GLM /CAIdCO 3 ~/Z" KBUG GLM - -- 6760' GLM 7236' GLM -- 7696' GLM -- 8152' GLM 816B' BoJ~er Seat Bore Recepfacle v/2.BI~*" X -profile 12 SPF, I~'O° phasing, 5' guns ( Fr~m DIL-12/7/82) -- BI95' BOker'FHL' RetTmvoble Packet (5.97" OD, ?.987' ID) B259' CAMCO 'W*I' Selective N,pple w/2.812' profile B370 - B390' lad 6950 - 6970' TVD --B~'93' CAMCO 'MMG~Z' Gel, Lift Mandrel {GLM) s ?.92' lO, 15' valvll ----8330' GLM 8546 - 855B* MD ?126'- 713B' TVD --8366' BIo$~doin'll (4Z3' OD, ':",.O"ID) tolallength Z'9~2' B56~ - B596' MD 7146- 7176' TVD B416' Baklt K- onchM leal Olllmbl! 8417' Baker SA B ~ermonenf Packer I/mllloul e,ten$ion (OD · 5 697,' ID ; '5.25") B456'Olil 'X'N° N~pple ~/2 el'profile ~ --B488' Vonn Mechanical ~ PrlelUra AclUOlld Tubing Relapse 8495' Tubing Tall (8494' WLM) B681'Top of Fish-- Spin! 5" Vann Pltforotmg Gun ( 12 SPF), comsst~ng Of p~e~uutt actuated tubing releall, plrfolafad tub, X - O, I tub,Pa, 2 3/I" tub, 3 %' fir,ha heap, guile, ~ bull plug 8786' PBTD ( Cos,ha mea~Jtement ) 8869' 7" 29~ L'80 BTRS (6.184" ID, 6,059" drift) 11 Fu~n N~ME: Milne Point CAS~: 7" 29 LB L-80 BTC T~: 3-1/2" 9.2 LB BTC x 2-7/8" 6.4 LB ~;3 8~D x 2-3/8" 4.6 _ Q~ NO: 432/1001/00/90 ~: Jar,~y 12, 1990 (907) 344-4144 ~c~ I.D. O.D. L~,mm 1. 3-1/2" 9.2 lb BTC T~bi~ 2.99" 4.5" 2. Electric Cable - Size #4 3. 1/4" Stainle~__~ Steel C~,trol .25" 600' Line. 0.049" Wall x 600t ~ 316 Material (P/N 22 SXX 31060) 4. ~a.~Or - 3-1/2" 9.2 lb BTC x 2.44" 4.5" .8' 2-7/8" EU 8Rd BxP L-80 5. 2-7/8" 2.313" Otis "FM)g' 2.313" 4.76" 7.0' Series 10 Tubing ]%etrievable Flapper Closure. ~28 Service. Meets NA~ MR-01-75, 2-7/8" 6.4 lb ~3 8~dBxP. Max. (P/N 778 FMX 23111-E) 6. 2-7/8" 6.4 LB ~3 8]~d 2.44" 3.668" 6.0' Pu~ Joint w/cou~ir~ L-so 7. (~binaticn ODupling 2.44" 3.668" .6' 2-7/8" ~J 8 Bd x 2-3/8" ~3 8 Bd B;cB P-105 8. BIW Power Cable Feed ~hru For No. 4 Electric Cable 50 AMP, 2400 Volts Electric Cable Im_ngth: 20' Above Upper Plu~ Oonnector/ 20' Below Lower Feed ~]%ru (Bef: P/N 12 O0 755) 9. Tubing Seal Sub ~ptor 2"-UN-2 x 2-3/8" ~3 8~d BxP (P/N 120 6637) 10. Otis An~ar Vent Valve 3,000 psi W.P. Setting Depth 500', 2-3/8" ~3 8Rd BxP (P/N 78 A%~S 2000) 11. 2-3/8" 4.6 lb ~3 8 Rd Pup Joint P-105 42' 1.83" 3.09" 2.61' Eoc. 3.69" 1.99" 3.06" 6.0 ' 1.96" 3.11" 1.5' -- 10 11 12 ~ ~): 432/1Om-%/00/90 ~: Jamm~y ' ".990 7" 26-32 lb 2-3/8" ~3 8Bd Box x Pin - Pr{ma~y and (P/N /2 RE~ 7003) (P/N /2 R 71~) b. ~Sbe~ ~ Pins Q~Y (2) (P/N /2 P 2~) ¢. L~bor to Package for Cold T~=~=~ (7O Center Fan, er Type B~i.d Dir~ 13. 2-3/8" 4.6 lb ~J 8Bd PUp Joint W/Ccuplin~ P-105 Nipple W/Cc:uplin~ 1~110 (Nipple P/N 11 X 18700-A "Blank" Thread for 2-3/8" ~J 8 Bd PxP)* a. 2-3/8" 4.6 lb ~3 8Bd cou~lir~ ~1o5 15. 2-3/8" 4.6 lb ]~J 8 ~ ~ joint w/cou~].ing P--lO5 16. ~r~nr 2-3/8" ~J x 3-1/2" BT~ BxP 17. 18. 3-1/2" 9.2 lb BTC TUbing Ccnooo Supplied otis ciruulatin~ Ball at 1,000 psi Diff. Pressure. (P/N /2 FID 80 "Blank" ~ Oor~ecti~ for 3-1/2" BTC BxB) * One (1) 3-1/2" 9.2 lb BTC Joi~t of Tubir~ or Pup Joint~ Supplied 20. Electric ~ible Pump 1.94" 1.94" Sec. O.D, ~ 5.95" 7.1 ' 1.99" 3.06" 2.0 ' 1.875" 3.06" 1.0 ' 3.06" 1.99" 3.06" 4.0' 1.97 3.76" .6 ' 2.99" 4.5" 1.5" 4.5" .80 ' 2.99" 4.5" TU/~L ~ F.O.B. PRD/~DE BAY, AIASKA (Item /2) to Har~3er type and threadin9' of Items 14 ~ 18. Telecopy No. (907) 276-7542 January 14, 1987 Mr. T. R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter: The enclosed Administrative Approval (AA) No. 173.8 dated' December 30, 1986 is a corrected copy that should replace the Administrative Approval No. 173.1, also dated December 30, 1986, which was recently sent to you. Please destroy all copies of AA No. 173.I of that date. Sorry for this inconvenience, and please call me at 279-1433 should you have any questions. Lonnie C. Smith Commissioner Enclosure LCS: j ob December 30, 1986 Telecopy No. (907) 276-7542 ADMINISTRATIVE APPROVAL.NO. 173.8 Re: Exemptions from Conservation Order No. 17.3, Rule 9(a), requiring production surveys. Mr. T, R. Painter Division Manager . Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter: We have received your letter of December 12, 1986, in which you requested exemptions to the resuirements of Conservation Order No. 173, Rule 9(a), for Conoco s Mtlne Point Unit wells B-10, C-i, C-2 and C-7. Due to impending shutdown of production and injection operations at Milne Point Unit (MPU), the Commission agrees that production profiles at this point would not provide data essential for monitoring reservoir depletion. Therefore, the production surveys required by Rule 9(a) of Conservation Order No. 173 for MPU wells B-10, C-l, C-2 _and C-7 are suspended. When production operations resume at MPU, then the production surveys for these wells will be required within twelve (12) months after regular production, begins. Sincerely, ~ Lonnie C. Smith Commissioner BY ORDER OF THE COMMISSION jo/3.AA173.8 Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Milne Point. ACTIVE: -. B-3, B-4A, B-6, B-9, B-10, B-ii, B-13, B-15, B-16, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-!7, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive wate~ injection wells in the Milne Point Unit. ~ ~ ~ [ ~-! ~ ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-11, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. %he E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, -~-- STATE OF ALASKA ALASi 'OIL AND GAS CONSERVATION COMI~ 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon El... Suspend ~ Operation Shutdown Re-enter suspended well Fi Alter casing ~ Time extension ,% Change approved program '%.' Plugging ~ Stimulate [] Pull tubing ~ Amend order ~ Perforate ',-J Other 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Add~S~l C Street Ste 200, Anchorage Alaska 99503 6. U ni.t.9~ Prop~erty name , . , £vzl±ne rolnE UnlE 4. Location of well at surface 1229' FSL, 2459' FEL, Sec. At top of productive interval 4019' FNL, 3858' FEL, Sec. At effective depth N/A At ttt2J4~lCPtC]SL, 1433' :~-~T_,, Sec. 10, T13N, R10E, U.M. 11, T13N, R10E, U.M. 11, T13N, R10E, U.M. 7. Well number C-2 8. Permit number 82-194 9. APl number 50-- 029-20866 10..POO~uparuk River 11. Present well condition summary Total depth: measured 8900 true vertical 7480 feet feet Plugs (measured) Effective depth: measured N/A feet true vertical feet Junk (measured) Casing Length Size Cemented Structural Conductor 80' 16" To Surface Surface 2614' 13 3/8" 538 bbls Intermediate Production 8835 ' 7" 164 bbls Liner Perforation depth: measure~l 8370'-8390'; 8546'-8558'; true vertical 6950'-6970'; 7126'-7138' Tubing (size, grade and measured depth) 3½", L-80, 8495' Measured depth 115' 2650' True Vertical depth 115' 2338' 8566'-8596' 8869' 7449' · Packers and SSSV (type and measured~Sp~h)SCSSV',@ 1938'; Ret. Pkr. @ 8195'; Perm. Pkr. @ 8417' 12.Attachments Description summary of proposal ;~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I herebry-c~ftify that the foregoing is true and correct to the best of my knowledge Signed .~,.. t~, Title Sr_ Productien Engi~.,e=_r Commission Use Only Conditions of approval 0£1~ Approved by AY /§NNIE Form 10-403 Rev 12-1-85 Notify commission so representative may witness ~, Plug integrity ..~ BOP Test ~ Location clearance ~pproved Returned Approval No. 70/¢ Commissioner by order of the comm ss o. O ,e Submit in triplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 -/ Tom Peinter Division Manager December 12, 1986 FILE: Mr. Chatterton, Chairman Alaska~Oil and Gas Conservation Commission 3001Pdrcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: COnservation Order No. 173 Rule 9 Conoco requests exemption from Conservation Order No. 173 Rule 9 for Milne Point Unit wells B-10, C-l, C-2, and C-7. These wells are currently being supported by water injection but production and offset injection will be suspended in early 1987. Considering the circumstances, production profiles in these wells can not be justified. If you should have any questions please contact Don Girdler at 564-7637. Y~~T ~/R. Painter Division Manager DRG/vv 500.~4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 82-194 3'Addre~201C Street,-Suite 200, Anchorage, Alaska 99503 8. APINumber 50-- 029-20866 4. Location of Well 1229' FSL, 2459' FEL, Sec. 10, T13N, RIOE, U.H. 5. Elevat~o~ in f~t (,nd,cate KB, DF, etc.) 9. Unit or Lease Name Milne Point Unit 10. Well Number C-2 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought_on as an oil producing well on 12-3-85, and its suspended status should be removed. 14. I hereby certify that the foregoing ,s true and corre//ct to the best of my knowledge. Sign - Title The space be]~/.~ for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate *' N SIM LAGOON MILN[ PT. UNIT " ; I' · - SCALE IN MILES lOCATION IN SECTION STATE PLANE CO-ORDS. FROMS. t. INIF F~O~ E. UNE 1168' 2?.56' 1:>29' 2459' C - 3 J 1395'. 2326' 6 ,0Z9 , 677.42 I'~ 4 4' .--2494' 557,963.42 __J 551' 2254' 6 ,0:>8 ,8.54-07 558,211 .74 C- 6 j 665' 2289' 6 ,028,947.80 558 , 17`5.18 C - 7 J 1009' 2396' 6 ,029 ,:>90. 40 .558 , 065.29 780' "Z32`5' c-si 1114' 2428' 894' 2360' NORTHINGS 6,029,450.20 EASTINGS 558,20~..57 6,029,`509.93 I `5`57,999.98 `5`58 ,I$1 .08 6,029,624.27 J 6 , 029,062.00 `558,138.49 6,029 ~ 6,029, 176.48 5`58 , 101.82 GEODETIC LATITUDE 70~29' 27.86 8"N. ~"29' 2~. ~.7,",. m°:,9' zo. · o°29' z~. ~a".. ~°29' 2~. 807"N 70029, 26. ~0029' 24. 055~. ~°29' 27.340"N. 70° 29' 25 .I 8 4 CERTIFICATE OF SURVEYOR : ~--~,.~_ ~.'J' ..-~j.~ '".~_~ I ~[R[BY CERTIFY THAT .I ~M PROPERL~ ~ ~2 ~" ~".:~"~ ' ~, '~ ~-~ ~T SUY~VlSlOri, k'ID THAT ~LL W ~ CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT STATE PLANE CO.ORDINATES AR[ ,'~;NE 4. ALL GEODETIC POSITIONS ARE BASED N.A.D. 19Z7. OFFSETS TO SECTION LINES ARE COMPUTED BASED-ON PROTRACTED VALUES OF TI~E SECTION CORNER POSITIONS. LO~ATED WITHIN SE:CT. 10, T 13 N, RIOE, LLM.,AK. POSITION J LONGITUDE 0ATE 149° 31'27.056"W' J 6. 1,85 149° 51'3~0:~4"W. J 10.30,84 149°31' 29.137"W. J " 149° 31' ~4.08~"W. 149° 31' 26.957."W. I 3.18,85 149° 31' 28.007"W. J 149° 31' 31. 162: "W. j 149°31' 29.060"W. J'- 149°~i' ~2.123"W. I 6. I, 85 14g°31' 30. II3"W. J ' d.B.S. J.B-S. · FIELD BOOK 22 -85 24 - 84 · mm Cons.*'/u%mmissio 'C' PA D AS- BUILT WELL LOCATION Su~'ve/md for CONOCO SCALE : j SHEET : I' · 400' J I O¢ 2 CO~a'-' E N TS : Page 1 of 2 .CONOCO, INC SCHLUMBERGER OFFSHORE SERVICES 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Attenticn' M~ke Bradshaw Gentlemen: Enc!osed are_3 BL_prints of the Compar, y _~ONOCO Fie!d MiLNE POINT Division of Schlumberger Limited HOUSTON. TEXAS 77001 10/16/85 PL~.~sr KI'I~L.Y' 'TO ICHL. U ltKAG i:11 O~IHOI~ Pouch 340069 Prudhoe Bay, AK 99734 ATTN: Marcia Sherburne x~ ~PL, RUN ONE, 8/17/85 ~%POST FI{AC TEMP LOG , RUN ONE, 8/18/85 · Well C-2 , CounW NORTH SLOPE Additional prints are being sent !~_e_!L__~_cast & Alaska Division ~90 w=~ Gour~ ~uite 284 Ventura, CA 93003 .ATTN: Phil Salvador -11_ 1.: 1 BL prints & 2RF Chevron USA INC iP 0 BOX 107839 Anchorage, Alaska 99510 ATTN: J. L. Weaver I BL mr,nls & iRE ~,3.us~s_~ T~-< .77252 ATTN: Gerald ~el % George Lamb P 0 Box ~2~7 ~ca Cl~y, OK 74603 ATTN: H. E. Giitiland/6356RW & 1RF ~k!aaka Oil & Gas ~/~nservanion Commission 'J/iQi Porcupine Drive Anchorage: Alaska qqSOl The film is RE~RNED TO CONOCO-- We appreciate the privilege of serving you. 1 BL prints & IiLF Chevron USA, INC _60Ol Bellin~er Canyon Rd _San Ramone, CA 94583 % I.n-~}i~ Klnn~kv ?_Z__]~Lprints & iRF Ghamplin Petroleum Company 0 Box 1257 Englewood, CO 80150 ATTN: James T. Laws Jeff DeJarnett __Z_gL~rints & 1RF Reading & Bates Petroleum Co 3200 Mid Continent Tower Tulsa~ OK 74103 ATTN: C_R_ Roery: Jr Charles R. Merriman OISTR ICT MANAGER Page 2 of 2 CONOCO, INC 3201 "C" Street Anchorage, Alaska 99503 Attention: SCHLUMBERGER OFFSHORE SERVICES C-.enfiemen: FJ~c]osed are prints of the Cort~,oany CD_NOC.~; TNC Fie!d MTIJ~E PC~!NT Additional prints .are being sent to: ! BL prints & I~~ C±:ies Service 0il & Gas Cord P "3 Box 939 Bakersfield, CA 93302 ATTN: Nell Buttram % .Jim Quinn A Division of Schlumberger Limited HOUSTON. TEXAS 77001 10/16/85 Pouch 340069 ' Prudhoe Bay, A~ 99734 ATTN: Marcia Sherburne PL, RUN ONE, 8/17/85 POST FI{AC TEMP LOG, RUN ONE, 8/18/85 .Well C~2 " ,Coun~ NOR_TR sLnPg ~;t(:te Al. ARImA prints ~',rfnts prints ~.prfnts prints prints prints The film is We appreciate the privilege of serving you. k ECEi\/ED Very truly yours, SCHLUMBERGER OFFSHORE SERV!CE~ DISTRICT MANAGF~,~ STATE Or: ALASKA ALASKA ("'-". AND GAS CONSERVATION CC '-"'.AISSION REPORT DRILLING AND WORI OVER OPERATIONS . Drilling well [] Workover operation 2. Name of operator Conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of Well at surface 1229' FSL, 2459' FEL, Sec. 10., T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 47434 7. Permit No. 82-194 8. APl Number 50- 029-20866 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 2 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Pull tbg. Run in hole w/DR plug. Set plug in packer. Shear out. POOH. MU perf. & DST assembly. Depth at end of month: 8415'MD. Footage drilled: 0'. 13. Casing or liner run and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run CCL-GR RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data Alaska 0JJ & Gas Cons. C0~rrlJssJ0rl - Anchorage ?erfed tbg. @ 8370' w/4 spf. POOH. Attempt to clrc. Could not clrc. Reperf. th§. at 8366' ~/4 spf. Circ. ~ell ~/10.2 b~i~e. Perfed csg. f/8370' to 8390' w/Geovann, 12 jspf, 5" hollow carrier, DP charges. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA( _AND GAS CONSERVATION CC; ¢IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 82-194 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-20866 4. Location of Well SURFACE: 1229' FSL, 2459' FEL, Sec. 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number C-2 11. Field and Pool Kuparuk Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-2 well is currently perforated and completed in the Lower Kuparuk Formations (L.K. (1) and L.K. (2)). We now propose to move on the Roll'n IV completion rig to recomplete the well as a single selective. The Lower Kuparuk Formations would be the primary sands while the Middle Kuparuk (to be perforated 8371'-8387' based on DIL 12-7-82) will be the selective. After recompleting the well the Lower Kuparuk Formations will be fracture stimulated. The well will then be temporarily suspended pending the installation of the production facilities. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 14. I here~b_y~certify that the foregoing is true and correct to the best of my knowledge. Signed ~b~_~,~ ~, Title The space below for Commission use Date 6-11-85 Conditions of Approval, if any: ~¥ l~-f~!l[ C. $liltfl~ By Order of Approved by COMMISSIONER the Commission Approved Returr~d Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MILNE POINT UNIT C NO. 2 CASING DIAGRAM OPERATOR' CONOCO, INC. SURFACE LOCATION: 1229' FSL, 2459' FEL, SIO, TI,~N, RIOE, U. BOTTOMHOLE LOCATION: 1245' FSL, SPUD DATE: II/22/82 GROUND LEVEL EL.: 17' I~SL KELLY BUSHING EL.: 52' 14SL · OE~T. (,K~ I ! ! / ~s.n~: ' J ! J l---;~', ~41tfIt, GR. 8 P~P---'~0"-~ 9& lb/fo, ~rade B, PELP, 0'-+_I15' i i I I3-3/P,", 72 lb/ft, L-80, BTRS, 0'-2650' I I ~,~ 7", 29 lb/ft, I.-80, BTRS, 0'-8869' I I ' E~:<ternal Casing Packers: I I A 7" Lynes external casing packer is set at the ! laN', R il/Il, - ,L 80 I~RS Cement- Primary i / iq with 750 sks. (712.5 ft ) of Permafrost type I ~l~:~ / C. 3 I I 7" - First stage - 800 sks. (920 ft ) class G Ilia, ~~t 1~ ~F ~ w/l% CFR-2, 0.3% Halad 9, 5% KC1. 11 bbl of ~,4'~ % ~! I,- -I cement followed the top pluR. 3 Z6~' ' 'l I * ? ~ ~ s ~ · Ft0~T S~ IZS ~[UI Permafros~ type C followed by 220 bbls. of Arctic .,, I/~ ~-'"~" ~J ' Pack. ' S~Q~ IS ~ F~LQ~S: Production $~', $~-$'~ 8566'-8596', 12 JSPF, 5" Scalloped Vanngun 8S11' 1445' IS04' ~ IS46' ~. 15~' "-1 L-BO, ~.J Il/fl, ITRC OEVELOPEO AT A O[PTH OF 4100~ 'WITH ANARGLE & 0~1~0II OF ~e 15', S BOO E 8546'-8558', 12 JSPF. 5" Scalloped Vanngun Well Test Results: Test Intv. BOPD No Date Form. (°API) BIFPD MCFPD Pwh Pwf Pe I 12/17/82 8546'-58' 600 0 198 125 2375 3557 LK-I (24.5°) 8566'-96' LK-2 RECEIVED J U N 2 0 .!.,,o85 Alaska Oil & Gas Cons. Commission Anch. orage The projected hole angle and direction at total depth is: 2°, S 25° E. ORIGINAl.: dBF, 5/85 RE.¥ISJONS: MILNE POINT UNIT C NO. 2 - COMPLETION DIAGRAM --': ' ~ -~-~: -~: OPERATOR :' CONOCO,'INC2 -- ~ · - '~ SURFACE LOCATION: 1229'FSL, 2_459'FEL, SEC IO,TI3N, R IOE, U.M. BOTTOMHOLE LOCATION: 12_45' FSL, 1435'FWL,SECI I,TI3N,RIOE, U.M. RIG K.B. TO THE TOP OF THE TUBING HANGER = :30.21' DESCRIPTION LENGTH 0 D DEPTH (RKB) 30 21'/~'-~'~1~-- CAMERON' i ~:::>~ I-I~ 3 I/2"TUBING HANGER W/BPV [~~1~ DUAL ENCAPSULATED SAFETY VALVE CONTROL L,NE ..I-2,60' -- ~ 7",ZgL.B/F'_T, L-80 8TRS CASING -*-8839' 7.656" 5 I/Z",9.ZLB/FT, L-80, BTRS TUBING ZII4' :3.90" 2144' _ CAMCO "KBUG" GAS LIFT MANDREL 6.:33' 5.31:3" 2151' ~ :5 I/2"~9.2LB/FT, BTRS TUBING 29.98' :3.90" 2181' CAMCO TRDP SAFETY VALVE W/FLOW COUPLINGS (~/-HXS 1272; OPEN et 1850 PSI, CLOSEot 1600PSI) 19.65' 5.9:37" 2200' 2:300' ~ :3 I/2", 9.2 LB/FT, L-80, BTRS TUBING 6102.57' $.90" 8303'~ --J Q~-- ~ RADIOACTIVE MARKER N/A N/A ~ $ I/2"t 9.2LB/FT, L-80, BTRS TUBING 86.4:3' 3.90" BAKER "EXTRA LONG" SBR W/2.81" "X" PROFILE 8416' 8417" K-22 ANCHOR TUBING SEAL NIPPLE BAKER "SAB" PERMANENT PACKER 5.5" O.D. MILL-OUT EXTENSION ~5"z :5 I/2" BTRS CROSS-OVER ~ :3 I/2'°, 9.2 LB/FT, L- 80, BTRS TUB1NG 8456' 8457' ~ OTIS "XN" NIPPInE W/2.81" PROF LE AND 2.75" NO-GO WITH OTIS "PXN PLUG IN PLACE. ~ :5 I/2"~ 9.2 LB/FT, L - 80, BTRS TUBING 8487'~ 8488' $ I/2" BTRS x :5 I/2" 8RD RUE CROSS-OVER 8489' ~ :5 I/2" VANNTAGE MECHANICAL TUBING RELEASE 8494' ~ :3 I/2" RUE 8RD TUBING (PUP JOINT) 8546'~ ~ 3 I/2" PRESSURE ACTUATED TUBING RELEASE 8558' " 8566' '~ PERFORATIONS (LOWER KUPARUK) 8596' - 8681'~ / :5 I/2" PRESSURE ACTUATED TUBING RELEASE 1.0' 868~' 0 / 3 I/2" EUE SRO PERFORATED SUB 10.05' 8693 ! :5 I/2" EUE 8RD x 2:3/8" EUE 8RD CROSS-OVER 0.8:5' 2:5/8" EUE 8RD TUBING 30,47' 872:52 8731'. ~ 2:5/8" EUE 8RD SUB W/8' FIRING HEAD EXT. ~ 1.56" NO-GO 8.0' 8733'- VANNTAGE 3 3/8" O.D. FIRING HEAD 1.59' SPENT 5" VANN PERFORATING GUNS (12 JSPF) ?0.0' 12' LOADED - 8' BLANK -- :30' LOADED 8783'. 5"O.D. BULL PLUG 3.13' 8786'~ ~,~ B 8~ W STAB-IN FLOAT COLLAR 8869'~ ,~ ,<~ <3 o <3 ~:~ ,k, BP, W FLOAT SHOE 8900' ) o ~ ~ z~°,O o< ' TOTAL DEPTH · NOTE: AN UNKNOWN RESTRICTION WAS ENCOUNTERED INSIDE THE :3 I/2" TUBING AT A DEPTH OF 4060~ THIS RESTRICTION WAS ENCOUNTERED WHILE ATTEMPTING TO RUN A LOCKING MANOREL FOR PRODUCTION TEST No. 1(12/17/82). TIGHT SPOTS WERE ALSO SEEN ON 4/27/83 et THE SSSV (2181') AND 4060' WHILE RUNNING A "P×N" PLUG. RECEIVED ORIGINAL: JBF, 5-85 REVISIONS: JUN 2 0 1 85 Alaska Oil & Gas Cons. Commission 6.184" 2.992" 2.875" 2.992" 2.812" 2.992" 2.992" 26.27' 5.75" I. lO' 4.00" 4.6:5' 5.697" :5.25" 5.64' 4.50" 4.00" O. 58' 5. 00" 3,00" 28.79' :5.90" 2.992" 1.30' 3.90" N/A 29.98' :5.90" 2.992" 0.58' 4.50" 2.992" 1.44' 4.575" 2.75" 4.07' 3'90" 2.992" 1.51' 4.20" 3.50" 12'+ :30' = 42' TOTAL unoc6)_ . Conoco Inc. November 6, 1984 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-I, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-I, L-I, M-iA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questJ, ons. Yours very truly,, / anager of Alaskan Operations JTD/ks Attachments RECEIVED NOV 0 91984 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA .- ALASK. )IL'ANDGASCONSERVATIONL MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 'COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 81-194 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-20866 4. Location of Well 1229' FSL, 2459' FEL, Section 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47437 12. 9. Unit or Lease Name MiJ.ne Point Unit 10. Well Number Milne Point C-2 11. Field and Pool Kuparuk River Field Kuparuk R~ver Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] ,Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. ' Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will be utilized in the Phase I development of the Milne Point Unit. Work to re-activate this well will begin prior to production in .early 1986. 14. I hereby~~,goiz aLco~the best of my knowledge. Manager of Alaskan Operations Signed ~___//J_~//~¢¢' ! '"'~...~ ¢'~.,~',~'V~~ Title The spac¢/w for Commission us~ ~" Condit~of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H. D. Haley Manager of Alaskan Operations October 17, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-i, B-2, B-3, B-4A, C-I, C-2, C-3, C-4, D-l, and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells, and Conoco will be contacting one of your representatives to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #I and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. H. D. Haley Manager of Alaskan Operations JTD/kp cc: A. E. Hastings, Anchorage ~-.., STATE OF ALASKA '-~, ALASK/-. ILAND GAS CONSERVATION C' AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 82-194 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20866 4. Location of Well 1229' FSL, 2459' 9. Unit or Lease Name Milne Point Unit FEL, Section 10, T13N, RIOE, U.M. lO. Wel~Number Milne Point C-2 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk Ri ver P001 ADL 47434 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other )~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14. I hereby cejAfl'r)~that the foregoing is true and correct to the best of my knowledge. Signed '-,~_~//~~-.~-.-,~' ~ T it,e Manager of Alaskan Operations The spac~'be~'w for'Commission use H. D. Hal ey Conditions of Approval, if any: Approved by. IIRIGilIAI. SIGilED ~Y LONHIE C. SMITH Date Approved Copy Returned / o ~ ~ o ~o°~ By Order of COMMISSIONER the Commission 10.-!9-83 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska September 108A:Jll -'~ ALAS~.A OiL AND GAS CONSERVATION. COM~-~ISSIQ~ TO: C.,. ~.. -~.' '~~tt. erton DATE: THRU: ~nnie C. Smith ? ~3 c~i~ ~io~er TELEPHONE NO: Harold R. Hawkins Petroleum.: Inspector ?/?'~;'?" SU BJ ECT: FROM: 2, 1983 Cleanup Inspection For Extension of Suspended_ Status, . Conoco, Milne Point C-2, Surf. Loc. 4,051' ~TL, 2,449' FEL, Sec. 10, T13N,R10~:,U~ Permit No. 82-194. Wednesday, August 17¢ 1983: I left Conoco's ~ilne Point C-l, subject of another report to Conoco's ~2ilne Point C-2 Well. I inspected ~ilne Point C-2 and found all requirements of A.O.G.C.C. regulations were met for extension of suspension. I filled out an A.O.G.C.C. report which is attached. In summary, I inspected Conoco's Milne Point C-2 ~.~ell. all re~_irements of A.O.C.C.C. regulations were met. approval of extension of suspension. I found I re c c~-~nd Attachments 02-001AIRev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Ope ra tor .... ~..~/~ ~ ~ Addre s s Surface Location of Well Date Suspended Permit No._~.~2- Sec. ~6, T j? /J , RID z= ., ..t) M. Unit' or Lease Name ~/f~ /~g~/'- Well No. _~--__-~ __ Field & Pool Condition of Pad _~D~._~9 _ Condition of Pits ~._~) ~9/D . Well head - Ail outlets plugged Well sign - Attached to well~ Atta~che. d t,o..welt (guar~d.) Attached to . ~ Ye s No No Information correct Cellar - Opened Yes Ye s capped WaterWell .- Pl.ugged off No No No Ope n No Rat Hole Open Yes No Fil led Yes No Exp la na ti on Photographs taken to verify above condition~ Ye~s~ No . ¢ ~-- ~o_~.,~,..".~.~A.D _~--... ,'~ Exp la na ton Work to be done to be acceptable This well and lOcation is (unacceptable) to be classi ied as suspended for the period of '~~ 19_~ thru /'~2' _/~_ 19 ~'/ Inspected by: ...... ~' ' Da te ,,,~'./7 7 Revised 8/24/82 ~')noco Inc. .. ';cord of Shipment of ~.onfidential Information [] Under Separate Cover Quantity Contents ~,, 1 , I t .- . _~., / -.,, _,!;~FcF~p .A r~o~ Signed By Transmittal d-By Date ]nstruction~/'Please acknowledge-receipt promptly by signing and returning carbon copy. ~ece. ived By Date Remarks Alaska Oil & Gas Cons, ;]ommission Anchorage Transmittal Copy Only To 13-98 PCX1 7-79 .oR:cC OKLA, CITv · PRINTED IN U.S.A. March 31, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Well completion Reports - Milne Point C No. 2, A-2, D-2, D-2A Enclosed are the original and one copy of the subject completion reports for each of the captioned wells. Please refer any questions to Gary Merriman at 279-0611. Very truly yours, A W. M. Haskell Administrative Coordinator SHB/kr At t achment MAR I .9g-3 Alaska Oil & Gas C,.~ns. Commis.~ior~ Anchorage STATE OF ALASKA ALASKc, -,,-AND GAS CONSERVATION cOi,~/IISSION 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 6onoco :[nc. 82-194 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20866 4. Location of well at surface .............. ~- 9. Unit or Lease Name , ~ LOCA'f i C;i'q 5 ~ 1229' FSL, 2459 FEL, Section 10, T13N, R10E .~ X,, ~ ~ ~ ~ .. __ ~ .......... ~ ' Milne Point Unit At Top Producing Interval ~ 10, Well Number 1260' FSL, 1421' FWL, Section 11, T13N, RIOE tsu~" ¢~~, r~'~ , C-2 At Total Depth iR. H. ~-~-~--1 11. Field and Pool 1245' FSL, 1433' FWL, Section 11, T13N, RIOE Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc]) [ 6. Lease Designation and Serial No. Kuparuk Ri vet P001 52' KBI ADL 47434 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. / 15. Water Depth, if offshore 16. No. of Completions 11-22-82 12-7-82 ....l-8-~1 ~.-'-'(..~"' *~"~ feetMSL I 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set [ 21. Thickness of Permafrost 8900 (7480) 8786' 7366' YES[~X NOF] I 2190' feetMD I +1800' 22. Type Electric or Other Logs Run DIL/BHCS/SP-GR/CNL/FDL/NGT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ZU" 94# PELP 0' 80' 26" T© Surface t3 3/~" 72# L-80 0' 2650' 17½" 1300 sks. Fondu, 751) sks Permafrost 7" 29# L-80 0' 8869' 8½" 800 sks. Class G & 300 sks. Permafro,, C. 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) 3½" 9 3# 8503' 8426' ~ · 8546' - 8558' 12 SPF "~ '- 8566' - 8596' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. :~ . . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ; . . ... . · : ' . · 27. ~ PRODUCTION TEST SEE ATTACHED Date ;First prO:duction ' I Method of OPeration, .(F.,Iowing, gas ,lift, etc.) I '~.. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE IGAS-OILRATIO I : TEST PERIOD I~ . , Flow Tubing C~ising Pressure . cALCULATED: OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press: ~4-HOU. RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No :cores_ taken, : ' ' ::' ~,1,- . An.,~_orago Form 10-407 Rev. 7-~-80 AFL 1012 AOGC¢ (2) CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Schrader Bluff w. Sak (OA) Seabee Shale Lower Kuparuk Unconformity Middle Kuparuk Lower Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 3686' 5738' 5930' TRUE VERT. DEPTH 3046' 4446' 4614' 6648' 6951' 7125 30. 8067' 8371' 8545' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and g,avily, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title ~/' Date 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". MILNE POINT NO. C No. 2 WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Interval Tested: Date of Test: Method of Operation: Hours Flow Tested: Production Test No. 1 8546' - 8558' MD (7126'-7138' TVD) 8566' - 8596' MD (7146'-7176' TVD) ].2/17-18/82 Flow Test 10 Minute Initial Flow 598 Minute Final Flow Wellhead Flowing Tubing Pressure(PSIG): 125 Gauge Depth: Oil Produced (BBL): Gas Produced (MCF): 83 Water Produced (BBL): 0 GOR (MCF/BBL): 0.330 Choke Size: , Flowing Bottomhole Pressure (PSIG): 2374 , Final Build-Up Pressure (PSIG): 3465 Maximum Rates: BOPD 610 BWPD 0 MCF/Day 200 Oil Gravity: 8450' MD (7030' TVD) 226 28/64" 24.5°API All pressure values listed are the values recorded at gauge depth. WELL HISTORY MILNE POINT C NO. 2 Kuparuk River Field - North Slope Borough, Alaska - 39.56375% Milne Pt. C No. 2 - CONFIDENTIAL (8500' - Kuparuk River)AFE 10-61-1012 11/21 -API No. 50-029-20866 Ak. Permit No. 82-194 Elevation: 52'-KB Location: 405].' FNL, 2459' FEL, Sec. 10, T13N, R10E, Umiat Meridian. Move in and rig up. Nabors #27-E (0-0-0) Drilling Foreman - Fritsch 11-22 Finish rig up. Spud 8:30 p.m. on 11-22-82. Mud wt. 8.7#. Visc. 200. Nabors #27-E (0-0-0) Drilling Foreman - Fritsch 11-23 Drlg. @ 940', made 834'. Rig up floor; break circ., tag cmt. @ ].06', Drill 106' to 506' POOH, lay dn. steel collars, P/U Dyna drill & teleco collar & M/U BHA. TIH to 506' & break circ. Orient Dyna drill, drill & survey 506' to 940'. Survey: 506'-vertical hole 609' 3.3° due east 699' 6.4° N85E 790' 10.0° N88E 882' 13.3° N87E Mud wt. 9.4# Visc. 180 Nabors #27-E (0-1-0) Drilling Foreman - Fritsch 11-24 - Drlg. @ 1700', made 760'. Dynadrilled f/940' to 1110', POOH. Changed bit & Dynadrill. Cut Drlg. line & TIH. Dynadrilled & surveyed f/lll0' to 1369', Dynadrill quit. POOH, change bit & Dynadrill. TIH & break Circ. Dynadrilled & surveyed f/1369' to 1700'· Survey - Dev: 14.9° S86E @ 973' 17.9° S88E @ 1065', 20 8° N89E @ 1186' 25 7° N89E @ 1312' 29 9° due east @ 144~' 34 5° S88E @ · , · , · , · 1568'. 11-25 - Drlg. @ 2665', made 965'. Dynadrilled & surveyed f/1700' to 1940'. POOH, L/D Dynadrill, M/U BHA & TIH. Drilled & surveyed f/1940' to 2665'. Circ. & cond. mud. Short trip 20 stds. - P/U 89 jts. D.P. Circ. & cond. mud & POOH. L/D BILA, R/U to run 13-3/8" csg. and ran same. Survey - Dev: 39° due east @ 1727', 41.7° N86E @ 1823', 40.0° S89E @ 1990', 40.4° S89E @ 2304', 40.6° S89E @ 2610'. 11-26 - Depth-2665'. Run 66 jts. 72# L-80 Butt csg. w/B&W Float shoe @ 2650'; B&W stab-in float collar @ 2584'. R/D csg. tools. TIH w/D.P, stinger & stab-in too].. Circ. & cond. hole. Pump 75 bbls. water, test lines w/4000#. Mix & pump 1100 sks. Arco Fondu cement (2310 fta); 11.7 ppg. followed w/750 sks. Permafrost "C" cmt. (712.5 fta), 15.6 ppg; Disp. w/45 bbls. mud; 200 sks. (420 ft~) Arco Fondu returns to surface; floats held. Cements mixed @ 5-6 bpm, disp. @ 4 bpm, C.I.P. @ 4:00 p.m. POOH w/drill pipe stinger. P/U Diverter & spool. Set slips on 13-3/8" csg., N/D diverter & finish cutting 13-3/8" csg. Install secondary packoff & csg. spool. Test w/1500#; N/U BOP stack. 11-27 - Drlg. @ 2674', made 9'. Change to 5" rams. R/U & test BOP stack & all rams 500# & 5000#, annular 500# & 2500#, valves & choke manifold 500# & 5000#. Choke line HCR valve had leak, was repaired & retested. Test approved by R. Foster, State of Alaska. Caliper & P/U 6~" BHA w/12~" bi~ .... i-T~ ~/~ ~].oat collar @ 2584'. Unfreeze stand pipe. Test 13-3/8" csg. w/1500#/30 min. Drill out float collar & shoe, drill formation to 2674'. Circ. & cond. mud to 8.7 ppg., test csg. shoe, leak-off @ 480 psi, 12.6 E.M.W. POOH, L/D excess D.P., M/U BHA, P/U 15 HWDP & TIH. 11-28 - Drlg. @ 3761', made 1087'. TIH & break circ. Drill f/2674' to 2886'. Surveyed w/Teleco & single shot. POOH, P/U Dynadrill & TIH. Dynadrilled & surveyed f/2886' to 3175'. POOH, L/D Dynadrill; M/U BHA & TIH to 2975'. Wash down 200' to 3175'. Drilled & surveyed f/3175' to 3761' & POOH. Change bit & BHA & TIH. Survey - Dev: 38.4° S85E @ 2759', 40.6° N88.5E @ 2877', 46.3° N87E @ 3037', 48.2° N89E @ 3099', 49.5° N87E @ 3269', 52° N89E @ 3556', 54.1° due east @ 3681'. Mud Wt. - 9.0#. Visc. - 37 11-29 - Drlg. @ 4728', made 967'. Wash & ream 5 jts. to bottom. Drill & survey f/3761' to 4135'. POOH, P/U Dynadrill & TIH. Dynadrilled f/4135' to 4447'. POOH & L/D Dynadrill. M/U BHA & TIH. Wash to bottom @ 4447'. Drill & survey f/4447' to 4728'. POOH to 4400', swabbing, kelly up & circ. clean. POOH. Survey - Dev: 54.3° S89E @ 3778', 53.2° S85E @ 3906', 54.1° S81E @ 4033', 55.3° S83E @ 4183', 49.7° due east @ 4311', 47.6° N86E @ 4373', 48.2° N86E @ 4571', 48.2° N88E @ 4667'. Mud Wt. - 9.1#. Visc. - 36 11-30 - Drlg. @ 5478', made 750'. M/U BHA & TIH to 4300'. Wash & ream f/4300' to 4727'. Drilled & surveyed f/4727' to 4955'. POOH, L/D stabs, P/U Dynadrill & TIH. Break circ. Dynadrilled & surveyed f/4955' to 5478', POOH. Survey - Dev: 48.5° N89E @ 4711', 51.1° S89E @ 4839', 47.5° S86E @ 5010', 44.5° S87E @ 5138', 41.0° S87E @ 5234', 37.4° S89E @ 5329', 34.7° due east @ 5415'. Mud Wt. - 9.2#. Visc.- 35 12-1 - Drlg. @ 5478'. POOH, L/D Dynadrill. Service rotary table & pipe stripper. TIH, cut & slip line @ shoe. Tight hole @ 5150', pipe stuck, jarred free. L/D a single jt. Kelly up & reamed @ 5150', pipe torqued up and stuck. Jar on pipe. Mix & spot 25 bbl. mix of lube 106. Jar on pipe. Mix & spot 25 bbl. diesel w/3 gal per barrel pipe lax. Preceeded by 25 bbl. straight diesel, followed by 15 bbls. diesel. Jar on pipe. Jarred free at 1:45 p.m. Circ. diesel out and cond. mud. POOH, service all drill collar connections. L/D Teleco. Mud Wt. - 9.2#. Visc. - 50 12-2 - Drlg. @ 5774', made 296'. L/D Teleco, make up bit. TIH, break circ. Ream f/5157' to 5478'. Drld. f/5478' to 5500'. Plugged bit - can't unplug. POOH, unplug jets. TIH, break circ. Drld. & surveyed f/5500' to 5623', lost 900# pump press. POOH, look for washout. L/D one stab - washout; check BHA & surf. equipment for leaks. TIH, break circ. Drld. f/5623' to 5774'; attemped to survey, rig wireline machine not working properly. Survey - Dev: 32° N87.5E @ 5513'. Mud Wt. - 9.2#.. Visc.- 50 12-3 - Drlg. @ 6568', made 794'. Surveyed; wireline machine broke down, no survey. Drilled f/5774' to 6336'. Ran survey @ 6304', drld. to 6419'. POOH, change bit & BHA, and TIH. Drld. f/6419' to 6568'. Survey - Dev: 29-3/4° N88.5E @ 5712', 27¼° N86.5E @ 6253'. - 2 - 12-4 - Drlg. @ 7173', made 605'. Drill & survey; POOH. Test BOPE & TIH, no fill. Survey - Dev: 24° N87~E @ 6539', 19½° N85½E @ 6731', 16¼° N83½E @ 6923'. 12-5 - Drlg. @ 7966, made 793'. Drill & survey. Pump pill, drop survey & POOH. Change bits & TIH, no fill. Drld. f/7701' to 7966'. Survey - Der: 7¼° N76.5E @ 7335' 5° N86.5E @ 7618' Mud Wt. - 10.0#. Visc. - 46 12-6 - Drlg. @ 8606, made 640' Drill & survey f/7966' to 8474'. Stuck pipe, circ. & condition mud. Drld. ~/8474' to 8506'. Pump pill; s.l.m. POOH, change bits & TIH. Drld. f/8506' to 8606'. Mud Wt. - 10.5#. Visc. - 44 12-7 - Depth @ 8900', made 294'. Drill f/8606 to T.D. @ 8900'. Circ. Short trip 25 stands (tight first 4 stands, hit bridge 6 stands off bottom TIH, washed through it). Circ. & condition hole for logs. POOH to log. R/U Schlumberger & log. Survey - Der: 2¼° S28~E @ 8757'. Mud Wt. - 10.5+#. Visc. - 47 12-8 - Depth @ 8900'. Logging. Ran DIL-BHCS, FDC-CNL-NGT. TIH with sidewall core gun. Mud Wt. - 10.4#. Visc. - 44 12-9 - Depth @ 8900'. Finish running sidewall cores, R/D Schlumberger. L/D monels, P/U steel drill collars. Change drilling line spools & TIH. Wash to bottom 30', no fill. Circ. & condition mud to run csg. L/D drilling string. Mud Wt. - 10.3#. Visc. - 46 12-10 - T.D. - 8900'. N/U tubing spool. L/D drilling string, break kelly, and install 7" pipe rams. R/U casers & run 7" L-80 29# csg. to 8869', csg. stuck. R/U cementing lines & circ. Test lines, pump pre-flushes, & 800 sks. Class "G" cmt. w/l% CFR-2, .3% Halad-9, 5% KCL. Circ. pressures high. External pkrs. set when plug passed; R/D Halliburton (displaced cement w/9.4# brine). N/D BOP stack, hang csg., cut off csg. & N/U tubing spool. 12-11 - T.D. - 8900'. Run tubing. N/U tubing spool; packoff & test packoff to 2000 psi. Downsqueeze 200 bbl. water, 300 sks. Permafrost "C", & 220 bbl. Arctic Pack. N/U BOPE. R/U GO, run gyro survey & gauge ring w/junk basket. Test stack & 7" csg. to 2000 psi. R/U casers & run tubing. 12-12 - T.D. - 8900'. Space out & run 3~" tbg. Control line failed (wearing out across tbg. collars), POOH. Splice bad spots & TIH to 8768'. R/U GO and run GR-CCL correlation log. Space out tbg., control line failed downhole again while hanging tbg. after a 10-minute test @ 5000 psi. 12-13 - T.D. - 8900'. POOH & replace control line. TIH, test control lines & land tbg. Pack off tbg. hanger. Displace brine w/diesel. N/D stack & N/U tree. Test tree, control line & SSSV. (Installed BPV) Rig released 6 p.m. on 12/13/82. Nabors 27E (0-21-0) Drilling Foreman - Jackson -3 - ...... C:ONCIC:O, '[ NC:. - ............................. p~_~A~L,~._W~_I~L. C~:_:___~]~ dClB NO: A 1282G0115 MILNE PT, NORTH SLOF'E, ALASKA ............... OM'S~ 0-~8700 MD,-S~URVEYOR: ~ MILLER/GEMMILL .... gATE RUN: .-lO-DEC-E:2 C:AMERA NO: 1607 5-90 DEG. A/U NO: 1566 GYRO NO: 631 FORES:IGHT: N ~ E C'ONOC:O, INC. PAD C, WELL NO: 2 GMS MILNE F'T., NORTH SLOPE., ALASKA JOB NO: A128260115 COMPLI'I: AT I'01(I T I ME DATE 11:11:15 13-DEC-82 PAGE NO. i ............... TRUE · MEASLIRED DRIFT DRIFT COLIRSE VERTICAL VERTICAL R E C: T A N G U L A R C: L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION C 0 0 R D' I N A T E S DISTANCE DIRECTION :-3EVERIT FEET D M D M FEET FEET FEET FEET FEET D M T~G/100F O, 0 0 0 0 O, 0,00 0,00 0,00 0,00 0,00 0 0 0,0C) · 100. 0 0 0 · 0 100. 100.00 0.00 0.00 0.00 0.00 0 0 0.00 200. 0 0 0 0 1 O0. 200. O0 0.00 0.00 0. O0 0. O0 0 0 0. O0 :300, 0 0 0 0 100. 300, 00 0,00 0.00 0.00 0 · 00 0 0 0, 00 400. 0 0 0 0 100. 400. O0 O. O0 O. O0 0. O0 O. O0 0 0 O. 00 500. 0 45 N 84 0 E 100. 500.00 0.65 0.07 N 0.65 E 0.65 N 84 0 E 0[-~5 ...... 600. 3 15-N 81 0 E ...... lO0.- 5.97.'..-73 4.10 ...... 0.52. N. 4.11 E 4.14 N 82 44 E . 2~ J '700, 7 0 N 82 0 E 100, 699,51 12,.90 1,84 N 12,94 E 13,07 N 81 54 E 3.75 ..... · _,3 E 27 8~ N 81 57 E 3 00 800, 10 0 N :~2 0 E 100 798 40 27 48 3 .90 N 27,.='. · . · .......... F~00. 13 0 S 87 O.'.E ........... t00', ................... 8.96~38 .................. 47.34 4.77 N ...... 47.46 E .............. 47.70 N 84 16 E 3.70 1000, 15 45 N 85 0 E ....... 1100, 18 15 N 89 0 E 1200, 21 30 N 88 0 E 1300, 25 0 N 87 0 E ........ 1400. 28 30 S,87 0 E 100. LO0 00. 1500, 31 45 N .90 0 E 100, 1 1 1274. 04. 1450.53 72,45 N 85 53 E 3,39 101,68 N 86 12. E 2,76- 135,65 N 86 47 E 3,27 175,11 N 86 57 E 3,52 220,08 .... N.87,22.,.E 3.~3 270,20 N 87 57 E 3.27 ........ 1600. 35 30., N 8~ ........O.--E ............... t00.. .................. 1533.-78 ...................... 325...07 ........................ 10.,t7. N ........... 32,5..3.9 ,E ................. :325.55 ...... N. 88 .... 13 E ........8.7'.:',' 1700, 38 45 N 8.9 0 E 100, 1613,50 385,37 11,23 N 385,73 E 385,8?) N 88 20 E 3,25 1800, 40 30 N 88 0 E 100, 16~0,52 449,07 12.'.T~0 N 44.9, 48 E 44.9,67 N 88 21 E 1,86 ...... -t' 900 ~ .............. 41'""" 30 ........ N'" 87 ...... O-""E ............. t 00 '~' ............ 1"765'"~"~99' ........... S' t"4"~"53 ................. 15'~'-76'"-'. N .............. 515 ,' 02"-' "E ............... ~ t'5.' 27 N 88 .~,, 15., E ............................ 1,20 2000. 40 0 :3 .c,'O. 0 E 1 O0 . 1841 .75 57.9.71 17 .47 N ' 5:30 .27 E ..,=::"-"(".:, ..,. 53 N .~'::'°,..? 17 E 2.1"'e 7 ............ ~2-100. ............. 40 Ci .......... S- .90, .... O-E ........ i 0 0.. ........ tC,~,t8..,,35 ............ /_-43,,,,-.98 .......................... 17~...,.,47-N ......... 644..,55-E ................... ~:. 44, 78 ........... N, 88--2 , E 0.,, 00 2200. 40 15 N 8.9 0 E 100. 1.9.94.82 708.3.9 18.03 N 708..9.9 E 70.9.22 N 88 33 E O./_-.9 2300. 40 15 N 8'7 0 E 100. 2071.14 772..95 17.".16 N 773.5.9 E 773.83 N 88 35 E 0.00 ..... 2400.. .................. 40 15 .......... $,..90 ....... O-E, ............... 100,, ............... 2.t47...,46 .................. 837,.53 ..................... 1,9.,,,,72~,.N .............. 838...20-E ............... 838.43 ............. N.,,88,,,39.-,E O. 65 2500. 40 15 S 89 0 E 100. 2223.7.9 .902.13 19.16 N .902.81E .903.01 N 88 47 E 0.65 2~0~.------40.-45 ...... 8-88---C~.-E-- .... 10.0.. ...... 22,~'83 ........ ~67.-0.~ ..... 1.7...4~-N ...... 9&,7...,,]3.,...,E .... 96.7,.89 ...... N,,.,,.88,,,.,58,.,E ................... 0.82 2700, 38 15 S 87 0 E' 100, 2376,.98 1030,66 14,68 N 1031,27 E 1031,38 N 89 11E 2,58 2800. 3.9 15 S 86 0 E 100, 2454,.97 10.93,21 10,86 N 10.93,75 E 10~3,80 N 8.9 26 E 1,18 ---~.00.- ........ 4,~-..t.5 ........ N.-,..8~ ....... O-E 1.00~---,,..~53.1.,..~,2~ .... li57..,.80 ................ ~..-.I~.,-N ........ 1.158..31 E .... ~158,.,35 ....... N..,.8~..,-,33,-E ............... 3.,80 I_-'~iNi-ii~i'~ ~ NC · COMF'I_I~;AT I ON PAD- tS: ,.-.- WELL. NO: 2 . -. Gbt$ .............. - ................................ %lnB_ -NO: A l'-'°r'~.~OO, 1-15 ..................................................... T I ME ..................... DA]'E MILNE PT, NORTH 8LOPE, ALA._.~'KA MEASURED DRIFT DRIFT COURSE DEPTH ANGLE DIRECTION LENGTH FEET- D M D M FEET PAGE NO.' 2 ) 11:11:15 13-DEC-82 TRUE ........................ = ........................................ VERTICAL VERTICAL R E C T A N G U L A R C L 0 $ U R E DOGLEG DEPTH SECTION C 0 0 R D'I N A T E S DISTANCE DIRECTION SEVERIT FEET.. FEET ....... FEET ..... FEET .. D M DG/IOOF 3000. 44 45 N 86 0 E 100. -. 3100. 48 0 N 8~- 0 E 100. 3200. 47 30 N 87 0 E 100. :3300. 50 0 N 86 0 E 100. 3400. 50 0 N 86 0 E 100. 2604.41 1225.83 12.14 N 1226.43 E 1226.4~ N 87 26 E 4.05 2673.40 12~8.04 15.30 N 12~8.73 E 12~8.82 N E:~ 20 E 3.~1 273~.33 1373.0~ 17.~2 N 1373.86 E 1373.~8 N 8~ 15 E 2.12 2803.~4 1447.14 22.58 N 1450.04 E 1450.22 N E:~ 6 E 0.~1 2868.22 1525.41 27.~3 N 1526.46 E 1526.71 N 88 57 E 0.00 3500. 51 0 N .... 3600. 52 30 N :3700. 54 15 N 3800. 54 30 S ~?yO0. 53 30 ':' 87 0 E 100. 2~31.83 1602.30 32.64 N 1603.48 87 0 E ........100.. .... 2773.74 ........1680.61 ...........:36.75 N 1681.70.. E:9 0 E 10C) 3053 2:9 1760 72 3~ == ...... · ~,~, N 1762.10 88 0 E 100. 3111.64 1841.~ 38.84 N 1843.37 88 ...... O..E .......... 100. ............ 3170.42 ......... 1~22..8~ ..........36.02 N 1~24.22 E 1603. ,q 1~ N , .'., E-. ....... 16,B-. . :30. N E 176,2.54 N 88 43 E 2.2:7 E 1843.78 N ~,,~'"' 4:-: E 2.45 E 1~724 56, N "'~ · ,:,~, 56 E 1.00 4000. 54 0 ...... 4100,. 56 15 4200. 55 0 42:00. 51 0 ........... 4400·47..45 4500. 4600. 4700. 4800. .......... 4~00.. 5000. .......... :5100 .. .......... 5200. S84 OE S. 80 0 E S 84 0 E N ?,'0 0 E N ...85 0 E ). 32 45 200:3 :'::0. :~ ."'¢ ...... N 2004 65 E 2004. '=' ~,~, ,..,, N ,.:,o.._.. 8 E ~ ""/- ,... 8::N :.~085. c.7 E .,..,.,,=,..,· 9& ........ N ,=.,. E 2.98 ~,',;: :;,,',,L~;,,~;:,. k,~:,;;~,. :,,, , , , ..w 7, 49 N 21/_,7~! E 2167 60 N P,9 4:_=: E 3 52 · ,' · ~: ; -- ,~, # -- . , -- ~ ~' 2247', E 2247 29 N c,~., --~. ,, · ~.."- ~.~, E 6.24 E 232~.. 0'~ ..... N,, c..~Y ,50 E 4 ,:c;~7 · :..-'~'.., 23~-'6 11 1~.,~,4'"'1<i'"' 22:97 03 E oo.v 0/~, N 88.,' 42 E 0.78 · · · . ~ .,.m .¢ ¢ · 48 15 N. 86 ......... 0...-E 100. 3602:..28 ................... 2470.25 17.,.64.., N 2471.30 E 2471.37 N., E O. 25 48 15 N 89 0 E 100. 3668.87 ,2544.~:,8 20.89 N 2545.83 E 2545.'F.,'2 N 89 32 E 2.24 50 15 S 90 0 E I00. 3734.14 2620.39 21.55 N 2621.58 E 2621.67 N 87 32 E 2.14 52-.. 30 ........ S,~87 ........ O.,-,,,E 100., ...................... G.,"7~/=,,..,5/.:., ................. 2/:,S,'8.,50 1.9.51 ...... 1'4 2699'..6/.:,,,,.E ............. 2699.73 ........ N 88.,',.35. E 3· 25 48 45 S :--:7 0 E 100..¢,~._,.-..°'"='"'. 98 2775.75 15.46 N' 2776· 84 E 2776.89 N ;~9.. 41 E 3.('.,5 45 ...... 0 S,...88 ............ O,..E 100. 3.S.,'28.33 ...................... 2848.71 12..28,.,N 2849.75,,E 284S.,'. 77 N 89 45 E 3.82 41 45 S 88 0 E 100. 4(:,01.01 2917.38 9.88 N 2918.37 E 28.,'18.39 N 8~ 48 E 3.25 5300. 37 15 S ............. 5400. ....... 34..45 ..... N 5500. 32 45 N .......... 5~00. ............. 31 ..... 15 ......... N 5700. 30 0 89 0 E 100 4078 15 -,,.',~-,r~ -,¢,~, ~ · · l:¢c,.. 96, 8.22 N ~ :¢c,.· 94 E~:-c, 1"¢'~' · 95 N c,~'°..- 51 E 4. :~,4 88 .......... O...E ............................ 100. ................... 41,58,'.05 .................... 303'.~,,..70 8,73 ,,N 3040.71 E ................. 3040.7,2 N 8,"P 50 E 3.06. 88 0 E 100 ...... 4242 19 2¢~¢~5.16 10.67 N ¢,r,~.:,.... o. 23 E '~'~,0~.;]/_',. 25 N 89 48 89 O..,,E I ')(' .-,o ,~ .-, ,~ ~'..06. N 314.9.20 E ............... 3ta':~ '-,'~, c/0 0 E 100 4413.04 31 ~ '~ . . · . ~:~.00 12.50 N 32o0 14 E 3200.16 N 89 47 E 2.00 E ........... 1.59 E 1.'."= ~, ._1 · -, ...... ,., 0 S 90 0 E 100. 4500 (38 :3248 '"'"-,' .":.,._-,~o ~-.'-,,,~ ,=,,.=, " -' -- · . .,::,._, 12.50 N ..,=-..-. 38 E .:,,...-,... 40 N,.,.. 47 E 1 . 00 ........... ?:900., .............. 28..45 N ~_,cy 0 o.~ ....... E ........................ 100, ................... 4587.64 ................ 3296.50 12.92. N 3297./=,6 E o.-,o~_,_._r,.~./=,9 N 8w- 47 E 0.54 .,, '!" ~i, i ' ......................................................................................................................................................................................................................................................................................................................................................................................... :,, : :, ' -i '-' . COMPU~ A T I'L-l~ ' .,ONLCU, INC ':'AB C:-, WELL NO.".'2 OM.C:_; ' ,JOB NO: At282G01-15 TIME .............. hATE .. dlLNE PT NLRTH SLOPE ALASKA 11:11 15 13-DEC:-82 PAi}E NO. .................................. ' .......................................................................................... TRUE ~EASLIRED DRIFT DRIFT COURSE VERTICAL VERTICAL R E E: T A N G U L A R C L 0 8 U R E DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION P 0 0 R D I N A T E S DIoTAN_.E DIRECTION FEET D M D , M FEET FEET FEET FEET FEET D M DOGLEG SEVER I 'fY DG/100F] 6000. 28 45 N 89 0 E 100. 4675.32 3344.56 13.76 N 3345.76 E 3345.78 N 89 46 E '~'6100. 28 15 N 89 0 E .... 100. 4763.20 3392.23 14.60 N 3393.47 E ...... 3393.50 N 89 45 E 6200. 28 15 N :38 0 E 100. 4851.29 3439.51 15.83 N 3440.78 E 3440.82 N 89 44 E 6300. 27 15 N 87 0 E 100. 4939.78 3485.97 17.87 N 3487.30 E 3487.34 N 89 42 E 6400. 27 0 N 87 0 E 100· 5028.79 3531.43 20.25 N 3532.83 E 3532.88 N 89 40 E. 0.00 0.50 0·47 1.10 0.25 6=d00. 24 30 N 87 0 E 100. 51,~, o=. .~-;~ '~ -,c, =--, ~ "=~' "' ' "'S~' "~' 89 c,c, ,~.. ~,¢ ~..~. ,~ ~. ~,~, ,, ¢.~,/o. z, ~ ~,:,. ~,:,N , ._,,.. ..... 6600. "2'1 45 N'87 O'"'E 1(.0. ..,.10~..o0 ................. o61C4,.91 24.,,'58.,. N ........ c, 61,.,,,4=.,. E :361._,., ~ 1 N S9 37. 6700. z( 0 N ~,7 0 E 100, 5:304.24 3~49.44 ~6.45 N 3651.01 E 6800 18 45 N 87 0 E 100 5398 57 3682 52 ~,~. 18 N 3684, 14 E 3684.24 N ~"~' 34 ~,900. . 16 45 N 6~' ~ ......... r). E I()()'~ .................. ~ 4,~'Z4~ ,~~ ~ ~' .......................... ~'~71.z.~ 8~' ~ ~ ~'o0.0.4.,,N 37 7000. 14 45 N 85 0 E 7100. 12 0 N.84 0 E 7200. 10 0 N 82 0 E 7300. 8 0 N 80 0 E 7400. 7. 0 N 79. 0 E 7._ 00 6 7600. '=' '7700. 4 7:300. 5 ....... 7900.. ......... 4 3741.76 N 89 30 3764.80 .... N 89..29 3783.76 N 89 27 3799.23 N 89 25 3812.09 N 89 23 0 N 79 0 N 84 30 ~.c' 88 0 S 82 0 E 100· 6381.60 3846.92 44.68 N 3848.97 E 3849.23 N 89 .... 0 ...... S .-. 85 ....... O-.-E .............. 100.- ....... ~4.8.1-~--.29 .............. 3854, 74 ............... 4 ~:. 80 .. N 3856.76-. E ............. 3857.01 .... N. 89 O, E 100'. 6082 .75 3820 ,96 43, 7,n, N 3822.?.'8 E ":'-':'"":'. 23...,,.,.,...., N O.E .... 100.- 6182..28 ....... o.o:~,r,., 41 ...45 12 N 3832 45 E .... 3,~.~2 72 ....N ................... ._l i~ ~ i~ I ............... i · ..... -- --· ~! ~1 N 0 E 100. 6281.94 3838·66 45.40 N 3840.72 E oo40.99 89 21 89.20 20 8000. 3 -- 8100, ........ 4 8200. 4 8300. 2 ..... 8400.- ........ 2 0 :3 82 0 E 100. 6581.10 3860.82 43.10 N' 3862.83 E 3863.07 N 89 22 0 .... 8-.67 ........ O--E-- t00.- ...... 6680..~I ........... 3866.72 ........... 41.48..N ..... 3868.69,.E .......... 3868.92 N-89 23 0 S 51 0 E 100. 6780.67 3872.76 37.~0 N 3874.65 E 3874.84 N 89 26 45 S: 44 0 E 100. 6880.4~ 3877.19 33.92 N 3878.99 E 3879.14 N 89 30 -30 ...... S45 .... O....-E ......... 100~-- ..... 6980.-3~ ......... 3880~4% ............ 30.65 .N ...... 3882.20-E ..... 3882.32 ..... N..89_33 E 1.75 E ! E 2.02 E 2.76 E 2.04 E 2.02 E 1 ·,01 E 1.00 E ......1.11 E 0.83 E O. 70 E .................... 1 · 03 E I ,_~ E .. 1.~'5 E 1.11 E 1.31 E ........... 0.25 8500. 2 30 c.._, 3.9 0 E 100. 8600-.~2--.-0---S-43_.8, 0- E .... 1-00. :E:700. 2 0 'S "-~ 0 E 100· 7080.29 3883.46 7.1.80-.-2-1 .:_,o,~. 7280.15 ':-'R'='~ 86 27.41 N 3885.12 E 3885.22 N 89 36 24 .J 4-.-N--3887..-56-E ...... 3887-.-64 .... N _89_.38_ 21 .3:7 N '"'~'"'~ .-,o,-',¢, 89 · _',,:,c:,.. 38 E N 41 · · o..,o ..,. 44 E 0.26 E 0.45 -T-HE--F~3 LLO W I NG -S TA T- I ON--IS-P-. RC~. iEC TED. '":£:~NCiC:O, I NC:. COMF'U]:AT I'01~ PAGE NO. 4 AD .... .,.., ..... WEt.~L.--.. NO: ........ 2 ......... r~Pl~ ................ - ....................................... IF~B..-N£1: ....... A 1282001..-1 = ....... , .............................................. T.I.I~IE .................. DATE I LNE F"r, NI'IRTH E;LOF°E ~ ALAE;KA 11.' 11 '· 15 1 ~-'.-~-~-r~'F'~- _._~.,~_~ .................................... i ....................................................................................... TRUE ~-'1 ' ' I ~' 'IEA;:,.IRED DRIFT DRIFT C. OI.R;:,E VERTICAL VERTICAL R E C T A N G U L A R C: L 0 S U R E DOOLEG DEPTH ANGLE DIRECTION LENOTH DEPTH SECTION C 0 0 R O' I N A T E E; DIE;TANC:E DIRECTION E;EVERIT~ FEET. D M D M ...... FEET FEET ............ ~EET FEET FEET ......... D M .... DG/100~] ,:,,.:.,..:,,'. :," 0 ._, 25 0 E 157, 7437 06 3890 ~ 16 41 N ..",8:.','1 70 E 3891 73 N 8'~ 46 E · ii ,~,,,, ,, · · · O. O0 F I NAL C:LOE;URE - D I RECT I ON: ............. D I E;TANCE: N ¢.,9 DEGS 45 MINE; E:O SE[.;:, E 3891.73 FEET 3230!" :3860, ~ coNOco. ~c. ,. PaD C. WELL NO: 2 GMS ~ MILNE PT, NORTH SLOPE, :ALASKA ............. PSTOCK. i EASTI*IAN I,/H! INC. . . i · · , · · t "' i - : : ; ~ , ' - . ~ [ ' : i ...... : ..... [ -; .....~-~T ..... !-:-t--~ .... ; ...... c ..... ~":-'; . ..i ........ j ...... ' !--' :' :,~- - : ~ ' . · . . ~ .... ' :.,?'".-.:. : tooo _ ~__~ ooo .: :., ::; ~ ;_: ; :~ .... LL::'-:: : ' ,:~:_;_~::_.:: --.:..-" ; oo : :':-:-' ~-::-- ~::-::: ~-: .... .- ; : .~. 2soo~;' -. ::-'4;::;: ::;~:';::-:;.;:: -..-. .... ~ .... : I .......... ~_.~ .3000 ,._~.~.~,~.~.~F_~-~:_~:b~i · .,,-.....:,. :_. .~ ..: ..... ~ ...... ~..~_; ~_. ~_~...:.., .-_~.~. ~_,~ :~U~_~ ...... :-':. ~'.~.:r ~ : . -_ _. :~-_-_------:-_-_---: :: ;;~:::::::::::::::::::::::::: ,... ....... :.__- ...... 4ooo_ .._ ....... ,__.~: .... --:-~_ _~.,.x _~ .... ~ ...... ~ '- - . '- .' .......... ~_ ~ ................. i ~ · · ~~ ~ -: ...... t. ........ : ~ -.:-~ .... i--=--:;---~4-~ ........ , ~ ~ ~-: ..... ~---;::-FF :~-F~-:t'-~-~-?S~:':-'- ; ..... ~ · Suggested form to be inserted in each "Active" well folder to check_ for timely compliance with our regulations~_ ·Ope. rator,'W .e~, 1 Nam~ and Number - Reports and Materials to be received by:b~ ~_j.~--~ Date Required Date Received Remarks , Completion Report. Yes Drill St~ Test Re~=s . . H. D. Haley Manager of Alaskan Operations January 20, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report of Operations - Milne Point C No. 2 & A No. 2 The original and a copy of the subject reports are attached. If you have any questions, please contact Gary Merriman at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachment o ,~_, STATE OF ALASKA ~__. , ALASKA' AND GAS CONSERVATION C£ 'MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well E~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 82-194 3. Address 8. APl Number 2525 C Street, Suite 100, ~Anchorage, Alaska 99503 5o-029-20866 4. Location of Well at surface 40511 FNL, 2459' FEL, Sec. 10, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. C-2 11. Field and Pool Kuparuk River Field Kuparuk River P001 For the Month of December ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TD - 8900'. Pipe stuck several times but was able to free up. 12-13-82. Well is currently pending further operations. Rig release on 13. Casing or liner run and quantities of cement, results of pressur9 tests Size Wt. Grade From To 7" 29# L-80 O' 8869' Cement 800 sks. Class G Downsqueeze 200 bbl. water, 300 sks. Permafrost C & 220 bbl. Arctic Pack 14. Coring resume and brief description Sidewall cores were taken. 15. Logs run and depth where run Log From To DIL-BHCS 2650' 8880' FDC, CNL, NGT 2650' 8884' GR-CCL 8200' 8640' 1 6. DST data, perforating data, shows of H2S, miscellaneous data From To SPF 8546' 8558' 12 8566' 8596' 12 DST data to follow on final report 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~'~"~ / ~ TilLEDril 1 lng Supervisor DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 AFF' ](")17 ~.Cl~l"r' (~ [~&'l~ Submit in duplicate 5co Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 December 7, 1982 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report of Operations - Milne Point C No. 2 The original and a copy of the subject report are attached. If you have any questions, please contact Gary Merriman at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachment DEC.: 5 AnCborag~ Comniission STATE OF ALASKA · ' ALASKA'?"L AND GAS CONSERVATION C{~ '.MISSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 82-194 3. Address 8. APl Number 2525 C Street, Suite #100, Anchorage, AK 99503 50-029-20866 4. Location of Well at surface 4051' FNL, 2459' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52 ' tfBI ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 2 11. Field and Pool Kuparuk River Pool For the Month of November ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth 5478' on 11/30/82. Spud on 11/22/82. No major problems encountered while drilling. 13. Casing or liner run and quantities of cement, results of pressure tests Size Weight Grade From To 20" 94~ PELP 0' 80' 13-3/8" 72~ L-80 0' 2650' Cement To Surface 1100 sks. Arco Fondu Cement 750 sks. Permafrost C 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None , ,EC i 5 iga? Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 December 9, 1982 Mr, C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re- Sundry Notice - Intent to Perforate - Milne Point C No. 2 Dear Mr. Chatterton- Enclosed are the original and two copies of a Sundry Notice which outlines Conoco's proposed procedure for perforating and testing Milne Point C No. 2. The estimated starting date for the proposed work is December 11, 1982. If you have any questions concerning this Sundry Notice please call me at 279-0611. Very truly yours, G. A. Merriman Supervising Production Engineer tt cc: R. J. Francis, Anchorage A. E. Hastings, Anchorage T. S. Lucht, Anchorage G. A. Merriman, Anchorage File - Milne Point C-2 D£C ,9 9 982 Alaska 0il & Gas Cons. Comrnlssion Anchorage STATE OF ALASKA ALASKA ~.~ AND GAS CONSERVATION CL .,MISSION SUNDRY NOTICES AHD REPORTS ON WELLS 1. DRILLING WELL r~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. Conoco Inc. 82-194 3. Address 8. APl Number 2525 C Street, SUite 100, Anchorage, Alaska 99503 50-029-20866 4. Location of Well 9. Unit or Lease Name Milne Point OTHER [] 4051' FNL, 2459' FEL, Sec. 10, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB Elev. (KB - MSL) 12. I 6 . Lease Desig.nation and Serial No. ADL 47434 10. Well Number Milne Point C-2 11. Field and Pool Kuapruk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate I'~ Alter Casing 1--1 ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] ' Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposed starting date - December 11, Please note the attached prOcedure. 1982 RECEIVED DEC 0 9 i982 Alaska Oil & Gas Cons. COlnrnission Anchorage 14. i hereby ~tify that the foregoing is true and correct to the best of my knowledge. Signed .... . -- ~ Tit~eSupervising Production Engineer Date The sp~6e below for Commission use 12-'§-82 Conditions of Approval, if any: Approved by COMMISSIONER Approved 'opy Returned By Order of the Commission F cfm 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 12/8/82 MILNE POINT C NO. 2 - COMPLETION/TEST PROCEDURE Objective of Testing: Measure the production rates of oil, water, and gas from the Lower Kuparuk Zone, and measure sufficient pressure data to evaluate the formation pressure and permeability, and the skin factor of the completion. Status of Well at Beginning of Procedure: Nabors Rig 27-E will have run and cemented 7-inch casing to TD. A Gyro Survey will have been run. Procedure: 1. Run in hole with Vanngun perforation/completion assembly on 3~-inch tubing (Note: tubing string includes a subsurface safety valve at 2200'±MD). 2. Space out tubing and land in wellhead. 3. Reverse circulate brine from well with diesel. . Nipple down BOP. Instal]. back-pressure valve. Nipple up tree, and test to 5000 psi. 5. Release Nabors Rig 27-E. 6. Rig up wireline unit and testing equipment. Test lubricator to 3000 psig. RECeiVeD 7. Open subsurface safety valve. DEC 0 9 ~J82 8. set hydraulic packer (100' + above top perf). Alaska Oil & Gas Cons. Commission Anchorage 9. Drop bar and perforate casing from 8546' to 8558' and 8566' to 8596' MD DIL (42' total). 10. Flow well to tanks to remove diesel. Shut-in we].l at surface. 11. Run in hole with Otis downhole shut-in system (well must be shut-in downhole before next step). 12. Open wellhead and all surface equipment to flow to tanks. 13. Initial Flow: Open downhole shut-in system to flow well for 10 minutes. 14. Initial Buildup: Close downhole shut-in system for 100 minutes. 15. Final .~low: Open downhole shut-in system to flow well for 12 hours of stabilized flow. Measure the oil., water, and gas production rates. 16. Final Buildup: Close downhole shut-in system for 12 hours. If a discontinuity appears in the pressure response, extend the buildup period to at least twice the elapsed time at which the discontinuity appeared (not to exceed 24 hours). 17. Fill gas space at top of tubing with diesel. Pressure up tubing and recover downhole shut-in system. 18. Close subsurface safety valve. 19. Rig down wireline unit and testing equipment. RECEJVEg DEC09 '~ - Alaska Oil & Gas Cons. Commission Anchorage T F_, R!3 - 'M EM ORAN DU M TO: Sta~e of Alaska FROM: ALASKA OIL AND C~S CONSERVATION COM~ISSION C. ;, tterton DATE: Ch ~i]~ FILE NO: Lonnie Co ~ ' ~ Com~& ssioner TELEPHONE NO: Bobby Foster U~ ~ SUBJECT: ~troleum Ins~ctor ~]ovember 29, 1982 108A/F Witness BOPE Test on Conoco's C-2 Sec. 10, T13N, ~_10~, UM Permit #82-194 _Friday,. Novem~b~_ r 26, 1982 - I-traveled this date to Prudhoe Bay to ~tness the upcoming BOPE test on Conoco's C-2. The test ~-egan at 11:00 p.m. and. was concluded at 2:00 a.m. November 27, 1982. As the attached BOPE test report shows there ~.~s one failure which was repaired, and. retested. In summary, 1%~tnessed the BOPE test on Conoco's C-2. O&G #4 4/8i · . STATE OF ALASKA ALASKA OIL & GAS ODNSERVATION CCF~MISSION B .0. P .E. Inspection Report ra or. Well ~tion: Sec /~ T/~ffR__, _ /b~M ~~r -/~Casing Set~~ ~., ft~ ~illing ~n~a~or ~: ~~: .Ric :/-~ Repre~ntative ~tion, ~nera] ~ AC~U~R SYS~M Well Si~ ~' C~neral Ho~e~g Resets pit F/ff Test Pressure I n~i Charge Pressure ~/c~-O psig Pressure After Closure /~d-~ psig Pump incr. clos. pres. 200 psig - min/~' sec. Full Charge Pressure Attained:. / min~ sec. N2d~.2,~; /~i),,2~r'~.;_ j¢:/~psig Controls: Master U C ~ / Remote~ C S Blinds switch cover ~Y.~: Kelly and Floor Safety Valves · Annular Preventer Pipe ~ams Blind Rams Choke Line Valves. Upper Kelly Lower Kelly Ball Type Ins ide BOP Test Pressure Test Pressure-- Test Pressure ~~'~ Test Pressure H.C.R. Valve Kill Line Valves Check Valve Choke Manifold ~-~ Test Pressure~4'-~ valves, /7 NO. flanges 3~ Adjustable Chokes ~ Hydrauically operated choke / Test Results: Failures L / Test Tir~' _.~ . .hrs.. Repair or Replacement of failed, equipment to be made within days and Inspector/Ccrnmission office notified.. .., Distribution orig. - AO&(t]C cc - Operator cc - Supervisor Inspector ,~{ov~be r 18, 1982 Mr. Don ~irdIer Engineer Conoco Inc. 2525 C Street, Suite Anchora~, Alaska Se: Milne Point Unit ConOco Inc. Pemit ~o~ 82-194 Sur. Lee. 4051'F~L, 2459'F~, Sec. 10, ~I3N, R10~., ~. ~tmhole Loc. 4130'FNL, 4230"F~L, Sec. 11, T13N, ~10~, ~. Dear ~r. Girdler~ Enclosed is the approved application for per,nit to drill the above referenced well, If coring i~ condue-ted, a one eubi,-~ inch cl~ip frown each foot of recovered c~re is required. S~l~les of well cuttings and a t..-ai(~, log a~e not required. A centinuous directional survey i~ reciuired as per 2-9 AAC 25.050(b)(5). If available, a tape containing the digitized tog info..-n~ation shall be sub~nitted on all logs for copying e~eept ex.~-erin~ental logs, velocity ~urveys and dilai---neter surveys. ~3any rivers in Alaska and their drainage systems have been classified as ia--portent for the spa~ning or n~,igration of anadro{~ous fish. Oi~erations in these areas are subject to AS i~.~5.875 and the regulations pror=-ulgated theret, nder (Ti-tle 5, Alaska Administrative Code). Prior to cor.-.~menctng e~erations~ you ~av~ be Contacted by the Habitat Coordinator's Office, Department of Fish and Came. Pollution of any waters of the State t~ prohibited by AS 4~, Chapter 3, Article 7 and the regulations pro~sulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control. Act, as mm..ended. Prior to con~encing operation~ you ~ay be contacted by a representative of the Del~artm. ent of Enviror~ental Conservation. To aid us in scheoul'~n~ field work, please notify this oifice 24 hours prior to cm~--~encing installation of the blow, out ~r, Don Girdler ~}tlne Point Unit C'2 -2- November 18, 1982 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. ~ere a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tneSs present. Very,.t ruly. you¥~r~s, ./ Alaska Oil and Gas Conservat~d~"~~l ss ion Eric 1 o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC: be Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 17, 1982 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MILNE POINT UNIT, WELL C-2 Lonnie, I spoke with Jim Trimble yesterday and he asked me to submit a letter to the Commission in regards to the proposed path of the "C-2" well in relation to the nearest existing well. The closest that the proposed "C-2" well comes to another well is at 1400'~ where it will be 68'± north of the "C-I" well. This takes into account'both the proposed trajectary of "C-2" and the gyro survey of "C-i". A Teleco too]. will be in use during this interval and it will be checked by a single shot at 1200'±. The Teleco will enable us to take frequent directional surveys to ensure that we are on course and well away from the "C-i" well. I hope that this letter is what Jim had in mind but if any other information is needed, I can be reached at 279-0611. Very truly yours, Don G±rdler Engineer kr t ECEIVED NOV I e 1982 Alaska Oil & Gas Co/~s. Corn/~issior~ Anchorage Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 15, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: PERMIT TO DRILL MILNE POINT C NO. 2 Enclosed for your approval are the original and two copies of the subject permit. A check for $100 is also enclosed in order to comply with the State's filing fee. If you have any questions, please contact Don Girdler at 279-0611. Yours very truly, W. M. Haskell Administrative Coordinator SHB/kp STATE OF ALASKA "'--'-., ALASKA t.,- AND GAS CONSERVATION CC..,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of wOrk. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~ MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite lO0, Anchorage, Alaska 4. Location of well at surface 4051' FNL & 2459' At top of proposed producing interval 4130' FNL & 4230' At total depth 4130' FNL & 4230' 5. Elevation in feet (indicate KB, DF etc.) 52' 12. Bond information (see 20 AAC 25.025) Type B1 anket FEL, Sec. lO, T13N, RIOE FEL, Sec. ll, T13N, RIOE FEL, Sec. ll, T13N, RIOE I 6 . Lease designation and serial no. ADL 47434 Surety and/or number 8086-1 5-54 13. Distance and direction from nearest town I Deadhorse - Southeast miles 33 I 16. Proposed depth (MD & TVD) 8500' MD 7492' TVD feet IV&R_li. AI. 99503 9. Unit or lease name Milne Point Unit 10. Well number C-2 11. Field and pool Kuparuk River Amount $200,000 15. Distance to nearest drilling or completed C-4 we. 120 feet 18. Approximate spud date November 19. 1982 / I LiU psig~ U ' . Surface 14. Distance to nearest property or lease line 1230 feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 34 oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program 3740 psig@ 7492 ft. TD (TVD) SIZE Hole Casing Weight 17½" 3 ,3,/8"1 72# 8½ ' 7I 29# 22. Describe proposed program: CASING AND LINER Grade Coupling PELP L-80 L-80 BTRC BTRC SETTING DEPTH Length M D TOP TV D 0' I 0' I I MD BOTTOM TVD 115'I 115' 2488'~ 2300' 8500'1 7492' I I I QUANTITY OF CEMENT (include stage data) 300 CF 4000+ CF (AHS-20½") 785_+ CF (2000' Fill- Up' AHS: 11") 2nd Stage' 1300 CF incl. Arctic pack See the attached Supplemental Data, Proposed Directional and Bottomhole Location Plats, and BOP sketches. RECEIVED NOV 1 5 ],982 Alaska. Oil & Gas Cons. Oommission Anohorage 23. I hereby c~hat the foregoir~ is true and correct to the best of my knowledge L] SIGNED '"'t ~--~J/'~ ~,____ L TITLE Enqineer The space be,o~; fo; C;~m~ss~on us.------] DATE 11/15/82 CONDITIONS OF APPROVAL Samples required []YES ~0 Permit number APPROVED BY~~/ Form 10-401 Mud Icg required [ Directional Survey required APl number []YES [~NO I [;~YES ENO 50- O ?--~/'- 'Lo ~C G Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS 11 18/8 I ~ ,COMMISSIONER DATE November 18, 1982 /~"'~--/'~J-L) by order of the Commission Submit in triplicate Ie CEMENTING PROGRAM Ae Be Ce SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C'2 Conoco Inc. ' ONFIDENTIAL 2525 "C" Street, Suite 100.( ~ Anchorage, Alaska 99503 The 20" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. The 13-3/8" surface casing will be cemented with 4000± sacks of permafrost cement. Cement will be pumped until good cement returns are obtained at the surface./ The 7" production casing will be cemented in two stages. The primary cementing job will consist of 680± sacks of class "G" cement pumped around the casing shoe (estimated 2000'± of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 30~ sacks of permafrost type "C" cement followed by 200± barrels of Arctic Pak, pumped down the 7" x 13-3/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, silt and sand sequences. Estimated based of permafrost at 1700±. 4500' - TD Predominately shale until the Kuparuk sands - expected at 6880'± subsea TVD. III. FORMATION EVALUATION A. Standard mud logging equipment to be used below the surface pipe. B. Sidewall cores to be taken as determined by onsight geologist. Ce Wireline logs for the 8~" hole from T.D. to the 13-3/8" shoe will include: Dual induction laterolog; borehole compensated sonic-gamma ray; formation compensated density with CNL and GR-caliper. We do not plan to log the 17~" hole. IV. DRILLING FLUIDS A high viscosity gel-fresh water (dispersed) mud system 0' - 2500' Low solids dispersed gel/water mud system 2500' - TD NOV 1 5 ,Oil & Gas Cons. Commission /~nchorag~ (- I FROM MUD PUle,, KILL MANIFOLD FROM REMOTE HIGH ~ ~ ~ REMOTE PRESSURE GAGE SENSOR PRESSURE PUMP ~ ~--U.I ~.[Y-~]_~--UJ ~ NOTE: ~ HYDRAULIC CONTROLLED REMOTE OPERATED I. HYDRAULIC CONTROL SYSTEM FOR BOP STACK & CHOKE MANIFOLD TO INCLUDE (5) STATION CONTROL MANIFOLD LOCATED REMOTELY WrrH ~5000 PSI ACCUMULATOR 8 \/ 160 GAL. RESERVOIR 8 AUX. ENERGY SOURCE. {5} STA. CONTROL MANIFOLD PLUS VARIABLE CHOKE CONTROL TO BE LOCATED ON RIG FLOOR. ~ DRILLING z KILL 8 CHOKE MANIFOLDS TO MEET APl RP53 CL. { {' ~ 5M STDS. . ~ 3. KILL MANIFOLD SIZE- RATING Z"- 5000 4. CHOKE MANIFOLD SIZE - RATING 3"- 5000 - ~ HYDRAULIC CONTROLLED REMOTE OPERATED ' ~ RE~=~E PRESSURE GAGE SENSOR POSITIVE OR ~ ~ ~ POSITIVE OR CHOKE ADJUSTABLE , ~ ~ F--LU/~.LLL/~ ADJUSTABLE MANIFOLD CHOKE ~ : ~ CHOKE BLEED LINE TO ATMOSPHERIC .TO PiT MUD/GAS SEPARATOR NOV ;Alaska Oil & Gas Cons. Ccmmission ^nchoraCa · .. , _ , , BOP MANIFOLD LAYOUT-CONOCO, INC. ZO " O. ~. CASING ~ #tCEL IEF I NOTES 7'0 AI C~Ot, qt~ I, St-t DO A/NI.,~IA/'D DI VEi~',.SiOIt{ ttYI~I~AUL. IC COlVTt~OI ,.gYST~td FOt~ TI-IlS STACt~ TO ItVCLUD~ ~O/VT~'OL t,¢A&IIFO~D Oltlt~l~ ~O0~ ~v'iTI-I 3000 P,91 ~/O~K{itlG P~E~SU~E. LgOTAI I-IYDJ~AULIC MEtdOTE COMTMOL VALV£$ OPEN WI-lEK TIlE P~EVEI~ITEt~~ CLOSES f TI-lEA1 E/TI-tE~ OtVE OF THE VALVES tdAY' CLOSED. . , ,-.- :% .,-~ ~_:,...: ..... -.,,. :;...: . - .mLL-u~ ~~'--~ 'A :t ' ~ ' tz)- ~0~ ~0-~ O~AZ~ O~ a~c~ - : ~IT~ I~0 GALLOM ACeUMULA70~ A~D :. ~ ~: OF OME 8~ T OF ~LIMD . ~AMS AM~ T~O .., ... .... ?~:,.:,-~ . . -.5 7 .:( . ~ ~ ~ ~ ~ ) .--, ~,~ z~oo<: ~c~ ~~ z ,,~ ,~ooo ~,~ _ ~- 5000 S/RE OUTLETW / VALVE~ ~ .:1 ~ , ~ CASING .... ' .... a ' .... ~ . . ,,i-::__ ~ CAa/N~ ~e~o: zo- zooo y 2o cee o ___._~uuc.;.._: _..z: --:: .... -:~ '":- '.: -- ' ga'ZOO0 FLA~GED ¢TLET~ ~EA~ ~~ , , . . I _ _ ~ ~ .. ............ !!1~ --:'L ~ilIKAIIi ~ .~b- ' . ' ..... . ~' _ ~ !_ !~: :-~. NOV, CHECK LIST FOR NEW WELL PERMITS Comp any .~ ~,~-~ /~'~-~ Lease & Well No. /~ ~'f~ ITEM APPROVE DATE (."2 thru 8) . . 3. 4. 5. 6. 7. 8, (3) Admin ~ ~"'x--~ / Izff~'~'~" 9. (9.:~thru 11) 10. 11. (4) Casg (12 thru 20) (5) , thru 24) (6) Add: 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .............................................. Is well to be located in a defined pool ...... Is well located proper distance from property {i~]!ii!i[!!!!!!!'!{ Is well located proper distance from other wells. Is sufficient undedicated acreage 'available in this pool Is well to be deviated and is well bore plat included. Is operator the only affected party ................ ................ Can permit be approved before ten-day wait .......................... Does operator have a bond in force Is a conservation order needed ......... Is administrative approval needed ................................... REMARKS Is Is Wil Wil Wil Wil Is Is Is conductor string provided ........................................ enough cement used to circulate on conductor and surface ......... 1 cement tie in surface and intermediate or production strings ..i~ 1 cement cover all known productive horizons .................... 1 surface casing protect fresh water zones ....... , .............. 1 all casing give adequate safety in collapse, tension and burst.. this well to be kicked off from an existing wellbore ............. old wellbore abandonment procedure included on 10-403 ............ 11 b paratio prop ed adequate we ore se n os .......................... Are necessary diagrams of diverter and BOP equipment'~;;~g~'~ Does BOPE have sufficient pressure rating -Test to ig Does the choke manifold comply w/AP1 RP-53 (Feb.78).~?f~] P.~.,. Additional requirements Additional Remarks: ~ff/~c~$'~=co ~~~ ~~~ o ~ o Geology.: Engineering HWK ~ LC S BEW ~7A ' ' JKT~-~ RAD JAL ~,---_MTMZ/o-' HJH -~' rev: 08/19/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particulady germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING CONFIDENTIAL: tNFORMATTON Furnished By Conoco in~. L..21,~ iml [! 1 i-i I iI~] i[! [:.] ~ { ~P 010,[~o1 V~:RIiF.~ICATiON blSTING PAGE FIbE HEADER NAME :SERVIC,O01 ERVICE NAME ERSION # : ; %XINUM LENGTH : 1024 TYPE REVI~US FILE ~ INF(.)RMATION RECORDS C~3NTENT$ UN I'r TYP~ CATE: 8IZ~ COD ~:~ N ~ CONOCO INCORPORATED 000 000 020 065 ~ : MILNi POI~T C-2 000 000 016 0~5 N : KUP~R[.iK 000 000 008 065 ~NG: IOE 000 gOO 003 0~5 DWNI 13N 000 000 003 065 ~:CT: 10 000 000 002 065 [)UN: NORTH SLOPE 000 000 012 065 ~ATI ALASKA 000 000 OOb 005 rRYI IJ.S.A 000 000 006 065 * COMMEN~$*~ $CHbU~iBERGER * P OIO,H01 YERIF'IC. ATION L].STiNG P/~GE 2 : P E F b lj ! D iT SIZE JOCOSITY ,,OIO bOSS AI',,,ASJ~A C,DMPUTING CENTER 'I~L = ~II,~E POINT C-2 EI, D = ~UPARU~ 'ATE : ~b~SKA ~B NUN. BE~ AT ACC: 6616~ IN ~l DA~,~E LOGGED: 7 DEC : 13 3/B" SURFACE T(,] 2650' ~ LI(~NOSLI]~ ONA~,E = = 10,5 bB/G RM = 2,700 ~ 70,0 DF = ~4,0 S R~ = 2,220 (a 70,0 DF = 9,0 R~C = 2,390 C~ 70~0 DF = 5.o C3 R~ AT BHT = 1.1~3 (a 178,0 DF ~,TR I X SANDSTONE CONFIDENTIAL INFORMATION, Furnished By Conoco rP OlO,!iO1 VERIFICATION BiST1NG PAGE * SCHhU~It!tE]RGE',R LOGS INCLUDED ~ITlt THIS ~AGNETIC TAPE; * DUAL INDUCTION SPHERICALLY FOCUSED LOG (DI~) $ BOREHOLE CO~P~NSATED I~OG (BHC) ~ P'OR~ATION D~iNSITY COmPeNSATED LOG (FDC) ~ CO~,~PE~,~SATE,O NEUTRON bOG (CNb) * N.ITURAf, GAaaA SPECTROSCOPY (NGT) * GA~A RAY LOG CGR) DATA FORMAT RECOIiD ** ~TR¥ BLOCKS TYPE SIZE REPR CODE ENTRY 4 I 66 9 4 65 ,liN 0 1 ~6 0 SPECI~'ICATiON SERVICE SERVICE UNI ,aPI AP1 API AP1 FILE SIZE PROCESS SAMPLE REPR ID ORDER ~ ,LOG TYPE CLASS MOD NO, FT 0 0 0 0 0 4 D I L 0 H ~ ~ 7 0 0 0 0 4 DIb 0~, 7 0 0 0 0 4 OIL O.H~M 7 12 4~ 0 0 4 DIL N,V 7 1 0 0 0 4 DIb GAPI 7 31 32 0 0 4 BHC US/F' 60 52 32 0 0 4 BHC GAPI 60 31 32 0 0 4 FDN PU 42 68 2 0 0 4 FON G!C3 42 44 0 0 0 4 FDN G/C3 42 35 1 0 0 4 F'DN 42 34 92 0 0 4 bEVEls CODE 0 1 68 0 1 68 0 I 6~ 0 1 68 0 1 68 0 1 68 0 1 68 0 1 (~8 0 1 68 0 1 OB ~P 010,H01 VLRIFIC, ].ION [,,!8I'£NG PA(3E 4 DATA P}iPT _8924'5000999,2500 GRSFL'tJ ~.9.'v9999" P H I 40,31320 D R ~ 0 ' 0 2Nla 556,5000 CA L'.I 8 ~'RA 3,3594 "~I '~3R 10 gR 79. 1250 SGR 92 EPT 8900 0000 SFLI.~ -999 . P '999.2500 GR -999 PHI 39,3555 D~HO 0 CNL 699.0000 CAL. I 4 NRA 3,2324 'I'M(JR 10 GR 79. 1250 SG~ 92 E P T 8 ~ 00 . 0000 5 F 1.,, t,J 2 P 9 7813 G a 105 PHI 34[0820 DRBO 0 CNL 646~ 5000 CAb1 8 NRA 3,2754 THf3R 11 GR 82.~750 SGR 107 EPT 8'100,0000 S.FLU 2 P ' 6,4961 GR 94 PHI 33,2031 DRHO 0 CNL, 686,5000 CALl 8 NRA 3 3223 THOR 10 GR 84~5625 SGR lOi EPT ~6000o00 SFi. I~ 5 P -11:0234 (;R 89 PHI 31,4941 DRHO 0 CNL 722.5000 CAbl. 8 NRA 3.14~5 THOR 12 GR 78,5625 S(;R 89 EPT 8500.0000 5FI..IJ 5 P -22.5313 GR 84 PHI 30.3200 DRHI] 0 CNL 763.5313 C~LI 8 NRA 3,0679 T~UR 113 ,2500 ,2500 ,o112 ,5000 .6328 ,3750 25OO ,2500 ,0986 .5820 ~6328 3750 .5098 .3750 .0532 .6719 .0547 .3750 .3379 .0625 0562 :6172 ~7031 '0000 :7734 3750 .0537 .~609 .4609 ,8125 .6250 .6250 .0358 ,5669 .~961 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 IL~ DT RHOB SGR ORAN DT ORAN i L,M DT ORAN IbM D T URAN IbM D T RHOB SGR ILM D? HOB SGR ORAN -999,2500 -999,2500 GR I , 9873 NCNb 92.3750 NRAT I .6475 PQTA -9992500 -9992500 21133 923750 16475 2.0723 99,0000 2 4'107 107:3750 3,1.172 2 1543 94:1875 2.4160 101,0000 2.0469 4.9]36 93,1875 2.4023 91,~125 1,3965 4.3154 91.7500 2.3836 78.0625 1,0420 IbD GR NCNb NRAT PUTA GR NCNb NH. AT POTA IbD GR NCNb NRAT PDTA 1 I,, D GR NCNb NRAT POTA lb[) GR NCNb NRAT POTA 1 68 I 68 1 6a 1 68 I 68 I 68 -999 2500 -999 2500 1870 0000 3 0684 0 0229 '999,2500 '999,2500 2260,0000 3,0215 0,0229 1,9687 !05,3750 2118,0000 2.9922 0.0259 2.0898 94.0625 2282 0000 2:9629 0.O259 5.0313 89.3750 2274.0000 2.8359 0.0190 4.2422 84.6250 2343.1562 2.76~7 O.01'13 GONFIDENTIAL iNFORMATIOI Furnished By Gonooo Inc, P OiO,H01 VERIFICA',,,I. 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