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190-038
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Change Out 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 10,716 feet N/A feet true vertical 7,608 feet N/A feet Effective Depth measured 10,609 feet N/A feet true vertical 7,518 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5#/ L-80/ EUE 8rd 9,685' 6,812' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC David Gorm WINJ WAG 0 Water-Bbl MD 115' 6,227' 10,697' TVD Oil-Bbl measured true vertical Packer Size N/A Casing Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL0025509 N/A measured 115' 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-038 50-029-22029-00-00 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-397 345 Authorized Signature with date: Authorized Name: dgorm@hilcorp.com 360 MILNE PT UNIT L-04 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 208 Gas-Mcf 380 Casing Pressure Tubing Pressure 61 Length 82' 6,194' 10,664' Surface Production Conductor 777-8333 13-3/8" 9-5/8" 7" 4,649' 7,592' 5,410psi 948 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 740psi 2,020psi Burst 1,730psi 3,520psi 7,240psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:21 am, Sep 22, 2021 Chad Helgeson (1517) 2021.09.21 22:34:35 - 08'00' DSR-9/22/21 SFD 9/28/2021MGR15OCT2021 RBDMS HEW 9/24/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP L-04 ASR 50-029-22029-00-00 190-038 8/21/2021 8/25/2021 RU LRS on L-04. RU vac trucks. SITP 604 psi, IA 853 psi, bled off gas to tiger tank. Began well kill pumping down tbg taking returns out the IA displacing well over to 8.8 NaCl, ave 3bpm 200 psi, 410 bbls of 8.8ppg NaCl returned after pumping 480bbls (Took Approx. 80bbl to fill void from gas bled off. SD to monitor press. SITP 187psi, IA 193 psi., bleed off press. to tank tbg 33psi, IA 41psi. pumped 20bbls down the tbg 1bpm. 520psi tbg, 485psi IA,Tbg 201 psi, IA 206 psi, displaced tbg with 80bbls of 8.8ppg NaCl taking returns to test tank . Shut down and monitor for Press. BU, TBG and IA equal at 205psi which equals 9.4ppg EMW. W.O. 9.8ppg Nacl/NaBr KWF to be delivered to L-04, ETA 04:00 hrs. ASR crew performing planned maint. on the rig, changing out oil and filters, installing new jacks on pipe racks. Check pressures : Tbg = 170 psi and IA = 176 psi. Bleed very little gas. RU LRS and vac trucks. Begin pumping 9.8 ppg NaCl/NaBr brine down the tubing up the IA to the kill tank at 3 BPM, ICP = 730 psi and FCP = 800 psi. Pumped a total of 500 bbls with 392 bbls return for a total loss of 108 bbls. At 450 bbls pumped 360 return starting getting 9.3 ppg back. At 500 bbls pumped and 392 bbls returned we were getting good 9.8 ppg back. Well shut in to monitor pressures. 8/21/2021 - Saturday 8/22/2021 - Sunday Observe the well for flow for 30 minutes. Both the tubing and IA were on a slight vac. Install BPV. LRS freeze protected their lines. RD vac trucks. RD LRS. Blow down and RD circulating lines. Empty kill tank. Install VR plug and remove IA valve. Spot the mud boat, pusher's shack, company man shack, change room and the pits. ND the tree. Check the lift threads - good. Install the plug off tool into the BPV. Check gland nut and LDS - all good. Spot the crane. Fly the well house into position over L-04. Install the rig floor on top of the well house. Lay out koomey lines and RU. Continue to NU the BOP stack. Mobilize the rig from A-pad tent to L-pad. Spot and level the rig. Raise the derrick. Spot the mud pump. Take on 40 bbls for fresh water to the pits. Continue to RU koomey lines. Install the stairs around the rig. RU the pits and service lines. Set the catwalk. PU test jt. and shell test BOPE 250/3000 psi, good test. Tested BOPE per Sundry as following: Annular 250-2500psi, Valves 250- 3000psi, Rams 250-3000psi. Tested Fire and Gas and performed the Koomey Drawdown Test. Tested with 2-7/8" Joint. Witness was waived by Brian Bixby on 8/21/21 @ 4:42 AM. Performed drawdown test - good. Choke valve #14 failed high pressure test. Replace and retest passed. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-04 ASR 50-029-22029-00-00 190-038 8/21/2021 8/25/2021 Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 1,800' to 89' spooling ESP cable. Lay down ESP components. Spool ESP cable to the spooling unit. Pull the spooling unit back. Pull used ESP cable spool and install two new spools of ESP cable. Clear the rig floor. RD the elephant trunk. Offload ESP components from the catwalk/Piperack. Run rope over sheave to spooling unit. Place ESP components in order on the pipe rack. PU motor gauge/motor assembly and MU the centralizer. Service the motor. PU and MU the lower & upper tandem seal section, intake and gas separator. Service the seals. Pull the MLE and ESP cable over the sheave. MU the MLE. PU and MU pumps 1-3, zenith ported sub, discharge head and pup joint. SimOps: Place 76 joint of new 2-7/8", 6.4#, L-80, EUE 8rd tubing on the pipe rack. Strap and tally the tubing. RIH with ESP completion on 2-7/8", 6.4#, L-80, EUE 8rd tubing per tally spooling ESP cable, installing cross coupling clamp and testing electrical continuity every 2,000' from 120' to 4,524'. Make reel to reel ESP cable splice. Blow down BOPE testing equipment and RD. Empty the pits of fresh water. RU to pull completion. Pull plug off tool from BPV. Tubing on a vac. Pull BPV. MU TIW to landing joint and MU landing joint to the tubing hanger. BOLDS. Had to replace the void bleeder fitting due to it leaking with the LDS loss and fluid in the stack. Slowly PU unseating the hanger at 35K and continue to PU to 70K with no movement. Work the pipe several times with no movement. Notify town engineer and discuss plan forward. Continue work the pipe in 5K increments up to 100K. Work the pipe 3 times at 100K and the packer released. PU 5' to ensure it is free and stop. Fill the backside with 9.8 ppg brine. Took 6 bbls to fill. Allow the packer element to relax. SimOps: Run rope for the ESP cable and control line from the rig floor to the spooling unit. Spot the pipe tube. Clean around the rig. Pull the tubing hanger to the rig floor from 10,061' to 10,020. Disconnect the ESP cable and control line from the tubing hanger. Connect the ESP cable and control line to ropes in order to pull over the sheave. Break out the tubing hanger and lay down. POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 10,020' to 9,835' with 10K drag. The well is swabbing due to the packer. Connect to the vent valve control line and open the vent valve. Lock in the pressure to keep vent valve open while POOH. Tie control line and ESP cable to each spool. Continue POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 10,020' to 7,566' (ESP packer) spooling control line and ESP cable. Once the vent valve was open no more swabbing or drag; PU = 68K. Bleed pressure off the control line and disconnect. Cut the ESP cable above and below the packer. Splice the ESP cable together. Break out the packer. Had difficulties due to 1.28' short pup joint below the packer. Continue POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 7,545' to 6,255' spooling ESP cable. Kicked out jts 60-120, moved the pipe off of the pipe racks. Continue POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 6,255' to 5,153' spooling ESP cable. Crew lunch break. ESP cable spool full. Pull spooling unit back. Remove full ESP cable spool and install empty ESP cable spool. Move spooling unit back into position. SimOps: RD manual elevators and RU hydraulic elevators. Continue POOH with ESP completion laying down 2-7/8" EUE 8rd tubing from 5,153' to 1,800' spooling ESP cable. 8/24/2021 - Tuesday 8/23/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP L-04 ASR 50-029-22029-00-00 190-038 8/21/2021 8/25/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/25/2021 - Wednesday Continue to RIH with ESP completion on 2-7/8", 6.4#, L-80, EUE 8rd tubing per tally spooling ESP cable, installing cross coupling clamp and testing electrical continuity every 2,000' from 5,615' to 9,650'. MU the landing joint to the 11" x 2-7/8" WKM tubing hanger. MU the TIW to the landing joint and MU the tubing hanger to the completion. Cut ESP cable and splice to the tubing hanger penetrator. MU penetrator to the tubing hanger. Dummy off the control line port. Test electrical continuity - good. SimOps: Move the pipe racks and catwalk away from the rig. Land the ESP completion at 9,685' and RILDS. Test electrical continuity - good. PU = 63K and SO = 38K. Test between upper and lower hanger body seals - good. Install BPV. Clear the rig floor of ESP running tools. RD the ESP cable sheave. Blow down and RD lines to the pump skid. Roll up herculite. RD the floor. Blow down and RD line to the kill tank. LD the derrick, moved rig off mud boat, spot in crane and removed rig floor and wellhouse. Removed BOP stack with crane, Baker and wellhead reps made their final checks. NU tree, tested void to 500/ 5,000 psi. Move to L-47. See L-47 report. _____________________________________________________________________________________ Revised By: DH 9/13/2021 SCHEMATIC Milne Point Unit Well: MPU L-04 Last Completed: 8/25/2021 PTD: 190-038 TD = 10,716 (MD) / TD = 7,608’(TVD) 13-3/8” Orig. KB Elev.:56’/ GL Elev.:21’ Nordic 3: 33.00’ RKB to THF 7” 9-5/8” PBTD =10,609’ (MD) / PBTD = 7,518’(TVD) KUP C1 KUP B6 KUP A3 KUP A2 KUP A1 Est TOC 8,900’ 13 2 1 3 4 5, 6 &7 8 12 9&10 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / J-55 / BTC 8.765 Surface 6,227’ 7" Production 26 / L-80 / BTC 6.151 Surface 10,697’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 9,685’ JEWELRY DETAIL No Depth Item 1202’GLM STA# 2: 2-7/8” w/ 1" OV (BK Latch) 29,481’GLM STA# 1: 2-7/8” w/ 1" DV (BK Latch) 3 9,529’ 2.313” XN-Nipple (2.205” No-Go) 4 9,572’ Discharge Head: DSCHG B/O PMP 400 5 9,573’ ESP Pump: 400PMSXD 134 FLEX 17.5 6 9,597’ ESP Pump: 400PMSXD 134 FLEX 17.5 7 9,620’ ESP Pump: 400PMSXD 134 FLEX 17.5 8 9,644’ Gas Separator: Centrilift 538GSTHVEVZ MT 9 9,650’ Upper Tandem Seal: Centrilift GSBDB H6 SB/AB PFSA 10 9,657’ Lower Tandem Seal: Centrilift GSBDB H6 SB/AB PFSA 11 9,664’ ESP Motor: Centrilift 562XP 250/2505/61 12 9,680’ Motor Gauge, Centrilift Zenith 13 9,683’ Centralizer, bottom at 9,685’ PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/B6 Silt 10,156’ 10,235’ 7,151’ 7,212’ 79 9/20/1990 Open A3 Sands 10,256’ 10,270’ 7,229’ 7,240’ 14 9/20/1990 Open A2 Sands 10,276’ 10,300’ 7,244’ 7,263’ 24 9/20/1990 Open A1 Sands 10,313’ 10,343’ 7,274’ 7,297’ 30 9/20/1990 Open WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 54 deg. @ 4,200’ Hole Angle thru perfs+39 Deg. TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M Tubing Hanger 2-7/8”WKM, Top and Bottom GENERAL WELL INFO API: 50-029-22029-00-00 Drilled and Cased by Nabors 27E - Sept 1990 ESP RWO by Nabors 4ES - 8/14/1995 ESP RWO by Nabors 4ES – 8/4/1997 ESP RWO by Nabors 4ES – 2/14/2000 ESP RWO by Nabors 4ES – 5/15/2001 ESP RWO by Nabors 4ES – 12/29/2005 ESP RWO by Doyon 16 – 2/2/2014 ESP Change-out by Nordic 3 – 4/4/2015 ESP Change-out by ASR – 8/13/2018 ESP Change-out by ASR – 8-25-2021 OPEN HOLE / CEMENT DETAIL 13-3/8” 485 sks Permafrost “C” 9-5/8” 305 bbls Arctic Set and IV & 67 bbls Class”G”in a 12.25” Hole 7” 85 bbls Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 10,156’ to 10,343’ – 128,320 lbs. 16/20 mesh Carbolite 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: ESP Change Out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,716'N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade:Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 190-038 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22029-00-00 Hilcorp Alaska LLC Length Size 7,608' 10,609' 7,518' 2,402 N/A Milne Point Field / Kuparuk River Oil 115' 115' 6.5#/ L-80/ EUE 8rd TVD Burst 10,061' MD 1,730psi 3,520psi 7,240psi 4,649' 7,592' 6,227' 10,697' Perforation Depth MD (ft): See Schematic See Schematic 82' 13-3/8" 9-5/8" 7" 6,194' 10,664' Perforation Depth TVD (ft): MILNE PT UNIT L-04 C.O. 432D TriPoint ESP and N/a 2,509 MD/ 2,262 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/20/2021 2-7/8" ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:35 am, Aug 12, 2021 321-397 Chad Helgeson (1517) 2021.08.12 09:11:36 - 08'00' MGR12AUG2021 DLB 08/12/2021 DSR-8/16/21 BOPE test to 3000 psi. Annular to 2500 psi. X 10-404 2,402 dts 8/17/2021 JLC 8/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.17 09:47:25 -08'00' RBDMS HEW 8/19/2021 ESP Change Out Well: MPU L-04 Date: 8/11/2021 Well Name:MPU L-04 API Number:50-029-22029-00 Current Status:SI Oil Well [ESP]Pad:L-Pad Estimated Start Date:8/20/2021 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:190-038 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Current Bottom Hole Pressure: 3,123 psi @ 7,212’ TVD (SBHPS 7/28/2021 / 8.33 ppg EMW) Maximum Expected BHP:3,123 psi @ 7,212’ TVD (No new perfs being added) MPSP:2,402 psi (0.1 psi/ft gas gradient) Max DL: 8.64° @ 864’ MD Max Inc: 52° Min ID: 2.205 XN @ 9,939’ MD Brief Well Summary: MPU L-04 was drilled in April 1990, fracture stimulated and completed as an ESP lifted Kuparuk River producer in September 1990. ESP installation history: September 1990 (initial), July 1991, August 1995, August 1997, February 2000, May 2001, December 2005, February 2014, and May 2015. ESP performance had degraded significantly in April 2017 and the ESP was replaced in 2018. Current ESP ran from 2018 and failed when the power was lost to the well on 7/13/2021. After attempting to re-start the ESP it was found the ESP power was grounded below the wellhead. Notes Regarding Wellbore Condition x The 7” production casing was tested to 1,500 psi at 9,738’ MD on 4/4/2015 and to 2,000 psi at 2,509’ MD on 8/13/2018. x Per CO 390A, the BHP is below 8.55 ppg EMW and an ESP packer will not be required. x Pulled the DGLV at station #1 (9,892’) and left the pocket open on 7/29/2021. x Freeze protected the well on 7/30/21 with diesel. x Completed a TBG caliper run on 8/1/21 indicating tubing was in good condition (>96% remaining wall area). x Offset Injectors: o L-08 (currently Shut-in) o L-24 (Currently shut-in) Objective: Pull the ESP packer and the failed ESP and run a new ESP (no ESP packer). Pre-Rig Procedure: 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 bbl returns tank. 4. Pressure test lines to 3,000 psi. ESP Change Out Well: MPU L-04 Date: 8/11/2021 5. Circulate 345 bbls with 8.6 ppg KCL water down the tubing taking returns up the IA. (Note: Ensure e packer vent valve is open and circulate the IA below and above the packer through the vent vale, and may require slower pumping than normal.) Notify Operations Engineer with the well kill results. 6. Confirm well is dead. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 11. NU/Test BOPE to 250 psi Low/ 3,000 psi High, 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 ram on 2-7/8” Test joint e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 12. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 13. Bleed any pressure off casing to the returns tank. Pull TWC. Kill well with 8.6 ppg KCl as needed. 14. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2018 ESP swap was 69 K lbs (no ESP packer). b. The ESP packer is set to release with 40 K-lbs PU weight over string weight above the packer. Estimate the packer should release pulling an estimated 65 K-lbs. Contact the operations Engineer before pulling more than 70 K-lbs to release the packer. c. Monitor IA pressure after releasing the packer, potential trapped gas under the packer. d. Circulate the wellbore with 8.6 ppg KCl to rebalance the wellbore fluids as needed. Verify the well is static. ESP Change Out Well: MPU L-04 Date: 8/11/2021 e. Ensure the packer elements are giving time (30min-1 hr) to relax before pulling over string weight. Confirm with Engineer if having to pull more than 20% over string weight. 15. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8” tubing and ESP packer. Number all joints. Tubing will be re-used as noted. Lay down the failed ESP. a. Replace bad joints of tubing as necessary.Replace all joints between jts 60 – 120 per the TBG caliper on 8/2/2021. b. Look for over-torqued connections from previous tubing runs. c. Document any electrical cable bad spots that might be the cause of the electrical failure. 17. PU a new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ a. Base of ESP at ± 10,057’ MD b. 2-7/8” XN (2.205” No-Go) Nipple c. 1 joint of 2-7/8”, 6.5#, L-80, EUE 8rd tubing d. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV e. ± XXX joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing f. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV g. ± XXX joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 18. Land tubing hanger (Caution not to damage cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 19. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: NLW 07/30/21 SCHEMATIC Milne Point Unit Well: MPU L-04 PTD: 190-038 TD = 10,716 (MD) / TD = 7,608’(TVD) 13-3/8” Orig. KB Elev.: 56’/ GL Elev.: 21’ Nordic 3: 33.00’ RKB to THF 7” 9-5/8” PBTD =10,609’ (MD) / PBTD = 7,518’(TVD) KUP C1 KUP B6 KUP A3 KUP A2 KUP A1 Est TOC 8,900’ 5 15 2 4 1 7 3 6 8 9& 10 11 12 & 13 14 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / J-55 / BTC 8.765 Surface 6,227’ 7" Production 26 / L-80 / BTC 6.151 Surface 10,697’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 10,061’ JEWELRY DETAIL No Depth Item 1143’GLM STA# 4: 2-7/8” Camco w/ 1" DGLV (BK Latch) 22,446’GLM STA# 3: 2-7/8” Camco w/ 1" DGLV (BK Latch) 3 2,509’ TriPoint ESP PKR 7" X 2-7/8" W/ Weatherford Vent Valve X 3/8" Control 4 2,547’ 2-7/8” X profile W/ RHCM installed (2.313” Packing Bore) 52,590’GLM STA# 2: 2-7/8” Camco w/ 1" OV (BK Latch) 69,892’GLM STA# 1: 2-7/8” Camco w/ 1" (Empty) 7 9,939’ 2-7/8” XN-Nipple (2.205” No-Go) 8 9,981.7’ Discharge Head: FPDIS 9 9,982’ ESP Pump: 134FLEX17.5 SXD H6 10 10,006’ ESP Pump: 134FLEX17.5 SXD H6 11 10,029’ Gas Separator: GSHVVX H6 FER 12 10,033’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 13 10,040’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 14 10,046’ ESP Motor: CL5 Model XP 15 10,057’ Sensor Pheonix XT150 w/ Centralizer Bottom: 10,061’ PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/B6 Silt 10,156’ 10,235’ 7,151’ 7,212’ 79 9/20/1990 Open A3 Sands 10,256’ 10,270’ 7,229’ 7,240’ 14 9/20/1990 Open A2 Sands 10,276’ 10,300’ 7,244’ 7,263’ 24 9/20/1990 Open A1 Sands 10,313’ 10,343’ 7,274’ 7,297’ 30 9/20/1990 Open WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 54 deg. @ 4,200’ Hole Angle thru perfs+39 Deg. TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M Tubing Hanger 2-7/8”WKM, Top and Bottom GENERAL WELL INFO API: 50-029-22029-00-00 Drilled and Cased by Nabors 27E - Sept 1990 ESP RWO by Nabors 4ES - 8/14/1995 ESP RWO by Nabors 4ES - 8/4/1997 ESP RWO by Nabors 4ES – 2/14/2000 ESP RWO by Nabors 4ES – 5/15/2001 ESP RWO by Nabors 4ES – 12/29/2005 ESP RWO by Doyon 16 – 2/2/2014 ESP Change-out Nordic 3 – 4/4/2015 ESP Change-out ASR – 8/13/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 485 sks Permafrost “C” 9-5/8” 305 bbls Arctic Set and IV & 67 bbls Class”G”in a 12.25” Hole 7” 85 bbls Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 10,156’ to 10,343’ – 128,320 lbs. 16/20 mesh Carbolite _____________________________________________________________________________________ Revised By: TDF 7/30/2021 PROPOSED Milne Point Unit Well: MPU L-04 Last Completed: Proposed PTD: 190-038 TD = 10,716 (MD) / TD = 7,608’(TVD) 13-3/8” Orig. KB Elev.: 56’/ GL Elev.: 21’ Nordic 3: 33.00’ RKB to THF 7” 9-5/8” PBTD =10,609’ (MD) / PBTD = 7,518’(TVD) KUP C1 KUP B6 KUP A3 KUP A2 KUP A1 Est TOC 8,900’ 11 2 1 3 4 5 &6 7 8&9 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / J-55 / BTC 8.765 Surface 6,227’ 7" Production 26 / L-80 / BTC 6.151 Surface 10,697’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf ±10,057’ JEWELRY DETAIL No Depth Item 1 ±200’GLM STA# 2: 2-7/8” w/ 1" (OGLV) 2 ±9,892’GLM STA# 1: 2-7/8” w/ 1" DGLV (BK Latch) 3 ±9,939’ 2-7/8” XN-Nipple (2.205” No-Go) 4 ±9,982’ Discharge Head: 5 ±9,983’ ESP Pump: 6 ±10,006’ ESP Pump: 7 ±10,029’ Gas Separator: 8 ±10,033’ Upper Tandem Seal: 9 ±10,040’ Lower Tandem Seal: 10 ±10,046’ ESP Motor: 11 ±10,056’ Sensor Pheonix XT150 w/ Centralizer Bottom: ±10,057’ PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/B6 Silt 10,156’ 10,235’ 7,151’ 7,212’ 79 9/20/1990 Open A3 Sands 10,256’ 10,270’ 7,229’ 7,240’ 14 9/20/1990 Open A2 Sands 10,276’ 10,300’ 7,244’ 7,263’ 24 9/20/1990 Open A1 Sands 10,313’ 10,343’ 7,274’ 7,297’ 30 9/20/1990 Open WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 54 deg. @ 4,200’ Hole Angle thru perfs+39 Deg. TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M Tubing Hanger 2-7/8”WKM, Top and Bottom GENERAL WELL INFO API: 50-029-22029-00-00 Drilled and Cased by Nabors 27E - Sept 1990 ESP RWO by Nabors 4ES - 8/14/1995 ESP RWO by Nabors 4ES - 8/4/1997 ESP RWO by Nabors 4ES – 2/14/2000 ESP RWO by Nabors 4ES – 5/15/2001 ESP RWO by Nabors 4ES – 12/29/2005 ESP RWO by Doyon 16 – 2/2/2014 ESP Change-out Nordic 3 – 4/4/2015 ESP Change-out ASR – 8/13/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 485 sks Permafrost “C” 9-5/8” 305 bbls Arctic Set and IV & 67 bbls Class”G”in a 12.25” Hole 7” 85 bbls Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 10,156’ to 10,343’ – 128,320 lbs. 16/20 mesh Carbolite Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL MPU L-04 (PTD 190-038) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/10/2021 By Abby Bell at 3:21 pm, Aug 09, 2021 of T� THE STAIP Alaska it and 4as „ LAsKAL�,,;`s Conservati®n Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 ® *'� Main: 907 279 1433 F ALASY'P Fax 907.276.7542 www.aogcc.alaska.gov Bo York SCOW JUN 0LU1a Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-04 Permit to Drill Number: 190-038 Sundry Number: 318-234 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Commissioner DATED this le-day of June, 2018. RBDMS1' JUN 182018 ' 0 0 RECERID JUN 0 STATE OF ALASKA ` � � ALASKA OIL AND GAS CONSERVATION COMMISSION Or 5 (y I 15 1 1 APPLICATION FOR SUNDRY APPROVALS Aknof 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 • Pull Tubing Q - Change Approved Progfam❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-o$t ❑ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development D • 190-038 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22029-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D _ Will planned perforations require a spacing exception? Yes inNo ❑., MILNE PT UNIT L-04 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 • Milne Point Field/Kuparuk River Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,716'• 7,608' • 10,609' 7,518' 3,043 N/A N/A' Casing Length Size MD TVD Burst Collap e Conductor 82' 13-3/8" 115' 115' 1,730psi 740p i Surface 6,194' 9-5/8" 6,227' 4,649' 3,520psi 2,020 si Production 10,664' 7" 10,697' 7,592' 7,240psi 5,410 i Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1 See Schematic See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 10,046' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/14/2018 OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhOlat hiICOrp.COm ''''-'8.-------------- Contact Phone: 777-8412 Authorized Signature: Date: 5/31/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:1 1 Plug Integrity ❑ BOP Test illMechanical Integrity Test ❑ Location Clearance G Other: LJee,.`.5 lieVLC ,R6-55'4,02(.J)Q r --rerf 7'0 3S6er,S Post Initial Injection MIT Req'd? Yes ❑ No LTJ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: :74(..41ji„ COMMISSIONER HE COMMISSION Date: 6_�S , fe 7 Submit Form and RBDMS.1 JUN 181018 OR IG1NATL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. DuplicateAttachment , ��� in 4,C, . 14 i Well Prognosis Well: MPU L-04 Ilileurp Alaska,LLI Date:5/30/2018 Well Name: MPU L-04 API Number: 50-029-22029-00 Current Status: SI Oil Well [ESP] Pad: L-Pad Estimated Start Date: June 14th, 2018 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-038 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Job Type: 'ESP Repair Current Bottom Hole Pressure: 3,743 psi @ 7,000'TVDss (SBHPS 4/24/2018/10.28 ppg EMW) Maximum Expected BHP: 3,743 psi @ 7,000'TVDss (No new perfs being added) MPSP: 3,043 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-04 was drilled in April, fracture stimulated and completed as an ESP lifted Kuparuk River producer in September 1990. ESP installation history: September 1990(initial),July 1991,August 1995,August 1997, February 2000, May 2001, December 2005, February 2014, and May 2015. ESP performance had degraded significantly in April 2017 and recently failed in April 2018. Notes Regarding Wellbore Condition • The 7" production casing was tested to 1500 psi at 9,738' MD on April 4, 2015. • Per CO 390A,the BHP is above 8.55 ppg EMW and an ESP packer will be required. Objective: The purpose of this work is to pull the failed ESP, spot a scale inhibitor squeeze and run a new ESP. Pre-Rig Procedure: 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 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 10.8 ppg NaBr brine down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU L-04 Hilcorp Alaska,Lb Date:5/30/2018 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/10.8 ppg NaBr brine prior to pulling BPV. Sem C. 12. Test BOPE to 250 psi Low/3,500 psi High, annular to 250 psi Low/3,500 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 dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/10.8 ppg NaBr brine as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 110K lbs. (block weight not noted) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. PU 6" bit and 7" 26#string mill assembly. . 15 • Well Prognosis Well: MPU L-04 Hilcorp Alaska,LLI Date:5/30/2018 19. RIH '10,609' MD (PBTD or as deep as possible through perforated interval) on 3-1/2" workstring. Circulate the well clean with 10.8 ppg NaBr brine.Attempt to clean out any fill encountered. 20. PU to 10,150' MD above the top perfs. 21. Mix and pump 48.5 bbl of pre-flush (7.5% mutual solvent WAW5206), 37.0 bbl of squeeze pill (12.5%scale inhibitor SCW4004), and 358 bbl of displacement 10.8 ppg NaBr brine. [Scale Inhibitor Treatment]. 22. POOH and LD 3-1/2" workstring and 7" string mill assembly. 23. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP assembly at± 10,045' MD. a. Top GLM @ ± 140' MD w/SO b. Upper Middle GLM @ ±2,440' MD w/ DGLV c. ESP Packer @ ±2,500' MD w/vent valve and control line d. 2-7/8" X(2.313" Profile) @ ±2,525' MD e. Lower Middle GLM @ ±2,575' MD w/ DGLV f. Bottom GLM @ ±9,890' MD w/DGLV g. 2-7/8" XN (2.205" No-Go) @ ±9,950' MD [Pre-load RHC plug body] h. Base of ESP centralizer @ ± 10,045' MD i. Test ESP cable at least every 1,000'. Utilize cross collar and mid-joint clamps as needed. 24. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Freeze protect inner annulus taking returns out the tubing (+/-80 bbl). SI inner annulus. 26. Drop ball and rod. Allow to fall for approximately 10 minutes to land. 27. Pressure up to 3,900 psi down tubing to set ESP packer. 28. Hold pressure on tubing to 3,900 psi for 30 min and chart. 29. Bleed tubing to 0 psi. 30. Test inner annulus to 2,000 psi for 30 min and chart. Monitor tubing for packer leak. 31. Bleed inner annulus to 0 psi. 32. Lay down landing joint. Set BPV. Post-Rig Procedure: 33. RD mud boat. RD BOPE house. Move to next well location. 34. RU crane. ND BOPE. 35. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 36. RD crane. Move 500 bbl returns tank and rig mats to next well location. 37. Replace gauge(s) if removed. 38. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic • • Well Prognosis Well: MPU L-04 IIileorn Alaska,LLI Date:5/30/2018 4. Existing Tree/Wellhead 5. Blank RWO Sundry Change Form Milne Point Unit . H . III Well: MPU L-04 SCHEMATIC Last Completed: 4/4/2015 Hamra Alaska,LLC PTD: 190-038 TREE&WELLHEAD Orig.KBEIev.:35'/GLEIev.:21' Tree WKM 2-9/16"5M 4 't L4 Wellhead WKM 11" 5M id Tubing Hanger 2-7/8"WKM,Top and Bottom 13-3/8' , OPEN HOLE/CEMENT DETAIL 1 w 13-3/8" 485 sks Permafrost"C" 9-5/8" 305 bbls Arctic Set and IV &67 bbls Class"G"in a 12.25"Hole 7" 85 bbls Class"G"in a 8.5"Hole r A CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 9-5/8„ A k _13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' 9-5/8" Surface 36/J-55/Btrc. 8.765 Surface 6,227' 7" Production 26/L-80/Btrc 6.151 Surface 10,697' TUBING DETAIL 2 7/8 Tubing 6.5/L-80/EUE 8rd 2.347 Surf 10,046' 3/8" Capstring Stainless Steel N/A N/A 10,046' WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=54 deg. @ 4,200' Hole Angle thru perfs+39 Deg. JEWELRY DETAIL No Depth Item 1 144' Sta#2 2-7/8"GLM with 1"BK latch-s/o glv set 1/25/18 2 9,804' Sta#1 2-7/8"GLM with 1"BK latch-dglv set 3/21/17 3/8"SS Capstring 3 9,981' XN-Nipple 4 9,991.6' Discharge Head: 5 9,992' Pump:160P11 PMSSD1 AR 6 10,013' Gas Separator: GPXARCINT H6 7 10,014' Upper Tandem Seal Assembly:GSB3DBUT SB/SB PFSA �, 8 10,021' Lower Tandem Seal Assembly: GSB3DBUT SB/SB PFSA 4 v2 8u' 9 10,028' Motor:CL5 MSP-250,168hp/2,295V/45A t" I fy 10 10,042' Sensor w/6 Fin Centralizer-Bottom @ 10,046 - PERFORATION DETAIL t Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 4 01) 3 s„ C/B Silt 10,156' 10,235' 7,151' 7,212' 79 9/20/1990 Open 4 A3 Sands 10,256' 10,270' 7,229' 7,240' 14 9/20/1990 Open A2 Sands 10,276' 10,300' 7,244' 7,263' 24 9/20/1990 Open Al Sands 10,313' 10,343' 7,274' 7,297' 30 9/20/1990 Open 0.,"' 4 STIMULATION DETAIL •I Interval:10,156'to 10,343'- t 1i5 128,320 lbs.16/20 mesh Carbolite 7 GENERAL WELL INFO * API:50-029-22029-00-00 t; 8&9 Drilled and Cased by Nabors 27E -Sept 1990 ;1' ESP RWO by Nabors 4ES -8/14/1995 ESP RWO by Nabors 4ES -8/4/1997 '�10 ESP RWO by Nabors 4ES-2/14/2000 w ESP RWO by Nabors 4ES-5/15/2001 iii Kl�Sands ESP RWO by Nabors 4ES-12/29/2005 ESP RWO by Doyon 16-2/2/2014 ,' ESP Change-out Nordic 3-4/4/2015 v i 7„A IIS TD=10,716(MD)/TD=3,608'(TVD) PBTD=10,609'(MD)/PBTD=7,518'(TVD) Revised By:BK 1/25/2018 • Milne Point Unit • • Well: MPU L-04 PROPOSED Last Completed: Proposed Itiho�u Alaska,LLC PTD: 190-038 Orig.KB Elev.:56'/GL Elev.:21' TREE&WELLHEAD Nordic 3: 33.00'RKB to THF Tree WKM 2-9/16"5M LWellhead WKM 11" 5M Tubing Hanger 2-7/8"WKM,Top and Bottom 13-3/8" 1 OPEN HOLE/CEMENT DETAIL 13-3/8" 485 sks Permafrost"C" 9-5/8" 305 bbls Arctic Set and IV &67 bbls Class"G"in a 12.25"Hole 7" 85 bbls Class"G"in a 8.5"Hole 1 I CASING DETAIL i Size Type Wt/Grade/Conn Drift ID Top Btm 2 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' 9-5/8" Surface 36/J-55/BTC 8.765 Surface 6,227' 7" Production 26/L-80/BTC 6.151 Surface 10,697' 4 l' 3 TUBING DETAIL 4 2 7/8 Tubing 6.5/L-80/EUE 8rd 2.347 Surf 10,045' 1 5 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=54 deg. @ 4,200' 9-5/8"`, ► Hole Angle thru perfs+39 Deg. JEWELRY DETAIL No Depth Item 1 ±140' GLM STA#4:2-7/8"x 1"GLM w/SO ) 2 ±2,440' GLM STA#3:2-7/8"x 1"GLM w/DGLV 3 ±2,500' TriPoint ESP Packer w/WFD Annular Vent Valve w/control line 4 ±2,525' 2-7/8"X profile(2.313"Packing Bore) 5 ±2,575' GLM STA#2:2-7/8"x 1"GLM w/DGLV Est TOC 8,900' 6 ±9,890' GLM STA#1:2-7/8"x 1"GLM w/DGLV 7 ±9,950' 2-7/8"XN-Nipple(2.205"No-Go) 8 ±9,990' Discharge Head 9 ±9,992' ESP Pump 6 10 ±10,014' Gas Separator 11 ±10,015' Upper Tandem Seal 12 ±10,021' Lower Tandem Seal 3 7 ' 13 ±10,030' ESP Motor 14 ±10,043' Sensor w/Centralizer Bottom:10,045' 'j 8 9 PERFORATION DETAIL 1. 10 Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status C1/B6 Silt 10,156' 10,235' 7,151' 7,212' 79 9/20/1990 Open 11 A3 Sands 10,256' 10,270' 7,229' 7,240' 14 9/20/1990 Open LTi 12 A2 Sands 10,276' 10,300' 7,244' 7,263' 24 9/20/1990 Open Al Sands 10,313' 10,343' 7,274' 7,297' 30 9/20/1990 Open 13 STIMULATION DETAIL Interval:10,156'to 10,343'- m l 128,320 lbs.16/20 mesh Carbolite 14 KUP c1 GENERAL WELL INFO KUP B6 API:50-029-22029-00-00 KUP A3 Drilled and Cased by Nabors 27E -Sept 1990 KUP A2 ESP RWO b Nabors 4ES 8/14/1995 - KUP Al Y ESP RWO by Nabors 4ES -8/4/1997 ESP RWO by Nabors 4ES-2/14/2000 7 A I' ESP RWO by Nabors 4ES-5/15/2001 TD=10,716(MD)/TD=7,608'(TVD) ESP RWO by Nabors 4ES-12/29/2005 PBTD=10,609'(MD)/PBTD=7,518'(TVD) ESP RWO by Doyon 16-2/2/2014 ESP Change-out Nordic 3-4/4/2015 Revised By:STP 5/30/2018 • • II Milne Point ASR Rig 1 BOPE 2018 11" BOPE , , Stripping Head r1 1 4.48' / -° if ydril GK (. 11" - 5000 i. lit illI Iii iiii?l i III III Ill III III 4.54' . l I CI U l ) H VBR or Pipe Rams . H 1 ( "- 5000IIIIIJ - Blind ®�11 III 111 Iii Ill II 21/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves 2.00' 1 &vs jiL ) `�� •L III■Illl■111�itI\II11t ' : " — ,` !9` I �-., HCR Manual Manual HCR Updated 5/14/2018 • II E STING TREE/WELLHEAD MPU L-04 Wellhead/Tree Hilrarp Alaska,Lu Milne Point Unit Tree Cap IMIlt AINEk tiPICIR(6):" Tree Valve 2-9/16" 5M *0 ,.. o mmit Tree Cross 2-9/16" 5M [ r>►w Tree Valve 2-9/16" 5M "o SSV 2-9/16" 5M , p Tree Valve 2-9/16" 5M - r:,(,:;,;) 000 ESP Cable �- Control Line ":" Tubing AdapterIF ,,, . _ ..wr .=. r, ®Mss 1111 I Tubing HeadI, im II, 1 1" 5M Top x 11" 5M Bt 1 —) ft, i ■11111 .. ,'1'j III li III - � 1-- I Casing Head IEurival 'J 11" 5M Top x 11" 5M Btm ��� � {1t v,r, 0 0 / § k te = / \ 2f / / � > g > \ \ 00_ 0, § < a0_ ± < — E © o SJ 22 00 > J f %< 2 $ aCL ±/ < c L- D 0 D0 22 $ \ � f I \ Ia)\ � \ / � CO % .@ a 3 2 \ ci 0 q % 01 Co / 4- CI) \ a a) \ § Qs / 0 >ct & \ \\ / % n \ 0 ) p0 2 \ C/) o \ 0 / 0 a) E § o_ \O k ./ § \/\ /S »7 / \ m / > k / g ° 0 0. k § ■ cri CD aC L n / Q.cl. CO\ 0 Cas - k ® \ / 0 0 rA « - 0 & .? t Z ¢ C .0 C & 0. 0. 00 wcr) 0 \ co 0 0 � E k / � 0. \ co - .0 c >0 a / U 3 / $ \ 0 o_ E STATE OF ALASKA AL __rKA OIL AND GAS CONSERVATION COMh.__,ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate Li Other pi ESP Cahnge-out Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 190-038 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22029-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509 MILNE PT UNIT KR L-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Fielde/Kuparuk River Oil 11.Present Well Condition Summary: RECEIVED Total Depth measured 10,716 feet Plugs measured N/A feet true vertical 7,608 feet Junk measured N/A feet P��.a}. P5 '015 Effective Depth measured 10,609 feet Packer measured N/A feet AD(3 CC true vertical 7,518 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 6,227' 9-5/8" 6,227' 4,649' 3,520psi 2,020psi Intermediate Production 10,697' 7" 10,697' 7,592' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic - �C�►NWED MAY 2 0 .O E True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/EUE 8rd 10,046' 7,068' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - Prior to well operation: 89 13 355 960 178 Subsequent to operation: 200 46 481 260 232 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil D Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 315-160 Contact Chris Kanyer Email ckanverahilcoro.com • Printed Name Chris Kanyer Title Operations Engineer Signature *------4-'•........4 Tom Fouts for Chris Kanyer Phone 907-777-8377 Date 5/5/2015 C RBDM�- MAY - 6 2015 Form 10-404 Revised 10/2012 i,r���� J'-7-1 Submit Original Only Milne Point Unit Well: MPU L-04 14 SCHEMATIC Last Completed: 4/4/2015 llilcorp Alaska'.LLC PTD: 190-038 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:21' Size Type Wt/Grade/Conn Drift ID Top Btm a • 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' 9-5/8" Surface 36/J-55/Btrc. 8.765 Surface 6,227' 13-3/8" II 7" Production 26/L-80/Btrc 6.151 Surface 10,697' i TUBING DETAIL 3-1/2" 1 Tubing 9.2/L-80/EUE 8rd 2.347 Surf 1 10,046' 3/8" Capstring Stainless Steel N/A N/A 10,046' JEWELRY DETAIL • No Depth Item 35/8' • 1 1 144' GLM 2 9,804' GLM 3 9,981' XN-Nipple 4 9,991.6' Discharge Head 5 9,992' Pump 6 10,013' Gas Separator - 7 , 10,014' Upper Tandem Seal Assembly 8 10,021' Lower Tandem Seal Assembly 9 10,028' Motor 10 10,042' Sensor w/6 Fin Centralizer-Bottom @ 10,046 PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status C/B Silt 10,156' 10,235' 7,151' 7,212' 79 9/20/1990 Open A3 Sands 10,256' 10,270' 7,229' 7,240' 14 9/20/1990 Open A2 Sands 10,276' 10,300' 7,244' 7,263' 24 9/20/1990 Open 3/8"SS Capstring '-... .3k Al Sands 10,313' 10,343' 7,274' 7,297' 30 9/20/1990 Open OPEN HOLE/CEMENT DETAIL 13-3/8" 485 sks Permafrost"C" 9-5/8" 305 bbls Arctic Set and IV &67 bbls Class"G"in a 12.25"Hole • 7" 85 bbls Class"G"in a 8.5"Hole 2 WELL INCLINATION DETAIL KOP@500' Max Hole Angle=54 deg. @ 4,200' Hole Angle thru perfs+39 Deg. a. 3 % TREE &WELLHEAD 4, Tree WKM 2-9/16"5M ' Wellhead WKM 11" 5M 1.4 Tubing Hanger 2-7/8"WKM,Top and Bottom 4 STIMULATION DETAIL 0.'5 Interval:10,156'to 10,343'- 6 128,320 lbs.16/20 mesh Carbolite [ i ', GENERAL WELL INFO API:50-029-22029-00-00 1 8 Drilled and Cased by Nabors 27E -Sept 1990 *:11ESP RWO by Nabors 4ES -8/14/1995 t•9 ESP RWO by Nabors 4ES -8/4/1997 ESP RWO by Nabors 4E5-2/14/2000 = ESP RWO by Nabors 4E5-5/15/2001 KUP Sands ESP RWO by Nabors 4E5-12/29/2005 ESP RWO by Doyon 16-2/2/2014 ESP Change-out Nordic 3-4/4/2015 7" A 1' TD=10,716(MD)/TD=7,608'(TVD) PBTD=10,609'(MD)/PBTD=7,51811VD) Created By:TDF 5/5/2015 Hilcorp Alaska, LLC , Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP L-04 50-029-22029-00-00 190-038 4/1/2015 4/5/2015 Daily Operations: 4/1/15-Wednesday Rig spotted and accepted . Berm cellar, rig up lines,off load hot saltwater, spot kill tank, pull BPV,SICP 1,000psi.SITP 6802si,_ri&up kill and choke lines.Blow down well to 100psi stable ISIP 220 psi. Line up and pump full GLM circ volume 304 bbls. Plentiful gas oil/water mix in returns,268 bbls recovered. ISIP 40 psi. Bull head 50 bbl to perfs and circ additional 60 bbls to vent tubing. Bleed of well to 10psi elect to set BPV w/lubricator. Let well stabilize during NDNU test ops. Utilizing lubricator set BPV. Proceed with ND NU operations. 4/2/15-Thursday PJSM. Resume ND Tree NU BOPE.Annulus pressure now 165.Check w/production Injector,not shut in.Order 9.5 ppg weighted brine to bring pits up to 9 ppg per Engineering. NU BOPEs,add 240 bbls 9.5 to existing volume to build 9.0 ppg NaCI.SIP fluctuating 160-185 psi. Install U and TIW valve w/1502 pump in sub. Discuss circ.9.Oppg conventionally due to BPV in hanger @ 2 bpm. Circ full hole volume no measurable losses.Observe well not quite static light blow not diminsihing,elect to weight up to 9.2ppg for trip margin safety with ESP cable and no shut in capabilities.Weight up pits/hole volume w/115 bbl diplacemnts and roll hole 9.2 all around.Some intermitent gas/oil still noted in BU returns between displacemnts.Observe well light vacuum both sides minor losses 6 bph est. BO/LD pump iron/landing joint/floor valve, remove BPV Install TWC Shell test 250psi low/3,000psi high.Test BOPE witness waived By AOGCC/ Hill 4/1/15 @ 0735 hrs. BOPE test 250psi low/3,000psi high.Annular Test 250psi low/2,500 psi high.Accumulator drawdown test all OK. LD test Joint, pull TWC, back out lockdowns PU 110 K hanger moving SW 105K pull to floor. Decomplete hanger& penetrators RU to strip line to spooler and POOH. 4/3/15-Friday PJSM. POOH with ESP completion. Recover ESP assy 2 GLMs x nipple LD 5 bad joints destroyed threads and 3 sanded up joints that were plugged and wet below the bottm GLM string pulled wet. Pull full length ESP assy to inspect for scale. Sand coated on outside of upper assembly Intake,clean Motor and Centralizer no sand or scale. BO/LD plugged singles and ESP assembly after full pull inspection. PU MU 7"26#Champ packer 12.75'to element. RIH with 102 stands from derrick, PU 3 singles.Circ down annulus.Set packer @ 9,738'w/20k dn.Test and Chart casing to 1500psi for 30 minutes. Bleed off open bypass release packer, PU 9 singles and RIH to 10,011'.Circ down annulus reverse circ 2 x tbg volume 114 bbl good returns minimal sand,oil water mix clean returns. POOH w/Champ Packer LD and replace 2 singles and get back on last break. 4/4/15-Saturday PJSM POOH BO/LD offload packer.Slip/n cut drilling line. PU MU ESP assembly and service same.String sheave with Cap and#2 cable connect same and check.3,100psi on check. RIH w/ESP on 2-7/8"6.5#L-80 tbg.Check cable and cap every 2,000' RIH to 9,068'.Swap spools in ESP spooler and perform splice @ 9,068'.Check valve tests 3,100-3,400 psi. Continue to RIH w/test cable, install hanger and penetrator. Make ESP cable top connection splice. Landing Hanger, Install BPV Run in lockdowns. Depths Hgr,PJ,3 jts 2-7/8"6.5#L-80 tbg, pup.,GLM @ 144', PJ,306 jts tbg, PJ,GLM @ 9804', PJ,5jts tbg,XN Nipple@ 9980',PJ, Discharge Head 9,991',Pump @ 9,992'gas separator@ 10,013', 2 tandem seals, Motor @ 10,028', Pumpmate@ 10,043',Centralizer bottom 10,046'. 4/5/15-Sunday ND BOPE NU Tree P/T void 250psi low/5000psi high.Wash down tree and cellar area RDMO. Rig release 4/6/15-Monday No operations to report. 4/7/15-Tuesday No operations to report. �w\�\OF..//77;,,,,774, /j,� THE STATE Alaska Oil and Gas �w - '01 ��� ofALASKA Conservation Commission x _ 333 West Seventh Avenue "44X77-, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALASICe. Fax• 907.276 7542 www.aogcc alaska.gov SCI$EU ;,, s 'y 'I I • Chris Kanyer Operations Engineer J q rj °33 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR L-04 Sundry Number: 315-160 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. 'oerster Chair DATED this 2' day of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 2 3 2015 ' ALASKA OIL AND GAS CONSERVATION COMMISSION PTS 3 I ac 7/3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑✓ Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate 0 Pull Tubing Q lime Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ESP Changeout ❑, 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number:..... p Hilcorp Alaska,LLC • Exploratory ❑ Development ❑• 493-038- Jq0 C)_3 3.Address: Stratigraphic El Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22029-00-00• 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O.432C- Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT KR L-04 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 . Milne Point Fielde/Kuparuk River Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,716 ' 7,608' - 10,609 ' 7,518 ' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 6,227' 9-5/8" 6,227' 4,649' 3,520psi 2,020psi Intermediate Production 10,697' 7" 10,697' 7,592' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 10,053 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal Q 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: 4/5/2015 Oil ❑., • Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer anhilcorp.com Printed Name Chris Kanyer Title Operations Engineer J Signature _i y Phone 777-8377 Date 3/23/2015 ✓ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t5 -1eo Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ,❑0 ) Other: X- 3 CitiL i /�S L. B oP e S/� ( i Y = 12:(`( f'z / Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / O -Y(�; Li sy APPROVED BY Approved by:a '---)19..x.„1,..)(2Lfz•-- COMMISSIONER THE COMMISSION Date:S.ZS L.S.--- --I t 01 �� ��fidiaG+NsAlizr ?A\ 3/24d1`5 .fith 3- -/S Submit Fop and Form 10-403 Revisi0/23012) p 12 months from he date o oval. Attach nts in Duplicate '0 ` l RBDMSU1 APR - 3 2015 Well Prognosis Well: MPL-04 Hilcory Alaska,LL' Date:3/23/2015 Well Name: MPL-04 API Number: 50-029-22029-00-00 Current Status: SI Producer Pad: L Pad Estimated Start Date: April 5, 2015 Rig: Nordic 3 Reg.Approval Req'd? April 3,2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-038 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550678 Current Bottom Hole Pressure: —2,950 psi @ 7,072' ND (Last BHP measured 3/2/2015) Maximum Expected BHP: —2,950 psi @ 7,072' ND (No new perfs being added) Max.Allowable Surface Pressure: 129 psi (Based on actual reservoir conditions and water cut of 73% (0.410psi/ft)with an added safety factor of 1000' ND of oil cap) O(<- Brief Well Summary: The Milne Point L-04 well was drilled as a Kuparuk development well that TD'd at 10,716' and ran and cemented 7" casing in April 1990. The well was initially completed with an ESP.This and subsequent ESPs failed and were replaced in 1995, 1997, 2000, 2001, 2005, and 2014. The recent pump failed March 2015. The most recent casing pressure test performed after initial cementing of casing on 4/8/90 to 3,000psi.A casing pressure test will be completed during this workover." ✓ 7- Due Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. RWO Objective: Pull ESP, run casing scraper, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) f a. Notify Operations Engineer(Hilcor), Mr.Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure Well Prognosis Well: MPL-04 Hilcorp Alaska,LL Date:3/23/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 10,053'to surface and lay down same. 6. RIH with 7"cleanout BHA to+/-10,150'. POOH with same. c'a 7. RIH and set test packer at+/-9,700' (within 500ft of open perforations). JL\ 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 9. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8"8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-10,053'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic n Well:Mile MPointPU L-0Unit4 • 11 SCHEMATIC Last Completed: 2/2/2014 Ililcarp Alaska,LLC PTD: 190-038 CASING DETAIL Orig.KBEIev.:35'/GLEIev.:21' Size Type Wt/Grade/Conn Drift ID Top Btm 4 t� 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' ; . J k 9-5/8" Surface 36/J-55/Btrc. 8.765 Surface 6,227' 3/g 7" Production 26/L-80/Btrc 6.151 Surface 10,697' t i TUBING DETAIL .. 2-7/8" Tubing 9.2/L-80/EUE 8rd 2.441 Surf 10,053' , JEWELRY DETAIL i., , No Depth Item 1 142' Camco 2-7/8"x 1"Sidepocket KBMM GLM w/DSOV d 2 9,803' Camco 2-7/8"x 1"Sidepocket KBMM GLM w/Dummy 9-5/8"A k 3 9,951' 2-7/8"XN-Nipple (2.441 No-go ID) 4 9,995' Pump,161P11 SDX 5 10,009' Tandem Gas Separator -Model:GRSFTX AR 6 10,021' Upper Tandem Seal Assembly-GSB3DBUT 7 10,028' Lower Tandem Seal Assembly-GSB3DBUT 8 10,049' Centrilift KMH Motor,168HP,3460 Volt,30 amp 9 10,051' Centrilift PumpMate w/6 Fin Centralizer-Bottom @ 10,053' PERFORATION DETAIL ,, Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status C/B Silt 10,156' 10,235' 7,151' 7,212' 79 9/20/1990 Open A3 Sands 10,256' 10,270' 7,229' 7,240' 14 9/20/1990 Open A2 Sands 10,276' 10,300' 7,244' 7,263' 24 9/20/1990 Open Al Sands 10,313' 10,343' 7,274' 7,297' 30 9/20/1990 Open OPEN HOLE/CEMENT DETAIL 13-3/8" 485 sks Permafrost"C" 9-5/8" 305 bbls Arctic Set and IV &67 bbls Class"G"in a 12.25"Hole 7" 85 bbls Class"G"in a 8.5"Hole WELL INCLINATION DETAIL 1� 14 KOP @ 500' " Max Hole Angle=54 deg. @ 4,200' 2 r'' Hole Angle thru perfs+39 Deg. TREE&WELLHEAD !' Tree WKM 2-9/16"5M 4 1119A< Wellhead WKM 11" 5M h )3 Tubing Hanger 2-7/8"WKM,Top and Bottom 1 a STIMULATION DETAIL a11 Interval:10,156'to 10,343'- :4 128,320 lbs.16/20 mesh Carbolite ,li 5 GENERAL WELL INFO '1a g API:50-029-22029-00-00 i� !7 Drilled and Cased by Nabors 27E -Sept 1990 t vsa irt C, ESP RWO by Nabors 4ES -8/14/1995 1ESP RWO by Nabors 4ES -8/4/1997 ct. IF 1+8 ESP RWO by Nabors 4ES-2/14/2000 ;i", _ .r ESP RWO by Nabors 4ES-5/15/2001 . '9 ESP RWO by Nabors 4ES-12/29/2005 ESP RWO by Doyon 16-2/2/2014 li .0 1}KUP Sands Y i I T 7 ` k: IP TD=10,716(MD)/TD=7,608'(TVD) PBTD=10,609'(N))/PBTD=7,5181ND) Created By:CVK 3/23/2015 Milne Point Unit . ii Well: MPU L-04 - PROPOSED Last Completed: 2/2/2014 Ili[carp Alaska,LLC PTD: 190-038 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:21' Size Type Wt/Grade/Conn Drift ID Top Btm 4 ` `` k 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' ' a 9-5/8" Surface 36/J-55/Btrc. 8.765 Surface _ 6,227' 13-3/8' .„ 7" Production 26/L-80/Btrc 6.151 Surface 10,697' 1 TUBING DETAIL 9. g. : I 3-1/2" Tubing I 9.2/L-80/EUE 8rd I 2.347 Surf I ±10,053' s: 3/8" Capstring Stainless Steel N/A N/A ±10,053' R R JEWELRY DETAIL it No Depth Item 9-5/8".4 i0 1 ±142' GLM 2 ±9,803' GLM 3 ±9,951' XN-Nipple 4 ±9,995' Pump 5 ±10,009' Tandem Gas Separator - 6 ±10,021' Upper Tandem Seal Assembly 7 _ ±10,028' Lower Tandem Seal Assembly 8 ±10,049' Motor 9 ±10,051' Sensor w/6 Fin Centralizer-Bottom @±10,053 PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status V C/B Silt 10,156' 10,235' 7,151' 7,212' 79 9/20/1990 Open A3 Sands 10,256' 10,270' 7,229' 7,240' 14 9/20/1990 Open A2 Sands 10,276' 10,300' 7,244' 7,263' 24 9/20/1990 Open - Al Sands 10,313' 10,343' 7,274' 7,297' 30 9/20/1990 Open 3/8"uCapstring OPEN HOLE/CEMENT DETAIL 13-3/8" 485 sks Permafrost"C" 9-5/8" 305 bbls Arctic Set and IV &67 bbls Class"G"in a 12.25"Hole ;, .A 7" 85 bbls Class"G"in a 8.5"Hole to 2 WELL INCLINATION DETAIL ' KOP @ 500' Max Hole Angle=54 deg. @ 4,200' ,., (, Hole Angle thru perfs+39 Deg. 'g TREE&WELLHEAD �i ( 3 Tree WKM 2-9/16"5M +h Wellhead WKM 11" 5M E rI'',4 Tubing Hanger 2-7/8"WKM,Top and Bottom V 4 STIMULATION DETAIL 11 Interval:10,156'to 10,343'- I 05 128,320 lbs.16/20 mesh Carbolite 4. .ice 5 ;; ' 7 GENERAL WELL INFO API:50-029-22029-00-00 °' Drilled and Cased by Nabors 27E -Sept 1990 ro ;�8 ESP RWO by Nabors 4ES -8/14/1995 '.,. a ESP RWO by Nabors 4ES -8/4/1997 F9 ESP RWO by Nabors 4ES-2/14/2000 ESP RWO by Nabors 4ES-5/15/2001 ESP RWO by Nabors 4ES-12/29/2005 KUP Sands ESP RWO by Doyon 16-2/2/2014 7" IP TD=10,716(MD)/TD=7,60811VD) PBTD=10,609'(MD)/PBTD=7,518'(TVD) Created By:CVK 3/23/2015 11" BOP Stack r I O O III iaiii Hydril 11" 5M i"i*"1 al:0 *Shaffer — 2 7/8-5.5 _ - variables _ /j .0_-____L\ 11" SM 0°D Blinds _ __ [41 t il 'PA 'pi 11"5M Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i(~ 0" 0.~,~ File Number of Well History File RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: B~Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd STATE OF ALASKA AL,soKA OIL AND GAS CONSERVATION COi,uuvIISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS FEB 2 8 2014 1. Operations Performed: /"1�rr'`V`i+ (� ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well V,i 1 ❑Alter Casing _ Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic I. 190-038 3. Address: ®Development 0 Service 6. API Numbe . P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22029-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL025509 ' MPL-04 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Kuparuk River Sands 11. Present well condition summary: Total depth: measured '• 10716' feet Plugs:(measured) None feet true vertical 7608' feet Junk:(measured) None feet Effective depth: measured • 10609' feet Packer: (measured) None feet true vertical 7518' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 13-3/8" 33'- 115' 33'- 115' 1740 750 Surface 6194' 9-5/8" 33'-6227' 33'-4649' 3520 2020 Intermediate Production 10664' 7" 33'- 10697' 33'-7592' 7240 5410 Liner Perforation Depth: Measured Depth: 10156'- 10343' feet SCAMAUG 1 4 2014 True Vertical Depth: 7152'-7298' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80 10053' 7073' Packers and SSSV(type,measured and true vertical depth): None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: RBDMS MAY 1 3 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 32 45 515 740 214 Subsequent to operation: 31 55 486 240 296 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: • 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: . ®Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Sean McLaughlin,564-4387 N/A Email: Sean.McLaughlin@bp.com Printed Name: Joe Lastu Title: Drilling Technologist Signature: ,X\J J&____—...\ Phone: 564-4091 Date:2124/14- Form 10-404 Revised 10/2012 JV/- r !`-- J j 4 Submit Original Only North America-ALASKA-BP Page 1 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date:1/29/2014 End Date:2/3/2014 X4-OOXX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table©36.00usft(above Mean Sea Level) Date From-To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 6/6/2013 00:00 - 04:00 4.00 MOB P PRE SPCC CHECKS AND PRE TOUR MEETING PREP FOR RDMO ON MPE-11 -FLUSH LINES WITH FRESH WATER -BLOW DOWN/RIG DOWN LINES -CLEAN PITS R/D SECONDARY KILL AND CEMENT LINES MOBILIZE EQUIPMENT IN PREPARATION FOR RIG MOVE -RIG DOWN 0/A LINE,INSTALL FLANGE 04:00 06:00 2.00 MOB P PRE PJSM FOR RIG MOVE OFF OF MPE-11 -NOTIFY PAD OPERATOR -NIGHT TOOLPUSHER 8 NIGHT WSL ON LOCATION -MOVE OFF OF MP E-11 TO EDGE OF MP E PAD INSTALL REAR BOOSTER TIRES 06:00 - 12:00 6.00 MOB N WAIT PRE GENERAL MAINTENANCE AND HOUSE I KEEPING. MOVE MATS FROM AROUND WELL MPE-11 '-CLOSE OUT WELL WORK TRANSFER FORM AND TURN WELL OVER TO PAD OPERATOR. -CLEAN REAR WHEEL WELL 12:00 - 00:00 12.00 MOB N WAIT PRE GENERAL MAINTENANCE AND HOUSEKEEPING -CHANGE CABLES ON TUGGERS -CONDUCT A DERRICK INSPECTION -CHANGE CABLE ON PIPE SKATE. 6/7/2013 00:00 - 07:00 7.00 MOB N WAIT PRE SPCC CHECKS,PRE-TOUR MEETING GENERAL MAINTENANCE AND HOUSEKEEPING -CLEAN FRONT WHEEL WELLS - AFTER CREW CHANGE AT MID NIGHT THE CREW WAS PREPARING TO CHANGE CABLES ON BEAVALATOR(EQUIPMENT ELEVATOR). THE BEVALATOR WAS LOWERED TO THE GROUND WHERE IT CAME IN CONTACT WITH THE LOADER THAT WAS PARKED AT THE BOTTOM OF THE ELEVATOR. -THE JOB WAS STOPPED AND AN INVESTIGATION WAS CONDUCTED. -SEE IR 4441964 07:00 - 17:00 10.00 MOB N WAIT PRE THE RIG WAS PLACED IN SAFETY STAND DOWN MODE UNDER CODE 8 WHILE THE INVESTIGATION CONTINUES AND REMEDIAL POLICIES ARE PUT IN PLACE AND APPROVED.IN DEPTH DISCUSSIONS HELD WITH CREW ON SAFETY TOPICS AND FOLLOWING PROCEDURES. 17:00 - 00:00 7.00 MOB N WAIT PRE GENERAL MAINTENANCE AND HOUSEKEEPING CHANGE OUT TUGGER CABLE RELEASE FROM MPL-04©2359 6-7-2013 NEW WELL CHARGES ON MPH-07©0000 6-8-2013 1/29/2014 12:00 - 15:00 3.00 MOB P PRE PJSM.PREPARE TO LAY OVER DERRICK. -LAY OVER DERRICK,TOOLPUSHER AND WSL PRESENT. Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date:1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table @36.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) • 15:00 - 16:30 1.50 MOB P PRE PJSM.NOTIFY DRILL SITE OPERATOR. -MOVE RIG OFF WELL,DOYON SUPERINTENDANT PRESENT. 16:30 - 18:30 2.00 MOB P PRE PJSM.REMOVE BOPE FROM CELLAR, SECURE ON PEDESTAL. -INSTALL REAR BOOSTER TIRES. -CLEAN UP AROUND WELL HEAD. 18:30 - 21:30 3.00 MOB P PRE PJSM.MOVE RIG TO MPL PAD. -STAGE RIG AND PREPARE TO REMOVE BOOSTER TIRES. 21:30 - 00:00 2.50 MOB P PRE PJSM.REMOVE REAR BOOSTER TIRES. -LAY MATS AND STAGE WELLHEAD EQUIPMENT BEHIND WELL. -INSTALL BOPE IN CELLAR AND LAY MATTING BOARDS. 1/30/2014 00:00 - 05:00 5.00 MOB P PRE PJSM.FINISH LAYING MAT BOARDS. -SPOT RIG OVER WELLAND SHIM. -PJSM.RAISE DERRICK AND PIN. -RIG UP FLOOR,RIG UP CELLAR,SPOT SLOP TANK. -BRIDLE DOWN.TAKE ON 11.9 PPG BRINE TO PITS. RIG ACCEPTED @ 04:00 HRS,01/30/2014. 05:00 - 09:00 4.00 KILLW P DECOMP HARDLINE CREW HERE @ 06:30 HRS. -RIG UP HARDLING TO FLOW BACK TANK -SPOT BLEED TRAILER. 09:00 - 10:00 1.00 KILLW P DECOMP PJSM.INSPECT FLOW BACK TANK& FUNCTION TEST ALARMS. -PRESSURE TEST SURFACE LINES TO 250/ 3500 PSI,5 MIN EACH,CHARTED. 10:00 - 10:30 0.50 KILLW P DECOMP PERFORM RIG EVACUATION DRILL. 1-SIMULATE FIRE IN BOILER ROOM,MILNE PT NOTIFIED. -ALL PERSONEL ON PAD NOTIFIED.GOOD (RESPONSE. -MR HELD. '10:30 - 12:00 1.50 WHSUR P DECOMP PJSM.RIG UP LUBRICATOR TO PULL BPV. -PRESSURE TEST LUBRICATOR @ 250/3500 PSI,5 MIN EACH. PULL BPV,RIG DOWN LUBRICATOR. -O/A=10 PSI,I/A=1460 PSI,TUBING PRESSURE=1620 PSI. 12:00 - 14:00 2.00 WHSUR P DECOMP PJSM.MOBILIZE TRUCKS FOR WELL KILL. -PREPARE CELLAR AREA. -CONDUCT PRE KILL MEETING WITH ALL PARTIES INVOLVED. -STRESS DOUBLE CHECKING VALVE ALIGNMENT AND GOOD COMMUNICATION TECHNIQUES. Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Pages of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date:1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table @36.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 KILLW P DECOMP LINE UP AND BLEED GAS FROM I/A THRU CHOKE TO FLOW BACK TANK -MAINTAIN LESS THAN 150 PSI DOWN STREAM OF CHOKE. -BLEED I/A FROM 1500 PSI TO 300 PSI,STILL SOME GAS IN FLUID RETURNS. -LINE UP AND PUMP DOWN TUBING @ 3 BPM,TAKING RETURNS UP I/ATHRU CHOKE TO FLOW BACK TANK. -PUMP 58 BBLS 11.9 PPG BRINE,INITIAL CIRC PRESSURE=1350 PSI @ 3 BPM. -WITH 58 BBLS PUMPED,3 BPM/400 PSI. -CLOSE CHOKE AND BULLHEAD 30 BBLS DOWN TUBING @ 3 BPM/750 PSI.I/A PRESSURE=1950 PSI WHILE BULLHEADING TUBING. -SHUT DOWN AND ALLOW PRESSURES TO STABILIZE. 16:00 - 17:00 1.00 KILLW P DECOMP PIT WATCHER OBSERVED WE SHOULD HAVE PUMPED 90 BBLS. -ONLY 60 BBLS PUMPED ACCORDING TO STRAP.PUMP OPERATING @ 66% EFFICIENCY. SOME INDICATION THAT THE#2 SUCTION VALVE ON MUD PUMP MAY NEED INSPECTING. -SHUT IN WELL,TUBING PRESSURE READING CLOSE TO 0 PSI. -BLOW DOWN LINE TO FLOWBACK TANK. SECURE WELL. -INSPECT VALVES ON MUD PUMP,ALL GOOD 17:00 - 18:30 1.50 KILLW P DECOMP PJSM.BULLHEAD DOWN TUBING. -BULLHEAD ANOTHER(30)BBLS DOWN TUBING,3 BPM/900 PSI. -I/A=2200 PSI,SLOW RATE TO 2 BPM/800 'PSI. -AFTER BULLHEADING(30)BBLS,ALLOW PRESSURES TO STABILIZE. 118:30 - 22:30 4.00 KILLW P DECOMP 1LINE UP AND PUMP DOWN TUBING @ 3.5 BPM,TAKING RETURNS UP IA THRU CHOKE TO FLOW BACK TANK. PUMP 150 BBLS 11.9 PPG BRINE,CIRC PRESSURE AT 3.5 BPM,TUBING=1250 PSI,IA =1450 PSI -SHUT DOWN AND CLOSE IN WELL,SUCK OUT TANK,RETURNS EQUAL BBLS PUMPED AND BLED -PUMP 350 BBLS MORE,FOR A TOTAL OF 450 BBLS 11.9 PPG BRINE DOWN TUBING TAKING RETURNS OUT IA TO FLOW BACK TANK -PUMP AT 3.5 BPM,TUBING ICP=1200 PSI, FCP=1050 PSI -IA ICP=900 PSI,FCP=150 PSI -SHUT DOWN PUMPS,TUBING=0 PSI,IA=0 PSI -STRAP FLOW BACK TANK,9 BBL LOSS ON CIRCULATION Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 4 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date. 1/29/2014 End Date:2/3/2014 X400XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table @36.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 KILLW P DECOMP MONITOR WELL FOR 30 MINUTES -WELL IS ON LOSSES -BLOW DOWN KILL MANIFOLD AND ALL CIRC LINES -R/U CIRCULATING LINES TO MAINTAIN CONSTANT HOLE FILL AND MONITORING WHILE NIPPLE DOWN -OA=65 PSI -24 HOUR LOSS=27 BBLS 11.9 BRINE -LOSS RATE=14 BPH 11.9 PPG BRINE 1/31/2014 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST 250/4000 PSI,5 MIN,CHART -SET TWC,R/D LUBRICATOR 01:30 - 02:30 1.00 WHSUR P DECOMP PERFORM ROLLING TEST BELOW TWC,500 PSI,5 MIN -TEST TWC FROM ABOVE,250/4000 PSI,5 MIN,CHART -BULLHEADED(12)BBLS TO ACHIEVE TEST, GOT(1)BBL BACK 02:30 - 04:00 1.50 WHSUR P DECOMP PJSM FOR N/D TREE WITH CAMERON REPS -N/D TREE AND ADAPTER FLANGE 04:00 - 06:00 2.00 BOPSUR P DECOMP PJSM,N/U BOP,RISER,FLOOR VALVES,TEST JOINTS FOR BOP TEST i-MAINTAIN CONSTANT HOLE FEED TO IA WITH 11.9 PPG BRINE KWF -LOSS RATE @ 05:00=11 BPH. 06:00 - 10:30 4.50 BOPSUR P DECOMP CONTINUE TO NIPPLE UP BOP EQUIPMENT. -MONTORING LOSS RATE,LOSS RATE STABILIZED i 8 BPH. -BODY TEST ON BOP AND NOTIFY STATE MAN READY TO TEST. 10:30 - 15:30 5.00 BOPSUR P DECOMP PJSM.CONDUCT FULL BOPE TEST. -TEST ALL RAMS @ 250/4000 PSI.USED 2 7/8"&4"TEST JTS. -(4)PREVENTOR STACK 2 7/8" X 5"VBRS, MUD CROSS,BLIND SHEAR RAMS,2 7/8"X 5" VBRS AND ANNULAR PREVENTOR. -TEST ANNULAR PREVENTOR @ 250/3500 PSI. -ALL CHOKE VALVES TESTED CO 250/4000 PSI.(5)MIN ON EACH TEST,CHARTED AND WITNESSED BYAOGCC INSPECTOR JEFF TURKINGTON. -NO FAILURES. 15:30 - 16:30 1.00 BOPSUR P DECOMP BLOW DOWN ALL SURFACE LINES AND EQUIPMENT,DRAIN BOP STACK -R/D ALL TEST EQUIPMENT 16:30 - 18:00 1.50 WHSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST 250/4000 PSI,5 MIN,CHART -PULL TWC,R/D LUBRICATOR 18:00 - 19:30 1.50 PULL P DECOMP PJSM,INSTALL BALES/ELEVATORS -M/U LANDING JOINT TO HANGER AND TOP DRIVE Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date:1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table @36.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 20:30 1.00 PULL P DECOMP PJSM,WSL VERIFY NO PRESSURE ON IA, CAMERON REP BOLDS -PULL HANGER FREE AT 115K,PUWT=105K -CUT ESP CABLE AT BOTTOM OF FIRST JOINT,POSITION SLICK PIPE ACROSS BOP STACK -CLOSE ANNULAR 20.30 - 21 00 0.50 PULL P DECOMP 'CIRCULATE 1 TUBING VOLUME TRU GAS BUSTER,3 BPM=660 PSI,LOSS 4 BBLS ON CIRC. MONITOR WELL,WELL IS ON LOSSES -LOSS RATE=8 BPH -MAINTAIN CONSTANT HOLE FILL WITH 11.9 PPG KWF 21:00 - 22:30 1.50 PULL P DECOMP PJSM,R/U ESP SHEAVE AND TRUNK -L/D HANGER,POOH AND PULL ESP CABLE TO SPOOLING UNIT 22:30 00:00 1.50 PULL P I DECOMP POOH,2 7/8"6.5#8RD EUE TUBING ESP COMPLETION -F/10044'T/9074' -OA=20 PSI LOSS RATE=9 BPH 24 HOUR FLUID LOSS=294 BBLS 11.9 PPG BRINE 2/1/2014 00:00 - 00:30 0.50 PULL P DECOMP PJSM,SPCC AND EQUIPMENT CHECKS SERVICE AND INSPECT DRAW WORKS 00:30 - 08:30 8.00 PULL P DECOMP POOH,2 7/8"6.5#8RD EUE TUBING ESP COMPLETION -F/9074'T/60'BHA -MAINTAIN CONSTANT HOLE FILL WITH 11.9 PPG KWF 08:30 - 11:00 2.50 PULL P DECOMP PJSM.REMOVE CLAMPS FROM MOTOR ASSEMBLY. -TERMINATE CABLE,BREAK DOWN AND LAY DOWN PUMP ASSEMBLY. -RECOVERED 165 LA SALLE CLAMPS,3 FLAT GUARDS AND 5 PROTECTROLIZERS. 11:00 - 12:00 1.00 PULL P DECOMP CLEAND RIG FLOOR. -FLUID LOSS RATE TO WELL BORE IS 9-12 BPH. -127 BBLS OF 11.9 BRINE LOST TO WELL IN LAST(12)HRS. 12 00 - 14 30 2.50 RUNCOM P RUNCMP CONTINUE TO CLEAN RIG FLOOR. -CAMERON COMPLETED DUMMY RUN AND REDRESS TUBING HANGER. -CENTRILIFT LOAD NEW ESP SPOOL. -PJSM.PULL ESP CABLE OVER SHEAVE TO RIG FLOOR. 1430 - 19.00 4.50 RUNCOM P RUNCMP PJSM.CENTRILIFT PERFORM ESP SPLICE. -DSOV AND DUMMY VALVES INSTALLED IN GLMS. FLUID LOSS RATE REMAINING @ 9-12 BPH. 19:00 - 22:00 3.00 RUNCOM P RUNCMP M/U CENTRILIFT PUMP AND MOTOR ASSY INSTALL ESP CABLE AND TEST,GOOD • Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 6 of 8 S mm OperationSummary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date:1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table©36.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 RUNCOM P RUNCMP RIH WITH 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/60'T/2025'MD INSTALL CLAMPS ON FIRST 9 JOINTS,THEN I EVERY OTHER TO SURFACE,TORQUE TO 2300 FT/# -CHECK CONDUCTIVITY AND PUMP 5 BBLS EVERY 2000',.5 BPM=1901 PSI -CROWN 0 MATIC TESTED,OK. -OA=40 PSI -LOSS RATE=9 BPH -24 HOUR FLUID LOSS=239 BBLS 11.9 PPG BRINE 2/2/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM,SPCC AND EQUIPMENT CHECKS -SERVICE AND INSPECT DRAW WORKS 00:30 - 07:30 7.00 RUNCOM I P RUNCMP PJSM,RIH WITH 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/2025'T/7752'MD -INSTALL CLAMPS ON FIRST 9 JOINTS,THEN EVERY OTHER TO SURFACE,TORQUE TO 2300 FT/# -CHECK CONDUCTIVITY AND PUMP 5 BBLS EVERY 2000',.5 BPM=1901 PSI • 07:30 - 12:30 5.00 RUNCOM P RUNCMP PJSM.PERFPRM REEL TO REEL SPLICE. -TEST CONDUCTIVITY,GOOD. 12:30 - 14:30 2.00 RUNCOM P RUNCMP PJSM.CONTINUE TO RUN IN HOLE W/ESP COMPLETION. -RIH F/7752'-10,052'W/2 7/8"6.5#EUE 8 RND TUBING. -TORQUING CONNECTIONS TO 2300 FT/LBS, USING BEST 0 LIFE PIPE DOPE. -CHECKING CONDUCTIVITY EVERY 2000' • 14:30 - 15:00 0.50 RUNCOM P RUNCMP PJSM.PICK UP LANDING JT. -MAKE UP HANGER AND ORIENT. -PERFORM CONDUCTIVITY TEST. -CUT ESP CABLE,INSTALL PENETRATOR. PUWT=103K,SOWT=77K 15:00 - 18:30 3.50 RUNCOM P RUNCMP CENTRILIFT TERMINATE ESP CABLE AT HANGER PENETRATOR -CHECK CONDUCTIVITY -R/D ESP SHEAVE AND CLEAR RIG FLOOR OF CENTRILIFT EQUIP -TOTAL CANNON CLAMPS=154 -PROTECTOLIZERS=5 FLAT GUARDS=3 18:30 - 19:00 0.50 RUNCOM P RUNCMP LAND HANGER IN TUBING SPOOL -WSL OBSERVE HANGER"J"INTO ALIGNMENT PIN 19:00 - 19:30 0.50 WHSUR P RUNCMP RUN IN LOCK DOWN SCREWS,CAMERON REP L/D LANDING JOINT -INSTALL TWC 19:30 - 20:30 1.00 WHSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW TWC,500 PSI,5 MIN,14 BBLS PUMPED -TEST TWC FROM ABOVE,250/3500 PSI,5 MIN,CHARTED Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 7 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date: 1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM 'Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table t36.00usft(above Mean Sea Level) Date From-To Hrs Task Code • NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:00 1.50 BOPSUR P RUNCMP FLUSH BOP STACK AND ALL SURFACE LINES WITH FRESH WATER -FUNCTION RAMS,DRAIN STACK,BLOW DOWN ALL LINES -MAINTAIN CONSTANT HOLE FILL WITH 11.9 PPG KWF 22:00 - 23:00 1.00 BOPSUR P RUNCMP PJSM,N/D BORE,RISER,TURNBUCKLES, PULL MOUSE HOLE,DISCONNECT KOOMEY LINES 23:00 - 00:00 1.00 WHSUR P RUNCMP CLEAN AND PREP HANGER -INSTALL ADAPTER AND WKM 2 9/16"-5M TREE ON WELL HEAD -OA=40 PSI -LOSS RATE=7 BPH -24 HOUR FLUID LOSS=150 BBLS 11.9 PPG BRINE 2/3/2014 00:00 - 01:00 1.00 WHSUR P RUNCMP PJSM,SPCC AND EQUIPMENT CHECKS -CHECK CROWN 0 MATIC,OK. -INSTALL ADAPTER AND WKM 2 9/16"-5M TREE ON WELL HEAD 01:00 - 01:30 0.50 RUNCOM P RUNCMP CENTRILIFT REP CHECK ESP CABLE CONDUCTIVITY=GOOD 01:30 - 03:30 2.00 WHSUR P RUNCMP CAMERON TEST ADAPTER FLANGE VOID -250 PSI LOW,5 MIN,5000 PSI HIGH 30 MIN, CHART 03:30 - 05:00 1.50 WHSUR P RUNCMP R/U AND FILL TREE WITH DIESEL -TEST,250/5000 PSI,5 MIN,CHART 05:00 - 06:00 1.00 WHSUR P RUNCMP R/U WELL SUPPORT LUBRICATOR -TEST 250/4000 PSI,5 MIN,CHART -PULL TWC,R/D LUBRICATOR 06:00 - 07:00 1.00 WHSUR P RUNCMP R/U WELL SUPPORT LUBRICATOR 1 '-TEST 250/4000 PSI,5 MIN,CHART -SET BPV,R/D LUBRICATOR Printed 2/17/2014 9:43:38AM North America-ALASKA-BP Page 8 of 8 Operation Summary Report Common Well Name:MPL-04 AFE No Event Type:WORKOVER(WO) Start Date: 1/29/2014 End Date:2/3/2014 X4-00XX8-E:(2,000,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/14/2001 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292202900 Active datum:Kelly Bushing/Rotary Table @36.00usft(above Mean Sea Level) Date From-To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 12:00 5.00 WHSUR P RUNCMP PJSM.RIG UP LITTLE RED FOR FREEZE PROTECT. -PRESSURE TEST LINES @ 250/3500 PSI,5 MIN EA/CHARTED. VERIFY MECHANICAL POP OFF ON PUMP SET @ 5000 PSI. -TRIP OUT ON PUMP WHILE PUMPING DOWN TUBING SET&TESTED @ 3000 PSI. -BULLHEAD 12 BBLS 80 DEGREE DIESEL THRU BPV DOWN TUBING. PUMPING 1/2 BPM DOWN TUBING,ICP= 2140 PSI&FCP=2450 PSI. -LINE UP TO PUMP DOWN I/A.SET AND TEST PUMP TRIP OUT @ 2000 PSI. BULLHEAD 63 BBLS DIESEL DOWN I/A @ 1 1/2 BPM.ICP=560 PSI,FCP=1120 PSI. -WHILE BULLHEADING DOWN I/A CHECK FOR ANY FLOW ABOVE BPV,OK. -BPV TEST IS GOOD.BLEED ALL PRESSURE, BLOW DOWN LINES AND RIG DOWN LITTLE RED. -WELL SECURED.RELEASE RIG @ 12:00 FIRS,2/3/2014. 0/A=40 PSI. LOSSES TO WELL LAST(12) HRS=70 BBLS. Printed 2/17/2014 9:43:38AM Tree: WKM 2-9/16" 5� MPU L-04 Orig. r 'ev. = 56' Wellhead: WKM 11" Orig. l._ _rev. =21' Tbg. Hng: 2-7/8"WKM,Top& Bottom / Top of 7" hng.to RKB-32' / / 13-3/8"48#H-40 11 / / ) Camco 2 7/8"x 1" sidepocket KBMM GLM 142' W/DSOV / / KOP @ 500' / Max. hole angle = 54 deg @ / 4200' / Hole angle thru' perfs= 39 deg. / / / 9 5/8" Casing Shoe 9 5/8"36 ppf, J-55 Btrc. surface csg. A / 6227'and (cap. =0.0773 bpf, drift ID=8.765") / Camco 2 7/8"x 1" 9803' / sidepocket KBMM GLM / W/Dummie 7"26 ppf, L-80, Btrc. prod. casing / XN 2-7/8"HES XN-Nipple 9951' (drift ID=6.151", cap. =0.0383 bpf) / I (2.441"id) / -- 2 7/8"6.5 ppf, L-80, 8 rd EUE tbg.. Pump, 161P11 SDX 9995' (drift ID=2.347", cap. =0.00592 bpf) •• • Tandem Gas Seperator 10009' h m Model-GRSFTXAR Tandem Centrilift GSB3DBUT 10021' Stimulation Summary - seal sections 10028' Interval: 10,156'- 10,343' 128,320 lbs. Centrilift KMH* 168 hp motor, 16/20 mesh Carbolite 10049' 3460 v./30 amps. 5 Centrilift Pumpmate 10,051' w/6-Fin C -' - Centrilizer _ Perforation Summary Ref log: DIL Size SPF Interval (TVD) _ _ 4.5" 5 10156'-10235' 7151'-7212' = _ 4.5" 5 10256'-10270' 7229'-7240' = I- 4.5" 5 10276'-10300' 7244'-7263' _ — 4.5" 5 10313'-10343' 7274'-7297' Original PBTD 10,609' 7", 26#, L-80, BTRC 10,697' DATE REV. BY COMMENTS MILNE POINT UNIT 8/14/95 DKW/JBF ESP Completion following RWO WELL L-04 2/14/2000 GMH RWO Nabors 4ES API NO: 50-029-22029 5/15/01 GMH RWO-Nabors 4ES-ESP Replacement 12/29/05 REH RWO-NABORS 4ES-ESP Replacement_ BP EXPLORATION (AK) 02/02/14 B.Kruskie Doyon 16 RWO ESP Replacement_ NIPL-04 (PTD #1900380) Packerless ESP Completion with high IAP on 06/30/08 Page 1 of ~~ • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIllntegrityEngineer@BP.com) Sent: Friday, July 11, 2008 11:26 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: MPL-04 (PTD #1900380) Packerless ESP Completion with high IAP on 06/30/08 Attachments: MPL-04.pdf; MPL-04 TIO PIot.BMP Hi Jim, Thank you again for our conversation yesterday. This email is to make notification of welt MPL-04 (#1900380) which had IA pressure in excess of 2000 psi on 06/30/08 with wellhead pressures equal to tubingllA/OA SSV/2420!40. As explained below, the ESP was started and the well was put on production the next day. Conservation Order 496 regulating sustained casing pressure within the Milne Point Field is unclear if wells completed with ESPs shall be reported for sustained casing pressure when shut-in. As we discussed, the packerless completion allows for high IA pressure by design but the pressure has not been intentionally applied. A wellbore schematic and TIO plot have been included for reference. «MPL-04.pdf» «MPL-04 TIO PIot.BMP» For now, we will continue to make notifications of pressures over 2000 psi on the IA and 1000 psi on the OA. Thank you, Anna 1~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~~ ~UL s ~ 2~~8 From: MPU, Wells Ops Coord Sent: Tuesday, July Ol, 2008 3:44 PM To: NSU, ADW Well Integrity Engineer Cc: MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord Subject: MPL-04 Elevated IA Anna/Andrea Just a heads up on the elevated psi on MPL-04. We had the ESP well SI for the TAR and we had hopes of having the 2nd SL unit perform the static prior to the pressure passing the 2000 psi. Since it was for a static we did not want to bleed the pressure as the psi crept up taking a big leap last night. Unfortunately, the unit arrived a day later then planned. The static has been achieved and the well is currently being bled down to start the ESP and put the well back in the production line. Let me know if you have any questions or concerns about this well. Lee Hulme MPU Wells Operations Coordinator 7/11/2008 ~ ~ ~} ~ cn~ _. 0 ~- ~ © ~' J ~, ~ ~ 4- O 0 0 ~D h~ Q O i O Q ~ O a a 0 a r~ 0 0 u~ ~ ~ O O O O (y r 0 a 0 0 r 4 ~ V' Tree: WKM 2-9/16" - 5M MPU L-04 Orig. DF Elev. = 56' Wellhead: WKM 11" Orig. ~v. = 21' Tbg. Hng: 2-7/8" WKM, op & Bottom Top of i''Ting. to RKB - 32' 13-3/8" 48# H-40 115' Camco 2 7/8" x 1" sidepocket KBMM GLM 140' KOP @ 500' Max. hole angle = 54 deg @ 4200' Hole angle thru' perfs = 39 deg. 9 5/8" 36 ppf, J-55 Btrc. surface csg. {cap. = 0.0773 bpf, drift ID = 8.765"} 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) Stimulation Summary Interval: 10,156' - 10,343' 128,320 lbs. 16/20 mesh Carbolite Perforation Summary Ref log: DIL Size SP interval (TVD) 4.5" 5 10156'-10235' 7151'-7212' 4.5" 5 10256'-10270' 7229'-7240' 4.5" 5 10276'-10300' 7244'-7263' 4.5" 5 10313'-10343' 7274'-7297' 9 5/8" Casing Shoe 6227' and Camco 2 7/8" x 1" sidepocket KBMM GLM 2-7/8"HES XN-Nipple (2.25"id ) Pump, 151 stg. GC1700 GPMTAR 1:1 Tandem Gas Seperator Model - GRSFTXARH6 Intake TVD Centrilift GSB3DBUTPFSA seal section 9833' 9976' 9991' 10009` 7039` 10014` Centrilift KMH" 190 hp motor, 10027` 2415 v./ 48 amps. Centrilift Pumpmate 10044` w/6-Fin Centrilizer Original PBTD 10,609' 7", 26#, L-80, BTRC 10,697' DATE REV. B COMMENTS MILNE POINT UNIT 8/14!95 DKW/JBF ESP Completion following RWO WELL L-04 2/14/2000 GMH RWO Nabors 4ES API NO: 50-029-22029 5/15/01 GMH RWO -Nabors 4ES -ESP Re lacement p 12/29/05 REH RWO - NABORS 4ES -ESP Replacement BP EXPLORATION {AK) · "'...:",£:,vt:u STATE OF ALASKA ALASKelL AND GAS CONSERVATION C~ISSION JAN 1 I 2006 REPORT OF SUNDRY WELL OPERA TIOfll& Oil & Gas Cons. Commissiol1 Anchorage .. 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL025509 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 82' 6194' 10664' Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 181 Repair Well 181 Pull Tubing 56 10697 7592 10609 7518 Chan~ Out ESP o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver 181 Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 190-038 6. API Number: 50-029-22029-00-00 99519-6612 9. Well Name and Number: MPL-04 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 13-3/8" 115' 115' 1740 750 9-5/8" 6227' 4649' 3520 2020 7" 10697' 7592' 7240 5410 ". - {\,1\~' 1 ¡;;;" !I} .:)(;,,; .~\'.' ) {4.j 10156' - 10343' 7152' - 7298' 2-7/8", 6.5# L-80 10050' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment description including volumes used and final pressure: RBDMS BFl JAN 11 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl 319 309 Re resentative Dail Gas-Mcf 60 56 Water-Bbl 556 548 Casin Pressure 360 380 Tubin Pressure 293 331 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 17. t at t e oregolng IS true an David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: Dat{)l·cA-O (P Sondra Stewman, 564-4750 Submit Original Only Phone 564-4750 Tree: WKM 2-9/16" - 5Ma Wellhead: WKM 11" ., Tbg. Hng: 2-7/8" WKM, Top & Bottom 13-3/8" 48# H-40 I 115' I KOP @ 500' Max. hole angle = 54 deg @ 4200' Hole angle thru' perfs = 39 deg. 9 5/8" 36 ppf, J-55 Btrc. surface csg. (cap. = 0.0773 bpf, drift ID = 8.765") 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) Stimulation Summary Interval: 10,156' - 10,343' 128,320 Ibs. 16/20 mesh Carbolite Perforation Summary Ref I()g: OIL Size SP 4.5" 5 4.5" 5 4.5" 5 4.5" 5 Interval 10156'-10235' 10256'-10270' 10276' -10300' 10313'-10343' (TVD) 7151'-7212' 7229'-7240' 7244'-7263' 7274'-7297' MPU L-04 Orig. ralev. = 56' Orig,.lev. = 21' Top of 7" hng. to RKB - 32' Cameo 2 7/8" x 1" sidepocket KBMM GLM ~ 9 5/8" Casing Shoe 16227' md Cameo 27/8" x 1" sidepocket KBMM GLM 19833' I 2-7/8"HES XN-Nipple (2.25"id ) 19976'1 Pump, 151 stg. GC1700 GPMTAR 1:1 I 9991' I I 10009' I 17039' .1 10014' I Tandem Gas Seperator Model - GRSFTXARH6 Intake TVD Centrilift GSB3DBUTPFSA seal section Centrilift KMH* 190 hp motor, 2415 v.l48 amps. 10027' I Centrilift Pumpmate w/6-Fin Centrilizer I 10044' I Original PBTD 7", 26#, L-80, BTRC 10,609' 10,697' DATE REV.B COMMENTS MILNE POINT UNIT 8/14/95 DKW/JBF ESP Completion following RWO WELL L-04 2/14/2000 GMH RWO Nabors 4ES API NO: 50-029-22029 5/15/01 GMH RWO - Nabors 4ES - ESP Replacement 12/29/05 REH RWO - NABORS 4ES - ESP Replacement BP EXPLORATION (AK) Page 1 of 2 BP EXPLORATION Operations Summary Report Legal Well Name: MPL-04 Common Well Name: MPL-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I From - To I Hours! Task ! Code ¡ NPT, Phase 11/29/2005 12/24/2005 Spud Date: 5/14/2001 End: 12/24/2005 Start: Rig Release: Rig Number: I ..u.____ .1..____ ..."------ 12/19/2005 PRE 16:00 - 18:00 2.00 RIGD P 18:00 - 21 :00 21 :00 - 20:00 3.00 MOB 23.00 RIGU P P PRE PRE 12/20/2005 20:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 4.00 RIGU 1.00 KILL 0.50 KILL 3.50 KILL P P P P PRE DECOMP DECOMP DECOMP 05:00 - 06:00 1.00 KILL P DECOMP 06:00 - 13:00 7.00 KILL P DECOMP 13:00 - 15:30 2.50 KILL P DECOMP 15:30 - 16:00 0.50 KILL P DECOMP 16:00 - 17:00 1.00 WHSUR P DECOMP 17:00 - 18:00 1.00 WHSUR P DECOMP 18:00 - 20:00 2.00 BOPSU P DECOMP 20:00 - 00:00 4.00 BOPSU P DECOMP 12/21/2005 00:00 - 03:00 3.00 BOPSU DECOMP 03:00 - 03:30 0.50 BOPSU DECOMP 03:30 - 06:00 2.50 BOPSU DECOMP 06:00 - 11 :30 5.50 BOPSU DECOMP 11 :30 - 12:00 0.50 BOPSU DECOMP 12:00 - 14:00 2.00 BOPSU DECOMP 14:00 - 16:00 2.00 BOPSU DECOMP 16:00 - 17:00 1.00 BOPSU DECOMP 17:00 - 18:00 1.00 BOPSU DECOMP 18:00 - 20:30 2.50 BOPSU DECOMP 20:30 - 21 :30 1.00 BOPSU DECOMP 21 :30 - 00:00 2.50 BOPSU DECOMP 12/22/2005 00:00 - 01 :00 1.00 BOPSU DECOMP 01 :00 - 01 :30 0.50 BOPSU DECOMP 01 :30 - 05:00 3.50 BOPSU DECOMP Description of Operations ....~._-_........_.__.. .....----.-.. -.---... PJSM. Scope down & layover derrick. Rig down rig components. Move rig from L-29 to L-04. Set Herculite and mats. Spot Rig. Scope and Raise derrick. R/U Modules. Rig accepted at 22:00 hrs Spot I Set Tigar tank. Run Lines to Tank and Tree R/U Lubricator & pull BPV. Test lines to 3500 psi PJSM. Well Kill procedures. Check pressures Tbg. 840 psi Csg. 770 psi. Bleed gas. Pump 60 bbls heated sea water 3 bpm 890 psi. Bullhead 20 bbls 1400 psi. Circulate to returns of sea water 470 bbls pumped. Shut in and monitor. Monitor well. Tbg 350 psi. Csg 350 psi. Order out 900 bbls 9.8 ppg. Wait on Brine. Continue to pump hot seawater at 4bpm at 1200 psi to clean well 290 bbls. Take on brine. Offload seawater Kill Well. Circulate 9.7( heavy) ppg brine 4 bpm 11000 psi. Bullhead 15 bbls at 3 bpm 1 550 psi. Continue circulate Monitor Well Tbg. 0 psi Csg. 0 psi Set TWC. Test @ 5 bpm at 700 psi NID Tree N/U BOPE PJSM Pressure test BOPE as per BP and AOGCC regulations 250 psi low 1 3500 psi high Test witness waived by Chuck Sheve with AOGCC. Not getting good test. Looking for leak. Testing BOPE have leak,. Eliminate all possible sources, except TWC R/U lubricator. Pull TWC. Inspect and find grit in seal areas. Set Re-buitl TWC. Still unable to get a good test. However, bleed-off has decreases. Double check surface equipment, again. Wait on Doyon 14 the finish pulling their TWC so we can get our lubricator back. Plan on pulling TWC again. Order out Test Plug. Continue to isolate leak testing all possible sources Change out high-pressure hose. Continue to test no change Testing seeing slow leak still. Recieve lubricator. Pull TWC. Small amount of sand and grit again found in TWC. Flush BOP Stack. Reset Redressed TWC. Testing BOPE No chage Drain stack. R/U lubricator pull TWC Circulate well 4 bpm 1 1100 psi 9.7 ppg brine full volume. Fluid loss 0.75 bpm. Monitor Well. Static Fluid Level at 50-ft. M/U landing Jt. BOLDS. Pull hanger to floor. Lay down 1 Jt. Cut cable and secure to tbg. M/U Landing Jt too Test plug with 4-1/2" XO pin. Try to land!! 4-1/2" XO x 2-7/8" crossover to long the O.D. bottomed out in 7" Csg. Can find no other crossovers. Not able to use test plug. Pull test plug and lay down M/U redressed Tbg hanger. RIH and hang off. Set TWC Test BOPE 250 psi low I 3500 psi high through complete test on each test as volume area decreases leakage increases. Printed: 12/27/2005 8:35:51 AM Page 2 of 2 BP EXPLORATION ,Operations Summary Report legal Well Name: MPl-04 Common Well Name: MPl-04 Event Name: WORKOVER Start: 11/29/2005 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 12/24/2005 Rig Name: NABORS 4ES Rig Number: _~ate_ I Fr~m-_~o ! Ho~rs I ~ask _! cOd~1 NP~ ! ~_as~ I 12/22/2005 01 :30 - 05:00 3.50 BOPSU P DECOMP 05:00 - 06:00 1.00 BOPSU P DECOMP 06:00 - 08:30 2.50 BOPSU P DECOMP 08:30 - 12:00 3.50 BOPSU P DECOMP 12:00 - 13:00 1.00 BOPSU P DECOMP 13:00 - 15:00 2.00 PULL P DECOMP 15:00 - 16:30 1.50 PULL P DECOMP 16:30 - 19:00 2.50 PULL P DECOMP 19:00 - 00:00 5.00 PULL P DECOMP 12/23/2005 00:00 - 04:00 4.00 PULL P DECOMP 04:00 - 06:00 2.00 PULL P DECOMP 06:00 - 10:00 4.00 RUNCO RUNCMP 10:00 - 14:00 4.00 RUNCMP 14:00 - 17:00 3.00 RUNCMP 17:00 - 19:00 2.00 RUNCMP 19:00 - 23:00 4.00 RUNCMP 23:00 - 00:00 1.00 RUNCO RUNCMP 12/24/2005 00:00 - 01 :00 1.00 RUNCO RUNCMP 01 :00 - 01 :30 0.50 RUNCO RUNCMP 01 :30 - 02:00 0.50 RUNCO RUNCMP 02:00 - 03:30 1.50 BOPSU P RUNCMP 03:30 - 04:30 1.00 WHSUR P RUNCMP 04:30 - 05:00 0.50 WHSUR P RUNCMP 05:00 - 05:30 0.50 WHSUR P RUNCMP 05:30 - 06:00 0.50 WHSUR P RUNCMP Spud Date: 5/14/2001 End: 12/24/2005 Description of Operations .---- .-"."--.--,--.-..----.,..-.---- -..- Leakage rang from 5 psi to 20psi in 5 min. Leak is 99% sure to be at hanger area. Confer with on call Eng and order out storm packer. R/U lubricator and pull TWC M/U HES Storm Packer in string. Set at 27'. Test Pkr. at 1500 psi. Install Test Plug PJSM Test BOPE 250 psi low /3500 psi high as per BP/AOGCC regulations. Test witnessed by BP Rep. and Nabors Toolpusher. Witness waived by AOGCC Chuck Sheve. Pull Test Plug. Relaese HSE Storm Packer at 27' POH lay down. Circulate well at 5 bpm I 1500 psi. Returns are "gas cut". Monitor final returns at 9.7 Ib/gal.. However, static fluid level remains in BOP Stack. We have lost our "Trip-Margin" Build fluid in pits to 9.9 ppg Circulate and condition returns to 9.9 ppg brine 3 bpm 1550 psi. Bullhead 15 bbls @ 3 bpm 1 1500 psi. Monitor well on vaccum PJSM TOH with 2-7/8" ESP montor hole keeping full. Taking fluid at 26 bbls hr. TOH with 2-7/8" ESP Completion keeping hole full. Lay down ESP Assembly. M/U ESP Pump Assembly, Centralizer, Sensor, Motor, Lower Tandem Seal, Upper Tandem Seal, Gas seperator, Pump, and Discharge Head. Service same. Attached pig tail. Check Cable TIH with ESP on 2-7/8" eue 8rd Tbg with La Salle proterctors. Check conductivity of cable each 2000' Change out cable spools. Make Cable splice. Test same. TIH with ESP. . Making up Hanger found 2-7/8" threads in upper section buggered up. Send same to machine shop for repair M/U Hanger. Install Penetrator. Make connector splice. Test Land hanger. PUW 76K / SOW 42K. RILDS Set TWC. Test. Test Lower Hanger Seals. Drain BOPE N/D BOPE. Test Spool and Double Stud Adaptor. Clean Pits. N/U Adaptor Flange, Tree Test Flange to 5000 psi R/U lubricator and pull TWC. LD same. Install BPV. Secure Tree and Cellar. Rig released at 06:00 Printed, 12/27/2005 8:35,51 AM -~----. STATE OF ALASKA ~- ALASK/--. ,_ AND GAS CONSERVATION COMN. .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE - 56' 3. Address .......... [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. L(~cati0n 8'f well at surface ........ 8. Well Number 3192' NSL, 4910' WEL, Sec. 08, T13N, R10E, UM MPL-04 At top of productive interval 9. Permit Number / Approval No. 190-038 3691' NSL, 2122' WEL, Sec. 06, T13N, R10E, UM 10. APl Number At effective depth 50-029-22029-00 4363' NSL, 2281' WEL, Sec. 06, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River Field 4411' NSL, 2284' WEL, Sec. 06, T13N, R10E, UM 12. Present well condition summary Total depth: measured 10697 feet Plugs (measured) true vertical .7592 feet Effective depth: measured 10609 feet Junk (measured) true vertical 7518 feet Casing Length Size Cemented MD TVD Structural Conductor 82' 13 3/8" 485 SKS Permafrost 'C' 115' 115' Surface 6194' 9 5/8" 305 Bbls Arcticset IV, 67 Bbls Class G 6227' 4649' Intermediate Production 10664' 7" 84 Bbls Class 'G' 10697' 7592' Liner Perforation depth: measured 10156' - 10235', 10256' - 10270', 10276' - 10300', 10313' - 10343' true vertical 7152'-7213', 7229'-7240', 7245'-7264', 7274'-7298' RECEIVED Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10039' J U N 1 ? 0 01 Packers and SSSV (type and measured depth) None Alaska Oil & Gas Cons. Commission Anchora~)e 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments ' ' 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17.1 hereby C'ertify~t~egoi~...Qd correct ,o the 'best of my knowledge Signed i~;Z,~ra"'"~ ~ ~'""'--~'""~'~'~'~Stew~~~,~,._ Title Technical Assistant Date f,._r--~ (..O~ I L-I '- L~ I Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPL-04 Common Well Name: MPL-04 Spud Date: 5/14/2001 Event Name: WELL SERVICING Start: 5/14/2001 End: 5/16/2001 Contractor Name: NABORS Rig Release: 5/16/2001 Rig Name: NABORS 4ES Rig Number: ~:~: ~:~ Description of Operations ............ 5/14/2001 07:30 - 11:00 3.50 MOB P PRE MOVR FROM MPL-12 TO MPL -04. SPOT IN RIG & BERM AROUND SAME. 11:00 - 12:30 1.50 RIGU P PRE RAISE & SCOPE DERRICK. ACCEPT RIG @ 1200 HRS. 5-14-01. HOOK UP TIGER TANK. 12:30 - 13:00 0.50 WHSUR P DECOMP M/U LUBRICATOR & PULL BPV. TAKE ON KILL FLUID. 13:00 - 14:30 1.50 KILL P DECOMP R/U HCR & HARD LINES TO X-MAS TREE. TEST SAME TO i3500 PSI, OK. 14:30 - 17:00 2.50 KILL P DECOMP OPEN WELL. SlTP 470 PSI, SlCP 480 PSI. KILL WELL W/ SEAWATER @ 4 BPM, 1100 PSI. 17:00 - 17:30 0.50 KILL P DECOMP MONITOR WELL, WELL DEAD. 17:30 - 18:00 0.50! WHSUR P DECOMP INSTALL TWC & TEST 3500 PSI, OK. 18:00 - 19:00 1.001 WHSUR P DECOMP N/D X-MAS TREE. ~ 19:00 - 21:00 2.00 BOPSUR P DECOMP N/U BOPE. 21:00 - 00:00 3.00 BOPSUR P DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI. TEST WITNESSING WAIVED BY CHUCK SHEVE WI AOGCC. 5/15/2001 00:00 - 01:00 1.00 WHSUR P DECOMP M/U LUBRICATOR & PULL TWC. 01:00 - 01:30 0.50 WHSUR P DECOMP M/U LANDING JT & PULL HANGER. 01:30 - 02:00 0.50 PULL P DECOMP TEST ESP CABLE & L/D LANDING JT. 02:00 - 04:30 2.50 KILL P DECOMP CIRCULATE HOLE. HAG GAS OIL & DIESEL RETURNS. CIRCULATE UNTIL HOLE CLEAN. 04:30 - 07:30 3.00 PULL P DECOMP POOH W/2 7~8" COMPLETION 07:30 - 08:00 0.50 PULL P DECOMP CHANGE OUT CABLE SPOOL. 08:00 - 12:30 4.50 PULL P DECOMP CON'T POOH W/2 7~8" COMPLETION STRING. 12:30 - 14:00 1.50 PULL ::) DECOMP L/D ESP & CLEAR FLOOR. 14:00 - 00:00 10.00 EVAL ::) COMP PJU SCHLUMBERGER & RUN RST LOG. TAGGED PBTD @ 10475' 5/16/2001 00:00 - 04:30 4.50 EVAL ::) COMP RUN RST LOG. R/D SCHLUMBERGER. 04:30 - 05:30 1.00 RUNCOI~13 COMP PJU TO RUN COMPLETION. 05:30 - 08:00 2.50 RUNCOI~13 COMP M/U ESP. SERVICE & TEST SAME. 08:00 - 12:30 4.50 RUNCOI~13 COMP RIH W/2 7/8" COMPLETION STRING TO 6600'. 12:30 - 15:30 3.00 RUNCOI~13 COMP CHANGE OUT CABLE SPOOLS. MAKE MID-RUN SPLICE & SERVICE RIG. 15:30 - 17:30 2.00 RUNCOk13 COMP CON'T TO RIH W/2 7/8" COMPLETION STRING TO 10039'. 17:30 - 19:00 1.50 RUNCOI~ I3 COMP M/U LANDING JT. ALIGN HANGER & ATTACH LOWER CONNECTOR. MAKE LOWER CONNECTOR SPLICE. 19:00 - 19:30 0.50 RUNCOI~ P COMP CHECK PENETRATOR, LANDIND TBG HANGER. RILDS. 19:30 - 20:30 1.00 WHSUR P COMP SET TWC & TEST SAME. DRAIN BOP & HARD LINES. 20:30 - 21:30 1.00 BOPSUF:P COMP N/D BOPE. 21:30 - 22:30 1.00 WHSUR P COMP N/U X-MAS TREE. 22:30 - 23:00 0.50 WHSUR P COMP PRESSURE TEST ADAPTER FLANGE & TREE TO 5000 PSI, OK. 23:00 - 23:30 0.50 WHSUR :~ COMP PULL TWC. SET BPV. 23:30 - 00:00 0.50 WHSUR 3 COMP SECURE WELL & CLEAN CELLAR. RELEASE RIG @ 2400 HRS, 5-16-01. Printed: 5/24/2001 2:44:30 PM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julia Heusser, Commissioner Tom Maunder, ~-~~ P. I. Supervisor DATE: December 22, 2000 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments: SVS MPU L pad 12-22-00jc ..cc; NON-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX OperatOr Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator psi: LPS 140 Date: 12/22/00 HPS Well· Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060 140 100 90! P P ...... OIL L-03 1900070 L-04 1900380 140 100 lb5 P P OIL ,I L-05 1900390 140! 100 100 P P OIL , ,,,, L-06 1900100 140! 100 100 P P OIL L-07 1900370 140 100 100 P P OIL: L~08 1901000 4000 2000 1950 P '" P WAG · L-09 1901010 L-11 1930130 140 ' 100 1'15 'P .... P OIL L-12 1930110 140 100 100 P P OIL L-13 1930120 140 i00 100 P P " OIL L-14 1940680 140 100 95 P P OIL L-15 1940620 ' L-16A 1990900 L-17.' 1941690 L-20 1971360 140 1001 100 P P ' OIL L-25 1951800 140 100 105! P P OIL L-28A 1982470 140 100 110 P P OIL L-29 1950090 140 100 95 P P OIL L-32 1970650 140 100 100l P 'P OIL ~-33 ' 1971050 ~-~5 1970920 '140 100 105 P ~ " OIL ~-~6 1971480 140 100 105 P P ' OIL L-57A 1980560 L-4o '" 1980100 14o 100 i00 e P ~\~~'~\'~ OIL, L-45 1981690 140 100 105 P P ~x5' OIL L-~4 1970800 4000 2000 1900 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% [390 var Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIr~J, Number Number PSI PSI Trip Code Code Code Passed aASorCVCLE_ II I I 12/26/00 Page 2 of 2 SVS MPU L Pad 12-22-OOjc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LORlqVllqLIvt DOC L A T E R IA L THIS M A E E U R E W NDE K E R R --", STATE OF ALASKA ALASK, elL AND GAS CONSERVATION COry, JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP ............ 2. Name of Operator 5. Type of well: 6. Datum Elevation ('DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' .......... [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 81 Well Number 3192' NSL, 4910' WEL, Sec. 08, T13N, R10E, UM MPL-04 At top of productive interval 9. Permit Number / Approval No. 190-038 3691' NSL, 2122' WEL, Sec. 06, T13N, R10E, UM 10. APl'Number ...................... At effective depth 50-029-22029-00 4363' NSL, 2281' WEL, Sec. 06, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River Field 4411' NSL, 2284' WEL, Sec. 06, T13N, R10E, UM ...... 12. Present well condition summary Total depth: measured 10697 feet Plugs (measured) true vertical 7592 feet Effective depth: measured 10609 feet Junk (measured) true vertical 7518 feet Casing Length Size Cemented M D TVD Structural Conductor 82' 13 3/8" 485 SKS Permafrost 'C' 115' 115' Surface 6194' 9 5/8" 305 Bbls Arcticset IV, 67 Bbls Class G 6227' 4649' Intermediate Production 10664' 7" 84 Bbls Class 'G' 10697' 7592' Liner Perforation depth: measured 10156' - 10235', 10256'- 10270', 10276' - 10300', 10313' - 10343' true vertical 7152'-7213', 7229'-7240', 7245'-7264', 7274'-7298' i ,ECEIVED Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10034' MAR F~ '~ ~.000 Packers and SSSV (type and measured depth) None ::\]~,~ 0il,& Gas Corer,. C0m~,l[~si~l'~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressureORIGINAL 14. Representative Daily Average Production or Injection Data OiI-Bbl GaS-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ,~.~.~ ~ Title Technical Assistant III Date 0o~-o~(~,~) ............................................................................... Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt L Pad Well MPL-04 Page 1 Rig Nabors 4ES Date 21 February 00 Date/Time 11 Feb 00 10:00-00:00 10:00-00:00 12 Feb 00 00:00 00:00-06:00 00:00-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-12:00 08:30-12:00 13 Feb 00 12:00 12:00-13:00 12:00-13:00 13:00 13:00-15:00 13:00-15:00 15:00 15:00-19:00 15:00-19:00 19:00 19:00-21:00 19:00-20:00 20:00 20:00-21:00 21:00 21:00-06:00 21:00-06:00 06:00 06:00-09:00 06:00-09:00 09:00 09:00-16:30 09:00-16:30 16:30 16:30-06:00 16:30-00:30 Duration 14hr 14hr 6 hr 6 hr 2-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 1 hr 1 hr 2 hr 2 hr 4 hr 4 hr 2 hr 1 hr 1 hr 9 hr 9 hr 3 hr 3 hr 7-1/2 hr 7-1/2 hr 13-1/2 hr 8 hr Activity Move rig Rig moved 100.00 % Move rig from J-Pad to L-pad & rig up & scope derrick etc. At well location - Slot Repair Repaired Fluid system Trouble shoot pits for leaks (leaks not found after welding suctions & adding water to pits & so forth) continue to investigate for a answer. Fluid system failed - Change operation Fluid system Fill pits with Seawater take on sea h20 & ru lub & pull bpv. tbg. 750 psi. ann 750 psi. ru hcr & lines to tree & test to 2500 psi. Completed operations Well control Circulated closed in well at 9971.0 ft spud meeting & kill well with 8.4 ppg. fluid & monitor same Static-set twc & test to 2500 psi. rd-lines to tree. Hole displaced with Seawater - 150.00 % displaced Wellhead work Rigged down Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test witnessed by Chuck Sheve with aogc Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger RECEIVED Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 1648.0 ft ~A[~ ~O '1 2000 Stopped: To hold safety meeting Co,.r',,,~. Pull Single completion, 2-7/8in O.D. (cont...) ~-,~,~ 0il,& Gas O"ns m ,,~.-, Pulled Tubing in stands to 0.0 fl Anchorage cont. pooh & lay dn esp assy & inspectect same. lost in hole 2-flat guards & 20-flat bands. Completed operations Slickline wireline work Conducted slickline operations on Slickline equipment - Retrival run rig up HES & Make 3-Run with 6.0" GR/JB No. 1 =2980' Rec. 1-fiat & 2-bands. No. 2=4560' Rec. 5-bands & Run no. 3=10300' Rec. 4-bands. Completed run with Junk basket/gauge ring from 0.0 h to 10300.0 ft Run Single completion, 2-7/8in O.D. Functioned ESP · ,, U & csp motor was Facility M Pt L Pad Progress Report Well MPL-04 Page 2 Rig Nabors 4ES Date 21 February 00 Date/Time 14 Feb O0 00:30 00:30-06:00 06:00 06:00-11:00 06:00-09:30 09:30 09:30-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-14:00 12:00-14:00 14:00 14:00-06:00 14:00-16:00 16:00 16:00-17:00 17:00 17:00-18:00 18:00 Duration 5-1/2 hr 5 hr 3-1/2 hr 1-1/2 hr 1 hr 1 hr 2 hr 2 hr 16hr 2 hr 1 hr lhr Activity readied for pick up was dropped as it was being loaded Equipment work completed Ran Tubing in stands to 6650.0 fl rih to 6650' & stop to splice esp cable. Stopped: To splice cable Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 10034.0 ft On bottom Rigged up Tubing hanger install hanger & make splice in esp cable & land hanger & rilds. Equipment work completed Wellhead work Installed Hanger plug rilds & set twc & test to 2500 psi. rd landing jt. Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Tested Xmas tree Pressure test completed successfully - 5000.000 psi Removed Hanger plug rig lubricator & pull twc & set bpv & rd cellar & secure tree. Equipment work completed RECEIVED MAR G 1 2000 ~:~.~:~ Oil& Gas o~,~o Ccm~,'~issi~ Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,¥~,~ DATE: Chairman February 12, 2000 THRU: Blair Wondzeil, ~.,~~ P. I. Supervisor FROM: Chuck Scheve, 4 ~ SUBJECT: Petroleum Inspector BOPE Test Nabors 4ES MPU L-04 PTD # 190-038 Saturday February 12, 2000: I traveled to BPX's MPU L-04 Well being worked over by Nabors Rig 4ES and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report indicates the test lasted 3 hours with no failures. The Kelly valves were not tested today because it will not be used during recompletion of this well. The testing went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the initial BOPE test on Nabors Rig 4ES doing a pump change on well MPU L-04. Nabors 4ES, 2/12/00, Test time 3 hours, 0 failures Attachment: BOP Nabors 4ES 2-12-00 CS X Unclassified Confidential Confidential (Unclassified if doc. removed ) BOP Nabors 4ES 2-12-00 CS STATE OFALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X DATE: 2/12/00 Nabors Rig No. 4ES PTD # 190-038 Rig Ph.# 659-4154 BPX Rep.: Larry Myers MPU L-04 Rig Rep,: Gene Sweat Set @ X Weekly Other Location: Sec. 8 T. 13N R. 10E Meridian UM MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign N/A Upper Kelly/IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP PTD On Location YES Hazard Sec. YES ~ Ball Type Standing Order Posted YES .- Inside BOP Test Quan. Pressure P/F 2 250/5,000 P 1 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/2500 P 1 250~3,5OO P 1 250~3,500 P 1 250~3,500 P 2 25013, 500 P I 250~3,500 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 25O/5,000 P 22 250/5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3000 1900 minutes 30 sec. 2 minutes 5 sec. OK Remote: OK 4 @ 1800 Psi Psig, Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No, 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- nspe tour..., F~-u-'-~L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve 4ES 2-12-00 CS STATE OF ALASKA ALASKA 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 2055' SNL' 420' EWL, Sec. 8, T13N, R10E, UM At top of productive interval 4086' NSL, 783' WEL, Sec. 5, T13N, R10E, UM At effective depth 4500' NSL, 4476' WEL, Sec. 5, T13N, R10E, UM At total depth 4649' NSL, 4473' WEL, Sec. 5, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-05 9. Permit Number / Approval No. 90-39 94-196 10. APl Number 50-029-22030 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10526' feet Plugs (measured) 7581' feet 10340' feet Junk(measured) 7468' feet Length Size Cemented 82' 13 3/8" 485 sx PF 'C' 6011' 9 5/8" 400 sx 'G' & 1257 sx AS IV 10493' 7" 435 sx Class 'G' MD TVD 115' 115' 6044' 4676' 10526' 7581' Perforation depth: measured true vertical 9809'-9913',9949'-9964',9980'-9999',10024'-10098' 7183'-7203',7225'-7234',7244'-7256',7272'-7319' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9759' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) 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 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 Chip Alvord ,, /,~p~_~, ..... Title Eng,,!,,n,,,eering Supervisor Date J'/~,,(,~,~ ! ....... Prepared By ~r~}~vumber: Mary Youngers 564-5242 I Submit In Dupli~" Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-05 Rig Name: N-4ES AFE# 339055 Accept Date: 8/1/97 Spud Date: - Release Date: 8/3/97 AUGUST 2, 1997 PREP FOR RIG MOVE, MOVE & SPOT RIG ON MPL-05. RAISE & SCOPE DERRICK. BERM RIG. RU FLOOR & MUD LINES. SET TIGER TANK. RU HARD LINE FOR WELL KILL. PULL BPV W/LUB. KILL WELL CIRCULATE WELL DOWN TUBING - RETURNS TO TT @ 5 BPM/1400 PSI MONITOR WELL. SET TWC, ND TREE. NU BOPE, RU TO TEST BOPE. AUGUST 3, 1997 TEST BOPE PER BP/AOGCC REQUIREMENTS, STATE WAIVED RIGHT TO WITNESS TEST (DA). MU LANDING JT BOLDS & FULL TUBING HANGER. POOH W/2 7/8" TBG & ESP COMPLETION. CHANGE CABLE SPOOL. CONTINUE POOH W/ESP. FINISH POOH W/ESP LD ESP ASSY. RECOVERED ALL BANDS & FLAT GUARDS. RU HALLIBURTON WL. RIH W/5.99" GR/JB. TAG BTM @ 10348' WLM. POOH RECOVERED SEVERAL PIECES OF BANDS FROM PAST WORK. RD PU & SERVICE ESP ASSY. RIH W/ESP & 2 7/8" TUBING STOP & CHANGE CABLE SPOOLS. MAKE SPLICE. AUGUST 4, 1997 LUBE RIG, FINSH RIH W/ESP COMPLETION. MU HANGER & LANDING JT. MAKE PIG-TAIL SPLICE. CHECK CABLE OK. LAND HANGER RILDS. LD LANDING JT INSTALL TWC. ND BOPS NU TREE. TEST TBG HANGER & TREE TO 5000 PSI OK. CHECK CABLE. OK. PULL TWC & INSTALL BPV. FREEZE PROTEST WELL W/DIESEL. RD LINES. SECURE WELL. RIG RELEASED @ 23:00 HRS. Page STATE OF ALASKA ALASKA 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 Replacement 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3192' NSL, 4910' WEL, Sec. 8, T13N, R10E, UM At top of productive interval 4161' NSL, 2282' WEL, Sec. 6, T13N, R10E, UM At effective depth 4363' NSL, 2302' WEL, Sec. 6, T13N, R10E, UM At total depth 4411' NSL, 2306' WEL, Sec. 6, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-04 9. Permit Number / Approval No. 90-38 10. APl Number 50- 029-22029 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10697' feet 7605' feet 10609' feet 7518' feet Length Size 82' 13 3/8" 6194' 9 5/8" 10664' 7" Plugs (measured) Junk (measured) Cemented 485 SKS Permafrost 'C' 305 Bbls Arcticset IV & IV & 67 Bbls Class 'G' 84 Bbls Class 'G' MD TVD 115' 115' 6227' 4649' 1O697' 7605' Perforation depth: measured 10156'-10235', 10256'-10270', 10276'-10300', 10313'-10343' (open) true vertical 7151 '-7212', 7229'-7240', 7244'-7263', 7242'-7297' (open) Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10018' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 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 Signed Chip Alvord' ~,L ~' ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Engineering Supervisor Date,,, ..................... [,; ......... , .... ~repared By Name/Numbe;;' Mary Youngers 564-5242 Submit In Duplicat~N~ Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPL-04 Rig Name: N-4ES AFE# 330188 Accept Date: 08/10/95 Spud Date: . Release Date: 08/14/95 AUGUST 11, 1995 RIG ACCEPTED @ 2000 HRS ON 08/10/95 SPOT TIGER TANKS & RIG UP LINES F/TREE WAIT ON SOURCE H20 (UNABLE TO GET SOURCE H20 DIVER TRUCKS BACK TO DEADHORSE TO LOAD) TAKE ON H20 PULL BPV ANNULUS PSI = 1300 TUBING = 1000 PSI BLEED OFF PRESSURE ON TBG & ANNULUS. ADDING ALDACIDE G TO H20 PER (BARIOD). AUGUST 12, 1995 BLEED GAS INFLUX FROM TBG & ANNULUS (LUBRICATE 11 BBL FLUID IN ANNULUS TO PKR TOP) BULLHEAD 360 BBL 150 DEG SOURCE H20 DOWN ANNULUS RIG CAMCO WIRE LINE TRUCK & RIH TO SLIDING SLEEVE @ 9950' & ATTEMPT TO SHIFT SLEEVE TO OPEN POSITION (NO SUCCESS) POOH & REDRESS TOOL, RIH, SHIFT TO OPEN POSITION POOH & PU KICKOVER TOOL & RIH TO 561' & SET DUMMY VALVE IN GLM POOH & RIG DOWN CAMCO. SPOT 50 BBL XANVIS PILL SET TWC & ND TREE. NU BOP'S TEST BOP TO 250 LOW & 5000 HIGH (TEST WAIVED BY LEW GRIMMALDI AGOCC) PULL TWC & INSTALL LANDING JT, BOLDS & SHEAR PACKER SLIPS SPOT 40 BBL XANVIS PILL TO PERFS, WELL TAKING 150 + BBL PER HR MIXING & PREPARING TO SPOT LIQUID CASING PILL. AUGUST 13, 1995 CONT TO SPOT LIQUID CSG PILL & MONITOR WELL @ 32 BPH. LD 19 JTS TUBING TO PKR POOH W/ESP COMP (HAD APP 90 BAD JTS TUBING) RIG CAMCO & RIH TO 10500' W/SAMPLE CATCHER RIH W/6" GR/JB TO 10200' POOH & RIG DOWN SAME (REC SMALL AMOUNT RUBBER IN JUNK BASKET) RIH W/TBG FROM DERRICK, SORTED OUT BAD JTS (TBG COLLARS DAMAGED FROM ELECTROLYSIS). AUGUST 14, 1995 CONTINUE TO SORT OUT & LD BAD JTS TUBING TOTAL OF 50 JTS CLEAR OUT & LOAD PIPE SHED & RIG UP TO RUN ESP SERVICE & M/U ESP & SAFETY, RUNNING MEETING. RIH W/ESP RAN TOTAL OF 315 JTS 2 7/8" 6.5# L-80 8RD EUE MU HANGER & LANDING JT, SPLICE ESP LINE & MU TO HANGER LAND TUBING & RILDS TEST HANGER TO 5000 & INSTALL TWC ND BOP'S. GEARY REAMER & REX YATES. AUGUST 15, 1995 ND BOP'S NU TREE & TEST SAME TO 5000 PSI. FREEZE PROTECT ANNULUS W/60 BBL DIESEL & TBG W/10 BBL DIESEL BLOW DOWN LINES & SECURE TREE, CLEAN PITS. RIG RELEASED @ 1200 HRS ON 8/14/95. Page 1 of 1 10/29/92 7292 SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION · COMPUTING CENTER PRINT CENTER WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME ' SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES· JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: WELL NAME · SERVICES · t NO. OF BOXES: JOB NO. ' ADD'L TAPES · WELL NAME ~'......- ~, r" ! ~, I ~-. ~ s~v,c~s /.K ~ L ~ ~ v ~ ~ OC~ 3 0 ~99~ NO. OF JOB NO. · ADD'L TAPES · '.,,/~'": ~/),Z') "' RECEIVED BY: Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 July 3, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Sundry Approval Application Attached please find a Sundry Approval Application for Well L-4 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 Attachments cc Well L-4 File RECEIVED d U L - 9 ~99~ Alaska .0il & Gas Cons. C0mmiss~0n ~nch0rage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 J~ J G I N A L APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation shutdown Re--enter suspended well Alter casing . . Repair well ~ Plugging m Time extention __ Stimulate Change approved program Pull tubing ~ Variance Perforate Other ... X Replace ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development x 56. KDB feet 3. Address Exploratory ~ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic ~ Milne Point Unit 4. Location of well at surface 8. Well number 2087' FNL, 4911' FEL, Sec. 8, T13N, RIOE; Umiat Meridian L-4 At top of productive interval 9. Permit number 4100' FSL, 2275' FEL, Sec. 6, T13N, RIOE, Umiat Meridian 90-38 At effective depth 10. APl number 4364' FSL, 2304' FEI., Sec. 6, T13N, RIOE, Umiat Meridian 50-029-22029 At total depth 11. Field/Pool 4423' FNL, 2309' FEL, Sec. 6, T13N, RIOE, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 10716' feet Plugs (measured) true vertical 7606' feet Effective depth: measured 10609' feet Junk (measured) true vertical 7517' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 84' 13-3/8" 485 SX Permafrost C 115' 115' surface 6196. 9-5/8" 305 bbl Arctic Set IV 6227' 4648' Intermediate 67 bbl Class G Production 10666' 7" 84 bbl Class G 10697' 7596' uner Perforation Depth: measured 10156-10235'; 10256-10270'; 10276-10300'; 10313-10343' true vertical 7151-7212'; 7229-7240'; 7245-7264'; 7274-7298' RECEIVED Tubing (size, grade, and measured depth) 2-7/8", L-80, 10064' J U L - 9 Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 545'; Otis RDH Pkr. 568~laska Oij & Gas Cons. Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 21, 1991 16. If proposal was verbally approved Oil X Gas Suspended Name of approver Date approved Service . 17. I hereby ~ertify thai the foregoing is true and correct to the best of my knowledge. Signed~')tS //tj~j~ J.H. Andrew T'~e Production Engineer Date July 2, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test __ Location clearanceI ~._~¢~'/'/~ ~1~ Mechanical Inteclritv Test Subsequent form required 10- /~;~ ¢- " ORIGINAL $16NEO ~'~-- LONNIE C, SMITI4 Approved Copy Approved by order of the Commission '"'[ ~ tl IC~ J ..... Commissioner Date q q / SUBMIT IN TRIPLICATE :orm 10-403 Rev 06/15/88 Milne Point Unit L-4 Well ESP Replacement Procedure Summary le · · · Se e · · · 10. 11. 12. 13. MIRU workover rig. Kill well by circulating hole full with 8.4 ppg source water. Spot salt-based LCM pills, if necessary, to control fluid losses. ND tree. NU and test BOP's. MU landing joint to tubing hanger. PU 25,000# above pipe weight to release Otis RDH retrievable packer at 568'. POOH with 2-7/8" production tubing and ESP. RU wireline. GIH and tag sand fill in casing. POOH and RD wireline. TIH with sand bailer on 2-7/8" production tubing and bail to clear perf interval, if necessary. MU new ESP assembly and TIH on 2-7/8" production tubing. MU an Otis RDH packer with annular vent valve. Install a 2- 7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. Land production tubing hanger and freeze protect annulus. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. Pressure test packer and annular vent valve by pressuring up on annulus to 500 psig. Freeze protect tubing. ND BOP's, NU and test tree. RDMO workover rig. RU and test flowline. Return well to ESP lift production. RECEIVED JUL -. 9 .Alaska Oil & Gas Cons. Commission Anchorage uI IGINAL ~ ' STATE OF. ALASKA ' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLL=..TION REPORT AND LOG 1. Status of Well Classification of Serwce !OIL '-~_ GAS r-~.~ SUSPENDED ? ABANDONED ~ SERVICE ~-2 Name of Operator CONOCO INC. 3. Address 340045 PRUDHOE BAY, 4. Location of well at surface 369' FWLt 2087' FNLt At Top Producing Interval 2275' FELt 410' FSLt At Tota~ Depth 2303' FEL¢ 914' FNL, AK 99734 SECTION 8 SECTION 6, T13N, R10E,~U~ImFi~D SECTION 6 ,T13N,RIOE, Elevation in feet iind~cate KB, DF, etc.) KB 56' MSI I6. Lease Des,gnat,on and Serial No. ADL25509 13. Date T.D. Reacl3ed 1 14. Date Comp., Susp. or AOand. ,04/07/90 COMP}. 09/28/90 COMP. 12. Date SpudOed 03/24/90 7. Perm~l NumDer 90-38 8 APl Number so- 029-22029 9. Unit or Lease Name MILNE POINT UNIT 10. Well Number T,--4 11. Field and Pool KUPARUK RIVER FIELD 15 Water Depth, if offshore 116 '.Nc of ComPleTions N/A feet MSL i 17. Total Depth IMD+TVD) )181Piug Back Depth (MD+TVD)I 19. D,rectional Survey 10,716~QT~D~Al 10,609/7518 ( YES .'~i[ NO~ 22. Type El~'tr,c ~r ~D~CmLogs Run 20. Deo~hwnereSSSV set I 21 Tn,c~ness of Permairos~ 544' ~e~M~ I +--1800' GR, CCL, CET, CBT, GCT, GYRO 23. CASING SIZE ,13-3/8' WT. PER FT. ,, 48# 24 Perforations open to Production (MD+TVD of Top and 36# 7" 26# 25. i SETTING DEPTH MD GRADE JTOP BOTTOM H-40 I 33 115'RKB J-55 t 33 6227'RKB L-80 t 33 10,697 ' RKB )ottom and CASING, LINER AND CEMENTING RECORD HOLE SIZE CEMENTING RECORD iAMOUNTPULLED 30" 14'85 SK'~ PE~I~ROS~ "C"NON~; 12.25 J305 BBLS A~CTIC S]~T NONE t IV & 67 BBLS CLASS "G"NONE 8.5,, 8;i C'L Ss ,;a,,i NONE TUBING RECORD interval, size and number) 10 ~313-10t343 ' (7274) 10~276-10t300 ' (7244) 10 ~256-10 t270' (7229) 10~ 156-10t235' (7151) - 7297' ) - 7263' ) - 7240' ) - 7212 ') 5JSPF & 4.5" 00 HYPER JET EHD=. 49" TTP=30.25" ... SIZE t DEPTH SET (MD) 2 7/8" 567' 2 7/8"1 9994' PACKER SET (MD) 567' 26. ACID, FRACTURE. CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) j AMOUNT & KIND OF MATERIAL USEL'" 10' 15.6,10:343 ! 350]~BLS LINEAR GEL PRODUCTION TEST iDate First Production , 11/05/90 iDate Of Test j Hours Tested · 12./23./9o) Method of Operation (Flowing, gas lift, etc.) FLORING IPROOUCTION FOR iOIL-BBL ITEST PERIOD ~m~ 220 GAS.MCr JWATER-BBL JCHOKESIZE iGAS-OILRATIOi 70 ' 206 I 318/1 Fi°wTubing tCasingPre$~ure iCALCULATED JOIL*BBL GAS*MCF iWATER'BBL iOILGRAVITY*API Ic°rr)i R m~ Press. 285 0 124-HOU RATE 880/ 280 22.6 * 28. CORE DATA . ,, .~ :..-, ~ ~,. :~[ ?. ~i''~ Briet description of Itthotogv, porosity, fractures, appatbnt 0iDS and presence of oil, gas or ware r. Submi:~'b6~e dht~{~ ~ ~)~:: ~,:¢ ~') NONE Form 10-407 DRILLING HISTORY Kuparuk River Field - North Slope Borough. Alaska Milne Pt. L No. 4 (I) CONFIDENTIAL Location: 2087' FNL, 369' FWL, Sec 8, T13N, R10E Objective: 7375' TVD - Kuparuk River W.I. 100% AFE 10-61-1194 Umiat Meridian 3-24-90: Accepted rig at 0400 HRS. NU divertor and function test. PU kelly and BHA, orient motor. Drlg. f/ 115' to 1053'. DEPTH ANGLE 315 0.20 495 2.60 586 3.80 676 6.40 766 8.50 857 11.5 Mud wt. 8.9 Viscosity: 49 Nabors 27E (0-1-0) DIRECTION N36.7W N35.1W N34.1W N31.8W N31.1W N32.5W Cum. mud cost:$ 4,415 Drilling Foreman: Mountjoy 3-25-90: Drlg f/ 1053' to 1356' short trip to 400' Drlg f/1356' to 2169'. Ream f/ 2044' to 2169'. Drlg. f/2169' to 2766'. short trip. DEPTH ANGLE 1191 22.30 1590 27.90 1874 34.80 2095 35.30 2378 42.80 2629 48.90 Mud wt. 9.5 Viscosity: 46 Nabors 27E (0-2-0) DIRECTION N26.5W N30.4W N29.5W N28.5W N27.8W N25.1W Cum. mud cost:$ 5,402 Drilling Foreman: Mountjoy 3-26-90-. Completed short trip. Drlg. f/2766' to 4124', circulate, short trip. Drlg. f/4124' to 4360'. DEPTH ANGLE 2974 49.80 3262 47.00 3610 46.50 3864 52.10 4210 54.20 Mud wt. 9.3 Viscosity: 43 Nabors 27E (0-3-0) DIRECTION N26.9W N25.8W N21.8W N20.2W N23.7W Cum. mud cost:$ 8,576 Drilling Foreman: Mountjoy 3-27-90: Drlg. f/4360' to 4788', MWD failed. Circ btms up, pump pill. POOH 6 stands, replace bearing in drawworks. POOH Change MWD and RIH. Drlg. f/4788' to 5108'. ~'~ '~i~' i DEPTH ANGLE DIRECTION 4430 53.10 N23.9W i~i 4714 49.20 N20.0W ~..% 4970 49.90 N19.7W '~.'~ ~ ~ Mud wt. 9.4 Nabors 27E (0-4-0) Viscosity: 46 Cum. mud cost:$ 11,173 Drilling Foreman: Mountjoy DRILLING HISTORY Kuparuk River Field - North Slope Borough. Alaska Milne Pt. L No. 4 (I) CONFIDENTIAL Location: 2087' FNL, 369' FWL, Sec 8, T13N, R10E Objective: 7375' TVD - Kuparuk River W.I. 100% AFE 10-61-1194 Umiat Meridian 3-28-90: Drlg. f/5108' to 5802'. Short trip 15 stands. Drlg f/ 5802' to 6063'. DEPTH ANGLE DIRECTION 5190 48.80 N21.6W 5471 49.10 N24.9W 5726 49.30 N22.7W 5886 49.20 N24.6W Mud wt. 9.60 Nabors 27E (0-5-0) Viscosity: 48 Cum. mud cost:$ 14,429 Drillinq Foreman: Mountjoy 3-29-90: Drlg. f/6063' to 6179'. POOH 9 stnds Laydown 1 jt washed out DP. RIH, Drlg f/6179' to 6238'. Circ and cond mud. POOH to DC, Had to wash up from 1238' to 1128'. RIH, circ and cond mud. POOH and laying down BHA. DEPTH ANGLE DIRECTION 6164 50.78 N21.1W Mud wt. 9.80 Nabors 27E (0-6-0) Viscosity: 45 Cum. mud cost:$ 18,679 Drillinq Foreman: Mountjoy 3-30-90: L/D BHA. R/U Csg crew & equip. Run 153 jts 9 5/8" 36# J-55 Butt. Csg w/mandrell hanger. M/U landing jt. & circ head. Circ & cond. one hole volume, pump two stage cement job: Stage 1 - 25 bbls 11.5 ppg sepiolite spacer + 25 bbls water, 316 bbls Permafrost E Cmt., 67 bbls Premium G Cmt., 5 bbls water + 275 bbls mud displacement. Stage 2 - 25 bbls water, 250 bbls Permafrost E Cmt., 5 bbls water & 140 bbls mud displacement. Bump plug w/ 2000 psig. R/D cmt equip., & L/D csg. running equip. R/D riser & diverter system. M/U speed head & N/U BOP stack. Mud wt. 8.40 Viscosity: 26 Nabors 27E (0-7-0) Cum. mud cost:$ 20,243 Drilling Foreman: Mountjoy 3-31-90: Test BOP's & assoc, equip. Install wear bushing. P/U BHA & orient MWD. TIH & tag cmt. @ 1865'MD. Drill cmt & DV tool to 1907'MD. TIH & tag float collar @ 6145'MD. Test csg. to 1600 psig for 30 min. --OK. Drill float equip. & 10' new form F/ 6238' to 6248'. Drlg F/6248' to 6928'. DEPTH ANGLE DIRECTION 6395 51.60 N21.1W 6615 52.30 N23.5W 6805 53.10 N24.1W Mud wt. 9.20 Viscosity: 37 Nabors 27E (0-8-0) Cum. mud cost:$ 22,989 Drilling Foreman: Polya DRILLING HISTORY Kuparuk River Field - North Slope Borough. Alaska Milne Pt. L No. 4 (I) CONFIDENTIAL Location: 2087' FNL, 369' FWL, Sec 8, T13N, R10E Objective: 7375' TVD - Kuparuk River W.I. 100% AFE 10-61-1194 Umiat Meridian 4-01-90: Drlg F/ 6928' to 7220'. MWd survey, pump dry slug blow down kelly. Short trip 12 stds. Drlg F/ 7220' to 7820'. Short trip 10 stds. Two stds tight,worked pipe free. Drlg F/ 7820' to 8015'. DEPTH ANGLE DIRECTION 7022 51.70 N26.2W 7116 51.80 N26.3W 7306 51.80 N28.6W 7433 52.30 N27.4W 7716 49.70 N30.6W 7872 49.00 N27.4W Mud wt. 9.40 Viscosity: 39 Nabors 27E (0-9-0) Cum. mud cost:$ 26,744 Drilling Foreman: Polya 4-02-90: Drlg F/ 8015' to 8418'. Short trip 10 stds., hole good--no fill. Drlg F/8596' to 9185'. Short trip 10 stds.,hole good--no fill. Drlg F/9185' to 9211'. DEPTH ANGLE 8029 48.20 8219 48.80 8409 49.60 8822 50.40 9043 51.10 Mud wt. 10.20 Viscosity: 44 Nabors 27E (0-10-0) DIRECTION N26.2W N26.0W N23.5W N24.1W N24.1W Cum. mud cost:$ 33,605 Drilling Foreman: Polya 4-03-90: Drlg. f/ 9211' to 9367'. Circ. bottoms up, pump dry slug, POOH. Change BHA, bit and MWD. TIH, work tight spots at 9144'. Drlg. f/9367' to 9412' Mud wt. 10.30 Viscosity: 43 Cum. mud cost:$ 36,419 Nabors 27E (0-11-0) Drilling Foreman: Polya 4-04-90: Drlg. f/ 9412' to 9526. Short trip 10 stands. Drlg. f/9526' to 9907'. Short trip 10 stands. Drlg. f/9907' to 9917'. Mud wt. 10.30 Viscosity: 46 Cum. mud cost:$ 39,881 Nabors 27E (0-12-0) Drilling Foreman: Mountjoy 4-05-90: Drlg. f/ 9917' to 10,267'. Short trip - 10 stands. Drlg. f/10267' to 10527'. DEPTH ANGLE 9992 41.10 10120 39.50 10213 38.40 10337 36.10 10465 33.40 Mud wt. 10.40 Viscosity: 44 Nabors 27E (0-13-0) DIRECTION N14.7W Nll.2W N09.5W N09.3W N07.9W Cum. mud cost:$ 41,748 Drillinq Foreman: Mountjoy DRILLING HISTORY Kuparuk River Field - North Slope Borough. Alaska Milne Pt. L No. 4 (I) CONFIDENTIAL Location: 2087' FNL, 369' FWL, Sec 8, T13N, R10E Objective: 7375' TVD - Kuparuk River W.I. 100% AFE 10-61-1194 Umiat Meridian 4-06-90: Drlg. f/10527' to 10,580'. Circulate, short trip to shoe, circulate. POOH and LD MWD. RU Schlumberger. RIH to 10,566' to log. Pull DIL/SFL AND CNL/LDT. RD Schlumberger. RIH to 6500' w/ sidewall core gun, couldn't get down. POOH. RIH w/ DP. Mud wt. 10.40 Viscosity: 44 Cum. mud cost:$ 43,917 Nabors 27E (0-14-0) Drilling Foreman: Mountjoy 4-07-90: RIH to shoe. Service rig. RIH, Drlg. f/10580' to 10716'. Circ. and condition hole. POOH LD DP. Change to pipe rams. LD HWDP AND BHA. Mud wt. 10.40 Viscosity: 43 Cum. mud cost:$ 48,004 Nabors 27E (0-15-0) Drilling Foreman: Mountjoy 4-08-90: RU csg crew, run 246 jts 7" 26 #/ft L-80 BUTT csg · , , , · Pump 50 BBLS Sepolit, 84 BBLS Class G cement· Displace w/ 380 BBLS 10.2 NaBr and 25 BBLS diesel, test csg to 3000 psi. RD cementing head and csg crew. Install 5" rams. ND BOP. Mud wt. N/A Viscosity: NA Cum. mud cost:$ 51,211 Nabors 27E (0-16-0) Drilling Foreman: Mountjoy 4-09-90: ND flowline,riser and BOP. Install tbg hanger and NU tree. Released rig at 0800HRS. PBTD 10,609'. This well will be droped from the drilling report until it is completed. Mud wt. N/A Viscosity: NA Cum. mud cost:$ 51,211 Nabors 27E (0-17-0) Drilling Foreman: Mountjoy Milne Point L No. 4 COMPLETION HISTORY Kuparuk River Field - North Slope Borough. Alaska Milne Pt. L No. 4 (P) CONFIDENTIAL Location: 2087' FNL, 369' FWL, Sec 8, T13N, R10E Objective: 7375' TVD - Kuparuk River W. I. 1.0 AFE 10-61-1194 Umiat Meridian 09-13-90: MIRU EWS rig 4. Accept rig at 1400 hrs. Mud wt. N/A Viscosity: NA Brine cost: $ EWS 4 (0-17-1) Drillinq Foreman: Stevens 09-14-90: Spot equipment. ND wellhead & NU BOPE. Test BOPE, vaived by AOGCC. MU 6" bit & csg scraper on 4" drill pipe. RIH w/ 4". Tag ice plug @ 400' & work through. Continue RIH. Brine wt. 10.2 Viscosity: NA Brine Cost: $ Cum. comp. cost: $ 17, 254 EWS 4 (0-17-2) Drilling Foreman: Stevens 09-15-90: Ice plug f/400' to 500' Continue RIH. Tag @ 10,606'. Reverse circ. filtering to 3 microns. Pump 25 bbls w/ 3ppb HEC, 50 bbls w/ DM-40, 25 bbls w/ 3ppb HEC. Circ. chem sweep around filtering returns to 3 microns. POOH. Brine wt. 10.2 Viscosity: NA Brine cost: $ 3,322 Cum. comp. cost: $ 20,716 EWS 4 (0-17-3) Drilling Foreman: Stevens 09-16-90: Continue POOH. Repair pipe skate. PU TCP guns and test assembly. RIH w/ TCP guns, 7" pkr, jars, bundle carrier, LPRN valve, drain valve, 2 DC's, drain valve, OMNI valve, 2 DC's, safety valve, R/A marker, & 4" work string. RU Sclumberger to correlate. POOH and R/D Schlumberger. Brine wt. 9.8 Viscosity: NA Brine cost: $ 3,322 Cum. cost: $ 1,761,356 (Includes drlng cost) (EWS 4 (0-17-4) Drilling Foreman: Stevens 09-17-90: LD pups & PU 1 Jt 4" DP. RIH to correlate. POOH and set pkr. RIH to correlate. OK. POOH & RD E-line. Pressure test lines and drill string to 3000 psi. Pressure up annulus & open LPRN the pressure up to fire guns. Run well flow test. SI well for pressure build up test. Brine wt. 9.8 Viscosity: NA Brine cost: $ 3,322 Cum. cost: $ 1,803,054 (EWS 4 (0-17-5) Drilling Foreman: Stevens 09-18-90: Continue pressure build-up, reverse circ w/9.Sppg bine. Release pkr. Reverse circ to kill well. POOH. Brine wt. 9.8 Viscosity: NA Brine cost: $ 3,586 Cum. cost: $ 1,824,599 (EWS 4 (0-17-6) Drilling Foreman: Stevens Milne Point L No. 4 COMPLETION HISTORY Page 2 09-19-90: Continue to POOH. LD DST tools, TCP guns, all guns fired. RU and RIH w/slcik line, tag fill at 10,530' WLM (10,543' RKB). PU 4" Schl. perforating guns, pkr, etc. RIH w/ perforating assembly. Brine wt. 9.8 Viscosity: NA Brine cost: $ 80,832 Cum. cost: $ 1,887,529 (EWS 4 (0-17-7) Drilling Foreman: Fox 09-20-90: Continue to RIH w/ perforating assembly. Correlate and space out. Pressure test surface lines to 3000 psi. Circulate to obtain 500 psi underbalance Perforate f/10,156' - 10,235' 10,256' - 10,270', 10,276' - 10,300' with 5 SPF. Flow weel for approx 20 min. SI well, reverse cirulate 120 BBL. Release pkr, POOH LD DP. Brine wt. 9.8 Viscosity: NA Brine cost: $ 80,832 Cum. cost: $ 1,914,760 (EWS 4 (0-17-8) Drillinq Foreman: Fox 09-21-90: Continue to POOH and LD perforating assembly. ND annular preventer, NU conversion spool, install tree saver. RU E- line, pressure test lubricator and test lines. RIH w/GR/TEMP/PRESS/CCL logging tool, correlate, make intial base line run across perforations, RIH to mid-perfs to monitor press and temp. Complete gelling and pump data frac as per procedure. Log across perforated interval. Secure frac equipment, pump 123 bbl of methanol/water to freeze protect well and complete displacement of tracer. Relog perforated interval. Survey indicates all intervals are taking fluid. Brine wt. 9.8 Viscosity: NA Brine cost: $ 80,832 Cum. cost: $ 1,992,463 (EWS 4 (0-17-9) Drillinq Foreman: Fox 09-22-90: Gel-up fluids, QC fluids, hold safety meeting. Pressure test lines to 5400 psi. Pump frac job @ 40 BPM as follows: 350 BBL of linear gel @2586 psi, 2200 BBL of cross-linked gel @2500 psi, 128,316 lbs 16/20 Carbo-Lite propant gradually ramped into 580 BBL of crossed-linked gel in concentrations from 0-8 lg/gal. Flush w/390 BBL 9.9 ppg NaCl brine @ 2520 psi. SD pumps, monitor pressure, final pressure = 1488 psi. RD frac equipment, NU Annular BOPE. Allow 4 hrs for gel to break, WHP = 700 psi and falling slowly. RU slick line, RIH w/2" blind box, tag fill @ 10,280' WLM, 49' above bottom perf. RIH w/ bailer on SL, tag fill at same depth, recovered frac sand and gel. Prepare to run memory gauge. Brine wt. 9.8 Viscosity: NA Brine cost: $ 80,832 Cum. cost: $ 2,384,076 (EWS 4 (0-17-10) Drillinq Foreman: Fox Milne Point L No. 4 COMPLETION HISTORY Page 3 9-23-90: RIH w/GRC memory gauge to 10,200' RKB. Took 30 minute stationary reading. Pooh taking 10 minute gradient stops & Pooh. EMW @ 10200' = 10.7 ppg, Avg Phyd = 9,72 ppg. Pressure tested 7" CSG. Packoff to 3000' psig-ok. PWH = 325 psig. Bleed off 10 bbl of fluid in 4 min. Shut well in Pwh = 200 psig. Wait 10 min. Pwh increased to 300 psig. Repeat two more times with identical results. Total volume bled off = 30 bbl. Wait on 550 bbl of 11.2 ppg brine to be mixed filtered, and transported. Rack & tally tubing. PWH @ 2400 hrs. = 270 psig. Brine wt. 9.2- 9.9 Viscosity: NA Brine cost: $80,832 Cum. cost: $2,435,070 EWS 4 (0-17-11) Drilling Foreman: Fox 9-24-90: Off load and filter brine. Mix 10 bbl HEC pill & pump 20 bbls. 11.2 ppg, 10 bbl pill, 374 bbls brine. RIH w/ notched collar and 2 7/8" tbg & TFF @ 10,356' RKB. Prepare to reverse circ. Could not maintain returns. POOH. P/U standing valve & Bulldog bailer. RIH w bailer and 2 7/8" tbg. Brine wt. 11.2 Viscosity: NA Brine cost: $ 182,638 Cum. cost: $2,571,800 EWS 4 (0-17-12) Drilling Foreman: Fox 9-25-90: Continue RIH w/ tbg. TFF @ 10,354' RKB. CO fill and bridges to 10,482 RKB. POOH w/tbg and bailer. Clean out bailer and redress flapper valve. RIH w/ bailer and tbg. and TFF @ 10,380' RKB. CO sand to 10,515' RKB. Short trip 10 stds. and TFF @ 10,485' RKB. CO to 10,515' and short trip 10 stds, TFF @ 10,515' RKB. POOH & L/D bailer. Brine wt. 11.2 Viscosity: NA Brine cost: $ 182,638 Cum. cost: $2,596,498 EWS 4 (0-17-13) Drilling Foreman: Fox 9-26-90: P/U Baker model G bridge plug & RIH on 2 7/8' tbg. Set BP @ 10,148' & test to 1000 psig. OK. Reverse circ. 15 bbl HEC pill and 555 bbls brine w/ corrosion inhibitor. Recovered 2 cu. ft. sand. Release BP & POOH w/ tbg & BP. R/U to run ESP. Pump 20 bbls deisel & RIH w/ ESP, 1 jt. tbg., check valve, 1 jt. tbg., Otis sliding sleeve circ. sub. RIH w/ 2 7/8" tbg and cable. Brine wt. 11.2 Viscosity: NA Brine cost: $ 203,348 Cum. cost: $2,648,833 EWS 4 (0-17-14) Drilling Foreman: Fox 9-27-90: Continue RIH. Ran 301 jts 2 7/8", 6.5#/ft, L-80 EUE 8 rd. tbg., Otis Dual Retrievable Pkr, 2 7/8" TMX SCSSV, 16 jts tbg, pump and 1/4" non-encapsulated control line. M/U tbg Hanger and final splice. Land tbg hng. Prep to set pkr. Brine wt. 11.2 Viscosity: NA Brine cost: $ 203,348 Cum. cost: $2,665,808 EWS 4 (0-17-15) Drilling Foreman: Fox Milne Point L No. 4 COMPLETION HISTORY Page 4 9-28-90: Press. up tbg. and bled off. R/U Transtech & RIH w/ X-X plug and attempt to set in sliding sleeve profile. Could not set. Redress plug and attempt again. Could not set. Set plug in pkr assembly & POOH w/ running tool. PT tbg to 500 psig. OK. Pressure up to 3000 psig and set pkr. Held pressure 10 min. OK. Pump 10 bbls diesel down csg. annulus. R/D Transtech. Pump 13 bbls diesel down annulus and test to 500 psig. OK. N/D BOP stack Check and repair hanger plate and seals. Pressure test hanger to 5000 psig. OK. RDRR Brine wt. 11.2 Viscosity: NA Brine cost: $ 203,559 Cum. cost: $2,795,363 EWS 4 (0-17-16) Drilling Foreman: Fox SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ORIGINAL CONOCO INC. MILNE POINT UNIT L-4 MILNE POINT NORTH SLOPEt ALASKA SURVEY DATE: X-MAY-90 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo OISTo PROJECTEO ONTO A TARGET AZIMUTH OF NORTH ZZ DEG 37 MIN WEST CONOCO INC. NILNE POINT UNIT HILNE POINT NORTH SLOPEr ALASKA COMPUTATION DATE: 1', AY-90 GE 1. DATE OF SURVEY: 1-HAY-90,. KELLY BUSHING ELEVATION: 56.00 FT . ENGINEER: SCHNARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -56.00 0 0 N 0 0 E 100.00 100.00 4&.O0 0 19 S 31 26 W ZO0.O0 200.00 144.00 0 15 S 59 52 W 300.00 300.00 244.00 0 22 S 89 10 ~ 400.00 399.98 343.98 I 13 N 52 9 ~ 500.00 499.94 443.94 2 11 N 43 32 W 600.00 599.77 543.77 4 18 N 33 25 W 700.00 699.28 643.28 6 55 N 31 19 W 800.00 798.26 742.26 9 32 N 31 59 ~ 900.00 896.29 840.29 13 49 N 30 36 W 1000.00 992.65 936.65 16 33 1100.00 1087.85 1031.85 19 33 1200.00 1181.21 1125.21 22 11 1300.00 1273.04 1217.04 24 41 1400.00 1362.20 1306.20 28 52 1500.00 1449.34 1393.34 29 0 1600,00 1537.11 14.81.11 28 45 1700.00 1624.20 1568.20 30 32 1800.00 1709.15 1653.15 33 16 1900.00 1791.88 1735.88 34 35 0.00 0.00 0.00 N 0.00 E -0.06 0.27 0.09 S 0.06 W -0.26 0.26 0.41 S 0.30 W · -0.30 1,16 0.64 S 0.75 W 0.81 1.13 0.02 S 2.14 W 3.54 1.53 2.03 N 4..33 ~ 9.02 2.62 6.55 N 7.73 W 18.66 1.43 14..83 N 12.93 W 32.65 1.37 26.86 N 20.43 W 52.07 4.42 43.65 N 30.62 W 2000.00 1873.95 1817.95 35 34 2100.00 1955.02 1899.02 35 39 2200.00 2035.78 1979.78 37 15 2300.00 2113.44 2057.44 40 58 24.00.00 2187.03 2131.03 4.4 11 2500.00 2256.12 2200.12 48 25 2600.00 2.321.50 2265.50 4.9 23 2700.00 2386.52 2330.52 4.9 39 2800,00 2450.83 2394.83 50 24 2900.00 2514.11 2458.11 50 52 N 29 11 W 78.53 N 27 21 ~ 108.95 N 26 16 ~ 14.4.67 N 26 23 W 184.16 N 27 2 W 229.28 N 26 55 ~ 278.17 N 27 5 W 325.96 N 27 27 W 374.94 N 27 9 W 427.50 N 26 59 W 483.50 3000.00 2577.81 2521.81 49 56 3100.00 2643.22 2587.22 4.8 40 3200.00 2709o36 2653.36 4.8 28 3300.00 2776.18 2720.18 4.7 46 3400.00 2843.03 2787.03 48 11 3500.00 Z909.97 2853.97 47 33 3600.00 2978.15 2922.15 46 39 370C. 00 304.6.24 2990.24. 47 53 3800.00 3112.08 3056.08 50 Z 3900.00 3174.39 3118.39 52 12 N 26 5 ~ 540.49 N 25 29 W 598.96 N 25 33 ~ 657.85 N 25 20 ~ 720.74 N 24 30 ~ 788.37 N 23 16 ~ 860.61 N 22 22 ~ 936.2T N 21 57 W 1012.24. N 21 27 W 1088.81 N 23 47 W 1166.23 N 23 56 W 1243.29 N 23 19 ~ 1318.92 N 22 37 W 1393.92 N 21 13 ~ 1468.30 N 20 13 W 1542.63 N 19 31 N 1616.84 N 18 48 ~ 1689.85 N 18 27 W 1762.91 N 17 58 W 1837.95 N 17 36 ~ 1915.87 0.00 N 0 0 E 0.10 S 34 26 W 0.51 S 36 22 W 0.98 S 49 36 W 2.14. S 89 32 W 4.78 N 64 50 W 10.13 N 49 42 W 19.68 N 41 6 W 33.75 N 37 16 W 53.32 N 35 3 W 1.72 4.12 2.09 3.91 3.39 2.41 0.76 2.84 2.93 0 66.79 N 43.87 W 79.91 N 33 18 W 93.73 N 58.32 W 110.39 N 31 54 W 125.70 N 74.4.5 W 14.6.10 N 30 38 W 161.18 N 91.99 W 185.58 N 29 4.3 W 201.61 N 112.28 W 230.76 N 29 7 W 2¢5.28 N 134.57 W 279.77 N 28 45 W 288.02 N 156.26 W 327.67 N 28 29 W 331.70 N ' 178.75 W 376.80 N 28 19 W 378.54. tq 203.00 W 4.29.53 N 28 12 W 428.57 N 228.53 W 485.69 N 28 4, W 2.49 0.90 3.52 3.84 2.92 3.09 0.63 0.59 1.11 1.90 479.66 N 254.10 W 542.81 N 27 55 W 532.42 N 279.48 W 601.31 N 27 42 W 585.65 N 304..85 W 660.24. N 27 30 W 64.2.51 N 331.91 W 723.17 N 27 19 W 703.86 N 360.49 W 790.81 N 27 7 W 769.91 N 389.80 W 862.96 N 26 51 W 839.69 N 419.04 W 938.44 N 26 31 W 910.07 N 647.66 W 1014.21 N 26 12 W 981.ZZ N 4.75.98 W 1090.57 N 25 53 W 1052.86 N 505.35 W 1167.86 N 25 38 W 0.67 0.48 0.97 1.23 0.73 1.32 0.81 Z.17 0.50 1123.24 N 536.79 W 1244..91 N 25 33 W 1192.53 N 567.12 W 1320.51 N 25 26 W 1261.57 N 596.43 W 1395.45 N 25 18 W 1330.58 N 624.20 W 1469.72 N 25 8 W 1400.14 N 650.50 W 1543.88 N 24 55 W 1470.04 N 675.68 W 1617.89 N 24 41 W 1539.11 N 699.75 W 1690.71 N 24 27 W 160B.54 N 723.06 W 1763.58 N 24 12 W 1680.01 N 7~6.63 W 1838.45 N 23 58 W 1754.52 N 770.39 W 1916.21 N 23 42 W CONOCO INC. MILNE POINT UNIT L-4 MZLNE POINT NORTH SLOPEr ALASKA COHPUTATION DATE: 1'~ ~Y-90 DATE OF SURVEY: 1-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ' INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3235.41 3179.41 52 39 4100.00 3295.45 3239.45 53 52 4200.00 3353.87 3297.87 54 22 4300.00 3412.49 3356.49 53 23 4400.00 3472.57 3416.57 53 10 4500.00 3532.66 3476.66 52 17 4600.00 3595.45 3539.45 50 24 4700.00 3659.84 3603.84 49 28 4800.00 3725.12 3669.12 49 5 4900.00 3790.28 3734.28 49 36 N 18 58 W 1994.86 N 20 8 W 2074.69 N 21 11 ~ 2155.81 N 20 49 N 2236.79 N 20 31 ~ 2316.69 N 20 18 N 2396.56 N 20 9 g 2474.31 N 19 47 ~ 2550.74 N 20 16 ~ 2626.40 N 20 48 g 2702.21 5000.00 3854.92 3798.92 49 58 5100.00 3918.76 3862.76 50 43 5200.00 3982.53 3926.53 49 36 5300.00 6047.50 3991.50 49 48 5400.00 4111.88 4055.88 49 52 5500.00 ~176.80 4120.80 49 9 5600.00 4242.58 4186.58 48 37 5700.00 4308.35 4252.35 49 15 5800.00 6373.48 4317.48 49 23 5900.00 6438.82 4382.82 49 7 N 20 15 N 2778.46 N 22 42 N 2855.40 N 22 28 N 2932.43 N 24 19 N 3008.44 N 24 26 W 3084.91 N 23 38 W 3160.95 N 23 2 ~ 3236.26 N 22 7 ~ 3311.59 N 21 27 ~ 3387.47 N 20 59 ~ 3463.14 6000.00 4504.00 4448.00 49 32 6100.00 4568.53 4512.53 50 11 6200.00 4631.92 4575.92 51 16 6300.00 6694.03 4638.03 51 57 6400.00 4755.61 4699.61 51 49 6500.00 4817.62 4761.62 51 48 6600.00 4878.91 4822.91 52 29 6700.00 4939.44 4883.~4 52 56 6800.00 4999.39 4943.39 53 23 6900.00 5058.87 5002.87 53 11 N 20 26 N 3538.94 N ZO 9 W 3615.26 N 20 9 g 3692.53 N ZO 20 ~ 3770.83 N ZO 37 ~ 3849.57 N 21 54 ~ 3927.99 N 24 0 ~ 4006.99 N 24 15 W 6086.56 N 24 24 g ¢166.56 N 24 36 ~ 4246.91 0.66 2.95 0.66 1.96 0.38 3.18 0.83 0.65 1.60 0.63 0.71 1.38 2.06 2.08 0.76 1.06 0.95 0.81 0.40 0.54 0.53 0.93 1.29 0.63 0.84 2.65 0.74 0.37 0.68 1.72 1829.75 N 795.23 ~1 1995.09 N 23 29 W 1905.22 N 821.67 kl 2074.85 N 23 20 I,/ 1981.03 N 850.63 g 2155.93 N 23 1, W 2056.66 N 879.69 g 2236.89 N 23 9 N 2131.47 N 907.8, W 2316.76 N 23 4 g 2206.38 N 935.74 ~1 2396.61 N 22 59 W 2279.39 N 962.67 . 2,7,.34 N 22 54 W 2565.00 N 1068.00 ~ 2778.46 N 22 36 ~ 2636.65 N 1096.08 g 2855.40 N 22 34 H 2707.71 N 1125.80 W 2932.43 N 22 35 g 2777.66 N 1155.56 ~ 3008.4' N 22 35 W 2847.25 N 1187.37 g 3084.91 N 22 38 W 2916.72 N 1218.34 ~ 3160.95 N 22 40 g 2985.89 N 1248.16 ~ 3236.27 N 22 41 W 3055.43 N 1277.09 ~ 3311.59 N 22 41 g 3125.92 N 1305.21 ~ 3387.47 N 22 ~0 g 3196.49 N 1332.60 W 3463.14 N 22 38 W 3267.43 N 1359.41 g 3538.94 N 22 35 g 3339.09 N 1385.86 ~ 3615.27 N 22 32 g 3411.70 N 1412.48 g 3692.54 N ZZ 29 g 3485.23 N 1439.61 g 3770.85 N 22 27 g 3559.08 N 1467.09 W 3849.59 N 22 24 g 3632.29 N 1495.27 g 3928.02 N ZZ 22 W 3704.92 N 1526.38 W 4007.03 N 22 23 g 3777.56 N 1558.93 g 4086.59 N 22 26 W 3850.69 N 1591.88 g 4166.58 N ZZ 28 W 3923.67 N 1625.16 ~ ~246.92 N 22 30 W 7000.00 5119.66 5063.66 52 11 7100.00 5180.92 5124.92 52 18 7200.00 5241.85 5185.85 52 31 7300.00 5302.87 5246.87 52 21 7400.00 5363.82 5307.82 52 7500.00 5424.46 5368.46 52 42 7600.00 5486.88 5430.88 50 6 770~.00 5551.07 5495.07 50 1Z 7800.00 5614.95 5558.95 50 17 7900.00 5679.40 5623.40 49 37 N 25 1Z N 4326.25 N 25 30 g 4405.20 N 25 44 ~ 4484.38 N 26 16 W 4563.47 N 26 46 g 4642.56 N 27 6 ~ 4721.86 N 28 50 ~ 4799.64 N 29 20 W 4875.82 N 29 27 g 4952.21 N 27 12 g 5028.30 0.83 0.37 0.62 0.63 0.38 1.17 I .28 0.78 1.01 0.24 3995.66 N 1658.65 ~1 4326.25 N 22 33 W ~067.08 N 1692.52 N 4405.20 N 22 36 ~1 4138.59 N 1726.78 ~I 4484.38 N 22 39 W 4209.80 N 1761.49 Id 4563.47 N 22 42 W 4280.74 N 1796.88 N 4642.58 N 22 46 g 4351.65 N 1832.87 ~1 4721.89 N 22 50 I,I 4420.69 N 1869.38 g 4799.70 N 22 55 kl 4487.68 N 1906.71 N 4875.94 N 23 1 g ~554.65 N 1944.58 W 4~952.39 N 23 7 H ~,622.04 N 19t10.T0 Id 5028.56 N 23 12 N CONOCO 1:NC. H]:LNE PO:[NT UNIT L-4 HILNE POZNT NORTH SLOPE· ALASKA COHPUTATION DATE: 1~ .AY-90 5E 3 ,. DATE OF SURVEY: 1-MAY~90, KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHNARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZIMUTH ' FEET DEG/ZO0 FEET FEET FEET DEG 8000.00 5744.38 5688.38 49 13 8100.00 5809.85 5753.85 49 7 8200.00 5875.18 5819.18 49 17 8300.00 5940.13 5884.13 49 33 8400.00 6004073 5948.73 49 55 8500.00 6068093 6012.93 50 17 8600000 6132.61 '6076.61 50 39 8700.00 6195.90 6139.90 50 47 8800.00 6258.92 6202.92 51 4 8900.00 6321.64 6265.64 51 19 N 25 25 14 5104.11 N 23 57 g 5179.66 N 23 59 g 5255.35 N 23 58 14 5331.37 N 23 51 14 5407.68 N 23 50 14 5484.33 N 23 54 g 5561.42 N 23 58 14 5638.82 N Z4 8 14 5716.44 N 24 15 14 5794.29 9000.00 6383.94 6327.94 51 37 9100.00 6445.71 6389.71 51 54 9200.00 6508.02 6452.02 50 47 9300.00 6570.28 6514.28 52 9 9400.00 6631.24 6575.14 52 29 9500.00 6692.96 6636.96 51 25 9600.00 6756.11 6700.11 50 15 9700.00 6820.65 6764.65 49 15 9800.00 6887.53 6831.53 46 33 9900.00 6958.43 6902.43 43 18 N 24 19 14 5872.48 N 24 17 14 5951.09 N 25 14 ~ 6029.25 N 26 0 14 6107.39 N 26 16 g 6186.50 N 25 18 g 6265.06 N 24 52 ~ 6342.53 N 24 30 14 6418.86 N ZO 42 14 6493.17 N 16 I W 6563.46 LO000.O0 7032.55 6976.55 41 25 L0100.O0 7108.19 7052.19 40 18 ~0200.00 7185.00 7129.00 39.17 t0300.O0 7263.61 7207.61 37 16 L0400.O0 7343.97 7287.97 35 35 LO500.O0 7426.55 7370.55 33 12 L0600000 7510.30 7454.30 33 6 L0613.00 7511.19 7465.19 33 6 N 12 2 ti 6629.78 N 8 43 14 6693.69 N 6 26 14 6755.44 N 6 34 ~ 6814.83 N 6 55 14 6872.10 N 4 28 14 6926.09 N & 3 14 6977.79 N 4 3 14 6984.52 3.49 0.16 0.00 0.79 0.12 0.30 0.37 0.11 0.63 0.41 4689.90 N 2014.91 14 5104.42 N 23 15 ti 4758.79 N 2046.02 14 5179.98 N 23 16 ~ 4827.97 N 2076.78 g 5255.69 N 23 17 14 4897.44 N 2107.70 . 5331.73 N 23 17 ti 4967.21N 2138.65 14 5408.05 N 23 18 ~ 5037.35 N 2169.63 14 5484.71 N 23 18" N 2200.82 W 5561.82 N 23 19 W '~ 5107.86 5178.63 N 2232.22 14 5639.2' N 23 19 ~ 5249-55 N 2263.83 "5716.88 N 23 20 N 5320.60 N 2295.72 14 5794.75 N 23 20 N 1.01 0.54 1.66 1.18 0.95 1.03 0.55 2.16 4.14 3.78 5391090 N 2327.89 14 5872.96 N 23 21 g 5463.55 N 2360.29 14 5951.59 N 23 22 N 5534064 N 2392.93 14 6029.79 N 23 23 ~ 5605.20 N 2426.74 g 6107.97 N 23 25 ~ 5676.26 N 2461.87 g 6187.15 N 23 27 g 5747.12 N 2496.05 14 6265.76 N 23 29 ~ 5817.39 N 2528.82 14 6343.26 N 23 30 ~ 5886.77 N 2560.79 14 6419.63 N 23 31 ~ 5955.26 N 2589.63 14 6493.94 N 23 30 ~ 6022.11 N 2611.93 14 6564.14 N 23 27 g 2.11 2.22 1.96 0098 3.43 3.32 0.00 0.00 6087.26 N 2627.99 ti 6630.32 N 23 21 14 6151.59 N 2639.77 14 6694.07 N 23 14 ti 6215.09 N 2647.93 14 6755.66 N 23 5 6276.49 N 2654.99 14 6814.93 N 22 56 6335.58 N 2662.06 14 6871.13 N 21 47 6391.66 N 2667.83 ti 6926.09 N 21 39 6446.01 N 2671.8Z 14 6977.80 N 22 31 6453.10 N 2671032 14 6984.54 N 21 30 14 CONOCO INC. MILNE POINT UNIT L-4 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 1' 'AY-90 GE 4 DATE OF SURVEY: 1-H~Y-90 KELLY 9USHING ELEVATION: 56,00 Ft ENGINEER: SCHWARTZ' INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE ~EASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG R~CTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG 0.00 0.00 -56.00 0 0 1000.00 992.65 936.65 16 33 2000.00 1873.95 1817.95 35 34 3000.00 2577.81 2521.81 49 56 4000.00 3235.41 3179.41 52 39 5000.00 3854.92 3798.92 49 58 6000.00' ~504.00 4448.00' 49 32 7000.00 5119.66 5063.66 52 11 8000.00 5744.38 5688.38 49 13 9000.00 6383.94 6327.94 51 37 N 0 0 E 0.00 N 29 11W 78.53 N 26 5 W 540.49 N 23 56 W 1243.29 N 18 58 W 1994.86 N ZO 15 W 2778.46 N 20 26 ~ 3538.94 N 25 12 ~ 4326.25 N 25 25 ~ 510&.11 N 24 19 ~ 5872.48 tO000.O0 7032.55 6976.55 41 25 [0613.00 75Z1.19 7465.19 33 6 N 12 2 W 6629.78 N 4 3 ~ 6984.52 0.00 1.72 2.49 0.67 0.66 0.71 0.53 0.83 3 1.01 2.11 0.00 0.00 N 0.00 E 0.00 N 0 0 E 66.79 N 43.87 W 79.91 N 33 18 W 479.66 N 254.10 ~ 542.81 N 27 55 W 1123.24. N 536.79 W 1244.91 N 25 33 W 1829.75 N 795.23 W 1995.09 N 23 29 ~ 2565.00 N 1068.00 M 2778.46 N 22 36 ~ 3267.43 N 1359.41 W 3538.94 N 22 35 I,I ~ 3995.66 N 1658.65 ~ 4326.25 N 22 33 ~ , 4689.90 N 2014.91 W 5104.42 N 23 15 N 5391.90 N 2327.89 W 5872.96 N 23 21 ~ 6087.26 N 2627.99 !,/ 6630.32 N 23 21 6453.10 N 2672.3Z W 6984.54 N 22 30 W AOGCC GEOLOgiCAL MATERIALS iNVENTORY LIST PEFIiviiT # I I ~ -- $4° WELL NAiViE .Y~r ~ ~,,',, Z' /_--/, Z ~/ /_ -- ~/ COMPLET!ON BATE /~ t,~ ! ,~'o C0. CONTACT ~,~o~.,, ..~. check off or list data as it is received.*list received date for 407. if not uired list as NR I'"'~o7 !' Y/Gal/?) I drilling histo~ I Jl' survey!' /I ~e[[ tests ~'~] c~re descriptio[~ J F,o,red intervals core analys, is ~ dh/ditch i'ntcrvais .... ' digital data ..... 5'/,/'-~ ? c' -v,~ , , ,-~_ RUN SCALE I1~1 I ...... I~0. [to.thc nearest foot] ... [inchll00'} - z]- .C.~_ ~.~ ~j ...... ¢ H~- ~¢.~;~y (~,~; / /~- - ', [ [ [ [[[ [ / [[ [ ii i ii 12] ' / ] .. 17] ~ L_ II I II IIIIJ IIIIIII I I I ~ II III IIIIlU_ . ,1111 I 18l , i ........ ~ ,,~ CONOCO, Inc. SCHLUMBERGER WELL SERVICES A DIVISION OF.~H~HLUMB£RGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 ~E REPLY TO SEP 2 6 1990 SC"~U~.E~GE~WELL ~,CES Pouch 340069 ?rudhoe Bay, ^K 99734-0069 Attn: Bernie/Shelley 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention:.. Marc Shannon Gentlemen: Temp/Press Log (Data Frac), Run 1, Enclosed ore_Z_llL_printsoftheTCP Correlatinn Log; R],n 1; ~/20/90 Company . CONOCO: .Inc. Well Milne Point Unit L-4 ~)/21/9o _on: Field Milne Poin~ Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George L~mb - OF 2015 PER County North Slope State Alaska _L_BL_prints, 1 RF Sepia CONOCO~ Tn¢ 1000 South Pi ne Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Driv~ Midland, TX 79710 Attn: John Carrol :*(915/685-5600) _[__][L_prints, 1RF Sepia Chevron U.S.A. 6OO1BollJnger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeray *(415/842-1000) Alaska"Oil & Gas con'Serv~ig ?:COmmission 73001 Porcupine Drive f' Anchorage, AK 99501 '<~ At tn: jOhn Boyle The film is returned to Conoco, Log Library. We oppreciote the privilege of serving you. prints prints prints ~ Anchorage Received by: .. ~x~~,~ ~ Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF ~C. HLUMB£RGER TIrCHNOL(X~Y CORPORATION I-tOUSTON, TEXAS 77251-2175 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention' Marc Shannon ~ RElY TO SCHLUMBERGER WELL ~ICE$Pouch 340069 ?rudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore~rints of the Gamma Ray - Position TCP Guns,_Run 1, 9/17/90 on: Company CONOCO~ Tnc. , Well MILNE POINT UNIT L-4 Field MJ lne Poi n~ Additionol prints ore being sent to' 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - 0F 2018 PER ... County_ North Slope Stote_ Alaska ~l_JtL_prints, I RF Sepia 1000 South Pine Ponca City, OK 74603 Attn: Log L~bIary 1BL prints, 1RF Sepia OXY U.S.A., Inc. § Desta Dr.iv~ Midlaod, TX 79710 Attn: John Carrol *(915/685-5600) prints _l_JtL_~rints, 1RF Sepia Chevron U.S.A. .6OO1BollJnger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1OOO) ...... prints Atask'a'?'0~i ~ & Gas Con~er'v'~'t~(:~ I' ' ~' ! V E O :/:~ Co .mmS.s. sion . "~'- - - - 3OO1 Porcupine Drive Jk,,:-~m,~ u~ Anchorage, ~ 99501 /<-~;,r~ ~i ;~ ]9~0 ~'.At tn: John Boyle ~?~;~'AJa~;n ..... ~il_.. -~ Gag C0~$. CO~JSSjOD The film is returned to Conoco, Log Library. prints ReceJ ved by; Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER $~-- 1327-4r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter Casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. 3. Address 4. Location of well at surface 369' FWL, 2087' FNL, SEC 8, T13N, At top of productive interval At effective depth At total depth 2303' FEL~ 914' FNL, SEC 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 6192 ' Intermediate Production 10662' Liner Perforation depth: measured N/A 6, T13N, RIOE 10719 7655'* 10612' 7574'* Operation shutdown __ Re-enter suspended well Plugging __ Time extension m Pull tubing __ Variance ~ Perforate J 5. Type of Weil: Development -X- Exploratory ~ Stratigraphic __ ~9 .'.7~ . Service __ RIOE, UR feet feet true vertical Tubing (size, grade, and measured depth) NONE Packers and SSSV (type and measured depth~0NE feet feet Plugs (measured) Stim utat%-~'-er __ 6. Datum elevation (DF or KB) 56' KB MSL Z Unit or Property name MILNE POINT UNIT 8. Well number I-4 9. Permit number 90-38 10. APl number 5o- n~q-22_npq 11. Field/Pool KUPARUK RIVER feet Junk (measured) Size Cemented Measured depth 13-3/8" TO SURFACE 115' 9-5/8" 519 BBL CLASS E 6227' 83 BBL CLASS G 7" 84 BBL CLASS G 10697' True vertical depth 115' 4667' 7646' 13. Attachments Description summary of proposatx__ Detailed operations program __ BOP sketcl, _ 14. Estimated date for commencing operation AIIPJI~T 1'~ 100¢1 16. if'l~r~s'al v~s've~'b'a~C'approved 9' 13E~a~e0approved 15. 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. Signed /~]~-'~4 _r')-)7-~,,~-,_~-'~ TitI~FN f I'll~ rtDTI I TNR · -, c FOR CO'FClMISSIONOSE ONTLy .......... Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- (", o~' JApproval No. ¢~).- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Commissi9ner Apprc':ed Returned Date~/~//~(~ SUBMIT IN TRIPLICATE L-4 COI~PLETION PROCEDURE S~Y 1. MIRU. ND TREE, NU AND TEST BOPE. · PICK UP WORK STRING (4~wDP) W/6w~ BIT AND 7" CSG SCRAPER. ADD 100 BBLS SOURCE WATER TO RIG VOLUME TANK. RIH AND CLEANOUT CSG (REVERSE CIRCULATING) TO PBTD @ 10,609~RKB. FILTER BRINE RETURNS. CIRCULATE AT LEAST i TBG VOLUME AFTER RETURNS CLEAN UP. 3. PRESSURE TEST CSG TO 3000 PSI FOR 30 MINUTES. · PUMP THE FOLLOWING CHEMICAL SWEEP @ 4 BPM TO CLEAN OUT CSG: 50 BBL PILL W/3PPB HEC IN SOURCE WATER 50 BBL SOURCE WATER 50 BBL SOURCE WATER W/1 DRUM DM-40 CIRCULATE TO CLEAN RETURNS. POOH MU DST TOOL STRING AND TCP GUNS. RIH AND PERFORATE LK-3 1000 PSI UNDERBAL]tNCEDW/TCP GUNS 5 JSPF IN THE FOLLOWING INTERVAL: LK-3 10,312 - 10,342 MD CORRELATE DEPTHS W/E-LINE GR & CCL LOG. FLOW TEST LK-3 FOR 6 HRS AT A STABILIZED RATE. RUN 18 HOUR PRESSUE BUILD-UP AFTER FLOW TEST. POOH W/DST TOOL STRING AND LD DST TOOLS. · · MU TCP GUNS ON 4w~ DP, RIH, AND PERFORATE THE LK-1 AND LK-2 400 PSI OVERBALANCED W/5 JSPF IN THE FOLLOWING..INTERVALS: LK-1 10,256 - 10,270 MD LK-2 10,276 - 10,300 MD .~ '! ~ i~(! POOH a LD PERF GUNS ' MU TREATING/ISOLATION TOOL (PKR) ON 4~DP. RiH AND SET 50 ABOVE LK-1 PERFS. RU DOWELL AND FRAC LK-1, LK-2, AND LK-3. SEE FRAC PROCEDURE· 10. RELEASE TREATING/ISOLATION TOOL AND POOH. RU W/L AND RIH TO TAG FILL. 11. BAIL FILL USING BULLDOG BAILER OR 5~ W/L BAILER DEPENDING ON AMOUNT OF FILL· 12. MU ?~RBP, RIH AND SET TO ISOLATE LZ FROM LK ZONES. SET BP @ 10, 245~ MD AND PRESSURE TEST TO VERIFY PLUG IS ABOVE LK PERFS. POOH· 13. MU TCP GUNSv RIH AND PERFORATE THE LZ 400 PSI OVERBALANCED W/SJSPF AT THE FOLLOWING INTERVAL= LZ 10w156 - 10w235 MD POOH /~ND LD GUNS 14. RU DOWELL AND FR~C THE LZ. SEE FRAC PROCEDURE. 15. 16. RU W/L RIH AND TAG FILL. BAIL FILL 17. RIH TO RETRIEVE 7~IRPB. POOH. 18. RUN ESP COMPLETION ON 2 7/8" TBG. . .LASKA OIL AND ~'As ~(~NSE-R~/ATION COk',,,,,iSSION FIEPO[ OF SUNDRY WELL OPEI TiON$ 1. Operations performed: Operation shutdown ~ Pull tuNng __ Alter casing __ Repair well __ 2. Name of Operator ~ 5. Type of Well: Development ~ CONOCO INC..1 Ex¢oratory__ 3. Address ! Stratigraphic_ P.O. BOX 340045, PRUDHOE BAY, ,AK 9973~3 Service__ Stimulate ~ Plugg,ng __ Perforate __ Other --X 6. Datum elevation (DF or KB) ,56 KB M~[ feet 7. Unit or Property name MILNE POINT UNIT .. 4. Location of well at surface 369' FWL, 2087' FNL, SECTION 8, TWP 13N, RIOE, UH At top of productive intervaJ At effective depth GYRO SURVEY NOT PRESENTLY AVAILABLE At total depth 12. Present well condition summary Total depth: measured Plugs(measured) 8. Well number I_/I g. P~'rm[t number/approval number 90-38 10. APl number 50-- 11. Field/Pool KIIPARIIK Effective depth: Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: 10719' true vedical 7 6 5 5 ' * measured 10612' true vertical 7574'* Length feet feet Junk(measured) Size Cemented Measured depth 80' 6192' 10662' measured N/A 13-3/8" ' TO SURFACE 9-5/8" 519 BBL CLASS E 83 BBL CLASS G 7" 84 BBL CLASS G True vertical depth 115' 115' 6227' 4667' 10697' 7646' true vertical Tubing (size, grade, and measured depth) *NOTE: TVD'S ARE BASED ON MWD DIRECTIONAL DATA, NOT FROM GY Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary KEL, EI V EL¢ 14. Intervals treated (measured) N/A MAY 1 4 1990 Treatment description includin9 ,,,*olumes used and final pressure A~aSk~ .0il & Gas Cons. Commission Representative Daily Average Production or Injection I~ai~ OiI-Bbl Gas-Mci Waler-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments · 16. Status of well classification as: Copies of Logs and Surveys ru~O Fo] l ow Daily Repod of Well Operation¢'__ Oil __ Gas __ Suspended __ 17. ! hereby cedify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 06115/88 Title SENIOR DRILLING FOREMAN Date O.q/n7/qn SUBMIT IN DUPLICATE tO. Kuparuk River River Field - North Slope Borough, Alaska W.I. 100% Milne Point Well Number L-4 CONFIDENTIAL API No. 50-029-22029 Alaska Permit No. 90-38 Location: 369' FWL, 2087' FNL, Section 8, TWP 13N, R10E, UM MARCH 24, 1990 NU DIVERTOR FUNCTION TEST, TAKE ON WATER, FUNCTION TEST. PU KELLY AND BHA, ORIENT MOTOR, DRLD 40' ICE IN COND. DRLD F/l15' TO 1053'. ACCEPTED RIG @ 0400 HRS 3/24/90. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 4,415 Cumulative Mud Cost: $ 4,415 67,464 Cumulative Cost: $ 67,464 MARCH 25, 1990' DRLD F/ 1053' TO 1356'. 1.0 SHORT TRIP TO 400'. DRLD F/ 1356' TO 2169'. 1.5 REAM 2044' TO 2169' TO REMOVE EXCESSIVE DOGLEG. 5.5 DRLD F/ 2169' TO 2766'. 2.0 SHORT TRIP TO 466'. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 986 Cumulative Mud Cost: $ 5,402 47,494 Cumulative Cost: $ 164,712 March 26, 1990 FINISH SHORT TRIP. DRLD F/ 2766' TO 4124'. CIRCULATE. SHORT TRIP 28 STANDS NO FILL NO EXCESSIVE PULL. DRLD F/ 4124' TO 4360'. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 3,174 Cumulative Mud Cost: $ 8,576 46,577 Cumulative Cost: $ 211,289 March 27, 1990 DRLD F/ 4360' TO 4788',MWD FAILED. CIRC BOTTOMS UP AND PUMP PILL. POOH WITH 6 STDS. REPLACE BEARING IN DRAWWORKS. POOH TO BHA. CUT AND SLIP 100' DRLG LINE. POOH W/BHA, CHANGE MWD, RIH. DRLD F/ 4788' TO 5108'. Daily Mud Cost: $ 2,597 Cumulative Mud Cost: $ 11,173 Daily Cost: $ 37,989 Cumulative Cost: $ 249,278 March 28, 1990 DRLD F/ 5108' TO 5802'. TO 6063 ' . Daily Mud Cost: $ Daily Cost: $ 1.0 SHORT TRIP 15 STDS. 7.5 DRLD F/ 5802' 3,077 Cumulative Mud Cost: $ 14,249 44,998 Cumulative Cost: $ 294,276 MARCH 29, 1990 DRLD F/ 6063' TO 6179'. 1.5 POOH 9 STDS, LAYDOWN 1 JT WASHED OUT DP, RIH. 4.0 DRLD F/ 6179' TO 6238'. 2.0 CIRC AND COND MUD. 6.0 POOH TO DC, HAD TO WASH UP 1238' TO 1128' RIH. 2.0 CIRC AND COND. 3.0 POOH AND LAYING DOWN BHA. Daily Mud Cost: Daily Cost: $ 4,430 Cumulative Mud Cost: $ 18,679 $ 171,308 Cumulative Cost: $ 469,584 MARCH 30, 1990 L/D BHA. CLEAR RIG FLOOR & R/U CSG CREW & EQUIP. RAN 153 JTS 9 5/8" 36# J-55 BUTT. CSG W/ MANDRELL HANGER. M/U LANDING JT. & CIRC. HEAD. CIRC. & COND. ONE HOLE VOLUME. PUMP TWO STAGE CEMENT JOB: STAGE 1: 25 BBLS 11.5 PPG SEPIOLITE SPACE + 25 BBLS H20. 316 BBLS PERMAFROST "E" CMT. 67 BBLS PREMIUM "G" CMT. 5 BBLS H20 + 275 BBLS MUD DISPLACEMENT. STAGE 2: 25 BBLS H20. 203 BBLS TYPE "G" CMT. 16 BBLS TYPE "G" CMT. 5 BBLS H20 + 140 BBLS MUD MISPLACEMENT. BUMP PLUG W/ 2000 PSIG. B/O LANDING JT., R/D CMT. EQUIP., & L/D CSG. RUNNING EQUIP. R/D RISER & DIVERTER SYSTEM. M/U SPEED HEAD & N/U BOP STACK. Daily Mud Cost: Daily Cost: $ 1,563 Cumulative Mud Cost: $ 20,243 $ 118,037 Cumulative Cost: $ 587,622 MARCH 31, 1990 TEST BOP'S & ASSOC. EQUIP. INSTALL WEAR BUSHING. P/U BHA 7 ORIENT MWD. TIH & TAG CMT @ 1865' MD. DRILL CMT & DV TOOL TO 1907' MD. TIH & TAG FLOAT COLLAR @ 6145' MD. TEST CSG TO 1600 PSIG FOR 30 MIN.--OK. DRILL FLOAT EQUIP. & 10' NEW FM. F/6238' - 6248'. PIT 14.2 EMW. 9.0 DRLG F/6248'-6928'. NO PROBLEMS. Daily Mud Cost: $ Daily Cost: $ 2,746 Cumulative Mud Cost: $ 22,989 40,631 Cumulative Cost: $ 628,253 APRIL 1, 1990 DRLG F/6928'-7220'. MWD SURVEY, PUMP DRY SLUG, BLOW DOWN KELLY. 1.0 SHORT TRIP 12 STDS. (HOLE IN GOOD CONDITION--NO PROBLEMS). 12.0 DRLG F/7220'-7820'. 1.0 SHORT TRIP 10 STDS. (LAST TWO STDS TIGHT, WORKED PIPE TO FREE O.0 UP 5' FILL. 5.0 DRLG F/7820'-8015'. NOTE: BIT SEEMS TO BALLUP AFTER MAKING SLIDES WHICH DRASTICALLY REDUCES ROP. SEEMED TO HAVE SOLVED THE PROBLEM W/ ADDING CONDENT (SOAP), CUP OF SAP ON CONNECTIONS, AND PUMPING 5 BBL FRESH H20 SWEEPS AFTER SLIDING. Daily Mud Cost: $ Daily Cost: $ 3,755 Cumulative Mud Cost: $ 26,744 48,316 Cumulative Cost: $ 702,151 APRIL 3, 1990 DRLG F/9211'-9367'. CBU & PUMP DRY SLUG. L/D 6 SINGLES & POOH, L/D TURBINE. (NOTE: CALC HOLE FILL = 85 BBLS, ACTUAL = 87 BBLS.) CHANGE BHA, BIT,K & MWD. SERVICE RIG. ORIENT MWD & TIH, WORK TIGHT SPOT AT 9144'. REAM 6 JTS. TO 9367'. 3.5 DRTGL F/9367' - 9412'. Daily Mud Cost: $ Daily Cost: $ 2,814 Cumulative Mud Cost: $ 36,419 42,626 Cumulative Cost: $ 804,874 APRIL 4, 1990 DRLD F/9412' TO 9526'. SHORT TRIP 10 STDS. DRLD F/9526' TO 9907'. SHORT TRIP 10 STDS. DRLD F/9907' TO 9917'. DAVID MOUNTJOY Daily Mud Cost: $ 3,462 Cumulative Mud Cost: $ 39,881 Daily Cost: $ 36,893 Cumulative Cost: $ 841,767 APRIL 5, 1990 DRLD F/9917' TO 10,267'. SHORT TRIP 10 STANDS. DRLD F/10,267' TO 10,527'. DAVID MOUNTJOY Daily Mud Cost: $ 1,866 Cumulative Mud Cost: $ 41,748 Daily Cost: $ 62,871 Cumulative Cost: $ 844,638 APRIL 6, 1990 DRLD F/10,527' TO 10,580'. CIRC. SHORT TRIP TO SHOE. CIRC. POOH AND LD MWD. RU SCHLUMBERGER, RIH TO 10,566', PULL DIL/SFL AND CNL/LDT, RD. WAIT ON SIDEWALL CORE GUN. RIH TO 6500' COULDN'T GET DOWN, POOH, RD. RIH WITH DP. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 2,168 Cumulative Mud Cost: $ 43,917 $ 105,132 Cumulative Cost: $ 949,770 APRIL 7, 1990 RIH TO SHOE. FILL PIPE. SERVICE RIG. REPAIR CLUTCH. CUT AND SLIP 110' DRLG LINE. RIH. DRLD F/10,580' TO 10,716'. CIRC AND CONDITION HOLE. POOH LAYING DOWN DP. CHANGE TOP PIPE RAMS. LD HWDP AND BHA. DAVID MOUNTJOY Daily Mud Cost: $ 4,087 Cumulative Mud Cost: $ 48,004 Daily Cost: $ 34,765 Cumulative Cost: $ 984,535 APRIL 8, 1990 PULL WEAR RING, RU CSG CREW. RUN 246 JTS 7" CSG, CIRC @ 6220' & 9235'. MAKE UP LANDING JT AND CEMENT HEAD. CIRC AND WORK CSG FREE, TRIED TO PACKOFF, PULLED 450K. DISPLACED WITH 380 BBLS 10.2 NABR AND 25 BBLS OF DIESEL. TESTED CSG TO 3000 PSIG FOR 30 MIN. RD CEMENTING HEAD, LD LANDING JT, RD CSG CREW. INSTALL PACKOFF AND TEST TO 5000 PSI. INSTALL 5" RAMS. ND BOP. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 3,207 Cumulative Mud Cost: $ 51,211 $ 424,910 Cumulative Cost: $1,409,445 APRIL 9, 1990 ND FLOWLINE, RISER AND BOP. INSTALL TBG HANGER AND NU TREE. FINISH CLEANING PITS. RELEASED RIG AT 0800 HRS 04/09/90. PBTD 10,609'. FUEL LEFT IN RIG 9352 GALLONS. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 0 Cumulative Mud Cost: $ 51,211 19,391 Cumulative Cost: $1,428,836 0ii & Anch~rag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Pull tubing __ Variance __ 2. N~l~lfcO0oef~(~. ~ 5. Type of Well: Development ~ Exploratory __ 3. Address Stratigraphic_ P.0. BOX 340045, PRUDHOE BAY, AK 997 Service__ Operation shutdown _~X Re-enter suspended well __ Plugging ~ Time extension __ Stimulate __ Perforate __ Other __ 6. Datum %l~;v~ati~,rb;(Dl~)[.KB) 7. Unit or Property name MILNE POINT UNIT feet 4. Location of well at surface 369' FWL, 2087' At top of productive interval At effective depth GYRO SURVEY NOT At total depth FNL, SEC 8, T13N, R10E, UM PRESENTLY AVAILABLE 12. Present well condition summary Total depth: mea§u red 10719 feet Plugs (measured) true vertical 7655 ' * feet 8. Well number L-4 9. Permit number 90-38 10. APl number 50- 029-22029 11. Field/Pool KUPARUK RIVER RECEIVEi? Effective depth: measured 10612 ' feet Junk (measured) true vertical 7574 ' * feet Casing Length Size Cemented Structural Conductor 80' 13-3/8" TO SURFACE Surface 6192' 9-5/8" 519 BBL CLASS E Intermediate 83 BBL CLASS G Production 10662' 7" 84 BBL CLASS G Liner Perforation depth: measured N/A MAY 1 ]. 1990 ,/~,iaska 0il & Gas Cons° Commissior~ Measured dep~flch0raff8 True vertical depth 115' 115' 6227' 4667' 10697' 7646' true vertical Tubing (size, grade, and measured depth) NOTE: TVD'S ARE BASED ON MWD DIRECTIONAL DATA, NOT FROM GYRO Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X__ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation AUGUST 1, 1990 16. If proposal was verbally approved Oil __ Name of approver Date approved Service ',z. 17. I hereby certify that the foregoing is true aff(J gG~'rect to the best of my knowledge. Signed 15. Status of well classification as: Gas ~ Title SENIOR DRILLING FOREMAN FOR COMMISSION USE ONLY Suspended Conditions of approval: Notify Commission so representative may witness Da~AY 9, 1990 d, I Approva, No. ¢O Plug integrity __ BOP Test __ Location clearance m Mechanical Integrity Test __ Subsequent form required 10- Z'fo z¢ Approved by order of the Commission Form 10-403 Rev 06/15/88 Approved Copy Returned ORIGINAL SIGNED BY L~ ~:r~ i ~Csi oSnlVle ? Date SUBMIT IN TRIPLICATE Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 5, 1990 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 301 Porcupine Drive Anchorage, AK 99501 Re: Letter of Application Dear Mr. Minder: I am requesting shutdown of well operations for the L-4 well until we can compact the new pad enough to get a workover rig on location and begin completion operations. This will happen later in the summer. Included is the Form 10-403 and a Form 10-404 with a copy of the Daily Reports of Well Operations will follow the approval of the 403. The cement plug was bumped, casing pressure tested, tree flanged up and tested, and the well was shutin. Sincerely, D. L. Mount joy Sr. Drilling Foreman SCHLUMBERGER ~ELL ~ERVICES A DIVISIO~I OF ~::HI. UMBERGE~R TE:CHNOLOGY CORFI~ATION HOUSTON. TE:XAS '/7251 -;2175 MAY 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Affention: M~rc Shannon Gentlemen: GCT, RunR~l'n5 /' 01/ 90 Enclosed ore 2 R1. prints of the CET, CBT, 1. 5/01/90 Company CONOC0, Inc, Well Mi 1 nm Field Hilne, l~oint Additionol prints ore beir~ sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER on: County Nnrth $!ope State Alaska _l__BL_prints, 1RF Sepia CONOCO. Tnc: 1000 Sou~h Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *{915/685-5600) _lJIL_prints, I RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon~ CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1 BL nrints,~;.~'l'~RF'~"S&~!~ Alasl~a' "0~'1 ~&--GaS .~.¥/?' C o~i s s i on '~. ..~.~// 3001 Porcupine Drive ~chorage, ~ 99501 . ~ ......... ~ film is returned ~o Conoco, ~og Library. We appreciate the privilege of serving you. prints prints prints MAY - Date: A~;~ 0ii & ~a8 ~0n$. C0~~ Ve~ trul~ yours, SCHLUMBERGER WELL SERVICES SwS-- 1327-F David M. Saalwaechter DISTRICT MANAGER SCHLUMBERGER WELL IERVICES A DIVISION OF' ~.,CHLUHBE:RGE:R TE:CHNOLOGY COI~PORATION ItC)US, TON. TE:XAS, '77251-21 '75 APR 2 5 lggo CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 A~ention:, Marc Shannon ICHLUMBE~GE~WELL ~1~$ Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore--tints of the Company CONOCO, Inc. Cyberlook, Run 1, 4/6/90 (Corrected Copy) Well Milne Point Unit L-4 Field. Milne Point Additionolprintsorebeingsentto: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 201~ PER County North Slope State Alaska ~rints, 1 RF Sepia CONOC0, Inc. 1000 South Pine Ponca City; OK 74603 Attn: Log l.~brary 1BL prints , 1RF Sepia OXY U.S.A., Inc. :6 Desta Drive Midland, TX 79710 Attn: John Carrol ,.? (915/68575600) 1BL prints , 1RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy 3001 Porcupine Drive Anchorage, AK 99501 Attn: John Boyle ..~ ..~ The film is ,returned to Conoco, Log Library. We appreciate the privilege of serving you. -0- prints 1AField ~11~ Chnvrnn lJ: $ _.~oa._~~~ .... Sa~ _~_amo_~l~.__JaR~ 94583-0943 ATTW~ ~ qvnn~ _ prints prints Date: ~'auim .Oii& Gas ConS; .... ,,~ ~cn0rage Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SWcu--1327~ CONOCO, Inc. SCHLUMBERGER WELL SERVICES A DIVISION C)F $CHLUHB£RGrR TECHNOLOGY CORI~ATION HOLISTON. TEXAS 77251-2175 ~ I~l'l.'~ TO ICHLUMBEROER WELL IERVlCES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley 3201 "C" Street, Suite 200 ..Anchorage, AK . 99503 Attention: Marc Shannon , Gentlemen: Enclosed ore 2 BLprintsofthe . Company CONOCO, Inc, Well , Milne Point Unit L-4 Field Milne Point Additionolprintsorebeingsent ~: 1 BL prints CONOCO, .Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: Geor;e Lamb - OF 2018 PER DIT, CNL (RAW), CNL (PORO), NGT (5" & 2"), Cyberlook, Run 1. 4/06/90 County North Slope State Alaska 1BL prints, 1RF Sepia CONOCO. Inc. 1000 South Pine Ponca City, OK 74603 Attn: Lo~ Lihrmrv 1BL prints , 1RF Sepia ..OXY U.S.A., Inc. 6 Desta Drive Midland,.TX 79710 Attn: John Carrol * (915/685-560o) 1BL prints , 1RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLero¥ * (415/842-1000) 1 BL nrints~','-':~l-:'-RF~'Se'p-i~ '-~ ....... ~ Alaskh::':~0il & Gas Conservat~"b'm~ /COmmission /3001 Porcupine Drive Anchorage, AK 99501 Attn: John Boyle ............ ~he...-fiim is. returned to Conoco, Log Library. We appreciate the privilege of serving you. -0- prints 1 Field Tape C. hovrnn lJ: S=A_ San Ramon, CA 9~.583-09/: 3 .ATTN _'- Norm Ston~ * (4~5/84a-1000) prints prints APR 12 1990 Very truly yours, ~qaska Oi~ & Gas Con~ Coimtmlsslil. l~ SCHLUMBERGER WELL SEI~'~ David M. Saalwaechter DISTRICT MANAGER SWS-- 13274= Ar;- __ _B- 8)-. <~ o ~n~rol I ~ per Kelly } ?e&~ pressure N~,~ velvee ._ = __ ~ O. _. . : STATE OF ALASKA AL~KA OIL AND GAS CON$;RVATION COI~ISSION ELOPE I nsp~ctt on Report, DATE BOPE STACK= Annular preventer PIpe rams glfnd rams Choke line valves HCE v&lve KIll llne valve& Check valve Test Pressure ACCUNULATOR SYST~Sq': Full charge pressure Preaa eft, er oloaure Pump I nor alas press 200'.pstg Full charge preaa attained N2. Control ~; Hasher .. m{n Pe{g .... 01 t nd s~vtt.¢h Gover .... KELLY AND FLOOR SAFETY VALVES: pressure Upper Kelly pressure Lower Kelly Ball type ln~ida BOP Choke man1 fold Test pressure Number Test pressure Test pressure Number fl anges ft Adjustable shakes=_ ....... Hydraulically operated ~hoke ps~g --;-=: pstg TEST RESULTS Failures . ?/_/~-~ Test time hr~ Repe(r or replacemene Of fe(l~ equl~nb :o ~ ~de wtbhln end I n~ Pector/C~t ~ m ( on off I ~e not1 f ( ed. days DI stribut(on.. or( g -' AOGCC I nspect0r: Operator Superv(sor C.00~ (rev 03/17189) March 7, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Fore~n Conoco Inc Pouch 340045 P~dhoe Bay, AK 99734 Re: Milne Pt Unit L-4 Conoco Inc Permit # 90-38 Surf Loc 369'FWL, 2087'FNL, Sec 8, T13N, R10E, UM Btm~hole Loc 2249'FEL, 1075'FNL, Sec 6, T13N, R10E, UM Dear Mr Rainwater: Enclosed is the approved application for permit to drill the above referenced well. The pe~it to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter 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. Ve~ truly~urs, "~ .... ',. i'9 ~: ?'/~'7'.-~-" ~% C V Chat-~rton" Chai~an Alaska Oil and Gas Conservation Commission BY O~DEK OF THE COF~ISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of EnviroD~nental Conservation - w/o encl David L Bowler Division Manager Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 March 1, 1990 Mr. C. V. Chatterton Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Chatterton: Attached please find Applications for Permits to Drill Milne Point Unit Wells L-4, L- 5, and L-7. A check for $300 is also enclosed. If you should have any questions, please call Bob Soptei at 564-7617. Yours very truly, Division Manager RJS/cl Attachments cc Supervising Production Specialist, MPOC (cover only) Well File RECEIVED MAR - 5 1990 Alaska.0il & (las Cons. C0mm!ssitlll gndi0rage STATE OF ALASKA ALASKA' 'L AND GAS CONSERVATION C ..... iMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work Drill ~ Redrili" lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry ~ Deepen Service 1~ Developement Gas [] Single Zone [] Multiple Zone ~ '"2. Name of operat0i '' 5. Datum Elevation (DF or KB) 10. Field and Pool -- Conoco Inc. 56' MSL feet Kuparuk River Field 3. Address 6. Property Designation Pouch 340045, Prudhoe Bay, AK 99734 ADL 25509 ' , 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 20AAC 25.025 369'FWL,2087'FNL,Sec 8,T13N,R10E, UM Milne Point Unit Blanket At top of productive interval 8. Well' nurpber Number 2400'FEL,1400'FNL,Sec 6,T13N,R10E,UM L-4 8086-15-54 At total depth 9. Approximate spud date Amount 2249'FEL,1075'FNL,Sec 6,T13N,R10E, UM March 14, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well "14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1075 feet 60' @ Surface feet 2533 ac 10,477 MD,7375*TV~eet ,, 16. To be completed for deviated wells 171 Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff ........ depth 500 feet Maximum hole angle 51 o Maximum surface 3200 psig At total depth (TVD) 3800 psig 18. Casing program Setti'ng Depth - _ . size Specifications Top Bottom Quantity of cement Hole Casing weight l Grade Coupling Le~'gth MD TVD 'MD TVD (ir~clude stage dat',~) -- __ 30 13-3/8" 4.8#/Ft H-40 Welded 80! 35' 35' 115' 115' 485sks Permafrost C -- 12-1/4" 9-5/8" 36#/Ft J-55 B"L'RS 6196' 35' 35' 6231' 4659' 1st Stage:766sks Perma' iC~ao~ Type E and 425sks Class G, Second Stage: sks Permafrost E and 84sks Class G 8'1/2" 7" 26#/Ft L-80 BTRS t104j2', 35' 35' 10477' 7375' First Sta~e:322sks Cla..,. 19. To be completed'for Redrill, Re-entry, and Deepen Operations. G, Second Stage: Down Squeeze 180sks Present well condition summary Permafrost Type C & 60 bbls Dead Oil. Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured · feet Junk (measured) true vertical feet 'Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ISn~ reframC;d i ate RECEIVED Production LinerMAR - 5 1990 Perforation depth: measuredAlaska 0il & Gas Cons. Comm%ssl¢ true vertical Pit Sketch X Anchorage 20. Attachments Filing fee E:' Pr:0perty plat ~ BOP Sketch ,~' Diverter Sketch [] Diilling program ~Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [~ 20 AAC 25.050 requirements 21' I hereby/c~rti,~ that 7t~h~ foreg~.-~gJs~ue and correct to the best of my knowledge Signed ,//~'/~ j~'. ///~-/,,',- ~> Title Senior Production Foreman D ate .2,/~?/,~? commission'Use Only " - -Permit Number ' I '~,PI number " ' I Approval d'ate " I see cOver letter ' __ ¢O-~V~ , I 50-o.z~'-2.~o~_~p I 03/07/90 J for other requirements Conditions of approval Samples requ. ired [] Yes ~. No Mud Icg requi~d-- E] Yes _~No MIT r'equir'ed Hydrogen sulfide measures E] Yes ~No Directional survey required ~Yes Required working,,,la~ure f~ BOP.,,~;-~2,f~; [],,¢3~ ~ 5M; [] 10M; [] 15M E~ No Ca'l 1 for' r'ep Other: ~/' /.,~/ //~-' t.O W'fl;rless. by order of ~/,/ L--~.Appr°ved~ -;,-, ,,,-,~bY ,-,~.~ ~,, ~ o~~ '"'//. [.~ ~"//'//',¢~.//~~~ CCommissioner the commission Date"a/ t 564 10-401 Rev. 12-1-85 Submit id triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-4 Conoco Inc. P.O. Box 340045 Prudhoe Bay, AK 99734 I · Casing and Cementing Program Ae Be The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +480 sacks Permafrost type "C". Ce The 9-5/8" surface casing will be cemented in 2 stages with the first stage using +766 sacks of Permafrost "E" cement followed by +425 sacks of Class "G" cement. A DV tool will be placed at +1883~ MD. The second stage will contain +564 sacks of Permafrost "E" cement followed by +84 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of +322 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of +180 sacks of Permafrost type "C" cement followed by +60 barrels of Dead Crude and/or Diesel pumped down the 7" x 9-5/8" annulus. II. Drill ing Fluid Program A. 0-500' 9.0 ppg freshwater spud mud. Be Ce De 500'-6230' 9.0 ppg-9.8 ppg freshwater spud mud. 6230'-9200' 9.8 ppg-lO.2 ppg dispersed. 9200'-TD 10.2 ppg-lO.4 ppg dispersed. III. Drilling Program RECEIVED MAF~ - 5 ]9,90 Alaska Oil & Gas Cons. CommiSSiOD Anchorage Conoco Inc. proposes drilling the subject well as a injection well in the Kuparuk River Field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.2 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. Maximumdownhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbores are L-6 and L-4 with 60' of closure at surface. Dead Crude and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. Ac Drill a 30" conductor hole to +80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to +4650' TVD (6231' MD) and set 9- 5/8" cas ing. Ce Drill an 8-1/2" production hole to _+7375' TVD (10,477' MD)and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' O' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3647' 4610' "K" Sands 1-1-4 9.2 25 15 65 14 3736' 4748' "M" Sands 1-1-4 9.4 25 15 65 13 3992' 5146' "N" Sands 1-1-4 9.4 25 15 65 12 4164' 5413' "0" Sands 1-1-4 9.4 25 15 65 12 6629' 9248' Sea Bee 1-1-4 10.2 8 12 40 10 6851' 9594' Kup Top 1-1-6 10.2 8 12 35 5 7075' 9943' L K (1) 1-1-6 10.2 8 12 35 5 7094' 9972' L K (2) 1-1-6 10.2 8 12 35 5 7275' 10254' B L K 1-1-6 10.4 6 12 35 5 7375' 10410' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. RECEIVED MAR - 5 1990 Alaska Oil & Gas Cons. Go Anchorage CONOCO, Inc. Pad L, Well No' 4 Revl~-~,d Propossi HI I ne Po I nt Un l t, ,Nor{[ I ope, Al eska 0 _ RICB ELEVATION' 28' 10o0_ 2000 _ 3000 _ 4000 _ 5000 _ 6O00 _ 7000 _ 8000 _ 0 KOP $ I0 15 BUILD 2.5 DEO 20 PER 100 FT 25 3O 35 4O 4550 EOB TVD=500 TMD=500 DEP=O TVD=2258 TMD=2503 DEP=821 9 5/8" ceo PT TVD=4650 TMD=623! OEP=3680 AVERAGE ANGLE 50 DEG 5 M[N RECEIVED MAR - 5 !990 Oil & Gas Cons. C0mmiSSi~: Anchorage TARGET / LK-1 TVD=7075 TMD--IO010 DER=6578 TD / 7" LINER TVD=7375 THD=10477 DEP=6937 J I I I I I 1 000 2000 :3000 4000 5000 6000 VERTICAL SECTION i 7000 HOR~ ZONTAL PROJ£CT ~ON ;ALE 1 IN. = !000 FEET CONOCO, I,e. Pea L. Well N°, 4 Revleea Propoeel MIIne Poln~ Unl~, North Slope. Aleeke z o TO00 60OO 5000 _ 4000 _ 3000 _ 2000 _ 1000 _ ~ 1000 _ WEST-EAST 5000 4000 3000 2000 I I I 1000 I 0 1000 I I TD LOCATION, 107'5' FNL. 2551' FEL SEC. 6. T13N. RIOE TARGET / LK-1 TVD=?O?$ THD=IO010 DEP-6578 NORTH 5967 WEST 2769 TARGET LOCATION, 1400' FNL. 2400' FEL SEC. 6. T13N. RIOE RECEIVED MAR - ~ 1990 Alaska Oil & Gas Cons. Commissi~ Anchorage N 24 6578' DEG 54 MI N W (TO TARGET) 1' 13NR 9 E T 13 N R 10 E 1' 13 N R 11 E MILNE POIN' ~UNIT CH~¥RON (~) CONOCO ET Al. (~ CONO~ ET Al. (~) .... ~ Dlnoll. I,.ct numb.,. ~1 ~ CONOCOETAL ~ ~TotalAre. In Unit 35.744Acrll AOL~3!9717 1265,AC ~ ~L ~m~ con AL 0/84 ,, uu, ADL-47434 2560 AC ADL-47433 ~60 AC ~D~7432 68 j II I~ I~1 I I II IIII ~ .... CONOCO ET A~' CONOCO ET AL CH~RO,, CHEVRON ~ ~ ( ~ 15 21 - - 22 23 23 24 10 20 24 19 22 AO~-31SO4e ADL-25516 ~ L-47439 AOL-315846 1280 AC 1280 AC ADL-47437 2560 AC ADL-47438 2544~C 1280 AC I 1280 ~-25514 25.0 AC ~RoNADL 25518 2.4 AC~ '~~xON ~ ~ CHEVRON ARCO-EXXON~ 30 20 28 2T 26 25 30 ~O ! EXHIBIT A I + ~ ~1 3 03 34 ! B..ed on Umll 2560AC ADL"218231 ~555AC UNIT AREA Merldlln,Alalka I 2 Scale NOTES: I, STATE PI. ANE COORDINATES ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON 'N,A,D, 1927, OI:FSET8 TO S~CTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF TIlE ,SECTION CORNER POSTION& 6~O' PAD // - ~ RESERVE Pit ~ ~ MILNE POINT UNIT ~~~LGWYDYIt MILN~ PT, VICINITY MAP MILE6 L O CATION IN ,SEC, 8, T13N, R1OE, UMIAT MERIDIAN 'wELL l' I:"OM NORTH LINE I FROM WE8T LI~'-NI~' L-6 120,56' 1420' L-.? J2023' J470,~' STATE PLANE COORDINATES-ZONE 4 : WELL~i ..... Y" - j--:: ' X" ' L-4 6,O$~,383.1' j ~44,970.?' L-5 6,O31,41§,4' L-7 6,O31,447,6 J 54~,O71,9' GEODETIC PO,SlTION8 NAD 1927 WEL~ NOI?..TH LATITUDI~ 1J~49 WE3T LONGITUDE L-4 70' 29'47,782' ' 37'66,147' L--5 70' 29'48,096' J149' 37'~4.651" L-7 70* 29'48.410' J 149' 37'53,156' 1650 _ I 7OO _ 1750 _ 1800 _ 1850 _ 1900 1950 2000 2O5O 2100 2150 150 200 250 300 900 I , I 700 \ \ \ \ 500 \ \ \ \ \ 30O \ \ \ \ 2100 \ \ \ \ \ \ \ 350 400 450 500 I I I I 900 \ \ \ \ ~1700 \ \ \ 100 \ \ %\900 \ ~1500 \ \ \ ~1300 \ / '500 ~ 1 ~00 .~7'oo 500 , '~_~1'~00 I I I 55O RECEIVED AJaska Oil & Gas Cons. Comm~$$1Q~ Anchorage,,.1~oIf'/o~ 150 200 250 UO0 350 400 / 1700 / "'900 / / / .~' 700 '" 1500 500 450 500 55O 1650 _ 1700 _ 1750 _ 1800 _ 1 850 _ 1900 1950 _ 2OOO _ 2050 _ 2100 _ 2150 TIME ESTIMATE Hours ~ Cum. D a_D_y~ A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 100 4.17 4.50 C. Run Surface Casing and Cement 36 1.50 6.00 D. Drill Out and Test 8 0.33 6.33 E. Drill Production Hole 115 4.79 11.12 F. Log Open Hole 36 1.50 12.62 G. Condition, POOH, L.D. 20 0.83 13.45 H. Run Production Casing 16 0.67 14.13 I. Cement Production Casing 10 0.42 14.54 J. Run Cased Hole Logs & Perf 36 1.50 16.04 K. Run Completion EQ 12 0.50 16.54 L. Move Rig 0.33 16.88 TOTALS 441 16.88 16.88 RECEIVED Anchorage t-'0 !13 ~0 0 -1 -2 -3 -4 -5 -6 -7 -8 -9 -10 -11 MILNE POINT UNIT WELL L-4 Rate vs. Depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 RIG DAYS CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR - U FLOw LINI ltlLl, UP LIk~[ ~ ) ~.i - ........ OI ¥[ll l [ ItSAY [ R ' SUlQUICK A $ $ [ I,(*CY CONN CCT ASS[ l BLT RECEIV'ED - .. STARTII~O I*qCAD · ::.?.;.:.'.. '~'.'.. .': · :. °.-.~ . .'.. ~." '.' ['.~.'..'.~t.; *'~ " ir: AJaska Oil & Gas Co;~s. Anchorage. 1. The hydraulic control syste~ will be in accordance wi'th APl specifications and AOGCC requirements. 2. The HCR valve will open when the preventer c]oses. A singl~ , 10" relief line will run off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening and linked together to enable one to always be open and the other to be closed. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FLOW LINE ANNULAR PREVENTER (1) 13 tltl'' APl 50004 RAM BOP 1~'¥~ · APl 5000 ~ (2) RkU BOP / ~ II,% ' APl 5000l S.~ (~ ~t ,- ~ - ..... z IlS/i' APl $000I SOO, Od. · 'Il' APl 5000 R.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors ali hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to .' AP, ~oooe include a mfntmut~ ~n of one set of RECEI~~'~' blind rams and two sets of a riate pi e ;lIT-:..~ ~AR = !990__ ~ppr°p p II. '. ~ ""- m~ t~.-[[ '..- . .' ,~chorage (5) Choke and kill manifolds 8ho~ ,,'-'tr." · · : separately to meet · . = · APl RP 53 class 5M H.." -.. ' l[~ ~ , requirements. II -.. KiLL MANIFOLD FROM REI~IOTE ~ISH RE.~OT PRESSURE PUMP ~1 ~ ~ NOTE' ' '~~ HYDRAULI~ CONTROLLED ' r FOR ~ ~ ~ ~ ~ REMOTE OPERATED 160 O~ RESE~IR ~ AUX. E~ERGY SOURCE. iS) STA ~NTROL JA~IF~ PLUS ~RIA8~ CHOKE ~T~L TO 8E ~C~TED OH RIG FLOOR. 5. KILL ~NIF~D SIZE- RATING ~'- 5~ X/ ~ CHOKE ~4NIFO~ SiZE - RATING 3"- 5~ , ~ HYDRAULIC- - CONTROLLED ' ' ~ R~OT/ OPIATED ADJU~AB~ ~ ~ ~ ADJU~AB~ ~tANIFOLD ~OKE ~ CHOKE ( c~ ~o~! .. SHAKER 1 ,o RECEIVED TO PiT ~UD/~AS SEPARATOR .. Al~ka Oil & Anchorage .... ...... , ............... , . ..... CHOKE 8 KILL ~A~IFOLDS FOR ~/8'~ ~ 7" OD CASING BOP STACK 1 BOP MA~IFOLD LAYOUT- CONOCO, INC. : ........ L , I, ~ I ,, ,, I ~ I , L .. · ~ : ~ ,. · I I IrRCM SAL AMANCERS TROUGH ' [ ' i MuD CLEANER w&TE.R ~ HOLE FILL TANK I VA FLI~a ' PU~,'~ i MuO ~,~ ~x CHLaGE CH,'~-qGE AGITATO.q GATE VALVE MUD GU~ Psv ~C710N ~CT~C~ CR D~SCH~G[ IT CHECK LIST FOR NEW WELL PERMITS Company ~,v/~ ~O Lease & Well IT~ ~PROVE DATE-- - ~ NO (1) .Fee ~ ~/~/~ 1. Is the ps,it fee attached ......................................... .- ~ ~,~ thru (3) Admin~ ~ 9. ~9-th~u 10. (10 and 13) 12. 13. (4) Cas~ ' ~.~. ~', ~-~ -~. (14 thru 22) (5) BOPE ~,~. ~"~ (23 thru 28) 2. Is well t~ be located in a defined pool ............................. 3. Is well located proper distance from property line .................. ~_ .... 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party .......... ' ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .......... ".~'~;" . ................. Is a conservation order needed ................. ~,~';. ................. Is administrative approval needed ............. ''~7 ................... Is the lease number appropriate ...................................... Does the well have a unique name and number ....... · .................. 16. 17. 18. 19. 20. 21. 22. 14. Is conductor string provided ........................................ 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/A_PI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER ~ (29 tnr6 (6) Add: Geology: DWJ~ Engi~, eering: LCS ~_~.~' BEW MTM ~z~ RAD ~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT j ON/OFF POOL CLASS STATUS AREA NO. SHORE o ~z ~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ,. No special 'effort has been made to chronologically organize this category of information. .o BOROUG~ : MORT}.{ SLOPE API NU~ER : 50-0~9-220~9 R~FERENCE NO : 9~6~9 L-4 I C 0 F ILr4 ED RECEIVED OCT 3 0 1992. Alaska 0ii & Gas Cons. Commission Anchorage .~!S Ta.~e Yeti. flotation l.,1. stl. nq ;ch.lumber(~er' 51aska ComputinO Center 29-0C~-I992 09:50 DaTE : 90/04/23 O~I~IN ~ FLIC CONTIM!..]AT!O~ # : P~EVIOU$ REEL : CO~ENT : CONOCO INC., MILNE POINT UNIT b-4, ~PI ~50-0~9-22029 **** TAPE MEABMR **** SERVTCE ~A~E : EDIT DAT~ I 90!04/23 T~P~ ~ : 737!)2 P~EVIOUS TAPE : CO~ES~T : cONocO I'MC,, ~I'LNE POINT:: UNIT L-4, ~PI .#50-029-22029 **** FILE HEADER **** SERvIcE : FLIC VER$IO~ : 00t~04 DaTE ~ g0/04/2~ ~X REC SIZE : 1.024 W?LE TYPE bAST FIbE ******************************************************************************* ******************************************************************************* ** ** ** ** ** SCHL!..I~BERGER WELL SERVICES ** ** ,~ ******************************************************************************* ******************************************************************************* CO,PAUlY ~iA}~E: CONOCO lb;C, WELL: ~I[,LE POI~)T UNIT L-4 WTELD: ~Ib{~E PO!~T AVl NU~E~: 50-029-22029 LmCaTTO.N: 2o~.7' W,.,I. & 369' RECEIVED 0CT 5 0 1992 Alaska 0ii & Gas Cons. Commission Anchorage bis Tane Verification Listing. Schlumberger AlasKa Computing Center 29-[~CT-1. 9~P 09:50 ELEVATIONS KB: 56 TD DRILLER: TD LOGGER: 06-~P~-1990 ONE 10580 10564 /~ Bfi:VE P~F~MANENT C,aSING: 9 5/8" {7 LB 0 DRILL~]R DEPTM OF 6~27 AND LOGGER DEPTH OF 6226 TYPE FLUID IN HOSE: LLND DISPERSED, DENSITY,' 10.4 VISCOSITY: 44 P},~..' !0 FL[IlO LOSS: 4.5 bUD RESISTIVITY: F?LTR~TE RESISTIVITY: ~UD CAKE ~ESIST!VITY: 1,93 ~ 77 2.!7 a 77 1,77 ¢ 77 T!~E CIRCUbATIDN ENDED: 07:00 6-APR TI~E LOGGER ON B(JTTO~ 14:55 6-APR MAXI~IJ~ TE~P PECORDE~: !61 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: D!bLt]N/MOI!NTJOY TOOL NUMBERS: DIS-~.{C-!39 DRS-C-4950 TCC-8-32¢) NSC-E-775 NGD-B-739 A~u-A-774 TOO[, STR!~G (B[1T-T[lP) : DIT~-LDT-CNT-NGT-TCC-AMS. FOUR 1,25" TEFLON :TnNDOFFS AND A 2' HOLE FIND~TR WEPE ItSED. SGR SPIKE ON NAIN PASS AT 10400' CAUSED gY 8TOPD!NG TOOL STR1NG O~ WAY TU ~OTTO~ AFTER FIRST PhSS. N~I.!~RON MATPTX - SANDSTONE HOLE CDR~ECTION : CALIPER. DENSITY UAT~I× = ?.65 G~/CC. ~EMS!.TY WAT~IX = ~.0 Gu/CC. NGT FILTERING = !,EAST SQUARES. BOWSPRING WAS ~DT USED ON CNL, DaTE JOB STARTRD: 23-AmP-Q0 ,lOB REFERENCE NO: 71792 LDP/ANA: KONR!NG PAGE: ****************************************************************************** * * FILE - MDIT.OO! * * C~N~CO ?NC, ~,~I$ T~e Ver~ication bistln~ ~chlum~er~er Alaska Co~putinq Center 29-0CT-1992 09:50 PAGC: MILES POIF!T UNIT b-4 50-02g-~2029 D~T~ SAMPLED EVERY -.5000 FEET TYPE USED DIT-E ,bTM LDT ,bDT CNT-A/D/H ,CNI~ ~GT ,NGT GR ,CSG PHASOR DU~L !NDUCTIO~{ SFh L, ITHO DENSITY CgFIPENSATED NEUTRON NATURAb GA~,~A SPECTROSCOPY 10556' TO 6226' 10389' TO 9988' 1051.0' TO 9988' !0498' TO 9988' 6220' TO 992' ****************************************************************************** TUN! VALU DEF! NC com~an~ ~ame W ~ILNE P(..INT Field .ame WN $!ILNE POINT UNIT b-~ Well Name raqaska01I&~sC°ns'G°mm|ssi°~ ~PI~ 50-02g-22o29 APl Serial Numbe, SFC? ~ Section TOwN 13N Township · R~NC lOE Range COuN NORTH SbOPE County STAT ALASKA State or Province NATI USA Nation WITN DILLON/~UUNTjOY Witness' Name SON 549154 Service Order Number PD~T MSL Permapemt datum ~DD FT I,~F PK~ boq Measured From APb PT' 56, EW~ FT 56, EDF FT 55, EG~, ~T B[-I FT 10556, Bottom LOg Interval T[,! FT 1000, Top Lo~ Interval TCS 07:00 ~-~p~ Time Circulation Stopped TLA~ 14:55 6-A~ Time Logger At LIS WaDe verificat!,on Listino Schlumberger AlasKa Comput. io~ Center 29-0CT-1,997 09:50 TABLE TYPE ~ CURV 8 F L U ibp IDO~ IIRD IIXD D P H ~l RHOB b~ SS~U Cb. bi HTEK~ RCF7 S~!, Resistivity (uDavera~ed) ~ediu~ Induction Standard Processed Resist, lvlt¥ Deed ~ndUct~om Standard Processed Spontaneous Potential IMDUCTIOM DEeP PHASOR RESISTIVITY INDUCTIOM ~EiDIU~ PHA$OR RESISTIVITY IndtlctioD Calibrated Preguency IOOF DEEP INDUCTION QUaLiTY IHOF ~ED INDUCTION O!JAI.,ITY FACTOR !NOUCTIDN DEEP PHASOR CONDUCTIVITY INDUCTIQ~ MEDIUM PHASOR CONDUCTIVITY Deed Induction Real Intermed{ate Conductivity Deed IndUCtiOn Ouad InterD~ediate CondUctivity ~i:ediu~n Indt{ction Real IDtermeOlate conductiv Spectroscopy Co~puted G~ ~rom Thorium. Uranium. Potassium Tension ~ud Temperatt~re Nun Reslstlvlty Head TensIOn DensltF Porosity Delta PHO Photoelectric Factor Oual!tY control of lo~](~ sDaCi.g ~or LOT oua!lty control on short Spacinq ~or I.~DT LOn~ SDaCl~ Co~outed Co~]nt ~ate (LL~LU/~) bona ~pDer ~-~ W~ndow Cogent Rate 5on~ Lower ~indow Count. R~te 51tnolo~ ~ndow Count Rate Short SDaci.~ ! w~ndow Count Rate Short Soac~n~ ~ Window Count ~ate LODq SPacing Ni~h Vo]ts~e Outunt Short Spacln~ Hiqh Voltage Loon OutF~ut Short SDacIno 1 Den$~tV LOn~ SDac~n~ PNOB (Uncorrected) bon~ UDDer Caliper SDectrosCODy ~am~a-Rav ~omDute~ GR from Thor~tlm. l~raD~um, Potass~.m Tensior~ ~ud Temperature ~!IU ~esistivitv Mead Tenslon ~eutro~ Porosity Thermal ~eutron Porosity Calibrated Thermal Neut~oD ~at~o ~eutron Porosity Output Fro.~ an ~pl!cation Program ~CmT PAGE: ~,~iS Tape refill, cation Llsti. ng ~cblum~erqer ,.~laska ComputinO Center 29-OCT-lq92 09:50 DEF~ CNq'C ~NTC C~TC CFTC ~R Spectroscooy C~R omP~]ted CAbl Caliper YTE~ )~ud Temmerature ~TEM ~ead Tension C~P ,..omptlted GR ir'om T:hortu~, Uranlt.!~, Potassiu~ T~40~ T~or ~ u~ POT~ PotasSium U ~ A N U r a n ftl ~ - WING %~Indow 1 (,150 W2NG Window 2 (.5 - 1,1 MEV] W~NC ~IndOw 3 (!.t.- 1,6 ~EV) w4N~ Window 4 (1.6 WSP~G WindOW 5 TENS TeDst. on NTE, MUd Temperature ~ES ~ i..l D Pesist ~,v~.ty CS Cable S~eed HT~7~ Head Tension SGR Spectroscopy Gamma-RMv TF~3S TeDsion ~ES ~4UD Res ist iv ],.t:V ~TE~ ~ud Temperature HTEN Head Tension ** DATA FOPMAT SPEC!FICATI(}N ~EC(~D ** 2 66 0 _~ 73 320 4 66 1 7 65 0 65 FT lJ. 66 3 ~3 66 0 [.,IS Tape verification [,isti. no ~chlumberoer AlasKa C. om[,,utinq C~nter 29-0CT-i992 09:50 PAGE: ** SET MAMF ~':DV lIMIT ID DEPT FT SFLU DTE ![,M DTE ILD DTF O'H~ ~ IDPH DT~3 !~F~ gTE !FRK DTF HZ ID~r gTE I~g~ DTE C I [')PDTF MMHO C?~D DTK SGR gTE GAPI CON DT~C GAP! TENS DTF LB ~TK~ DT~ DFGF HTfi;~' DTE BP DPHI LOT PU RH~ LDT G/C3 DDHO LDT G/C3 DKF LOT ~l,S LOT OSS I_,S [, I"~% CPS LH L, DT CPS L[~ LDT CPS LITH I,DT CPS SS1 bDT CPS 882 50I CPS bSHV LOT V SSHV LDT V S1Ru LbT G/C] BSRu LDT G/C3 LU~ LOT G/C3 SGR I,F)T (;APl C~D bDT GAPI TFNS bDT TYPM- CHAN ** SKDV!CE API API APl API FILE ORDER # LOG TYPE CLASS MUD ~UgB 540154 O0 000 O0 0 ! 549154 07 220 Ot 0 549154 07 !20 ~4 0 i 549154 07 120 46 0 54915.4 (:)7 01.0 549154 07 120 46 0 549154 07 120 44 0 549154 07 000 O0 0 5~9t5~ 07 000 00 0 549154 07 000 O0 0 549154 07 110 46 0 549154 07 110 44 0 540154 07 000 O0 0 549154 07 000 O0 0 549154 07 000 O0 0 ~49154 07 3i0 Ol 0 540154 07 310 O! 0 54915~ 07 635 21 0 549154 07 000 O0 0 940154 07 000 O0 0 549154 07 000 O0 0 1 549154, 07 890 O1 0 549154 07 350 02 0 1 540154 07 356 Ol 0 1 549~54 07 358 0~. 0 549154 07 354 O1 0 549154 07 354 Ol 0 1 54915~ 07 354 O1 0 1 540154 07 354 O1 0 1 549!5~ 07 354 549154 07 354 O1 0 549154 07 354 02 0 ! 549154 07 354 02 0 54915~ 07 354 O0 C 549154 07 35~ OO 0 1 54915a 07 350 02 0 1 549154 07 350 540154 07 350 02 0 1 540154 07 280 Ol 0 549154 07 310 O! 0 1 549154 07 310 O1 0 540154 07 635 2! ¢:) I ! i1 1 1 ! 1 ! 1 1 I 1 1 1 1 1 1 1 I 4 6~ 0000000000 ! 4 6~ 0000000000 1 4 68 0000000000 I 4 6R 0000000000 I 4 68 0000000000 ! 4 6~ 0000000000 I 4 68 0000000000 1 4 6~ 0000000000 1 4 6e 0000000000 1 4 68 0000000000 1 ~ 68 0000000000 ! 4 6~ 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 6~ 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 O00000000O ! 4 6R 0000000000 1 4 6~ 0000000000 ! 4 68 0000000000 ! 4 6~ 0000000000 ! 4 6~ 0000000000 ! 4 6~ 0000000000 1 4 6~ 0000000000 ! 4 69 0000000000 1 4 68 0000000000 l 4 68 0000000000 ! 4 6~ O00000000O I 4 6~ 0000000000 1 4 68 0000000000 ! 4 68 0000000000 1. 4 68 0000000000 I 4 68 0000000000 ! 4 68 0000000000 ! 4 6e 0000000000 1 4 6~ 0000000000 1 4 60 0000000000 !. 4 68 0000000000 1 4 68 0000000000 ! a 6~ 0000000000 bis Tame Verification Listing Sch!umberoer Alaska ComPuttDg Center 29-OCT-1992 09:50 ID ORDER HTEN LbT LB 549154 NPHI C~L p!t 549154 TNPH CNL PU 549154 T~ C~L 549154 ~C~T CNL CPS 540154 ReFT C~L CPS 549154 C~TC C~L CPS 549154 CFTC CUL CPS 549154 $~R C~b G~P! 549154 CGR C~L G~P! 549!5~ C~,LI CNL IN 540154 T~$ tnb LB 549154 M~ C~L 0~ 549154 ~TE~ CNL DEGF 549i5~ ~TE~, CML LB 549154 $~ NGT GAP! 549154 CG~ NGT GAPI 549154 TgO~ MGT PP~ 549154 POT~ MGT ~U 549154 U~AN NGT PP~ 549154 WIN~ NGT CPS 540~54 W~ MGT CPS 549154 W~G NGT CPS 549154 W~N~ NGT CPS 549154 WS~C NGT CPS 549154 T~MS ~GT LB 549154 ~R~$ NGT U~ 549154 CS NGT W/~ 54915~ E~T~N NGT LB 549154 SGR CSG G&PI 549154 TFNS C$~ LB 549~54 M~ES C$(~ O[,{q~ 549154 ~T~;U CSG DEGF 549154 HTEM CSG LB 549154 '"'"'""""'"'"'"'"','"",'"","'"'"o, ooo oo o ..68 "'"'""""o°Oo°ooo°o o7 coo oo o 1 i I 4 68 oooooooooo 07 000 O0 0 1 I I 4 68 0000000000 07 ~90 oo 0 i ! I 4 68 0000000000 o~ 89o oo o i ~ i 4 6~ oooooooooo 07 4~o o! o 1 i I 4 s~ oooooooooo o~ 89o oo o I t 1 4 6e oooooooooo 0~ 420 01. 0 ! 1 1 4 6e 0000000000 o7 420 o~ o t ~ i 4 6~ oooooooooo 07 420 o! o 1 I ! 4 6~ oooooooooo 07 420 O1 0 ! I 1 4 6a 0000000000 o? Ilo o! o ! 1 ~ 4 6~ oooooooooo o7 ~io ol o t 1 1 4 68 oooooooooo o~ ~8o ol o !.. i I 4 6~ oooooooooo o7 635 21 o i ~ t 4 sa oooooooooo 07 000 O0 0 1 I I 4 68 0000000000 07 000 00 0 I ! I 4 68 0000000000 07 000 O0 0 ~ I 1 4 6~ 0000000000 07 ]!o oi o ~ 1 ~. 4 6~ oooooooooo 07 31o ol o i 1 1 4 6~ oooooooooo o7 79o 5o o t ! I 4 6~ oooooooooo 07 719 50 0 1 1 1 4 68 0000000000 07 792 50 0 1 I I 4 68 0000000000 07 310 01 0 1 t ! 4 68 0000000000 07 31o o~ o 1 ! ! 4 6~ oooooooooo 07 310 Ol 0 1 1 I 4 68 0000000000 07 310 01 0 I 1 ! 4 68 0000000000 07 ]to el o 1 i ~ 4 6~ oooooooooo 07 635 21 0 I 1 1 4 68 O0000OO000 07 000 O0 0 1 1 I 4 68 0000000000 07 OOO O0 o 1 1 ! 4 68 0000000000 07 636 21 0 1 1 1 4 68 0000000000 07 000 00 0 ! 1 1 4 68 0000000000 07 310 Ol 0 1 1 I 4 68 0000000000 07 635 2~ 0 1 1 1 4 68 OOO0000000 07 000 O0 0 I 1 1 4 68 0000000000 07 000 O0 0 ! ! 1 4 68 0000000000 07 000 O0 0 I 1 1 4 68 0000000000 ** DATA ** DMpT. 1O624.500 SP.PTE -20.109 I. DQ~:,DTM 3.OEO IIRD.DTE 200.500 CGP,DTE !33,802 HTEN,UT~' 32752,000 PKF,LDT 4.563 LU,LD~ 1957,000 SFLU.DTE 2.234 ILH.DT~; 2.555 II.D,DTE TDPW. DT[~: 2.80! I~Pa. 9TE 2.559 IFRE.DTE I~OF. DTE 2.000 CI DP. {')T~ 356.750 CI"P.DTE IIXD, [:,TE 48.875 II.R~,!)TE 363.250 SGF.DTE TUBS. DTE 4020.000 MTE:',i. RTE 160,750 MRES.DTF D~HI. I,DT 61,11~ ~}{Oa. LDT 1,642 DRMO.LDT ......... ~oS.LDT -0.042 [,S.LOT L!,. !,f~T 554.500 I.,,I TI4. LBT 25~.875 SS~.LDT 2.766 20,000 300.500 125,621 0.733 0,017 1083,000 246,~50 [:.lis Tape VerifIcotfon L!stinq Schlumberger Alaska Co~pt~t.inq Center .KS2, LDT 433.500 !,S}{V. L[)T CCP.!,DT I~1.802 TE~S. LDT HT'E~4. LDT 32752,000 ~IDHI CP~L CFTC. C~:~L 930,60a SG~. CNL TE P.~.S. C*4L 4029,000 ~g~ Es. C~JI, SG~'. NGT 175.6~I CG~.~"~GT U~.~, [~GT -!,646 WING.NGT W4NG,~G, ~7,875 WS~G.NGT ~ES *.~G~ O, 733 CS,NGT TE~S,CSg '999,250 }~RES,CSG DEPT. I0600.000 SFLU,DTE SD,DT~ -20,297 IDPg. DTE IDi}~.DTE 3,000 ~40F, DTE I !'~D, DTE 299,500 . IX[), DTE CG~.DTE 66,875 TENi~. DTE ~TE%~ DTE 911,(}O0 DPBI,bDT · ....... . P~F', !.,DT 4,203 (~L5. I.DT h[t. LDT !057.000 L .LDT SS~,LDT 433.500 BSHV.I.,DT t..,S~. LDT I ,624 LU~H.LDT Ct'.,.., ~. LDT 66.875 T E N $,. b..,,., rr'" ~TF:[~. LDT 91!.000 NPHI.CNL ~POP. C~IL 30.659 RCNT.CNL CFTC. CN I, 930.60g SGP. CNL T~JNS,CNL 67a4,0Of) SGg, NGT 195,69'1 CGR. NGT U~A~. 5*GT 9.192 W1NG.NGT W4NG.~GT ~7,875 ~PE~. ~GT O. 733 CS. NGT TF~S, CSG -999. 250 ~4~ES. CS(; !i'~W..PT. 10500.00(} SP.DTE -15.945 IDqF. r')wE 0.000 IUOF !I~.DT~ 319.000 IIXD,DT~ CG~.DT~ 62.251 TENS. DT~j ~TE~. I.)TE 872.500 DDWI,LDT PEr. LDT 4. 579 OLS. LDT I.l;. LDT 1070. 000 LL. LDT SS?.bDT 428,000 LS~V.LDT bS9~ LDT 1,603 L~IRH. Ca~.I.DT 62,251 TF~S. LDT ~!'EN. [,D* 872.500 UP~I.C~L UPQ~.CNL 35.950 ~CNT,CNL C~TC.CNL 7 ~3. 557 T~NS.CNL 6340.000 SGP. NGT 129.212 !J~AN. ~G7.. .,. q.324 . w 1, NG. ~Jf4/~ _ , . 7'~uS. CSG -9o9. 250 29-0CT-!99~ 09150 1156.000 SSHV. LDT I. 639 CALl. BDT 4020,000 UTEri, bDT 36,246 T ~ P ~t, C N L ~661.167 RCFT ~ C~I[, 125.621 CGR,CNh 0,733 ~TE~I, CNb 133.802 THOR,[iGT 392'567 w2NG,NGT a oo ooo u -999' 250 ~ITE~,CSG ~.234 ILi.4. DTE ~.~01 I ~lPt:'l. DTE 2,000 CIDP. DTE 48.875 IIR~4.D..ET 6784,000 ~4TE~, DTE 61. I 18 ~HOB, LDT -0.039 OSS,LDT 1156.000 SSHV,bDT 1.639 CALl.bDT 67~4,000 ~TE~i, UQT 36,~46 TNP~, .... 26~I,~67 RCFT,CNL !25,62i C .... GR 392.567 W~NG.NGT 11.614 *' ~ NGT 2436.000 -999.250 UTE~,CSG 2.770 ILa. DTE 2.604 !MPH,DTE 0,000 C!DP.OTE 44.68~ IIRM.DT~ 6340 000 ~T~,DTm 62.954 RHOB,LDT -0.003 OSS,LDT 587.500 LIT!i. LDT !156.000 SSHV.LDT 1.632 CALl,LB? 6340.000 ~TES.LDT 42.876 THP~.CNL 24U2.2!4 RCFT.C~L 12g.~12 CGR.CNL 0.734 ~T~q.CNL 6~.251 TUOR,~G? 429,530 w2NG.NGT 6.711 T~S.~GT 1. al.!.0OO HIE~;.NGT -qq9.250 12t, 6,0 2.~ 160.7 3O !,33.8 !60.7 20,9 4020 0 -999,2 2 5 356.7 363.2 1.60.7 !.6 251 .~ 5 0 1212i$ 160 7 .'!0.6 909.~ 160 ! 0.6 2o0.9 6784.0 91~.0 -999.2 2.5 2.5 383.7 362.5 160.7 !.6 -0.0 251.1 1215.0 160.7 36.3 760.4 6~.2 160.7 8.2 197.~ 6340.0 872.5 -999.2 55 ILD,DTE 59 IF~E.DTE 50 50 50 ~RES.DTE 42 DRNO.LDT 42 LS 75 SStiLD? O0 SIPH 98 SGR..5DT 50 ~RES.t, DT 59 TN~A.CNL 44 29 W3NG.~GT 00 ~TE~.NGT O0 SGR CSG 50 ~TEN:CSG 61 ILD.DTE 5! IFRE DTE 50 CI~P]DTE 00 SGR.DTE 50 ~RES.DTE ~1 D~HO.LDT 43 bS.LDT 25 SS1,LDT 00 SIRN,LDT 98 SGR.LDT 50 ~RES.LDT 73 TNRa.CNL 58 CNTC,CNL 51 CALI.CNL 50 HTFN.CNL 37 POTA.NGT 87 w3NG.NGT O0 O0 50 HTE~oCSG PAGE: 1.562 125, 2,1 254~,567 898 3275~000 4 651 66:202 .!.60'750 999,250 '999'250 2.766 20,000 390.500 125'621 0,733 0.017 lo 3;ooo 246,250 12~256262! 0.733 2"768 2542'567 2 898 911:000 1.791 66,202 160,750 -999,250 -999,250 2.539 20.000 391.750 129,212 0,734 0.008 1123.000 24!.500 1.571 129.212 0,734 3.130 2273,093 2.898 872,500 2,078 63,758 160 750 - 9 225o -ggg,~50 LIS TaDe Verification I,ist.i~q Schlumber.Q.e~.r AlasKa Co~qtinq Center D!~TpT. 1.(1400,000 SFI,U.DTE SP.OT~ -~0.90~ CG~,DTE 75,235 TENS,DTE DEF, L[)T 4,570 aLS. bDT h U. h D T 935,500 !., L. L D T SS~,t. OT .4~6,500 LSMV bDT C~, [,DT 75, ~35 TE~S, bDT HTEN.[,DT 835,000 NP~I,CNL ~PO~. C~ [, 43.039 ~CNT C~L CFTC,CMl., 588,747 TFNS,CNb 6152,000 ~EES CML SG~,NGT 166,6~5 CGR U~A'~, MGT !~,677 W~NC,NGT 54,381 WSNG, ~GT M ~E,c., ~GT 0,761 CS, ~GT TFNS, CSG -999,250 DEPT, 10300,000 SF!:U,DTE Sm,PTE -33,43~ IDP~,DTE IDOF,DTK 0,000 ImOF,DTE IIRD,gTE !10,063 IIXO,DTE CGR,DTE 75,448 ~TE~,DTF !007,000 OPHI.LDT PE~', bDT 2,777 ObS. bDT I,D'~ 275,250 Lb I,DT 1.,~..1. Lf)T 2Q2 75n I.,SNV.LOT S8~. _ . ,.. ' l,S~. LDT 2 383 L!I~H. LDT -'CG~.LDT 75:a4.8 TEMS.LDT HTE~J, LDT 1007.o00 ~P~i.CNL ~2PO~. C~L 26,831 RCNT,CNL CFTc, CML 1147,7aO SGR, C~L TF~. C.NL 636~.000 ~RES,CNL SGP. MGT 82. 590 CG~, NGT W4NG.NGT 7,042 w5NG,MGT ~.~DE8. NGT 0.75J CS, NG'I TENS.CS~ -99q,250 DEPT. 10200,00(} SFLU. DT~7 SP. DTE -3.7. 656 IDPH. DIE I D~D'. DTE: 0,0fi0 IMOF. DT~ !IPg. DTE 1 l 3.063 IIXD.DTE CGP.DT~ 53.765 ~ENS.~TE HTE~. DTE 961,500 DP[,~ I. bDT PEW. bDT 2.46] O[,S. I,[.)T Lt~. LDT 284. 500 Lb. LDT S~. LDT 2ql. ~50 LSHV. LDT I.;S~. I,DT ~. ]67 I;tlP~. LDT CGP,Lr)T 53,765 TE~S.bDT HTMN. [.,DT 96l .500 29-0C'r-199~ 09:50 3.063 Ib~t, DTE 2.514 IMPH'DTE 0,000 57,031 .T I ~ ?'.--4:, O~E 615~,000 MTEM,DTE 56,871 RHOB' ~,DT -0,024 OSS,LDT 508' 750 LITH. LDT I160.000 6~52.000 5J.731. ~66~62s cG.~. C.~5 586,103 W2NG,~t~T t3.092 TENS,~GT 8,828 ILm,OTE 8.104 I~PH,DTE 0,000 CIDP,DTE 10 922 !IRV,DTE 636~O00 ~TE~,DTE 15.~57 RHOB,bDT -0.014 OSS,LDT 151.250 LIT~.LDT !161.000 SSHV,LDT 2.381 C~LI,DDT 6368,000 ~TE~.LDT 26,713 TNP~,CNL 316~,256 RCFT,CNb 82,590 CGR,C~L 0,75! ~TFM,CMb 75.448 THO~,MGT 263,581 W2~G.~GT 1~.066 TENS,NGT 1.839.000 HTE~,~GT -999.250 mTEM.CSG 13.063 _TL~.DTE ~.453 I~PH.DTE 0 000 CIDP,DTE 16:!25 II~': 6060.000 16.645 RHOB.bDT -0.025 OSS.LDT 154.750 blTa.bDT 1162.000 SSHV.bDT 2. 359 CALl 6060.000 26. 394 TNpH, C~L 2,568 2,566 397 500 160 ! 7i2 -0 032 220 125 1916 000 160.250 41.909 575 162 !60,250 !1.289 282 981 6152:ooo 835.000 -999.250 S.055 ~ 500 117250 160i625 2 398 0,021 88 188 1216:000 8,805 !60.625 27.005 1114.412 75,448 160,625 I1 6368.000 1007.0o0 -999.750 8,820 9.242 118.188 107.1.88 t59.875 2.375 0.017 90.500 !216.000 8,859 159 875 26:702 ILD,DTE IFRE,DTE CIMP,DTE MRES,DTE DRHO'LDT bM,bDT SS!,LDT SIRH LDT MRES,LDT T~RA,CNL CMTC,CNL CALI,CML ~{TEN CNL PO~A.:NGT W3NG,NGT ~TEM,NGT SGR,CSG HTEN,CSG 'TLD DTE IFRE:DTE CXMP,DTE SGR DTE ~'RESiDTE DRHO bDT L$,LDT SS1.LDT SIRE,bDT SGR bDT TNRA,CML CMTC.CNb C~LI,CNL HTEM,CNL POTA.MGT W3NG.MGT UTEM.NGT SGR.CSG ETEN.CSg ILD.DTE [FRE.DTE CIMP.DTE SGR.DTE ~ES.DTE D~HO.LDT LS,LDT SS1.LDT S1RH.LDT SGR,LDT ~mES.LDT T~IR~.CNL PAGE: 2 4 20 0 389 2 166 6 0,7 0,0 976,5 248,6 1.5 166.6 0 7 ~5 0 ! 0 1 7 160.2 -999,2 -999,2 96 oo 50 25 61. 30 00 25 95 ~5 1 78 oO SO SO 5O 8,0!.6 20.000 11.7,500 82.590 0.751 0,O15 289,000 208.6~5 2,324 82,590 0,751 2,545 2938,835 8.805 1007.000 2.048 42,254 160.625 -999,250 -999,250 0 20, 108. 69. O, 297. 205, 2, 69, 0, 2. 148 000 125 615 767 O08 000 75O 336 615 767 528 LIS Tame Verifl, cati. on $chl, u~bero~er AlaskTa Com.~outimO Center' N P[)~?, CML 27,761 RC !'~ T, C~i!, CFTC, Ca:L 1214,894 SG~, C~>L T~'N $, Ci-J[, 6060,000 SGR, NGT 69,615 CGR, {J~AM, MbT 2,461 W4:,~C.~ ~,~T ,035 WbNG,NGT T~S: CSG 999' ? 67 CS. ~T DMPT, $~.DTE IDOF.DTE I!RD,DTE CGR,DTE MTEN,DTE PEW,LDT LU,LDT SS~,LDT CG~.LOT ~.C~L CFTC,C~L SGR,~GT w4NC.NGT 10!00, ~0~ 90. 906, 244, 277, 2, 906, 5844. 13!, 5, -9~9. 000 SFLU.DTE 439 IDPH,DTE 000 I~QF.DTE 750 II×D,DTE 016 TENS, DTE 000 DP~i' !bDT 0~8 aLS, I, DT 000 LL,LDT 000 LSHV.LDT 473 LURH,LDT 0~6 TENS, bDT 000 NP~I,CNb 770 RCMT,CNL 809 000 ~ES'CML 087 CGR,~GT 040 250 MRE$.CSG IINO.DTM HTEW,DTF PE~.LDT LI!,LDT LSR~.LDT CGm.LDT ~PO~.C~L CWT~,C~L TM~S.C~L KGb. MbT Uu~W.~GT TFqS.CSC 10000, '38. 202, 101. 3, 227. 290. 98~. 33. 7rig. 6060. 1~5. ]. O. -909. 000 SFLU,DTE 563 IOPH.DTE 250 IIXD.DTE 36g TENS,DT~] OOC DP~I,LDT 1.39 OLS.LDT 500 LL,LDT 250 I,$~V.L~T 492 I,URH.LDT 369 TM~S,LDT 000 !8~ RCNT.CNL 69~ SGR.C~}L 000 HRES.CaL 754 CGR,~GT gOO W!NG,~GT 841 790 CS.~GT 250 ~REa. CSG DEPT, SP.DTE IDQF.DTE 9.900 0o 51 3 . 000 S F L U. D T 03i 500 2g-OCT-lg9P 09:50 3073,767 RCFT,C~IL 69,61,5 CGR,CNL 0,767 53.765 THOR ~22.111 ~2~G''~ ~0i050 TE~$.~!GT 825 000 HTEN'MGT }o9 25o 2.~28 !LM:,OTE 2.7!,5 IMPb~,DTE 0.000 CIDP,DTE 54'750 II~.DTE 5844.000 MTE~,DT.E 10,033 RHOB,LDT -0,045 OSS,LDT 125,625 LIT~.[,DT I!62,O00 $SNV.LDT 2,459 CALl.bDT 5844,000 ~TEa,LDT 31,965 TMPM,CML 2488,314 RCFT,CNb 131,087 CGR,CML 0,785 ~TF~.C~B 90,01.6 THOR,NGT 456.28~, W2NG.WGT 10.050 TEMS,NGT 1844 000 ).iTE~I,MGT -999~250 ~TE~,CSG 2.B52 II~,OTE 2.873 I~PH.DTE 0.000 CIDP.DTE 50,656 !IR~,DTE b060.000 HTE~.DTE 5.631 RHOB.LDT 0,003 OSS.BDT !23,375 LITN.bDT 1.162.000 SSMV,GDT 2.504 CALl.bDT 6060,000 ~TEM,[~DT 32 375 TNPH.CML 2370[999 RCFT.CNL ~25.754 CGR.CML 0.790 MTE~.CNL 10~,369 THOR,~GT ~33.800 W~MG.~GT 17.223 TF~$.WGT 1R41,,O00 HTEi,!.h!GT -999.250 1.839 ILU.DTE 1,514 !~P~.DTE 0.000 CIDP.DTE 113,375 ?!~a.UTE !163.76 !59 7 0 9 1, o5; 2 96!. 50 999 25 2:75 368.00 337.75 158.00 2 48 ~7 12i~ O0 9188 !5~ O0 33 ~g 768 68 90o01 158.00 I0.40 !91.96 58~4.00 906.00 -99g,~5 ~.90 2 87 347:75 320,25 J56.25 52.78 1217,00 9.85 !56o25 ~4o88 692.74 156,25 15,70 175,.45 ~060.00 981.00 -999.25 1.57 1.62 660.00 580.00 CMTC,CML CALI.CNL H '~"; CNL .TE~, POTA,NGT ~3~G,NGT ~TE~ sca:cst I[,D DTE CIMP.DTE SGR.DTE MRES,DTE DRHO,LDT LS.LDT SS1.LDT SIRH.LDT SGR.LDT ~RES'LDT ~NRA,C~I., CNTC.C~b Ca5I.CNL HTEN.C~L POTA,NGT ~3~,MGT ~TE~,NGT SGR,CSG ~TEN,CSG ILD,DTE .IFRE,DTE CI~P,DTE 5GR.DTE MRES,DTE O~O,LDT L$,LDT SS~,b~T SI~H.LDT SGR.LDT MRES.LDT T~RA,CNL CNTC.CNL C~L~.C~L HTEb.CML POTA.NGT W3NG.NGT ~TE~,NGT SGg.CSG HTEN.CSG ILD,DTE IFRE.DTF CI~P,DTE SGR.DTE PAGE{ 3025, 961. 35. 1,59. '999. '999. 2 2oi 361. 131. O. O. 247 2. 131, & 2. 2434. 9. 906. 3. 74. 1,58, '999, '999. 0 20. 347. 125. O. O. 237. 214. 2. 125. O. 3. 2173. 9. 981, 2. 72, 156, -999. -999, i , 20. 615. 125, I0 738 859 5OO 176 875 2:50 25O .7001 O0 750 O87 785 625 375 426 O87 785 984 958 8.8.,..'3 000 372 372 000 25O 25O 846 000 000 754 790 064 125 25O 346 754 790 OO9 230 859 000 825 121 25O 250 ~50 5O4 000 000 $4O L!~ Taoe Vetlfication Listing Schlumberger A.las~a Co~put~a~ Center L!!.LDT -9~9 250 Lb,bDT SS2'bDT -999 ~ 250 LSHV,LDT L~,LOT -999,250: L[jlR~ LDT ~ T E ~,!. b P T - 99 O. 25-o i~.;i P ~ I. C~ L NPOa,C~iL -999'~50 aC~T,C~L CFTC,CNL -999,250 SGR,C~L T~MS,CS!L -999,250 i~RES,CNL SG~,NCT -999,~50 CGR'NGT U~AN,NGT -999.250 W1NG.NGT W4[~G.NGT -999.250 W5MG.NGT MRES.~GT -999.250 C$,NGT T~NS,CSG -909,250 MRES.CSG DEPT. 9800.000 SFLU [)TE SP. D~.~E -37.031 IDPHiDTW I~RD,DTE 458,750 I!XD,DTE CG~. PT~ .. ~.~ 93,14! TENS,. DTE HTE~, ~TM 978,000 DP~I,LDT PMF, LD~ -999, ~5() ObS, bDT bU, bDT -999,250 bb, bDT SS~, [,DT -999,25() LSR~ bDT -999,250 LURH bDT HTE~', bDT -999,250 NP~ [,CNI, ~POP,CNL -999,250 ~CNT,CML CFTC, CNL -999,250 SGR, CMb TENS. C ~.~ !..., --~09,250 ~4 RES, CNL SGP, NGT -999,250 CGR, NGT [J~AN,MGT -999,~5Q W!.NG,NGT W4N~,NGT -999,250 WSNG,NGT ~PFS, NGT -909,250 CS. NGT TE~S.CSG -999,~50 ~RFS,CSG DEPT. 9700.000 SFLU. DT[~ SP. DTF: -~,6.1. ~8 lfr)p~{. DTE IDqF. PTE O. 000 !i'40F. DTE IIP~.[)T~ 35],~50 IIXD.DTE CGP.DTE 140,543 TM.NS. DTE ~ITS;N. D T ~.~' 9ia I. OOn DPHI, bDT PF.?. bDT -gqq. 250 ObS. bDT LU. bDT -999,250 Lb. bDT SS~.LDT -qqq.25fi bS[~ V. I.,DT LSR~, LL~T -9q9.~50 !.,U~ H. I, DT HTE~}.LDT -9~9.250 'iPHl. C~.~L NmU~.CNI 999,250 ~CNT.CML CFTC. CML -999 TFLS.CNI. -9q9.250 u!.!~S. CNL SGP. NGT -999. 250 CGR. kGT UPA~. WGT -999.25~ W1NG.~GT 29-0CT-1992 00:50 -999 250 -9'99[~50 '99 -999,250 TNPH CNL -999.250 CG~, -999.~50 MTE~.CN'L -999.250 THOR'MGT -999.250 W2NG.MGT -999 250 TEM$.NGT -999'250 ~TE~,~ MGT · . . -999.250 1.910 ILM.DTE 1,709 IMP~,DTE 0 000 CIDP.DTE !02~3!3 IiR~.DTE 6164.000 '~TE~,DTE -999.250 RHo3,LDT - 9925o -9991250 [,I H.LDT -999,250 SSBv,LDT -999,250 CALI,LDT -990,250 MTE~,LDq' -~99,250 -999,250 RCFT,CML -999.~50 CGR,CNL -999 ~50 MTE~,CMb -999[250 THOR,NGT -999.250 -999.~50 TENS.NGT -999.250 HTEN.NGT -999.250 ~TE~.CSG 2,344 ILM,OTE 2.314 IHPW.DTE O,OOO CIDP,DTF 64.439 IIR~.DTE 611~,000 MTE~.DTE '999.250 ~OB.LDT -099.250 OSS.LDT '999.250 LIT~,LDT '999,~50 SS~V.LDT '999.250 CALI,LDT '999.~50 THP~.CNI,, -~99.~50 RCFT.CNL -999.~50 CGk. C~L '°°°.2~0 ~TE~,' CNL "*" - ~ : · -999.~50 -990.750 154:875 -999 250 -999 250 -999 250 -999 250 -999 250 -999 29 . so 999.~50 -999 250 . -999.250 '999,250 '999,~50 '999.250 '99925O -999[750 1 747 584,5o0 525.000 153.000 -999.250 -999.250 -999;250 -990250 -999,250 -999,250 -999 ~50 '999i250 -999 250 -999 ~50 -099.~50 -999,250 -999,~50 -999,250 2,297 2.309 431.750 402,750 1.52,375 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999 250 -999~250 ~RES.DTE DRMO.LDT LS,LDT SSi bDT SGR.LDT MRE$.LDT TN~A.CML C~TC,CNL CALI.CNL HTEN.CML POT~..NGT W3NG,NGT MTEN.CSG !LDDTE IFRE:.DTE CI~P.DTE SG~.DT~ DR~O:LDT LS.LDT $$I.LDT S1RH.LDT SGR.bDT ~RES.LDT TNRA.CNL C~TC,CNL CALI,CNL ~TEN.C~L POTA,NGT W3NG,NGT ~TEM,NGT SGR,CSG HTEN,CSG ILD,DTE IFmE,DTE CI~P,DTE SGR,DTE ~ES,DTE DRMO,LDT bS,LDT SSI,bDT SIRH,LDT SG~,LDT MRE$.LDT TNgA.CNL C~TC.C~L CALI,CNL HT~2N,CML POTA,NGT W3NG,NGT PAGE: 0,798 999,2.50 :999,250 -999,250 -999,250 -Q99 250 -6~9'250 , -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 999~50 -999 250 , 575,500 126,961 0.811 -999:250 -909i250 -999 250 999.~250 -999,250 -999,250 .99 250 99 250 -999,250 -999.250 -999,250 99:250 2.301 20.000 433.000 136,706 0,876 '999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,~50 LIS Taoe Ve?~fieat~on Listing Schlumberger Alaska Comuuttno Center DEPT, 9600.000 SFLU.DTE ~P, .. TK -46. 063 IDPH, DTE ID(~F.DTE 0,000 I~OF, DTE IIRD DT~: 285,750 ~IXD,DTE CG~ :DTE 82,465 HTEN,DTF 915,0(~0 'DPHI,LDT DEF.LDT -999,2~6 OI,A.LDT LU. LDT -999. 250 Lb. LDT 8S~,LDT -999.250 bSRH. LDT' -999,250 LURH' :BDT CG~,LDT -999,250 T~'N: ~. $.,bDT HTE~. bDT -999,250 NPHI, CNL NPOT~,CML -999,.~50 RCNT,CNL FTC,CHL -999,250 SGR CNL ~MS, C~<~L -999. 250 MRES," CNh SGP.NGT -999.250 CGR NGT !.l~g, NGT -999,250 W4NG,NGT -999.250 WSNG NGT MRES,NGT -900,250 CS T~NS. C,SG -999.250 MRMS.CSG DEPT, 9500,000 SFI, U.DTg SP,DTE -51.031 !DPH,DTE IDOF.DTE 0.000 IuOF,DTE IIRD.DTE ~79,750 IIXD,DTE CG~.{~TE 106.!44 TE~S,DTE HT~,DTF 841,500 DDHI,bDT PEF.LDT -999.250 QL$.LDT LU.LDT -999.250 LL.LDT 8Sg. 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NGT -999 URAN.~GT -999.250 WlNG.NGT -999 W4~,;G. NG~ -999. ~50 WS~:'G. NGT -q99 ~PES. NGT -909. 250 CS. NGT -099 T~NS.CSC -909.250 u~ES.CSG -999 DE~T. 8000.000 SFL;I.DTE 3 SP. DTF -67. 375 IDPH. DTE 3 IDOF. DTE O. 000 1 ~OF. DTE 0 I IpD.DTE 249. 375 IIXD. OTE 38 CG~.DTF 97.920 TENS.DTE 5420 HTFV.DTE 9~9.500 DPHI.LDT -999 PEF. I, DT -999. 250 O[.S. BDT -999 [.~!. !..DT -999. 250 !~L. bDT -999 SST.BDT -999.250 LSHV.LDT -999 LSRH.LD~ -gQQ.~5(:) LURH,LDT -999 CGR. LIJT -999.750 TFNg. LDT -099 HTE~. L, DT -999.250 NPH'[. C~I, -999 29-0CT-1992 O9:50 .959 !La, DTE . 156 I~PH,DTE .000 CIDP,DTE '03I !IR~,DTE 25o ~HOS t,~T 250 Oss ,25 o 250 SSHV.LDT 250 CALI,LDT 250 ~TE~.bDT 250 T~PH,CNL .250 RCFT,CgL ,250 CGR,CNL 250 MTE~. CNL [ 250 TMOR. .250 W2NG,NGT .250 T~NS,NGT .430 !b~,DTE ,727 !MPH.DTE ,000 CIDP DTE .188 !IR~4' ' ,DTE ,DO0 MTEM.DTE ,250 RHOB,bDT .250 OSS,bDT .250 LITE.bDT .250 SSHV,LDT ,250 CALI,LDT .250 ~TE~,LDT :~50 TNPH.C~b 250 RCFT'CN5 .250 CGR.C~5 .250 ~TE~,CNL .250 THOP.NGT .250 W2NG.NGT .250 TENS.~GT .250 HTEN,MGT .~50 ~wE".CSG .236 IL".DTE .406 I~PH.DTE .000 MTE~.D~E .250 ~HOR.LDT .250 OSS.LDT .250 LITH.L~T .250 .259 CAL!.LDT .250 ~TE~.LDT 3.184 3.182 3i6.500 292.750 ~.47 ~00 -999:; 50 -999 250 -999~50 -999 ~50 -999 ~50 -999 250 -999 250 -999 250 -999 ~50 -999 250 -g99:~50 -999.250 -999.250 -999.250 -999,250 2 646 2i65~ 366 500 51 ooo -999.2:50 -999.~50 99.250 -999.250 -999.~50 -999.~50 -999,250 99.~50 -999.250 -999.~50 -999.250 -999.~50 -990.250 .404 ] 422 · 293 500 274:250 145 375 -999:~50 -gg9 250 -999~250 -990.250 -999.250 -990.250 -99~.~50 ILD,DTE IFRE,DTE CIMP..DTE SCR,DTE MRES.DTE DRMO,LDT LS BDT S1. RH,LDT SGR.hDT MRE$ LDT TNRaiCNL CNTC.CN5 HTEN.CNL POTA.NG~ W]NG.NG? MT~M,NGT SGR.CSG H~EN.CSG ILD.DTE IFRM,DTE SGR,DT~ ~REs,DTE DRMO,LDT LS,LDT SS!,LDT $1RH,LDT SG~.LDT MRES.LDT TMRA.CNL CNTC.CNb HTEN Nh POTA.NGT w3NG.NGT ~TEM.NGT SGR.CSG ~T~N.CSG IbD.DTE IF'RE.DTE CI~P.DTE SGP.DTE MRES.DTE DRHO.LDT LS.LDT S$1.LDT S1RH.LDT SGR.LDT HRES.BDT TNRA.CNL PAGE: 3, 314. -90o: -999, -999' -9~9 -999 -999' -999, '999, '999' '999, '999' °999' '999' , ~0' 376' 92' -999, -999, -999. -999, -999, -999, -999, -999, -999, -999, -999, -999. -999, -999. 292 -999, -999, -999, -999. -099, -999. -999, 14 !50 000 000 94 5 256 250 250 250 250 250 250 250 50 i,o 250 250 709 000 750 250 250 250 250 250 250 250 250 250 2.50 250 2.50 250 250 250 379 000 O00 671 837 250 25O 250 25O 250 25O 25O his Tape veriflcatton Llstinq .~ch.lumbero~r ~.laska Compu..tlnq Center NPOP.C~3L -999,250 ~CNT,CNL CFTC.CML -999,250 SG~.CNL TMNS,C~L -909,250 S~,NG? -999.25Q C~,~GT URAN,NGT -999,250 WING,NGT W4NC,NGT -999,250 wSNG,M~T MREM,NGT -999,250 C5"NGT TFMS,CS~ -909,~0 MRES,CSG DFPT, 8~00,000 SFLU,DTE SP.DTF -65,000 IDOF,DTE 0,000 IMOF,DTM II~D,DTE 336,750 Ii×D,DTE CGR,DTE 90.576 TENS,DTE HTEN,DTF ~!05.000 DPH~,LDT PEF,LDT -999,~50 OL$,LDT LU,LDT -999,250 Lb,LDT MS~,LDT -999,250 bSHV,LDT LSRM,LDT -999,~50 LURH,LDT CG~.I, DT -999,250 TENS,LDT HTEM,LDT -999,~50 MPMI,CNL NPt~ C~.L -999,2~0 ~CNT CNb SGR,MGT -999,250 CGR,NGT UP~M,NGT -909,250 W1NG,MGT W4N~,NGT -999,250 WSHG,NGT ~P~ NG~ -9~9,250 CS.,NGT T~i~$'CSG -9~9 250 ~RES,CSG , · . , ..... . ~FPT, 8700,000 SFLU,DTE SP,DTE -66,563 IDP~,DTM IDOF,DT~ 0,000 I~OF,DTE CG~,DTF 71.o46 TEN$,DTE HTEW.DTFi 1011.000 OPHi,LDT PEF,L~T -99~'250 OLS,LDT L!~.LDT -999,250 LL.LDT S$~.LDT -999,250 LSg¥,LDT I.$P~.LDT -999.~5U CC~.I.D~ -999,259 TENS,bDT HT~N.LD'r -99q.~50 NPHI.CNL MPOm.C~!.. -999.25P ~CNT,CNL CFTC.C~L -999,25© SG~.CNL TFN$.CML -999.~50 ~RFS,C~L SGP.NGT -q0o.250 W4~iC.MGT -999.250 ~mES.WGT -9~o.250 C$.UGT TF~$,CSG -999.250 SRES,CSG DEDT, P6~O.O0o SFI,U.DTE SP.DTF -65.250 IDP~.DTE IBOF.DTE 0,000 I~OF.OTE II~D.D?E 302.750 II×D.DT~ 09:50 -999'250 ugEh. CNL -996z50 -999~250 TMOR,NGT -999,~50 -999,250 W2M~"NGT -999,~50 -999,~50 T~NS*NGT -999,250 -999,~50 HTEM,MGT -999,1~50 -q~9.250 MT~,?M,CSG -999,~50 2:4J~ I~4PM.DTE 60,688 IIR~,DTE 5704,000 ~TEM,DTE -999,250 -999,250 LITH,LDT '999,250 '999,250 CALI, [~DT -999 250 MTE[~, BDT - 9 9: s o -999,250 RCFT,CMb -999,250 CGR,CN[~ -999,250 MTM~,CNb -999,~50 THOR,MGT -999,250 W~NG,NGT -999,~50 TENS,NGT -999 250 MTE~I, NGT -999[250 MTEg,CgG 2.482 IL~,DTE 2,54~ I~PH,DTE 0,000 CIDP,OTE 58.7~ IIRq,DTE 5320.006 ~TEM,DTE -099.250 RHOB,LDT -999,250 OS$,LDT -99~ 250 LITH.I, DT -999:250 SSHV,LDT -999.250 CAL!,LDT -999,~50 -999.250 T~PH,CKb -999.250 RCFT.CNL -999.~50 CGR.CNb -999.~50 -999.?50 T[~OR,NGT -990.250 W2NG.NGT -999,~50 TENS,WGT -999.~50 HTEN.NGT -999.~50 2.656 !Lg. DTE 2.721 !~P~.DTE 0.000 ClDP,DTE 52.406 II~M.DTE 409 O0 37~'000 144750 2999,250 -999.~50 - so -999 -999:50 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999:~50 -999,250 -999,250 2 5~7 2:570 393,000 364,250 1.43.500 -999,250 -999,~50 -999,~50 -999.250 -999.~50 -999,250 :999.~50 999,250 -999,250 -9q9.250 -999.~50 -99o,~50 -999,250 -999.250 -999.250 2.~05 367.250 331.500 CMTC,CNL CALI CNL POTA,NGT ~TEM,NGT SGR,CSG MTEN,CSG ILD. DTE iFRE:DTE C!~P,DTE SGR.DTE ~RE$,DTE DRHO.LDT LS,LDT S$~.LDT $1RH,LDT SGR.LDT ~RE$,LDT T~RAoCNL CMTC.CNb HTEN,CNb POTA,NGT W3NG..NGT SGR.CSG HTEN.CSG ILD,DTE IFRE,DTE CI~P,DTE SGR,DTE MRES,DTE D~MO,LDT LS,LDT SSI.LDT SIRH.LDT SGR,t. DT ~RE$,LDT T~RA,CNL CNTC,CNL C~LI,C~L HTEN,CML POTA,NGT W3NG.MGT ~TE~,WGT SG~,CSG HTEN,CSG ILD.DTE IFRE.DTE CI~P,DTE SCR,DTE -999'250 -999,250 -999,:250 -999,250 -099,250 -999,250 -999,,250 -999,250 2,.438 20,000 404,750 106,534 0,943 -999,250 -999.250 '999,250 -999,250 :999,~50 .999,~50 -999,250 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2 541 2O 000 388 750 102 151 0 841 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 -999o250 -999,250 -999,250 -999,250 -999,250 -999.250 2,697 20.000 35.).500 98.08~ bls Tare Veri..ficatinn histinq SchlUmberqer AlasKa ComptltInq Center CGR t. TE 79.07.. i TENc~. D~'E '~ t' ~ '' hTEN .DTE 95:1,500 DP~I PEW, bDT -999,250 QLS. EDT l]~I BDT -9~9 250 LL.LDT ss : .99 :250 I:.,SRH, LD~ -999.250 LURH,LDT CG~, LDT -999,250 TENS, LI)T HTE~;. [,[)T -909,250 ~P~I.CNL NPO~,CNL -9~9 ~50 RCNT'CNL CFTC.CNL -999' ..... .250 8C;R.CNb TENS.CNL -999,250 ~RES,CNb URA~.NGT -999 .~50 W i Nt; 2 :~,~GT ~4N~.NGT -909.250 W5NG.NGT ~[:S, ~GT -999,250 CS, NGT TENS.CSG -999,250 .~RE8, CSG DEPT, 8500,000 gFLU,DT~ .. ~ .? g¢,PTE -68,688 IDOF,DTE 0,0o0 !fqOF,DTE I!~D,DTE 273,000 IIXD,DTE CG~.DTK 08,545 TENS,DTE , HTEN,DTE 10~0 500 PE:W. LDT -999,250 ()LS.. BDT L[] . [,DT -999,250 LL, BDT SS?. bD~ -999,250 [,SEV. LDT l' ~n~ LDT '909.250 I.,H~H,LDT Ca°. bDT -999,250 TEllS. I~DT ~TEN. [,.,[:}T -999,250 NPHI,CNi~ NPOn. C~.~L -999,250 ~CNT.CNL CFTC, CNb -999,250 SGR. CNL TFNS. Cai, -999. ~o :~RES. CNL SG~. hGT -999. 250 CG~. NGT Ii~A~ NGT -999.250 WIN(i. NGT W4NC,NGT -909,950 WLNG.IqGT ~.'~E8. NGT -999 250 CS.NGT TFNS. CSG -999.' 250 M~S, CSG DFPT. ~400,000 SP.DTF -69.438 IDP~,DTE IIR9.DTF ~97.00a IIXD.DTE C~.DT~ 80.8~.3 TEt.!S. DTF ~TE~. DT~ 95].500 PEw. [.DT -99°, ~50 ObS, LDT LU. LDT -999. 250 !Jb. i, PT 582.LDT -9~9.250 LSHV.LDT LSRN.LDT -999.250 LI!PM. I.[)T CGm. BDT -999. 250 TENS. I,DT HTEN.LDT -999.~50 C~TC. Cab -999. 250 5GR. CNb TE'NS.CNL -999,25o a~ES.C~L SG~. 5:GT -999.25O !J~ ~ ~. ~(;'r -909.250 29-0CT-:1992 09:50 252 - g 99 - 9.2 999 -999 '999~ '99~.2 '999.2 999 -999 -999 -099 3.3 3.! O.O 41,5 5468,0 i999.2 999,2 999,2 999, 999,2 '999,~ 99c~ 2 -999,~ '999.2 -999.2 -999.2 -999!2 -999 2 2.7 5! .! 5204.0 -999.2 -090.2 -999.2 -999.2 -990.2 -999.2 -999.9. -999.~ -999.~ -999.2 -999.~ 00 ~ T Et4, DTE 50 RHOB,bDT 50 0 S $. b D T 50 b!TH':bDT 50 SSHV,bDT 50 CALl,LDTD '''~ 50 TNPH, CNL 50 ~CFT,CNh 50 C~R,CNb 50 T ~ C~ R, N G T 50 W2NG, NGT 50 TENS. NG~ 50 HTE:~, NGT 50 ~TE~'~, CSG 07 IL~,DTE 21 I MPH, DTE DTE O0 CiDD, 3 ! I: i R: ~, D T O0 MTEq, DTE 50 RHOB. bDT 50 OSS. LDT 50 LITfi.bDT SSHV. BDT 0 CALI, bDT 50 ~TE;M., bDT 50 TNPH,CNL 50 ~CFT,C~L 50 CGR,CNL 50 aTE[I, CNL 50 THO~, ~GT 50 W2~.~G. NGT 50 u~.~,.:... CSG 143 375 -999 -999150 -999 ~50 -999 250 -.999 ~50 -999.~50 -999 250 -999 250 -999 -999 250 -999~50 -999,.50 -999~50 -999.:250 -999 250 :883 90O 322,750 .1.42.125 .999,250 .999,250 999,250 -999 250 -9991250 -999 250 :999.250 999,250 -999 250 '999i~50 -999 250 -999 250 -999,250 -999.250 2,799 2.816 356,5O0 332.250 1.41.125 -999.250 -999.250 99.250 .99.250 -999.250 -999.250 -999.250 -999.~50 -999,250 ~RES ,DTE ORgO.LDT SSI .LDT s 1 LOT SdR ~DT TNRA. CNb CNTC,CNb HTE Nh POTA.NGT W]NG.NGT MTEM, NGT SGR. CSG HTEN,CSG ! b D ' D T E IFRE.DTE CI~P DTE SG~ :DTE ~RES,DTE D~O, bDT [.,~. LDT SSI'bDT S 1 RH. LgT 8GR,LDT aRES,bDT TNRA,CNL CNTC,CNb ClbI · HTEN.CNb POTA.NGT W3NG.NGT ~!TEM. NGT SGR,CSG HTEN,CSG I LD. DTE IFRE,DTE CIMP.DTE SGR.DTE MRES.DTE DRHO.bDT LS.LDT SSi .LDT S1RH.LDT SGR. LDT MRES.LDT TM~A . CML C~TC .C~b CALl .CNL HTEN.CNL POT~..NGT W3NG.NGT P A G E: 16 0.9!0 -999 250 -9991250 -999'~50 -999,~50 -999,250 -999'250 -999,250 -999,250 -999,~50 -999,250 -999,250 -999'250 '999,~50 3 057 20!000 344 750 106.581 0.869 :999,250 999,250 999 250 999~250 999,250 -999 250 -999!250 -999 250 -999.250 -999.~50 -999.250 -999 250 =999i250 -999 250 -999,250 2,793 20,000 354,750 101.308 0,877 -999,250 -999.~50 -999.250 -999,250 -999,250 -999,250 -999.250 -999.~50 -999,250 -999,250 -999.250 -999,250 ils Tape verifl, cat!on !,istina ~cblumberqer Alaska ComDutino Center 29-0CT-1992 09:5o DFPT, 8]00,000 SFLU,DTE~ SP,DTE -70,188 IDP!:{, DTE IDOF,DTE 0,000 INQF, DT~ I!?D.DTE~ 308,000 IIXD,DTE C~R,DTE 73,91. ~ TENS. NTE~.~ DTE ~067,000 DPNI,LDT PE~,' [~I)T. 99~_ , 250 OLS, LU. LDT -999,250 Lb, LDT SS2,LDT -999,250 LSHV,LDT LSPH.LDT -~oq,250 LUgM,LDT ~GR I_,D~ -999 250 T...,ENS, LDT [t'~EN ~ Bt)j. -999:250 NP~I,CNL NPO~ CNI] -999,250 C~TC, CNL -999,250 SGR, CML T~NS,CNb -999,250 ~'RF:S, CML SG~, NGT -999,25~ C~R, NGT U~AN,MGT -999,250 W~.rG,NGT W4N~,NGT -999,250 wSt4G. ~:~GT ~RES. NG? -999,250 CS, UGT TE~$, CSG -9~9,250 2.580 2,688 0,000 5~'656 532~.000 -999,2~0 -999,~50 -999.~50 -999.250 -999.~50 -999'250 -999 -999 -999 250 -999 -999 -999,~50 -99Q,~50 -999,250 -99Q,250 InQF,OT~ 0,000 I~QF.~TE 0.000 I!RD.DT~ 338.000 IIXD,DTE ~2'688 CG~ DTE 71,491 TENS.DTE 5252 OCO HTEN:DTE 1002,500 DPMI,hDT -999S250 PEF.hDT ~999,~59 QI,,S.LDT -999,250 LU,LDT 990,250 t,L.LDT -999.250 SS2.LDT -909,25() LSHV.bDT -999 250 LS~H LhT -909,250 LLIRH BDT -999:250 CG~.LDT -999,250 TEMS,LDT -999.~50 HTEN,LDT -999.~50 NPHI,CNb -999,250 NPQP.CNL -999,250 RCNT.CML -999,~50 CFTC.CNL -999,250 SGN.CNL -999,250 TEMS,CML -999,~50 ~ES,C~L -999.?50 ~GR,NGT -999.250 CGR,~GT -999,250 UPAw.NGT -909,250 w!NG.NGT -999.250 W4NC,NGT -999.250 WSMG.NGT -999,~50 ~E$,~GT -909.950 CS,MGT -999,~50 T~NS.CGG -999,~50 ~RES,CGG -999,250 [b ~TPT . ~ 10 O . 09(') SFLU , DTE SP. DTF -71.18~ It,OF,. DTE: IDler. DTE (). OOn I~QF. Dq~K ! T~, DTK 3~ 3,500 CG~. DT~i ~ &. 3 ]9 NTP~k~. DTE 1001. 500 DPHI. L, DT P~. !,DT -909. 250 OLS. I,r)T bti , LDT -QQQ , 2~(~ S82. LDT -9gq, 250 LSHV. Lr)~ 2.467 2.5%7 0,000 5~.625 5248.000 -999,250 -999.250 -999.250 -999.250 T E NS, :N (,T H TMon!, NGT ~TE?~,CSG i~PH, DTE C I D P, P T g: I IR~, g'.rE RHOS,LDT OSS,LDT biTH, LDT SSHV, bDT CALI,LDT MTE~4, bDT TNPH, CNG RCFT, CNb CGR,CNL ~TE~, C~tb THOR, ~GT W~NG, TENS, NGT MTEN, ~TE~,CSG IL~, DTE I MP~, DTE CIDP,DTE !IR~,DTE NTEM. DTE RHO~, LDT OSS,LDT bITH. LDT SSHV, LDT CAL!.LDT MTE~, L, DT TNPM,CNL ~CFT, CNL CGR, CN b ~TEM. CNL TMOR,UGT W~NG,NGT TE~S, NGT WTE~, NGT ~ T E ~,~. CSG IMP~,DTE CIDP,DTE OSS. LDT L!TN.L~T SSHV. bDT -999,250 -999,250 -999,~50 2,684 2,686 ]72'000 346,000 140 000 '999:250 -999 250 -999 ~50 -999,:250 -999,250 -999,~50 -999,250 -999,~50 -999,~50 -999 -999:50 -999 i50 -999 50 411: . 381 ~00 O0 139 625 099' -.. .250 -999.250 -999,250 99,250 99.250 -999.250 -999 250 -999:250 -999,250 -999,250 -999.~50 -999 250 -999i250 -q9g 250 2.527 2.533 392.500 367,000 138.625 -999,250 -999.250 999 250 MTE~,NGT SGR,CSG ~T~'CGG ILD,DTE IF~E,DTE CI~P,DTE SGR,DTE ~RE$'DTE DRHO,LDT LS.LD~ SS!,LDT SIRH,LDT SGR,LDT ~RES*LD:T TNRA,CNL CNTC.CN[., HT.~N CNL POTANGT W]NG,NGT NTE~~ NGT HTE~ CGG LD,DTE I RE,DTE CI~P,DTE SGR.DTE MRES,DTE DRHO bDT LS:LDT SS~,LDT $1RH,LDT SGR.LDT MRES.bOT ~NRA,CNL CnTC.CWL CALI.C~L ~TEN.CNL POTA,NGT w]NG.~GT VTE~.NGT SGR.CS~ HTEN,CSG ILD.DTE !F~E,DTE CXMP.DTE SG~,DTE ~RES.DTE DRHO.LDT LS.I. DT SS].,LDT S1RH.LDT PAGE: 17 -999,250 -999' 250 -999, ~50 20'000 372,00O -999,250 -999,250 -999,~50 -999 250 -999 0 -999 0 -999 250 -999,250 -999' 250 -999,250 -999 ' 250 --909,250 999,250 4 0 41. 250 O. 958 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999.250 99,250 '999,~50 '999,250 '999,~50 '999,250 0oo 394.250 90,488 0,895 -999,250 -999,9~50 -999,250 -999,250 LIS Tape Verification Listl. nc~ Schlumberger Alaska Computi. nO Center LSRU.LDT -99q,250 L{IPH,t~DT CC~. LDT -999. 250 TE~S. bDT HT~;~. LDT -9~9.250 NPOP,C~L -999.250 ~CMT,CNL CFTC, CML -999,250 SGR.CNL TENg,CM'L -999,250 8GR. ~G T -999,250 I.~R ~', ~GT -999,250 W1MG.NGT W~g,~GT -999.250 ~bMG,NGT ~ES, NGT -999,250 CM.~GT T~NS,CSg -999,250 DEPT, 8000,000 SFBU,DTE ~P,DTE -72,563 IDPM,DTE !D'OW,DTE 0,000 I I~.!)T~ 2o9,000 !IXD DTE CG~, DT~ 86,409 HTE~. DTE !083,009 DP~I,LDT DEF, LDT -999,250 QLS, bDT LU, bDT -9gg, ~50 Lb, bDT SSg. LDT '999,250 LSHV,LDT LSR",LDT -999.~50 LURH,LDT CG~,LDT -999,250 TENS,bDT HTE~3, LDT -999,250 NPMI.CNL NPOP,Ct~b -999,250 ~CMT,C~4L CFTC, CWL -999,250 SGR,CNL TFM~,C~4L -999,~50 ~G~ '~'GT -999,2~0 CGR MGT ~!~: A~' ' ~GT -999 2~0 W4~JG.NGT -999.250 W55~G. ~GT ~PEM MGT -999,250 CS,NGT T~NS ~CSC -909,250 DFDT. 7900,000 SFLU,DTE SP.DTE -73,688 !DPH,DTE I~DW,DTE 0,000 !~.~QF, DTE IIRD.DTE 3~6,000 I!XD,DTK CGP.DTK 52,447 TENS,DTK HTE~.DTE 99~,000 DPM1,LDT P~F, LDT -999. 250 ObS, LPT LU. LD~ -999,250 Lb, bDT SS9, bDT -999. 250 LSHV. [,DT LSAt. LDT -999,250 L[.}~, bDT CGm. L~T -99~. 250 TENS. bDT DTEM,I. DT -999,250 NPHI.C~L NPO~,CHL -999,250 ~CNT.C~L CFTC, C~JL -999,250 SGR, CNL T~S,CNL -999,250 ~RES. C[.~b SGP. ~-iGT -999. 250 CGR, ~GT . ~,T -q~9.250 WlNG.NGT W4~C. NGT -990.250 WbWG. ~:GT 29-0CT-1.992 09150 -999,250 CALl .bDT :~9 250 ~wE~, bDT 9: 250 TNP~.CNL -999.250 RCFT. Ci~'h -999,250 CGR'CML -~99 ~50 ~TEM, CML ~999 250 -999. 250 MTE~ ,NGT -999,~50 MTE~'CSG 2,939 IbM,DTE 2,807 IMPH, DTE 0'000 CIDP,DTE 53,375 I!R!~,DTE 5448,000 MTE.*~, DTE -999 250 RHOB, bDT -999~ 250 f~SS,bDT -999,250 LITH,LDT -999,250 SSHV,bDT -999,250 CAbI,bDT -999 250 ~TE~-~ LDT ,250 .... ,C~L '999.250 RCFT.Cr~b '999,~50 CGR,C~b -999,250 999 ~50 THOR, 999[250 -999,250 TE. NS, N'GT -999'~50 gTEN,~JGT -999,~50 ~TFg,CSG 2,21] IL~,DTE 2.367 IMPH,DTE 0.000 C!DP,DTE 65.500 IIR~,DTE 5~44.000 ~TE~,DTE -999,250 ~HOB,bDT -999,250 OS$,LDT -999.250 LITH,LDT -999.250 -999.250 CALI,LDT -999.~50 T~Pg. CNL -~9o.250 RCFT,CWL -999.250 CGP,C~L -999.250 ~TEU,CM[, -999.~50 TMOR,NGT -999.250 W2NG.MGT -999.250 TENS.MGT -~99,~b0 MTEiJ,N~T -999.250 -999,250 99,.,:250 -999,250 ,999.~50 .999,250 999;250 -999,250 -999,250 2,789 ~.848 ~56.000 333,250 137,250 -999,250 -999,250 -999,250 -999,~50 -~g~ 250 -999 250 -999!250 -999 ~50 -999,250 -999 250 , -999,250 -999,250 -999,250 -999,250 2 348 2 346 422 000 39~ 250 116 ~75 -999.250 2999,250 999,250 999,250 999,250 999,250 -99~,250 999.250 :999,250 -999.250 -999.~50 -999.250 -~9~.250 -999,250 -999,250 SGR. MAES, TN:AA. C~TC, C~L!, MTEN, PQTA. W3NG. ~TE~. MTEN, t, DT bDT C~L tnb N~T CS~ ILD,DTE IFRE,DTE CIMP~DTE SGR,DTE ~RES,DTE DRHO.,bDT .L$,LDT SSI,bDT SI~H,LDT SG~,LDT MAES.bDT TNRA,CNL CNTC,CNb CALI,C~b HTEN,CNL POTA,NGT ~3~G,NGT ~TE~,NGT SGR,CSG HTEM.CSG !LD,DTE IFRE.DTE CI~P.DTE SGR.DTE MRES.DTE DR~O.LDT bS.LDT SSI.bDT SIRH,LDT SG~,LDT ~RES,LDT TM~A.C~L C~TC.CNL CAbI.C~L HTEN,C~L ~T~.~:GT W3~G.~GT ~T~.~GT S~F.CSG HTE~.CSG PAGE: ! 8 '999,250 '999"~50 '999~50 '999,2~0 '999,950 '999,~50 '999,250 '999,250 '999,250 999,250 2 791 20 0o0 350 750 109,961 0.898 -999,250 '999,250 -999 250 -999:250 :99.9 250 99 22so 2999 250 999]250 -999,250 -999,~50 -999,~50 -999,250 99:250 -999,250 2.357 20,000 426.000 109.147 0.914 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,~50 -999,250 -999,~50 -999,250 bis Tape verification LiStln~ 3chlumberoer ~l. ask'a ComDutinO Center DEPT. 7800.000 SFLU SP,DTE -75,250 IDPH,'DTE ]IRD,DTE 371,000 IIXD.DTE CGD,DTF 45 450 TENS,DT~ PEF, I..[)T -999, ~50 OLS, LDT L U, b [) T - 999,250 b L, L D T S S 9, L '0 T - 999,250 1,. ,~ }'t V'. L D T LSR~,LDT -999,~50 CGR LDT -999,250 ~NS,LDT HTEM:~]DT -999,250 NPO~,Ck![ -999,250 RCNT.CNL CFTC,CML -999' 250 SGR" CNL TM~J'S, CNL -999,250 ~RES,CNL SG~, NGT -999,250 CGR,NGT URAN,NGT -999.250 W1NG.NGT W4N~,NGT -999,250 W5NG, ~GT ~EM, ~GT -999,250 CS, NGT TENS,CSG -999,250 NRES,CSG DEPT, 7700,000 SFLO,QTE SP,DT[; -73,563 IDP}~,DTE I DOW, [>T~.~ 0,000 I~OF,DTE IIRD,DTE 363,500 IIXD,DTE CG~,.DTE 62,13~ TENS, [)TF~ HT~, DTE ~018 500 DPHI,LDT LIt, LDT -999,250 L[,. LDT SSg,LDT -999,250 bSHV.LDT LSRH, LDT -999. 259 CG¢.bDT -999.250 TENS.BDT ~T~. I,,I)T -999.250 ~PHI.CNB NPO~.CN!, -999.250 ~CNT.CNL CFTC CN~I. -99~,750 SGR ,C~,L TFNS :C~.!L -999.~50 MREM,CNL SG~. ~4CT -999,250 CGm, NOT !1~A~, NGT -QQ9,250 W 1NG. ~'GT W~NC,NG7 -999,250 ~PES, NC~ -999,250 CS. NGT TFqS.CSG -999,~50 ~R~S.CSG DFPT. 7600.000 SFLU. DTF.. SP. DTF. -77.06~ IDPH. IDO?.DTT 0.000 IMQF.[)TE I IRD.DT~7. 353.7~0 CG~.DTE 89,773 TENS,DTE HTE[r,DT~ 920.500 OP~IT.LDT ~MW. f. DT -gPg. 250 QLS. LDT L~, tDT -999.75~ Lb. L!)T SS?. L~)T -999. ~50 LSUV. LDT LSPu.[,~T -999,250 CG~,LDT -999.250 T~}S. LDT HT~M. [.,!.)~ -99q. 250 09:50 2,061 !L~J DTE 2.1, 86 I 0,000 C!DP, DTE 71. ,438 -99": 250 -999,250 ()SS, LDT 999,250 LI]'..~, LDT 999, ~50 CALI'LDT -999,250 MTE~,LDT -999,750 TNPg,CNL -999,250 RCFT,CNL -999,250 CGR,CNL -999,~50 MTEM. CN'~L -999,250 THOR,NGT -999,250 W2NG,NGT -999,250 TEN8, NGT -999,250 HTEN,MGT -999,~50 2,031. !LM,~TE 2.232 0,000 CIDP,DTE 69,313 IIR~,DTE 4920.000 ~TE~,DTE '999,250 RHOB.LDT '999.250 OSS,LDT '999,~50 LIT~,LD'T '999,250 SSHV,L~T '999 250 CALI,LDT '999:250 MTEM.LDT -999 250 TNPH,CN[. '999:250 RCFT,CNL '999,250 CGR,CNb '999,250 MTEM,CNL '999,~50 '999.~50 W~N~,NGT '999.250 TEN$,NGT '999.250 '999.250 uTE~,CSG 2.105 ILM.DTE 2.309 IMPg. DTE 0.000 CIDP,bTE 68.000 IIRU,gTE 4644.000 '999.250 ~H[]B.LDT '999.250 QSS.LDT -999,~50 I~!TH,LDT -~99.250 SSHV.LDT -g99.250 CA[..I,I,DT -999.~50 ~T~g. LDT -099.950 TNP~.CNL ~i~'43141 457 250 431000 135 625 '9991~50 -999~50 -999 ~50 -999 250 -9992250 -999.~50 -999,250 -999 ~50 -999250 -999 ~50 -999! 50 -99950 -999,~50 -999:50 -999,~50 2,t74 2.184 447,750 5 000 -999 250 -9992 5o 99,250 -099 250 -999 250 -999 250 -999 250 -999 25O -999 250 -gg9 -999 250 -999,~50 -999.~50 -999.250 2.264 2,264 433 000 408:500 !33.875 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.~50 -99~.250 !LD,DTE IFRE.DTE CI~P.DTE ~4RES DTE LS.L~T S$1,LDT SIRH.LDT SGR.LDT TNRA.CNL CNTC.C~L CALI.CN5 HTEN.C~L POTA.NGT w3NG.~GT ~TEg,NGT SG~,CSG 8TE~,CSG !LD,DTE IFRE,DTE CI~P,DTE SGR DTE DRHO,bDT LS,LDT S$1,LDT SI~B,LDT SGR,LDT g~ES,LDT TNRA.CNb C~TC,CNL CALI,CNL HTEN,CNL POTA.NGT W]NG,NGT MTEM.NGT SGR.CSG HTE~.CSG ILD.DTE IFRE.DTE CI~P.DTE SGR.DTE ~RES.DTE DRHO.LDT LS.LDT SS1.LQT SI~H,LDT SGR.LDT uRES.LDT T~A.C~L 20, 466 1,03' O, -999, -999, -999, -999, -999, -999, -999 '999! -999 -999 -999 -999 -999 -999 -999 178 000 500 948 921 250 25O 25O 25O 250 2.5O 25O 25O 25O 25O 25O 250 25O 25O 25O 2223 20i000 457 500 I03,699 0,904 -999,250 -999,250 999 250 2 9 22so -999,250 -999,250 -999250 '9992250 -999.250 '999,~50 -999,250 -999,250 -999,250 -999,250 -999,250 9 , 20, 441, 97, O, -999. -999, -999, -099, -999, -999 -999: 299 000 25O 668 918 25O 25O 25O 25O 25O 250 250 ils Tape ver]fl. Cation Li. stino ~chlumber~er Alaska Computing Center NPOR,CNL -999,250 RCNT,CNL CFTC,CNt. -~o9,250 TENS,CML -999,250 ~RES'CNI., .$Gp.NGT -999 250 CG~ NGT ~':~ '999 ' ~,T 250 ~!N~.NCT ~ .- .- , ~ -. ~RES, NGT -999,250 CS, NGT TEM.9. CS(; -900.250 ~RES.CSG DEPT 750¢~ 00() SFLU.DTE !DO~.DTE 0,000 I~OF,D~E I IRD, DTf~ 355,750 IIXD,DTE CG~,DTE 63 405 T"' O ' ~ kN,DT~ 950'500, . DPHI,LDI DEF. bDT -999. ~50 OL8. LDT LU. bDT -999,250 bL. bDT SS?.LDT -999,~50 bSHV.LDT bSR~,LDT -999.250 C~P,bDT -999 250 TFNS.L[)T }'{T~N, [~D T -9991250 HP~I,CNL NPOP.CNL -999,250 RCNT.C~JL CFTC. CNb -999,250 8GR.CNL TE~!S,CMb -999,250 SGP, NGT -999. 250 CGR. NGT URA~:~, NGT -999,250 W!MG,NGT W~-MG. ~GT -~99.~50 WbNG.NGT ~K'S, NGT -999. 250 CS. ~3GT ~EN.q. CSG -9qq,250 MR~S, CSG DEPT. 7400,000 SFLtt,DTE SP,DTE -82.688 IOPH.DTE ID(~F.DTE 0.000 I?~QF. DTE IiRD.DTE 301.00(> I!XD.DTE CGo. DT~ 107,408 TE~{$. DTE PE'F, LDT -999,250 OI, S. I.,DT LU, bDT -99~, 250 LL,LDT 8Sg,LDT -999,250 LSHV,LDT LSRF, bDT -999,250 LUSH, LDT cG~,LDT -909.250 TENS, bDT HTEW,LnT -99Q,250 NPNI,C~L ~POP,CNL -999,250 CFTC, CN[. -99~. 250 SGR. C~L TENS.C~L -909.250 ~RE&. CNI., SGP, MGT -999,250 CGR, NGT URA~,NGT -q99,250 WlNG,NGT WaNG.NGT -999,250 WbNG.i~GT ~RES, NG~ -999. 250 CS. ~GT Tw~';~. CSG -999.250 ~'~RES. CSG 29-0CT-1992 09:50 999 250 RCFT.CNL : 99:25o -999.250 -999 250 T~OR,NGT -999[~50 W~'NG,MGT -999.250 TEN$,NGT -999,250 HTEM,NGT -999.250 ~TEE,CSG IL~.OTE 0 000 C!DP.DTE 66~250 'I!R~,DTE 4728 000 -999:~50 R~OB".bDT -999,~50 OSS.bDT -999,250 LITH,bDT 999 ~50 SSHV.bDT 29 9225o -999,250 ~TE~,LDT -999,250 T~Pg.C~L -g99,250 RCFT,C~L -999.250 CGR,C~i~ -999,250 -999,25o -999.250 W2NG.NGT -999.250 TENS.NGT -999.250 HTEN,NGT -999.~50 ~TE~.CSG 2,559 Ib~.OTE 2,773 IgPH,DTE 0.000 C!DP,DTE 52.156 !IR~.DTE 4524.000 MTE~I.DTE -999.250 RHOB,LDT -g990~50 OSS.LDT 999 250 LITH,LDT 299 : so "g99,250 "999.250 MTE'~ LDT -o90.250 TMPg. CNL '999.250 RCFT,CNL '999.~50 CGR.CNb '099.250 ~TE'~ C~b -990.250 THOR.~GT -999.250 W~N~.~{GT -999.250 TENS.NGT -999,250 HTE~J,NGT -999.250 ~TE~.CSG 2.430 !I,M.DTE 2.752 I~'PH.D'FE 0.000 CIDP.DTE 53.250 IIRg. DTE -999..250 999 250 29992250 -999.250 999 ~50 -999.2~0 -999,2~0 ~ 230 4351~50 4!4 50 -999.250 -999 -999:. 50 -999:~50 -999 50 -999'250 -999.~50 -999 -999:50 -999 !50 =999i 50 -999 50 -999 250 -999~250 -999,250 2 664 2~686 360.950 34~.500 132.375 -999.250 -999.250 -999,250 -999,250 -999,250 -999,~50 -999,250 -999.250 -g99.250 -999.250 -999.250 -999.~50 -99q.250 -999.250 -999,~50 ~ 650 363.000 350.250 C~TC.CML CALl.CML HTEN.CNL POTA.MGT w3~G.NGT ~TE~.~!~GT SGR.CS~ HTEN.CSG ILD,DTE CI~P.DTE SGR.DTE gRES.~TE DRHO,LDT I...S,LDT SiR~.LDT SG..LDT ~RES.LDT TN~A.CNL C~TC.CNb CALI,CML POTA .GT W3. NG.NGT MTE~NGT SGR:CSG HTEN.CSG ILD.DTE !FRE.DTE CIMP.DTE SGR.DTE MRE$.DTE DRHO.LDT L$.LDT S$1,bDT S!RH,LDT SG~,bDT ~RES.I, DT TNRA.CNI, Ct~TC.C~L CALI.CSL NTEN.CNL POTA.NGT w3P~G.NGT MTEM.NGT SG~.CSG ~T~N.CSG TLD DTE SGR,DTE PAGEt 20 -999,250 -999'250 -999,250 -999'250 -999.25O -999,250 -999~250 -999,250 2.28! 20,000 447,750 99,~32 ~ 0,934 999~250 2999,250 999,250 ~999.~250 999,250 -999.250 -999'250 -999,250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,~50 -999,250 2 754 20i000 372 000 107 534 0 936 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 -999,250 999,250 :999,250 -999 250 '999i250 -999 250 -999.~50 -999,250 2 736 20~000 377,250 100.606 Tame verification !,IstJnq ;ch!umberQer Alaska Computl~g Center CG~.DTE 77.144 TEN$,DTSI HTEN'.D'.,:E 904 000 DPF~I LDT PEF.LDT -9991~S0 Ot, S,Lr r [.,U.LDT -999. 250 LL.. LDT SS2,LDT -999.250 LSHV.LDT LSRM, LDT -999. 250 LUSH, LOT CGm, LDT -999. ~50 ~EN:$. LDT HTE'~. LDT -990, ~50 ~PHI, CNL NPOP.C~gL -999,250 RCNT.CNL CFTC C~L -999.250 C -L SGR.NGT -999.250 U~A~,NGT -999.250 W!NG.MGT W4NG.NG? -990 250 ~SN- NGT ~PES. NGT -999' 250 CS~ MGT TENS,CSG -999.250 ~4'RES, CSG {)EOT. 72~00.000 SFbU.DTE SO..DTE 84.625 IDP.~.DTE II ~,DTF 288,250 I.lXD, ...... DTE CGP.DTE 61.852 TENS.DTE H~E~.r)TE 980.000 P~IF LDT -999 ~50 OLS.LI)T ...... , L[)T -999,250 bL. bDT . L~>~V. LDT gS~ LDT '999. 250 LSR~.LDT -999,250 LURg. LDT CGR.LDT -999,250 TENS.LDT HTEN.LDT -999,250 NDHI,CNL NPO~,CML -q99,~50 RCNT.CNL CWTC. Ck?L -999. ~50 SG~. CNL TENS.CNL -909.250 SGP. N..T -999. 250 CGR. ~JGT [.{~ A~:. ~GT -909.250 W1NG.NGT W~MC. ~.~GT -000.250 W5NG.NGT MPES. NG* -999. 250 CS. MGT TENg.CSG -909.~50 MRES.CSG D~PT, 7100.000 SFLU.DTE SP.DT~ -83.375 II)PH.DTE IBO.W.DTE 0.000 II~D.PT~ 31.9.250 IIXD.DTE CG~.DTE 68.204 TENS.DTE ~TEN.DT~ 964.500 DPMI.LDT PE~. LI)T -909. ~50 0LS. bl)T LU. LDT -999. 250 Lb. LDT SS~.L~T -990.250 LS~V.LDT LSP~.LDT -999.~50 CG~. L[~T -99q. ~50 TENS. L[)T t{TEt;. I~DT -999.250 NP};I.CNL wPOP.C~L -999.250 ~CNT.CNL CFTC. CN[. -999. 250 SGR. CNL TFNS.CNL -999.250 ~RES.CNL S(;~. NGT -999.25n CGm. bGT 29-0CT-!992 09:50 449~,000 gTE~..DTE -999.250 R!4OB.LDT -g99.~50 -999 50 LIId. LDT -9'9~ ..50 99.250 ~TE~.LDT -999.250 T,. ~.CNL -999.250 RCFT.CNL -999, 50 -999, 50 MTE~.CNb 999. 50 W2NG,~GT -999.~50 TENS,NGT -999.250 ~TE~.NGT -999.250 ~TE~,CSG 48,031 IIRU,DTE 9.250 ~HOB.LDT :999 250 OSS.LDT 999:~5o himS.bDT -999~50 8SH¥.LDT -999~250 C~bI,bD? -999.250 MTE~,LDT '999,250 TNPH,CNL -999.250 RCFT.CNL -999.250 CGR.CMh -999 ~50 ~'TE~,C~b -g~9.250 w~n.~T -999.~50 T~$.~G~ -~99.250 -999.~50 MTE~.CSG 2.17b IL~.DTM 2.60~ I~PH.DTE 0.000 CIDP.DTE 5~.250 IIRM.DTE 4624.000 -999.250 -999.250 CSS.LDT -999.250 bITH.LDT '990.250 SSHV.LDT -999.250 CAbI.LDT -099.250 MTE~.LDT '999.~50 T~{P~.CNL -99g.250 RCF~.C~L 'ggq.~SO CGR.C~b '999.~50 ~TE~.CNL '999.250 THO~.NGT 'gqq.250 W2NG.UGT 131625 -999:250 -999.~50 -999'250 .999.~50 -999:~50 :999 50 999250 -999 250 -999 ~50 -999250 -99g:~50 -999 250 -999 ~50 -999 250 -999,250 7!1:750 345 000 34~:750 130.625 2999.~5o ~.~5o 9992~50 -999.250 -999 ~50 -99 : 5o -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 999.~50 2.410 ~.402 384.250 384.250 129.375 99.250 -999.250 -999.250 -999o250 -999.~50 -999.250 -999.250 -999.250 -999.~50 -999.~50 -999.~50 MRES,DTE ORHO,~DT LS.[DT SS!.LDT SIRH.LDT SGR,LDT M~ES.LDT T~R.~:~NL CNTC Nb CALI.CNL MTEN.CNL POTA.NGT W3NG.MGT ~Tg~ NGT HTEN.CSG ILDDTE CI~P DTE SGR:DTE M~E$.DTE D~O.LDT bS.LDT SSI.bDT $1. RH.LDT SG~.LDT MRES.LDT TMRA.CNL CUTC.C~L CALI.CNL HTEN.CNL POTA.NGT W3NG.NGT ~TEM.MGT SGR.CSG HTEU.CSG ILD.DTE IFRE.DTE CIMP.DTE SGR.DTE MRES.DTM DRHO.LDT LS.LOT SSI.LDT S1RH.LDT SGR.LDT MRES.LDT TNRA.CNL CNTC.CNL CAL!.CNL HTEN.CNL POTA.NGT W3NG.NGT PAGEI 21 0,942 -999'~50 -999'250 -999.250 -999,250 :999.250 ;999'250 999.250 -999,250 -999.,2~0 -999"250 ~999,~50 -999,250 :999,250 999,250 -999,250 877 g:ooo 363,500 10!'634 0,956 '999.250 '999.250 '999,250 :099 250 ~992~50 -999 250 -999~250 -999.250 -999,250 99:250 -999,250 -999.250 -999.250 -g9g.~50 2.568 20.000 416.000 89,803 1.003 :999.250 999,250 -999.250 -999.250 -999.250 -999.25~ -999.250 -999.250 -999,250 -999.250 -999.250 -999.~50 LIS Ta~e Verification Listl~0 Schlumberger Alaska ComputinO Center M4NO,NGT -999,250 WBNG,NGT ~RES.NGT -9o9,250 CS,NGT TE~8,CSG -999,250 ~EM,CSG DMPT. 7000.000 SFLU.DTE SP,DT~ '~6,375 ID.Pg. DTE !DOF.DTE 0.000 IuOF.DTE I~RB.DTE 285,500 IIXD,DTE CG~,DTE ~4,66! TEM$,DTE HTES!.DTE 9~3.000 DPMI.LDT PMW'[,~T -999'250 OLS,LDT LU,LDT -999.250 LL LDT $$~,LDT -999,250 LSHV:LDT I,,S~'LDT -999,250 L[!PH,LDT CG~,LDT -999,250 TEN$'LBT HTE~,LDT 909,250 NPHI,CNL CFT;C CML -909 250 SGR'CN!. T~.;.,,S.CN!, -999.250 .aRES.;CNL SG~.~JGT 9~0 ~50 URh~'NGT [999'250. W1NG.NGT.... . W4N~.NGq' -909.250 WSNG.NGT E.~.MGT -999.250 C$,NGT TF~S.CSG -999,250 ~RES.CSG D~PT. 6900.000 SFI, U.DTE SP.DTE -85.750 !DPH.DTE IDQF.DTE 0.00o !NOF.DTE IIRD.DTE 286,500 IIXD.DTE CG~.DTF 67,677 TEN$,DTE ~TE~ DTE 888'000 DPHI.LDT P~F.I,,DT -999.250 QL$.I,,DT LU.LDT -990,~50 bL,LDT SSg. LDT -990.250 LSHV.I.,DT LSR~{,LDT -999.250 L[i~H,LDT CGP.LD~ -990.250 TENS. LDT HTEM.LDT -999.250 ~P~I,CNL ~POP.C~L -9o9.250 RCNT.CNL CFTC.C~L -999.250 SGR.CML TMMS.CML -999.250 SGR.~GT -9oQ.~50 CGR.NGT iIPA~.NGT -999.250 W1NG.NGT W4NG.NGT -Q99.250 WSNG.NGT M~ES.MGT -999.250 CS. NGT T~NS.CSG -999.250 D~PT. 6~00.000 SP. PTE -87.68;3 IDPH. DT[~ IDOF. DTE O. 000 I~OF. DTE I IRD. DT~ ~94. ~50 I C~.DT~ 9~.077 TENS. [;TE HT~.DTE 930.500 PE~ . bDT -990. 250 OilS. bDT LU. LDT -999. 250 LL. LDT SS?. I,DT -990,250 I,SHV 29-0CT-1992 09:50 -999.250 TMNS.NGT -999.250 HTE~t.ffGT -999'250 ~TE~.CSG 2.443 2.936 0.000 4~,500 4428..000 -9g9,~50 -999,250 -999,250 -999.~50 -999.250 '999,250 '99~ 250 '999 250 '999 250 -999 250 -999 250 -099 250 :999,250 999,~50 2.479 2'930 0.000 45.2!9 4192 000 -999!~50 -999 250 -999.250 -999.~50 -999,250 -999.250 -999.250 -999.250 -999.250 -999.~50 '999,250 '999,250 -999.250 -999.250 -990.~50 2.307 2.~38 0.000 ~5.750 -~99.250 -999.250 :q99.250 99n.25o I L~, gTE IgPH, DTE C I DP. DTE IIR~.DTE aTEM.DTE RHOB.LDT QSS.bDT L!TH.LDT SSMV.LDT CALI.LDT MTE~.bDT TNPH,C~b RCFT,CNb CGR.CNL MTE~,CNb TBOR,MGT W2NG,MGT TEN$,MGT HTEN.NGT MTEM.CSG IL~,DTE I~P8,DTE CIDP.DTE IIR~.DTE MTE~.DTE R}IOB.LDT OSS,LDT LITM.LDT SSHV,LDT CAL!,LDT ~TEM,LD? TNPH.CNb ~CFT,CNb CG~.CNb MTE~.CNL THOR.~GT TENS.NGT HTEN.~GT ~TE~.CSG !LU. CIDO. I!RU. QSS. LITH. S5~V. DTE DTE DT E DTE DTK b D T bDT LDT 999,!250 999.250 999.250 ~..797 2.789 340,500 332.500 128 ~75 -999:50 -9992:i~59 999 50 :9 o: so -999.250 -999.~50 -~99 ~50 -9992:50 -999 50 '999:~50 '999 -999~250 -999 -9991250 -999,250 2.840 2.836 341 000 3271500 127 813 999.250 -999.250 -999.~50 :999,250 990.250 999.250 :999.250 :999.250 999.250 999.250 2999.250 1999.250 999.~50 2.652 2.660 352.000 350.250 !26.438 -999.250 -999.250 -999.250 -999.250 MTEM.NGT TE 'CSG tLD,DTE IFRE.DTE CI~P.DTE SGR.DTE ~RKS.DTE DRanO,bDT L$.bDT $$I.LDT $~RH,LDT SGR.LDT ~RE$,LDT TMRA.CNL CNTC,CNL C~LI.CNL HTEM,C~L POTA.NGT W3N~.NGT ~TEM,NGT SG~.CSG HTEN.CSG ILD DTE CI~P.DTE SG~,DTE ~RE$.DTE DRHO,LDT LS.LDT SSi.bDT $1RH.LDT SGR.LDT M~ES.LDT TMRA.CNL CNTC.CNL CALI.CNL MTEN.CNL POTA.NGT W3NG.NGT ~TEM.NGT SGR.CSG HTEN.CSG ILD.DTE IFRF.DTE C!~P.DTE S~R.DTE ~RE$.DTE DR~O.LDT L$.LDT S$1.LDT S1R~.LDT '999,250 '999'250 '999,250 2'9~2 20 o00 358 25O 98 395 I O3O -999,250 -999,250 -999,250 :999,250 999,~50 ~999,250 999.250 '999~250 '999 250 '999 250 '999 '999 ~50 '999 250 '999 250 '999,250 2 902 201000 352 500 95 686 99~'020 - .250 -999 250 1999:250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 2999.250 999.250 -999.250 -999.250 2 801 2o:o0o 375,750 97.2~9 1.020 -999,250 -999.250 -999.250 -999,250 his Tape Verification Listing ~cbl,3mberger AlasKa Computing Center LS~.LDT -999.250 L[IR'~. LOT CG~ LOT -999.250 TE~.iS. bDT MT E~': L[JT -{~99,250 ~PH I.. C N L ~,IPO~. C:~L -999. 250 RCN'T. CFTC. C~!L -999. ~50 T~S.CNI, -999. 250 ~RES.CML U~h5~ MGm -999,250 W1NG,NGT W4NC:NGT -999.250 WL~;~G' MGT MPES. ~GT -999. 250 CS. NGT TENS.CSG -999.~50 ~RES.. CSG DEPT. 6700.000 SFLU.DTE SP'DTE -89.250 IDOH.DTE IDO~.DTE. 0.000 !~QF. DTE !~RD.DT~ 290.500 IIXD.DTE CG~ riTE 88,741 TENS. DTE HTE~.;. DTE 9~,9. 000 DPH~, I.,DT PEF'L[)T -999. P5(} OLS. LDT :DI -999 250 LL LDT S8~.LDT -999:25() [~SHV:LDT LSR~.bDT -999.250 LU~H,LDT CGP. bDT -999. ~50 TENS. bDT HTE~,LDT -999.~50 UPHI.CNL MPO~,CNL -909,250 RC ~T.CNL' , CML -999,250 SGR, CWT', ..... C}Ob TEMS.CNL -999.250 MR~]$.CNL SG~ MGT -999 250 CGR NGT ~.... NGT -999.250 W1NG:NCT w4MG.NGT -999.250 WLNG NGT ~RES* NGT -909,250 CS: NGT TF~$, CSg -999.250 ~RES,CSG DFPT 6~.00 00(, SFI,U DTE IDQF:DTE 0.000 IM~F.DTE I!RD.DTE 307.250 IIXB.DTE CG~.DTE 64.1.~7 TENS,DTE HTEN. DTE 929. 500 DPHI, BDT DEF. LDT -99~. 259 OLS. LDT LU.bDT -990. 250 Lb. L!')T SS~.!.DT -999.250 !.,SUV. I~DT bSN~.LDT -9q9.250 L[~RH.LDT CG~.LDT -999.250 TE~}S. LOT HTEM.LDT -999.250 HPHI.CMI. ~PO~. Cb~I< -°~9.250 ~CNT.CML CFTC. CML -999. 250 SC~. CML TwMS. C~.L -909. 250 MRES. CNL SGP.~GT -909.250 CCR .~(,T [..~ R g ~. NGT -909. 250 ~t4G.NGT -999.250 WSNG.NGT ~'~P~]S. k~GT -999. 250 CS. NGT TVqR.CSG -990.250 ~4RES.CSG 29-0CT-1992 09:50 ~99 25O 99 50 .,99~50 -999,250 -999.250 -999 250 -999 250 -999 -999 250 -999 250 2.559 2.879 0,000 49.625 4428.000 -q99'250 -999.~50 9:99,250 999, ' 999,~ 0 0 999,250 999,250 -999.250 -999'~50 -999.250 -999.250 -999.250 -999.~50 -999.~50 2~ 0.000 55.188 4200.000 -999.250 -999.~50 -999.250 -999.250 -999.250 -99~.250 -999.250 -999.250 -999.250 -999.250 -990.250 -999.~50 -999.~50 -999.250 -999.250 CAbI.LDT ~ ~ LDT , .TE~4, T~i P H. CN L RCFT,CML CGR,CNb ~TE~'CNb THOR.MGT W~MG.NGT HTEN.NGT ~TE~.CSG ILM.DTE I~PH.DTE CIDP.DTE IIR~.DTE MTE~.DTE RMO~,LDT OSS,bDT L~TM.LOT SSHV,LDT CALl.bDT ~TE~,LDT TMPH.CNL RCFT.CML CGR.C~b MTEu. C~L THO~.NGT W~3G.~GT TE?S.~GT HTE~.MGT ~TE~,CSG -999 ~50 -999:50 -999 50 -999 50 -999 !50 -9991!50 -999 5O -999 ~50 -999:50 -9991250 2.744 2.771. 347.250 338.750 I26.188 2999.250 999.250 -999.250 -999'~250 999~250 -999250 -999.250 -999.:250 -999 ~50 -999~50 -999 250 -999:2so 2 592 369,250 358.250 ~24,625 .99.250 99:250 999.250 99~ 250 999,250 -999.250 -999,250 -999.250 -999.~50 -990.250 -999.250 SG~,LDT ~RES.LDT TMRA..CMb CNTC.CNL CALf'CML HTEN.CNL POTA.NGT w3NG,NGT ~TEM'NG~ SGP.CSG HTEN'CS~ ILD.DTE IFR~DTE ClM :DTE SGR.DTE M'RES,D'TE DRHO.LDT SSI'LoT $1R~,LDT SGR.LDT MRES'bDT ~'C~b CNTC,CNL CaLI.CNb HTEN.CNb POTAN~T MTE~,NGT SGP.CSG HTEN.CSG ILD.DTE IFRE.DTE CIMP.DTE SGR.DTE ~RES.DTE DR~O.LDT L$.LDT SSI.LDT SI~M.bDT SGR.LDT M~ES.LOT CNTC.CNL CA!..I.CNL HTEN.CNL POT~.NGT w3NG.NGT ~TE~.NGT SGF.CSG HTKN.C$~ PAGE: 23 -999,250 -999'250 999'~50 -999,250 -999.250 2999;~so 999'250 -9991250 -999'250 -999'250 2.859 20'000 360.1500 99 88 i999.250 999'~50 999,250 999.250 999'250 999.250 -999 25 -999..250 '999ii50 -999 ~50 -999 50 -999 50 -999 50 -999.~50 2,684 20.000 384.500 102.169 1.062 '999,250 '999,250 '999,250 '999,250 '999,250 '~99,250 '999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 bi8 Tare Verification L,!$t:i. no 5chlUmberoer ~lasKa Comput.!nO Cent.r DEPT. 6500,000 SFI..,!J, DTE "~ DTE -92 688 !DPEX. CGP [)TE 70,500 TEMe DTE ~TEM. DTE 926,000 [)P~'!, bDT DEF, !.,D'P -999,250 QLS, bDT LU, bDT -999,250 I..~h, bDT SS~,LDT '999,250 LSHV,LDT I, SRH. bDT -999,250 LURH.bDT CG~.bDT. . -q99. ,~50 TEMS,LDT ~TE~f,LDT -999,250 NPO~ CMb -999 250 PCMT,CNL C~T~'CNb .q~o' ' . 250 ~ "': .~ ...... · ..... . oGR. CNL SG~. NG'.r -999. ~0 CG~ URAM ~GT -999 250 ;ql~t:G , NG -999 ' ...... . .250 WSNG NGT T~NS~CSC -999.250 MRES,CSG DEpT, 6400.000 ~FL[.t' DTE SP PTg -95,375 IDPH. DTE 'I:D(~?~ DTE 0,000 tMOF. DTE I!~D.DTE 248.750 IIXD.DTE CGP.DT~ 7R,1.~9 TENS.DTE NTE~7. DTE 921,500 DPMI.LDT PEF. b[)~ -999,250 OBS.. L!J, bDT -909,250 Lb. bDT SS~.LDT -999.250 LSHV.bDT LSR~.I~DT -999.z~0 LU!~H. LDT CG~.bDT -999 25~, TEuS LDT ~TE~. 1.1)~ -999. 250 NPHI. C~L N. POm.CNL -999.250 RCNT.CNL C~TC,CNL -999.250 SGR CNL TFt'iS. C~ L -999.250 ~RES~CNL 2.0 CGR F(;T URa~.NGT -999.250 WlNG,NGT watlC.NGT -999.250 WhP~G. PGT ~RE8. MGT -999,250 CS. hGT TM~IS.CSG -9~9.250 ~aRES.CSG DFPT. g.30O. 000 SFI,[}. DTF; SP. DTE -94. 063 IDPH. DTE IDOl. DTE 0. 000 I~QF. DTE II~D.DTE 3~ ]. 250 IIXD. DTE CGP.D.cE 54.095 TENS.DTE }ITF~. DTF 85~.500 DPHI.LD~ P~F. bDT -999. 250 (~Lg. bDT bU . [~DT -9~9. 250 Lb. bDT gS?.LDT -q99.250 LSHV.LDT !~8R~. bDT -909. 250 I~[IRH. I. DT CGP. LDT -999. 250 TE~JS. LDT HTEN.LDT -qqQ.250 NPHI.C~.;L 29-0C'T-t 992 09:50 1,590 !,499 0.000 i05,!25 ~!6,4.000 999.~50 -999.250 -999.250 -999.250 999,~50 999,250 999,~50 -999.250 -999.250 -999.250 -999,~50 -999,250 -999,~50 -999'2 0 3.771 0 0 4 188 415~ 000 -999.250 -999.250 -99g,250 -999.250 -999.250 -999.~50 -q99o250 -999.250 -~99.250 -999.250 -099'250 -999,250 -999.~50 -999.250 -999.250 2.~4 2.555 0.000 49.469 3924.000 -990,~50 -999.250 -999.~50 -99~ ~50 -999.250 -999.~50 IL~.DTE CIDP.DTE I!R~.DTE MTEM,:DTE RHOB.LDT OSS,LDT LITE.bDT SSHV.LDT CALI,LDT ~TE~.b~T TNPH.CML RCFT.CNL CG~.CNb ~TE~,CNL TMOR,NGT W2NG,~GT TE~!S'NGT HTEN,MGT ~TE~,CSG ILa,DTE I~PH,DT~ CIDP,DTE IICU.DTE ~4TE~,DTE RHOB,bDT O$S,LDT bIT~,bDT SSHV,LDT CAL!,I.,DT ~TE",LDT ~MPH,CNL RCFT.C~b CGR,CNL MTE~,C~L TgOR,NGT W2NG.NGT TEN$.NGT HTEM.WGT ~TE~.CSG IL~.DTE I~lPE. DTE CIDm. DTE II~.~t. DTE ~HOg, LDT ~SS.LDT LITE. bDT SSHV. bDT CAL [. bDT ,~ TEt~ LD'r T~IPH, CNb I 380 65 000 12'313 -999.250 -999'250 -999,~50 -999.~50 -999.~50 -999.250 -999.250 2999,~50 -999.250 -999.250 -999':250 -999,~50 3,467 3'572 287':750 269 500 -999.250 -999250 -999:~50 -999.250 -999.250 -999.250 -999 250 -999~250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.~50 -999.250 2.363 2.381 391.250 391.750 122.875 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 ILD.DTE IFRE,DTE CIMP DTE ~RES.DTE DRHO,LDT LS.LD; SSi,hD' 81RM.hDT S~R.bDT MRE$.bDT T~RI,Cffb C~TC,C~h CAL!,C~L SG~.CSG HTE~,CSG !bD,DTM IFRE,DTM Ci~P,DTE SGR,DTE MRES,DTE DRWO.LDT bS,LBT SSI.bDT SGR,LDT M~ES.LDT TNRA.CML CMTC.CNL CALI.CML HTEN.CNL POTA.NGT W3NG.NGT ~TEM.NGT SGR.CSG HTEN.CSG IbD.DTE IFRE.DTE CI~P.DTE SGR.DTE ~RES.DTE DRHO.LDT LS.LDT SS~.LDT S!RH.LDT SG~.LDT ~RES,LDT ?~.CNL PAGE: 24 000 714,500 93.614 1. 077 '999 250 '999 250 -999 250 -9~ 250 '9 290 -999 250 -999 250 -999 250 -999 250 -9 2:50 -999 250 -999 250 :99 250 3 422 20~000 270.750 , 81 -999,250 -999,~50 -999,~50 -999,250 -999,250 -999,250 -999,250 -999,~50 -999,250 -999,250 -999,250 -999,250 -999,250 -999,~50 -999,~50 2 516 20~000 419.750 74.560 1.157 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 bis Tane Verifi. cat.ion Listi. nq ~chlumberger Alaska Comr~uttnq Center NPOR,CNL -999.250 RCNT. CFTC, CNL -999,25!3 SGR. T~TNS,CNL -999.~50 $G~, NGT -999, ~50 CGR. U~N" NG.T -909,250 N4NG ~ttiT -999,250 WStlG ~RES, MOT -909. 250 T~M'S, CSG -999,~50 CN b C~L CNL NGT NGT MGT CSt DTE BTM OTE LOT bDT L~T bDT LPT CNL C~L NOT MOT NGT CSG DTE DT~ DTE LDT bDT LDT LDT LDT LDT C~L CNL C~L NOT NGT NGT NCT CSS DT L DEPT. 6200.000 SFLU. SP.DTE -999,250 IDOF,DT.E -999,250 I~OF, IIRD,DTE -999.250 IIX{'), CC~, DT~ -999,250 TEN'S, MTE~. DTE -999. 250 DP'HI, ~T -909 250 OhS PEF, L[ ..... ' !..SRH,LDT -999,~50 CGR,LDT -999,~50 TENS' HTE~,' . LDT -999,250 MPOR C.,~[, -999 2~(') PCNT, C~TC, CNL -999,250 8GR, TENS,CNL -990,250 SGR, NOT -999, ~50 CGR, i..iR A ~. MGT -999,250 WING, W4NG,NGT -999,250 W5NG, ~P~.~. NGT -9q9. 250 TENS'CSG 3974.000 MR~$. D~PT. 6100 000 SFL~ SP..T~ -999'.25o ......... ~DP..' IDQF,DTE -999,250 I~OF. IIRD.I)~ E -999,250 CGm, DTE -999. 250 TENS. ~TEN,DTE -999,250 DPH!. P~F, LPT -999. 250 O..LS. [.,U. L[.'T -999,250 !..L, SS?.LOT -999,250 LSHV. LSPH. !_,DT -999,250 !,IJRIt. CG~, LDT -999,250 T~NS, HTEN.LDT -ggg,~50 NPNI. NP~P.CHL -999,250 PCNT. CFTC. CNL -999. 250 SGR, T~NS.CNL -999,250 SOP, NGT -9gg. 250 CG~. U,~AN. ~GT -999.250 WING. 'd4~)C. NGT -999,250 wMNG. ~PE$.NGT -909.~50 CS. IENS.CSG 39~4.000 29-0CT-1992 09:5n -999.250 ~CFT,CgL '999'250 CGR,CNL '999,250 gTEg,CNL -999,250 THOR,NOT -999,250 W~NG,~GT -999,250 T~$,NGT -099,250 HTE~,MGT -999.~50 ~TE~,CSG '99~.250 iL~'.DTE '99 .250 !~PH,DTE -099,~50 C!DP,DTE -999,250 IiR~,DTE :999:250 CALI,LDT 999 250 MTES.LDT 2999[250 TNPg,CNL 999.250 ReFT,Cub :999.250 CG[{,cNL :999,250 MTE~.CNL 999,250 THOR.NGT -999.~50 W2NG,NGT -099,250 TENS.NOT -999.~50 HTEN,NGT 1.128 ~TEN,CSG -999,250 IL~,DTE -999,250 -999.~5o 1999 250 99q:250 ~TE~ DTE -999,250 ~HOB,bDT -999,250 O$S,LDT -099,250 LITH,LDT -999,250 $SHV,LDT -99o,250 CALI,LDT -99q,250 MTE~,[,DT -999,250 TMPH,CNL -990.250 RCFT,CNL -~99,250 C~,C~L -9q9,250 -990,~50 -999,~50 -999,250 -99q,250 {.111 ~I~,CSG -99q.250 -999.250 -q99,250 CIDP,DTE -90o.250 -999,250 -999,250 -999,~50 -999,:250 -999,250 -999,250 -9991250 -999,250 i999.2509v9;25o 999.250 -999,~50 -099,250 -999,250 :999.250 999,250 -999.250 -999'.250 :999.250 999.250 999,250 999,250 -999,250 2999.250 999.250 1.20,918 -999,250 -999,250 -999,250 -999,250 -999,250 -999 250 -999:250 -999,~50 -999,250 -999,250 -999,250 -999,250 -999.250 -ggg 250 -999.25O -999.~50 -999,250 -999,250 121.125 -999 250 -999 250 -999:~50 CNTC.CNL CALiI,CN:L MTEN.CNb POTA. NGT ~TEM, NGT SGR,CSG HTEM,CSG ILD,DTE IFRE,QTE C!MP.DTE SGR.,DTE gRES,DTE D~H~.bDT [.S LDT SS I. ~ LDT S1RH,LDT SGR.LDT RES, bDT TNRA ,CNL CNTC,CNL CALI,CNL MTEM CNL 'WSNG,NGT ~TEM',NGT HTEN SG !F~E,DTE CIMP,DTE SG~.DTE N~RES,DTE DRHO,LDT LS,bDT SSi.bDT SG~,LDT MRES,LDT TNRa,CNL CNTC,CNL CALI,CNL HTEN.CML POTA,NGT WS~G.NGT ~TEM,NGT SGR .CSG HTEw.CSG ILD.DTE IFRE,DTE CI~P.DTE SG~. DTE PAGE: 25 '999,250 '999,250 '999,250 '999,250 '999'250 -999,~50 '999, 50 '999,250 -999,250 :999'250 999,~50 -999,250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 66 423 833 000 -999,250 -999,250 -999.250 -999,250 -999,250 2999 250 999:250 -099,250 -999.250 -999,250 -999,~50 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -99q,250 65,221 831,500 -999,250 -999,250 -999,250 -999,250 'IS Tame Verification Listlno 5cb!umberqer alaska Computino Center CG~.DTF -999.2~0 TCNS'DTE HTEN, DT~] -9~9 250 DPHI. [,DT LDT .9 9 250 Ob,S. LU. LDT -ggg. 250 I..,!,, LDT MN2 LDT 999,250 L~NV,bDT CGP.LDT -999.250 ~NS'LOT HTEN' LDT -999. 250 NPMi'CNb NPO~,CNI -999,250 ~CNT,CNL C~'TC.CNL -go9, ~0 oGR.CNb TENM.CN~ -99q,:~50 MRES,CNb SGP,NGT.. -999,250 ' CGR,N W4NG,NGT -999,250 W5N(;'NC~ ~ES. NGT -999, ~50 CS. ~JgT TEN8,CS6 3934.000 MRES.CSG 9oo. ooo sr ,,u DTE SP:DTE :999,250 IDPH:DTE IDQF'DTF 999,250 !MeF UTE IIRP,DTE -999,250 IIXD:DTE CGP,DTE -999,250 TENS,DTE HTEN,QTE -999,250 PEF, bDT -999,250 QLS, I~DT L U, L 0 T - 999,25 n b b. b b T .s2 Lt) 9U9 25O CGm. I,DT -999. 250 TEIN5. bDT bTEN, LDT -999, 2~0 ~PHI,C~b NPn~ C ~,.~ L -099.250 PCNT,CNL CFTC, C.~L -999,250 8GR.CNb TENS,CNL -9o9,250 MRES,CNb ,:.. GP, NGT -~99,250 CGR, {~R,~~ N~T -9~9.250 W! NG.~G~ W4NC.NGT -999.25o W5MG,NGI PRES. NGT -999. 250 CS. NGT T~NK.CSC 39~ ~, 00() "RES. CSG DEPT. 5~00.000 SFLU.DTE SP.DTE -990,~50 IDPH,DTE IDOF. f)TE -999,250 I~OF.DTE IIRD.DT~ -9~9.250 IIXD,DTE C~.DT~ -099.250 TE~iS.DTE HTEN.DTF -999.250 DPHI.LDT PFw. bDT -q 99.250 0 l_,$. 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TFNS,CNL -999.250 MRES.CNL SGR.~;,GT -999. 250 C6~. ~,~GT I)RAN.NC~ -999,250 W'l~,~(: ~GT 29-f')CT-1992 09:50 -9.99,250 -999.250 -o99,250 -999 250 -99~250 -999,~50 -999,250 -999 ~50 -999 ~50 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 ~50 1.~15 -999,250 -999,250 -~99,250 -999,~50 -999,250 -999,250 -999°~50 -999,250 -999,250 -999,250 -999.~50 -999.250 -999,250 -999,250 -999,250 -999,250 -999,~50 -999,250 -Q99.250 ~,125 -999,250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999.~50 -gq9.~50 -999.250 -~99,~50 -999,250 -999.~50 -99~.250 -999.250 -999.~50 ~TE~,DTE QSS,LDT LITH,LDT SSHV,LDT CAL!,LDT ~TE~,LDT TNPH,CNL RCFT,CNL CGR,CNL MTE~,CNL THOR,NGT W2NG,NGT TENS NGT ~TE~,CSG IL~,DTE IMPH,DTE CIDP,DTE IIRM.DTE MTE~,DT~ RHOB,bDT OSS,bOT LITH,LDT CALI,LDT UTEM,LDT TMPH,CNL RCFT,CML CGR,CNb MTE~,CNb THOR,NGT W2NG,NGT TENS,NGT HTFN.MGT ~TEM,CSG ILM,DTE IMPH,DTE CIDP,DTE IIWM,DTE MTEU,DTM RMOR,LDT OSS,bDT LITH,bDT SSHV.LDT C~LI,LDT ~TEM,LDT TNPH,C~L RCFT,CNL CG~,CNL THOR,NGT -999~50 -g99~ 50 -999 .50 -999 0 -999 ~50 -99 2 5o -999 !50 -999! 5.0 -999150 -999.250 -999250 -999~250 -999,~50 '999,250 121,125 -999 ~50 -999 50 -999 250 -999 250 -999 250 -999250 -999 ~50 -999 50 -999 250 -999 250 -999,~50 -999 ~50 -999 ~50 -999 250 -999 250 -999 999,250 -999,~50 ~20.938 -999,250 -999,250 -999,250 -999,250 -999 250 -999125o -999,250 -999 250 -9991250 -999,250 -999.250 -999.250 -999.~50 -999,250 -909.250 -999 250 -999:25o ~iRE$,DT£ DRHO,LDT LS,LDT $81LDT SGR,LDT ~RES,LDT TNRA,CNL CMTC,CNL CALI,CNL HTEN,CNL POT~,NGT W3NG,NGT MTEM,NGT SGR,CSG HTEN.CSG !I,D.DTE !FRE,DTE CIMP.DTE SGR.DTE MRES,DTE DRH~.LDT bS,LDT SSI,LDT SIRH,LDT SGR,LDT MRES,LDT TNRA,CNL CNTC,CNL CALI,CNL t' ' CNL .{TEN, POTA,NGT ~3NG.NGT MTE~,NGT SG~,CSG HTE~,CSG ILD.DTE IFRE.DTE CIMP,DTM SG~.DTE MRES.DTE DRMO.LOT L$.bDT SS1.LDT S]R~.LDT SG~.LDT ~RES.LDT TN~A.CNI, C~TC,CNL CALI.CNL HTEN.CNL POTA.NGT ~3~G.NGT PAGE: 26 '999,250 '999,250 '999 250 '999 250 '999 '999 ~50 '999 ~50 '999 '999,250 '999 250 '999 '999 '999 250 50 758 866.500 -999 250 -999:250 -999,250 -999'250 -999,~50 -999,250 -999,250 -999,~50 -999,~50 -999,~50 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,~50 -999,250 60.150 871'500 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,~50 -999,250 -999.250 -999,250 -999,~50 -999.250 -999.250 lis TaDe Verlf.icat~on ~chlumberc~er Alaska Computinq Center W4N~.MGT -999,250 WS~G,NGT ~ES.~Gt -999.~50 CS,NgT TEN$,CSG 3994,000 ~RE$,CSG D~PT, 5700,000 SFLU,DTE SP,OTE -999,25o IDPF!,DTE IDOF,DTE -99~,250 IIRD,OTE -999,250 IIXD,DT CG~,DTM -999.25© TEN$,DTE N?E~.DTE -9~9,250 DPMi,LDT P~jF, bDT -999,250 ObS, bDT bU, bDT -999. 250 [,L,o bDT S$2,LDT -999.250 LSR~.LDT -999,250 LUR!I,LDT CG~,LDT -999,250 TEN$,I,DT RT~'.LDT '999,250 NPN~,CN.L NPOP,CNL '999.~50 RC~T,CNb CFTC,CNL '999,250 SGR,CNL "F~qS C~I., -99q,250 ~RES,CNL SG~.NGT -999.250 CGR,NGT UPAN.NGT -999,250 WlNG.NGT W4N~,NGT -999,250 W5NG,NGT M~ES,NGT -999,250 CS,NGT T~N$,CSG ]904,000 DMPT 560(').000 SFLU DTE SP~DTE -999,250 I..Pd IDOW'If) E 9~9,250 !~Or DTE !IRD,DT~ -999,250 IIXD,DTE CG~,DT~ -909,250 TENS,DTE }-]TE~.DTE -999.250 DP~ I. !..,DT PE~, [.DT -999,250 QL$, bDT bU, bDT -909, ~50 Lb, bDT S$~,LDT -999,250 [~SHV,]~DT LS~g,LQT '999,25() LURH,I, DT CG~.LDT '999,250 TENS.LOT ~{TEN.LDT -999,250 MP~I,CNb ~PO~,C~L '999.250 RCNT,CNL CwtC,CML '999,25C SGR,CNb SG~,MGT -999.250 CGR,NGT U~a~,NCT -9~9.250 WlNG,~!GT W4HG.NGT -999.25C WSNG.NGT ~E$,NGT -999.250 C$.NGT TE~S,CSG 3774.000 DEPT. 5500.000 SF!,!I.UTE SP.DTE -999,250 IDPH.DTE IDQV.~TE -99Q,250 I~OF,DTE II~D.~TW -999.~50 II×D.DTE CGR.DTE -9q9,250 TENS,DTF; ~TFM.DTE -999.250 DPMI.LDT P~F.L[)T '999.250 QLS.LDY LU,LDT -999.250 Lb. 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Center NPOP,CNI, -999.250 RCNT,CNL CFTC,CML -999,250 TFNS,CNL -999,250 ~RES.CNL SGR,NGT -999,250 CGR,NGT [{PA~!,NGT -999,250 W4NG,NGT -999,250 WLNG,~GT ~E~,NGT -999.250 C$,NGT TENS,CS~ ~.925,000 ~RES'CSG DEPT 1.000 000 SFLU,L SP ;DTE 9991250 IDPg I I Rn . DT~ -9o9. 250 'l XTM ~T ,.. . ..~ ~ · CG~, D T ...~ -999,250 TENS, HTEN,DTE -999,250 DPHI,LDT PEF LD:T -999,250 r e LU, LDT -999,250 L!], LDT SS~,LDT -999,250 LSHV,LDT LSPH,LDT -999,250 LURH,LDT CG~.LDT 999.~50 TEJS LDT ~TE~.LDT -999.250 NPHIiCNL NPO9, C~.!L -999,250 RCNT.CNL CFTC,CML -999,250 SGR,CNb T~NS,C?~L -999.250 mRES,C~L SGP.NGT -999,250 CGR. NGT _ , . 25~ WING GT riPeN NGT .999,~ (' . W4NG,NGT -999,250 WLNG,NGT ~'RES. NGT -999,250 CS, U'GT T~NS,CSG !900,000 MRES,CSG DEPT, 992,000 SFL!!,DTE SP,DTE -999,250 IDOF.DT~ -~99,250 I~OF,DTE IIRD,DT~ -0~9,~50 IIXD.,DT~ CG~,DTE -999.250 TENg,DT HTEU.DTE -999.250 DP~I.bDT PEF,LDT -999,250 QLS,LDT bU,LDT -999,250 LI~,LDT gSa,bDT -999,250 LS~V,LDT LS~M.LDT -9~9,~50 LU~[t,LDT CG~,LDT -999.250 TEMS,I.,DT MT~,T:DT -999,25C NP~I,CNL ~JPO~,CNL -999,250 RCNT,CN!.. CFTC.CML -999,~50 SGR,CNL T~N$,CNI, -999,250 SGP.NGT -9~9.250 CGR.NGT UP~N.NGT -999,~50 W~G,NGT W4NC.NGT -999,250 45NG.NGT M~ESe~GT -999.250 TENS,CSG J. 8~5,00¢) uRES.CSG ** END OF DATA ** 29-0CT-!992 09150 -999,250 RCFT,CNL -999,~50 CGR,CNb -999,2~0 MTE~,CNb :9~0,~50 T"OR.~GT 9 ~, 50 W2NG'NGT ~.ENo,NGT ~999,250 ~e 999.250 HTEN'NGT ~,677 ~TF~M,CSG -999:250 iIR~!,DTE :990 250 MTE~,DTE :999,250 OS$,LDT 999,250 LITM,LDT -099.250 SS}{V bDT -999.250 CAbi:LDT -999,250 MTE~,LDT -999.~50 TNPM,CNL -999 250 RCFT,CNb -999[250 CGR,CNL -999,~50 -999,250 THOR,NGT -999,250 W2NG,NGT -999,250 TENS,NGT -~99,25£ HTEN,NGT ~ 693 ~"'~' CSG , ,, ~E~, . -999,250 -999. 250 IMPH,DTE; -999.250 CIDP,DTE -909 250 II~U,DTE -099;250 -999,250 RH[]6.bDT -999,~50 OSS,LDT -999.~50 LITM,LDT -999.250 SSMV,LDT -999,~50 CALl,bDT -999,250 }~{TEM, bDT -999.250 TNPH,CNL -999.250 RCFT.CNL -999.250 CGR,CNL -999,250 MTE~,C~b -999.250 T~OP,NGT -999.~50 W2NG,UGT -999.250 -999,250 HTr;q. F~GT ~ .6~9 MT~]~. CSG -999,2:50 -999:~50 -99~ 50 -999.250 -999,250 99.,~5 BB.000 -999 250 -999:250 -999°250 -999,~5~ .999,250 .999,2~0 999,250 -999,250 -999,250 -999,250 -999,250 -999 ~50 -999" .999 ,250 ,250 -999,250 -999 ~50 m999,250 87,6~5 999,250999,250 999,250 -999,250 -999,250 -999,250 -999,~50 -999,250 -999,250 2999.250 999.250 999, 0 -999.250 -999.~50 -999.~50 -999,259 -999,250 -999,250 87,625 CNTC,CNL POTA,NGT wBNG.NGT ~TEM,NGT SGR.CSG HTEN,CSG ILD.DTE IFRE,DTE ClPP ~TE SGR:DTE M~ES DTE DRH0!LDT L$ bDT SSI,bDT S1RH.LDT SGR,LDT ~R~S,LDT TNRA,CNL CNTC,CNL CALl,CML HTEN CMl, ~3~G.NGT ~TE~,NGT SGR,CSG HTEN.CSG !LD,DTE IFRE.DTE CIMP.DTE SGR.DTE ~RES.DTE I)RHO.LDT bS.LDT $S%.LDT S1R!I.LDT SGR,LDT ~RES.bDT TNmA,CNL CNTC,CNL CALl.CML HTEN.CNL POT~.~GT W~NG.NGT ~T~.NGT SGR,CSG HTEN.CSG PAGE: 45 -999,250 -999'250 -999,250 -999 250 -9992250 -999,250 42,566 1030.000 -999,250 -999,250 =999,250 -999.250 2999,250 ,999,250 ,999"250 .999'250 999,250 -999"250 -999,250 -999,250 -999,250 -999,250 -999'250 '999,250 -999,250 -999,250 32'933 1044,000 '999,250 -999,250 -999,250 -999 250 =999:250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,~50 -999,250 -999,250 :999 5O -999,250 4~,095 !030,000 : 3d~ ~OI. A2~d '~ ;# NOIi~Ni&NoD DIq~ : NID!~O ~O~IO0 : NOiSa3A DIq~ ~ ~DIA~9 9~ t39~d
