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Home My WebLink About193-0131. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Kill String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,603 feet N/A feet true vertical 7,407 feet 11,400 (Fill)feet Effective Depth measured 11,400 feet N/A feet true vertical 7,285 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 R2 3,012' 2,433' 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 324-110 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1000 0 00 0 0 Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 110' 380 Size 110' 4,588' 0 ADL0025509 / ADL0355017 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT L-11 Plugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-013 50-029-22336-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: Casing Conductor 11,590' 6,688'Surface Production 13-3/8" 9-5/8" 7" 80' 6,658' Length 6,870psi 7,240psi11,620' 7,418' Burst N/A Collapse N/A 4,760psi 5,410psi measured TVD N/A measured true vertical Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:37 am, May 29, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.05.29 09:44:28 - 08'00' Taylor Wellman (2143) DSR-5/29/22 RBDMS JSB 053024 WCB 8-28-2024 _____________________________________________________________________________________ Revised By: TDF 5/16/2024 SCHEMATIC Milne Point Unit Well: MP L-11 Last Completed: 4/17/2024 PTD: 193-013 TD =11,630’(MD) / TD = 7,424’(TVD) Orig. KB Elev.: 51.00’MSL 7” 9-5/8” 1 HOS-SE Cement Tool @ 1,902’ PBTD =11,492’ (MD) / PBTD = 7,341’(TVD) FISH: 4 Flat Guards and 3 Bands left in hole below perfs. 13-3/8” FCO to 11,400’ on 6/14/2009 FISH: Tandem Seals & Motor @ 11,030 MD. CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / BTRC 12.615 Surface 110' 0.1546 9-5/8" Surface 47 / N-80 / BTRS 8.681 Surface 6,688’ 0.0732 7" Production 26 / L-80 / BTRC 6.276 Surface 11,620’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE R2 2.441 Surface 3,012’ 0.00579 JEWELRY DETAIL No Depth Item 1 3,011.6’ WLEG -Btm @ 3,012’ OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of PF “C” in 30” Hole 9-5/8" Cmt w/ 1,750 sx Arctic Set III, 305 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 302 sx Class “G” in 8-1/2” Hole Note: Perforated 7” Casing w/ 9 shots @ 10,990’ to 10,992’ and squeezed 28 bbls class ‘G’ cement. Tested to 1,875psi WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 7” 5M WKM w/ 2-7/8” 8rd Treetop connection 2-1/2” Cameron type ‘H’ BPV Profile GENERAL WELL INFO API: 50-029-22336-00-00 Drilled, Cased & Completed by Nabors 22E – 6/20/1993 ESP Swap by Nabors 22E – 7/9/1993 ESP Swap – 4/26/1994 ESP Swap by Nabors 4ES – 5/3/1995 & 8/20/2001 ESP Repair by Nabors 3S – 3/7/2009, 6/16/2009 ESP Repair by Doyon 16 – 11/14/2012 ESP Swap by ASR#1 – 4/19/2018 Kill String br ASR#1 – 4/17/2024 FRAC DETAIL Frac’d w/ Total of 191,471lbs of 12-18 ISP 172,500lbs of 12-18 ISP behind pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/ B6 11,016’ 11,036’ 7,051’ 7,063’ 20 6/15/1993 Open B6 11,050’ 11,060’ 7,072’ 7,078’ 10 6/15/1993 Open B6 11,087’ 11,097’ 7,094’ 7,100’ 10 6/15/1993 Open A3 11,164’ 11,184’ 7,141’ 7,153’ 20 6/15/1993 Open A2 11,197’ 11,227’ 7,161’ 7,179’ 30 6/15/1993 Open A1 11,256’ 11,286’ 7,197’ 7,215’ 30 6/15/1993 Open A1! 11,336’ 11,346’ 7,246’ 7,252’ 10 6/15/1993 Open 12 SPF 5” Casing Guns Well Name Rig API Number Well Permit Number Start Date End Date MP L-11 ASR#1 50-029-22336-00-00 193-013 4/7/2024 4/18/2024 Install wear ring. L/D wear ring running tool. Remove ESP sheave from derrick. Secure & stow. Fishing tools on location. Tally & stage. Load racks with 3-1/2" Workstring. P/U 5-3/4" box tap fishing BHA. as per YJ rep. Box tap, safety sub (3000 lbs), bumper sub, oil jar, 6 x 4-3/4" DC Completed P/U BHA. Fill hole w/ 5 bbls. XO to 3-1/2 workstring. Continue trip in hole with fishing BHA T/10,898' pumping double displacement. DN WT - 42K Kelly up obtain parameters. P/U wt= 103k S/O wt = 55K. ROT P/U wt = 90k S/O wt = 40K. ROT TQ = 4500 lbs at 15 RPM. Trouble shoot torque issue on swivel. No operations to report. 4/6/2024 - Saturday Cont. POOH w/ 2-7/8" 6.5# L-80 EUE ESP completion f/ 7,255' P/U wt = 48K to discharge head. P/U wt = 1 K. weight is lighter than calculated. Observed ESP assy. parted at gas separator. Recovered discharge head, one pump. & .86' of the gas separator.( Recovered all ESP cable. Cable pulled out at motor). Notify OE & mobilize fishing tools. Clean & clear rig floor of ESP tools & disassembly equipment. Change elevators. Clear off pipe racks. P/U wear ring & wear ring setting tool. M/U XO. 4/9/2024 - Tuesday 4/7/2024 - Sunday P/U test tools. Blow air through fluid lines. Found suction line connection leaking. Replace 4" hammer union. Flood stack for shell test. Montior IA (static). Shell test completed. AOGCC rep waived witness of the BOP test. Test BOP's as per Sundry at 250 /2500 PSI f/ 5/5 charted mins. No failures. Perform drawdown test. Rig up to pull tubing. Hang ESP cable sheave & change elevators. Pull BPV. Pump 50 BBLS of 8.4 source water down the tubing, with no returns. IA, and tubing on a vacuum. Make up the landing joint with floor valve. BOLDS, pull tubing hanger to rig floor with 77K upweight. Cut the ESP cable and attach to rope to string to the spooler. Breakout & lay down the hanger. Continue POOH with 2 7/8'' ESP completion pumping 5 BPH, F/ 10,924'. T/ / 7,255' P/U wt = 48 K Fill well w/ 5 BPH of 8.4ppg source water. No returns. 4/8/2024 - Monday 4/5/2024 - Friday No operations to report. 4/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/4/2024 - Thursday No operations to report. Observed ESP assy. parted at gas separator. Recovered discharge head, one pump. & .86' of the gas separator.( Recovered all ESP cable. Cable pulled out at motor). Notify OE & mobilize fishing tools. Clean & clear rig floor of ESP tools & disassembly equipment. Change elevators. Clear off pipe racks. P/U wear ring & wear ring setting tool Test BOP's as per Sundry at 250 /2500 PSI f/ 5/5 charted mins. No failures. Load racks with 3-1/2" Workstring. P/U 5-3/4" box tap fishing BHA. as per YJ rep. Box tap, safety sub (3000 lbs), bumper sub, oil jar, 6 x 4-3/4" DC Completed P/U BHA. Fill hole w/ 5 bbls. XO to 3-1/2 workstring. Continue trip in hole with fishing BHA T/10,898' pumping double displacement Rig up to pull tubing. Hang ESP cable sheave & change elevators. Pull BPV. Pump 50 BBLS of 8.4 source water down the tubing, with no returns. IA, and tubing on a vacuum. Make up the landing joint with floor valve. BOLDS, pull tubing hanger to rig floor with 77K upweight. Cut the ESP cable and attach to rope to string to the spooler. Breakout & lay down the hanger. Continue POOH with 2 7/8'' ESP completion Well Name Rig API Number Well Permit Number Start Date End Date MP L-11 ASR#1 50-029-22336-00-00 193-013 4/7/2024 4/18/2024 Continue RIH w/ BHA#4 while filling DP F/ 9,893' MD T/ fish at 10,024'. Esblish parameters. Burn over fish down to 11,030'. Penetration rate stopped. Change parameters of pump rate, RPM's and weight on bit trying to get the burn shoe deeper. No Go. Current loss rate of less than 10 bbls/hr Discuss with OE, decsion to POOH. POOH T/ 3,320'. Fill BOP stack, fill and purge lines. Start again on the BOP test successfully as per the sundry testing to 250 / 2500 PSI. Test with 2 7/8'' and 3 1/2'' test joints. Peform successful draw down test. Witness of test waived by AOGCC rep - B. Bixby. Make up Fishing BHA #3, 5 3/4'' Ovsershot assembly with a 4 3/4'' Spiral Grapple. jars, and Drill collars. RIH w/ BHA T/ 2,212' MD while maintaining 1x displacement. 4/13/2024 - Saturday Continue OOH F/ 812'. Single displacement pumped. OOH w/ remaining portion of Gas Seperator and "Head" or top sub of the Upper Tandem Seal (1.68' oal). Make up the Fishing BHA #4 with 6.125'' Drag Tooth shoe, 1 joint of 5 3/4'' Wash pipe, jars,12- DC's and Float sub. RIH T/ 9,893' filling drill string with fluid. 5.75hrs NPT due to overheating generator, Carraige leak, and DPF filter replacement. 4/16/2024 - Tuesday 4/14/2024 - Sunday Continue RIH w/ Fishing BHA #3, 5 3/4'' Ovsershot assembly with a 4 3/4'' Spiral Grapple. jars, and Drill collars F/ 2,212' MD while maintaining 1x displacement. 1.5 BPM - 110 PSI. The well took 7.5 BBLS to fill . Observed the pressure increase to 170 PSI as we got over the fish. Picked up, observing 5-6K overpull and then fell off, with the pump pressure not falling off, and as we worked it back down we still saw 135 PSI on the pump, 1.5 BPM. Repeated fishing attempts, with no other overpull observed. Up weight - 90K, Down weight -53K. Each time we went back down, we tagged in the same place, and never agin any overpull. Fluid losses minimal while pumping. POOH T/ 812' 4/15/2024 - Monday 4/12/2024 - Friday POOH w/ BHA#2 - 6-1/8" Burn Shoe F/ 10,980' while pumping 1x displacement. 5hrs NPT due to DPF/DEF systems. LD BHA recovered 1.2' section of Gas Seperator. Prepare for BOP test. 4/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Rig down time, troubleshooting swivel torque indicator & 300 k gen issue. Cont. to RIH w/ Box tap BHA slowly. Tag top of fish at 11,019' Set 10 k on fish. Non ROT - P/U wt = 105K S/O wt = 42 k. Kelly up to pump & engage fish. Set dw at 11,019' ASR RKB. Set 10 -20k down working down to 11024'. Pump at 1 BPM w/ 70 PSI psi. Pump down T/ 11,024' Attempt to work past. Continue to set down on obstruction / fish with increasing weight & pump. Up to 2.5 BPM w/ 400 psi. Observed no significant increase in pump pressure when on top of the "fish". No torque increase either. Discussion with the OE, decision to POOH. Pull and lay down 2 jnts. Blow down lines. POOH with 3 1/2'' workstring from 11024' - 1300', pumping double displacement. 4/11/2024 - Thursday CONT POOH w/ 3-1/2" workstring & BHA#1 while maintaining 2x displacement. Leading edge of Box Tap missing ~.75" material, mushroomed inward. RIH w/ 6-1/8" Flat BTM Burn Shoe, Drive Sub, 5" Boot Basket, LBS, Oil Jar, 6ea Drill Collars. Bring pump on & catch returns after 12bbls away. Pump = 2.5bpm @ 415-430psi. Set rotation 80rpm / 3k torque / 66k rotating wt. Begin milling at 11,019' MD. Mill over ESP 3' to 11,022' pump varied 400-550psi. Dry tag with Mill. Blow down lines and prep to POOH. Continue RIH w/ Fishing BHA #3, 5 3/4'' Ovsershot assembly with a 4 3/4'' Spiral Grapple. jars, and Drill collars F/ 2,212' MD while maintaining 1x displacement. 1.5 BPM - 110 PSI. The well took 7.5 BBLS to fill . Observed the pressure increase to 170 PSI as we got over the fish. Picked up, observing 5-6K overpull and then fell off, with the pump pressure not falling off, and as we worked it back down we still saw 135 PSI on the pump, 1.5 BPM. Repeated fishing attempts, with no other overpull observed. Up weight - 90K, Down weight -53K. Each time we went back down, we tagged in the same place, and never agin any overpull. Fluid losses minimal while pumping. POOH Tag top of fish at 11,019' Set 10 k on fish. Non ROT - P/U wt = 105K S/O wt = 42 k. Kelly up to pump & engage fish. Set dw at 11,019' ASR RKB. Set 10 -20k down working down to 11024'. Pump at 1 BPM w/ 70 PSI psi. Pump down T/ 11,024' Attempt to work past. Continue to set down on obstruction / fish with increasing weight & pump. Up to 2.5 BPM w/ 400 psi. Observed no significant increase in pump pressure when on top of the "fish". No torque increase either. Discussion with the OE, decision to POOH Begin milling at 11,019' MD. Mill over ESP 3' to 11,022' pump varied 400-550psi. Dry tag with Mill. Blow down lines and prep to POOH Continue RIH w/ BHA#4 while filling DP F/ 9,893' MD T/ fish at 10,024'. Esblish parameters. Burn over fish down to 11,030'. Penetration rate stopped. Change parameters of pump rate, RPM's and weight on bit trying to get the burn shoe deeper. No Go. Current loss rate of less than 10 bbls/hr Discuss with OE, decsion to POOH Well Name Rig API Number Well Permit Number Start Date End Date MP L-11 ASR#1 50-029-22336-00-00 193-013 4/7/2024 4/18/2024 No operations to report. No operations to report. 4/20/2024 - Saturday No operations to report. 4/23/2024 - Tuesday 4/21/2024 - Sunday No operations to report. 4/22/2024 - Monday 4/19/2024 - Friday No operations to report. 4/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH w/ 6.125" Drag Tooth Shoe BHA #4 F/ 3,320' pumping 1x displacement. LD BHA. Recovered 6.3' - Upper Tandem Seal. RIH w/ 2-7/8",6.5#,L,EUE R2 (used) Pipe. Land Hanger, RILDS. Final EOT = 3,012' MD w/ ORKB. Release rig 18:00. 4/18/2024 - Thursday WELLHEAD: MU tbg hgr to 2 7/8 Eue LJ, PU and MU to kill string, Bpv pre set. Line up hgr to alignment pin, Land into profile RKB 18.' RILDS, BO alignment pin and puul LJ. ASR RD, BOP pulled, clean void and land tree/adapter. Torqe to spec, test tbg hgr void to 500/5000 5/10 min (PASS). Pull 2.5" Bpv with T Bar. All valve in closed position MU tbg hgr to 2 7/8 Eue LJ, PU and MU to kill string, Bpv pre set. Line up hgr to alignment pin, Land into profile RKB 18.' RILDS, 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 Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,630'11,400 (Fill) Casing Collapse Conductor N/A Surface 4,760psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 80' 13-3/8" 9-5/8" 7" 6,658' 11,590' MD N/A 6,870psi 7,240psi 4,588' 7,418' 6,688' 11,620' Length Size Proposed Pools: 110' 110' 6.5# / L-80 / EUE 8rd TVD Burst 10,960' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0355017 193-013 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22336-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/15/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-11 7,424' 11,400' 7,285' 2,190 N/A MILNE POINT KUPARUK RIVER OIL N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:15 pm, Feb 23, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.23 12:14:14 - 09'00' Taylor Wellman (2143) 324-110 DSR-2/26/24 BOPE test to 2500 psi. 10-404 *Well Completion Rpt dated 9/14/93 SFD 11,603' *,190 MGR27FEB24 2,, SFD 2/24/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 16:25:25 -09'00'2/27/24 RBDMS JSB 022824 Well: MPL-11 PTD: 193-013 API: 50-029-22336-00-00 Well Name:MPL-11 API Number:50-029-22336-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:4/15/2024 Estimated Duration:6 days Regulatory Contact:Tom Fouts Permit to Drill Number:193-013 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2887 psi @ 6,970’ TVD 12/20/2023 | 8.0 EMW 8.2 KWF Max Potential Surface Pressure: 2,190 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 58° Max Sail Angle at 7,800’ MD Brief Well Summary: MPU L-11 was drilled, fracture stimulated and completed as a Kuparuk River producer in June 1993. ESP installation history: June 1993 (initial), July 1993, April 1994, May 1995, August 2001, March 2009, June 2009, November 2012 and April 2018. The ESP failed Aug 2022. Objectives: Pull failed ESP completion, Test packer run, and run new ESP completion. Notes Regarding Wellbore Condition: x The 7” production casing was tested down to 10,800’ MD / 3,500 psi on November 12, 2012. Pre-Rig Procedure (Non Sundried Work) Slickline (Complete) 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from 10,893’ to surface. 4. Attempt to pull dummy valve from GLM at 10,748’ MD and leave open. 5. Pull GLV and set dummy valve in upper GLM at 140’ MD. 6. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) Well: MPL-11 PTD: 193-013 API: 50-029-22336-00-00 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is a 11” x 2-7/8”, with 2-7/8” EUE thread. b. 2018 ESP pull weight on ASR #1 84 kip to unseat hanger. Slack off weight on ESP Install recorded as 28 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Keep joints 1-64, 86-115. Based on counting only Full Joints from Caliper 12/20/23. Wash and toss the rest. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 182 ii. Protectolizers: 4 iii. Flat Guards: 2 10. Lay Down ESP. 11. Contingency:This well has never shown debris in the pull reports from 2012 or 2018 but if any solids are found during the pull plan to make a 7” scraper run to 10,850’ MD. 12. PU and RIH with 7” test packer to 10,800’ MD. 13. Test 7” casing to 2,000 psi for 30 minutes. 14. POOH with test packer. 15. RIH with re-use and new 2-7/8” 6.5# L-80 ESP completion to +/- 10,960’ and obtain string weights. a. Run in slow with the ESP from 1300’-1600’ MD as we have 4.6 degree DSL at 1407’ and 1503’ MD. b. Check electrical continuity every 1000’. Well: MPL-11 PTD: 193-013 API: 50-029-22336-00-00 c. Note PU and SO weights on tally. d. Install ESP clamps per Baker, and cross coupling clamps every other joint. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 4 3 Gas Avoider 52 4 8 Gas Separator 52 4 10 GINPSHL 45 4 57 Pumps – 3 Flex7 ER 45 4 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.505" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 10,490 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 16. Land tubing hanger. Use extra caution to not damage cable. 17. Lay down landing joint. 18. Set BPV. 19. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. Well: MPL-11 PTD: 193-013 API: 50-029-22336-00-00 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double Ram BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 5/8/2018 SCHEMATIC Milne Point Unit Well: MP L-11 Last Completed: 4/19/2018 PTD: 193-013 TD = 11,630’(MD) / TD = 7,424’(TVD) Orig. KB Elev.: 51.00’MSL 7” 3 4 7 & 8 9-5/8” 1 HOS-SE Cement Tool @ 1,902’ MIN ID= 2.205 @ 10,854’ PBTD =11,492’ (MD) / PBTD = 7,341’(TVD) 2 11 FISH: 4 Flat Guards and 3 Bands left in hole below perfs. 10 13-3/8” 5 9 6 FCO to 11,400’ on 6/14/2009 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / BTRC 12.615 Surface 110' 0.1546 9-5/8" Surface 47 / N-80 / BTRS 8.681 Surface 6,688’ 0.0732 7" Production 26 / L-80 / BTRC 6.276 Surface 11,620’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 10,960’ 0.00579 JEWELRY DETAIL No Depth Item 1140’STA #2: Camco 2 7/8 X 1'' Side pocket,W/Orifice 2 10,748’STA #1: Camco 2 7/8 X 1'' Side pocket,W/Dummy 3 10,860’ XN-Nipple: 2-7/8” HES (2.205 No-go ID) 4 10,902.97’ Discharge Head: GPDIS 5 10,903.48’ Pump: Type- 161P11, Model - SXD 6 10,925’ Gas Separator: GRS FER N AR 7 10,929’ Upper Seal Section: GSB3DBUT SB/SB PFSA 8 10,935’ Lower Seal Section: GSB3DBLT SB/SB PFSA CL5 9 10,942’ Motor: XP, 200HP / 3,635V / 34A 10 10,956’ Sensor: WellLift E 11 10,958’ Centralizer /Bottom @ 10,960’ OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of PF “C” in 30” Hole 9-5/8" Cmt w/ 1,750 sx Arctic Set III, 305 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 302 sx Class “G” in 8-1/2” Hole Note: Perforated 7” Casing w/ 9 shots @ 10,990’ to 10,992’ and squeezed 28 bbls class ‘G’ cement. Tested to 1,875psi WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 7” 5M WKM w/ 2-7/8” 8rd Treetop connection 2-1/2” Cameron type ‘H’ BPV Profile GENERAL WELL INFO API: 50-029-22336-00-00 Drilled, Cased & Completed by Nabors 22E – 6/20/1993 ESP Swap by Nabors 22E – 7/9/1993 ESP Swap – 4/26/1994 ESP Swap by Nabors 4ES – 5/3/1995 & 8/20/2001 ESP Repair by Nabors 3S – 3/7/2009, 6/16/2009 ESP Repair by Doyon 16 – 11/14/2012 ESP Swap by ASR#1 – 4/19/2018 FRAC DETAIL Frac’d w/ Total of 191,471lbs of 12-18 ISP 172,500lbs of 12-18 ISP behind pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/ B6 11,016’ 11,036’ 7,051’ 7,063’ 20 6/15/1993 Open B6 11,050’ 11,060’ 7,072’ 7,078’ 10 6/15/1993 Open B6 11,087’ 11,097’ 7,094’ 7,100’ 10 6/15/1993 Open A3 11,164’ 11,184’ 7,141’ 7,153’ 20 6/15/1993 Open A2 11,197’ 11,227’ 7,161’ 7,179’ 30 6/15/1993 Open A1 11,256’ 11,286’ 7,197’ 7,215’ 30 6/15/1993 Open A1! 11,336’ 11,346’ 7,246’ 7,252’ 10 6/15/1993 Open 12 SPF 5” Casing Guns SFD 11,603' _____________________________________________________________________________________ Revised By: DH 2/13/2024 PROPOSED Milne Point Unit Well: MP L-11 Last Completed: 4/19/2018 PTD: 193-013 TD = 11,630’(MD) / TD = 7,424’(TVD) Orig. KB Elev.: 51.00’MSL 7” 3 4 7 & 8 9-5/8” 1 HOS-SE Cement Tool @ 1,902’ MIN ID= 2.205 @ 10,854’ PBTD =11,492’ (MD) / PBTD = 7,341’(TVD) 2 11 FISH: 4 Flat Guards and 3 Bands left in hole below perfs. 10 13-3/8” 5 9 6 FCO to 11,400’ on 6/14/2009 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / BTRC 12.615 Surface 110' 0.1546 9-5/8" Surface 47 / N-80 / BTRS 8.681 Surface 6,688’ 0.0732 7" Production 26 / L-80 / BTRC 6.276 Surface 11,620’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±10,960’ 0.00579 JEWELRY DETAIL No Depth Item 1 ±201’STA #2: 2 7/8” X 1'' GLM, w/Orifice Valve 2 ±10,719’STA #1: 2-7/8” X 1'' GLM, w/Dummy Valve 3 ±10,777’ XN-Nipple: 2.313” HES (2.205 No-go ID) 4 ±10,829’ Ported Discharge Head 5 ±10,830’ Pump: 3 Flex7 ER 6 ±10,897’ Gas Separator 7 ±10,908’ Upper Tandem Seal 8 ±10,915’ Lower Tandem Seal 9 ±10,922’ Motor: 250HP 10 ±10,956’ Intake Sensor 11 ±10,958’ Centralizer / Bottom @ 10,960’ OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of PF “C” in 30” Hole 9-5/8" Cmt w/ 1,750 sx Arctic Set III, 305 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 302 sx Class “G” in 8-1/2” Hole Note: Perforated 7” Casing w/ 9 shots @ 10,990’ to 10,992’ and squeezed 28 bbls class ‘G’ cement. Tested to 1,875psi WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 7” 5M WKM w/ 2-7/8” 8rd Treetop connection 2-1/2” Cameron type ‘H’ BPV Profile GENERAL WELL INFO API: 50-029-22336-00-00 Drilled, Cased & Completed by Nabors 22E – 6/20/1993 ESP Swap by Nabors 22E – 7/9/1993 ESP Swap – 4/26/1994 ESP Swap by Nabors 4ES – 5/3/1995 & 8/20/2001 ESP Repair by Nabors 3S – 3/7/2009, 6/16/2009 ESP Repair by Doyon 16 – 11/14/2012 ESP Swap by ASR#1 – 4/19/2018 FRAC DETAIL Frac’d w/ Total of 191,471lbs of 12-18 ISP 172,500lbs of 12-18 ISP behind pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1/ B6 11,016’ 11,036’ 7,051’ 7,063’ 20 6/15/1993 Open B6 11,050’ 11,060’ 7,072’ 7,078’ 10 6/15/1993 Open B6 11,087’ 11,097’ 7,094’ 7,100’ 10 6/15/1993 Open A3 11,164’ 11,184’ 7,141’ 7,153’ 20 6/15/1993 Open A2 11,197’ 11,227’ 7,161’ 7,179’ 30 6/15/1993 Open A1 11,256’ 11,286’ 7,197’ 7,215’ 30 6/15/1993 Open A1! 11,336’ 11,346’ 7,246’ 7,252’ 10 6/15/1993 Open 12 SPF 5” Casing Guns Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Nolan Vlahovich Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/5/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: MPU L-11 PTD: 193-013 API: 50-029-22336-00-00 Caliper Survey (12/20/23) SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 193-013 T38259 1/5/2024Kayla Junke Digitally signed by Kayla Junke Date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y Anne Prysunka at 3:39 pm, Oct 03, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 6)' %23(WHVWWRSVL 0,7,$WRSVLKRXUQRWLFHWR$2*&&IRURSSRUWXQLW\WRZLWQHVV 0*52&7 6)' '65 *&: Jessie L. 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Chmielowski Date: 2022.10.26 16:54:47 -08'00' RBDMS JSB 102722 ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌ tĞůů͗DWh>Ͳϭϭ ĂƚĞ͗ϬϵͬϮϳͬϮϬϮϮ tĞůůEĂŵĞ͗DWh>Ͳϭϭ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϯϯϲͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŝůtĞůů WĂĚ͗>ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗KĐƚŽďĞƌϮϭ͕ϮϬϮϮ ZŝŐ͗^Zϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϯͲϬϭϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dŽĚĚ^ŝĚŽƚŝ ;ϵϬϳͿϳϳϳͲϴϰϰϯ;KͿ ;ϵϬϳͿϲϯϮͲϰϭϭϯ;DͿ &EƵŵďĞƌ͗:ŽďdǇƉĞ͗ŽŶǀƚŽ/ŶũĞĐƚŽƌ &XUUHQW%RWWRP+ROH3UHVVXUH SVL#¶79' )(63*DXJHSSJ(0: 0D[LPXP([SHFWHG%+3SVL#¶79' (VW1RUPDOO\3UHVVXUHGSSJ(0: 0363SVL SVLIWJUDGLHQWWRVXUIDFH ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWh>ͲϭϭǁĂƐĚƌŝůůĞĚ͕ĨƌĂĐƚƵƌĞƐƚŝŵƵůĂƚĞĚĂŶĚĐŽŵƉůĞƚĞĚĂƐĂ<ƵƉĂƌƵŬZŝǀĞƌƉƌŽĚƵĐĞƌŝŶ:ƵŶĞϭϵϵϯ͘^W ŝŶƐƚĂůůĂƚŝŽŶŚŝƐƚŽƌǇ͗:ƵŶĞϭϵϵϯ;ŝŶŝƚŝĂůͿ͕:ƵůǇϭϵϵϯ͕Ɖƌŝůϭϵϵϰ͕DĂǇϭϵϵϱ͕ƵŐƵƐƚϮϬϬϭ͕DĂƌĐŚϮϬϬϵ͕:ƵŶĞϮϬϬϵ͕ ĂŶĚEŽǀĞŵďĞƌϮϬϭϮ͘dŚĞ^WŚĂƐĨĂŝůĞĚ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x dŚĞϳ͟ƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐǁĂƐƚĞƐƚĞĚĚŽǁŶƚŽϭϬ͕ϴϬϬ͛Dͬϯ͕ϱϬϬƉƐŝŽŶEŽǀĞŵďĞƌϭϮ͕ϮϬϭϮ͘ KďũĞĐƚŝǀĞ͗ ZŝŐͲWƵůůĨĂŝůĞĚ^WͬZƵŶϳ͟ĐĂƐŝŶŐƐĐƌĂƉĞƌͬdĞƐƚϳ͟ĐĂƐŝŶŐƚŽцϭϬ͕ϵϬϬ͛DͬZƵŶϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶ WŽƐƚZŝŐʹĚĚƉĞƌĨŽƌĂƚŝŽŶƐƚŽ<ƵƉĂƌƵŬƐĂŶĚƐ ^ůŝĐŬůŝŶĞ;EŽŶͲƐƵŶĚƌŝĞĚƐƚĞƉƐͿ ϭ͘ Zh^ůŝĐŬůŝŶĞƵŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝͬϭ͕ϱϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ ƌŝĨƚĂŶĚƚĂŐǁŝƚŚƐĂŵƉůĞƌďĂŝůĞƌ͘ ϯ͘ ĂůŝƉĞƌƚƵďŝŶŐ͘ ϰ͘ WƵůůůŽǁĞƌ'>sĨƌŽŵϭϬ͕ϳϰϴ͛ŵĚ͘ ϱ͘ WƵůů>'>sĂŶĚƐĞƚ'>sŝŶƵƉƉĞƌ'>DĂƚϭϰϬ͛ŵĚ͘ ϲ͘ Z^>ƵŶŝƚ͘ WƌĞͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ Ϯ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞůů͘ ϯ͘ Zh>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐ͘ZhƌĞǀĞƌƐĞŽƵƚƐŬŝĚĂŶĚϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘ ϰ͘ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƚŽϯ͕ϬϬϬƉƐŝ͘ ϱ͘ ŝƌĐƵůĂƚĞĂƚůĞĂƐƚŽŶĞǁĞůůďŽƌĞǀŽůƵŵĞǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌͬƐŽƵƌĐĞǁĂƚĞƌĚŽǁŶƚƵďŝŶŐ͕ƚĂŬŝŶŐ ƌĞƚƵƌŶƐƵƉ/ƚŽϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘ ϲ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌŝĨĨƌĞĞǌĞƉƌŽƚĞĐƚŝŽŶŝƐŶĞĞĚĞĚĚĞƉĞŶĚŝŶŐŽŶ ^ZĂƌƌŝǀĂů͘ S SVL SSJ SSJ(0: ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌ tĞůů͗DWh>Ͳϭϭ ĂƚĞ͗ϬϵͬϮϳͬϮϬϮϮ ϳ͘ Z>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐĂŶĚƌĞǀĞƌƐĞŽƵƚƐŬŝĚ͘ ϴ͘ ^ĞƚWs͘EƚƌĞĞ͘ ƌŝĞĨZtKWƌŽĐĞĚƵƌĞ͗ ϵ͘ D/Zh^Z͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐ͘ ϭϬ͘ ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŝĨϬƉƐŝ͘/ĨŶĞĞĚĞĚ͕ďůĞĞĚŽĨĨĂŶǇƌĞƐŝĚƵĂůƉƌĞƐƐƵƌĞŽĨĨƚƵďŝŶŐĂŶĚĐĂƐŝŶŐ͘/Ĩ ŶĞĞĚĞĚ͕ŬŝůůǁĞůůǁͬƉƌŽĚƵĐĞĚǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌ͘^Ğƚd^WůƵŐ͘ ϭϭ͘ EhKW͘ ϭϮ͘ dĞƐƚKWƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ Ă͘ EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ dĞƐƚƵƉƉĞƌϮͲϳͬϴ͟ǆϱ͟ƌĂŵƐǁŝƚŚƚŚĞϮͲϳͬϴ͟ĂŶĚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐǁŝƚŚƉƉƌŽǀĞĚ^ƵŶĚƌǇ͘ Ě͘ ŶƐƵƌĞƚŽŵŽŶŝƚŽƌƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐĂŶĚĂŶŶƵůƵƐǀĂůǀĞƉƌĞƐƐƵ ƌĞŐĂƵŐĞƐƚŽĞŶƐƵƌĞŶŽƉƌĞƐƐƵƌĞ ŝƐƚƌĂƉƉĞĚƵŶĚĞƌŶĞĂƚŚƚĞƐƚƉůƵŐ͘ Ğ͘ KŶĐĞKWƚĞƐƚŝƐĐŽŵƉůĞƚĞ͕ƐĞŶĚĂĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚ;ϭϬͲϰϮϰĨŽƌŵͿƚŽK'ĂŶĚƚŽǁŶ ĞŶŐŝŶĞĞƌ͘ ϭϯ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůd^ƉůƵŐĂŶĚWs͘<ŝůůǁĞůůǁŝƚŚ ƉƌŽĚƵĐĞĚǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌĂƐŶĞĞĚĞĚ͘ ϭϰ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚĚƵƌŝŶŐƚŚĞϮϬϭϴ^WƐǁĂƉǁĂƐϴϰŬƚŽƵŶƐĞĂƚƚŚĞŚĂŶŐĞƌĂŶĚϳϰ<ůďƐƚŽĨƌĞĞ ƉŝƉĞ͘ ď͘ dŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶǁĂƐůĂŶĚĞĚǁŝƚŚϮϴ<ƐůĂĐŬŽĨĨǁƚ͘WhǁĞŝŐŚƚǁĂƐŶŽƚƉĞƌĨŽƌŵĞĚŽĨĨ ďŽƚƚŽŵƚŽŵŝŶŝŵŝǌĞƌŝƐŬĨŽƌĐĂďůĞĚĂŵĂŐĞ͘ ϭϱ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ϭϲ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘EƵŵďĞƌĂůůũŽŝŶƚƐ͘dďŐǁŝůůďĞƐŽƌƚĞĚďĂƐĞĚŽŶƚŚĞ ƚƵďŝŶŐĐĂůŝƉĞƌƌĞƐƵůƚƐ͘'ŽŽĚũŽŝŶƚƐǁŝůůďĞďƌŽƵŐŚƚƚŽŝŶǀĞŶƚŽƌǇƵŶůĞƐƐĚĂŵĂŐĞŽƌŽƚŚĞƌ ŽďƐĞƌǀĂƚŝŽŶƐĂƌĞƐĞĞŶǁŚŝůĞƉƵůůŝŶŐ͘>ĂǇĚŽǁŶĨĂŝůĞĚ^W͘ Ă͘ ŽŶƚĂĐƚKĨŽƌĐĂůŝƉĞƌƌĞƐƵůƚƐŝĨŶŽƚƉƌĞǀŝŽƵƐůǇƉƌŽǀŝĚĞĚ͘ ď͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů͘ Đ͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐĂŶĚũƵŶŬƚŚĞŵ͘ Ě͘ ůůĐůĂŵƉƐĂŶĚũĞǁĞůƌǇǁŝůůďĞĐůĞĂŶĞĚĂŶĚƉƵƚŝŶƚŽŝŶǀĞŶƚŽƌǇ ĨŽƌƌĞͲƵƐĞ͘ Ğ͘ ůůĐĂďůĞŝƐƚŽďĞĐůĞĂŶĞĚĂŶĚƐĐƌĂƉƉĞĚ͘ &URVVFROODUFODPSV 3URWHFWROL]HU&ODPSV )ODW*XDUG&ODPSV ϭϳ͘ Dhϳ͟ĐĂƐŝŶŐƐĐƌĂƉĞƌǁͬŽůĚďŝƚ,ŽŶϯͲϭͬϮ͟ǁŽƌŬƐƚƌŝŶŐ͘d/,ƚŽΕϭϭ͕ϰϬϬ͛D͘ZĞĐŝƉƌŽĐĂƚĞĨƌŽŵ ϭϬ͕ϴϱϬ͛ʹϭϬ͕ϵϱϬ͛DǁŚŝůĞWKK,͘ Ă͘ /ĨƐĞƚƚŝŶŐĚŽǁŶĞĂƌůǇ͕ĐŽŶƚĂĐƚKƚŽƐĞĞŝĨĐůĞĂŶŽƵƚŝƐŶĞĞĚĞĚ͘ ϭϴ͘ WhĂŶĚd/,ǁͬϳ͟ƚĞƐƚƉĂĐŬĞƌƚŽцϭϬ͕ϵϬϬ͛D͕ƐĞƚĂŶĚƚĞƐƚĐĂƐŝŶŐƚŽϭ͕ϴϬϬƉƐŝ͘ ϭϵ͘ ZƵŶŶĞǁϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶ͘ /XEULFDWH%39LISRVVLELOLW\RISUHVVXUHRQWXELQJEHORZ ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌ tĞůů͗DWh>Ͳϭϭ ĂƚĞ͗ϬϵͬϮϳͬϮϬϮϮ ŽůŽƌƐŝŶĚŝĐĂƚĞĂƐƐĞŵďůŝĞƐƚŽďĞďƵĐŬĞĚƵƉƉƌŝŽƌƚŽZtK͘ 1RP 6L]H a/HQJWK ,WHP /EIW 0DWHULDO 1RWHV :/(* / 3ODFHDW¶0' ´-RLQW / ´ 3XS-RLQW / ´;1LSZLWK5+&SURILOH /¶0' ´ 3XS-RLQW / ´MRLQW / ´ ;2 WR -RLQW / ´[´3DFNHU /7UL3RLQW3DFNHUVHW 0' ´ ;2´WR -RLQW / ´-RLQWV / ´ 3XS-RLQW / ´;1LSSOH /¶0' ´ 3XS-RLQW / ´-RLQWV / ´6SDFHRXW3836 / ´MRLQW / ´383 / ´7XELQJ+DQJHU / ϮϬ͘ ^ƉĂĐĞŽƵƚĂŶĚůĂŶĚƚŚĞϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶ͘Z/>^͘ Ϯϭ͘ ƌŽƉďĂůůĂŶĚƌŽĚĂŶĚĐŽŵƉůĞƚĞůŽĂĚŝŶŐƚƵďŝŶŐǁŝƚŚ&WĂŶĚŚǇ ĚƌĂƵůŝĐĂůůǇƐĞƚƚŚĞƉĂĐŬĞƌĂƐƉĞƌ ŵĂŶƵĨĂĐƚƵƌĞƌƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ͘ Ă͘ EŽƚĞƚŚĂƚƚŚĞŵĂǆƉƌĞƐƐƵƌĞƚŽĨƵůůǇƐĞƚƚŚĞƉĂĐŬĞƌŝƐΕϯ͕ϴϬϬƉƐŝ͘dŚĞůŽĐŬŽŶƚŚĞZ,ƉůƵŐŝƐ ƌĂƚĞĚĨŽƌϱ͕ϰϳϬƉƐŝ͘ ϮϮ͘ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽϯϬϬϬƉƐŝĨŽƌD/dͲdǁŝƚŚƉ ŽƐŝƚŝǀĞƉƌĞƐƐƵƌĞŽŶƚŚĞ/͘ůĞĞĚŽĨĨ ƚŚĞƚƵďŝŶŐƚŽфϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮ͕ϬϬϬƉƐŝĨŽƌD/dͲ/͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬ ŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ Ă͘ ϮϰŚƌEŽƚŝĨŝĐĂƚŝŽŶĨŽƌĂǁŝƚŶĞƐƐĞĚƚĞƐƚďǇƚŚĞK'/ŶƐƉĞĐƚŽƌŝƐƌĞƋƵŝƌĞĚ͘ Ϯϯ͘ ^ĞƚWs͘ Ϯϰ͘ ZDK^Z͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ;EŽŶͲ^ƵŶĚƌŝĞĚ^ƚĞƉƐͿ͗ tĞůů^ƵƉƉŽƌƚ ϭ͘ ZŵƵĚďŽĂƚ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯ͘ ZhĐƌĂŶĞ͘EKW͘^Ğƚd^ƉůƵŐ͘ ŽŶǀĞƌƚƚŽ/ŶũĞĐƚŽƌ tĞůů͗DWh>Ͳϭϭ ĂƚĞ͗ϬϵͬϮϳͬϮϬϮϮ ϯ͘ EhƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϰ͘ dĞƐƚďŽƚŚƚƌĞĞĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϱ͘ WƵůůd^ƉůƵŐΘWs͘ ϲ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϳ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϴ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ^ůŝĐŬůŝŶĞ;EŽŶͲ^ƵŶĚƌŝĞĚ^ƚĞƉƐͿ͗ ϵ͘ Zh^>ƵŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ͘ ϭϬ͘ WƵůůĂůůΘZŽĚ͘ ϭϭ͘ WƵůůZ,ƉůƵŐďŽĚǇ͘ ϭϮ͘ ƌŝĨƚǁͬϭͲϭϭͬϭϲ͟ĚƵŵŵǇŐƵŶ͘ ϭϯ͘ ZDK͘ Ͳ>ŝŶĞ;^ƵŶĚƌŝĞĚ^ƚĞƉƐͿ͗ ϭϰ͘ Zh>ƵŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ͘ ϭϱ͘ WhWĞƌĨ'ƵŶ,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚĞĨŽůůŽǁŝŶŐŝŶƚĞƌǀĂůƐ͗ Ă͘ ŽĐƵŵĞŶƚĐŚĂŶŐĞƐŝŶǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞĂŶĚĐŽŶĚŝƚŝŽŶŽĨŐƵŶƐĂƐƚŚĞǇƌĞƚƵƌŶ͘ ϭϲ͘ ŽŶƚĂĐƚ'ĞŽůŽŐŝƐƚĂŶĚͬŽƌKƉƐŶŐŝŶĞĞƌƚŽƌĞǀŝĞǁĚĞƉƚŚĂŶĚƉůĂŶŶĞĚƉĞƌĨŽƌĂƚŝŽŶĚĞƉƚŚƐƉƌŝŽƌƚŽ ĨŝƌŝŶŐŐƵŶƐ͘ ď͘ KƉƐŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ƚǁĞůůŵĂŶΛŚŝůĐŽƌƉ͘ĐŽŵ͖;ϵϬϳͿϵϰϳͲϵϱϯϯ Đ͘ 'ĞŽůŽŐŝƐƚ͗:ŽŚŶ^ĂůƐďƵƌǇ ũƐĂůƐďƵƌǇΛŚŝůĐŽƌƉ͘ĐŽŵ͖;ϵϬϳͿϯϱϬͲϭϬϴϴ Ě͘ WĞƌĨŽƌĂƚŝŶŐ'ƵŶƐĂƌĞϭͲϭϭͬϭϲ͟ʹϮͲϭͬϴ͟,Dy͕ϲ^W&͕ϲϬĚĞŐƌĞĞƉŚĂƐĞŐƵŶƐ͘ WĞƌĨdǇƉĞ &ŽƌŵĂƚŝŽŶ >ĞŶŐƚŚ ;ĨƚͿ dŽƉ;DͿ ŽƚƚŽŵ;DͿ dŽƉ;dsͿ ŽƚƚŽŵ ;dsͿ ĚĚͬZĞWĞƌĨ <ƵƉĂƌƵŬƐŝůƚƐ ϱϬ͛ цϭϭ͕ϬϭϬ͛ цϭϭ͕ϬϲϬ͛ ϳ͕Ϭϰϴ͛ ϳ͕Ϭϳϴ͛ ZĞWĞƌĨ <ƵƉĂƌƵŬϯ ϭϬ͛ цϭϭ͕Ϭϴϳ͛ цϭϭ͕Ϭϵϳ͛ ϳ͕Ϭϵϰ͛ ϳ͕ϭϬϬ͛ ĚĚͬZĞWĞƌĨ <ƵƉĂƌƵŬϯ Ϯϵ͛цϭϭ͕ϭϲϰ͛ цϭϭ͕ϭϵϯ͛ ϳ͕ϭϰϭ͛ ϳ͕ϭϱϵ͛ ĚĚͬZĞWĞƌĨ <ƵƉĂƌƵŬϮ ϯϵ͛цϭϭ͕ϭϵϳ͛ цϭϭ͕Ϯϯϲ͛ ϳ͕ϭϲϭ͛ ϳ͕ϭϴϱ͛ ĚĚͬZĞWĞƌĨ <ƵƉĂƌƵŬϭ ϯϵ͛цϭϭ͕ϮϱϮ͛ цϭϭ͕Ϯϵϭ͛ ϳ͕ϭϵϱ͛ ϳ͕Ϯϭϵ͛ ZĞWĞƌĨ <ƵƉĂƌƵŬϭ ϭϬ͛цϭϭ͕ϯϯϲ͛ цϭϭ͕ϯϰϲ͛ ϳ͕Ϯϰϲ͛ ϳ͕ϮϱϮ͛ ϭϳ͘ ZDK>ƵŶŝƚ͘ ϭϴ͘ ƌŝŶŐǁĞůůŽŶŝŶũĞĐƚŝŽŶ͘^^^sŵƵƐƚďĞŝŶƐƚĂůůĞĚǁŝƚŚŝŶϭϰͲĚĂ ǇƐ͕ďƵƚƐĐŚĞĚƵůĞƐůŝĐŬůŝŶĞƚŽŝŶƐƚĂůůDy ĂĨƚĞƌďĂƐĞůŝŶĞŝŶũĞĐƚŝŽŶƌĂƚĞƐĂƌĞĚŽĐƵŵĞŶƚĞĚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ƌĞĂKĨZĞǀŝĞǁ;DĂƉͿ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϱͬϴͬϮϬϭϴ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW>Ͳϭϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϵͬϮϬϭϴ Wd͗ϭϵϯͲϬϭϯ dс ϭϭ͕ϲϯϬ͛;DͿͬdсϳ͕ϰϮϰ͛;dsͿ KƌŝŐ͘<ůĞǀ͗͘ϱϭ͘ϬϬ͛D^> ϳ͟ ϵͲϱͬϴ ͟ ,K^Ͳ^ ĞŵĞŶƚ dŽŽů Λϭ͕ϵϬϮ͛ D/E/сϮ͘ϮϬϱ ΛϭϬ͕ϴϱϰ͛ Wdс ϭϭ͕ϰϵϮ͛;DͿͬWdсϳ͕ϯϰϭ͛;dsͿ &/^,͗ϰ&ůĂƚ'ƵĂƌĚƐ ĂŶĚϯĂŶĚƐůĞĨƚŝŶ ŚŽůĞďĞůŽǁƉĞƌĨƐ͘ ϭϯͲϯͬϴ͟ &KƚŽϭϭ͕ϰϬϬ͛ŽŶ ϲͬϭϰͬϮϬϬϵ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬdZ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϬΖ Ϭ͘ϭϱϰϲ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬEͲϴϬͬdZ^ ϴ͘ϲϴϭ ^ƵƌĨĂĐĞ ϲ͕ϲϴϴ͛ Ϭ͘ϬϳϯϮ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬdZ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϲϮϬ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ ϭϬ͕ϵϲϬ͛ Ϭ͘ϬϬϱϳϵ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭϭϰϬ͛^dηϮ͗ĂŵĐŽϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬKƌŝĨŝĐĞ Ϯ ϭϬ͕ϳϰϴ͛^dηϭ͗ĂŵĐŽϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬƵŵŵǇ ϯ ϭϬ͕ϴϲϬ͛ yEͲEŝƉƉůĞ͗ϮͲϳͬϴ͟,^;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ ϭϬ͕ϵϬϮ͘ϵϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗'W/^ ϱ ϭϬ͕ϵϬϯ͘ϰϴ͛ WƵŵƉ͗dǇƉĞͲϭϲϭWϭϭ͕DŽĚĞůͲ^y ϲ ϭϬ͕ϵϮϱ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&ZEZ ϳ ϭϬ͕ϵϮϵ͛ hƉƉĞƌ^ĞĂů^ĞĐƚŝŽŶ͗'^ϯhd^ͬ^W&^ ϴ ϭϬ͕ϵϯϱ͛ >ŽǁĞƌ^ĞĂů^ĞĐƚŝŽŶ͗'^ϯ>d^ͬ^W&^>ϱ ϵ ϭϬ͕ϵϰϮ͛ DŽƚŽƌ͗yW͕ϮϬϬ,Wͬϯ͕ϲϯϱsͬϯϰ ϭϬ ϭϬ͕ϵϱϲ͛ ^ĞŶƐŽƌ͗tĞůů>ŝĨƚ ϭϭ ϭϬ͕ϵϱϴ͛ ĞŶƚƌĂůŝǌĞƌͬŽƚƚŽŵΛϭϬ͕ϵϲϬ͛ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ŵƚǁͬϱϬϬƐǆŽĨW&͟͞ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϳϱϬƐǆƌĐƚŝĐ^Ğƚ///͕ϯϬϱƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϯϬϮƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ EŽƚĞ͗WĞƌĨŽƌĂƚĞĚϳ͟ĂƐŝŶŐǁͬϵƐŚŽƚƐΛϭϬ͕ϵϵϬ͛ƚŽϭϬ͕ϵϵϮ͛ĂŶĚƐƋƵĞĞǌĞĚ ϮϴďďůƐĐůĂƐƐ͚'͛ĐĞŵĞŶƚ͘dĞƐƚĞĚƚŽϭ͕ϴϳϱƉƐŝ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϴĚĞŐ͘Λϳ͕ϴϬϬ͛D ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϱϯĚĞŐ͘ DĂǆŽŐ>ĞŐϰ͘ϲϱĚĞŐ͘Λϭ͕ϰϬϳ͛D dZΘt>>, dƌĞĞ ϮͲϵͬϭϲ͟ͲϱDĂŵĞƌŽŶt<D tĞůůŚĞĂĚ ϭϭ͟ǆϳ͟ϱDt<DǁͬϮͲϳͬϴ͟ϴƌĚdƌĞĞƚŽƉ ĐŽŶŶĞĐƚŝŽŶϮͲϭͬϮ͟ĂŵĞƌŽŶƚǇƉĞ͚,͛WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϯϯϲͲϬϬͲϬϬ ƌŝůůĞĚ͕ĂƐĞĚΘŽŵƉůĞƚĞĚďǇEĂďŽƌƐϮϮʹϲͬϮϬͬϭϵϵϯ ^W^ǁĂƉďǇEĂďŽƌƐϮϮʹϳͬϵͬϭϵϵϯ ^W^ǁĂƉʹϰͬϮϲͬϭϵϵϰ ^W^ǁĂƉďǇEĂďŽƌƐϰ^ʹϱͬϯͬϭϵϵϱΘϴͬϮϬͬϮϬϬϭ ^WZĞƉĂŝƌďǇEĂďŽƌƐϯ^ʹϯͬϳͬϮϬϬϵ͕ϲͬϭϲͬϮϬϬϵ ^WZĞƉĂŝƌďǇŽǇŽŶϭϲʹϭϭͬϭϰͬϮϬϭϮ ^W^ǁĂƉďǇ^ZηϭʹϰͬϭϵͬϮϬϭϴ &Z d/> &ƌĂĐ͛ĚǁͬdŽƚĂůŽĨϭϵϭ͕ϰϳϭůďƐŽĨϭϮͲϭϴ/^W ϭϳϮ͕ϱϬϬůďƐŽĨϭϮͲϭϴ/^WďĞŚŝŶĚƉŝƉĞ WZ&KZd/KEd/> <ƵƉĂƌƵŬ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵ Ɛ ϭͬϲ ϭϭ͕Ϭϭϲ͛ ϭϭ͕Ϭϯϲ͛ ϳ͕Ϭϱϭ͛ ϳ͕Ϭϲϯ͛ ϮϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϲ ϭϭ͕ϬϱϬ͛ ϭϭ͕ϬϲϬ͛ ϳ͕ϬϳϮ͛ ϳ͕Ϭϳϴ͛ ϭϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϲ ϭϭ͕Ϭϴϳ͛ ϭϭ͕Ϭϵϳ͛ ϳ͕Ϭϵϰ͛ ϳ͕ϭϬϬ͛ ϭϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϯ ϭϭ͕ϭϲϰ͛ ϭϭ͕ϭϴϰ͛ ϳ͕ϭϰϭ͛ ϳ͕ϭϱϯ͛ ϮϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ Ϯ ϭϭ͕ϭϵϳ͛ ϭϭ͕ϮϮϳ͛ ϳ͕ϭϲϭ͛ ϳ͕ϭϳϵ͛ ϯϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϭ ϭϭ͕Ϯϱϲ͛ ϭϭ͕Ϯϴϲ͛ ϳ͕ϭϵϳ͛ ϳ͕Ϯϭϱ͛ ϯϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϭ͊ ϭϭ͕ϯϯϲ͛ ϭϭ͕ϯϰϲ͛ ϳ͕Ϯϰϲ͛ ϳ͕ϮϱϮ͛ ϭϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϭϮ^W&ϱ͟ĂƐŝŶŐ'ƵŶƐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭϬͬϯͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW>Ͳϭϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϵͬϮϬϭϴ Wd͗ϭϵϯͲϬϭϯ dс ϭϭ͕ϲϯϬ͛;DͿͬdсϳ͕ϰϮϰ͛;dsͿ KƌŝŐ͘<ůĞǀ͗͘ϱϭ͘ϬϬ͛D^> ϳ͟ ϵͲϱͬϴ͟ ,K^Ͳ^ĞŵĞŶƚdŽŽů Λϭ͕ϵϬϮ͛ D/E/сϮ͘ϮϬϱ ΛцϭϬ͕ϵϱϬ͛ Wdсϭϭ͕ϰϵϮ͛;DͿͬWdсϳ͕ϯϰϭ͛;dsͿ &/^,͗ϰ&ůĂƚ'ƵĂƌĚƐ ĂŶĚϯĂŶĚƐůĞĨƚŝŶ ŚŽůĞďĞůŽǁƉĞƌĨƐ͘ ϭϯͲϯͬϴ͟ &KƚŽϭϭ͕ϰϬϬ͛ŽŶ ϲͬϭϰͬϮϬϬϵ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬdZ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϬΖ Ϭ͘ϭϱϰϲ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬEͲϴϬͬdZ^ ϴ͘ϲϴϭ ^ƵƌĨĂĐĞ ϲ͕ϲϴϴ͛ Ϭ͘ϬϳϯϮ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬdZ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϲϮϬ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϭϭ͕ϬϬϬ͛ Ϭ͘ϬϬϱϳϵ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϮ͕ϰϬϬ͛ yͲEŝƉƉůĞ͗ϮͲϳͬϴ͟,^;Ϯ͘ϯϭϯEŽͲŐŽ/Ϳ Ϯ цϭϬ͕ϵϬϬ͛ϳΗǆϯͲϭͬϮΗZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ ϯ цϭϬ͕ϵϰϬ͛ yEͲEŝƉƉůĞ͗ϮͲϳͬϴ͟,^;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ цϭϬ͕ϵϴϬ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ŵƚǁͬϱϬϬƐǆŽĨW&͟͞ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϳϱϬƐǆƌĐƚŝĐ^Ğƚ///͕ϯϬϱƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϯϬϮƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ EŽƚĞ͗WĞƌĨŽƌĂƚĞĚϳ͟ĂƐŝŶŐǁͬϵƐŚŽƚƐΛϭϬ͕ϵϵϬ͛ƚŽϭϬ͕ϵϵϮ͛ĂŶĚƐƋƵĞĞǌĞĚ ϮϴďďůƐĐůĂƐƐ͚'͛ĐĞŵĞŶƚ͘dĞƐƚĞĚƚŽϭ͕ϴϳϱƉƐŝ t>>/E>/Ed/KEd/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϴĚĞŐ͘Λϳ͕ϴϬϬ͛D ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϱϯĚĞŐ͘ DĂǆŽŐ>ĞŐϰ͘ϲϱĚĞŐ͘Λϭ͕ϰϬϳ͛D dZΘt>>, dƌĞĞ ϮͲϵͬϭϲ͟ͲϱDĂŵĞƌŽŶt<D tĞůůŚĞĂĚ ϭϭ͟ǆϳ͟ϱDt<DǁͬϮͲϳͬϴ͟ϴƌĚdƌĞĞƚŽƉ ĐŽŶŶĞĐƚŝŽŶϮͲϭͬϮ͟ĂŵĞƌŽŶƚǇƉĞ͚,͛WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϯϯϲͲϬϬͲϬϬ ƌŝůůĞĚ͕ĂƐĞĚΘŽŵƉůĞƚĞĚďǇEĂďŽƌƐϮϮʹϲͬϮϬͬϭϵϵϯ ^W^ǁĂƉďǇEĂďŽƌƐϮϮʹϳͬϵͬϭϵϵϯ ^W^ǁĂƉʹϰͬϮϲͬϭϵϵϰ ^W^ǁĂƉďǇEĂďŽƌƐϰ^ʹϱͬϯͬϭϵϵϱΘϴͬϮϬͬϮϬϬϭ ^WZĞƉĂŝƌďǇEĂďŽƌƐϯ^ʹϯͬϳͬϮϬϬϵ͕ϲͬϭϲͬϮϬϬϵ ^WZĞƉĂŝƌďǇŽǇŽŶϭϲʹϭϭͬϭϰͬϮϬϭϮ ^W^ǁĂƉďǇ^ZηϭʹϰͬϭϵͬϮϬϭϴ &Zd/> &ƌĂĐ͛ĚǁͬdŽƚĂůŽĨϭϵϭ͕ϰϳϭůďƐŽĨϭϮͲϭϴ/^W ϭϳϮ͕ϱϬϬůďƐŽĨϭϮͲϭϴ/^WďĞŚŝŶĚƉŝƉĞ WZ&KZd/KEd/> <ƵƉĂƌƵŬ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵ Ɛ ^ŝůƚƐ цϭϭ͕ϬϭϬ͛ цϭϭ͕ϬϲϬ͛ цϳ͕Ϭϰϴ͛ цϳ͕Ϭϳϴ͛ цϴϬ WĞŶĚŝŶŐ &ƵƚƵƌĞ ϭͬϲ ϭϭ͕Ϭϭϲ͛ ϭϭ͕Ϭϯϲ͛ ϳ͕Ϭϱϭ͛ ϳ͕Ϭϲϯ͛ ϮϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϲ ϭϭ͕ϬϱϬ͛ ϭϭ͕ϬϲϬ͛ ϳ͕ϬϳϮ͛ ϳ͕Ϭϳϴ͛ ϭϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϯ цϭϭ͕Ϭϴϳ͛ цϭϭ͕Ϭϵϳ͛ цϳ͕Ϭϵϰ͛ цϳ͕ϭϬϬ͛ цϭϬ WĞŶĚŝŶŐ &ƵƚƵƌĞ ϯ ϭϭ͕Ϭϴϳ͛ ϭϭ͕Ϭϵϳ͛ ϳ͕Ϭϵϰ͛ ϳ͕ϭϬϬ͛ ϭϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϯ цϭϭ͕ϭϲϰ͛ цϭϭ͕ϭϵϯ͛ цϳ͕ϭϰϬ͛ цϳ͕ϭϱϵ͛ цϮϵ WĞŶĚŝŶŐ &ƵƚƵƌĞ ϯ ϭϭ͕ϭϲϰ͛ ϭϭ͕ϭϴϰ͛ ϳ͕ϭϰϭ͛ ϳ͕ϭϱϯ͛ ϮϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ Ϯ цϭϭ͕ϭϵϳ͛ цϭϭ͕Ϯϯϲ͛ цϳ͕ϭϲϭ͛ цϳ͕ϭϱϵ͛ цϯϵ WĞŶĚŝŶŐ &ƵƚƵƌĞ Ϯ ϭϭ͕ϭϵϳ͛ ϭϭ͕ϮϮϳ͛ ϳ͕ϭϲϭ͛ ϳ͕ϭϳϵ͛ ϯϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϭ ϭϭ͕Ϯϱϲ͛ ϭϭ͕Ϯϴϲ͛ ϳ͕ϭϵϳ͛ ϳ͕Ϯϭϱ͛ ϯϬ ϲͬϭϱͬϭϵϵϯ KƉĞŶ ϭ цϭϭ͕ϮϱϮ͛ цϭϭ͕Ϯϵϭ͛ цϳ͕ϭϵϱ͛ цϳ͕Ϯϭϵ͛ цϯϵ WĞŶĚŝŶŐ 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Plug for Redrill ❑ :rforate New Pool ❑ Repair Wee Re-enter Susp Well ❑ Other:ESP Change-out ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development 0 Exploratory ❑ 193-013 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22336-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509/ADL0355017 MILNE PT UNIT L-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 11,630 feet Plugs measured N/A feet true vertical 7,424 feet Junk measured 11,400(Fill) feet Effective Depth measured 11,400 feet Packer measured N/A feet true vertical 7,285 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 13-3/8" 110' 110' N/A N/A Surface 6,658' 9-5/8" 6,688' 4,588' 6,870psi 4,760psi Production 11,590' 7" 11,620' 7,418' 7,240psi 5,410psi ff 21 •ZUT Perforation depth Measured depth See Schematic feetSCAMEI) JUN b True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 10,960' 7,017' 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 I Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 280 0 Subsequent to operation: 95 17 638 140 212 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 318-137 ►e Authorized Name: Bo York Contact Name: Paul Chan <yy� Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: )1,2\--- �`_ _`"` �v �ur l� Date: 5/8/2018 Contact Phone: 777-8333 IL 4'zt,/.9 /.4 it*Ai RBDMS MAY 2 4 2018 Form 10-404 Revised 4/2017 Submit Original Only " • 110Well: Point Unit ell: MP L-11 SCHEMATIC Last Completed: 4/19/2018 Hileorp Alaska,LLC PTD: 193-013 TREE&WELLHEAD Orig.KB Elev.:51.00'MSL Tree 2-9/16"-5M Cameron WKM Wellhead " " w/ " d Te Al . connec11x7tionSM 2-1/2WKM"Cameron type8r 'Hr'BPVetop Profile OPEN HOLE/CEMENT DETAIL 13-3/8" 1 , 13-3/8" Cmt w/500 sx of PF"C"in 30"Hole r 9-5/8" Cmt w/1,750 sx Arctic Set III,305 sx Class"G"in 12-1/4"Hole 4 7" Cmt w/302 sx Class"G"in 8-1/2"Hole Note:Perforated 7"Casing w/9 shots @ 10,990'to 10,992'and squeezed w 28 bbls class`G'cement.Tested to 1,875psi CASING DETAIL 9 5/8" A 1 Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 54.5/K-55/BTRC 12.615 Surface 110' 0.1546 HOS-SE Cement Tod 9-5/8" Surface 47/N-80/BTRS 8.681 Surface 6,688' 0.0732 @ 1,902' 7" Production 26/L-80/BTRC 6.276 Surface 11,620' 0.0383 ) TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 10,960' 0.00579 WELL INCLINATION DETAIL I KOP@400' Max Hole Angle=58 deg. @ 7,800'MD Hole Angle through perforations=53 deg. Max Dog Leg 4.65 deg.@1,407'MD • , JEWELRY DETAIL No Depth Item 1 140' STA#2:Camco 2 7/8 X 1"Side pocket,W/Orifice 2 10,748' STA#1:Camco 2 7/8 X 1"Side pocket,W/Dummy ' 3 10,860' XN-Nipple: 2-7/8"HES(2.205 No-go ID) 4 10,902.97' Discharge Head:GPDIS 5 10,903.48' Pump:Type-161P11,Model-SXD 6 10,925' Gas Separator GRS FER N AR ) 7 10,929' Upper Seal Section:GSB3DBUT SB/SB PFSA 8 10,935' Lower Seal Section:GSB3DBLT SB/SB PFSA CL5 9 10,942' Motor: XP,200HP/3,635V/34A 2 i• 10 10,956' Sensor WeIILift E MIN ID=2.7r'r ' 11 10,958' Centralizer/Bottom @ 10,960' @ 10,854 14 3 fa) PERFORATION DETAIL 11 Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 4 C1/B6 11,016' 11,036' 7,051' 7,063' 20 6/15/1993 Open 5 B6 11,050' 11,060' 7,072' 7,078' 10 6/15/1993 Open B6 11,087' 11,097' 7,094' 7,100' 10 6/15/1993 Open , F 6 A3 11,164' 11,184' 7,141' 7,153' 20 6/15/1993 Ogen A2 11,197' 11,227' 7,161' 7,179' 30 6/15/1993 Open as Al 11,256' 11,286' 7,197' 7,215' 30 6/15/1993 Open All 11,336' 11,346' 7,246' 7,252' 10 6/15/1993 Open 12 SPF 5"Casing Guns 9 FRAC DETAIL 010 Frac'd w/Total of 191,4711bs of 12-18 ISP 172,500lbs of 12-18 ISP behind pipe GENERAL WELL INFO API:50-029-22336-00-00 FISH:4 Flat Guards • FCO to 11,400'on Drilled,Cased&Completed by Nabors 22E-6/20/1993 and 3 Bands left in 26/14/2009 ESP Swap by Nabors 22E -7/9/1993 hole below perfs.---,_-_.+0 ESPSwap-4/26/1994 7"A .1 ESP Swap by Nabors 4E5-5/3/1995&8/20/2001 TD=11,630'(MD)/TD=7,424'(TVD) ESP Repair by Nabors 3S-3/7/2009,6/16/2009 PBTD=11,492'(MD)/PBTD=7,341'(TVD) ESP Repair by Doyon 16-11/14/2012 ESP Swap by ASR#1-4/19/2018 Revised By:TDF 5/8/2018 • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-11 ASR 50-029-22336-00-00 193-013 4/16/18 4/19/18 Daily Operations: 4/11/2018-Wednesday No activity to report. 4/12/2018-Thursday No activity to report. 4/13/2018- Friday No activity to report. 4/14/2018-Saturday No activity to report. 4/15/2018-Sunday No activity to report.. 4/16/2018 Monday Finish spot pits, mobe TP trailer, office &change room &spot,spot well house & rig floor, spot rig on mud boat. (note killed well, set BPV, n/d tree, n/u BOPE prior to moving rig onto location). R/U Fluid Lines, Stairs and Walkways, start winterize lines lay out containment for catwalk and Pipe Racks, Hydraulic Lines For BOPE M/U test jt,fill surface eq. w/test fluid, Shell test 250/2,500, repairing leaks as needed Test BOPE as per Hilcorp &AOGCC requirements,witness was waived by AOGCC inspector Matt Herrera. 4/17/2018-Tuesday Continue to test BOPE as per Sundry and IWS test procedure. 250psi low f,2500psi high f/5 charted mins each. Witness waived by AOGCC rep Mathew Herrera. Blow down lines, verify no pressure on the IA, M/U blanking sub retrieving head, back out blanking sub,wellhead reps on location to pull BPV, M/U landing joint (9.5 turns), BOLDS (4.75") Pull TBG hanger to rig floor. 84klbs to unseat hanger, 74klbs hook load break over weight. Pull ESP cable over sheave. POOH w/ESP completion on 2-7/8" EUE TBG 1/—10,960'md to 6,000'md. Cont. POOH w/esp completion 1/d 2-7/8" EUE tubing, 1/d 342 jts total, 2- GLM assy, 1- Disassemble & L/D ESP assy Clean &clear floor. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-11 ASR 50-029-22336-00-00 193-013 4/16/18 4/19/18 Daily Operations: 1 „ �`�� _ <<` 4/18/2018-Wednesday Crew change,fluid checks. Continue to M/U Baker Centrilift ESP completion as per Centrilift rep. SIMOPS: Center BOP stack in prep for RIH. RIH w/ESP completion on 2-7/8" EUE TBG f/surface to 3,700'md. Cont. RIH w/ESP completion on 2-7/8" EUE TBG f/3,700',t/7,003',testing cable every 1,000', pumped down tubing took 4 bbls to fill pumped .5 BPM, 1005 psi, good Cont. RIH w/ESP completion on 2-7/8" EUE TBG f/7,003',t/8,046'Test cable good, Change spools make splice &test good, simops- prep for rig move &wk on rig project list Cont. RIH w/ESP completion on 2-7/8" EUE TBG f/8,046'to 10,115'md,testing cable every 1,000' (note splice landed on jt 259). 4/19/2018-Thursday Crew change,check fluids Continue to RIH/w ESP completion on 2-7/8" EUE TBG f/ 10,115'md to 10,800'md. R/U to circulate down the TBG to ensure clear flow path through TBG and pump. Circulate @ 0.5BPM = 1,720psi f/ 10bbls. Pressures leveled off, system seems clear. M/U remaining pipe, P/U TBG hanger and begin ESP cable to penatrator splice. Splice ESP cable to penetrator. Land TBG hanger, 5' mark landing joint as we RIH w/TBG hanger to ensure hanger is properly seated. Note slight rotation as hanger aligned with wellhead alignment pin. Wellhead reps on location to RILDS and set BPV. Baker Centrilift perform Meggar test once hanger landed. Good test. R/D and M/O well L-11. Perform engine service, change all oils and filters on primary power producers. Cont. load trucks w/eq. pull carrier from mud boat, r/d pits & prep to travel, pull floor from well house, n/d BOPE, N/U tree Test void 250/5,000psi, hanger neck seals leaking, N/D tree, replace neck seals, retest,w/same results, simops, load camp &change house, load floor& loader Pull tree & redress neck seals, n/u tree test void 250/5,000psi good. 4/20/2018-Friday No activity to report. 4/21/2018-Saturday No activity to report. 4/22/2018-Sunday No activity to report. 4/23/2018- Monday No activity to report. 8., OF O �//7, sV THE STATE Alaska Oil and Gas �►-l..�i� of /\ sKA Conservation Commission -ire_ - ==_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 t'' Main: 907.279.1433 ®F-ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 S( Anchorage, AK 99501 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-11 Permit to Drill Number: 193-013 Sundry Number: 318-137 Dear Mr. York: 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, Hollis S. French Chair DATED this day of April, 2018. RBDMSiv APR 0 4 2018 • • RECEIVED STATE OF ALASKA MAR �/2� 8 ALASKA OIL AND GAS CONSERVATION COMMISSION /mss' APPLICATION FOR SUNDRY APPROVALSAOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out 0 2.Operator Name: 4.Current Well Class: Hilcorp Alaska LLC Exploratory5.Permit to Drill Number: 3.Address: 3800 Centerpoint Dr,Suite 1400 0 Development El , 193 013 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 7.If perforating: 50-029-22336-00-00 • 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D j Will planned perforations require a spacing exception? Yes 0 No Q ✓ 9.Property Designation(Lease Number): 10. MILNE PT UNIT L-11 Field/Pool(s): • ADL0025509/ADL0355017 '1 MILNE POINT/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): • 11,630' 7,424' 11,400' 7,285' 2,182 V N/A 11,400(Fill) Casing Length Size MD Conductor 80' TVD Burst Collapse 13-3/8" 110' 110' Surface 6,658' 9-5/8" 6,688' N/A 6,688' si 4,588' 6,870 Production P � 4,760psi 11,590' 7" 11,620' 7,418' 7,240psi ( Perforation Depth MD(ft): (Perforation Depth TVD(ft): (Tubing Size: Tubing Grade: p 5,410psi(Tubing MD(ft): See Schematic / See Schematic 2-7/8" 6.5#/L-80/EUE 8rd Packers and SSSV Type: 10,960' Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/11/2018 16.Verbal Approval: Date: OIL Q • WIND ❑ WDSPL ❑ Suspended 0 GAS ❑ WAG 0 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 .C\-- . Authorized Title: Operations Manager Contact Name: Paul Chan Contact Email: pchan(a�hilcorp.com Authorized Signature: i4._ cr.,, aContact Phone: 777-8333 o 1.4. Date: 3/28/2018 COMMISSION USE ONLY - Conditions of approval: Notify Commission so that a representative may witness (Sundry Number: �/-g — /3? Plug Integrity ❑ BOP Test L!0 Mechanical Integrity Test111❑ Location Clearance Other: OZ �L� ,--- /-e— Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /0 —4./a 41 APPROVED BY Approved by: tirggi\------- COMMISSIONER THE COMMISSION Date: y 13/1C) y/3�27k , 3�f/l Form 10-403 Revised 4/2017 Approved application'oRIGIN�' R1�f ffryry■■�� ^� ,•q��p�p pp is valid for 12 months from the date of approvaIPDM� t Flu 7raN �ttac mens up Well Prognosis Well: MPU 1-11 n ron)Alaska,Ili Date:3/28/2018 Well Name: MPU L-11 API Number: 50-029-22336-00 Current Status: Oil Well Pad: L-Pad l Estimated Start Date: April 11th, 2018 Rig: ASR 1 ,/ Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 193-013 First Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFENulrriber' 40 00• a ESP Re 18 Current Bottom Hole Pressure: 2,882 psi @ 7,000'TVDss SBHPS 03/25/2018/7.93 ppg EMW) Maximum Expected BHP: 2,882 psi @ 7,000'TVDss (No new perfs being added) / MPSP: 2,182 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-11 was drilled,fracture stimulated and completed as a Kuparuk River producer in June 1993. ESP installation history: June 1993 (initial),July 1993,April 1994, May 1995, August 2001, March 2009,June 2009, and November 2012. The ESP has failed. Notes Regarding Wellbore Condition ./ ess' • The 7" production casing was tested down to 10,800' MD/3,500 psi on November 12, 2012. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as _/,,. the reservoir pressure is less than 8.55 ppg EMW. d /lc /� /1/41t 4 �"� e.�� Objective: �`P / y.1-f Replace failed ESP. / �v" 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 8.5 ppg sea water 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. II• Well P F nosis Well: MPU L-11 Ilanorp- .a.u Date:3/28/2018 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/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 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 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" test joint. 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 k to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure S 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/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2012 ESP swap was 120K lbs. (40K block weight included) 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 joints 40—105 (Ref: March 26, 2018 Caliper survey) b. Replace bad joints of tubing as necessary and note on tally new tubing run. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs. • Well Prognosis Well: MPU 1-11 Uilrnry Ata ka.L Date:3/28/2018 18. PU new ESP/cap string and RIH on 2-7/8"tubing. Set base of ESP assembly at± 10,960' MD. a. Upper GLM @ ± 140' MD w/SO b. 2-7/8" tubing c. Lower GLM w/DGLV d. 3 joints of 2-7/8" tubing e. 2-7/8" XN (2.205" No-Go) f. 1 joint of 2-7/8" tubing g. Base of ESP centralizer @ ± 10,960' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form Milne Point Unit Well: MP L-11 SCHEMATIC Last Completed: 11/14/2012 HiramPT©: 193-013 Abe@La.Hi TREE&WELLHEAD Orig.KB Elev.:51.00'MSL Tree 2-9/16"-5M Cameron WKM Wellhead 11"x 7"5M WKM w/2-7/8"8rd Treetop Jconnection 2-1/2"Cameron type'H'BPV Profile OPEN HOLE/CEMENT DETAIL 13-3/8 1 13-3/8" Cmt w/500 sx of PF"C"in 30"Hole 9-5/8" Cmt w/1,750 sx Arctic Set III,305 sx Class"G"in 12-1/4"Hole 7" Cmt w/302 sx Class"G"in 8-1/2"Hole Note:Perforated 7"Casing w/9 shots @ 10,990'to 10,992'and squeezed 28 bbls class'G'cement.Tested to 1,875psi F., CASING DETAIL 9 5/8„ Sue Type Wt/Grade/Conn ID Top Btm BPF a 13-3/8" Conductor 54.5/K-55/BTRC 12.615 Surface 110' 0.1546 HOS-SE Cement Tool 9-5/8" Surface 47/N-80/BTRS 8.681 Surface 6,688' 0.0732 @ 1,902' 7" Production 26/L-80/BTRC 6.276 Surface 11,620' 0.0383 TUBING DETAIL I,- 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 10,960' 0.00579 WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=58 deg. @ 7,800'MD Hole Angle through perforations=53 deg. Max Dog Leg 4.65 deg.@1,407'MD JEWELRY DETAIL No Depth Item 1 143' STA#2:Camco 2-7/8"x 1",KBMM GLM dummy 3-14-18 2 10,701' STA#1:Camco 2-7/8"x 1",KBMM GLM open 3-14-18 3 10,854' XN-Nipple: 2-7/8"HES (2.205 No-go ID) - 4 10,896' WeIILift Discharge Gauge Unit 5 10,900.8' Discharge Head:GPDIS 6 10,901' Pump:Type-137-P17,Model-SXD 7 10,920' Gas Separator:GRSFTX AR H6 8 10,925' Upper Seal Section:GSB3DBUT SB/SB PFSA 9 10,932' Lower Seal Section:GSB3DBLT SB/SB FSA 2 10 10,939' Motor: MSP1,210HP/2,380V/53A MIN ID=2.205 a 11 10,956' Sensor:WeIILift MGU @ 10,854' 3 12 10,958' Centralizer/Bottom @ 10,960' PERFORATION DETAIL 4&5 Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 6 1 C1/B6 11,016' 11,036' 7,051' 7,063' 20 6/15/1993 Open B6 11,050' 11,060' 7,072' 7,078' 10 6/15/1993 Open 7 B6 11,087' 11,097' 7,094' 7,100' 10 6/15/1993 Open A3 11,164' 11,184' 7,141' 7,153' 20 6/15/1993 Open i, 8&9 A2 11,197' 11,227' 7,161' 7,179' 30 6/15/1993 Open Al 11,256' 11,286' 7,197' 7,215' 30 6/15/1993 Open 10 All 11,336' 11,346' 7,246' 7,252' 10 6/15/1993 Open 1 12 SPF 5"Casing Guns I � J FRAC DETAIL ET 11 Frac'd w/Total of 191,4711bs of 12-18 ISP 12 - 172,500Ibs of 12-18 ISP behind pipe - GENERAL WELL INFO FISH:4 Flat Guards FCO to 11,400'on API:50-029-22336-00-00 and 3 Bands left in /6/14/2009 Drilled,Cased&Completed by Nabors 22E-6/20/1993 hole below perfs. �r ESP Swap by Nabors 22E -7/9/1993 7 A- ESP Swap-4/26/1994 TD=11,630'(MD)/TD=7,424'(TVD) ESP Swap by Nabors 4ES-5/3/1995&8/20/2001 PBTD=11,492'(MD)/PBTD=7,341'(TVD) ESP Repair by Nabors 3S-3/7/2009,6/16/2009 ESP Repair by Doyon 16-11/14/2012 Revised By:TDF 3/28/2018 Milne Point Unit Well: MP L-11 PROPOSED Last Completed: 11/14/2012 up PTD: 193-{313 TREE&WELLHEAD Orig.KB Elev.:51.00'MSL Tree 2-9/16"-5M Cameron WKM 11"x 7"5M WKM w/2-7/8"8rd Treetop Wellhead connection 2-1/2"Cameron type'H'BPV Profile J'' } OPEN HOLE I CEMENT DETAIL 133/8" -,1 13-3/8" Cmt w/500 sx of PF"C"in 30"Hole 9-5/8" w/1, sAcSet , C "G" /4" 7" CmtCmt w/302 sx750 Classxr "G"in 8-1/2III "Hole lass Note:Perforated 7"Casing w/9 shots @ 10,305990'sx to 10,992'an squeezed 28 bbls class`G'cement.Tested to 1,875psi CASING DETAIL 35/8„-� Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 54.5/K-55/BTRC 12.615 Surface 110' 0.1546 HOS-SE Cement Tool 9-5/8" Surface 47/N-80/BTRS 8.681 Surface 6,688' 0.0732 @1,902 7" Production 26/L-80/BTRC 6.276 Surface 11,620' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 10,960' 0.00579 Pi WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=58 deg. @ 7,800'MD Hole Angle through perforations=53 deg. Max Dog Leg 4.65 deg.@1,407'MD JEWELRY DETAIL a No Depth Item 1 ±143' STA#2:GLM 11 2 ±10,701' STA#1:GLM 3 ±10,854' XN-Nipple 4 ±10,896' Discharge Gauge Unit ' 5 ±10,900.8 Discharge Head 6 ±10,901' Pump il 7 ±10,920' Gas Separator 8 ±10,925' Upper Seal Section 9 ±10,932' Lower Seal Section Sol 2 iir 10 ±10,939' Motor MINID=2.20 11 ±10,956' Sensor @ 10,854' iih 3 12 ±10,958' Centralizer/Bottom @±10,960' PERFORATION DETAIL 4&5 it; Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 6 C1/86 11,016' 11,036' 7,051' 7,063' 20 6/15/1993 Open B6 11,050' 11,060' 7,072' 7,078' 10 6/15/1993 Open B6 11,087' 11,097' 7,094' 7,100' 10 6/15/1993 Open 8&9 A3 11,164' 11,184' 7,141' 7,153' 20 6/15/1993 Open A2 11,197' 11,227' 7,161' 7,179' 30 6/15/1993 Open Al 11,256' 11,286' 7,197' 7,215' 30 6/15/1993 Open 10 Al! 11,336' 11,346' 7,246' 7,252' 10 6/15/1993 Open is 12 SPF 5"Casing Guns F�t FRAC DETAIL 12 Frac'd w/Total of 191,4711bs of 12-18 ISP 172,SOOIbs of 12-18 ISP behind pipe GENERAL WELL INFO FISH:4 Flat Guards FCO to 11,400'on API:50-029-22336-00-00 and 3 Bands leftin /6/14/2009 hole below pens.--�* Il Drilled,Cased&Completed by Nabors 22E-6/20/1993 ESP Swap by Nabors 22E -7/9/1993 7 a II ESPSwap-4/26/1994 TD=11,630'(MD)/TD=7,424'(TVD) ESP Swap by Nabors 4ES-5/3/1995&8/20/2001 PBTD=11,492'(MD)/PBTD=7,341'(1VD) ESP Repair by Nabors 3S-3/7/2009,6/16/2009 ESP Repair by Doyon 16-11/14/2012 Revised By:TDF 3/28/2018 . iii Milne Point ASR Rig 1 BOPE Hamm"Um4 a,tit 2018 11" BOPE , Stripping Head I i 1 4.48' —T 3- ydrilG ._ 11" - 5000 lid tilli['1lt11li l inn III ill in ill 4.54' K. ) - CI ® U �� m° VBR or Pipe Rams mu : r - �� 11"- 5000 =B Blind � ' 1di. di Iii ill III 2 1/16 5M Kill Line Valves s 2 1/16 5M Choke Line Valves — V J6j iiri1Pi ritl'I11 - - E 2.00' 11 �l ( N t ° li�i■11hii'i�iiii.lilit - � € - Manual Manual Manual HCR Updated 1/05/2018 . MPL-11 Swab valve CIW_FL-2 9/16" 3-23-185K, manual gate valve, EE 2 9/16" tree w/ 2 7/8 PSL2,PR2 INI Tbg Hgr. Prepped for 1 17,16mai PN ea. 1/4" Control line, lea MEP' ®�® ESP . comes with 2 /z "H" �, Wing valve CIW_FL-2 9/16" A. BPV prep. Comes with 0 r 5K, manual gate valve, EE alignment screw and non- 0 0 PSL2,PR2 rotating flanges. NoPN 931 WO 11111 control line, W/ESP I " 0r..o g, ; 7 SSV CIW_FL-2 9/16" 5K, --„ _ manual gate valve, EE ®�,�� ' PSL2,PR2 d , / N PN reverse actuating gate OW" """' valve, w/ Baker actuator PN a: 1�� Master CIW_FL-2 9/16" 5K, � , manual gate valve, EE ( : PSL2,PR2 d1d ruw PER Tbg Hgr PN WKM TDF 11" 5K x 2 9/16" (. 5K, w/1 ea 1/4" NPT control ---,,,,„1„, Tbg Hd adapter WKM 11" line re lea BIW ESP 103 0 0 5K x 2 9/16" 5K, w/lea prep, 1111.1111111111111.—..— 11 .11 penetrator. . Prepped for control line prep exit block 2 1/2" "H" BPV and lea BIW-103- ESP PN 441741 penetrator preps and lea HT SN 2033519 — penetrator prep. PN 441743 Cil _ IJ SN - J I � � I_ t=om - imile_LI )041 '4) 1 o (LN1-11)111 T 1 n J I z - r. - C)> � 7ƒ ° ,/ > 0�\ \ a§ « E / • c o 7 -a in' \ %Y > d / 2 f a� 4 a ±/ « m 2 B D2 / / 22 \ 2 otP @ < a� & = I a) ƒ 7 � m § .@ ■ ■ 3 \ k CO % E E\ / 9- CD L. % / 5 0 2 § O > CO a) /� 2 a e \ 0 2 f / 2 \ L o L. / � o CD L. E § 0 k / / i 2 / a -ao »& ( f > \ / Zr) c 2 — co 0. k Co kG e CO « m ' / CID 0CNI % / 0 cn 2 CO- ■Ct ¥ a g °01 a) ® o $ R ' co12 ■ CO CO / A O O ■ U .o » a § .. « / _ . . a q 0 E0 / k , $ g a 0 o $ k \ / Cl. / . XHVZE Pages NOT Scanned in this Well History File 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. / ~,,~" 0 [~ File Number of Well History File PAGES TO DELETE Complete 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 COMMENTS: Scanned by: _~. Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si UNSCANNED, OVERSIZED MATERIALS AVAILABLE C~G.~ FILE # ~4 a r To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 STATE OF ALASKA Ai RECEIVED SKA OIL AND GAS CONSERVATION MISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS NOV 2 8 2012 1. Operations Performed: AUGCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program El Operation Shutdown ❑ Stimulate - Other ❑ 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 193 -013 3. Address: Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 22336 - 00 - 00 7. Property Designation (Lease Number): , 8. Well Name and Number: ADL 025509 & 355017 MPL - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Oil Pool 11. Present well condition summary: Total depth: measured 11630' feet Plugs:(measured) None feet true vertical 7424' feet Junk: (measured) –11400' feet Effective depth: measured 11492' feet Packer: (measured) None feet true vertical 7341' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 - 3/8" 30' - 110' 30' - 110' 2730 1130 Surface 6659' 9 -5/8" 29' - 6688' 29' - 4588' 6870 4760 Intermediate Production 11592' 7" 28' - 11620' 28' - 7418' 7240 5410 Liner Perforation Depth: Measured Depth: 11016' - 11346' feet True Vertical Depth: 7051' - 7252' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8, 6.5# L -80 10960' 6855' Packers and SSSV (type, measured and true vertical depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: FEB Q gn13 SCANNED EB U 2V 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 153 28 853 290 243 Subsequent to operation: 136 25 775 200 223 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: e ® Oil ❑ Gas ❑ WDSPL 0 Well Schematic Diagram ❑ 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: Contact: David Bjork, 564 -5683; David.Bjork@bp.com Email: Joseph.Lastufka @bp.com Printed Na' - Joe a . Title: Drilling Technologist Signature: 1 — Phone: 564 - 4091 Date: N II�� -- Form 10-404 Revi 10/2012 DMS NOV 2 9 2012 �� VGf /Z/ Z 7 -/, // b mit Original Only • • Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/9/2012 18:00 - 21:00 - SET HERCULITE AN 3.00 MOB P PRE MOVE RLOOLG IT _M MOVE CEN CUTTINGS IIFT TANK D RIG MATS AROUND MPL -11 21:00 - 00:00 3.00 MOB P PRE PJSM, PULL OFF OF MPL -36 IN - SPOT RIG OVER WELL MPL -11 SHIM RIG, SECURE STAIRS AND UN LANDINGS, LOWER CELLAR DOORS RS TN S P RP CUTTINGS PITO TAKE TANK AND FUEL TANK 11/10/2012 00:00 - 03:00 3.00 WHSUR P DECOMP RIG ACCEPTED - AT MIDNIGHT BRI 00: 00 HOURS PJSM, R/U WELL KILL CIRCULATING LINES SPOTFLOW BACKTANK MPU VALVE CREW GREASED VALVES ON CAMERON TREE, INSTALLED FLANGE ON OA imC MPLETE WELL TRANSFER PERMIT FOR -36 Rpi G UP HOT OILER ON DRILL MPL - OF EGRES S AND PROPER RE -ENTRY PROCEDURES ALL DS, TRU DRIVERS, HOT OILERS, WSL, TOUR PUSHER , SITE CONTROL 03:30 - PRESENT 06:00 2.50 WHSUR P DECOMP CONTINUE RIG UP TEST LINES - WI 9.3 PPG BRINE - R/U HARDLINE TO FLOW BAK TANK - TEST FILL ALL WELL TH KILL CIRCUL TING LINES A - TEST TO 250 / 3500 PSI, 5 MIN, CHARTED 06:00 - 07:00 1.00 KILLW P DECOMP PJSM, FILL HARD LINE AND MANIFOLD WITH DIESEL - PRESSURE TEST LINES TO 250 / 3500 PSI F/ 5 CHARTED MINUTES. PASSED. BLOW DOWN ALL SURFACE LINES 07:00 - 07:30 0.50 KILLW N WAIT DECOMP WAIT ON MPU WELL SUPPORT CREW 07:30 - 08:00 0.50 KILLW P DECOMP PJSM, WITH WELL SUPPORT CREW M/U LUBRICATOR AND PRESSURE TEST TO 250 / 3500 PSI F/ 5 CHARTED MINUTES. PASSED. 08:00 - 08:30 0.50 KILLW P DECOMP - PULL SITP = 1 BPV 100 PSI - = 1100 - RID LUBRICATO R. 08:30 - 10:00 1.50 KILLW P DECOMP P SICP JSM C TU O, O, - WSL, DRILLER AND WSL, MUD MAN SCS, CK & RIG ESC, . - COVERED DDI KILLI THE PS WEL L SOP PUSHER TOOL PUSHER VERIFY VALVE ALIGMENT. Printed 11/28/2012 9:49:35AM N o l a AL e,. Operation Summary F3e .. Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 17:00 7.00 KILLW P DECOMP NOTIFY MPU AND PAD OS OF VENTING GAS OPS. - BLEED GAS TILL FLUID RETURNS ARRIVE AT SURFACE - IA PRESSURE DECREASED FROM 1100 PSI TO 250 PSI IN 15 MINUTES - SITP DECREASED TO 700 PSI - PUMPED 65 BBLS HEATED KWF (9.2 PPG BRINE) DOWN THE TBG, THRU THE CHOKE SKID TO THE FLOW BACK TANK - ICP =3 BPM / 700 PSI, FCP = 250 PSI ,MAINTAINING 150 PSI DOWN STREAM OF CHOKE BULL HEAD 40 BBLS KWF DOWN THE TBG INTO THE FORMATION - 3 BPM /250 -1000 PSI - PUMP 525 BBLS KWF DOWN THE TBG UP r THE IA THRU THE CHOKE SKID TO THE FLOW BACK TANK. 4 -1/2 BPM @ 2200 - 2500 PSI- MAINTAINING 150 PSI DOWN STREAM OF CHOKE - VERY THICK CRUDE MIXED WITH —70 PERCENT GAS FOR MOST OF THE ENTIRE CIRCULATION - KWF ARRIVED AT SURFACE AFTER —480 PUMPED - CLEAN 9.2+ PPG KWF AT SURFACE AFTER 528 BBLS PUMPED. - SITP = 15, SICP = 15. LOST 168 BBLS TO THE FORMATION. - DISCUSS WITH RWO ENGINEER AND DRILLING SUPERINTENDENT TO CONTINUE CIRCULATION. - CIRCULATE 336 BBLS KWF DOWN THE TBG UP THE IA THRU THE FULL OPEN CHOKE / GAS BUSTER TO THE PITS - 4.5 BPM / 1400 PSI - LOST 44 BBLS DURING THIS CIRCULATION. - MONITOR WELL FOR 30 MINUTES, WELL IS STATIC. - DURING WELL KILL, PUMPED 636 BLS IN, 359 BBLS OUT = 277 LOSS, ( INCLUDES 40 BBLS LOSS FROM BULLHEAD) - JOHN CRISP OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST 11/10/12 @ 1600 HOURS 17:00 - 19:00 2.00 KILLW P DECOMP PJSM, BLOW DOWN ALL SURFACE LINES - R/D SURFACE LINES AND KILL MANIFOLD SKID. - 290 BBLS CRUDE SENT TO MILNE POINT RECYCLE Printed 11/28/2012 9:49:35AM Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 19:00 - 21:30 2.50 WHSUR P DECOMP PJSM, R/U AND TEST WELL SUPPORT LUBRICATOR - TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, CHARTED - INSTALL TWC - PERFORM ROLLING TEST FROM BELOW, 1.5 BPM = 500 PSI,10 MINUTES TEST FROM ABOVE, 250 / 3500 PSI, 5 MIN, CHARTED R/D LUBRICATOR AND TEST EQUIPMENT 21:30 - 00:00 2.50 WHSUR P DECOMP PJSM WITH CAMERON HANDS R/D TREE AND ADAPTER FLANGE CAMERON REP'S CLEANED AND INSPECTED TREE AND ADAPTER CHECK HANGER THREADS = 8.5 TURNS, 2 7/8" 8 RD EUE - PREP TO N/U BOP - 24 HOUR FLUID LOSS = 105 BBLS (POST WELL KILL = -15 BPH) 11/11/2012 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM, PERFORM EQUIPMENT CHECKS CONTINUE N/U BOP - R/U TEST EQUIPMENT M/U FLOOR VALVES AND PREP CHOKE MANIFOLD FOR TEST 02:30 - 07:30 5.00 BOPSUR P DECOMP PJSM, BOPE TEST - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -- TEST ANNULAR WITH27 /8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST UPPER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST LOWER RAMS WITH 2 7/8" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST - BLOW DOWN LINES AND R/D TEST EQUIPMMENT - JOHN CRISP OF AOGCC WAIVED ST:TE RIGHT TO WITNESS BOP TEST 11/10/12_@ 1600 HOURS - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST, FLUID LOSS = 11 BPH 07:30 - 09:00 1.50 WHSUR P DECOMP PJSM, PULL TWC - R/U DSM LUBRICATOR AND EXTENSION - PRESSURE TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, CHART - PULL TWC, TUBING AND IA ARE ON A VACUUM - R/D DSM LUBRICATOR Printed 11/28/2012 9:49:35AM Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:00 1.00 WHSUR P DECOMP PJSM, BOLDS AND PULL TUBING HANGER - M/U 2 7/8" TUBING JT WITH FOSV - WSL VERIFY NO TRAPPED PRESSURE UNDER HANGER - CAMERON WELL HEAD REP, BOLDS - PULL TUBING HANGER OFF SEAT @ 120K, PUW =115K 40K TOP DRIVE WT INCLUDED - CUT ESP CABLE AND UD TBG HANGER - M/U LANDING JT, POSITION SLICK PIPE ACROSS BOP STACK 10:00 - 12:00 2.00 WHSUR P DECOMP CIRCULATE 40 BBL DEEP CLEAN SWEEP SURFACE TO SURFACE THRU GAS BUSTER 3BPM =810 PSI '` LOST 90 BBLS TO WELL DURING CIRCULATION 12:00 - 13:00 1.00 WHSUR P DECOMP PERFORM TOP DRIVE INSPECTION - MONITOR WELL FOR 30 MIN = 10 BPH LOSS RATE -DRAIN GAS BUSTER 13:00 - 00:00 11.00 WHSUR P DECOMP PJSM, PULL 2 7/8" 6.5# EUE 8RD ESP COMPLETION W/ CENTRILIFT REP - F/ 10960' T/ 1252' - PUW = 115K, SOW = 75K, INCLUDES 40K TOP DRIVE WT - HANG ESP SHEAVE IN DERRICK - SNAKE ESP CABLE OVER SHEAVE TO SPOOLING UNIT - PULL ESP COMPLETION, STAND BACK IN DERRICK - L/D 1 GLM - NOTED SOME BENT PIPE IN FIRST 14 STANDS PULLED - MAINTAIN CONTINUOUS HOLE FILL @ — 10 BPH LOSS RATE - 9.25 PPG - ESP CABLE AND PIPE VERY CLEAN -OA =0 PSI - 24 HOUR FLUID LOSS = 283 BBLS 11/12/2012 00:00 - 01:30 1.50 PULL P DECOMP PJSM, PERFORM SAFETY AND EQUIPMENT CHECKS - CONTINUE POOH WITH 2 -7/8" ESP COMPLETION F/ 1252' T/ MOTOR 01:30 - 03:30 2.00 PULL P DECOMP PJSM, UD CENRILIFT PUMP AND MOTOR - DRAIN AND UD MOTOR AND PUMP ASSY - SPOOL UP REMAINDER OF ESP CABLE - LASALLE CLAMPS = 179 - PROTECTOLIZERS = 5 - FLAT GUARDS = 3 - CANNON CLAMPS = 2 - ESP MOTOR IN GOOD CONDITION - FOUND SHAFT BROKEN IN PUMP 03:30 - 05:00 1.50 PULL P DECOMP R/D ESP EQUIPMENT - R/D ESP TRUNK AND SHEAVE - CLEAN AND CLEAR RIG FLOOR - INSTALL WEAR BUSHING, ID = 6 3/8" Printed 11/28/2012 9:49:35AM Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 11:30 6.50 CASING P DECOMP PJSM, M/U 7" CHAMP PACKER - MOBILIZE 7" CHAMP PACKER TO RIG FLOOR - RIH ON 2 7/8" EUE 8RD STANDS FROM DERRICK - T/ 10800' MD. - MAINTAIN CONTINUOUS HOLE FILL @ —8 -10 BPH LOSS RATE. 11:30 - 12:00 0.50 CASING P DECOMP "'PJSM, SET 7" CHAMP TEST PACKER AND MIT -IA. PUW = 87K, SOW = 75K INCLUDES TOP DRIVE WT. - 5 BPM / 1500 PSI A CROSSED SETTING DEPTH, 4 TIMES. - SET 7" CHAMP AT 10,800' MD - W/ 20K DOWN WT. 12:00 - 13:00 1.00 EVAL P DECOMP PJSM, AT TOUR CHANGE ON PERFORM MIT -IA. - WSL I TOOLPUSHER VERIFY VALVE ALIMENT. CLOSE PIPE RAMS. - PRESSURE UP TO 3500 PSI W/ 4 BBLS KWF. OA PRESSURE WAS LESS THEN 10 PSI DURING TEST. 3500 PSI FOR 30 CHARTED MINUTES. - MIT -IA PASSED CRT- AK- 10 -45. - RECEIVED PERMISSION TO PROCEED FROM WTL. - BLEED OF TEST PRESSURE. - DRILLER AND WSL VERIFY NO TRAPPED PRESSURE. - OPEN PIPE RAMS. - BREAKING CIRCULATION. - 87K TO RELEASE TEST PACKER WITH HES REP PRESENT. 13:00 - 13:30 0.50 CASING P DECOMP MONITOR WELL WITH HOLE FILL PUMP. - ALLOW TEST PACKER ELEMENTS TO RELAX. - BLOW DOWN TOP DRIVE AND LINES. - 10 BPH LOSS RATE. - PJSM, POH. 13:30 - 19:30 6.00 EVAL P DECOMP POH FROM 10800' MD W/ 7" CHAMP TEST PACKER. • - PULL 10 STANDS SLOW. - STOP AND MONITOR WELL 10 MINUTES. - LOSS RATE —10 BPH WITH CONTINUOUS HOLE. - CONTINUE POH AT REDUCED TRIP SPEED, PER WSUHES REP. TO SURFACE - 1600 HRS PHASE 1 WITH 20 MPH WIND. 19:30 - 20:00 0.50 EVAL P DECOMP CLEAN CLEAR RIG FLOOR - UD HES 7" CHAMP PACKER 20:00 - 23:30 3.50 EVAL P DECOMP PJSM, WITH SCHLUMBERGER WIRELINE - R/U DUTCH RISER SYSTEM - MOBLIZE WIRELINE TOOLS TO RIG FLOOR - R/U WIRELINE SHEAVES AND M/U LOGGING TOOLS Printed 11/28/2012 9:49:35AM Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:30 - 00:00 0.50 EVAL P DECOMP BEGIN LOGGING RUNS - RUN #1 = MTT AT 5 AND 8 HZ (MEMORY) - RUN #2 = PDS CALIPER LOG -OA =0 PSI - 24 HOUR FLUID LOSS = 223 BBLS 11/13/2012 00:00 - 04:30 4.50 EVAL P DECOMP PJSM, CONTINUE LOGGING RUNS RUN #1 = MTT AT 5 AND 8 HZ (MEMORY) - RUN #2 = PDS CALIPER LOG - MAINTAIN CONTINUOUS HOLE FILL WHILE LiGGING - FLUID LOSS = 10 BPH 04:30 - 06:00 1.50 EVAL P DECOMP PJSM, R/D SVVS SLICK -LINE OPS - RID SWS TOOLS & EQUIPMENT. - R/D DUTCH SYSTEM. - PULL WEAR RING - CLEAN RIG FLOOR. 06:00 - 07:00 1.00 RUNCOM P RUNCMP PJSM, R/U COMPLETION RUNNING EQUIPMENT. - HANG ESP CABLE SHEAVE IN DERRICK. SPOT ESP CABLE SPOLLER & HOOK UP. 07:00 - 07:30 0.50 WHSUR P RUNCMP PJSM, WITH CAMERON REP. MAKE DUMMY TBG HANGER RUN. - STOP AND REMOVE SEALS TO PREVENT POSSIBLE DAMAGE TO ALIMENT PIN. - DUE TO LACK OF STRING WEIGHT. 07:30 - 08:00 0.50 RUNCOM P RUNCMP PJSM, WITH CENTRILIFT REP. - R/U FLOOR TO RUN ESP COMPLETION. 08:00 - 12:00 4.00 RUNCOM P RUNCMP PU /MU ESP PUMP AND MOTOR ASSEMBLY. - SERVICE WITH OIL AND INSTALL INJECTION LINE. 12:00 - 12:30 0.50 RUNCOM P RUNCMP CREW CHANGE, - SERVICE TOP DRIVE. - PERFORM PRETOUR INSPECTIONS. 12:30 - 20:30 8.00 RUNCOM P RUNCMP RUN ESP COMPLETION ON 2 -7/8" 8R EUE, 6.5# L -80 TBG. - FROM DERRICK. - TORQUE TBG TO 2300 FT LBS, USING OPTIMUM TORQUE VALUE. - USE BOL 2000 PIPE DOPE. - ONE LASALLE CLAMP ON THE FIRST 9 JTS, THEN ONE PER STAND OF TBG. - EVERY 2000' MD FLUSH PUMP W/ 5 BBLS KWF - 1990' MD= 1/2 BPM 1110 PSI. 3919' MD= 1/2 BPM 1029 PSI. - 5839' MD= 1/2 BPM 1450 PSI. 7759' MD= 1/2 BPM 1600 PSI. - CENTRILIFT REP CHECK CONDUCTIVITY EVERY 2000' MD. - RIH WITH 81 STANDS 2 7/8" TBG TO 7759' MD. - MAINTAIN CONTINUOUS HOLE FILL @ 10 BOH LOSS RATE / 9.2# BRINE. - AVERAGE FLUID LOSS RATE WHILE RIH 7 BPH 9.2 PPG BRINE. Printed 11/28/2012 9:49:35AM • Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 0OWPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 00:00 3.50 RUNCOM P RUNCMP _S PLICE TEST COND ESP CABLE PER OF CENTRA ESP LIFT REP. U CONDUCTIVITY CABLE. - SPLICE LOCATED @ 83 STANDS 7945' MD. - USE CONTINUOUS HOLE FILL. - WELL TAKING 7.5 BPH 9.2 PPG BRINE. LAST 24 HRS WELL TOOK 188 BBLS 9.2 PPG BRINE. 11/14/2012 00:00 - 03:00 3.00 RUNCOM P RUNCMP RUN ESP COMPLETION ON 2 -7/8" 8R EUE, 6.5# L -80 TBG FROM 7945' MD FROM DERRICK. TORQUE TBG TO 2300 FT LBS, USING OPTIMUM TORQUE VALUE. - USE BOL 2000 PIPE DOPE. - INSTALL LASALLE CLAMP ONE PER STAND OF TBG. - EVERY 2000' MD FLUSH PUMP W/ 5 BBLS KWF - 9717' MD= 1 /2 "BPM 1880 PSI CENTRILIFT REP CHECK CONDUCTIVITY EVERY 2000' MD. -,RIH TO 10943' MD. MAINTAIN CONTINUOUS HOLE FILL WITH 9 - .2# BRINE. - AVERAGE FLUID LOSS RATE WHILE RIH @ 7 BPH. 03:00 - 05:00 2.00 RUNCOM P RUNCMP M/U 11" X 2 8" R - POSITION 7/ HANGER TBG FOR HANGE ALIGNMENT. . P - CENTRILIFT MAKE FINAL CHECKS. - INSTALL PENETRATOR. - CENTRILIFT REP TERMINATE ESP CABLE. 05:00 - 06:00 1.00 RUNCOM P RUNCMP PJSM, LAND CAMERON TBG HANGER. - LAND WITH TWC INSTALLED. - 10,959' MD. - PUW =100K, SOW = 80K (INCLUDES TOP DRIVE WT.) WSL / CAMERON REP VERIFY ALIGNMENT WHILE LANDING. - RILDS 06:00 - 07:00 1.00 RUNCOM P RUNCMP PRESSURE TEST TWC. - PERFORM ROLLING TEST FROM BELOW TWC. - 1.6 BPM / 600 PSI FOR 10 CHARTED MINUTES. PASSED. 26 BBLS PUMPED DURING ROLLING TEST. - 5 BBLS BLED BACK. - 3500 PSI TEST FROM ABOVE FOR 5 CHARTED MINUTES. PASSED. 07:00 - 09:00 2.00 RUNCOM P RUNCMP AND PJSM, BARRIERS HANGER INL SEALS PLACE- , 9.2 TESTED KWF. TWC PPG - N/D BOPE. - MONITOR VA - CHANGE LOWER BOP RAMS. - 2 -7/8" X 5" VBR - N/D BOPE AND SET BACK STACK. - CLEAN PITS. 09:00 - 10:00 1.00 RUNCOM P RUNCMP NU 11" 5M, PRODUCTION ADAPTOTREE. R FLANGE & 2- 9/16" Printed 11/28/2012 9:49:35AM Common Well Name: MPL -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/9/2012 End Date: X4- 00WPM- E:DRILL (1,900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/27/1993 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @51.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 11:30 1.50 RUNCOM P RUNCMP CAMERON REP TESTED ADAPTER FLANGE TO 250 PSI FOR 5 CHARTED MIN. PASSED. - AND 5000 PSI FOR 30 CHARTED MIN. PASSED. - TREE TESTED 250 PSI & 5000 PSI WITH DIESEL - FOR 5 CHARTED MIN. PASSED. CENTRILIFT REP TAKE FINAL READINGS. 11:30 - 13:30 2.00 RUNCOM P RUNCMP PJSM WITH DSM. PU /MU DSM LUBRICATOR. - PRESSURE TEST 250 PSI & 3500 PSI FOR 5 CHARTED MIN. PASSED. - PULL TVVC. 13:30 - 15:00 1.50 WHSUR P RUNCMP P/U BPV MU DSM LUBRICATOR PRESSURE TEST 250 PSI & 3500 PSI FOR 5 CHARTED MIN. PASSED. - INSTALL 2- 1/2" TYPE 'H' BPV. - PERFORM ROLLING TEST FROM BELOW -1.5 BPM / 500 PSI FOR 10 CHARTED MIN. PASSED. - 21 BBLS PUMPED DURING ROLLING TEST. 7.2 BBLS BLED BACK. BARRIERS IN PLACE, TESTED TREE, BPV AND HANGER SEALS. - E -MAIL 24 HRS NOTICE TO AOGCC @ 14:48 HRS 11- 14 -12. 15:00 - 18:00 3.00 RIGD P RUNCMP PJSM. BLOW DOWN ALL SURFACE LINES. - CLEAN PITS, VAC OUT CUTTINGS BOX. - LAY HERCULITE AND MATS AROUND MPL -29. - CLEAR AND PREP CELLAR. - PREP FOR RIG MOVE. - WARMUP RIG MOVE SYSTEM. - RAISE FRONT AND REAR CELLAR DOORS. - WELL TOOK 105 BBLS 9.2 PPG BRINE LAST 18 HRS. - RIG RELEASED FROM MPL -11 AT 18:00 HRS. Printed 11/28/2012 9:49:35AM Tree: 2 9/16" 5M WI MPU L -11 v. Orig. D = 50' Wellhead: 11" x 7" 5M OM Orig. Gv. = 17.7' w/ 2 7/8" 8rd treetop connection 2 1/2" Cameron type "H" BPV Profile 13 3/8" 54.5 ppf K -55 110' N " Camco 2 -7/8" x 1" 143' KOP @ 400' sidepocket KBMM GLM Max. hole angle = 58 deg @ 7800' MD Max dog leg 4.65 deg @ 1407' MD Hole angle thru' perfs = 55 deg 0 7" HES - ES Cement Tool @ 1902' MD 9 5/8" 48 ppf, N -80 BTC 1§.07•1 and A 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7 ", 26 ppf, L -80, Btrc. Mod. prod. casing ( drift I D = 6.151", cap. = 0.0383 bpf ) Camco 2 -7/8" x 1" 10,701' * : p g sidepocket KBMM GLM „, 2 -7/8” XN nipple 10,854' (No -Go ID 2.25 ") WeIILift Discharge Gauge Unit 10,896' i v2 Note: 28 bbl class G cement EMI Discharge Head /GPDIS 10,900' behind 7" casing through perfs at 10,992' and tested to 1875 psi Centrilift ESP 10,901 ` p 137 -P17 SXD Pump Stimulation Summary GRSFTXARH6 10,920' Frac'ed with 172,500 lbs of 12 -18 ISP Tandem Seal Section behind pipe, June 1993 GSB3 DB UT /LT SB /SB PFSA /FSA CL5 1 0,925' Motor: MSP1 10,939' Ma 1 Man 210 HP, 2380 V, 53 Amp, WeIILift MGU Sensor 10,957` w/ 6 fin Centralizer Perforation Summary A, B and C Kuparuk Sands I I Size SPF Interval MD (TVD) 5" 12 11016`- 11036' 7055' - 7065 5" 12 11050`- 11060' 7073' 7078' I 5" 12 11087`- 11097' 7096' 7102' 5" 12 11164'- 11184' 7146' 7154' — I 5" 12 11197`- 11227' 7162' 7180' 5" 12 11256`- 11286' 7197' -7215' 5" 12 11336`- 11346' 7245` - 7251' 1 /CpO BTD to 11400' during RWO 6 -16 -09 7320' TVD I 11,492' md) FISH - 4 Flat Guards and 3 Bands left in hole below perfs 7" float shoe d I%l i 2- DATE REV. BY COMMENTS MILNE POINT UNIT 06/20/93 Initial Completion 5/94 M. Linder RWO WELL L -11 4/95 1 B. BR RWO WO Nabors 4ES API NO: 50- 029 -22336 3/7/09 REH RWO Nabors 3S 6/16/09 L. Hulme RWO & FCO - Nabors 3S 11/14/12 REH ESP RWO Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP RT OF SUNDRY WELL OPE~TIONS 1. Operations Performed: ~ ^ ^ ^ p~~~~~ Su ~~~ ^ Abandon Repair Well Plug Perforations Stimulate Re-Enter spen Well ^ Alter Casing ~ Pull Tubing ^ PerForate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown Chane out ESP ` ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 193-013 • 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22336-00-00 ~ 7. KB Elevation (ft): 5~, 9. Well Name and Number: MPL-11 • 8. Property Designation: ~~~ ~~ ~ ~`~ 10. Field / Pool(s): v,'/ ~.,`~l ~j~ ~~` ADL355017 ~ e Milne Point Uni t/ Kuparuk River s l- 11. Presentwell condition summary ~I~.U ; ~~7 ~,~ •~t Total depth: measured ~ feet true vertical 7424 ^~ feet Plugs (measured) None Effective depth: measured 11492 feet Junk (measured) ~11400' (Fish) true vertical 7341 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 110' 110' 2730 1130 Surface 6658' 9-5/8" 6688' 4588' °~ ~ 687~"~ 4760 Intermediate Production 11590' 7" 11620' 7418' 7240 5410 Liner ~~~~~~ Ui.. %~ ~FY~ Y i! ~" Z~~l~ Perforation Depth MD (ft): 11016' - 11346' Perforation Depth TVD (ft): 7051' - 7252' 2-7/8, 6.5# L-80 10952' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None . 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 43 11 371 260 232 Subsequent to operation: 207 ° 36 897 280 234 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number ~"~ 3"'(~ Sig ature Phone 564-4750 Dat Sondra Stewman 564-a~50 Form 10-404 Revised 04/2006 ~~ ~~. .fu~ ~ ~ 200~ ~~c~iv~~ ~u~ ~ ~ ~~~~ ~ ~~~~ ,~q Submit Original Only ~`~Icy.~ `~ ``~~~~ ~"~'/y/"~ Tree: 2 9/16" - 5M W Welihead: 11" x 7" 5M . w/ 2 7/8" 8rd treetop connection 2 1/2" Cameron type "H" BPV Profile 13 3/8" 54.5 ppf K-55 110' MPU L-11 Orig. DF v. = 50` Orig. GL~. = 177` KOP @ 400' Max. hole angle = 58 deg @ 7800` MD Max dog leg 4.65 deg @ 1407` MD Hole angle thru' perfs = 55 deg 9 5/8" 48 ppf, N-80 BTC ' md ~ ~~ ~ 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26 ppf, L-80, Btrc. Mod. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) Note: 28 bbl class G cement behind 7" casing through perfs at 10,992` and tested to 1875 psi Stimulation Summary Frac'ed with 172,500 ibs of 12-18 ISP behind pipe, June 1993 Perforation Summary A, B and C Kuparuk Sands Size SPF Interval MD (TVD) 5" 12 11016`-11036 7055` - 706 5" 12 11050`-1106 707: - 707 5" 12 11087`-1109 709E - 710 5" 12 11164`-1118 714 '- 715 5" 12 11197`-1122 716: '- 718 5" 12 11256`-1128 7197` - 721 5" 12 11336`-1134 7245` - 725 I FISH - 4 Flat Guards and 3 Bands left in hole below perfs DATE IFiEV. BY 1 COMMENTS 5/94 M. Linder RWO 21 ~ RWO 501 8/ B. Hasebe Nabors 4ES 3/7/09 REH RWO Nabors 3S 6/16/09 L. Hulme RWO & FCO - Nabors 3S Camco 2-7/8" x 1" 141' sidepocket KBMM GLM 7" HES - ES Cement Tool @ 1902' Camco 2-7/8" x 1" 10,730` sidepocket KBMM GLM 2-7/8" XN nipple 873' 10 (No-Go ID 2.25") , WeIILift Discharge Gauge Unit 1 ~,888` Discharge Head/GPDIS 10,893` Centrilift ESP ` 137-P17 SXD Pump 10,894 Gas Separator 10 913' GRSFTXARH6 , Tandem Seal Section 918` 10 GS63 DB UT/LT 56/SB PFSAlFSA CL5 , Motor, KMH-A, Rerated: 931 ` 10 140 HP, 2244 V, 37 Amp, , WeIILift MGU Sensor 948` 10 w/ 6 fin Centralizer , PBTD 7320' TVD 11,492' m 7" float shoe ~~(,,~p'~,,d, ~,zg md MILNE POINT UNIT WELL L-11 API NO: 50-029-22336 BP EXPLORATION (AK) • • c~peraYions summary ~eport Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 6/9/2009 End: 6/16/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/16/2009 Rig Name: NABORS 3S Rig Number: Date From - Tca Hours Task Cod~ NPT Phase D~scription of ~peratic~ns 6/11/2009 02:00 - 03:00 1.00 RIGD P PRE RD floor and Derrick board. Prep for laying over Derrick. Disconnect steam lines. RD upright tank and pull away blow down tank and cuttings box. 03:00 - 03:30 0.50 RIGD P PRE Scope down and lay over Derrick. 03:30 - 06:00 2.50 RIGD P PRE Jack down pits and pipe shed. Disconnect electrical lines. Separate modules from carrier. Roll carrier tires. Jack down carrier. Prep rig for move. 06:00 - 09:00 3.00 MOB P PRE Held safety meeting with Truck crew on Rig move. Move Pipe shed and Pits around Pad. Move Carrier off MPL-29 with Pad Operator and BP / WSL present. 09:00 - 11:00 2.00 MOB P PRE Lay Rig mats and position BOP cradle behind MPL-11. Spot Carrier over MPL-11 with Pad Operator and BP / WSL present. Spot Tiger tank behind flow lines with Pad operator's permission 11:00 - 14:00 3.00 MOB P PRE Spot Pipe shed, Pits and Rig components. Raise and scope up Derrick. 14:00 - 15:00 1.00 KILL P DECOMP Begin to R/U lines and kill manifold in cellar. Ri~ acce~ted at 1400 hrs on 6-11-09. Ready to place new lube pump in compound. 15:00 - 18:00 3.00 KILL N DECOMP Put new oiler pump in compound with rig mechanic. 18:00 - 19:00 1.00 KILL P DECOMP Continue to RU lines for killing well. RU tiger tank lines. Take on 9.2 ppg brine in pits and upright. Test rig lines to 3,500 psi, test hardline to Tiger tank to 500 psi. 19:00 - 20:30 1.50 WHSUR P DECOMP RU lubricator and test to 500 psi. Pull BPV. Tubinq = 600 osi. ic tor. 20:30 - 23:30 3.00 KILL P DECOMP PJSM with rig crew and vac truck drivers. Initial WHP's: TBG = 550 psi, IA = 650 psi, OA = 0 psi. Bleed IA to 150 psi, tubing to 150 psi. Break circulation with heated 9.15 ppg brine down tubing taking returns thru choke to Tiger tank with 3 BPM / 870 psi. Returns of crude and gas to tank. Circulated 65 bbis at 3 BPM / 440 psi for FCP. Returned 72 bbls of crude to Tiqer t 1° Close choke and bullhead 25 bbls of heated 9.15 ppg brine down tubing at 2 BPM / 1,060 psi. Monitor for 15 min, SICP = 570 psi. Open choke and continue to circulate down tubing taking returns to Tiger tank at 4- 5 BPM with 860 psi to 1550 psi range. Circulate a total of 391 bbls, returns of crude and gas cleaned uo to 9.15 ppp brine. Returned 315 bbls on circulation Pumped a total of 481 bbls with 94 bbis of 9.15 ppg brine lost to formation during circulation and bullhead. 23:30 - 00:00 0.50 KILL P DECOMP Initia! pressures: Tubing = 30 psi, IA = 50 psi. Monitor for 15 min - no change. Line pumps up to take returns back to pits. Open choke and circulate thru gas buster at 2 BPM / 270 psi. 6/12/2009 00:00 - 01:30 1.50 KILL P DECOMP Continue circulatin with 2 BPM / 270 psi down tubing taking returns thru choke to pits. Fluid weight 9.15 ppg on returns. Circulate 65 bbls with a 2 bbl gain. Monitor for 40 min. Shut in pressures: Tubing and IA are both 10 psi. 01:30 - 02:30 1.00 KILL P DECOMP Confer with town R engineer to discuss plan forward. Work numbers and calculate a Kill weight fluid +100 psi overbalance safety factor. Desired Kill weiaht fluid of 9.5 ~~o needed. Call mud engineer and order fluids. 150 bbls ot 10.5 ppg spike fluid Printed: 6/22/2009 2:10:37 PM ~ • Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 6/9/2009 End: 6/16/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/16/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase De$cription of Operations 6/12/2009 01:30 - 02:30 1.00 KILL P DECOMP ordered. 02:30 - 06:00 3.50 KILL N DECOMP Wait on fluids from MI mud plant. Rig maintenance on vairous projects. Clean rig. 06:00 - 07:30 1.50 KILL N DECOMP Crew change and perform pre-tour checks. Crew make Enviro walk around on L-Pad and trash pickup, no spills were found. 07:30 - 08:00 0.50 KILL P DECOMP Held crew safety meeting on displacing fluid to 9.5 ppg Brine. 08:00 - 12:00 4.00 KILL P DECOMP Increase fluid weight from 9.15 to 9.5 ppg brine. Circulated 65 bbls at 3 BPM / 520 psi down the tubing up the IA through the open choke to the Pits. Close choke and bull head 25 bbis 9.5 ppg brine into formation. Resume circulating 418 bbls 9.5 ppg brine to pits. Tubing and IA on a slight vacuum. 12:00 - 12:30 0.50 KILL P DECOMP Blow down kill mani o d, lines and valves. 12:30 - 14:30 2.00 DHB P DECOMP Cameron well head tech set TWC. Pressure test at 3,500 psi ve and in'ection test from below at 1 b m/ 600 si, pumped 27 bbis in bleed 4 bbls back, both test charted for 10 minutes. 14:30 - 15:00 0.50 WHSUR P DECOMP RD kill manifold, kill lines and valve. 15:00 - 16:00 1.00 WHSUR P DECOMP Cameron well head tech check alignment pin and function LDS. Function alignment pin, 7/8" in and 1-3/4" out. ND tree and PU/MU landing joint and mark RKB. 16:00 - 21:30 5.50 BOPSU P DECOMP NU DSA to wellhead. NU BOPE. Monitor IA - slight vac. Shoot fluid level with Wells Support, IA fluid level at 250'. Continue monitoring IA. 21:30 - 00:00 2.50 BOPSU P DECOMP Test BOPE 250 si low / 3,500 psi hi h. Hold each test for a charted 5 min. Test 2-7/8" x 5" VBR with 2-7/8" test joint. Continuous IA monitoring - slight vac. 6/13/2009 00:00 - 02:00 2.00 BOPSU P DECOMP Continue BOPE test of 250 psi low / 3,500 psi high. Test annular with 2-7/8" test joint. Complete Koomey draw down test. Test witnessed by WSL and NAD Tourpusher. AOGCC rep Lou Gramaldi waived the state's right to witness at 18:45 hrs on 6-10-09. Blow down equipment. LD test joint. Monitor IA during test - IA on slight vac. 02:00 - 03:00 1.00 BOPSU P DECOMP RU Opso-Lopso, lo-torque and lubricator. Test with water to 500 si. Pull TWC, tubin on vac. LD Opso-Lopso and lubricator. 03:00 - 04:00 1.00 PULL P DECOMP MU landing joint with closed TIW valve and screw into tubing hanger with 10 turns. Monitor IA thru 2" - IA on vac. BOLDS with Cameron rep. Pull hanger off seat with 75K. Hanger to ~oor with 72K. Pull penetrator with Cameron and isconnec ESP cable with Centrilift. Fill hole with 25 bbls and established a static loss rate of 18 bbl/hr. Open TIW valve. LD hanger for inspection. 04:00 - 06:00 2.00 PULL P DECOMP MU landing joint to string. Secure ESP cable with 2 carbon steel bands. RIH to position landing joint across stack. MU headpin and circulate 9.5 ppg brine down tubing back to pits at 3 BPM / 650 psi. Circulate 360 bbls with 9.5 ppg returns. Loss rate = 18 bbl/hr during circulation (89% returns). 06:00 - 08:00 2.00 PULL P DECOMP PU 2-7/8" tubinca from pipe shed and RIH from 10,960' to 11,185' incountered SOW = 10K and 15K over pull. Stand back 2 stands in Derrick. 08:00 - 09:00 1.00 PULL P DECOMP POH and snake ESP cable over sheave in Derrick to spooler unit. 09:00 - 17:00 8.00 PULL P DECOMP POH with ESP completion on 2-7/8" tubing and rack in Derrick. Printed: 6/22/2009 2:10:37 PM ~ ~ BP EXPLORATION Page 3 a~ 4~ : Operations Summary Repart Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 6/9/2009 End: 6/16/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/16/2009 Rig Name: NABORS 3S Rig Number: Date' Fr~m - To Hours Task God~ NPT Phase ` Description of Operations 6/13/2009 09:00 - 17:00 8.00 PULL P DECOMP Found cable splice on joint #102, remove reel from spooler and resume POH. Maintain pumping across the top with a loss rate of -11 bph. UD 3 bad joints, gaulded threads. Pulled 179 LaSalle clamps, 5 protectalizers, 3 armster guards, 2 short Cannon clamps. 17:00 - 20:00 3.00 PULL P DECOMP Service and LD ESP assembly. Welllift gauge wire was parted and washing found on pump discharge head flange (see 20:00 - 00:00 4.00 CLEAN P DECOMP PUMU 2-7/8" muleshoe to bottom of 2-7/8" tubina~H with 2-7/8" tubing out of Derrick. Losses = 10 bbl/hr while RIH. 6/14/2009 00:00 - 02:30 2.50 CLEAN P DECOMP Continue RIH with 2-7/8" tubing out of Derrick with 10 bbl/hr loss rate. 170 stands in hole. PUW = 52K, SOW = 35K. 02:30 - 03:30 1.00 CLEAN P DECOMP PU singles from pipe shed and RIH from 10,721' to tag depth of 11 240'. Unable to work thru fill. PUW = 55K, SOW = 37K. 03:30 - 06:00 2.50 CLEAN P DECOMP RU to reverse circulate. Wash down from 11,240' to 11,282' by circulating down the tubing. Close bag and reverse circulate at 2 BPM / 310 psi. Fine sand returns across shakers. Circulate until returns are clean. Loss rate durinq circulation = 20 bbl/hr. 06:00 - 12:00 6.00 CLEAN P DECOMP Continue FCO wash down from 11,282' to 11,400' by circulating down the tubing. Close bag and reverse circulate at 2 BPM / 310 psi and 3 BPM / 460 psi. 12:00 - 15:00 3.00 CLEAN P DECOMP Reverse circulate a 24 bbls Flo-Vis sweep at 3 BPM / 500 psi. Recovered formation sand and formation ieces u to 0.7 " 2 ards . 158 bbls lost durin FCO. 15:00 - 15:30 0.50 CLEAN P DECOMP Monitor Well formation bre thin back at - 15:30 - 16:30 1.00 CLEAN P DECOMP POH L/D the 20 joints 2-7/8" tubing used for FCO. Well static. 16:30 - 18:00 1.50 CLEAN P DECOMP POH 20 stands of 2-7/8" tubing in Derrick. Maintain continuous hole fill, tatic w losses = 6 r. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change. Perform pre-tour checks. 18:30 - 21:30 3.00 CLEAN P DECOMP PJSM. Cut and slip drilling line. Maintain continuous hole fill at 4-6 bbl/hr losses. 21:30 - 00:00 2.50 CLEAN P DECOMP Continue POH with 2-7/8" tubing. Maintain continuous hole fill. 87 stands out at 24:00 hrs. 6/15/2009 00:00 - 03:30 3.50 CLEAN P DECOMP Continue POH with 2-7/8" tubing. LD muleshoe and clear rig floor. Drain stack to hanger bowl. I-W ire tubing noticed in stack above han er bowl. Fish I-Wire out of stack. Recovered the 25' piece missing from previous ESP assembly. 03:30 - 04:00 0.50 WHSUR P RUNCMP PUMU landing joint and tubing hanger. Function alignment pin into position with CIW tech. Land hanger in bowl and visually confirm hanger "J" into positon and land. LD hanger and landing joint. 04:00 - 11:30 7.50 RUNCO P RUNCMP PU ESP components from pipe shed. MU new I-Wire lead with Centrilift rep. 11:30 - 12:00 0.50 RUNCO P RUNCMP Service blocks and adjust brakes on drum. 12:00 - 18:00 6.00 RUNCO P RUNCMP RIH with ESP com letion on 2-7/8" tubin from Derrick to stand #119. Maintain continuous hole fill at ~4 BPH loss rate. Fill / flush pump,and take conductivity test every 2,000' at .5 BPM / 770 psi. 18:00 - 20:30 2.50 RUNCO P RUNCMP Perform ESP reel to reel splice. Static losses = 6.5 bbl/hr 20:30 - 00:00 3.50 RUNCO P RUNCMP Continue to RIH with ESP completion on 2-7/8", 6.5#, 8-rd tubing from Derrick. Maintain continuous hole fill at -4 BPH loss rate. Fill / flush pump and take conductivity test every Printed: 6/22/2009 2:10:37 PM ~ ~ BP EXPLQRATION Page 4 of 4 Qperations Sumrnary Report Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 6/9/2009 End: 6/16/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/16/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 6/15/2009 20:30 - 00:00 3.50 RUNCO P RUNCMP 2,000' at .5 BPM / 740 psi. Use Best-O-Life pipe dope and MU connections to 2,300 ft-Ibs. Ran 342 joints 2-7/8", 2ea GLM's, XN nipple, 180 LaSalle clamps, 5 protectilizers, 3 armster guards, and 2 half Cannon clamps. 6/16/2009 00:00 - 01:00 1.00 Rl~NCO P RUNCMP Perform penetrator splice with Centrilift rep. Install penetrator and shipping cap with CIW tech. Check conductivity: BHP = 3430 psi, BHT = 183.9, Phase to Phase = 4.5 ohms, Phase to Ground = 500 meg ohms. 01:00 - 01:30 0.50 RUNCO P RUNCMP Position alignment pin with CIW tech. Land tubing hanger, "J" into osition.. RILDS. 01:30 - 03:30 2.00 WHSUR P RUNCMP PU T-bar and set TWC with CIW tech. Test from above to 3,500 si for 10 min - charted. Rolling test from below with 52 GPM / 500 psi for 10 min - charted. Pumped 21 bbis and bled back 3 bbls durin injection test. Blow down equipment and drain stack. 03:30 - 06:00 2.50 BOPSU P RUNCMP ND BOPE and DSA. Lay in cradle. 06:00 - 08:00 2.00 WHSUR P RUNCMP NU prduction Tree and adaptor flange. With Cameron well head tech. 08;00 - 08:30 0.50 WHSUR P RUNCMP Cameron well head tech tested tubing hanger void to 5,000 psi for 30 minutes. Test Tree to 5,000 psi with diesel for 5 charted minutes. 08:30 - 10:00 1.50 WFfSUR P RUNCMP ~U lubricator and test with diesel to 500 psi. Pull TWC. Tubin on vaa Set BPV with lubricator. LD lubricator. Remove second annulus valve. Secure cellar and normal up wellhead valves. 10:00 - 12:00 2.00 WHSUR P RUNCMP Clean Pits with Vac truck. Release rig at 1200 hrs on 6-16-09 for move to MPL-05. Printed: 6/22/2009 2:10:37 PM ~ ~ MPL-11 Well History Date Summary 04/19/09 FLOW & SCRAPE, C/O DPSOV, TEST TUBING RAN 1.60" CENT, 2-7/8" WIRE SCRATCHER. 0- 1950' 150-175 FPM, 1950 - 3100 75 FPM (light restriction), 3100' - 3500' 100 FPM. PULLED 1" BKP-DPSOV ST# 2 C~ 141' MD. 04/20/09 T/I/0=400/400/0 Assist s-line MIT-T PASSED to 1500 psi. Pumped 11.2 bbls diesel crude mix down Tbg to reach test pressure. 1st 15 min lost 40 psi, 2nd 15 min lost 20 psi for a total loss of 60 psi in 30 min. Bled down pressure. (4 bbls) DSO notified SLB S-Line on well upon LRS departure. FWHP's=500/400/0 04/20/09 ESP, TEST TUBING""` SET 1" BEK-DPSOV ST #2 C~? 141' MD. RAN 2-1/2" (2.30" OD) CAT STANDING VALVE TO XN C«~ 10,873' MD. PT TUBING W/LRS, PASSED. 04/23/09 T/I/0=300/300/0 (Injectivity Test) Pumped 12.5 bbls crude, 12.5 bbls diesel mixed & 90 bbls produced water down tubing. 04/24/09 (Injectivity Test) Pumped 5 bbls crude & diesel mixed down Tbg. DSO notified swab wing shut, ssv master ia oa open FWHP's=700/460/0 05/17/09 .T/I/0=220/320/0. (ESP acid treatment) Spear into tbg w/ 10 bbls crude for injectivity test. Pump 12 bbls 10% DAD acid and flush surtace lines w/ 3 bbls 60/40 meth down tbg. Spot acid at ESP w/ 56 bbls crude. Turn well overto DSO. FWHP-950/1020/0. 06/01/09 T/I/0=300/300/0 IA Flush Pumped 20 bbls dead crude down IA with ESP online. FWHP= 300/300/0 Master, IA, OA, Wing and ssv open. Swab closed. 06/02/09 T/I/0=300/380/0 Freeze Protect Pre RWO Pumped 15 bbls Diesel down tubing. Pumped 3 bbls 60/40 methano~, 3 bbls diesel, and 3 bbls 60/40 methanol down production and test flowlines. Closed root valves and bleed flowlines down to 0 psi. FWHP=440/440/0 Master, IA, and OA open . Swab, SSV, and Wing closed. 06/06/09 PULLED 1" DMY VALVE FROM 10730' MD PULLED 1" DPSOV & SET 1" DUMMYQ 141' MD RUN 1.74" CENT, S.S, DUAL SPARTEK GAUGES 30MIN STOP C~ 10393' SLM, 3HR C~ 10907 ( TAG ESP Q 10908' SLM, 10893' MD 14' DEEPER 06/16/09 T/I/0= 0/0/0 Post RWO Freeze Protect. Pumped 65 bbls crude down IA & 15 bbls crude down Tbg. DSO notified swab wing ssv shut, master ia oa open. FWHP's=700/350/0 07/09/09 T/I/O = 350/400/0 ""'`Scale Inhibition Treatment'*' Loaded IA w/ 175bb1s crude. Pumped 18.4 bbls 03VM082 (Scale Inhibitor) and 265 bbls dead crude for displacement. DSO to POP after 4 hours. FWHP=800/800/0 Master, IA, and OA open. Wing, SSV, and Swab closed. Page 1 of 1 STATE OF ALASKA osrosios OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/13/09 Rig Rep.: J. Greco/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: D.Rhodes/V. Volpe E-Mail adwdr3snu@bp.com Well Name: MPL-11 PTD # 1930130 f Operation: Drlg: Workover. x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 25013500 Annular. 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 518" P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5" P Flow Indicator P P #2 Rams 1 blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams o NA Quantity Test Result Choke Ln. Valves 1 3 1/8 P Inside Reel valves 0 NA HCR Valves 2 3 1/8 2 1/16 P Kill Line Valves 1 2 1116 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1600 P Quantity Test Result 200 psi Attained 30 P No. Valves 13 P Full Pressure Attained 152 P Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn. Bottles (avg): 2100 i CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 3.5 Hours Repair or replacement of equipment will be made within days. Notify the North Slope Ins ector 659-3607, follow with written confirmation to Su rvisor at: Remarks: Tested with 2 7/8" test joint against TWC. Witnessed by Vince Volpe Bp WSL, Rick Bjorhus NAD TP 24 HOUR NOTICE GIVEN YES x NO Waived By Lou Grimaldi Date 6/10/09 Time 18:45 Witness _, T, 1:30.. finish 01:00 BOP 06/05/09 Nabors 3s BOP Test MPL-11 6-13-09.x1s STATE OF ALASKA ~ ,~,~ ..~ ~ .., . ~ ~.~ A~ OIL AND GAS CONSERVATION CO i REPORT OF SUNDRY WELL OPE TII~S~ ~ ~1 ~ ;~~~~ ~~9 1. Operations Performed: , _ :, ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Chane out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 193-013 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22336-00-00 - 7. KB Elevation (ft): 51, 9. Well Name and Number: MPL-11 8. Property Designation: 10. Field /Pool(s): ADL355017 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11630 ~ feet true vertical 7424 feet Plugs (measured) None Effective depth: measured 11492 feet Junk (measured) -11346' (Fish) true vertical 7341 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 110' 110' 2730 1130 Surface 6658' 9-5/8" 6688' 4588' 6870 4760 Intermediate Production 11590' 7" 11620' 7418' 7240 5410 Liner Perforation Depth MD (ft): 11016' - 11346' Perforation Depth TVD (ft): 7051' - 7252' 2-7/8, 6.5# L-80 10961' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 43 11 371 260 232 Subsequent to operation: 207 36 897 280 234 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: - ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ~ ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact N/A Printed Na Sondra Stewman Title Drilling Technologist ignature ~p Prepared By NamelNumber: Phone 564-4750 Date~~ ' ~ D' V 1 Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ,.~~ ~. _ Submk Original Only Tree: 2 9/16" - 5M W~ Wellhead: 11" x 7' 5M M w/ 2 7/8" 8 rd treetop connection 2 1/2" Cameron type "H" BPV Profile 13 3/8" 54.5 ppf K-55 110' KOP Q 400' Max. hole angle = 58 deg @ 7800` MD Max dogleg 4.65 deg C~ 1407` MD Hole angle thru' perfs = 55 deg 9 5/8" 48 ppf, N-80 BTRS 6,715' and 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26 ppf, L-80, Btrc. Mod. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) MPU L-11 Orig. D~v. = 50` Orig. GL v. = 17.7' Camco 2-7/8" x 1" 141' sidepocket KBMM GLM ~ 7" HOS - ES Cement Tool @ 1902` Camco 2-7/8" x 1" 10,730` sidepocket KBMM GLM Note: 28 bbls class G cement behind 7" casing through perfs at 10,992` and tested to 1875 psig Stimulation Summary Fracced with 172,500 Ibs of 12-18 ISP behind pipe, June 1993 Perforation Summary A, B and C Kuparuk Sands Size SPF Interval MD (TVD) 5" 12 11016`-11036 7055` - 706 5" 12 11050`-11060 707: - 707 5" 12 11087`-1109 709E - 710 5" 12 11164'-11184 714 ' - 715 5" 12 11197'-1122 716, ` - 718 5" 12 11256`-11286 7197` - 721 5" 12 11336`-11346 7245` - 725 I FISH - 4 Flat Guards and 3 Bands left in hole below perfs DATE REV. BY ~ COMMENTS 4/95 DBR RWO 8/21/01 B. Hasebe RWO Nabors 4ES 3/7/09 REH RWO Nabors 3S ao 2-7/8" XN nipple 873` 10 (ID 2.25") , WeIILift Discharge Gauge Unit 10,888` Discharge Head/GPDIS 10,893` Centrilift ESP ` 207-P11 SXD Pump 10,894 Tandem Gas Separator 10 921' GRSFTXARH6 , Tandem Seal Section 927' 10 GSB3 DB UT/LT SB/SB PFSA/FSA CLS , Motor, 190 HP, 2415 Volt, 940` 10 48 Amp, Model KMH , WeIILift MGU Sensor 957` 10 , w/ 6 fin Centralizer PBTD 7320' TVD 11,492' and 7" float shoe yq.,~g' and 'rn MiLNE POINT U'NfT WELL L-11 API NO: 50-029-22336 BP EXPLORATION (AK) • • MPL-11, Well History Date Summary 01/25/09 Flush flowline w/ 2 bbls neat meth, 3 bbls diesel, & 2 bbls 60/40 meth. Flush test line w/ 2 bbls neat meth, 3 bbls diesel & 2 bbls 60/40 meth for de-mobe. 02/06/09 Freeze Protect (Pre-RWO) Heat diesel for job. 02/07/09 T/I/0=300/320/20 Freeze Protect (Pre-RWO) Continued from 02-06-09 WSR. Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 2 bbls Diesel ,and 2 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and bleed pressure down to 0 psi. on both flowlines. FWHP=450/420/20 Master, IA, and OA open. Swab, SSV, and wing closed. 02/13/09 The Well Support Techs rigged up and removed the wellhouse, foundation and the flowlines. Blinds were installed as needed. NOTE: The Back Pressure Valve was left OUT for upcoming slickline work. Also the spool piece next to the header on the production leg was taken to A-pad for projects. 02/14/09 *"WELL S/I ON ARRIVAL"* MADE SEVERAL ATTEMPT TO PULL ST#1 @ 10757 MD NO LUCK 02/15/09 MADE SEVEAL ATTEMP TO PULL ST# 1 C~ 10757 MD SHIRT ARE COMING BACK CRACKED RAN 2.5 OK-1 W/ 2.5~BRUSH TO LOC. POCKET C~3 10757 MD W/NO LUCK PULLING. SKIRTS COMING BACK DAMAGED /SPLIT RAN 2.5 OK-1 W/ 1 1/4 LIB TAG TOP LATCH Q 10757 MD GOT CHINA CAP AND TRASH BEHIND LATC H RAN 2.5 OK-1 W/ 1 1/4 JDC SPLIT SKIRT 02/16/09 RAN SBHP AS PER PROGRAM 02/22/09 RUN 2.15" CENT, 3' X 1.50" STEM, 1.70" LIB, S/D Q 10903' SLM IMPRESSION OF PUMP SHAFT MULTIPLE RUNS , P CAM PERFORATOR, 2' x 1 7/8" STEM & 2" BLIND BOX (SEE LOG) 02/23/09 RAN P CAM PEEFORATOR, 3' x 1.5" STEM, XO, 11" EXT, 2" BLIND BOX TO 10909' SLM PULL 1" DPSOV FROM 137' MD/ SET 1" BK DUMMY 02/26/09 MPU Well ST installed BPV after E-Line was completed. '"'WELL SHUT IN ON ARRIVAL'*' INITIAL T/ I/ O = 650/750/0 1.56" SMALL TUBING PUNCHER RUN TO PUNCH 2 7/8" TUBING AT FROM 10881'-10883'. WELL LEFT SHUT IN ON DEPARTURE. FINA /I/0=700 750 0 03/05/09 ~*~SURFACE WORK NABOBS 3S""' PULLED 1" BK-DGLV FROM SPM TO BE RUN ON TOP, SET 1" BEK-DPSOV (marked & flagged) VERIFIED 1" BK-DGLV WAS SET IN SPM TO BE RUN ON BOTTOM *~~NOTIFIED COMPANY REP OF SPM CONFIGURATION" 03/08/09 T/I/O=0/0/0 Freeze protect Tbq and IA (Po t RW )Pumped 65 bbls Dead Crude down IA. Pumped 15 bbls Dead Crude down tubing. FWHP=300/300/0 Master, IA ,and OA open. Wing, Swab, And SSV closed. 03/14/09 The Well Support Techs rigged up pulled the back pressrue valve and then pressure tested the flowlines ____ to 1150 psi. NOTE: The BPV was left OUT and the Leak test was GOOD!! Well is ready to POP! • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name:. MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 2/27/2009 End: 3/7/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/7/2009 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task I Code NPT Phase Description of Operations 2/28/2009 04:00 - 18:30 14.50 MOB P PRE Rig released from MPL-40. Prepare rig for move to MPL-11. Generator problems on rig. Call for electrician from Rig 7ES. 18:30 - 20:00 1.50 MOB P PRE Move Carrier off MPL-40, lay mats and herculite on MPL-11. At 20:00 hrs Spot Carrier over MPL-11 both witnessed by Pad operator, BP / WSL and NAD toolpusher. 20:00 - 00:00 4.00 MOB P PRE Spot Pipe Shed Pits and rig components. Spot Tiger tank behind flow lines. 3/1/2009 00:00 - 02:00 2.00 MOB N PRE Continue to spot rig components. Move BOPE and cradle, close cellar doors. Suspend all R/U operation out doors due to "Phase 2" weather with 35 mph wind. 02:00 - 05:00 3.00 MOB N PRE RU lines and perform general houskeeping task. Wait on wind to scope and raise Derrick. 05:00 - 06:00 1.00 MOB N PRE Held weeky safety meeting with Night crew. 06:00 - 07:00 1.00 MOB N PRE Held weeky safety meeting with Day crew. 07:00 - 18:00 11.00 MOB N PRE All operations shut down dure to Phase 3 weather conditions. 18:00 - 00:00 6.00 MOB N PRE Made crew change, 4 man crew on Rig watch, 3 CH2M Hill truck drivers on location. Total of 13 people on location. 3/2/2009 00:00 - 06:00 6.00 MOB N PRE Continue to wait on weather. MPU in Phase 3 weather condition. 4 man crew on Rig watch. 06:00 - 10:00 4.00 MOB P PRE Phase 3 lifted. Work to dig out equipment and complete rigging up the Rig. Work on getting rig motor started. Dig out equipment. 10:00 - 16:00 6.00 MOB P PRE Raise and scope derrick. Change out driller's side air tugger. RU circulation manifold and lines for well kill. Heat 10 #/gal brine with LRS from 80 deg F to 120 deg F. Rig accepted ~ 13:00. 16:00 - 17:00 1.00 WHSUR P WHDTRE Blow down lines to tiger tank. Well techs grease IA valve. PUMU lubricator and ressure test to 1,000 psi with diesel. Pull BPV. T / IA / OA = 800 / 800 / 0 psi 17:00 - 00:00 7.00 KILL P DECOM eat s ga rine wit LR from 80 deg F to 120 deg F. Transfer 250 bbls to Pits. Test surface lines to 3,500 psi and down stream of choke to Tiger tank to 500 psi. 3/3/2009 00:00 - 00:30 0.50 KILL P DECOMP Pre-Kill safety meeting with crew and truck drivers. 00:00 - 02:00 2.00 KILL P DECOMP WHP's = tbg - 710psi, IA - 800 psi. Bleed IA and tbg down to 450 psi (gas). Pump 65 bbls 120 degF 10.0 ppg NaCI down tubing taking return through choke to Tiger tank at 3 bpm / 390 - 470 psi. Bull head 15 bbls into formation at 1 bpm / 200 - 280 psi. After 30 minutes SITP = 0, SICP = 720, OA = 0. 02:00 - 05:00 3.00 KILL P DECOMP Continue to Heat 330 bbls 10 # /gal brine with LRS from 80 deg F to 120 deg F. SITP = 0, SICP = 720, OA = 0. Bleed gas from IA and circulate 415 Bbls of 10# brine with 370 Bbls of re urns. a e o - 05:00 - 06:00 1.00 KILL P DECOMP owc ec we . u ing on`vacuum. Slight blow of gas on IA. Line up and circu a e ~roug gas buster to pits. Circulate at 3-1/2 BPM / 1000 psi. Flow check well. Tubing and IA on a Vac. Prepare for ND BOPE. 09:00 - 15:00 6.00 WHSUR P DECOMP Dry rod TWC. TWC failed to test from below. Cameron well head tech tested Hanger void, good test. PU / MU Opso Lopso and test lubricator to 500 psi with diesel. Pull and set new TWC. Test from above to 3,500 psi for 10 charted minutes. Pum down IA at 12.5 bpm / 1,000 psi. 15:00 - 16:30 1.50 WHSUR P DECOMP Blow down lines, RD hard line kill manifold. 16:30 - 17:00 0.50 WHSUR P DECOMP ND tree and Hi-pressure lines. Printed: 3/16/2009 1:47:18 PM • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 2/27/2009 End: 3/7/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/7/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 3/3/2009 17:00 - 18:00 18:00 - 22:00 22:00 - 22:30 22:30 - 00:00 3/4/2009 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 08:00 08:00 - 08:30 08:30 - 09:00 13/5/2009 1.00 WHSUR P DECOMP Cameron well head tech inspect" WKM" well head Alignment Pin, LDS, etc. per new SOP. 4.00 BOPSU P DECOMP Move BOP cradle into position, PU / MU BOP stack and DSA. 0.50 BOPSU P DECOMP Function test BOPE. 1.50 BOPSU P DECOMP Pressure Test 13-5/8" BOPE with, 2-7/8" X 5" VBR, 2-7/8" test joint against TWC. Test to 250 / 3,500 psi arid chart each test for 5 minutes. AOGCC right to witness testing waived by John Crisp. Witnessed by BP /WSL and NAD toolpusher. 2.00 BOPSU P DECOMP Continue Pressure Test 13-5/8" BOPE with, 2-7/8" X 5" VBR, 2-7/8" test joint against TWC. Test to 250 / 3,500 psi and chart each test for 5 minutes. AOGCC right to witness testing waived by John Crisp. Witnessed by BP /WSL and NAD toolpusher. 1.00 BOPSU P DECOMP Blow down lines, lay down test joint. Drain BOP stack. 1.00 WHSUR P DECOMP PU / MU Opso Lopso and test lubricator with diesel to 500 psi. Pull TWC and LD same. Tubing on a slight vacuum, 0 psi on 1.001 PULL I P 3.001 PULL I P 0.501 PULL I P 0.501 PULL I P 09:00 - 10:00 1.00 PULL P 10:00 - 23:30 13.50 PULL P 23:30 - 00:00 I 0.501 PULL I P 00:00 - 03:00 3.00 PULL P 03:00 - 04:00 1.00 PULL 04:00 - 05:00 I 1.00 I R DECOMP MU 2-7/8" landing joint with TIW valve and screw into Hanger. BOLDS, Pull Hanger off seat at 83 K, PUW = 82 K, SOW = 37 K. DECOMP Circulate surface to surface down the tubing with 10.0 ppg rine at 3 bpm / 670 psi. Pumped a total of 520 bbls until returns cleaned up. Had crude and small gas bubbles in returns when bottoms up were reached. Weight of fluid going in and out were equal at 9.8+ ppg. DECOMP Shut down the pump and flow check the well for 30 minutes. The IA is falling but the Tubing is flowing slightly -well is out of balance. DECOMP Pump a tubing volume down the Tubing to flush the Tubing with clean brine at a rate of 3.25 bpm / 700 psi. Pumped a total of 65 bbls and shut down. The Tubing and IA are both on a very slight vacuum. DECOMP -Blow down and RD circulating equipment. LD Tubing Hanger. Prepare the rig floor for pulling out of the hole. DECOMP POOH with existing ESP Completion standing back 2-7/8," ubing in t e erric . isua y inspecting all joints as coming out of the hole. Maintaining continuous hole fill with average hourly loss rate of -5 bbls er hour. Bottom pup joint on first GLM out of the hole had a galled up pin. Call out for new GLM Assembly. POH 342 joints. 5 joints had galled pins, 1 joint perforated with 9 holes in the middle of joint, exterior Pitting and scale on pups on GLM assembly (bottom station). 1 mechanical cut hole in 10' pup above Discharge Head (also pitted). Broken motor shaft. DECOMP BO / LD ESP motor. Recovered 179 LaSalle clamps, 3 Flatguards, 7 Protectolizers. DECOMP BO / LD ESP pump and motor assembly. DECOMP Clean clear rig floor and spooling unit. RD ESP cable trunk from Derrick. RUNCMP Pump out BOP stack. Make tubing Hanger dummy run with Cameron well head tech as per WKM SOP. Maintaining continuous hole fill with average hourly loss rate of -2.5 bbls per hour. Printed: 3/16/2009 1:47:18 PM BP EXPLORATION Page 3 of 4 ~ Operations Summary Report Legal Well Name: MPL-11 Common Well Name: MPL-11 Event Name:. WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To 'Hours Task ~'~ Code NPT Spud Date: 5/27/1993 Start: 2/27/2009 End: 3/7/2009 Rig Release: 3/7/2009 Rig Number: Phase bescription of Operations 3/5/2009 05:00 - 06:00 1.00 BUNCO P RUNCMP Clean and clear rig floor. RD ESP cable trunk from Derrick. 06:00 - 07:00 1.00 BUNCO P RUNCMP Pre-tour checks. Lubricate and service the Rig. 07:00 - 14:00 7.00 BUNCO P RUNCMP PUMU new ESP Assembly with new WeIlLift installation. 14:00 - 18:00 4.00 BUNCO SFAL RUNCMP Perform conductivity check prior to running in the hole. The Tech Wire for the WeIlLift installation failed its test. Pull out of hole and, replace Tech Wire with new one_ 18:00 - 00:00 6.00 BUNCO P RUNCMP RIH ESP completion assembly on 2-7/8" 6.5#, EUE, 8rd tubing from Derrick. Check conductivity of ESP cable and fill and flush tubing every 2,000'. 1/2 bpm / 1,500 psi. 75 stands run at 00:00 hours. Maintaining continuous hole fill with average hourly loss rate of -2.5 bbls per hour. 3/6/2009 00:00 - 03:00 3.00 BUNCO P RUNCMP Continue to RIH ESP completion assembly on 2-7/8" tubi~ from Derrick. From stand # 75 to ESP splice depth at stand # 121. Check conductivity of ESP cable and fill tubing, flush pump every 2,000'. 1/2 bpm / 1,500 psi. Maintaining continuous hole fill with average hourly loss rate of ~2.5 bbls per hour. 03:00 - 08:00 5.00 BUNCO P RUNCMP Centrilift rep make reel to reel cable splice, remove empty spool from spooling unit. Check conductivity of ESP cable and fill tubing, flush pump -1/2 bpm / 1,500 psi 08:00 - 12:30 4.50 BUNCO P RUNCMP Resume RIH with stands of 2-7/8" Tubing from the Derrick. Maintaining continuous hole fill with 9.9 ppg brine with losses averaging 2 bbls per hour. Ran a total of 342 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing with 179 LaSalle Clamps, 5 Protectolizers, 3 Flat Guards and 2 Cannon Clamps. Final flush pumped at 0.35 bpm / 1,030 psi. 12:30 - 13:30 1.00 RNTBH P T UBHGR Pick up and make up Landing Joint with Tubing Hanger. Install Penetrator and align visually with Cameron rep. 13:30 - 15:30 2.00 BUNCO P RUNCMP Perform Penetrator splice with Centrilift rep. Make conductivity checks after making field connection - OK. 15:30 - 16:00 0.50 RNTBH P TUBHGR Obtain final PUW = 72K ,SOW = 40K. Land Tubing Hanger and observe it fall into slot with alignment pin.. RILDS with Cameron rep. Put 5,000 psi test between the body seals to verify landed properly - OK. 16:00 - 16:30 0.50 WHSUR P WHDTRE PU T-bar and set 2-1/2" Type "H" TWC with Cameron rep. LD T-bar. Fill the Stack with 9.9 ppg brine. 16:30 - 18:00 1.50 WHSUR P WHDTRE Pressure test the TWC from above to 3,500 si for 10 charted mins - OK. Hook up Little Red to the IA and pressure test tha TWC from below by pumping down the IA at a rate of 0.8 bpm / 400 si for 10 charted mins - OIL. Pumped a total of 16.5 bbls. Bleed off pressure. Blow down and rig down Little Red. 18:00 - 22:00 4.00 WHSUR P WHDTRE Blow down choke and suck out BOP stack. ND BOPE / DSA and LD in shipping cradle. Remove from cellar. 22:00 - 23:00 1.00 WHSUR P WHDTRE NU Adapter Flan a and Production Tree. 23:00 - 00:00 1.00 WHSUR P WHDTRE Cameron well head tech tested tubing Hanger void to 5,000 psi for 30 minutes. Centrilift perform final conductivity checks. 3/7/2009 00:00 - 00:30 0.50 WHSUR P WHDTRE Test Tree with diesel to 5,000 psi for 5 charted minutes. Final check readings on ESP Completion: phase to phase = 4.6 ohms ,phase to ground = 300 Mega ohms ,pressure at intake = 3589 psi ,pressure at discharge = 3568 psi ,temperature at intake = 180 degF ,temperature at discharge = 183 degF , temperature at motor = 180 degF. '~ 00:30 - 01:30 1.00 WHSUR P WHDTRE PU / RU lubricator test with diesel to 500 i Well support Printed: 3/16/2009 1:47:18 PM r BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 2/27/2009 End: 3/7/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/7/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 3/7/2009 00:30 - 01:30 1.00 WHSUR P WHDTRE tech pulled TWC and installed BPV, Tubing and IA on a vacuum. 01:30 - 02:00 0.50 WHSUR P WHDTRE Remove second annulus valve, secure well and normal up tree. Ria released at 02:00 hrs. 3/7/2009. Printed: 3/16/2009 1:47:18 PM ~ STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim,r~;~~~~€~~~_~_~1,~3, dog:. ~n ec. r;~til?:~n.b~sv'~~;iaska.~cv b+~i~.fe~: €~~::~:>teir~~) ala ~<€~~~. ta+~,r Contractor: Nabors Rig No.: 3S DATE: 3/3/2009 Rig Rep.: G.Sweatt / R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 ~~~ Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W.Hoffman / D. Rhodes ~, Field/Unit & Well No.: MPL-11 PTD # 1930130 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec Standing Order Posted P BOP STACK: Workover: X Weekly: Annular: 250/3500 TEST DATA Test Result P P P Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind/Shear P Choke Ln. Valves 1 3 1 /8" 5000 P HCR Valves 2 3 1 /8-2 1 /16" P Kill Line Valves 1 2 1 /16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Re Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1600 P 200 psi Attained 30 P Full Pressure Attained 3:10 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @ 1850 Number of Failures: Test Time: 3.5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: "iW:.:e~ ~%~iaska. ov Remarks: Tested against 2 way ck -test with 2 7/8" 24 HOUR NOTICE GIVEN YES x NO Waived By John Date 03/02/09 Time 8:00 Witness Dave Rhodes/R.B Test start 22:30 Finish 2:00 BOP Test (for rigs) ~~~ ~~~ ~ ~,~ ~ BFL 11/14/07 Nabors 3s BOP Test MPL-11 3-3-2009.x1s . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS {~¡aska Oil & Gas Cons. Commission D Stimulate [2] Other D nc D WaiverD Time ExtensionD D Re-enter Suspended Well D 5. Permit to Drill Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 51 KB 8. Property Designation: ADLO-025509 11. Present Well Condition Summary: Total Depth measured 11630 feet true vertical 7423.53 feet Effective Depth measured 11492 feet true vertical 7340.91 feet Casing Length Size Conductor 80' 13-3/8" 54.5# K-55 Surface 6689' 9-5/8" 47# N-80 Production 11645' 7" 26# L-80 Perforation depth: Measured depth: 11016' - 11346' True Vertical depth: 7051.28 - 7252' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Oil-Bbl 76 80 t"I-\JL-I " '- SEP 2 7 2006 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development r.¡ Stratigraphic Exploratory Service 193-0130 6. API Number: 50-029-22336-00-00 9. Well Name and Number: MPL-11 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool Plugs (measured) None Junk (measured) 11530 MD 30' - 110' 26' 6715' 25' - 11670' TVD Burst Collapse 30' - 110' 2730 1130 26' - 4605' 6870 4760 25' - 747' 7240 5410 - -':'I(~ ~'~,r\':::~ j ,-..~'--:~''J. \.~~ .; ','.,....\.;;-.~ 2-7/8" 6.5# Pump Equipment o o o o L-80 23' - 10881' 10881' - 10959' o o o o RBDMS 8Ft 0 c¡ 0 3 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 36 1140 0 39 1161 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 291 292 Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Contact Gary Preble Signature Title Data Engineer Date 9/22/2006 Submit Original Only . . MPL-ll DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/5/2006 T/I/O=1150/1100/0 Acid Treatment. Pumped 50 bbls diesel, 10 bbls 12 % DAD HCL Acid, 3 bbls meoh, and 59 bbls crude. Final WHP=2000/2000/0 8/5/2006 Load diesel for well work. FLUIDS PUMPED BBLS 10 12% dad he! aCID 50 01 ESEL 59 CRUDE 3 METH 122 TOTAL _ STATE OF ALASKA a ALA_ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED DEC 2 2 2005 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate 0 Alasi#1trit[&l GiS Can.. '"",; Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension Et., . U\JIi.Hii"",¡(¡ ¡ Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well flcharage 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [;'1 Exploratory D 193-0130 3. Address: P.O. Box 196612 Stratigraphic D Service D 6. API Number: Anchorage, AK 99519-6612 50-029-22336-00-00 7. KB Elevation (ft): 9. Well Name and Number: 51 KB MPL-11 8, Property Designation: 10. Field/Pool{s): ADL-025509 Milne Point Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 11630 feet Plugs (measured) None true vertical 7423.53 feet Junk (measured) 11530 Effective Depth measured 11492 feet true vertical 7340.91 feet Casing Length Size MD TVD Burst Collapse Conductor 80 13-3/8" 54.5# K-55 30 - 110 30 - 110 2730 1130 Surface 6689 9-5/8" 47# N-80 26 - 6715 26 - 4605.15 6870 4760 Production 11645 7" 26# L-80 25 - 11670 25 - 7447.33 7240 5410 Perforation depth: Measured depth: 11016 - 11036 11050 - 11060 11087 - 11097 11164 -11184 11197 - 11227 11256 - 11286 11336 -11346 True Vertical depth: 7051.28 - 7063.28 7071.7 - 7077.72 7094.02 - 7100.08 7140.84 - 7153.08 7161.05 - 7179.46 7197.25 - 7215.62 7246.18 - 7252.28 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 23 - 10881 Pump Equipment 10881 - 10959 Packers and SSSV (type and measured depth) "tANii\Ú¡¡;::' ", ¡;¡ . t, ,:j . ,,;!>';"',. ,...., 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMs 8Ft DEC 2 2: 2DD5 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 152 46 819 0 333 Subsequent to operation: 154 46 813 0 323 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development [;' Service D Daily Report of Well Operations X 16. Well Status after proposed work: Oil [;' Gas D WAG D GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr Signat~~~?)¿1~¡) Phone 564-4424 Date 12/19/2005 '\~ Form 10-404 Revised 04/2004 Submit Original Only e e .. MPL-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 11/23/2005 T/I/O=400/360/0 Acid Treatment. Pumped 55 bbls diesel, 10 bbls 7.5 % DAD HCL Acid, 3 bbls meoh, and 59 bbls crude down tbg. Final WHP=600/360/0 FLUIDS PUMPED BBLS 55 Diesel 10 7.5% DAD HCL acid 3 MeOH 59 Crude 127 TOTAL ~ ~ STATE OF ALASKA CECE ALASKA OIL AND GAS CONSERVATION COMMISSIO~'\. IVED REPORT OF SUNDRY WELL OPERA TIC9HS 3 2004 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimula1Alæf<a Oil & GM,~. Commission Abandon 0 Alter CasingD Pull TubingO Perforate New Pool D WaiverD Time E~~ Change Approved Program D Operation Shutdown 0 Perforate D Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD ~-- -~-- 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-22336-00-00 7. KB Elevation (ft): 9. Well Name and Number: 51.00 MPL-11 8. Property Designation: 10. Field/Pool(s): ADL-o25509 Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit 11. Present Well Condition Summary: Total Depth measured 11603 feet true vertical 7407.5 feet Plugs (measured) None Effective Depth measured 11531 feet Junk (measured) 11530 true vertical 7364.4 feet Casing Length Size MD TVD Burst Collapse Conductor 80 13-3/8" 54.5# K-55 27 - 107 27.0 - 107.0 2730 1130 Production 11645 7" 26# L-80 25 - 11670 25.0 - 7447.3 7240 5410 Surface 6689 9-5/8" 47# N-80 26 - 6715 26.0 - 4605.2 6870 4760 Perforation depth: Measured depth: 11016 -11036,11050 -11060,11087 -11097,11164 -11184,11197 -11227,11256 -11286,11336 -11346 True vertical depth: 7051.28 - 7063.28,7071.7 -,7094.02 - 7100.08,7140.84 - 7153.08,7161.05 - 7179.46,7197.25 - 7215.62 7246.18 - 7252.28 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 23 - 10881 Packers & SSSV (type & measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11016-11346 Treatment descriptions including volumes used and final pressure: 16 Bbls 10"10 DAD Acid @ 2700 psig 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: 195 0.06 855 425 347 Subsequent to operation: 187 0.07 908 1460 346 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - ~ OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 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 Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature )a~ ~- Phone 564-4657 Date 9/21/04 Ot<\G\\~Þ\L RBDMS 8F L SEP 2 7 7W'Íc Form 10-404 Revised 4/2004 ~ ~ MPL-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/17/04 T/I/0=800/425/20***LOADED IA. W/125 BBLS DC. PUMP DOWN THE TUBING-60 BBLS DIESEL,10 BBLS H2O, 16 BBLS 10% DAD ACID & 64 BBLS DC TO DISPLACE ACID TO THE PERFS. 2 HR SOAK.*** FLOWED BACK 240 BBLS TO A TANK***PUT BACK ON PRODUCTION. FINAL- T /1/0=1650/1460/0. FLUIDS PUMPED BBLS 60 Diesel 190 Dead Crude 16 10% Dad Acid 10 Water 276 TOTAL Page 1 ,, .... STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION COMMJoSION 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. I~1 Development KBE = 51' [] 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 : 8. Well Number 3256' NSL, 4808' WEL, Sec. 08, T13N, R10E, UM MPL-11 At top of productive interval 9. Pe~ Approval No. 4958' NSL, 1039' WEL, Sec. 05, T13N, R10E, UM 10. APl- Number At effective depth 50-029-22336-00 43' NSL, 917' WEL, Sec. 32, T14N, R10E, UM 11. Field and Pool At total depth Kuparuk River Unit 148' NSL, 883' WEL, Sec. 32, T14N, R10E, UM 12. Present well condition summary Total depth: measured 11630 feet Plugs (measured) true vertical 7424 feet Effective depth: measured 11492 feet Junk (measured) Fish: 4 Flatguards and 3 Bands left in hole below perfs true vertical 7341 feet (08/01) Casing Length Size Cemented M D TVD Structural Conductor 80' 13-3/8" 500 sx Permafrost 'C' 110' 110' Surface 6658' 9-5/8" 1750 sx AS III 6688' 4588' Intermediate Production 11590' 7" 302 sx Class 'G' 11620' 7418' Liner Perforation depth: measured 11016'-11036', 11050'-11060', 11087'-11097', 11164'-11184', 11197'-11227', 11256'-11286', 11336'-11346' true vertical 7051'-7063', 7071'-7077', 7094'-7100', 7141'-7153', 7161'-7179', 7197'-7215', 7246'-7252' Tubing (size, grade, and measured depth) 2-7/8", 6.5# L-80 to 10959' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary fi~% !~(i.~ ~"~ Intervals treated (measured) Treatment description including volumes used and final pressure .S ~ P ~ i.! ~ 0 01 14. Representative Daily Avera.qe Production or InjeCtion Data ~n, choraq,~ 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 -~~. ~ Title Technical Assistant Date Signed Terrie Hubble ~% !'~ ! ~% I ~ ! ~ ~ Prepared By Name/Numbec Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 ORiGiNAL Submit In Du ~P ~E~~ION Page 1 of 2 Legal Well Name: MPL-'I 1 Common Well Name: MPL-'I'I Spud Date: 5/27/1993 Event Name: WORKOVER Start: 8/'16/200'1 End: 8/20/200'1 Contractor Name: NABOR$ Ri9 Release: 8/20/200'1 Rio Name: NABOR$ 4E8 Rio Number: 4 ~ ~0~:~ ~ ~rs ~i¢i~ ~ :NPT Phase ; Description of Operations 8/16/2001 00:00 - 09:00 9.00 MOB P PRE STDBY FOR CTU TO RD OFF L-35. 09:00 - 19:00 10.00 MOB P PRE MIRU & SAFE OUT EQUIPMENT, 19:00 - 22:00 3.00 MOB P PRE RU TIGER TANK & LINES TO TREE. 22:00 - 23:00 1.00 RIGU P PRE PULL BPV. 23:00 - 00:00 1.00 RIGU P PRE TEST SURFACE LINES & BODY TEST CHOKE MANIFOLD TO 3500 PSI. 8/17/2001 00:00 - 01:00 1.00 RIGU P PRE TESTED SURFACE LINES & BODY TEST CHOKE MANIFOLD TO 3500 PSI. 01:00 - 02:00 1.00 KILL P DECOMP OPEN UP WELL. TBG 1200 PSI. CSG. 1360 PSI. 02:00 - 05:30 3.50 KILL P DECOMP KILL WELL W/9.3 BRINE. 05:30 - 07:00 1.50 KILL P DECOMP MONITOR WELL. TBG. PRESS. 590 PSI. BLED OFF OUTER CSG. PRESS. 07:00 - 08:30 1.50 KILL P DECOMP CIRC. THRU GAS BUSTER. MONITOR. 590 PSI. WT. UP PITS TO 9.9. CIRC. MONITOR. TBG 640 PSI. CSG 660 PSI. 08:30-21:00 12.50 KILL P DECOMP WALTON 11.1 BRINE. 21:00 - 21:30 0.50 KILL P DECOMP 11.1 BRINE ON LOC. TESTED SURFACE LINES TO 3500 PSI. 21:30 - 22:00 0.50 KILL P DECOMP OPEN UP WELL. TBG. 510 PSI. CSG. 640 PSI. 22:00 - 00:00 2.00 KILL P DECOMP CIRC. 11.1 BRINE. MONITOR WELL. TBG. 40 PSI. CSG. 70 PSI. 8/18/2001 00:00 - 01:30 1.50 KILL P DECOMP MONITOR WELL. TBG. 40 PSI. CSG. 70 PSI. WT. UP PIT TO 11.4 PPG. 01:30 - 03:30 2.00 KILL P DECOMP CIRC. 11.4 PPG BRINE. WELL ON SLIGHT VAC. 03:30 - 04:30 1.00 PULL P DECOMP INSTALL TVVC & TEST 3500 PSI. 04:30- 06:00 1.50 PULL 3 DECOMP ND TREE. 06:00 - 14:00 8.00 PULL ~ DECOMP NU BOPE AND TEST LINES. 14:00 - 18:00 4.00 PULL 3 DECOMP P/T BOPE 250/3500 PER BP/AOGCC REGS. WITNESSED BY J. JONES AOGCC REP. 18:00- 19:30 1.50 PULL ~ DECOMP RU & PULL TVVC. 19:30 - 20:30 1.00 PULL 3 DECOMP MU LDG. JT. BOLDS. PULL HANGER. PU WT. 80K. LAY DN HANGER & LDG. JT. 20:30 - 00:00 3.50 PULL P DECOMP POOH W/ESP & 2 7/8" TBG. 8/19/2001 00:00 - 06:30 6.50 PULL P DECOMP POOH W/ESP & 2 7/8" TBG. 06:30 - 08:30 2.00 PULL P DECOMP L/D PUMP & MOTOR ASSM. CLEAR FLOOR. 08:30 - 09:30 1.00 PULL P DECOMP RU HALCO TO FISH BANDS & FLAT GUARDS. 09:30 - 13:00 3.50 PULL P DECOMP RIH W/6.0" GR & JUNK BASKET TO 2732'. POOH. RECOVERED 4 BANDS. RIH TO 11,286'. POOH. RECOVERED 13 BANDS & 1 FLATGUARD. 13:00- 13:30 0.50 PULL P DECOMP RD HALCO. 13:30 - 15:30 2.00 PULL P DECOMP PU & MU PO RETRIEVING TOOL. LATCH PO. BOLDS. PULL PO. INSTALL NEW PO. RILDS. TEST PO. LD TOOLS. 15:30 - 16:00 0.50 PULL P DECOMP RU FLOOR TO RUN NEW ESP & 2 7/8" COMPLETION. 16:00 - 22:00 6.00 PULL P DECOMP PU PUMP & MOTOR. SERVICE SAME. 22:00 - 00:00 2.00 PULL P DECOMP RIH W/NEW ESP & 2 7/8" COMPLETION. 8/20/2001 00:00 - 06:00 6.00 PULL ~ DECOMP CONT. RIH W ESP & 2 7/8" TBG. 06:00- 06:30 0.50 PULL ~ DECOMP SERVICE RIG. 06:30 - 09:00 2.50 PULL 3 DECOMP FINISHED RIH W/ESP & 2 7/8" TBG. 1 SPLICE MADE W/ RIH @ 6500'. 09:00- 09:30 0.50 WHSUR 3 DECOMP MU LDG. JT. & HANGER. 09:30 - 11:00 1.50 WHSUR ~ DECOMP SPLICE EFT CONN. PLUG IN & TEST. 11:00 - 12:00 1.00 WHSUR ~ DECOMP P/U WT. 82K. S/O WT. 37K. LAND HANGER & RILDS. SET & TEST TWC. 12:00 - 14:00 2.00 BOPSUR P DECOMP ND BOPE. HANGER SET HIGH. Printed: 8/21/2001 3:58:20 PM Legal Well Name: MPL-11 Common Well Name: MPL-11 Spud Date: 5/27/1993 Event Name: WORKOVER Start: 8/16/2001 End: 8/20/2001 Contractor Name: NABORS Ri9 Release: 8/20/2001 Rio Name: NABORS 4ES Ri9 Number: 4 i:: :i::?::~ iD~tei;;:'.: HoUr: ~i~i~ C~ N~ p~ase Description of Operations , 8/20/2001 14:00- 15:30 1.50 BOPSUF,P DECOMP NU DOPE. 15:30 - 16:30 1.00 WHSUR P DECOMP MU LDG. JT. BOLDS. PULL HANGER TO FLOOR. REDRESS HANGER SEALS. 16:30- 17:00 0.50 WHSUR P DECOMP RELAND HANGER. RILDS 17:00- 18:00 1.00 BOPSUF P DECOMP ND DOPE. 18:00 - 20:00 2.00 WHSUR P DECOMP NU TREE. TESTES HANGER & TREE TO 5000 PSI. 20:00 - 21:00 1.00 WHSUR P DECOMP RU LUBRICATOR. PULL TWC. SET BPV. L/D LUBRICATOR. SECURE WELL & CELLAR. RELEASED RIG @ 21:00. Printed: 812112001 3:58:20 PM MEMORANDUM TO: THRU: Julia Heusser, ~\~ Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission 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 hiPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, 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-o4 1900380 140 lO0! 105: P P OIL ~-05 1900390 140 100 100' P P OIL L-06 1900100 140 100 100 P P OIL L-07 1900370 140 100 100 e ~ OIL L-08 1901000 4000 2000 1950 P P WAG L-o9 1901010 L-Il 193.0130 140 100 llS P P OIL L-12 1930110 140 100 100 P P OIL '~-13 1930120 140' 100 100 P P OIL L-14 1940680 140 100 L-15 1940620 L-16A 1990900 L-17 1941690 L-20 1971360 '140 100 "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 e P OIL L-32 1970650 140 100 ' 100 P P OIL L-33 1971050 L-35 1970920 140 100 1051 P P OIL L-36 1971480 140 100 105 P P OIL L-37A 1980560 L-40 1980100 '140 100 100 P P F-~\~b~¥,~ OIL L-45 1981690 140 100 105 P P ~5' OIL L-34 1970800 4000 2000 1900 P 4 WAG , Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% [290 oar Remarks: ~o/9n/aa Paee 1 of 2 SVS MPU L Pad 12-22-00jc.xls 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 CYCLr~ II II ,-~r~:~c~r~ Paee 2 of 2 SVS MPU L Pad 12-22-OOjc.xls 01"4 OR BEFORE W ¢:LOp. lXlv~I~M.DOC 1. Operations performed: STATE OF ALASKA ALASKA O,-AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [~Alter Casing []Repair Well [--~Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3256' NSL, 4808' WEL, Sec. 8, T13N, R10E, UM At top of productive interval 4966' NSL, 1063' WEL, Sec. 5, T13N, R10E, UM At effective depth 43' NSL, 917' WEL, Sec. 32, T14, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE -- 51' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-11 9. Permit Number / Approval No. 93-13 10. APl Number 50-029-22336 11. Field and Pool At total depth 149' NSL, 910' WEL, Sec. 32, T14, R10E, UM 12. Present well condition summary Total depth: measured 11630 feet true vertical 7424 feet Effective depth: measured 11492 feet true vertical 7341 feet Plugs (measured) ' '~.~ ~.~:~ Junk (measured) Casing Length Structural Conductor 80' Surface 6658' Intermediate Production 11590' Size Cemented MD TVD 13-3/8" 500 sx Permafrost 'C' 110' 110' 9-5/8" 1750 sx AS III 6688' 4588' 7" 302 sx Class 'G' 11620' 7418' · Liner Perforation depth: measured true vertical 11~16'~11~36'~11~5~'~11~6~~~11~87'~11~97~~11164'~11184'~11197'~11227'~11256'~11286'~ 11336'-11346' 7~51'~7~63'~7~71'~7~77'~7~94'~71~~'~7141~~7153'~7161'~7179'~7197'~7215'~7246'~7252' Tubing (size, grade, and measured depth) 2-7/8", 6.5# L-80, 8rd EUE to 10925' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes u~ed and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments ~ Copies of Logs and Surveys run [~ Daily Report of Well Operations 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Terrie Hubble /[L~_ Title Technical Assistant III ~ ' Prepared By Name/Number: I16. Status of well classifications as: E~Z] Oil [Z] Gas [~] Suspended Service Date Terrie Hubb/e, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-11 Rig Name: Nabors 4ES AFE: 330148 Accept Date: 04/26/95 Spud Date: .... Release Date: 05/03/95 04/27/95 Move in and rig up. Rig lines to completion tree and test. Pick up lubricator and pull BPV. Open SSSV and leave 3000 psi on line. Tubing 1050 psi, annulus 340 psi. Load pits with water and mix KCL. Bullhead 70 bbls down tubing at 4.5 bpm at 850 psi. Tubing psi -0- at finish. Bleed annulus above packer to 0. Rig Camco and test lubricator to 3000 psi. RIH and pull dummy valve from GLM at 622'. Gas pocket blew tool up hole and cut line. Run in hole with #2 blind box at 520'. Tag kickover tool. Pump 15 bbls fluid down tubing at 1.5 bpm at 3500 psi. O4/28/95 Attempt to knock Camco GLV kick over tool down hole form stuck position in SSSV at 556'. Bull heading source water, also to push oil and gas influx into formation. Friction pressure is 3500 psi. At 1 to 1-1/2 bpm due to friction of wire and knockover tool. Pull up periodically and check tool string for damage and tightness. Unsuccessful at knocking tool loose. Continue attempts to knock tool down hole to allow bullheading fluid in correct procedure. Set TWC and ND tree. Nipple up BOP's and install 2-7/8" pipe rams. Test BOP's and choke manifold to 250 Iow and 5000 high. Witness by Bobby Foster with the AOGCC. Pick up offset lubricator and pull TWC tubing. Bleed gas off tubing and lay down lubricator. Rig up landing joint. BOLDS and pull packer. Release and attempt to circulate around element to clear influx below packer. Unsuccessful. Work tubing to release element. 04/29/95 Continue to circulate influx around packer at 1 bpm, 3500 psi. Pull hanger to floor and check cable and penetrator, lay down same. POOH with ESP. Laying down singles with TIW valve in each joint to packer and GLM with empty pocket. Circulate and divert heavy crude 133 bbls. Crude to tiger tank. Clean up wellbore of influx. Spot Xanvis sweep. POOH with tubing and ESP system. Lay ESP and check out same. Change rams to 3-1/2" and test. Operations Summary for: MPL-,, O4/3O/95 Load pipe shed and makeup FTA #1, RIH picking up 3-1/2" drill pipe. Tag junk at 10690'. Wash and mill on junk from 10960' to 11004'. High torque, add EP lube and knocked torque down. Wash over packer at 11004' - 11006'. Packer dropped. CBU and will chase packer to bottom and dress off for overshot run. 05/01/95 CBU at 11000', circulate out influx below packer. TIH and push packer to 11427'. Wash and rotate from 11427' - 11472'. Set 20K down on packer. POOH with FTA#1. Clean J-baskets. Makeup FTA#2 and RIH (overshot and grapple assembly). Tag packer at 11472', wash over and latch packer, monitoring well. POOH w/FTA#2 and packer. Lay down packer and screen assembly. Clean boot baskets. M/U BHA #3, RIH for clean out. O5/02/95 Circulate Xanvis sweep. POOH laying down 3-1/2" drill pipe and BHA #3. Change rams in BOP's to 2-7/8" and test. Makeup and service ESP. RIH with ESP completion on 2-7/8" tubing. 05/03/95 Continue RIH with ESP completion. Splice ESP cable at 1000'. Continue to RIH with ESP completion. Makeup hanger and install penetrator spliced ESP cable. BOLDS and land tubing hanger, set TWC. N/D BOP's. N/U tree and adapter flange. Test same to 5000 psi. Pull TWC. Freeze protect annulus with 68 bbls diesel and tubing with 18 bbls diesel. Set BPV and secure tree. Finish cleaning pits. Secure well. Page 2 MEMORANDUM TO: David Jo~ Chairmar, r~--' ,. THRU' Blair Wondzell, ~-~ P. i, Supervisor FROM' Bobby Foster,~'0~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 27, 1995 FILE NO: AWPID1CD.doc SUBJECT: BOPE Test- Nabors 4ES BPX - MPU - L-11 PTD # 93 - 0013 Kuparuk River Field Friday, April 27, 199.5..:. I traveled this dte to BPX's Miine Point well L-11 being worked over by Nabors rig 4ES and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there was one failure. A flange ring gasket leaked - this was tightened and retested OK. The rig was clean and all equipment appeared to be in good working order. The location was clean and all extra equipment was stored in a orderly manner. Summary: I witnessed the initial BOPE test on Nabors rig 4ES working over BPX's L-11 - test time 3 hours - 1 failure. Attachment: AWPIDICD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X ....... Drlg Contractor: NABORS Rig No. Operator: BPX Well Name: L-11 Casing Size: 7" Set @ 11,670' Test: Initial X Weekly Other 4ES PTD # Rep.: Rig Rep.: Location: Sec. 93-0013 DATE: 4/27/95 Rig Ph.# 695-6475 LARRY MYERS DAN HEBERT 8 T. 13N R. IOE Meridian U Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Pressure P/F 500/5,000 ** 500/5,000 ** 1 500/5,000 P I 500/5,000 P BOP STACK: Quan: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve N/A Test Press. P/F 300/3,000 P P 500/5,000 500/5,000 1 500/5,000 500/5,000 500/5,000 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves 10 No. Flanges Manual Chokes 1 Hydraulic Chokes I 24 500/5,000 Te~ Pressure P/F 500/5,000 P P Fun~ioned Fun~ioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2150 3,000 I P 1,!)00 P minutes 27 sec. minutes 14 sec. YES Remote: YES Psig. Number of Failures: '/ ,Test Time: 3.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 ~.n,~-~ s~opc ],.~cr,o. 6~-~ or ~7 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: FAILURE: Flan~]e gasket leaked on choke line - tightened and retested OK ** The kelly will not be used so it was not tested. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AWPID1 CD.XLS BOBBY D. FOSTER PERMIT DATA T DATA_F'LLIS R U N D A 1" E ....... ir;i: E C "7 D 93 013 l.~ 07 93 ...... 0'13 DAILY WELL ~tq--OPR~665a. .... 11634. COHP DATE:06 .... 20'--93 '~ ~' "'3'--93 TO 7-'~09 ..... 93 '10/'13/'i 993 09/i 4.//1993 09/' 'l t~/1993 93 .... 013 SLRVEY ~I"EL..ECO~ ONE F'A,SiE 9q .... 0t '~ BD/,.qR 93 ..... 013 B[)/GR t,,4:~..,,"RI~HD.~5~6711~'11575 Lr"'~. TVD~5 ~ 10650'~ 1 I51 09/08/1993 09/0 ~:'' / 1 q93 a3 "'013 r'[" T ......... ~:~ ~,-,tk~.. R1~'10650..-I'1505 9:3 --' 013 DF'/NP/DPR/GR ~ R1 ,,k~F..',.,6'711'^-11575 09/"08/ 1993 9:3 .... 0 t ~ DP/NP/DPR/GR '-~.. TVD~5 ~'~ 1065.0 .... 11512 93 .... 013 ..... DF'/NP/GR ~k~D.~2&BH~ t06 ~,0 .... 1 i512 09/'08/1993 93 013 DPR/GR /...L/ Rl~ND~6711 ..... 11575 09/08/1993 93 -.' 0 I 3 D ~--.' k / ,.-~ R /./"[.. Ri ~TVD.,67'I 1~'i 1575 09 / 0 (.ii', / i 99 3 93 .... (iit3 DF'R/GR P A C K / P El R F/' r'... E!, T/ R 1 ~ 5 ~ ~ 'i 06 ..~, 0 .... 1 'i ...~::, 12 06/28/1 (.? 93 93 .... 013 PERF ,f__..~/ Ri~10680 .... 11000 Il) 6/28/' 1993 93 ..... 0 i 3 P E R F' ~.. R1~'10680'-"1 tl.~00 Ii) 6/© 9 / I 993 Ar'e We i 'i y (~ ES i"l 0 STATE OF ALASKA A~oKA OIL AND GAS CONSERVATION COMMIS...~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing.. Alter casing Repair well Perforate Other X ESP replacement 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 2023' SNL, 147' EWL, SEC. 8, T13N, RIOE At top of productive interval 314' SNL, 1063' WEL, SEC. 5, T13N, RIOE At effective depth At total depth 149'NSL, 910' WEL, SEC. 32, T14N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11630 7417 11492 7337 ORIGINAL feet Plugs (measured) feet feet Junk (measured) feet 6. Datum elevation (DF or KB) KBE = 46 feet 7. Unit or Property name Milne Point Unit 8. Well number MPL- 11 9. Permit number/approval number 93-13/94-077 10. APl number 50- 029-22336 11. Field/Pool Kuparuk River Unit Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 0' 6658' 13-3/8" 9-5/8" 500 sx Permafrost "C" 110' 11 O' 1750 sx AS III 6688' 4588' 11590' 7" 302 sx Class "G" 11620' 7417' measured true vertical 11016'-11036', 11050'-11060', 11087'-11097', 11164'- 11184', 11197'-11227', 11256'-11286', 11336'- 11346' 7051'-7063', 7071'-7077', 7094'-7100', 7141'-7153', 7161'-7179', 7197'-7215', 7246'-7252' Tubing (size, grade, and measured depth) 2-7/8", 6.5P, L-80 tubing to 10876' MD Packers and SSSV (type and measured depth) ESP Centralift GC 1200 @ 10876' MD; Arrow Hydrow liP dual packer @ 579' MD Otis FMX SSSV @ 560' MD n r c r I t ~ r r~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure AUG 1 2 1994 Alaska Oil & Gas Cons. Commission 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Productiorl or Iqjectior~ Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil x Gas Suspended 17' I hereby certify~?'~ ~,~g/~,~g. i;7 and c°rrect t° the best °f mY kn°wledge', Sicjned /'~ ~ F,~..,~~,...- Title Drilling Engineer Supervisor Form 10-404 Re(/d~/15/88 v Service SUBMIT IN DUPI~IC~TE MPL-11 W/O #1 04/19/94 11,630' PREP TO MOVE TO MPL-11. SET BPV IN L-11 AND WAIT FOR GRADER TO LEVEL PAD. GRADE PAD AND LAY MATS. MOVE COMPLEXES OFF L-7. SPOT SUB OVER L-11. SPOT PITS, PIPE SHED AND MOTOR COMPLEX. HOOK UP LINES. PREP TO TAKE ON SOURCE WATER. FILTER AND TAKE ON 650 BBL SOURCE WATER. REPAIR LEAK IN PILL PIT. R/U LUBRICATOR, PULL BPV. INSTALL L/J IN TREE CAP. PUMP 78 BBL SOURCE WATER FOLLOWED BY 14 BBL DIESEL. FINAL SHUT IN PRESSURE - 12OO PSI. ATTEMPT TO BLEED OFF PRESSURE ABOVE TRSV. PRESSURE BUILT TO 600 PSI. PREP TO BULLHEAD MORE WATER AND DIESEL DOWN HOLE. 04/20/94 11,630' PUMP 150 BBL SOURCE WATER DOWN TBG - FCP 1950 PSI. SUSPECT THAT GRAVEL PACK SCREEN IS PLUGGING W/DEBRIS FROM WELL. S/D. PRESSURE DROPPED TO 1000 PSI. BLEED TO 550 PSI. STARTED GETTING CRUDE AND DIESEL BACK AFTER BLEEDING 3-4 BBL. SI PRESSURE BUILT FROM 550 TO 750 PSI. BLEED TO 450 PSI - BUILT UP TO, 500 PSI IN 15 MINUTE. SUSPECT UPPER GL VALVE LEAKING FROM TBG TO ANNULUS. FREEZE PROTECT TBG W/7 BBL DIESEL. BACK OUT LANDING JOINT. R/U HOT OIL. PUMP 20 BBL DIESEL @ 160 DEGREE TO TBG WITH W/L IN HOLE WITH TUBING BRUSH TO CLEAN TBG WALL. GOT DOWN TO 710'. PULL ORIFICE VALVE AND SET DUMMY VALVE. PUMP 78 BBL WATER TO TBG. SHUT DOWN AND ALLOW PRESSURE TO DROP. BLEED PRESSURE. STARTED GETTING GAS BACK @ SURFACE BUILT TO 500. BLEED PRESSURE THROUGH CHOKE MANIFOLD. GETTING CRUDE/GAS BACK. PRESSURE BUILT. MONITOR TUBING PRESSURE. NO CHANGE. BLEED OFF ANNULUS PRESSURE. RIH W/SLICK LINE AND PULL DUMMY VALVE. COULD NOT GET DOWN TO ICE BUILDUP IN TBG. PUMP 20 BBL WARM SOURCE WATER. RIH W/GAUGE RING. RUN AND SET NEW DUMMY VALVE. PUMP 78 BBL WATER TO TBG. BLEED PRESSURE DOWN. PRESSURE BUILT TO 425 PSI. 04/21/94 11,630' OBSERVED TUBING PRESSURE. RETRIEVED VALVE FROM TOP GLM, RIH AND SET XX PLUG IN X NIPPLE, TESTED TUBING, RETRIEVED PLUG REDRESSED AND RESET DUMMY VALVE IN TOP GLM. ATTEMPTED TO PUMP DOWN TUBING NO SUCCESS. RIH WITH GAUGE RING. FLEXED TUBING TRYING TO MOVE ICE PLUG, NO SUCCESS. RIH TO PULL DUMMY, ENCOUNTERED ICE AT 158' WLM. WORKED DOWN TO GLM WITH KICK OVER TOOL, RETRIEVED DUMMY FROM TOP GLM. HEATED AND PUMPED HOT S H20, FOLLOWED BY 10 BBLS METHANOL H20. BLED OFF TUBING. PUMPED 70 BBLS HOT H20. RIH GR TO 2000 FT WLM, PULLED GR AND. RECEIVED AUG '1 2 1994 Oil & Gas Cons. Commission , Anchora~o RAN LIB VERIFIED ICE PLUG. PUMPED 150 BBLS HOT H20. RIH GR TO 1000 FT WLM, POH AND RIH DUMMY VALVE. 04/22/94 11,630' SET DUMMY IN TOP GLM. DUMMY NOT SET. PULLED AND SET ANOTHER DUMMY, INDICATIONS DUMMY NOT HOLDING. PULLED AND REDRESSED DUMMY, TO HOLD BOTH WAYS IN ONE SEAL SECTION, RESET DUMMY, BLED TUBING, PRESSURE STABILIZED. PUMPED 50 BBLS 8.5 BRINE, PRESSURE STABILIZED. WEIGHTED UP BRINE. RIH CAMCO AND SET XX PLUG IN X NIPPLE, TESTED PLUG. INSTALLED 2 WAY CHECK, NIPPLE DOWN TREE AND NIPPLE UP BOP, TESTED BOP, PULLED CHECK VALVE. RU CAMCO RIH TO PULL XX PLUG. 04/23/94 11,630' RIH TO RETRIEVE XX PLUG SSSV FLAPPER WAS CLOSED, POH AND PU HOLD OPEN TOOL, RIH TO WELLHEAD WOULD NOT ENTER TUBING, POH AND DRESSED BEVEL, RIH NO SUCCESS. FOUND SCALE ON BEVEL, RAN TUBING BRUSH AND BRUSHED TUBING, OTIS LOCK OUT TOOL ARRIVE, MU LOCK OUT TOOL AND RIH. SET TOOL, SHEARED OFF AND POH, RIH AND RETRIEVED TOOL, RIH CHECKED SSSV STILL CLOSED, RERAN LOCK OUT AND LOCKED SSSV OPEN. RAN EQUALIZING PRONG, RIH AND PULLED XX PLUG, RD CAMCO. FILLED TUBING WITH 8.3 BBLS 9.6 BRINE. RU TO KILL WELL, BLED OFF ANNULUS AND BACKED OUT LOCK DOWN SCREWS, PU AND UNSEATED PACKER, CIRC AND KILLED WELL WITH 9.6 PPG BRINE, FLUID LEVEL DROPPED. REDUCED BRINE WT TO 8.6, OBSERVED WELL. POH LAID DOWN SSSV AND PACKER, CONT. TO POH SLM. 04/24/94 11,630' POH TUBING, LAID DOWN ESP. LOST 7 BANDS AND 6' GUARD. INSTALLED WEAR BUSHING AND PU 15 JTS TUBING. RIH WITH GLOBE BASKET TO CLEAN OUT ESP JUNK. WORKED BASKET DOWN 3'. CBU. TRACE OF SAND. POH WITH GLOBE BASKET. 04/25/94 11,630' CLEANED OUT GLOBE BASKET. RECOVERED 6 BANDS, PULLED WEAR BUSHING. RIH ESP COMP. 04/26/94 11630' RIH ESP AND LANDED OUT SAME. TESTED CONTROL LINE. TESTED TBG HANGER, OK. PUMPED 60/40 METH. H20 DOWN 7" X 2 7/8" ANN TO 2283'. PUMPED DIESEL DOWN TBG TO 2283' MD. SET PACKER AND TESTED ANNULUS. CLOSED SSSV, INSTALLED TWC, ND BOP, NU TREE. TESTED FLANGE, CONTROL LINE, ESP CABLE, TREE TO PROGRAM SPECS. PULLED TWC AND INSTALLED BPV. BLEW DOWN LINES TO MOVE. RELEASED RIG @0200 HRS ON 04/26/94. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program .... Pull tubing __ Variance __ Perforate __ Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 4. Location of well at surface 2023' FNL, 147' FWL, Sec 8, T13N, RIOE, Umiat Meridian, North Slope Borough At top of productive interval 314' FNL, 1063' FEL, Sec 5, T13N, RIOE, Umiat Meridian, North Slope Borough At effective depth 6. Datum elevation (DF or KB) 51' MSL 7. Unit or Property name Mi/ne Point Unit At total depth 149' FSL, 910' FEL, Sec 32, T14N, RIOE, Umiat Meridian, North Slope Borough 8. Well number L-11 9. Permit number 93-13 ~ 10. APl number 50- 029-22336 ~'). feet 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical 11630 feet 7423 feet Plugs (measured) 11531'MD PBTD Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured cl~ True vertical depth Structural BKB Conductor 80' 13-3/8" 500 sx Permfrost C 110' 110' Surface 6658' 9-5/8" 1750 sx Arctic Set III 6688' 4588' Intermediate 305 sx Class G Production 11590' 7" 302 sx Class G 11620' 7417' Liner Perforation depth: measured 11016-11036, 11050-11060, 11087-11097, 11164-11184, 11197-11227, 11256-11286, 11336-11346 true vertical 7051-7063, 7071-7077, 7094-7100, 7141-7153, 7161-7179, 7197-7215, 7246-7252 RECEIVED Tubing (size, grade, and measured depth) 2-7/8" 6.5#/ft 8rd EUE L-80 10842' Packers and SSSV (type and measured depth) Arrow Hydrow II Pkr 595', Otis FMX SCSSV 579' 13. Attachments Description summary of proposal × Detailed operations program N1AR 2 1 1994 Atask~ Oil & Gas Cons. Commis BOP sketc~nchorage 14. Estimated date for commencing operation April 12, 1994 16. If proposal was verbally approved Oil __x_ Gas __ Name of appr?ver Date approved Service 17. I hereby certif~that'-~ th~foregoing is true and correCt to the best of my knowledge. Signed q,~ /~"~ ¢,,N Title D,~ ~.~' / FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended __ Date 15 Mar 94 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test__ Subsequent form required 10- I Approval NO. ? ~'"."-0 ~ ? Approved by order of the Commission Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 Commissioner [,;oF, Z ~,~u ~ V SUBMIT IN TRIPLICATE jolt Milne Point Unit L-11 ESP Replacement Procedure Summary 1. RU Nabors 22E rig. ND tree, NU and test BOP's. 2. PU and release Arrow Hydrow IIP packer at 595'. 3. Circulate and kill well with 8.0 ppg water/30% MeOH. 4. POOH and LD ESP assembly. 5. PU new ESP. 6. TIH with new ESP assembly and new cable on 2-7/8" tubing. 7. Land hanger. Freeze protect tubing and annulus with methanol. 8. Set and test packer. 9. ND BOP's. NU and test tree. 10. RD rig. 1 1. Place well back on line as ESP oil producer. RECEIVED N1/~F~ 2 1 1994 ~l~,sv,~ uu ~ Gas Cons. Commission Anchorage 6324/6116 Nielson Way Anchorage, AK 99518 907-563-3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-1358 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Atto: Larry Grant Date: 10 October 1993 Well Reference Data: Well No: L-11 Field: Milne Point Unit County: North Slope State: Alaska API No: 50-029-22336 BH-INTEQ No: 1225 Enclosed is the following data as listed below: 1 - LIS Data Tape 1 - LIS Verification Listing Upon receipt, please sign and remm to Baker Hughes INTEQ 6116 Nielson Way Anchorage, AK 99518 Atto: Tom Brockway Received By: Date: INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-013 BD/GR 93-013 BD/GR 93-013 CBT 93-013 DP/NP/DPR/GR 93-013 DP/NP/DPR/GR 93-013 DP/NP/GR 93-013 DPR/GR 93-013 DPR/GR 93-013 DPR/GR 93-013 PACK/PERF/CBT 93-013 PERF 93-013 PERF 93-013 407 93-013 DAILY WELL OP. RI,MD,5",6711-11575 TVD,5",10650-11512 R1,10650-11505 RI,MD,6711-11575 TVD,5",10650-11512 MD,2&5",10650-11512 RI,MD,6711-11575 R1,TVD,6711-11575 TVD,2&5",10650-11512 R1,5",10650-11512 R1,10680-11000 R1,10680-11400 COMP DATE:06-20-93 5-23-93 TO 7-09-93 Are well tests required? Yes (~o~,) Was well cored? Yes ~ If yes, was the core analysis & description received? Are dry ditch samples ri~ed? Yes~~~/ WELL IS ON COMPLIANCE. I iT AL Yes ~~__________. 09/16/1993 PAGE: 1 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 September 13, 1993 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: L-11; WELL COMPLETION OR RECOMPLETION REPORT AND LOG Dear Mr. Johnston, Attached are two copies of Well Completion or Recompletion Report and Log, Form 10-407, and associated information for Milne Point Unit Well L-11. Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist attachments CC: JDP, TJY L-11 Well File Chevron Occidental RECEIVED S E P 1 4 199~ Alaska Oil & Gas Cons. Comr~iss~o~ gncli0rage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 'i:~~' 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 305, Anchorage, AK 99503 Classification of Service Well 7. Permit Number 93-13 8. APl Number so-- 029-22336 4, Location of well at surface ~~Mj~i'ETL''2~'~ i 2023' FNL, 147' FWL, Sec 8 T13N, R10E, U.M , NSB,I~/~..~ 314' FNL, 1063~ FEL, Sec 5 T13N, R10E, U.M , NSB, At Total Depth 149' FSL, 910' FEL, Sec. 32, T14N, R10E, U.M., NSB, AK 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 51' MSL (30' AGL) I ADL 25509 & 355017 12. Date Spudded 5~27~93 17. Total Depth (MD+TVD) l1603'MD/7423'TVD 13. Date T.D. Reached 6~4~93 18. Plug Back Depth (MD+TVD) 11531 'MD/2364 ' TVD 9. Unit or Lease Name Milne Point Unit 10. Well Number 11. Field and Pool Kuparuk River 14. Date Comp.,Susp. or Aband. liE. Water Depth, if offshore 116. No. of Completions 6/20/93 (Initial) I N/A feet MSL / 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES ::~ NO [] 578' feet MD I +1800' 22. Type Electric or Other Logs Run MWD- Dir/GR/Res/Ne~/Den, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD CASINGSlZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD K-55 13 3/8" 9.5/8" 7'! 54,5 47 26 N-80 L-80 SETTING DEPTH MD TOP BOTTOM 3Q'(surf 110' 30'(surf 6688' 30'(surf 11620' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 30" 12 1/4" 8 1/2" 500sx Permafrost C 17503x Arctic Set II 3053x Class "G" 3023x Class "G" AMOUNT PULLED 11016-11036 MD 7051-7063 TVD 11050-11060 7071-7077 11087-11097 7094-7100 11164-11184 '7141-7153 11197-11227 7161'7179 11256-11286 7197-7215 11336-11346 7246-7252 27. N/A , N/A 25, TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2 7/8 6.5 10.842 595 & 10.971 . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ] AMOUNT& KIND OF MATERIAL USED 11016-11346 I 191,471(/ 12-18 I$.P 10992-11050 ]35 mx C_laS$. "G" cememt PRODUCTION TEST Date First Production 6/27/93 Date of Test 6/27/93 Hours Tested 6 Flow Tubing Casing Pressure Press. 692 0 28. CORE DATA Method of Operation (Flowing, gas lift, etc.) ESP lift PRODUCTION FOR OIL-BBL IGAS-MCF TEST PERIOD ~ 140 I 8 CALCULATED,~, OIL-BBL GAS-MCF 24-HOUR RATE I!~ 559 32 WATER-BBL 95 WATER-BBL 378 tCHOKESIZE GAS-OIL RATIO 209 57 oil GRAVITY-APl (corr) 22.7 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R' ' EIVED S E P 1 4 199;~ Alaska 0il & Ga:~ uons. Anchorage Submit in duplicate Form 10-407 ~.,, v ~ on t"':C)NTINtJEB ON REVERSE SIDE 29. 30. NAME HRZ MARKER LAMINATED ZONE LK-1 LK-2 LK-3 LK-4 BASE KUP INTERVAL GEOLOGICMARI<FIdS MEAS. DEPTH 10,574 10,781 11~004 11,164 11,195 11,250 11,339 11,348 TRUE VERT. DEPTH 6784 6910 7044 7141 7160 7193 7248 7253 hORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, arid time of each phase. 31. LIST OF ATTACHMENTS 32. Titte s (~ ~, "' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this welt is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of anv multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL No. L-11 CASING SKETCH (P) MILNE POINT UNIT APl No.: 50-029-22336 PERMIT No.: 93-13 DRILLED: 5/9.3 ARCTIC PACKED: OPEN OPERATOR: CONOCO INC. SURFACE LOCATION' 202..5' FNL, 471' SEC 8, T15N, RI OE, UM BOTTOM HOLE LOCATION: t49' FSL, 910' FEL, SEC 52, T14N, RIOE, UM SPUD DATE: 5-27-95 V~(M CSG SPOOL RKB = 29' /~ ',lABOR RIG 13 3/8", 54.5#, K-55 BTRC SET @ 80' BGL HOS-ES STAGE CEMENT TOOL @ 1902' MD TOC @ .... 9 5/8", 47#, N-80 BTRS, FS @ 6688' MD CEMENT DATA: 50BBLS WATER, 1750 SX ARCTIC SET III W/ 5% GILSONITE + 505SX CLASS 'O' + 1% D65 + 0.5% D156 + 1.5% S-1 (CaCI2) + 0.2% D46. CEMENTED TO SURFACE. CENTRALIZERS: RE6EIVED , 1 PER 40' JTS 1-20 1 PER 80' JIS 20-40 1 PER 40' JTS 112-114 S E P 1 4 1993 1 PER 40' JTS 98 AND 99 2 PER 40' dis 115 Alaska Oil & 6as 6ons. L;ommissio~ 1 PER 120' JTS 147-155 Anchorage NOTE: PERFORATED 7" CASING W/ 9 SHOTS @ 10,990' TO 10,992' & SQUEEZED W/ 28 BBLS CLASS 'O' CEMENT. TESTED TO 1875 PSIC. PBTD 11,492' MD TD 11,650' EPNA - ANCHORAGE DIVISION 7", 26#, L-80, BTRC SET @ tl, 670'. CEMENT DATA: 100 BBLS, 11.0 SEPIOLITE, SPACER, 302SX CLASS '6;' (67BBLS) CEMENT + 0.05 GPS D47 + 0.4% D65 + 0.1 GPS D155 + 0.5 (:;PS D600 + 0.15% D800 (LIQUID LATEX SYSTEM) ._ NOT[: LOST 50 BBLS RETURNS WHILE PUMPING CEMENT AND DISPLACING TO BUMP PLUG. CENTRALIZERS: 1 PER 40' JTS 1-17 1 PER 80' JTS 18-58 1 PER 40' PSO JTS 95-94 1 PER 80' PSO JTS 202-261 1 PER 120' PSO JTS 269-271 APPROVED BY: JDP DRAFTED BY: G. FAST DATE: 9-9-95 CAD FILE: WCAL11 WELL No. L-11 COMPLETION St(ETCH MILNE POINT UNIT (P) APl No.: 50-029-22336 PERMIT No.: 93-15 COMPLETED: 06-20-93 LAST WORKOVER: 7-9-95 WKM HANGER WITH 2 1/2" BPV PROFILE 2 7/8" 6.5#/FT L-80 8rd EUE TBG. ELECTRIC SUBMERSIBLE PUMP CABLE NO. 2 CL-350 NOTES: 1. ALL DEPTHS MEASURED KDB-SL = 51' KDB-GL = 28' 2. MAX. ANGLE = 58'@ 7804' 3. K.O.P. = 400' 4. SLANT HOLE: YES 5. TREE TYPE: WKM 2 9/16" APl 5000# W/ 2 7/8" 8rd TREETOP CONNECTION 6. MIN I.D. = OTIS 'X' NIPPLE (2.515" I.D.) @ 611' 7. COMPLETION FLUID: 10.2 PPG N(~Br 8. STIMULATION: FRACTURE STIMULATION 172,600# t2-18 ISP BEHIND PIPE MK, LZ, LK PERFORATIONS DENSITY: t2 SPF, 5" CSG GUNS 11,016'-11,036' MD (7055'-7065' TVD) 11,050'-11,060' MD (7075'-7078' TVD) 11,087'-11,097' MD (7096'-7102' TVD) 11,164'-t1,184' MD (7146'-7154' TVD) 11,197-11,227' MD (7162'-7180' TVD) tl,256'-11,286' MD (7197'-7215' TVD) 11,336'-t1,346' MD (7245'-7251' TVD) 26#/FT L-80 CSG---"~ CONOCO INC. ANCHORAGE DIVISION 579' 595' 611' 2 7/6" OTIS FMX SCSSV ARROW HYDROW I IP DUAL PACKER 2 7/8" OTIS 'X' NIPPLE (2.313" I.D.) 657' 2 7/8" CAMCO KBMG MANDREL W/ ORFICE 10,726' 10,774' 2 7/8" CAMCO KBMG MANDREL W/ OTIS HOT OIL VALVE SET @ 3200 PSI ~P 2 7/8" POSITIVE CHEGK VALVE 2 JTS. 2 7/8" 6.5#/FT L-80 8rd EUE TBG. 10,842' 10,888' CENTRILIFT ESP GC-1200, 146 STAGE TANDEM GSBT SEAL, MOTOR 100 HP 2145V, 27A, KRYTOX BOTTOM OF ESP 10,971' BAKER MODEL 'D' PERM PKR W/ MILLOUT EXTENSION .~.~--10,983' 11,004' 11,010' 20' 20 GAUGE SCREEN ON 4" BASE 6' 3 1/2" PUP JOINT CAMCO 'D' NIPPLE WITH A-2 BLANKING PLUG ON C-LOCK S EP 1 4 1993 11,492' PB~[~aska Oil & Gag Cons. OommissiO~ Anchorag APPROVED BY: JHA DRAFTED BY: G. FAST DATE: 7-20-93 CAD FILE: WCOL11 COt OCO) CONOCO Detailed Activity Report 05/23/1993 1 A14 45 11.00 00:00 11:00 I A14 45 4.50 11:00 15:30 I A14 41 8.50 15:30 00:00 05/24/1993 I A14 42B 24.00 00:00 50:00 05/25/1993 I A14 42B 12.00 00:00 12:00 I A14 42B 12.00 12:00 00:00 05/26/1993 I A14 42B 12.00 00:00 12:00 1 A14 42B 12.00 12:00 00:00 05/27/1993 I A14 42B 3.00 00:00 03:00 05/28/1993 05/29/1993 05/30/1993 I A14 42B 6.50 03:00 09:30 I PIB 1E 2.50 09:30 12:00 I PIB 1E 3.50 12:00 15:30 4 P2 2B 0.50 15:30 16:00 4 P2 6C 1.00 16:00 17:00 4 P2 2B 2.00 17:00 19:00 4 P2 6C 1.00 19:00 20:00 4 P2 2B 4.00 20:00 00:00 4 132 2B 11.50 00:00 11:30 4 P2 6D 1.50 11:30 13:00 4 132 7 1.00 13:00 14:00 4 P2 6D 0.50 14:00 14:30 4 P2 3B 0.50 14:30 15:00 4 P2 2B 9.00 15:00 00:00 4 P2 6D 2.00 00:00 02:00 4 P2 7 0.50 02:00 02:30 4 P2 6D 1.50 02:30 04:00 4 P2 2B 2.50 04:00 06:30 4 P2 2B 3,00 06:30 09:30 4 P2 6A 4.50 09:30 14:00 4 132 6A 2.50 14:00 16:30 4 132 3B 0.50 16:30 17:00 4 P2 2B 7.00 17:00 00:00 4 P2 2B 6.50 00:00 06:30 4 132 5 2.00 06:30 08:30 4 P2 10 0.50 08:30 09:00 0.0 MOVE IN RIG AND SPOT AUX COMPONENTS 0.0 NU/ND DIVERTER AND WORK ON PITS 0.0 WELDING AND REPARING PITS 0.0 GRIND AND REMOVE COATING FROM SEAMS IN PITS FOR INSPECTION, WORK ON 3" CEMENT UNE FROM CELLAR TO PITS WORK ON MUD CLEANER DISCHARGE LINE 0.0 CONTINUE TO GRIND AND REMOVE COATING FROM WELDED SEAMS IN PITS. CONTINUE TO WORK ON 3" CEMENT LINE FROM CELLAR TO PITS, WORK ON MUD CLEANER DISCHARGE LINE, 0.0 CERTIFIED INSPECTORS AND EQUIPMENT ARRIVED -- VlSUAI~ MAGNA FLUX, AND VACUUM BOX TEST WELDS IN PITS 1 & 2. 0.0 CONTINUE TO CLEAN AND INSPECT PITS -- VlSUAI~ MAGNA FLUX, AND VACUUM BOX. RESEAL WELDS. 0.0 CONTINUE PIT INSPECTION -- RESULTS: PIT POROSITY HOLE CRACKED WELD 2 0 2 3 I 0 6 I 1 7 0 2 8 0 4 TRIP 4 0 TOTAL 6 g 0.0 FINISH PIT INSPECTION W/VlSUAI~ MAGNA FLUX, AND VACUUM BOX -- SEE 5/28/93 COMMENTS FOR RESULTS OF PIT INSPECTION. 0.0 FINISH REPAIRING WELDS AND APPLYING SEALENT TO PITS -- ALLOW TO DRY. 0.0 P/U 5" DP AND STAND BACK IN DERRICK WHILE FILENG PITS W/WATER, 0.0 127.0 127.0 379.0 379.0 656.0 2335.0 2335.0 2335.0 2335.0 2335.0 4424,0 4424.0 4424.0 4424.0 4600.0 5237.0 5237.0 5237.0 5237.0 6315.0 6710.0 6710.0 6710.0 ACCEPTED RIG AT 0930 ON 5/27/1993 MIXING SPUD MUD. DRLG ICE IN CONDUCTOR F/35'-107' AND SPUD WELL WHILE DRLG F/107'-127', P/U & ORIENT MWD. DRLG F/127'-379' W/2 STANDS OF H P. RECORDING FOLLOWING DATA: SPM GPM PSIG 140 590 1900 120 16oo 100 420 1200 SLIDING F/379'-656'. (KOP DRLG F/656'-2335' -- 98% SLIDING. Anchorage MIX & PUMP DRY JOB, SHORT TRIP TO DCs. PULLED 60 K OVER P/U F/2147'-2091' & PULLED 50K OVER F/1546'-1482' -- WIPED THRU EACH AREA ONCE AND PULLED FINE. SERVICE TOP DRIVE. RIH T/2200' W/NO PROBLEMS. REAM OUT DOGLEG F/2200'-2335'. RETURNS AFTER SHORT TRIP SHOWED PATCHES OF CLAY & SAND WALLCAKE. DRLG F/2335'-4424' -- 95% ROTATING. PUMP DRY JOB AND SHORT TRIP 34 STANDS TO HWDP. WORKED PIPE THRU TIGHT SPOTS F/2811-2730' AND 2240'-1862'. SERVICE TOP DRIVE. RIH, TOOK WT. AND STACKED UP AT 2017'. A'FrEMPTS TO WORK PIPE PAST DOGLEG FAILED. CALL CO. MAN AND DIR DRLR TO FLOOR. ENGAGE PUMPS AND ROTARY WHILE STACKING UP SEVERAL TIMES WHILE WORKING PIPE THRU DOGLEG TO 2334'. FINISH RIH WHILE WIPING TIGHT SPOT AT 2800'. DRLG F/4424'-4600' (95% ROTATING). MOTOR TORQUED UP AND STALLED, PICKED UP, AND RESTART MOTOR -- EXPERIENCED 1000 PSIG LOSS IN PUMP PRESSURE. DRLG F/4800'-5237'. STACKING UP ON 30' INTERVALS AND EXPERIENCING ERATIC TORQUE READING S/SWINGS TO 1050 AMPS FOR LAST 2 STANDS -- NORMAL IS 550 TO 700 AMPS. DECISION TO PULL BIT. POOH SLOWLY -- SWABBING. BHA BALLED UP WITH FM CLAY -- TALKED W/MUD ENGINEER ABOUT STARTING POLYMER AND DESCO TREATMENTS. CHECKED BIT -- OTHER THAN MISSING ONE 16 NOZZLE, BIT LOOKED GOOD (2-2-WT-A-E-2-BT-PP). CHANGE BIT, TEST MOTOR AND MWD, & RIH TO 5050'. REAM F/5050'-5237'. DRLG F/5237'-6315' (95% ROTATING). DRLG F/6315'-6710' (SLIDING 25% IN A3-rEMPTS TO BUILD W/NO FAVORABLE RESULTS). CIRC & CONDITION TO RUN 9-5/8" CASING. DROP MULTI-SHOT SURVEY AND PUMP DRY JOB. CONOCO Detailed Activity Report 4 P2 3B 2.50 09:00 11:30 6710.0 4 P2 10 1.50 11:30 13:00 6710.0 4 P2 6F 1.00 '13;00 14:00 6710.0 4 P2 5 1.50 14:00 15:30 6710.0 4 P2 10 0.50 15:30 16:00 6710.0 4 P2 6F 3.50 16:00 19:30 6710.0 4 P2 6C 2.50 19:30 22:00 6710.0 4 P4 13A 2.00 22:00 00:00 6710.0 05/31/1993 4 P4 13A 6.00 00:00 06:00 6710.0 06/01/1993 06/02/1993 06/03/1993 06/04/1993 4 L14 8B 1.50 06:00 07:30 6710.0 4 P4 13A 3.00 07:30 10:30 6710.0 4 P4 13A 1.50 10:30 12:00 6710.0 4 P4 5 1.00 12:00 13:00 6710.0 4 P4 12A 3.50 13:00 16:30 6710.0 4 P4 12A 3.50 16:30 20:00 6710.0 4 P4 13A 1.00 20:00 21:00 6710.0 4 P4 14A 3.00 21:00 00:00 6710.0 4 P4 14A 2.00 00:00 02:00 6710.0 4 P4 14A 5.00 02:00 07:00 6710.0 4 P4 15A 3.50 07:00 10:30 6710.0 4 P4 24 0.50 10:30 11:00 6710.0 8 L14 8B 1.00 11:00 12:00 6710.0 8 P2 9 1.00 12:00 13:00 6710.0 8 P2 7 1.00 13:00 14:00 6710.0 8 L14 8A 2.00 14:00 16:00 6710.0 8 P2 6C 2.50 16:00 18:30 6710.0 8 P2 6F 0.50 18:30 19:00 6710.0 8 P2 6F 1.00 19:00 20:00 6710.0 8 P2 2A 2.00 20:00 22:00 6710.0 8 P2 6F 2.00 22:00 00:00 6710.0 8 P2 6F 1.50 00:00 01:30 6710.0 8 P2 5 0.50 01:30 02:00 6710.0 8 P2 15B 0.50 02:00 02:30 6710.0 8 P2 2B 1.50 02:30 04:00 6710.0 8 P2 5 1.00 04:00 05:00 6710.0 8 P2 17 0.50 05:00 05:30 6710.0 8 P2 6F 1.50 05:30 07:00 6710.0 8 P2 2B 17.00 07:00 00:00 6710.0 8 P2 2B 12.00 00:00 12:00 9767.0 8 P2 2B 3.00 12:00 15:00 10079.0 8 P2 7 0.50 15:00 15:30 10079.0 8 P2 2B 0.50 15:30 16;00 10079.0 8 P2 7 0.50 16:00 16:30 10079.0 8 P2 2B 7.50 16:30 00:50 10079.0 8 P2 2B 1.00 50:00 01:00 10885.0 ATTEMPT TO POOH TO RUN CASING. PULLED 5 STANDS W! NO PROBLEMS. NEXT 3 STANDS PULLED TIGHT W/75K OVERPULL WHILE SWABBING -- WIPED EACH STAND. ENGAGE TOP DRIVE, ROTARY, AND PUMPS WHILE BACKREAMING 8 STANDS F/5936'-5178' -- DISENGAGE TOP DRIVE AND PULLED FREE F/5178' TO 4400'. RETRIEVE MULTISHOT TOOL ON SLICKLINE -- SECKMNE CUT THRU SHEAVE MAKING IT NECESSARY TO REPLACE SHEAVE. RIH TO TD O 8710' -- NO PROBLEMS. ClRC & COND TO RUN 9-5/8" CASING -- SAND AND CLAY STRIPS ACROSS SHAKERS AT BOTTOM UP. DROP MULTI-SHOT TOOL & PUMP DRY JOB. POOH (SI.M) WHILE MULTI-SHOT EVERY STAND. CLEANED BALLED UP CLAY OFF OF TOOL JOINTS ON DRILL PIPE & HWDP -- DISCUSSED RUNNING CONDET AND SAPP IN FUTURE TO SUCK UP AND CLEAN CLAY OFF BHA. CLEAN CLAY BALLS OFF STABILIZERS AND & I./D BHA (SLM -- NO CORR). CLEAN & CLEAR RIG FLOOR. M/U TAMM PACKER (NOTE: THE 9-5/8" TAMM PACKER REQUIRES 15" WORTH OF 5" DP PUPS AND A SLING LONG ENOUGH TO PROVIDE CLEARANCE WHILE P/U THE CASING OFF THE SKATE. FINISH RU CASERS, CHANGE TOURS, HOLD PRE-JOB SAFETY MEETING, AND RUN 9-5/8" CASING. REPAIR CABLE ON PIPE SKATE. FINISH RUNNING 9-5/8" CASING. L/D TAMM PACKER, M/U HANGER, LANDING JT, AND CMT HEAD. CIRCULATE ONE ANNULAR VOLUME. PERFORM STAGE ONE OF TWO STAGE CEMENT JOB. SEE CEMENT SECTION. NOTE: CEMENTER ALLOW CEMENT PUMP TO CAVlTATE DUE TO TOO LOW A CEMENT LEVEL IN THE MIXING BOWL AND HAVING THE SUCTION VALVES OPEN IN BOTH MIXING WATER TANKS AT THE SAME TIME. BOTTOM LINE-- NO PUMPING FOR APPROX 25 MINUTES WHICH ALLOWED CEMENT TO FALL THRU SPACER AND CONTAMINATE MUD. SHEAR ES CEMENTER OPEN AND CIRC 450 BBLS. PUMP 2ND STAGE CEMENT JOB -- SEE CEMENT SECTION. R/D CEMENTERS, PULL LANDING Jr., AND R/D CASERS. WASH DOWN FLOW LINE, N/D DIVERTER SYSTEM. FINISH N/D 20" DIVERTER SYSTEM & MU SPEED HEAD -- BAKER LOCK. N/U BOPE & MODIFY BELL NIPPLE. TEST BOPE 500/5000 PSIG. TEST ANNULAR PREVENTER 250/2500 PSIG. INSTALL WEAR RING & BLOW DOWN CHOKE MANIFOLD. REPLACE DRLG LINE TIE DOWN BOLTS ON DRAWWORKS. SLIP & CUT DRILL LINE. SERVICE TOP DRIVE. CHANGE DIODE ON DYNAMIC BRAKE. MU BHA & SURFACE TEST TURBINE. RIH W/HWDP TO 1178' & TEST MWD. RIH PU 5" "E" DP TO ES CEMENTER @ 1900'. DRILL ES CEMENTER (DV TOOL) W/2-3K AND 5K MAX ALLOWABLE. RIH PU 50 JTS "E" DP AND 8 STANDS OF "G" DP. RIH WHILE P/U 5" S-135 DP. CIRCULATE FOR CASING TEST. TEST 9-5/8" CASING 1500 PSIG Fl30 MINUTES -- OK. DRILL BAFFLE PLUG & FLOAT EQUIPMENT AND 10' OF NEW FORMATION. ClRC & COND MUD UNTIL MWin-MWout=8.8 PPg. CLOSE ANNULAR AND PERFORM FORMATION INTEGRITY TEST 13.5 PPG EMW. POOH 25 STANDS S-135 & STAND BACK ON RIGHT SIDE OF DERRICK. DRLG F/6720'-8534'. NOTE: INCLINATION IS BUILDING .4/100' MAKING IT NECESSARY TO RUN LESS WOB AND SLIDE TO CORRECT. DRLG F/8534'-9767'. DRLG F/9767'-10079'. SERVICE TOP DRIVE (PART 1) DRLG F/10079'-10174'. SERVICE TOP DRIVE (PART II). DRLG F/10174'-10791'. DRLG F/10791'-10885' (TOP OF CAP ROCK). CP'( OCO) Detailed Activity Report 8 P2 2B , 11.50 01:00 12:30 11318.0 CONTROL DRLG F/10885'-11350' O 80 FPH 8 1=2 2B 7.00 12:30 19:30 11830.0 8 P2 5 2.00 19:30 21:30 11630.0 8 P2 10 0.50 21:30 22:00 11630.0 8 P2 3B 2.00 22:00 00:00 11630.0 06/05/1993 8 T4 6F 3.00 00:00 03:00 11630.0 06/06/1993 8 T4 6F 2.00 03:00 05:00 11630.0 8 T4 19 7.00 05:00 12:00 11630.0 8 T4 45 4.50 12:00 16:30 11630.0 8 T4 19 4.50 16:30 21:00 11630.0 8 T4 45 3.00 21:00 00:00 11 630.0 8 T4 45 1.50 00:00 01:30 11630.0 8 T4 35G 2.00 01:30 03:30 11630.0 8 T4 35G 5.50 03:30 09:00 11630.0 8 T4 35G 1.00 09:00 10:00 11630.0 8 T4 35H 2.00 10:00 12:00 11630.0 8 T4 35H 1.00 12:00 13:00 11630.0 8 T4 5 3.00 13:00 16:00 11630.0 8 T4 6F 5.00 16:00 21:00 11630.0 8 T4 6C 3.00 21:00 00:00 11630.0 8 T4 6F 1.00 00:00 01:00 11630.0 8 T4 9 1.00 01:00 02:00 11 630.0 8 T4 45 1.00 02:00 03:00 11630.0 8 T4 6F 4.00 03:00 07:00 11630.0 8 T4 5 1.00 07:00 08:00 11 630.0 8 T4 20A 0.50 08:00 08:30 11630.0 8 T4 20D 5.50 08:30 14:00 11630.0 8 T4 20D 2.50 14:00 16:30 11630.0 06/07/1993 -- CAP ROCK TO THE BASE OF THE LK-3. DRLG RATHOLE F/11350'-11630'. PUMP 25 BBL LOW/50 BBL HIGH VIS SWEEP WHILE ClRC & COND HOLE. NOTE: THE LOW VIS SWEEP CONSISTED OF 25 BBL WATER W/ 4PPB DEXTRID & THE HIGH VIS WEEP CONSISTED OF 50 BBL 10.4 MUD W/4 PPB BARAZAN -- 150 VIS. DID NOT REALLY SEE ANY ADDmONAL CUTTINGS OVER SHAKER AT BOTTOMS UP! DROP MAGNETIC MULTI SHOT SURVEY. BEGIN BACKREAMING OUT OF HOLE. NOTE: BACKREAMED 40' + 2 STANDS WI NO PROBLEM; HOWEVER, PACKED-OFF AND PULLED TIGHT AS TOP STABILIZER PULLED INTO THE BASE OF THE LK-3 SAND. WORKED PIPE DOWN, ROTATED, AND BROUGHT PUMPS BACK UP SLOW TO REGAIN CIRCULATION. REGAINED ClRC AND WORKED PIPE FREE AT BASE OF LK-3 O 11035'. CONTINUE TO BACKREAM WHILE STICKING THE PIPE AND PACKING OFF LOSING CIRCULATION AT 11062' -- WORK PIPE DOWN, ROTATE, AND PUMP SLOWLY TO REGAIN CIRCULATION AND FREE PIPE. BACKREAM TO TOP OF MK-1 AND ATTEMPT TO PULL THE PIPE WHILE CIRCULATING BUT NOT PUMPING -- STUCK PIPE AND PACKED OFF LOSING CIRCULATION AT 10999'. WORKED PIPE DOWN, ROTATE, AND PUMP SLOWLY TO REESTABLISH CIRCULATION. CONTINUE TO BACKREAM TO 10915' -- PIPE PULLED TIGHT AND BEGAN TO PACK OFF. SLACKED OFF AND ATTEMPTED TO MAINTAIN ClRC -- PACKED OFF AND STUCK PIPE. WORKING STUCK PIPE W/NO RESULTS -- DID HAVE JAR ACTION. TWO ATTEMPTS TO RETRIEVE THE MAGNETIC MULTI SHOT TOOL W/THE RIG FAILED. WORKING STUCK PIPE WITH TRISTATE WHILE WAITING ON OTIS SLICKLINE UNIT. RIG UP OTIS & RIH TO RETRIEVE MULTISHOT TOOL NECESSARY TO PULL 400K ON PIPE TO REDUCE SLICKLINE DRAG. LATCH TOOL AND BEGIN POOH. POOH W/MULTISHOT TOOL ON SLICKLINE AND FUD OTIS. R/U APRS SWIVEL AND SIDE ENTRY SUB & SCHLUMBEGER W/L UNIT. RIH W/APRS STRAIN GAUGE AND FIND FREE POINT ~ 10606' IN FIRST JOINT OF HWDP ABOVE JARS. NOTE: NECESSARY TO PUMP IOBBL VOLUMES AT 5 BPM AT 4 DIFFERENT DEPTHS BELOW 9200' IN ORDER TO ADVANCE APRS STRAIN GUAGE DOWNHOLE. POOH W/APRS FREE POINT TOOL. ESTABLISH RADIO SILENCE ON L-PAD & AND R/U STRING SHOT -- RIH TO CONNECTION BETWEEN 1ST AND SECOND HWDP ABOVE JARS ~ 10606'. WORK 8 TURNS OF LEFT HAND TORQUE INTO DP -- 700 AMPS. STRING SHOT (~ 10606', BACK OFF FISH, POOH W/STRING SHOT & STAND BACK APRS SWIVEL AND SIDE-ENTRY SUB. PULL 2 STANDS DP (CONNECTIONS VERY TIGHT -- HARD TO BREAK.) ClRC & COND MUD WHILE DISPLACING OLD MUD SYSTEM WITH NEW IN EFFORT TO LOWER COLLOIDAL SOEDS -- MBT. ClRC TWO HOLE VOLUMES TOTAL POOH WHILE BREAKING TIGHT CONNECTIONS. M/U FISHING BHA + 9DC + 5 STANDS HWDP. TIH W/FISHING TOOLS & 10 STDS 5" DP. SLIP & CUT DRILL LINE. SERVICE TOP DRIVE. FINISH RIH W/FISHING BHA. CBU & DISPLACE 63 BBL DIESEL/ENVIRO-SPOT PILL TO JUST INSIDE END OF FISHING STRING. SCREWW INTO FISH AND SPOT 30 BBLS OF DIESEL/ENVIRO-SPOT PILL OUT END OF BIT -- NO RETURNS. WORKING STUCK PIPE -- FIRST DOWN WITH NO SUCCESS, THEN UP, WHILE PRESSURING UP AND PUMPING 10 BBLS OF DIESEL/ENVIROSPOT PILL IN THREE SEPARATE STAGES. FISH BEGAN TO MOVE UP HOLE W/550K ON WT INDICATOR. FISH CAME LOOSE, POOH W/550K TO 400K PU WEIGHT WHILE L/D 13 JTS OF DP -- ALSO ESTABLISHED CIRCULATION. CONOCO Detailed Activity Report 06/08/1993 06/09/1993 06/10/1993 06/11/1993 06/13/1993 06/14/1993 8 T4 45 4.00 16:30 20:30 11630.0 8 T4 6F 3.50 20:30 00:00 11 630.0 8 T4 28 1.0o 00:00 01:00 0.0 8 T4 20D 3.00 01:00 04:00 0.0 8 T4 20D 2.00 04:00 06:00 0.0 8 132 6C 2.00 06:00 08:00 0.0 8 A2 24 1.00 08:00 09:00 8 A2 15A 2.50 09:00 11:30 8 A2 24 0.50 11:30 12:00 8 L14 8A 3.50 12:00 15:30 8 T2 6F 5.00 15:30 20:30 8 T2 5 0.50 20:30 21:00 8 T2 6F 2.00 21:00 23:00 8 T2 3B 1.00 23:00 00:00 8 T2 3B 12.00 00:00 12:00 8 T2 6D 1.00 12:00 13:00 8 T2 3B 6.00 13:00 19:00 8 T2 5 1.50 19:00 20:30 8 T2 6D 3.50 20:30 00:00 8 T2 6D 1.50 00:00 01:30 8 T2 3B 1.50 01:30 03:00 8 T2 5 0.00 03:00 03:00 8 P4 6F 9.00 03:00 12:00 8 P4 15A 1.50 12:00 13:30 8 P4 28 1.50 13:30 15:00 8 P4 13A 9.00 15:00 00:00 8 P4 13A 8.00 00:00 08:00 8 P4 5 3.00 08:00 11:00 8 P4 12A 1.00 11:00 12:00 8 P4 12A 1.00 12:00 13:00 10 P6 28 2.00 13:00 15:00 10 P6 24 1.00 15:00 16:00 10 P6 15A 2.50 16:00 18:30 10 P14 45 1.50 18:30 20:00 10 P14 45 1.00 20:00 21:00 10 P6 6F 3.00 21:00 00:00 10 T3 29A 3.50 00:00 03:30 10 T3 26B 2.50 03:30 06:00 10 T3 29A 6.00 06:00 12:00 10 T3 6F 3.00 12:00 15:00 10 T3 12B 2.00 15:00 17:00 10 T3 5 3.00 17:00 20:00 10 T3 6F 2.00 20:00 22:00 10 P2 7 2.00 22:00 00:00 10 T3 6F 1.50 00:00 01:30 10 T3 6C 0.50 01:30 02:00 10 T3 6F 3.50 02:00 05:30 10 T3 2A 3.50 05:30 09:00 0.0 0.0 10870.0 11512.0 PERFORM ELECTRICAL REPAIRS TO TOP DRIVE WHICH RESULTED FROM JARRING ON FISH -- CABLES ON REPAIR LEADS WERE TO SHORT. DECISION MADE TO BREAK OUT TOP DRIVE CONNECTION WITH HYDRAULIC RAM & ROTARY TABLE, POOH, AND REPAIR LEADS ON TOP DRIVE DURING BOP TEST ON 8/8/93. FISH ONlll POOH W/FISH. RIG DOWN SCHLUMBERGER AND APS TOOLS POOH WITH FISH LAY DOWN FISHING TOOLS AND BHA REMOVE SOURCE TOOL F/LWD AND LAY DOWN TURBINE AND CLEAR FLOOR 0.0 RUN/PULL WEAR BUSHING/TEST PLUG 0.0 TEST BOP'S 0.0 RUN/PULL WEAR BUSHING/TEST PLUG 0.0 REPAIRS, ELECTRICAL REPAIR TOP DRIVE CONNECTION AND REPLACE BRAKE BLOCKS 0.0 PU BHA AND RIH TO SHOE. 0.0 CIRCULATE & CONDITION 0.0 RIH TO 10758' - STARTED TAKING WEIGHT. 0.0 REAM FROM 10758' TO 10853' WELL TRYING TO PACKOFF. FREE AFTER REAMING TWO TO THREE TIMES. 0.0 REAMED F/10,853' TO 11,478', RAISING MUD WT TO 10.6 PPG 0.0 SHORT TRIP 11,478' TO 10,722', PULLED TIGHT 3 STD COMING OUT, CIRC AND WORK UP 80' REST PULLED GOOD 0.0 REAMED F/11,478' TO 11,630',RAISED WT TO 10.8+ 0.0 CIRCULATE & CONDITION 0.0 SHORT TRIP TO SHOE, NOW RIH 0.0 SHORT TRIPPING 0.0 WASH 11,430 TO 11,490, STILL DRAGGING REAM OUT SECTION, OK, WASH TO 11,630' 0.0 CIRCULATE & CONDITION 0.0 POOH,LD DP, CONNECTION SUPER TIGHT, STD 25 STDS G IN DERRICI~ 15 STDS E AND HWDP, LD REST OF DP AND BHA 0.0 PULL WEAR RING, INSTALL TEST PLUG, CHANGE RAMS TO 7", TEST DOOR SEALS TO 2O00 PSI 0.0 RU CSG EQUIPMENT, RUN 3 JTS AND RU TAM PKR, HELD SAFETY MEETING 0.0 RUN CSG 0.0 FINISHED RNG 271 JTS 7" 26# L-80 CSG, SHOE O 11,620', FC O 11,527' 0.0 CIRCULATE 2000 STKS W/TAM PKR, RU CEMENTING HEAD AND CIRCULATE 2500 STKS, STARTED OUT W/POOR RETURNS AND SLOW PUMP RATE 2 BPM GOT GOOD RETURNS AT THE END W/5 BPM PUMP RATE, LOST 75 BBLS PUMP 50 BBLS SEPIOLITE SPACER 0.0 PUMP 40 BBLS WATER TEST LINES TO 3000 PSI, DROP Bo3'rOM PLUG 0.0 DISPLACE CEMENT W/10.2 PPG BRINE AT 8 BPM, BUMPED PLUG TO 1700 PSI, CHECK FLOATS 01~ LOST 50 BBLS W/PUMPING CEMENT AND DISPLACING 0.0 CLEAR FLOOR, LD LAND JT, CHANGE BAILS CLEAN PITS, FLUSH OUT MUD LINES , LD CEMENTING HEAD 0.0 SET PACKOFF AND TEST TO 5000 PSI 0.0 CHANGE RAMS TO 3.5", TEST RAMS AND 3.5" TIW AND DART VALVES TO 5000 PSI INSTALL WEAR BUSHING 0.0 CHANGE TOP DRIVE OVER TO 3.5" 0.0 CUT AND SLIP DRLG LINE 0.0 PU AND RIH W/BHA AND DP 0.0 WAITING ON PERF GUNS FOR SQUEEZE 0.0 RIH AND PERFORATE FROM 10990' TO 10992' WITH 9 SHOTS RD. 0.0 WAITING ON RETAINER AND PLUG CATCHER ESTABLISH CIRCULATION 9/5/8" X 7" ANNULUS 0.0 MAKE UP RETAINER AND TRIPIN HOLE TO 10870'- SET REATINER AND TEST W/500 PSi HOLD SAFETY MEETING 0.0 RU DOWELL AND TEST LINES TO 4000PSI - PUMP 20 BBLS OF WATER - 28 BBLS SLURRY- 2 BBLS OF WATER - DISPLACE WITH 71.5 BBLS OF BRINE SQUEEZED LAST 2.2 BBLS OF CMT W/750 ON DP AND 500 PSI ON ANNULUS STING OUT OF RETAINER. 0.0 REVERSE OUT DP 0.0 POOH 0.0 LUBRICATE RIG/ROUTINE MAINTENANCE CHANGE OUT SAVER SUB ON TOP DRIVE POOH W/CEMENT RETAINER STINGER PU BHA TRIP IN HOLE AND TAG RETAINER AT 10870' DRILL OUT RETAINER AND CEMENT FROM 10945' TO 10995' - RIH AND TAG PBTD AT 11512'. CONOCO Detailed Activity Report 10 T3 5 13.00 09:00 22:00 11512.0 REVERSE CIRCULATE AND FILTER BRINE PROBLEMS WITH CEMENT CONTAMINATION PLUGGING FILTERS. 10 T3 6F 2.00 22:00 00:00 11512.0 POOH/TURN OVER WELL TO COMPLETION AFE. i r I I r i i r i i i iii i i i CONOCO Detailed Activity Report 06/12/1993 10 P6 6F 5.50 00:00 05:30 10 P6 5 12.00 05:30 17:30 06/15/1993 06/16/1993 10 10 06/17/1993 06/18/1993 06/19/1993 10 P6 6F 3.50 17:30 21:00 10 P6 45 3.00 21:00 00:00 8 P4 45 0.50 00:00 00:30 8 P4 6F 1.50 00:30 02:00 10 P7 26B 11.50 02:00 13:30 10 P8 15E 1.00 13:30 14:30 10 P8 34 9.00 14:30 23:30 10 P8 34 0.00 23:30 23:30 10 P8 34 0.50 23:30 00:00 P8 34 3.50 00:00 03:30 P8 34 6.50 03:30 10:00 10 P15 15A 4.50 10:00 14:30 10 P14 14A 5.50 14:30 20:00 10 P15 15A 1.00 20:00 21:00 10 P15 14A 1.50 21:00 22:30 10 P6 24 0.50 22:30 23:00 10 P9 7 0.50 23:00 23:30 10 P9 7 0.50 23:30 00:00 10 P9 7 0.50 00:00 00:30 10 P9 6F 3.50 00:30 04:00 10 P9 5 4.00 04:00 08:00 10 P9 15B 0.50 08:00 08:30 10 P9 5 2.00 08:30 10:30 10 P9 5 1.50 10:30 12:00 10 P9 5 12.00 12:00 00:00 10 P6 5 1.00 00:00 01:00 10 P6 6F 6.00 01:00 07:00 10 P6 15A 1.00 07:00 08:00 10 P9 9 1.00 08:00 09:00 10 P9 35A 4.00 09:00 13:00 10 P9 28 2.00 13:00 15:00 10 P9 13A 9.00 15:00 00:00 10 P9 13A 10.50 00:00 10:30 10 P9 13A 3.50 10:30 14:00 10 P9 13A 1.00 14:00 15:00 0.0 PU 3 1/~' DP RIH TO 11,492' TAG PBTD 0.0 REVERSE ClRC, 25 BBLS HEC, 50 BBLS SAFE KLEEN, 25 BBLS HEC, FILTERED BRINE UNTIL IT REACHED 30 DTU, HAD A LOT OF PROBLEMS WITH THE DE FILTERS PLUGGING AND EVEN PLUGGED THE CARTRIDGE FILTERS 0.0 POOH W/3 1/2" DP, LD BHA 0.0 RU SCHLUMBERGER, RUN BOND LOG, GOOD BOND PBTD TO 11225, POOR BOND 11,225-11,215, GOOD BOND 11,215-11,190 POOR BOND 11,190-11,165, GOOD BOND 11,165-11,150, POSSIBLE SMALL AMOUNT OF CEMENT 11,150 TO 11,050, NO CEMENT ABOVE 11,050, TOP PERF AT 11,018', WILL SHOOT SQUEEZE PERFS AND 10,090' 0.0 SERVICE TOP DRIVE 0.0 POOH AND LD BHA 0.0 PERFORATE IN 5 RUNS 11,336-11,346' , 11,256-11,286', 11,197-11,227', 11,164-11,184', 11,087-11,097', 11,050-11,060' AND 11,016-11,036', FILL AFTER EACH RUN 5.2 , 4 , 3.8 , 3.5 AND 3.5 BBLS RESPECTIVELY 0.0 RIH TO 472' SET PKR, TEST BACKSIDE TO 1000 PSI, DROP BALL TEST TO 2500 AND BLOW BALL SEAT. 0.0 RU DOWELL, TEST LINES 7530#, PUMP 406 BBLS DATA FRAC AT 40 BPM, FLUSH TO PERFS W/406 BBLS WATER, ISIP 2627 PSI, MAX PRESS 3969#, AVG 3639#, RECALULATE PAD SIZE, PUMP 875 BBLS PAD, 149 BBLS 0 I PPG, 104 BBLS @ 2 PPG, 126 BBLS ~ 4 PPG, 151 BBLS @ 6 PPG, 193 BBLS @ 8 PPG, 193 BBLS @ 10 PPG, FLUSH W/403 BBLS 11 PPG BRINE, RATE 40 BPM AV PRESS 3800, W/100 BBLS FLUSH PUMPED PRESSURE 0.0 JUMPED FROM 3800 TO 5000#, W/235 BBLS GONE PRESSURE CLIMBED TO 5500 PSI RATE DROPPED TO 7 BPM, W/240 BBL PUMPED RATE 8 BPM PRESS 5987#, THEN PRESS DROPPED TO 4400# WHILE RATE INCREASED TO 20 BPM, FINISHED FLUSH AT 25 BPM AT 4300 PSI, AT END REDUCED RATE TO GRADUALLY TO 5 BPM BUT DIDN'r SCREEN OUT, ISIP 2147 PSI, 5 MIN 2083 PSI, FLUSH 403 BBLS 0.0 WAIT ON FRAC GELS TO BREAK, TOTAL LIQUID TO RECOVER 2121 BBLS, TOTAL 12/18 PROP 191,471# 0.0 WELL SI PRESSURE @ 0330 700 PSI 0.0 BLEED 2-5 BBLS EVERY 30 MIN TO I HR UNTIL WELL WAS DEAD. UNSEAT PKR POOH AND LD SAME 0.0 PULL WEAR BUSHING, INSTALL TEST PLUG, TEST BOP AND CHOKE MANIFOLD TO 500/5000, ANNULAR FAILED 0.0 ND FLOWLINE AND RISER, MU POTATOE MASHER AND BREAK HYDRIL TOP, CHANGE OUT BAG, INSTALL HYDRIL TOP, LD POTATOE MASHER 0.0 MU TEST JT AND TEST HYDRIL AND IBOP 0.0 NU RISER,FLOWLINES, AND HOLE FILL LINES 0.0 RUN WEAR BUSHING 0.0 CHANGE OUT BAILS ON TOP DRIVE 0.0 CHANGE OUT CRANE ASSEMBLY ON IBOP VALVE 0.0 SERVICE TOP DRIVE 0.0 RIH W/MULESHOE, AND SCRAPPERS TO BE AT TOP OF PERFS, TAG SAND AT 10,640' 0.0 RU AND REVERSE SAND F/10,640' TO 10,876' 0.0 TEST 9 5/8 X 7 ANNULUS BY INJECTING 5 BBLS AT 1200 PSI NO COMMUNICATION TO INSIDE OF 0' 0.0 REVERSE CIRC 10,876' TO 11,002' W/ FILTERED BRINE 0.0 CLEAN FILTER PRESS 0.0 REVERSE Cl RC SAND F/11,002 TO 11,122' LOST 20 BBLS EACH STAND, F/11,122 TO 11,492' LOST 80 BBLS EACH STD, TOTAL LOST 320 BBLS 0.0 CIRCULATE WELL CLEAN, WELL OUT OF BALANCE PUMP SMALL DRY JOB 0.0 POOH LD DP AND SCRAPPERS 0.0 CHANGE TOP PIPE RAMS TO 2 7/8" AND TEST RAMS AND DOOR SEALS 0.0 CUT DRLG LINE 0.0 RU AND RIH AND SET PKR AND SCREEN AT 10,971 0.0 RU TBG TOOLS AND ESP CABLE AND SHEAVE 0.0 PU MOTOR, PUMP AND ETC SERVICE SAME, RIH W/TBG AND ESP CABLE 0.0 RIH W/TBG AND ESP CABLE 0.0 PU PKR AND SSSV, MAKE ESP CABLE SPLICE 0.0 MU SSSV CONTROL LINE AND RIH CONOCO Detailed Activity Report 10 P9 13A 4.00 15:00 19:00 0.0 SPACE OUT HANGER FOR ESP CABLE, MU HANGER, MAKE CONTROL LINE CONNECTION IN HANGER, LAND HANGER, DISPLACE TBG W/6 BBLS DIESEL AND ANNULUS W/22 BBLS, SET PACKER, TEST BACKSIDE TO 500 PSI,TEST HANGER TO 5000# 10 P9 28 2.00 19:00 21:00 0.0 LD LANDING JT, CLEAR FLOOR OF TBG AND ESP RUNNING EQUIP. INSTALL BPV IN HANGER 10 P9 14A 3.00 21:00 00:00 0.0 ND MOUSEHOLE, FLOWLINE, CHANGE RAMS TO 5" ND BOP 06/20/1993 10 P9 14A 1.00 00:00 01:00 0.0 NU/ND BOP'S 10 P9 14C 5.00 01:00 06:00 0.0 REWORK CONTROL LINE IN TOP OF HANGER AND INSTALL NEW FITTING, NU TREE, REMOVE BPV, INSTALL 2 WAY CHECK, TEST TREE TO 5000 PSI, REMOVE 2 WAY CHECK AND INSTALL BPV, RELEASED RIG 0600 HRS ON 6/20/93 CONOCO Detailed Activity Report 0710511993 10 P9 45 5.50 00:00 05:30 0.0 FINISH UP ON L-12 WELL. PIB 1C 13.00 05:30 18:30 0.0 MIRU NABORS 22-E DRILLING RIG ON L-11 PlO 45 2.00 18:30 20:30 11492.0 1 11 11 LIO 29A 3.50 20:30 00:00 11492.0 WELL FOR ESP CABLE CHANGE. RU TO PUMP DOWN THE 2-7/8" TUBING & KILL WELL. HAUL 10.8 PPG BRINE F/A PAD TO RIG. MODIFY GUN LINES IN PITS WITH FLANGE TO HOOK UP FILTER POD. RIG WATER TANK BLEW A FRONT SEAL ON MAN HOLE COVER AND SPILLED 5 BBLS SOURCE WATER ON CFP PAD. MI FILTRATION DELIVERY TRUCK WAS DELAYED DELIVlERING FILTER POD & 10 MICRON CARTRIDGES. WAITED ON ANOTHER CLEAN TRUCK FROM PRUDHOE TO HAUL SOURCE WATER WHILE REPLACING SEAL ON RIG WATER TANI~ FILTER POD DELIVERED AND RU IN PITS. CONOCO Detailed Activity Report ::: "'"'"'"::' :::'":'~'"'"::'""~::;: : -: '-~:':'!':':'::":'" =================================================================================================~:~~~:::::::::~::~::::~:~:~~~:~~~: "':'"," ' .~:::::::: .... : '": '"" ::::::::.. ' '" ' il;::::::' * :::;:x::::::::: ·" J:::::: · · -'-'-'-'"-'-'"-'"-'-'- "-'-'"'".-:' :' :-::. ::::::::::::: ::::::: 5:::: :: 5:::::: :;:::: :;:::::::::::::: 5::¢ ::5 :: :: 555::5::::: :::::::::: :: :55::: ::::::::::::::::::::: :::::::::::::::::::: :::::::::::::: :::::::::::;:: :::::::::::: :. 5:. 5:. :. 7 :. > > :. 5> > > :. ;-> > :. ;-? :-> > > > > F-'-'::='-'.':.'.-.....-............o..................:, .:..=-:....,..-..,...:..:........:...-....=..-..:..................................,......................,......::... 07/06/1993 11 PO 5 1.00 00:00 01:00 0.0 RU AND KILL WELL BLEED OFF PRESSURES 11 P6 45 0.50 01:00 01:30 0.0 N D TREE 11 P6 45 4.50 01:30 06:00 0.0 NU BOP'S, CHANGE RAMS TO 2 7/8" 11 P6 15A 8.50 06:00 14:30 0.0 TEST ANNULAR TO 500/3500, TEST CHOKE MANIFOLD TO 500/5000, ONE VALVE FAILURE, TEST KILL LINE, TEST PIPE AND BLIND RAMS TO 500/5000, LEAKS ON DOOR FLANGES AND HAD TO TIGHTEN 3 DIFFERENT RING JOINTS, HAD LEAK ON LOCKDOWN PACKING GLANDS, AND HAD A SMALL LEAK ON THE TBG HANGER CONTROL LINE ALL THE TIME WE WERE TESTING, TESTED KELLY VALVES TO 500/5000 11 P6 45 6.00 14:30 20:30 0.0 BLEED GAS PRESSURE OFF BELOW TWO WAY CHECKAND PU 14 STDS OF 5" DP AND STAND IN DERRICi~ NOTE DO NOT CRIMP END OF CONTROL LINE, LEAVE OPEN OR CAP OFF W/ A SWAGELOK, CRIMPING ALLOWS PRESSURE TO BECOME TRAPPED IN THE CONTROL LINE FROM TESTING BOP'S AND WILL NOT BLEED OFF AND LET THE SSSV CLOSE 11 P6 45 3.50 20:30 00:00 0.0 UNSEAT PKR AND PUMP 25 BBL HEC PILL DOWN TBG, BLED OFF GAS AND PKR RESET, GO REVERSE AND UNSET PKR, CIRC CONV AND WENT GOOD FOR ABOUT 50 BBLS AND PKR RESET, CIRC REVERSE AND UNSET PKR, NOW ClRC CONV CONOCO Detailed Activity Report 07/07/1993 11 P6 5 2.50 00:00 02:30 0.0 CIRCULATE OUT 335 BBLS OF OIL, SHIPPED TO MPU, 11 P6 5 1.00 02:30 03:30 0.0 CLEAN CRUDE AND HEC FROM DITCHES AND SHAKERS 11 P6 5 1.50 03:30 05:00 0.0 MIX 50 BBLS BRINE AND TAKE ON 200 BBLS OF BRINE FROM VAC TRUCI~ HEC STRUNG OUT THROUGH 100 PLUS BBLS 11 P6 5 3.50 05:00 08:30 0.0 CIRCULATE UNTIL GAS AND OIL DIED OUT AND WELL CLEANED UP 11 PlO 6F 12.50 08:30 21:00 0.0 POOH W/EXISTING PKR, SSSV, GLM AND ESP EQUIPMENT, SEVERAL DAMAGED SPOTS IN CABLE MOST FROM POOH, FAILURE WAS IN PIGTAIL DIRECTLY UNDER THE SURFACE PENETRATOR 11 P9 45 3.00 21:00 00:00 0.0 CHANGE OUT PHD, TAKE OIL SAMPLES AND REFILL MOTOR AND SEALS W/OIL 11 P9 13A 12.00 00:00 12:00 0.0 RIH W/TBG AND ESP CABLE 11 P9 45 5.00 12:00 17:00 0.0 PU PKR, INSTALL PIGTAIL, MAKE CABLE SPLICE 11 P9 45 1.50 17:00 18:30 0.0 REPAIR ARMOUR, ABOVE PKR, DO TO DAMAGE FROM BANDING TO CLOSE TO COLLAR 11 P9 13A 1.00 18:30 19:30 0.0 MU SSSCV, CONTROL LINE, RIH, 11 P9 13A 1.50 19:30 21:00 0.0 MU HANGER, LDG JT, HOOKUP ESP CABLE, INSTALL CONTROL LINE, LAND HANGER 11 P9 13B 2.00 21:00 23:00 0.0 RUN IN LOCKDOWNS, TEST HANGER TO 5000, PUMP 18 BBLS DOWN ANNULUS, PUMP 3.5 BBLS DIESEL DOWN TBG, DROP BALL, SET PKR TO 2500, TEST BACKSIDE TO 500, LD LDG JT, SET BPV 11 P9 23 1.00 23:00 00:00 0.0 LD 5" DP FROM DERRICK 07/08/1993 CONOCO Detailed Activity Report 07/09/1993 11 PO 23 0.50 00:00 00:30 0.0 LD 5" DP FROM DERRICK 11 P9 14A 2.00 00:30 02:30 0.0 ND BOP'S 11 P9 14C 0.50 02:30 03:00 0.0 REPLACE FERULE ON CONTROL LINE @ HANGER PORT 11 P9 14C 2.00 03:00 05:00 0.0 NU TREE, HAD TO ALIGN HANGER, 1/4" OFF, RETEST PACKOFF, 11 P9 15C 1.00 05:00 06:00 0.0 PULL BPV INSTALL 2 WAY CHECK, TEST TREE TO 5000, PULL 2 WAY CHECK, INSTALL BPV RELEASED RIG AT 0600 HRS ON 7/9/1993 CONOCO, Inc. Pad L,11 Mitne Point Unit,North S[ope, Alaska SURVEY LZSTING Page 1 Your ref : PMSS <6765-11630,> Last revised : 13-Jun-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 S 0.00 W 0.00 0.00 121.00 0.24 77.26 121.00 0.06 N 0.25 E 0.20 0.17 153.00 0.36 54.79 153.00 0.13 N 0.40 E 0.50 0.30 186.00 0.36 53.76 186.00 0.25 N 0.57 E 0.03 0.49 218.00 0.41 49.29 218.00 0.38 N 0.74 E 0.19 0.69 311.00 0.50 49.83 310.99 0.87 N 1.30 E 0.09 1.38 401.00 0.74 36.96 400.99 1.58 N 1.95 E 0.31 2.32 491.00 1.77 29.23 490.97 3.26 N 2.98 E 1.16 4.28 581.00 3.32 25.54 580.88 6.83 N 4.78E 1.73 8.28 671.00 5.63 26.38 670.59 13.14 N 7.87 E 2.57 15.30 761.00 8.38 30.73 759.91 22.74 N 13.18 E 3.10 26.27 851.00 10.69 33.30 848.66 35.35 N 21.12 E 2.61 41.14 941.00 14.01 30.80 936.57 51.70 N 31.29 E 3.74 60.34 1031.00 16.56 30.64 1023.38 72.10 N 43.40 E 2.83 84.05 1121.00 20.07 29.55 1108.81 96.57 N 57.56 E 3.91 112.31 1217.00 22.25 28.38 1198.33 126.89 N 74.33 E 2.32 146.96 1311.00 25.34 30.88 1284.33 159.82 N 93.12 E 3.45 184.85 1407.00 29.55 27.69 1369.51 198.43 N 114.67 E 4.65 229.06 1503.00 33.33 32.19 1451.42 241.73 N 139.74 E 4.63 279.07 1598.00 34.12 32.22 1530.43 286.36 N 167.85 E 0.83 331.69 1692.00 36.80 32.57 1606.99 332.40 N 197.07 E 2.86 386.07 1788.00 39.06 31.81 1682.71 382.34 N 228.49 E 2.40 444.93 1883.00 40.67 30.03 1755.62 434.58 N 259.76 E 2.08 505.75 1978.00 44.14 29.44 1825.76 490.20 N 291.53 E 3.67 569.78 2072.00 47.39 29.52 1891.33 548.82 N 324.67 E 3.46 637.10 2168.00 51.55 29.41 1953.70 612.34 N 360.55 E 4.33 710.04 2262.00 54.56 29.64 2010.19 677.70 N 397.57 E 3.20 785.14 2357.00 56.82 31.12 2063.74 745.38 N 437.26 E 2.70 863.54 2452.00 55.71 30.62 2116.50 813.20 N 477.79 E 1.24 942.45 2547.00 55.81 30.84 2169.94 880.71 N 517.92 E 0.22 1020.91 2642.00 55.27 30.95 2223.70 947.92 N 558.14 E 0.58 1099.16 2738.00 55.90 31.95 2277.96 1015.48 N 599.46 E 1.08 1178.22 2833.00 56.18 31.05 2331.02 1082.67 N 640.63 E 0.84 1256.89 2928.00 55.55 29.12 2384.33 1150.70 N 680.05 E 1.81 1335.48 3023.00 55.09 28.77 2438.38 1219.06 N 717.87 E 0.57 1413.59 3120.00 54.22 29.31 2494.50 1288.23 N 756.28 E 1.00 1492.71 3215.00 53.49 30.03 2550.53 1354.89 N 794.25 E 0.98 1569.40 3309.00 52.71 29.39 2606.97 1420.18 N 831.51 E 1.00 1644.54 3403.00 52.54 30.32 2664.03 1484.96 N 868.69 E 0.80 1719.21 3496.00 53.20 28.80 2720.16 1549.46 N 905..27 E 1.49 1793.33 3591.00 53.09 28.98 2777.14 1616.01 N 941.99 E 0.20 1869.34 3686.00 53.47 30.82 2833.95 1682.02 N 979.95 E 1.60 1945.45 3781.00 53.58 29.87 2890.42 1747.94 N 1018.54 E 0.81 2021.78 3876.00 53.62 30.06 2946.80 1814.18 N 1056.74 E 0.16 2098.21 3971.00 53.45 30.42 3003.26 1880.18 N 1095.22 E 0.35 2174.56 4066.00 53.35 29.76 3059.91 1946.17 N 1133.46 E 0.57 2250.79 4161.00 55.21 29.79 3115.37 2013.11 N 1171.76 E 1.95 2327.88 4256.00 54.76 29.31 3169.88 2080.79 N 1210.13 E 0.63 2405.66 4351.00 53.68 28.65 3225.43 2148.21 N 1247.47 E 1.27 2482.72 4445.00 54.07 28.59 3280.85 2214.86 N 1283.84 E 0.42 2558.65 AIl data is in feet un[ess other.ise stated Coordinates from slot #11 and TVD from wellhead (51.00 Ft above mean sea Vertical section is from wellhead on azimuth 28.20 degrees. Declination is 0.00 degrees, Convergence is 0.34 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco CONOCO, Inc. Pad L,11 Mi[ne Point Unit,North Slope, Alaska SURVEY LISTIN6 Page 2 Your ref : PMSS <6765-11630'> Last revised : 13-Jun-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 4538.00 55.31 28.47 3334.60 2281.53 N 1320.08 E 1.34 2634.54 4633.00 55.63 29.04 3388.45 2350.15 N 1357.74 E 0.60 2712.80 4728.00 55.15 29.09 3442.41 2418.49 N 1395.73 E 0.51 2790.98 4823.00 54.74 28.97 3496.97 2486.48 N 1433.46 E 0.44 2868.73 4918.00 54.96 28.34 3551.67 2554.64 N 1470.71 E 0.58 2946.41 5012.00 55.47 27.08 3605.30 2622.99 N 1506.60 E 1.24 3023.60 5107.00 55.11 27.53 3659.39 2692.38 N 1542.42 E 0.54 3101.69 5202.00 54.70 27.52 3714.01 2761.32 N 1578.35 E 0.44 3179.41 5297.00 54.90 27.73 3768.78 2830.09 N 1614.34 E 0.28 3257.03 5391.00 55.86 27.75 3822.19 2898.55 N 1650.35 E 1.02 3334.38 5487.00 55.82 28.08 3876.10 2968.74 N 1687.54 E 0.29 5582.00 55.85 28.64 3929.45 3037.91 N 1724.87 E 0.49 5675.00 55.18 28.69 3982.10 3105.17 N 1761.65 E 0.73 5769.00 54.47 29.35 4036.25 3172.36 N 1798.92 E 0.94 5864.00 54.02 29.74 4091.76 3239.43 N 1836.94 E 0.58 5958.00 53.37 29.09 4147.42 3305.42 N 1874.14 E 0.89 6053.00 53.35 30.16 4204.11 3371.68 N 1911.82 E 0.90 6148.00 53.81 28.68 4260.52 3438.26 N 1949.37 E 1.34 6243.00 53.06 29.20 4317.11 3505.03 N 1986.29 E 0.90 6338.00 52.52 29.34 4374.56 3571.04 N 2023.28 E 0.58 3413.81 3492.42 3569.07 3645.90 3722.97 3798.71 3874.91 3951.33 4027.63 4103.28 6433.00 53.44 28.69 4431.76 3637.37 N 2060.07 E 1.11 6526.00 52.28 29.05 4487.91 3702.29 N 2095.87 E 1.29 6639.00 51.59 27.50 4557.58 3780.63 N 2138.01 E 1.24 6765.00 51.30 29.50 4636.11 3867.22 N 2185.02 E 1.26 6951.00 52.50 28.40 4750.88 3995.30 N 2255.86 E 0.80 7141.00 54.10 28.40 4864.43 4129.30 N 2328.31 E 0.84 7329.00 55.50 30.20 4972.80 4263.25 N 2403.50 E 1.08 7614.00 57.10 30.20 5130.92 4468.17 N 2522.77 E 0.56 7804.00 58.00 30.20 5232.87 4606.74 N 2603.42 E 0.47 7994.00 57.70 29.50 5333.98 4746.26 N 2683.49 E 0.35 4179.12 4253.25 4342.21 Tie-In fr/ EMS Survey 4440.74 4587.09 4739.42 4893.00 5129.95 5290.19 5450.98 8184.00 57.50 30.60 5435.79 4885.12 N 2763.82 E 0.50 8373.00 57.60 30.60 5537.20 5022.40 N 2845.00 E 0.05 8562.00 56.90 29.90 5639.44 5159.70 N 2925.08 E 0.48 8751.00 56.60 29.50 5743.07 5297.00 N 3003.39 E 0.24 8941.00 56.30 26.70 5848.09 5436.65 N 3077.97 E 1.24 5611.32 5770.67 5929.52 6087.52 6245.84 9131.00 55.50 24.90 5954.62 5578.29 N 3146.45 E 0.89 9224.00 56.30 24.90 6006.76 5648.14 N 3178.88 E 0.86 9417.00 54.50 24.20 6116.35 5792.63 N 3244.89 E 0.98 9603.00 55.50 23.90 6223.03 5931.76 N 3306.98 E 0.55 9885.00 54.80 23.20 6384.17 6143.91 N 3399.45 E 0.32 10071.00 56.40 22.80 6489.25 6285.17 N 3459.41 E 0.88 10264.00 53.10 21.10 6600.63 6431.31 N 3518.35 E 1.85 10454.00 54.20 21.40 6713.25 6573.93 N 3573.82 E 0.59 10638.00 52.60 24.20 6822.96 6710.10 N 3631.02 E 1.50 11016.00 53.20 20.70 7051.02 6988.67 N 3746.08 E 0.76 11206.00 52.10 17.50 7166.31 7131.35 N 3795.52 E 1.46 11394.00 52.50 17.90 7281.27 7273.06 N 3840.75 E 0.27 11531.00 53.10 17.90 7364.10 7376.90 N 3874.29 E 0.44 11630.00 53.50 17.90 7423.27 7452.44 N 3898.68 E 0.40 6403.03 6479.91 6638.44 6790.40 7021.06 7173.89 7330.54 7482.44 7629.47 7929.35 R['CEIVED 8078.46 8224.72 8332.08 8410.18 Projected Data - NO SURVEY Alaska O~l & Gas CoJ]s. G0m~isS~t.0.P Anchorage All data is in feet unless otherwise stated Coordinates from slot #11 and TVD from wellhead (51.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 28.20 degrees. Declination is 0.00 degrees, Convergence is 0.34 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco 6324/6116 Nielson Way Anchorage, AK 99518 907-563-3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-1358 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Atto: Larry Grant Well Reference Data: Well No: L-11 Field: Cowry: State: q5-13 Milne Point Unit North Slope Alaska Date: 07 September 1993 AP1 No: 50-029-22336 BH-INTEQ No: 1225 Enclosed is the following data as listed below: Measured Depth Logs Log Type Bluelines BD~G6{ 1 5" MI)~/MNP/~% 11l" Folded Sepias 1 1 1 Rolled Sepias Mylar Film 0 0 0 0 0 0 TOTALS: 4 4 0 0 Log Type Bluelines DPR/'~ ~ 1 -:"~-S~ BDE~ 6:,P, 1 ~" TOTALS' 4 True Vertical Depth Logs Folded Sepias Rolled Sepias Mylar 1 0 0 1 0 0 1 0 0 1 0 0 4 0 0 Film Upon receipt, please sign and retum to Baker Hughes INTEQ 6116 Nielson Way Anchorage, AK 99518 Atto: Tom Brockway Received By: Date: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 7, 1993 MR. TOM YEAGER CONOCO INC. 3201 C ST. STE 200 ANCHORAGE, ALASKA 99503-7603 RE: 93-0013 MILNE PT L-ii COMPLETION REPORT 93-0011 MILNE PT L-12 COMPLETION REPORT DEAR MR'. YEAGER, OUR FILES INDICATE THAT CONOCO INC. IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. I PREVIOUSLY PHONED YOU ABOUT THESE WELLS. JUNE AND JULY MONTHLY PRODUCTION REPORTS INDICATE THAT THESE WELLS ARE OIL PRODUCERS FOR YEAR 1993. WE HAVE NO REPORTS TO SHOW THE MENTION WELLS ARE COMPLETED. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME.. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 August 3, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU L-11; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for replacing the power cable to the electrical submersible pump in Milne Point Unit well L-11. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: JHA, TJY Chevron Occidental L-11 Well-File RECEJV , A U G - 6 199,~ Alaska 0il .& Gas Cons. ~. nch0rage : I STATE OF ALASKA ALASrv~ OIL AND GAS CONSERVATION coaal~o~ON US end 0 eratlon shutdown Re-enter sas ended well /'~/~/a 1. Type of Request: Abandon __ S p p ' P __ ~'/// Alter casing Repair well Plugging Time extention Stimulate ! ~/~ . Change approved program '---Pull tubing -- Variance Perforat"-~Othe-~--'X Replace ESI~ ' -- ---6. Datum elevation (DF or KB) 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 305 Anchorage, AK 99503 5. Type of Well: 4. Location of well at surface 2023' FNL, 147' FWL, Sec. 8, T13N, R10E, U.M., NSB Alaska At top of productive interval 314' FNL, 1063' FEL, Sec. 5, T13N, R10E, U.M., NSB Alaska At effective depth Development Exploratory Stratigraphic Service 51' MSL (30'AGL) Unit or Property name Milne Point Unit Well number L-11 9. Permit number 93-13 10. APl number 11. Reid/Pool Kuparuk River Field At total depth 149' FSL, 910' FEL, Sec. 32, T14N, R10E, U.M., NSB Alaska 12. Present well condition summary Total depth: measured trUe vertical 11,630 feet 7,423 feet Plugs (measured) PBTD @ 11,531'MD/7364'TVD (FC) Effective depth: measured feet true vertical feet Junk (measured) NONE Casing Length Size Structural Conductor 80' 13-3/8" Surface 6658' 9-5/8" Intermediate Production 11,590' 7" Uner Perforation Depth: measured 10,990'-10,992' 9 SHOTS Cemented Measured depth True vertical depth Sudace 110' 110' Sudace 6688' 4588 E.T.O.C. @ 9840'MD11,620; 7417' RECEIV[D true vertical 7,035'-7,036' A U G - 6 199;5 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd, 10,842 Alaska 0il & Gas Cons. ~un;missio~ Anchorage Packers and SSSV (type and measured depth) Arrow Hydrow liP Dual Packer, 595'; Otis FMX SCSSV, 579' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: 7-6-93 16. If proposal was~/erbally approved Oil X Gas ~ Suspended Blair Wondzell 7-2-93 ~ nf ~pprover Date approved Service 17. I h~'r~by certify that the~oregoing is true and correct to the best of my knowledge. ~ ' L'~ FOR COMMISSION USE O~LY Conditions of approval: Notif~Oommission so representative may witness Plug integrity_ BOP Test Location clearance j op ov., No. Mechanical Integrity Test Subsequent form required 10-~. Original S~gned By Approved by order of the Commission ~8Vld W, Johnston Commissioner Form 10-403 Rev 06/15/88 App¢~v¢~d Co~¥ Returned , SUBMIT IN TRIPLICATE Proposed ESP Pulling Procedure CAUTION: NOTES: Confirm power to the ESP is locked out and cable is disconnected. All locks shall be attached in accordance with Milne Point Unit lock-out procedures. Locks shall be in place from Operations, Systems, and Rig Supervisor. . 2. 3· . . . Safety/planning meetings shall be held prior to beginning any new procedure and prior to performing any potentially hazardous or complicated tasks. A special prejob safety/planning meeting shall be held prior to beginning this work. A complete safety and environmental protection audit shall be performed once the rig is set up before any additional work is done. A Centrilift rep shall be on the rig floor when the ESP is being pulled. Completion fluid at 9.5 ppg will overbalance formation by 200 psi (0.5 ppg). All brine entering the hole shall be filtered wi th cartridge filters. External DE filtration is _not required. Confirm the density of the completion fluid with a mud balance prior to pumping. · · 3~ 4~ · DRAFT Check and record phase-to-phase and phase-to-ground conductivities for all three ESP cable legs at the surface penetrator. Install a protector on the wellhead penetrator threads prior to moving in rig. MIRU Nabors 22E rig. RU EWS ESP cable spooling unit with one empty spool installed. ND tree, NU BOP's with rams for 2-7/8" 6.5#/ft EUE tubing. Pull BPV and install two-way check. Test rams to 500/5000 and annular to 300/3500. Record on AOGCC and Conoco daily reports. NOTES: . Inform AOGCC of the test at least 24 hours in advance so a witness can be present. Confirm SCSSV is closed and well is completely dead prior to setting two-way check. Pull two-way check from the WKM tubing hanger. MU landing joint with TIW valve into hanger. Close valve. RU to pump down 2-7/8" production tubing. Attempt to kill well by pumping 140 bbl 9.5 ppg completion brine down tubing and bullheading into formati on. NOTES: 1. o Calculated hole volume in tubing, then casing to 11492' PBTD : 89 bbl. The SCSSV will be closed but can be pumpe_d throuqh_ RECE1V ED AU G - 6 199 Alaska Oil & Gas Cons. CommissiOr' Anchorage . Close annular protector. Adjust bag pressure to allow pipe movement through the protector while maintaining a seal. . Back out tubing hanger hold-down pins. Pull straight PU to shear and release the Arrow Hydrow II dual packer at 594' CAUTION: A gas bubble is trapped below the packer. NOTES: 1. , . o Packer is a hanger-type tool. Entire string weight above and below must be picked up to release packer. Buoyant weight of tubing string above packer is ±4K in 8.2 ppg fluid. Buoyant weight of string and cable below packer is ±74K, assuming 9.5 ppg completion fluid. Calculated neutral weight should be ±78K not including blocks. Packer is pinned to release at 29K above neutral PU weight. Do not exceed 144,960# tensile strength of 2- 7/8" 6.5 #/ft L-80 EUE pipe. Notify Supv Systems Specialist at MPOC prior to releasing the hanger. A Conoco Systems representative shall be on location when the hanger and packer penetrators are pulled and when the ESP assembly is examined. . Bleed off gas from the 2-7/8" x 7" production casing annulus through the rig choke manifold. Take gas returns through the rig gas buster to help knock fluids out of the flow stream. Bleed gas to near 0 psig or until fluid returns are seen. NOTE: 1. Confirm gas blowdown is not causing oil or oil mist carryover. . RU to pump completion fluid down the 2-7/8" production tubing and take oil and dirty fluid returns up the 2-7/8" x 7" production casing annulus. 10. Mix a 20 bbl high viscosity pill (3.5 # HEC/bbl brine) and pump down 2- 7/8" tubing. NOTE: 1. Mix gel through the hopper/jet line to ensure maximum hydration. 11. Displace pill with 9.5 ppg brine. Circulate well until returns are clean and well is dead. Record volume of fluid pumped and volume of completion fluid trashed. NOTE: 1. Hole volume including tubing and annulus capacity to the circulating mandrel and casing capacity to 11492' PBTD : 413 bbl. 12. Open annular preventer. Slowly PU assembly until hanger is at rig floor. LD landing joint and hanger. DRAFT 3 13. 14. 15. DRAFT NOTES: 1. . Check and record ESP conductivity phase-to-phase and phase-to-ground for all three phases above and below the hanger penetrator. Unless testing shows the cable failure to be in the top section, this section of cable will be reused as-is. It was made with new cable. POOH and rack back tubing to SCSSV. Disconnect control line and rack back SCSSV assembly. CAUTION: Portable gas detectors shall be available on the rig floor and in the spooling shed. Detectors shall be tested for proper operation prior to pulling cable. Gas checks shall be made periodically on the rig floor. Checks shall be made in the spooling any time persons enter the unit and every 15 minutes when personnel are inside. NOTES: 1. . . . . . . Tubing must be POOH very slowly (<1 jt/min) until the packer is retrieved to minimize swabbing. Hole volume should be monitored very closely for signs of swabbing. Refill as necessary while pulling the packer. The entire length of the ESP cable shall be visually inspected as it comes out of the hole by the Centrilift rep. Flag visible bad spots in ESP cable and record approximate depths. Confirm sheave is +54" in diameter. Confirm safety cable is attached to sheave. Spool cable above the packer separately (or lay down without spooling). Bands shall be cut off, not twisted off as they come out of the hole. Record the number of bands suspected of being lost. The hole shall be covered at all times when bands are being removed. Continue to slowly POOH an additional 20' to the Arrow Hydrow II dual packer. LD packer assembly. NOTES: 1. · . Immediately send the packer assembly to Macco, Deadhorse to be redressed. This packer will be reused in this well. Check and record ESP conductivity phase-to-phase and phase-to-ground for all three phases at the packer penetrator. Contact Otis, Deadhorse and have them dry-rod the RHC Ball Catcher sub on a 2-7/8" X-Lock (from L-12) into the Otis X-nipple located below the packer assembly. The RHC sub shall be pinned for 4000 psi shear. POOH with ESP no faster than 1 jt/min (1800 ft/hr) to allow gas to begin migrating out of cable. It is extremely important to avoid sudden starts RECEIVED AU G - 6 199) Alaska Oil & Gas Cons. Corm',qissi°~' and stops (especially when settinq slips/spider) to minimize cable stretchinq and damaqe. NOTE: 1. All cable below the packer shall be spooled and marked "BAD" as at comes out of the hole. 16. PU ESP assembly but DO NOT LAY DOWN. ESP assembly must be inspected in vertical position while on rig floor by Centrilift and Conoco representatives. Fax a copy of the ESP pulling report to Anchorage with the morning report. NOTE: 1. Check and record ESP conductivity phase-to-phase and phase-to-ground for all three phases at the motor pothead. 17. Disconnect pump and intake as one unit. LD pump. NOTES: 1. 2. o o Do not rack back or stand up. Examine the area just above the pump discharge for solids. Collect samples of material if identification is not positive. Attempt to manually turn the pump shaft with a small wrench. Check for shaft play. Do not force movement. Examine intake and pump body for traces of erosion or scale deposition. Gather and label samples of any solids found. Examine entire ESP assembly for indications of warping, dents, or bent sections. 18. PU seal chamber section. Perform the following testing procedure on the original seal chamber section: a. Collect and label one pint samples of dielectric oil from the seal assembly while the unit is upright on the rig floor. Samples shall be taken from middle and bottom for singles, and bottom of both for tandem seals. Examine for color, traces of water, solid contaminants, or metal shavings. Record on daily report. Send samples to MPU Systems Tech for dielectric testing. b. Test seal bags in accordance with manufacturers recommended procedure. (To be forwarded Monday July 5th.) c. Drain entire unit and refill with new CL-5 dielectric fluid. 19. PU motor to floor. Disconnect the motor lead extension. NOTES: 1. . Collect and label one pint samples of dielectric oil from the bottom of the motor the unit is upright on the rig floor. Examine for color, traces of water, solid contaminants, or metal shavings. Record on daily report. Send samples to MPU Systems Tech for dielectric testing. After the dielectric test, titrate the motor oil sample DRAFT 5 20. 21. · for water concentration. Contact MPU Production Specialists for this test. The same sample can be used for dielectric and titration tests. Examine area around motor pothead housing for indications of vibration. The motor lead extension will not be reused in this well. Manually turn motor to confirm smoQth operation and check shaft play. PU to PHD pressure sensor. Test and replace with PHD sensor from stock. Forward any cable, pigtails, penetrators, or potheads which may have failed to the vendor inside a the shipping boxes. Label well, source and depth. DRAFT RECEIVED Alaska Oil & Gas Cons. Cornmiss~u~, Anchorage Proposed ESP Runninq Procedure NOTE: , A safety/planning meeting shall be held at the beginning of this phase of the project to insure good communication between all parties on location. PU and TIH with the original completion equipment and spaceout. All NEW penetrators, pigtails, and cable shall be run. The following equipment was run: a. Centrilift ESP assembly consisting of the following: 1) PHD Downhole pressure sensor 2) Motor - Series 562, Model KME, 100 HP, 2145 V, 27A 3) Flat Cable - Series 562, Model CL-81, 5 kV, 55~ Monel 4) Tandem Seal Section - Series 513, Model GSBT 5) Krytox Blocking Fluid - 1 gal in top labyrinth 6) Pump Intake - GPINT, 513 Series, TC Intake Bearing 8) Pump - GC-1200, Series 513, 146 stages (1:5 TC AR) with integral 2-7/8" 8rd discharge head b. Handling Pup - 4~ length 2-7/8" EUE 8rd 6.5 #/ft c. Production Tubing - 2 jts 2-7/8" EUE 8rd 6.5 #/ft d. Check Valve - 2-7/8" 8rd Centrilift Dart-type Check e. Production Tubing - 1 jt 2-7/8" EUE 8rd 6.5 #/ft f. Gas Lift Mandrel Assembly: i. Bottom Handling Pup - I0~ length 2-7/8" EUE 8rd 6.5 #/ft 2. Camco KBMG Gas Lift Mandrel - 2-7/8" orienting mandrel, 1" Pocket (empty) 3. Top Handling Pup - 10~ length 2-7/8" EUE 8rd 6.5 #/ft 4. Top Handling Pup - 4~ length 2-7/8" EUE 8rd 6.5 #/ft g. Production Tubing - 2-7/8" EUE 8rd 6.5 #/ft to place Otis FMX SCSSV at _+578~ h. Gas Lift Mandrel Assembly: 1. Bottom Handling Pup - 10~ length 2-7/8" EUE 8rd 6.5 #/ft 2. Camco KBMG Gas Lift Mandrel - 2-7/8" orienting mandrel, 1" Pocket (1" dummy valve installed) 3. Top Handling Pup - 10~ length 2-7/8" EUE 8rd 6.5 #/ft 4. Top Handling Pup - 4~ length 2-7/8" EUE 8rd 6.5 #/ft i. Production Tubing - 1 jt 2-7/8" EUE 8rd 6.5 #/ft j. Otis X Nipple - 2-7/8" 8rd EUE Box x Pin preloaded with X lock mandrel with 1.25" RH ball catcher sub pinned to shear at 4000 psiq k. Arrow Hydrow IIP Packer Assembly: 1. Bottom Pup Jt - 6~ length 2-7/8" EUE 8rd 6.5#/ft 2. Arrow Hydrow IIP Dual Packer assembly for 7" 26#/ft csg 3. Pup Jt - 6~ length 2-7/8" EUE 8rd 6.5#/ft 1. Otis FMX SCSSV Assembly: 1. Bottom Pup Jt - 4~ length 2-7/8" EUE 8rd 6.5#/ft 2. 2-7/8" Otis FMX TRSV SCSSV to set near 579~ 3. Otis Control Line - 1/4" 316 SS to SCSSV/surface 4. Top Pup Jt - 6~ length 2-7/8" EUE 8rd 6.5#/ft m. Production Tubing - +/-510~ 2-7/8" 6.5#/ft 8rd L-80 EUE n. WKM tubing hanger with ESP penetrator, 2-7/8" 8rd pin down DRAFT 7 RIG NOTES DRAFT y. Landing joint · . . . . · . 10. 11. 12. 13. 14. 15. 16. 17. 18. Strap and record the dimensions of each piece of equipment while TIH. Recommended torque values for L-80 tubing are as follows: 2-7/8" 6.5#/ft EUE 8rd Minimum = 1690 ft-lb Optimum: 2250 ft-lb Maximum = 2810 ft-lb Rabbit all tubing. Dope only pin ends with a minimum amount of Conoco Himite or equivalent API Modified tubing dope. Dope shall be applied with a 1" or smaller paint brush. Wipe off all excess dope. Before installing the SCSSV, connect a hydraulic pump and cycle several times to verify smooth operation and confirm the operating pressures are within acceptable limits. Maintain hydraulic pressure on control line at all times to confirm SCSSV is open and to minimize washing past packer elements. Do not splice control line if it is damaged while TIH. POOH and replace entire line. Confirm sheave is _+54" in diameter. Confirm safety cable is attached to sheave. The sheave shall be lowered to 15'-20' above rig floor until flat-round splice is secured to tubing to minimize stress on the splice. Normal running height shall not exceed 40' above floor. Do not handle cable spool with forks or slings in direct contact with the cable. Exercise caution when handling seal section to minimize bending. Use at least two lift points when moving horizontally. A flatbed trailer shall be used to transport the seal section on the lease if not in a conex. All ESP AND CABLE movement shall be witnessed and approved by ESP Service company rep. Bring cable, motor oil and pump equipment into a heated location at least 48 hours prior to runninq. Do not allow any cable or pigtails to stick out of spooling shed until run to the rig floor· Confirm block is locked. Tubing must not be allowed to turn while making connections or while TIH with the ESP connected. Back up all connections while TIH. Test hydraulic bander on a junk piece of cable prior to use on this well. Adjust and retest as necessary to ensure proper band tightness. The hole shall be covered at all times when bands are being installed. Install a drillpipe wiper rubber for 5" pipe once the 2-7/8" tubing is run. TIH with ESP no faster than 1 jt/min (1800 ft/hr). Exercise extreme caution when TIH to avoid sudden starts and stops which may damage cable (especially when setting slips/spider). Operations shall be immediately shut down and the cable inspected any time a severe pull is noted. Exercise caution to insure slips will not be set on ESP cable RECEIVED Alaska Oil & 6as Gons. Gommismu,~ '~,nnhnmn~. 19. 20. 21. 22. 23. or SCSSV control line. Assign one man on the rig floor to be responsible. DO NOT allow cable to drag in dirt or gravel or across rough edges while TIH. Fill out new draft completion sketch. Reference all depths back to the original 52' KDB. Fax to Anchorage office with final daily report. Paint shall be removed from all equipment before TIH. Visually confirm bottom gas lift mandrel does NOT have a valve in place by inspecting entry ports. Visually confirm top gas lift mandrel DOES have a dummy valve in place by inspecting entry ports. The valve should be visible. ESP NOTES o , o . 5~ o , e , 10. 11. 12. Notify Supv Systems Specialist at MPOC prior to picking up ESP equipment. A Conoco Systems representative shall be on location when the ESP is assembled, when rotation is checked, and when hanger and packer penetrations are made. Centrilift rep shall be on the rig floor at all times when ESP cable or equipment is TIH. All equipment and cable shall be visually inspected and approved by the Centrilift rep prior to TIH. Unless otherwise specified, manufacturers recommended procedures shall be followed for all operations. Exceptions shall require notification from the manufacturer. Compare serial numbers/data for equipment on location with shipping manifest and design quote. Do not run any equipment which does not match both. Confirm a copy of the correct pump curve accompanies the equipment. The motor lead pothead shall be pressure tested with low pressure air or nitrogen prior to running in hole. This may be done off location. A factory test alone is not acceptable. Confirm test results prior to TIH. Take a sample of dielectric oil from the bottom of the can to be used to fill the motor and seal sections. Confirm oil is Centrilift CL-5 for Centrilift motor. A new can shall be used for each job. Send sample to Systems Specialist at MPOC for dielectric testing. Confirm with both Systems Specialist and Centril ift Rep that the voltage breakdown rating is acceptable prior to fillinq the ESP. Reclose can tightly. The top labyrinth stage of the upper seal section shall be filled with Krytox lubricating blocking fluid. Paint "Krytox" on this stage. New O-rings shall be installed on all penetrators and ESP stages. Motor phase resistance shall be checked and compared versus predicted resistance prior to picking up to rig floor. Confirm pressure sensor is operative prior to picking up to rig fl oor. Check height of motor shaft above flange face according to Centrilift guidelines. Measure shaft extension for upper seal unit. Confirm extension DRAFT 9 DRAFT is within manufacturers acceptable tolerance. 13. Run flat cable guards vertically in line from the pothead to above the top of the pump. F1 at cable shall be run on the hump side of pumps with an offset discharge. 14. Do not allow short bends in the flat cable, especially near the pothead. Replace flat cable that gets damaged. 15. Pothead/Motor Lead Extension Handling: a. Do not bend the motor lead near the base of the pothead. b. Never bend the motor lead along its major axis. This causes relative movement of the conductors. c. Never allow the pothead pins to be pushed into the pothead. d. Never pull directly on a pothead, especially when unreeling or running over a sheave. Pull on cable at least 1' away. e. Do not apply tension to the motor lead during installation. Have it and the cable above it completely banded prior to applying any cable tension. f. Do not raise the sheave more than 10' above the ground before all bands have been applied. g. Band above the pothead ~before banding near the pothead. h. If any of the above QC measures are violated, replace the motor lead extension with a new, tested one. · 16. Torque r~Srn ~o,,punen~ - - *~ together wi th a torque wrench in accordance with manufacturers specifications. 17. Check phase orientation of the power cable with a Conoco motor rotation meter once the flat-round splice has been made by manually rotating pump at rig floor. (Check prior to making up pump if the upper pump shaft is not splined.) A meter supplied and approved by the Conoco Systems Group shall be used. Centrilift pumps rotate clockwise. 18. Confirm seal-motor coupling is installed with "TOP" mark on top, if applicable. 19. Attach two 1-1/4" Gassco Super-Band cable bands per joint, one 2-4' above the collar and one 15' above that. The cable shall be double banded above and below each splice. Do not overtighten. Pre-formed bands shall be used at all times except across fl at cable. 20. Bands shall be attached with a hydraulic bander. Band stretcher shall be operated at the manufacturers recommended pressure of +40 psig. The pneumatic sealer shall be operated at the manufacturers recommended pressure of +90 psig. Check pressures every hour during banding operations. 21. Cable twisting to take up slack shall be minimized. All splices shall be spaced out to minimize excess cable. 22. Penetrator connections shall be made with a properly sized spanner wrench (if possible) or channel-locks. Pipe wrenches shall not be used at any time for any cable connections. 23. Check and record ESP conductivity phase-to-phase and phase-to- ground for all three phases at the motor and at each RECEIVED AU G - 6 1995 A_ las~a.Oil & Gas Cons. 24. 25. penetrator. Electrical continuity checks shall be made at least every 2000~ while TIH. Do not "meg" cable if a pressure sensor is attached. The following checks shall be witnessed on location by a Conoco representative: a. Free rotation of all components. b. Proper oil filling of motor and seal sections. c. Tightness of all fill, vent, construction, and drain plugs. Send one copy of the Centrilift installation report in with the Daily Workover Report and the original to the well file at MPOC. , Land hanger in tubing head. Pressure test SCSSV control line to 5000 psig for 10 minutes. Lock down and test hanger to 5000 psig for 10 minutes. , RU to pump down 2-7/8" x 7" annulus and take returns up production tubing. Pump 18 bbl diesel down annulus. RU to bullhead down 2-7/8" tubing. Bullhead 3.5 bbl down tubing. NOTE: 1. The diesel will provide ±600' of freeze protection in the tubing and annulus. 4· Drop an Otis 1.00" OD ball and allow to fall to Otis RH ball catcher sub in X-nipple below packer. · Pressure up on the tubing to 1000 psig to begin setting the packer. Continue setting by pressuring up to 3000 psig. Hold final pressure for 10 minutes. Bleed pressure to zero. NOTE: 1. Otis RH ball catcher sub is pinned to shear at 4000 psig. It is not necessary to shear ball seat before moving off.- o Bleed pressure off control line to close SCSSV. Pressure up on 2-7/8" x 7" annulus to 500 psig and hold for 10 minutes to test packer. Bleed pressure to zero. 7. Install BPV in tubing hanger. Close SCSSV. ND BOP~s and NU tree. Pull BPV. . Install two-way check. Pressure test tree to 5000 psig. Pull two-way check. · 10. Make a final check and record ESP conductivity phase-to-phase and phase- to-ground for all three phases at the hanger penetrator. Confirm balanced conductivity. Install BPV. Remove fusible cap from SSV. RD and move rig off location. 11. Notify AOGCC of the following: DRAFT a. Completion of project (AOGCC Eorm 10-404). 11 UUNUUU INU,--NABORS RI0 22E i3-5/8" 58988 BoP cjyS'I-EM Flit 'f Threaded L I ne Flow Line Annu~ Pr~entor msm RBm Ram Tubing Spool w/ 2"-500044 Side OtJtlet~ Casing Spool w/ 3"-5000~t Side Outlets 9-5/8" St3.r,t~ece. Ca~ing 13-3/8" Conductor Casing Choke Lt_ne~ 3" 51~888 Manua[ Oafe Vatve · & 3" HOR YALVE Ktt. t Lt. ne~ Two 3" 5888~: Hanuat Gate Vatves t, BOP' STACK SIZE RATING MEETS AP] RP53 & SPEC 6A FOR 2, BO?E TO BE OPERATED EACH TRI? AND TESTED WEEKLh', 3, BOP HYDRAULIO CONTROL SYSTEM TO INCLUDE (5) STATION MANIFOLD. LOCATED REMOTE WITH ~68 OALLON ACCUIdULAT'OR, UN]T, & AUXILIARY ENEROY SOURCE FOR SYSTEM ACT]VAT:iON, 4, HiNiHUFI ONE SET BL~ND RAHS & TWO SETS APPROPRIATE PiPE 5, CHOKE & KILL I';1AN]F:OLDS SHOWN SEPARATELY 'FO HEET CLASS 518 REOU]REHENTS, CLASS 5M CONTROL RESERVOIR RAHS, R? 53 , EMOR NDUM TO: David Johnst,~ Chairman STATE OF ,4z-,A ;K,4 OIL AND GAS CONSER I,'. ION COMMISSION DA TE: July 6, 1993 FILE NO: ATOIGFAA. DOC THRU: Blair Wondzell P.I. Supervisor FROM: Bobby D. Foste'r' ,~'~ Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: B.O.P. Test-Nabors 22-E Conoco - MPU - L-11 P.T.D. 93 - 13 Kuparuk River Field Tuesday July 6, 1993 I traveled this date to Conoco's L - 11 and witnessed the B.O.P. test on rig -E. As the attached B.O.P. test report shows there were 4 failures. Three of the failures were rep~red before I depared the location. The fourth failure, a valve in the choke manifold, is to be repaired and a A. O. G. C.C. inspector notified. SUMMARY: B.O.P. test on Nabors 22-E - test time 8 hours -4 failures. ATTACHMENTS: ATOIGFAA.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Drlg. Rig No. Operator: Conoco Well Name: L- 11 Casing Size: 7" Set (~ ~¢~¢ Test: Initial Weekly X Other DATE: 7/6/93 22-E PTD# g3- 13 Rig Ph.# 659-6452 Rep.: Dave Mountjoy Rig Rep.: Lenord Schiller Location: Sec. 8 T. 13 R. 13 Meridian U MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: X Well Sign X Upper Kelly/IBOP Housekeeping: X (Gen) Drl. Rig X Lower Kelly/IBOP Reserve Pit N~. Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Te~ Quan. Pressure P/F 1 30013500 P I 30013500 P N ia I 30013500 P 1 30013500 P 2 30013500 P 1 30013500 P N ia MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Gas Detectors X X Test Quan. Pressure P/F 1 300 13500 P 1 30013500 P I 300i3500 P I 300i3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 17 Test Pressure P/F 001350 5000 P 42 30015000 P 2 ACCUMULATOR SYSTEM: System Pressure Pressure After Closure -' 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 1 ~ 2200 3 ~ 2350 3,100 J P 1,900 P minutes 25 sec. minutes 20 sec. X Remote: X Psig. Number of Failures: 4 ,Test Time: ~ Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within 3 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: Failures · 2 flanges leaked in the choke line; packing gland on the tubing hanger Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c -Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: ATOIGFAA.XLS Bobby D Foster Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 June 30, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 C[Ora ~..I RE: MPU L-11; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for performing a remedial cement squeeze on Milne Point Unit well L-11. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: JLA, TJY Chevron Occidental L-11 Well File RECEIVED J U L - 6 Alaska 0il & 6as Cons. 60mmissi0~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS . 1. Type of Request: Abandon Suspend __ Operation shutdown Re-enter suspended well __ v/~f/ Alter casing Repair well __ Plugging __ Time extention ~ Stimulate ~ Change approved program Pull tubing__ Variance__ Perforate ,,. Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ Location of well at surface 2023' FNL, 147' FWL, Sec. 8, T13N, R10E, U.M., NSB AK At top of productive interval 314' FNL, 1063' FEL, Sec. 5, T13N, R10E, U.M., NSB AK At effective depth At total depth 149' FSL, 910' FEL, Sec. 32, T14N, R10E, U.M., NSB AK 6. Datum elevation (DF or KB) 51'MSL (30' AGL) 7. Unit or Property name Milne Point Unit 8. Well number L-11 9. Permit number 93-13 10. APl number 50-029-22336 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,630 feet 7,423 feet Casing Length Structural Conductor 80' Surface 6658' Intermediate Production 11,590' Liner Perforation Depth: measured 10,990' - 10,992' true vertical 7,035' - 7,036' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet feet Size 13-3/8" 9-5/8" 7" Plugs (measured) Junk (measured) Cemented PBTD @ 11,531' MD/7364' TVD (FC) NONE Measured depth True vertical depth Sudace 110' 110' Sudace 6688' 4588 E.T.O.C. @ 9840'MD 9 SHOTS 11,620' 7417' RECEIVED J U L - 6 1993 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program X BOP sketch X 14. Estimated date for commencing operation 6/13/93 16. If proposal was verbally approved Mike Minder Name of approver 6/13/93 Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ _ ~, Title J ,//~/ "' ' ' "~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ~ O~' Original Signed By Approved by order of the Commission David W, johnston Drilling Engineer Date ~/~/?~ JApproval No. v.,w '~,~' c,~-.~.~ ,~pproved Copy Returned Commissioner Date '~/"~ /~ '~ SUBMIT I~ TRIPLICATE Form 10-403 Rev 06/15/88 L-11: BRIEF DESCRIPTION OF ACTIVITY The Nabors 22E rig drilled the MPU L-11 well to T.D. at 11,630' MD. Production casing (7" 26 #/ft, L-80, BTRC) was set and cemented at 11,620' MD. Due to partial returns while cementing the production casing, a Cement Bond Log (CBL) was run to verify top of cement. The CBL indicated an estimated top of cement (ETOC) at 11,050' MD. The toP hydrocarbon zone in the well is located at 11,016' MD/7051' TVD and labeled as the "Laminated Zone". In order to satisfy 20 AAC 25.030 d.4.B. (reference to 3.C.) a remedial cement squeeze procedure was developed and relayed by Jeff Allison of Conoco and verbally approved by Mike Minder on 06/13/93. Based on the CBL, the production casing was perforated from 10,990'-10,992' with 9 shots. An EZSV was set at 10,870' MD and the packer was tested to 500 psig. Circulation was established up the 7" X 8-1/2" open hole annulus. Approximately 26 bbls of class "G" with additives was circulated through the perforations to place TOC at ±9840' MD (±1176' above top production interval) in the 7" casing by 8-1/2" open hole annulus. The last 2 barrels of cement were placed using the hesitation squeeze method. The EZSV and cement was drilled out and the casing string and squeezed perforations were tested to 1875 psi for 30 minutes to satisfy 20 AAC 030 g.1. RECEIVED d U L - 6 199,1 Alaska Oil & (;as Cons. Commission Anchorage SAFETY: · · · NOTE: · · RECEIVED L-11 REMEDIAL SQUEEZE CEMENT PROCEDURE Alas~ Anchorage Conduct pre-job safety meetings prior to each phase of the remedial squeeze operation to insure techniques are sound and equipment is in safe working order· This operation will expose personnel to explosives, high pressure, tripping drill pipe, and various operations/chemicals associated with cementing· R/U Schlumberger to perforate a two (2) foot interval with 4 SPF from 10,990'-10992' MD. This 2' interval is located above any known cement from the CBL (ETOC at 11,050' MD). Perforate and POOH. R/D Schlumberger. M/U Halliburton "EZSV" cementer for 7", 26# casing and TIH to 10,870' MD (120' above perfs). Test packer to 500 psi. Sting into EZSV and open 7" casing annulus valve and verify returns or establish injection rates at 1/2, 1, 2, 3, and 5 BPM into perfs. Unsting from the EZSV. R/U Dowell and test lines to 4000 psi. Mix and pump the cement slurry described below. Maximum differential pressure while the cement is in the drill pipe is estimated at '1200 psi. To keep the cement from running away, back pressure should be held on the annulus with a closed annular preventor. The pressure schedule should go from 0.0 to 1200 psi (or greater for safety factor) over the volume of the cement (28 bbls). This pressure should be held until stung into the EZSV. Mix and pump the following cement Dowell slurry: Slurry: Class "G" + 0.4% D156 (FLA) + 0.4% D65 (Dispersant) + 0.05 GPS D47 (Antifoam) Volume: 28 bbls (±137 sx) Weight: 15.8 PPG Fluid Loss: 90-100 cc's Compressive: Test being conducted at present - contact D/S on slope for results NOTE: Thickening time at ±3 hours. They can mix the additives in the mix water tanks If circulation is possible, pump cement and displace as usual. Go to Step 8. Displace the cement with brine while holding back pressure until cement is 5 bbls from EZSV. Reduce rate to 1-2 BPM and sting into the EZSV and begin squeezing fluid into the perfs. Bleed pressure off annulus and monitor annulus pressure during squeeze job. Squeeze ±25 bbls into perfs at sufficient rate then S/D and hold pressure on squeeze. 6. After 15 minutes squeeze 2 bbls into perfs at 1/4 to 1/2 BPM · · · 10. NOTE: monitoring injection pressure and comparing to previously established injection rates and pressures. S/D for 15 minutes and monitor pressure. Attempt to bleed off pressure while flowing back in the Dowell unit. Allow a maximum of 3 bbls flow back while bleeding pressure off. If 3 bbls is bled back before complete bleed- off, inject the 3 bbls back into the perfs at minimum rate and hold pressure for ±4 hours. Bleed-off pressure, unsting from EZSV and reverse circulate 2 drill pipe volumes to clean out cement. POOH and L/D stinger. M/U 6-1/8" bit and DC's and TIH to EZSV at 10,870' MD. Drill EZSV and cement. CBU. Pressure test perfs to 1850 psi. If test, POOH. M/U 6-1/8" bit, tandem 7" casing scrapers and DC's and TIH to PBTD. Circulate and condition brine. POOH. Wait 8 hours before drilling EZSV. Wait at least 12 hours before drilling cement. Check integrity of cement by S/O weight (6-10,000# is usually good cement). Displacement volumes to be verified on location. REC E[VED d U L - 6 199 Alaska 0ii & 6as Cons, Anchorage Activity Summary: L-11 Remedial Cement Job JUNE 12, 1993: PU 3-1~2" DP & RIH TO 11,492'- TAG UP. REVERSE CIRC, 25 BBL HEC, 50 BBLS SAFE KLEEN, 25 BBLS HEC, FILTERED BRINE UNTIL IT REACHED 30 NTU, HAD ALOT OF PROBLEMS WITH THE DE SILTERS PLUGGING AND EVEN PLUGGED THE CARTRIDGE FILTERS. POOH W~ 3-1~2" DP, LD BHA. RU SCHLUMBERGER, RUN BOND LOG, GOOD BOND FROM PBTD TO 11225, POOR BOND 11,225-11,215, GOOD BOND 11,215-11,190. POOR BOND 11,190-11,165, GOOD BOND 11,165-11,150, POSSIBLE SMALLAMOUNT OF CEMENT 11,150 TO 11,050, NO CEMENTABOVE 11,050, TOP PERF AT 11,018'. WILL SHOOT SQUEEZE PERFS AT 10,990'. JUNE 13, 1993: WAIT ON PERF GUNS FOR SQUEEZE. RU AND RIH. PERF FROM 10,990-92 W~9 SHOTS, RD. WAIT ON RETAINER AND PLUG CATCHER, ESTABLISH CIRC TO SURFACE ON 9-5~8'~7" ANNULUS. MU RETAINER AND PLUG CATCHER, RIH TO 10870', SET RETAINER, TESTED TO 500#. HELD SAFETY MEETING. RU DOWELL, TEST LINES TO 4000#, PUMP 20 BBLS WATER, 28 BBLS SLURRY, 2 BBLS WATER, DISPLACE W~71.5 BBLS BRINE, SQUEEZED LAST 2.2 BBLS, 500# ON ANNULUS AT SURFACE, 750# ON DP AT SURFACE, FORMATION STARTING TO TAKE FLUID, S/I AND STUNG OUT OF RETAINER. FLUSH MUD OUT OF CHOKE LINES, GAS BUSTER AND TROUGHS, REVERSE OUT DP. POOH. LUBE TOP DRIVE AND CHANGE OUT SAVER SUB ON TOP DRIVE. JUNE 14, 1993: POOH W/ CEMENT RETAINER STINGER. PU BHA. TRIP IN HOLE, TAG RETAINER AT 10,870'. DRILL RETAINER. DRILL CEMENT Fl 10,945'-10,995', RIH TAG PBTD 11,512.' REVERSE ClRC AND FILTER BRINE, TEST CSG TO 1875# BLED OFF 170# IN 30 MIN. PRESS KEPT PLUGGING OFF FROM THE CEMENT IN THE BRINE, RAN THRU CENTRIFUGE AND THEN FILTERS, FINAL NTU 45 ON RETURNS. POOH. RECEIVED J U L - 6 199; Alaska Oil & Gas Cons. OommlssJo~ Anchorage UUNUL;U _INC,--NADOES I '_IF..j 22E 13-5/8" 58888 BOP SYS'I Fill Line Flow Line · Annular Preventor API lt' SM Ram RBm Threaded Comeoft~n Ram Choke Ltne~ 3" 51aala~ Manual Oafe Vat,/e & 3" HOR VALVE Ktt[ Ltne~ Two 3" Valves Tubing Spool w/ 2"-5000~t Side Outlets Cas.trig Spool w/ 3"-5000~t Side Outlets 9-5/8" So,PFaoe. C~tng 13-3/8" Conductor Casing BOP' STACK SIZE RAT:lNG MEETS AP] RP53 & SPEO 6A FOR CLASS 5H BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKL'f, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL HANIFOLD LOCATED REMOTE WITH 1.6g GALLON ACCUMULATOR, RESERVOIR UNIT, & AUXlL. IAR¥ ENERO¥ SOURCE FOR S¥STEH HINIHUH ONE SET BLIND RAMS &. TWO SETS APPROPRIATE PIPE RAHS, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY TO MEET AP] RP 53 CLASS 5H REQUIREMENTS, /.. KILL ! ...... FOLD P~-,~.S SUr, E PU.MP ~'O[i: Z ~t 8 C~ e~k~OtOS ~ u((T ~ ~P~3 ~. flYGR~ULIC CONTRGLLI~D Rlr~OT£ OPERATED DRILLING SPOOL ~£.UOT£ PRESSURE GAGE SENSOR ADJUSTABLE AOJU~-T~' BL~ C~OKE CHOKE MANIFOLD - .o VARIABLE: CGKTROL u-.. · aUL - ~ TO ~vuo~uEmc Alaska Oil & Gas Cons. Com~s UUD/GA~ S[PARATOR. Anchorage GET-AWAY LINE TO RESERVE PIT CHGK£ $ };ILL HAt;IFOLDS FOR q s/8'; 8 7" OD C~,SING BOP STACK BOP MANIFOLD LAYOUT - CONOCO, INC. . SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 PLEASE REPLY TO JUN 2 4 1~3 SCHLUMBE,GE. WELL SE~V,CES Pouch 340069 Prudhoe Bay, AK 99734-0069 Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention:_ Linda Start Gentlemen' Enclosed are 3 BLorints. of the R~cerd, Run !, .., ~ ".,,°/93 Company Conoco, Inc. ~> i~ Well Milne Point Unit L-]i Field Milne Point County North Slope atin~ R~_cQrd~. Run 1, 6/15/93, ~ckerIset[in~ on: State .i Alaska Additional prints are being sent to: 1 BL _prints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PT 1BL prints , 1RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston, TX 77099 Attn: Larry Sydora 713/561-3674 1BL prints Conoco, Inc. I000 South Pine Ponca City, OK 74603 Attn: Janet Webb, 1030 EB 1 ~a Oil & Gas Conservatio~ ~Commission III 3001 PorcuPine Drive Anchorage, AK' 99501 ~ Larry Grant prints 1 BL prints , 1 RF Sepia OXY U.S.A., Inc. 6 Desta Driv_e~_Suite_6DO2 Midland, TX 79705 Attn: John Carrol 915/685-5898 .prints prints The film is returned to Conoco, Linda Start R,E J V. nEg D We oppreciate the prlv~ ege o serw you. JUN 2 8 1BBb SwS- t 327 Ir OH/CH (11 BL/3RF) Naska 0ii & Gas Cons. Commission Anchorage Received by: ,. ~__ f .... ~ _. Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Joh.0ston date: Chairman file: June 1, 1993 052593.doc thru: Blair E Wondzell ~o~ Petr Insp Supervisor from: ~obby Foster Petr Inspector subject: Diverter Test-Nabors 22E CONCO-MPU-L-11 Miine Pt. Field PTD 93-13 Tuesday, May 25, !993: ! traveled this date to CONCO's L-11 and inspected and function tested the diverter system. The system tested OK and was installed in compliance with AOGCC regulations. Summary: Inspected and function tested OK the diverter system on Nabor's 22E on CONCO's L-11. attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report .j/j Operation:Development Drlg Contractor: ..~ Rig No. Operator: ~__../o ~o~0 Oper. Rep.' Well Name: ~- /// Rig Rep.: '~, Location: Sec. ~ m. /_J/V/ R. ,/~ ~ Uerdian /~'J Date: ,.~,~.~- Exploratory: Rig Ph. # MISC. INSPECTIONS: Location Gen.' Housekeeping: Reserve Pit: ~//~ ACCUMULATOR SYSTEM: Well Sign: ,.--- Systems Pressure: _~z~)p psig · (Gen.) Drlg. Rig:Pressure After Closure: /.~. psig Flare Pit: 200 psi Attained After Closure: - mm. ~,? / sec. Systems Pressure Attained: ..~ min. /:~ sec. Nitrogen Bottles: ~[ ~ ~2'~ . DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: in. MUD SYSTEM INSPECTION: in. Trip Tank: ~/~'fl. Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm Light Alarm psig Distribution orig: - Well File c - Oper/Rep c - Database C - Trip Rpt File c - Inspector FI-022 OPERATOR REP.: Dvtrinsp2 ALASKA OIL AND GAS CONSERVATION COMMISSION April 12, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORA61E, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Jeff Allison Drilling Engineer Conoco Inc. 3201 C Street, Ste 305 Anchorage, AK 99503 Re: Milne Point Unit L-ii Rev. Conoco Inc. Permit No: 93-13 Sur. Loc. 2023'FNL, 471'FWL, Sec. 8, T13N, RiOE, uM Btmhole Loc. iOI'FSL, 389'FEL, Sec. 32, T14N, R10E, UM Dear Mr. Allison: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commi s s ioner BY ORDER OF T~IE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o enCl. Department of Environmental Conservation w/o encl. (~) prif~le.d on recycled p~per b y C.D. Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 March 12, 1993 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: MPU L-11; CHANGE TO DRILLING PERMIT Dear Mr. Johnston, Conoco, Inc., as operator of the Milne Point Unit, requests the Commission's approval for a change to the MPU L-11 bottom-hole location indicated on our original Permit To Drill, Permit Number 93-013, that was approved on February 12, 1993. In accordance with 20 AAC 25.015, a revised Permit To Drill with the new bottom- hole location is attached. Aisc attached, as promised in the cover letter for our original Permit to Dill, is the certified plat of the surface locations of wells MPU L-12 and MPU L-13, and a schematic drawing of the recently redesigned pit system utilized on the Nabors 22E drilling rig. As a consequence of this new bottom-hole location, the point at which the oil pool will be opened to the well bore is closer than 500 feet from a quarter section line. We have, therefore, also attached an Application for Exception to the well spacing requirements of 20 AAC 25.055. Please direct any questions regarding this changed bottom-hole location to our Drilling Engineer, Mr. Jeff Allison, at 564-7662. Sincerely, SHEAR Specialist att CC: SGB, JLA, CVL, TJY L-11 Well File Chevron USA, Inc. OXY USA, Inc. RECEIVED MAR 1,5 199,~ Alaska 0il & 6as Oons, l;0mmlssi0~ Anchorage March 12, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 COMM !CC)MM RES ENG SR ENG SR ENG ENG ',~SS~- .... ENG ASST SR GEOL GEOL ASST STA~ TECH' RE: MPU L-11; APPLICATION FOR EXCEPTION TO WELL SPACING PROVISIONS OF 20 AAC 25.055 Dear Mr. Johnston, Conoco, Inc., operator of the Milne Point Unit, requests the commission's approval of an exception to the well spacing requirements of 20 AAC 25.055(a)(3) to allow the drilling and completion of Milne Point Unit development well L-11 so that the oil pool will be opened to the well bore at a point that is closer than 500 feet to a quarter section line. The proposed location at which the well bore will be opened to the oil pool is 351'FNL, 1081'FEL, Section 5, T13N, R10E, Umiat Meridian. Chevron USA, Inc. and OXY USA, Inc. are the non-operating owners of governmental quarter sections directly and diagonally offsetting the quarter section in which well MPU L-11 is located. Attached are copies of the notices that were sent registered mail to each of these owners. Also attached is a plat showing the location of MPU .L-11, the location of all other wells on the same lease as L-11, and the location of all wells on adjoining leases. The undersigned verifies all the above is true and the attached plat correctly .portrays pertinent and required data. Please direct any questions regarding the drilling and completion of MPU L-11 to our Drilling Engineer, Mr. Jeff Allison at 564-7662. Tom Yeager "-' SHEAR Specialist att CC: SGB, JLA, CVL, TJY L-11 Well File Chevron USA, Inc. OXY USA, Inc. RECEIVED MAR 1 5 199~ Alaska 0ii & Gas Cons. /~ch0rage Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 March 12, 1993 Mr. Mike W. Sellers Chevron USA, Inc. 1301 McKinney Houston, Texas 77010 RE: MPU L-11; APPLICATION FOR EXCEPTION TO WELL SPACING PROVISIONS OF 20 AAC 25.055 Dear Mr. Sellers, The Alaska Oil and Gas Conservation Commission (AOGCC) requires that the applicant for an exception to the well spacing provisions of 20 AAC 25.055 notify by registered mail all owners of property adjacent to the property in which the exception will occur. The intent of this letter is to satisfy the AOGCC's notification requirement. Conoco, Inc. is applying for an exception to this well spacing provision to allow development well MPU L-11 to be drilled and completed so that the target oil pool will be opened to the well bore at a point closer than 500 feet from a quarter section line. This proposed bottom-hole location is 351'FNL, 1081'FEL, Section 5, T13N, R10E, Umiat Meridian. Please direct any questions regarding the drilling and completion of MPU L-11 to our Drilling Engineer, Mr. Jeff Allison at (907) 564-7662. Sincerely, Tom Yeager SHEAR Specialist cc: SGB, JLA, CVL, TJY L-11 Well File RECEIVED MAR 1 5 199~ Alaska 0il & Gas Cons. Anchorage STATE OF ALASKA ALASKA '-- - AND GAS CONSERVATION CL,,v~MISSION PERMIT TO DRILL la. Type of work Drill Re-Entry 2. Name of Operator Conoco I nc. 20 AAC 25.005 Redrill ----I lb. Type of well. Exploratory ~ Stratigraphic Test 2 Development Oil A~, DeepenCl Service __.% Developement Gas ;- 3. Address 3201 C Street, Suite 305 Anchorage, AK 99503 4. Location of well at surface 2023' FNL, q71' F'~L, Sec. 8, 'r13N~ RIOE~ U.N.~ NSB~ AK At top of productive interval 351' FNL, 1081' FEL~ Sec. 5 At total depth 101' FSL~ 839' FEL~ Sec. 32, TI~-N, AlOE 12. Distance to nearest property line 101' FSL @ TD 11,600 feet 13. Distance to nearest well ~-0' @ 1~50 ' feet 16. To be completed for deviated wells Kickoff depth 50( feet Maximum hole angle 55° 18. Casing program I size Specifications I Coupling I Length BTRS i 80' BTRS I ~11570': Hole Casing 30" 13 3/8" 12-1/q" 9 5/8" 8-1/2" 7" Weight J Grade J 54.5I '55 I "7 1"-8°! 19. To be completed for Redrill, Re-entry, and Deepen 0 Present well condition summary Total depth: Single Zone -- Multiple Zone 5. Datum Elevation (DF or KB) 51' HSL (30' AGL) feet 6. Property Designation ADL 25509 ,a -~..K'S<~ ! ? 7. Unit or property Name Milne Point Unit 8. Well number L-11 9. Approximate spud date April 1, 1993 14. Number of acres in property 2533 Acres 10. Field and Pool Kuparuk River Field 11. Type Bond (see 2o ^AC 25.025) BI anket Number 8086-15-5~ Amount $200,000 15. Proposed depth ¢,~D and TVD) 11600' ND, 7385' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2700 psig At total depth 0'VD) MD 30' 30' 30' Setting Depth Top Bottom ITVD I MD I TVa I I 30' I :t6715' J :t~-580 30, i .'11600,[ :!:7305 measured true vertical 3210 psig Quantity of cement (include stage data) + 600 sx Permafrost C :1:1800 sx Permafrost E + 300 sx Class G :!: 300 sx Class C )erations. Down Squeeze: · ~ sx Permafrost. C + 60 sx Bbls Diesel feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured true vertical Size Cemented Measured depth True Vertical depth RECEIVED MAR 1 5 199; Alaska 0il & Gas Cons..Commission Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch 1~ Diverter Sketch ~ Drilling program ~ Drilling fluid program IXl Time vs depth plot [] Refraction analysis [] Seabed report ,% 20 AAC 25.050 requirements 21. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Dril ling Engineer ~/'// ~" ' ' Commission Use Only Permit Number J APl number JAp. proval date 50- Conditions of approval Samples required E2 Yes ~ No Mud log required IL-] Yes I Date O.~//, Z/~'' ; JSee cover letter for other requirements ~ No Hydrogen sulfide.measures E3 Yes ,~f No Required working pressure for BOPE E]2M; Other: ORIGINAL SIGNED BY Approved by RUSSELL A. DOUGLASS Form 10-401 Rev. 12-1-85 Directional survey required ~ Yes [] No ~,3M; [] 5M; [] 1OM; [] 15M Commissioner by order of ~ the commission Date¢~__-...~___~_~,_~ Subrnit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-ii Conoco Inc. 3201 C Street, Suite 305 Anchorage, Ak 99503-3992 I. Casing and Cementing Program CASING PROGRAM Hole Size Casing Size Depth Weight Grade (Inches) (Inches) (ft) (DDf) Conn 30" 12-1/4" 8-1/2" 13-3/8" 115 ' 54.5 ppf K-55 WELD 9-5/8" 6,715' 47 ppf N-80 BTTS 7" 11,600' 26 ppf L-80 BTTS ae The 13-3/8" conductor will be set at 80' below ground level then cemented to the surface with ±600 sacks Permafrost type lie" . Be The 9-5/8" surface casing will be set approximately 100' below the base of the Schrader Bluff "OB" sand (±6715' MD) and cemented to surface. The cement job will be performed in two stages utilizing a hydraulically operated stage tool located at approximately 1,800' TVD. Stage I cement will consist of approximately 1000 sacks Permafrost type "E" cement followed by 250 sacks of class "G" tail. Stage II cement will consist of approximately 800 sacks of permafrost type "E" followed by a 50 sack class "G" tail. A top job utilizing Permfrost Type "C" cement will be performed if cement is not circulated to surface. Ce II. The 7" production casing will be set at 11,600' MD/7385' TVD or approximately 300' below the base of the Lower Kuparuk sands. Class "G" cement (approximately 300 sacks) will be circulated from the 7" shoe to 1000' above the_tDD_~3£~a~ Kuparuk interval. After the 7" casing is set, rig will be utilized to complete the well. Drilling Fluid Program MAR 1 AlaskaOil&GasCons. Comm~sS~°n A. 0 - 500' 9.0 ppg freshwater spud mud. Anchorage B. 500'- 6,715' 9.0 ppg - 9.5 ppg freshwater spud mud. C. 6,715' - T D (11,600') 9.4 ppg - 10.5 ppg dispersed. Conoco Inc. Supplemental Data Sheet Well L-11 January 1993 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well L-11 to continue development of the Kuparuk River Pool at Milne Point. The mud system will consist of a fresh water spud mud (9.0 - 9.5 ppg) from the surface to the 9-5/8" casing point at approximately 6,715' MD. A low solids, non-dispersed system (9.5 - 10.5 ppg) will be used from 6,715' to the 7" casing point at ±11,600' MD (T.D.). Magnetic single shot surveys will be taken at the 9-5/8" and 7" casing points to validate the MWD survey. MWD surveys will be taken every ±30' in the build interval and every 100' in the vertical and slant sections. The MWD survey will be used as the continuous survey. All surveys will be referenced to the Section Grid System and corrected for magnetic declination. Directional only through the Shallow Oil Sands (±5600' - 6600' MD) and Gamma Ray/Resistivity/Density Porosity through the Kuparuk Interval (±10,974' - 11,366' MD). Additional electric logs may be run upon further investigation of each sand interval. A 20", 2,000 psig diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5,000 psi RSRRA BOPE stack will be nippled up to the surface casing for drilling the production hole. Pressure tests and function tests will be performed on the pressure control equipment as per State Regulations. Maximum downhole pressure is estimated at approximately 3,210 psig and based on SIBHP of the L-7 well. Maximum surface pressure is estimated at 2,700 ps±g, based on the Crawford Equation assuming an evacuated wellbore with a 0.7 SG gas, 0.9 "Z" factor and a 610° R temperature. The closest wellbore is MPU well L-10 with 40' of closure at the 1450' MD. Approximately 400 sacks of Permafrost Type C cement displaced with dead crude and/or diesel will be pumed down the 7" x 9-5/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. RECEIVED MAR 1 § 199 Alas_ka Oil & Gas Cons. Commission mchorage Conoco Inc. Supplemental Data Sheet Well L-ii January 1993 Page 3 WELL PROGNOSIS AND DRILLING PROGRAM TVD MD FORMATION BIT TYPE WT YP PV VISC FL 500 500 GRAVEL 994 1000 SAND/SHALE 3921 5567 MA TOP 4366 6342 OA TOP 4521 6611 OB BASE 4580 6715 9-5/8" CSG. 6976 10887 CAP ROCK 7026 10974 MK-1 TOP 7146 11183 LK-1 TOP 7211 11296 BASE KUP. 517D 517D 517D 517D 517D 517D R417G R417G R417G R417G 7251 11366 BASE KUP RES R417G 7385 11600 T.D. R417G SPUD 9.0 50 20 100 15 SPUD 9.0 50 20 80 15 SPUD 9.2 25 15 50 15 SPUD 9.2 20 15 50 12 SPUD 9.4 15 12 50 10 SPUD 9.6 12 10 40 8 LSND 10.4 12 12 35 6 LSND 10.5 12 10 35 6 LSND 10.5 12 10 35 6 LSND 10.5 12 10 35 6 LSND 10.5 10 12 35 6 LSND 10.5 10 15 35 6 True vertical depths are based on a sub-surface datum. 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 1,5 199 Alaska Oil & Gas Cons. Commission ;Anchorage P. 6×10 L'~OCO ~ InC. Pad L 11 slot ~11 Nilne Point Unit North SLope, Alaska CLEARANCI~ REPORT East'm~n Te(eco Your ref : 11 Version Our ref : propT09 License : Data printed: 8-Mar-9~ Date crated: 8-1er-9~ Last revised: 8-1~ar-93 Field is centred on nTO ]0 8.305,,149 38 7.22 Structure is centred on n70 30 8.305,~1&9 ~8 7.22 Stot rotation is n70 29 ~8.&Og,w149 37 53.356 slot Grid coordinates are II 60314~,7.452, E 54506~.099 Stot tocat coordinate~ are 202~o00 S &71.00 E Reference North is True North ( ta~RNING: DATA BELOg 15 A SUHMARY, DETAIL PROX[NITIES NOT TABULATED Object wet tpath Ctosest approach uith 3-D minimum distance method Last revised Distance M.D. Diverging from 11o Feb-93 280.9 440.0 ~,0,0 11-Feb-95 120.& 0.0 0.0 11-Feb-95 60.2 0.0 0.0 11-Feb-9~ 180.6 0.0 0.0 11-Feb-9~ 115,8 2125.0 2125.0 11-Feb-93 215.2 1475.0 1675.0 11- Fel~93 8~,9 1525.0 1525.0 12-Feb-93 39.9 1450.0 1450.0 4-Feb-gS 252.4 500.0 500.0 11-Feb-93 317.4 180.0 Y.60.0 RECEIVED M AR 1 5 199;5 Alaska 011 & Gas Cons. commiSsb~ Anchorage MAR 12 '93 11:10 987+561 1358 987 PAGE.806 O' 50 1 O0 150' 200" :'250' 300 ...... 350' ' 400 450 500' '550' ' '600 I I 2100 ~0 650 .... 700 1750 1100 ! ' ; .-- . .. .: . 900 1500 700 , 1300 1700 1500 2~(~o 1800 700 7OO ~o 850 . 'i · ;19oo ' ' 9OO 0 950 ~ , . : . '~"":': .... ............ ~"E.'~:.". ........ ' .......... · :X': ...................... ,~ ..... : ....... ~ '::': :::. "~-~,._~;~.! .'~,7oo..:.': ;. . · \ :... :: .-::: :.. :.. ~oe o:: ; ..... ' : -i-:-'v-: .-.: .......... ~' '.;' "-:'-~-k:51 .o0 ............... :,. ....... :-..~-~Joo' -- ....... '": t'~oo : ............ :'i :. ..... .......... ...... ' · ' .............. : ........... : ...... ~~'~ .......... t ......... \ .... /~. ,.~o ..... 00.° 1:)0 -> ........ / - oo . ,.,~oo . . O0 .... ~ ~'"" ' : :' : : 5o0 '' 150 ~ m ..... / ~ 5'fruSta: Pad L ~ ~ ~.,~ ~oo · %.,~oo 2200 = L-Pad Proximity Analysis /k / ./ L.-PAD L-13 g-1 · L,'2 · RESEHVI:. I~11 PAD EL. ,- 15.5' ~ AS-.BUILT WF..LLS · EXISTING WELLS I. DAlE OF SURVEY MANClt 3, 1993. 2. REFERENCE FIr. LB BOOK C93-01 (Pas. i ~H~U S). 3. ALASKA STATi~. PI.ANE COORDINATES ARE ZONE 4. ALASKA, NAD27. ,~. HOmZON~^~ CONTROL BA~O ON ~'A0 MONUMEmS t.-~ NOmH ~ ~-2 SOU~H. 5, EL~VAT]~S SHO~ ARE CONOCO (MLLW). EEEIVED MAR 1 § 199,:3 Alaska .0il & Gas Cons. Commission ~Anchorage FEB 0~1 6:56 No.009 P.02 VlCINTY: MAP 1 N.T.S, .S .URVEYO~,'S' CERTIFI¢,ATE ) HEREBY CCRljl Y THAT I Ak{ ' PI)OP£RLY REGI61EI(~D AND LICENSED TO PRACTICE LAND SUIIV~'Y)NG IN 1HI~ STATE OF ~LASKA AND THAT Tills PlAT REP~E'~NI$ A SURVEY MADE DY ME O~ UNDER MY DIRECT SUI"£RVJ$ION ANn THAT ALL 01MENSION$ AND OTHER (JETAIIS ARE COREFCT AS O,F MARCH 4. 1995. LOCATFr) WITllJN PROTRACTED SEC. a, T.1;5 N., R.10 E., U.M., AK. JWELLI' A.$.P. ' PLANT"' J GEODETIC JDIVERYER J ..~ECIION i NO, } COORDINATES COORDINATFS. J POSIllON ~.~AD ELE~SEIS J --IY~-6:~i,'/4 Ni'i~.48 '/ '/~'~',q'¢7,57~"/ .... . '-~-1-~'?' FNLI J 13 IX- 54.4,736.28. E. 1104.,'52 J 149'38'03.0~"J 13.1 J '{3~' FW~I 3/g/g3 IRIiViSFD L'"12 PI. ANT C00ffO · SECll0N LINE 0rT~U ,0R. IOINA. L AS-BUILT IssUE m REVISIONS DAT~ MAR 9 '93 1a:29 F. R. BELL & ASSOCIATES ~RA~I~NU NAM~ '1 ....I jr.,~, "' I"~'''": I i J 3/5/93 I MS I ' , 'l NTS I I IDRAWN 1 CHECKII I SK-L1213AO / ,_ / I J,~ I ! L-PAD CONDUCTOR AS-BUILT WELL'S L--;12 &:: L-13 ,~,I,q,I~VAI: LI213AO { J N FYI. ' ~t;alotbtYea :: j8T;~r_93For : J ALLISON Plot Reference is 11 Version #2. Coordinates ore in feet reference slot #11. True Verticel Depths are reference wellhead. Eastman Teleco 6524/6116 Nielsen Way * Anchorage, AK 99518 Phone: (907) 565-5269 / Fax: (907) 565-5865 Phone: (907) 562-2646 / Fox: (907) 561-1358 500 _ . 1000_ _ 1500 _ _ 2000_ 2500 _ _ 5000_ _ 5500 _ _ 4000 _ - 4500 _ 50O0 5500 6000 _ 6500_ _ 7000_ _ 7500_ CONOCO, ][nC. Structure ' Pad L Field : Milne Point Unit Well · 1 1 Location : North Slope, Alaska Point Tie on KOP End of Build Target End of Hold WELL PROFILE DATA MD Inc Dir TVD North East 0 0.00 28.20 0 0 0 500 0.00 28.20 500 0 0 2332 54.96 28.20 2064 717 384 11183 54.96 28.20 7146 7103 3809 11600 54.96 28.20 7585 7404 3970 sGo,.,: 25o.oo East --> 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 I I I II II II II II II II II I 8000 L-11B/Kup L-11 T LK-I L-11T/MK1 N 28.20 DEG E 8401' (TO TD) i06 RKB £LEVAT~)N 51' KOP .00 2.00 ~.oo J,u,u) 3 ~G / ,oo' .o J I .00 .00 .00 x~.42.00 ',,.4~.oo Csg 54.96 DEG ~ ap Rock GET #2 - T/ LK-1 TD - 7 Csg Pt ........ i ' ' 'o'o ..... 'o'100' & ..... 100 ..... k' 0 500 1000 1500 2 O0 2500 5 0 3500 4000 45 0 5 5 6000 6500 7 7500 8000 85 Scale 1 : 250.00 Vertical Section on 28.20 azimuth with reference 0.00 N, 0.00 E fram slo! #11 7500 0 500 ~> RECEIVED MAR 1 5 1995 Alaska Oil & Gas Cons, .C.0.mlS~' Anchorage II A ~' '"'""'-'"' !' '----- MILNE POINT UNIT !1 ~_~.~0~0 ~'~ ..... -_®1~ .o,~, s,o,~.^,^s~ 5201.73...AC . .. ' _ AMERADA !l~ll~lll//~ 2 17 92 II AMERA~A ' ~ ETAL ~~------~. N,~0E /~ I ,,,,,, , , ,,, ,,,, ,,,,,,.,, ' .' .... ~ I E* AL ~--**~'--*'.~ ~ ............... ADL-355021 i ADL-355016 512o AC. 15071 AC, co.oco~. ® ~c~co 5734ADL'355022~ ,~11 ~"~ / ~/~ IA~~.~ ~~.~ ,~o~~c°"°c°~., ,~. , ~' ' ~ ~ co.ocok ONOCO cF, c. ca ET AL ET ~ CON o ~ ~ . ET AL . ~ :):> ADL-25515 315848 25516 ADL47437 ADL47438 .... ~J 47439ADL' ADL-315846 ~~' ~n :::30 ~ ~ I 2560 AC. 2544 AC . t2oo AC. 1200 AC.; ' , ~ ' , .... I 2560 AC. 2544 AC. ,, 25o AC. ~280 AC. o ~.o ~ CHEVRON 2580AC. coNoco CHEVRON ~_. ~ ~ IADL-2SS17 _ ~ ~0AALc. ADL-25518 ADL-28231 I I t,-,. [12235A0. ~F--~a~ 2560A0. 2555A0. I I '"TI I I llll I I I I I I I DIVER-I-ER STACK FOR 13 3/8" CONDUC'TOR DIVERTOR QUICK CONNECT ASSEMBLY FULL OPEN KNIFE VALVES RECEIVED MAR 1 §:199,3 Alaska Oil & Gas C6ns. Commissio~ Anchorage 1. The hydraulic control system will be in accordance with API specifications and AOGCC requirements. 2. The HCR valve will open when the preventer closes. A single 10" relief line will run off of the drilling spool HCR and go straight out the back of the sub base to reserve pit or open pad area (safe area). Down wind diversion will be accomplished with a tee with two knife valves on both sides of the tee and they will be linked together to enable one to always be open and the other to be closed. CONOCO INC,--NABORS RIO 22E L3-5/8" 56888 AFl AFl AFl TI-r-oeded L 1 ne Flow Line Annu~ Prevento. r. Ram ~x × ll'm Tubing Spool w/ 2"-5000~t APl 11' 5M Cas.~ng Spool w/ 3"-5000~ Oomeotbn 9-5/8" Choke Ltne~ 3" 5880~ Manual & 3" HOE VALVE 'KIll Line: Two 3" 5880~ Hanua~ · . Val. ves Side Outlets Side Outlets Su .~Face. Co~ing 13-3/8" Conductor Casing BOP Gale S¥S VaLve i'1"1 BOP STACK SIZE EATING MEETS APl EP53 & SPEC 6A FOR CLASS 5M BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STAT]ON CONTROL MAN]FOLD LOCATED REMOTE WITH t80 OALLON ACCUMULATOR, EESERVO]R UN~T, & AUXILIARY ENERGY SOURCE FOR SYSTEM ACT]VAT:lO,q, H]N]HUM ONE SET BLIND RAHS & TWO SETS APPR, OPR]ATE PIPE RAHS, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY 1'0 MEET CLASS 5H REQUIREMENTS, KILL L:~t:~FOLD PRF..S SUrE PUY. P ~ · ~'0 T£: I ~L~C C(.~IR2L S~slr£u fOR 8,3~ ~C~ 6 C~O~ ~T~ I0 ~[ ~CAT~O ON ~IG fLOOR. Z ~L 6 CHC~ ~klfOLOS ~ u~T ~ RP~ ~. i HYGR~ULIC CONTROLLED REI~.OTE OPERATED DRILLING SPCOL lff'ORAULIC CX)NTRCX_LED RE3~OTE OPE.RATED ADJU~'TA BL[ O~OKE EE~OTE PRESSURE GAGE SENSOR AOJUST~E~_E CJ'iOKE CHOKE MANIFOLD .. __ YARIASLE CHOKE CONTROL TO ATI, IOSPHERIC )dUD/GAS_. SEPARATOR R'ECEIV ~,. MAR 1,5 199; Alaska' 0ii-~,"6:~%'- Cons. Cc Anchorage GET-AWAY LINE TO RESERVE PIT CHCK£ ~S KILL P, At;IFOLDS FOR cls/8'~ 8 7" OD CASING BOP ST~CK BOP F,~AN1FOLD LAYOUT - CONOCO, INC. · D .o ]missior; CHOKE MANIFOLD 3' TO '~lll BOP STACK - 13518' 5000d' .. COMPAFITMENT CAPACITY c~crrY C, OIdPM~T il i (D ~,uc'no,~ ~ I Y5 ~~ I~l ~ ~ 8z "~tJ" ~Ulq'~Y VALVE ~ ~ VALVE [~] ,~JCTION VALVE [] E~JAUZ.~ GAG~I'ATOfl STANDP~E MAN'OLD 2' KIA,. LI*JE H.P.MUD PUMP No2 H.P. MUD PUMP No1 MUD SYSTEM FLOWSHEET STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF CONOCO, ) INC. for an order granting an ) exception to spacing requirements ) of Title 20 AAC 25.055 to provide) for the drilling of the Milne Point ) Unit L-11 development oil well. ) Conservation Order No. 313 Conoco, Inc. Milne Point Unit L-11 Development Oil Well April 6, 1993 IT APPEARING THAT: Conoco, Inc. submitted an application dated March 12, 1993 requesting an exception to 20 AAC 25.055 (a)(3) to allow drilling the Milne Point Unit L-11 development oil well closer than 500 feet to a drilling unit boundary. Notice of hearing was published in the Anchorage Daily News on March 20, 1993 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: · The Milne Point Unit L-Il well as proposed will be directionally drilled from a surface location 2023 feet from the north line (FNL) and 471 feet from the west line of Section 8, T13N, R10E, Umiat Meridian (UM). The proposed target location is 351 feet FNL and 1081 feet from the east line (FEL) of Section 5, T13N, R10E, UM, and the proposed bottom-hole location is 101 feet from the south line and 839 FEL of Section 32, T14N, R10E, UM. e Offset owners Chevron USA, Inc. and Oxy USA, Inc. have been duly notified. Conservation April 6, 1993 Page 2 der No. 313 . An exception to 20 AAC 25.055 (a)(3) is necessary to allow drilling of the well. CONCLUSION: Granting a spacing exception to allow drilling of the Milne Point Unit L-11 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: Conoco, Inc.'s application for an exception to 20 AAC 25.055 for the purpose of drilling the Milne Point Unit L-11 development oil well is approved as proposed. DONE at Anchorage, Alaska and dated April 6, 1993. David W. Johnsto~l% Chairman Alaska ~'~Conservation Commission Russell A. Douglass¢' Commissioner Alaska Oil and Gas Conservation Commission MPU_L-11.×LS State: Well: Field: Slate Permit It ~',~ Engineer. L-11 Work Sheet: Kuparuk River Date: 93-13 (REVISED) Cewen! l/o/~e £alculstion.~ $/22/g3 Cag~g Type Casing Size -Inches Casing Length - Feel Hole Diameter -Inches Cement- Sacks :111 Cement- Yield 111 Cement- Cubic ft 111 Cemen~ - Cubic ft 111 Cement-Sacks112 Cement- Yield 112 Cement- Cubic ft 112 Cement- Cubic ft 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic ft 113 Cement- Cubic tt 113 Cement- Cubic ft /Vol Cement- Fill Factor Conducto~ Surface 13.375 9.625 80.000 6,685.000 30.000 12.250 600.000 1,800.000 0.940 2.050 564.000 3,690.000 564.000 3.690.000 0.000 300.000 0.000 1.150 0.000 345.000 0.000 345.000 0.000 0.000 0.000 0.000 564.000 4,035.000 1.793 1.927 Line~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ItDIV/O! Cas',-,:j T.~pe Casing Size -Inches Casing Depth- Feet Hole Diamete~ -Inches Cement- Sacks 111 Cement- Yie~111 Cement- Cubic ft 111 Cement- Cubic R #1 Cement- Sacks 112 Cement- Yield 112 Cement- Cubic ft 112 Cement. Cubic ft 112 Cement-Sacks113 Cement- Yield 113 Cement- Cubic it 113 Cement. Cubic ft 113 Cement- Cubic ft /Vol Cement- interval ft Top of Cement - Feet Intermediate 111 Intermediate 112 0.000 0,000 0.000 0.000 0,000 0,000 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DNt~ 11DIVtO!. ItDIV/0! ItDIV/0! Production 7.000 11,600.000 8.500 300.00 1.15 345.00 345.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 345.00 2,720.68 8,879.3 Measured Depth R~ed 4/13/93 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Conoco Inc. for exception to 20 AAC 25.055 for the Milne Point Unit L-11 development oil well. Conoco Inc., Inc. by correspondence dated March 12, 1993, has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a development oil well in the Milne Point Unit. The exception would allow drilling the Milne Point Unit L-11 development oil well to a location closer than 500 feet from a quarter section line. The proposed surface location is 2023 feet from the north line (FNL) and 471 feet from the west line (FWL) of Section 8, T13N, R10E, Umiat Meridian (UM), and the proposed target location is 351 feet FNL and 1081 feet from the east line (FEL) of Section 5, T13N, R10E, UM, and the proposed bottom-hole location is 101 feet from the south line (FSL) and 839 feet FEL of Section 32, T14N, R10E, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 pm April 5, 1993 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on April 20, 1993, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after April 5, 1993. If no protest is filed, the Commission will consider the issuance of the order without a hearing. Russell A. DouglasK Commissioner Alaska Oil and Gas Conservation Commission Published March 20, 1993 ALASKA OIL AND GAS CONSERVATION COMMISSION February 12, 1993 WALTER J. HIOKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 William L. Brister, Div. Mgr. Drilling Engineer Conoco, Inc. 3201 C Street, Ste 305 Anchorage, AK 99503 Re: Milne Point Unit L-ii Conoco Inc. Permit No: 93-13 Sur. Loc. 2023'FNL, 471'FWL, Sec. 8, T13N, R10E, UM Btmhole Loc. 463'FNL, 463'FEL, Sec. 5, T13N, R10E, UM Dear Mr. Brister: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W .~Johnst~n Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ printed on recycled paper b y ALASKA OIL AND GAS CONSERVATION COM~MM_!.ISSION ;' " ERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill -J 11:). Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - Deepen~1 Service - Developement 6as ~. Single Zone -- Multiple Zone 2. Name of Operator CONOCO ! nc. 3. Address 3201 C Street:, Suite 305; Anchorage, Al( 99503 4. Location of well at surface 2023' FNL, ~71' FldL, Sec. 8, T13N, RIOE, U.H., NSB, AK At top of productive interval 816' FNL, 687' FEL, Sec. 5 At total depth ~63' FNL~ ~63' FEL, Sec. 5 12. Distance to nearest property line ~63' @ 'ID feet 13. Distance to nearest well 60' @ surface feel 16. To be completed for deviated wells Kickoff depth 500' feet Maximum hole angle 5~°i 5. Datum Elevation (DF or KB) 56' HSL (35'ACL) feet 6. Property Designation ADL 25509 · 7. Unit or property Name Nilne Point Unit 8. Well number L-11 9. Approximate spud date ^pril 1, 1993 14. Number of acres in propert 2533 Acres 10. Field and Pool Kuparuk River Field 18. Casing program size Hole Casing 30" 13 3/8" 12-1/~" 9-5/8" 8-1/2" Specifications W.'eigh, 1 6'fade I Coup,ing ~7 .... !.-80.,,! 8ms 11293' 11. Type Bond (see 20 AAC 25.025) B1 anket Number 8086-15 Amount $200,000 15. Proposed depth (MO an~ TVO~ 11,328~ ND/7333' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 {el(21~ Maximum surface 2700 psig At total deolh fTVD) 3210 Quantily of cement TVD (include stage data) 115' :tO:iiX) sx Per~afrst C Q780' ±1900 sx Permafrost E +RO0 sx Class G Setting Depth Top Bottom :1:]00 sx Class G ~00 sx Permafrost C . 60 Bbls Diesel 7333 ' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ Squeeze-. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth JAN 1 5 1995 A!as~a .Oil .& Gas Cons. C0m~tss't0t~ Anc 0rage. True Vertical depth 20. Attachments Filing fee I~ Property plat ~ BOP Sketch [~ Diverter Sketch '~ Drilling program ~ Drilling fluid program EX Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . Title Drilling Engineer Permit Number Conditions of approval Hydrogen sulfide measures ~ Yes J~ No Directional survey required ~ Yes Required working pressure for DOPE !7..~2M; ~'3M: ~ 5M; ~ 10M; L~ 15M Other: Oriainat.. ,.~C~gned By ' Approved by David W. Johnston Commissioner Form t0-~01 Re,.,. 12-1-85 Date 1/5/93 Commission Use Only I API number APl~roval date See cover letter 50--O~..?- .2.--~.. _~..~" ~ ~",/o,~, '"~; '~ for other requirements Samples required ~ Yes ~ No Mud Icg required g Yes '~ No ~ No ALASKA OIL AND GAS CONSERVATION COMMISSION ERMIT TO DRILL 20 AAC 25.005 la, Type of work Drill X Redrill =j lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil '~' Re-Entry - DeepenI~ Service - Developement Gas F" Single Zone -- Multiple Zone 2. Name of Operator CONOCO I nc o 3. Address 3201 C Street, Suite 305; Anchorage, AK 99503 4. Location of well at surface 2023" FNL, 471" FWL~, Sec. 8~ T13N, RIOE~ U.H., NSB, AK At top of productive interval 81Gt FNL, 687' EL, Sec. 5 At total depth q63' FNL, q63' EL, Sec. 5 12. Distance to nearest property line 463' @ TD feet 13. Distance to nearest well 60' @ surface feet 16. To be completed for deviated wells Kickoff depth 500" feet Maximum hole angle 5. Datum Elevation (DF or KB) 56' HSL (35'AGL) feet 6. Property Designation ADL 25509 ' 7. Unit or property Name Milne Point Unit 8. Well number L-11 9. Approximate spud date April 1, 1993 14. Number of acres in property 2533 Acres 10. Field and Pool Kuparuk River Field 11. Type Bond (see 20 AAC 25.025! B1 anket Number 8086-15 Amount $200,000 17. Anticipated pressure (see 20 AAC 25.035 Maximum surface 2700 pslg At total depth ~I'VD) 15. Proposed depth (MD and TVD) 11,328' MD/7333' 1'VD feet 3210 psi~ 18. Casing program size Hole Casing 30" 13 3/8" 12-1/4" 9-5/8" 8-1/2" 7" Specifications ,.Weight ! Grade I Coupling I Length Setting, iDepth Top Bottom Quantity of cement TVD (include stage data) 115" :t600 sx Permafrst C 4780" ~1900 sx Permafrost E :~300 sx Class G 7333" :e300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Down Squeeze.- Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet :[-~00 sx Permafrost C + O0 I~ls Diesel Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth REC V True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch ~. Diverter Sketch '~ Drilling program ~ Drilling fluid program I~ Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge // //- ~- / Commission Use Only Conditions of approval Samples required ~ Yes ,.~ No Mud log required ~ Yes Hydrogen sulfide measures ~ Yes .~ No Directional survey required ~ Yes Required working pressure for BOPE I-~2M; ,~3M: ~ ,_ ,_. ;..: 5M; ~ 1OM; L-.' 15M Other: Original~go~.ned By ' Approved by David W, Johnston Commissioner ~ , Form 10-~01 ~ev. 12-1-85 Date 1/5/93 JSee cover letter for other requiremen!s ~ No SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-ii Conoco Inc. 3201 C Street, Suite 305 Anchorage, Ak 99503-3992 I. Casing and Cementing Program CASING PROGRAM Hole Size Casing Size Depth Weight Grade (Inches) (Inches) (ft) (DDf) Conn 30" 13-3/8" 115 ' 54.5 ppf K-55 WELD 12-1/4" 9-5/8" 6,969' 47 ppf N-80 BTTS 8-1/2" 7" 11,328' 26 ppf L-80 BTTS A® The 13-3/8" conductor will be set at 80' below ground level then cemented to the surface with ±600 sacks Permafrost type llCll , Be The 9-5/8" surface casing will be set approximately 100' below the base of the Schrader Bluff "OB" sand (±6969' MD) and cemented to surface. The cement job will be performed in two stages utilizing a hydraulically operated stage tool located at approximately 1,800' TVD. Stage I cement will consist of approximately 1000 sacks Permafrost type "E" cement followed by 250 sacks of class "G" tail. Stage II cement will consist of approximately 900 sacks of permafrost type "E" followed by a 50 sack class "G" tail. A top job utilizing Permfrost Type "C" cement will be performed if cement is not circulated to surface. Ce The 7" production casing will be set at 11,328' MD/7397' TVD or approximately 200' below the base of the Lower Kuparuk sands. Class "G" cement (approximately 300 sacks) will be circulated from the 7" shoe to 1000' above the top of the Kuparuk interval. After the 7" casing is set, the drilling rig will be utilized to complete the well. II. Drilling Fluid Program A. 0 - 500' 9.0 ppg freshwater spud mud. B. 500'- 6,969' 9.0 ppg - 9.5 ppg freshwater spud mud. Ce JAN 1 § 199~ Alaska Oil & 6as Cons. Anchoragel Conoco Inc. Supplemental Data Sheet Well L-II January 1993 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well L-Ii to continue development of the Kuparuk River Pool at Milne Point. The mud system will consist of a fresh water spud mud (9.0 - 9.5 ppg) from the surface to the 9-5/8" casing point at approximately 6,969' MD. A low solids, non-dispersed system (9.5 - 10.5 ppg) will be used from 6,969' to the 7" casing point at ±11,328' MD (T.D.). Magnetic single shot surveys will be taken at the 9-5/8" and 7" casing points to validate the MWD survey. MWD surveys will be taken every ±30' in the build interval and every 100' in the vertical and slant sections. The MWD survey will be used as the continuous survey. All surveys will be referenced to the Section Grid System and corrected for magnetic declination. Logging will consist of LWD measurements of Gamma Ray/Resistivity through the Shallow Oil Sands (±5800' - 6900' MD) and Gamma Ray/Resistivity/Density Porosity through the Kuparuk Interval (±10,700' - 11,328' MD). Additional electric logs may be run upon further investigation of each sand interval. A 20", 2,000 psig diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5,000 psi RSRRA BOPE stack will be nippled up to the surface casing for drilling the production hole. Pressure tests and function tests will be performed on the pressure control equipment as per State Regulations. Maximum downhole pressure is estimated at approximately 3,210 psig and based on SIBHP of the L-7 well. Maximum surface pressure is estimated at 2,700 psig, based on the Crawford Equation assuming an evacuated wellbore with a 0.7 SG gas, 0.9 "Z" factor and a 610° R temperature. The closest wellbore is MPU well L-5 with 60' of closure at the surface. Approximately 400 sacks of Permafrost Type C cement displaced with dead crude and/or diesel will be pumed down the 7" x 9-5/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. RECEIVED JAN 1 5 t993 Alasga.Oit & Gas Cons. CommJssio~ ..... ~c.[lOragej Conoco Inc. Supplemental Data Sheet Well L-ii January 1993 Page 3 WELL PROGNOSIS AND DRILLING PROGRAM TVD MD FORMATION BIT TYPE WT YP PV VISC FL 500 500 GRAVEL 994 1000 SAND/SHALE 4176 5938 MA TOP 4601 6663 OA TOP 4721 6868 OB BASE 4780 6969 9-5/8" CSG. 6981 10727 CAP ROCK 7031 10812 MK-1 TOP 7151 11016 LK-1 TOP 7216 11128 BASE KUP. 517D 517D 517D 517D 517D 517D R417G R417G R417G R417G 7256 11196 BASE KUP RES R417G 7397 11328 T.D. R417G SPUD 9.0 50 20 100 15 SPUD 9.0 50 20 80 15 SPUD 9.2 25 15 50 15 SPUD 9.2 20 15 50 12 SPUD 9.4 15 12 50 10 SPUD 9.6 12 10 40 8 LSND 10.4 12 12 35 6 LSND 10.5 12 10 35 6 LSND 10.5 12 10 35 6 LSND 10.5 12 10 35 6 LSND 10.5 10 12 35 6 LSND 10.5 10 15 35 6 True vertical depths are based on a sub-surface datum. 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. RE£EIVED dAN 1,5 1 93 ........ ~c~orag.a · .... 01/05/93 MPU WELL L-1 1 DAYS-vs- MEASURED DEPTH SURFACE LOCATION: 2023' FNL, 471' FWL, Sec. 8 (approximate) TARGET LOCATION (MK-1): 816' FNL, 687' FEL, Sec. 5 TARGET LOCATION (LK-1): 676' FNL, 598' FEL, Sec. 5 TARGET LOCATION (Base KUP.): 600' FNL, 550' FEL, Sec. 5 TOTAL DEPTH: 463' FNL, 463' FEL, Sec. 5 SURFACE 2000' ,.I-- 4000' 6000' 8000' 10,000' 12,000' : 98b' , MOI~ KOP 50b' @ N:~2.43EI IOB 3i0 deg.V100i .............. f' · I I EOB ~ 2305' MDJ.2048'~TVD ." 1 "' : RIG I I i-. TER?NALIANGL~=: 54.1 DRILL I -1/4" ~OLE I I I I I ! I I I I I I · · I : I : ! I TD ~. 69691 MD/4i780' TVD ............ ~ ............. [ ........... ~ ............ r ........ '\~'", ..... ~ T .......... ! ............ : I : ' I : : -----! ----.----.-----,----..----.----.----.----!---- ............ ~ ............ ' ........... ~ ......................... ~.,,-i:.~.--~"".-.o.~. ......... i I 1 I I ................... TDI'@'T1~;3'28'" I ~D773.'g'7'""l~ 0 4 8 12 16 CUMMULATIVE DAYS Alaska Oil & Gas Coils. Anchorage MPU WELL L-ii PROPOSED WELLPATH 2000 :!.000 1000 2000 3000 4000 5000 6000 7000 0000 ~ ! ! ! ! ! ! ~ ~ ~ ~ '¢ ? '~ t 7 t ~ ? !' ? ................................................................................................... ?'"T'"7'""~ ........ ?'""f'"T'"7 ................. ~'""~ ..... 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KUP: 60e' FNL, 550 FEL TD: 463' FNL, 463' FEL " (SECTZON 5) EAST(+) / WEST(-) L-11 Proposed --- CLosest Approach AnaLysis --- /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPAR-T - DIST WELL [DENT (FT) (FT) (FT) (FT) (FT) L-4SURA -55 0 -55 0 120 L-5SURA 0 0 0 0 60 L-6SURA -55 0 -55 0 180 L-8SURA 1329 218 1286 53 234 L-9SURA 1390 251 1390 5 109 L-IOSURA 1340 224 1340 2 62 L-7SURA 1944 729 1921 553 63 SUMMARY The weLL which comes closest to the proposed weLL is: L-SSURA CLosest approach distance = 60 (FT) RECEIVED Alaska Oil & Gas L;ons. Oom~isSiOf~ PROXIMITY PLOT (L-il PROPOSED REFERENCE) -1 EAST(+) / WEST(-) ......... ~n---~ i ~ i - NOTES: /'- ~' jl L STATE PLAN[ COORDIN,,,.,.$ AgE ZONE 4. 2. ALL GEODETIC: PO,SmON8 ARE B^:B£D ON lq.~D. 1927. Oi:FS.ET8 TO :t~CTION LIN~I ARE COMPUTED BASED ON PROTR^CTF..D VALL,~8 OF TI-~ I~CTION CORNER POSTION~. . 630° 160' ~ 310' I 160' ..j i1__O' QTYPICAL SECTION NO ,~CAL£ MILNE PT. VICINITY MAP I,~IL I e I I I J I LOCATION IN .SEC. 8, T13N, R1OE, UMIAT MERIDIAN WELL I I:ROM NORTH LINIEJ FROM WE8T LINE 2087' 369' 2056' 1420' 2023 ' J ,1.71 * 20~.0' J 256 ' 191q' J 13q' L-4 L-6 L-11 *_ L-12 * L-13 '* NOT SURVEYED STATE PLANE COORDINATES-ZONE 4 WELL 'Y X L-4 L-5 6,05L383. r 6,03L415.4' 6,031,447.6 644,970.7' ~48,021.$ 548,07L9' GEODETIC PO,.SlTION8 NAD 1927 WELL NC~TH LATITUDE j WEST LONGITUDE L-4 L-5 L-7 70' 29'47.782' 70' 29'48.096° 70' 29'48.4 I0' 149* ,~7'66.147' 149; 87'84.661' 149' 37'63.156' -- I Ill I I Il I I Il I I I L I I r, II Ill I I F. Robert_-~,,' I ~h:" ../~"':~ I - ............... .... ] PROPOSED I A~sk~.Oi~ & Gss Gorm. Gomr~issio~ 'Anchorage: ' ET A CONOCO lADLe5509 ADL~7~4 2560~~,~-~_ ~ ~ ~~ 2533 AC. 2560 AC. o.ocos co. ET AL ET ET AL AOL- ADL- /ADL- ADL- II ADL-25514 IADL-25515 31~ 25516 .ADL47~7 ADL /47~9 31~ Il 2560 AC. I 2~ AC. 12~ AC.; 1280 AC. 2560 AC. 2~ AC. 1128o AC. ~2~ AC. II " ~CONOCO~,ADL-25~ ~ ~ ;CONOCO~/ ~ CHEVRON~ 2~AC. CONOCO CHEVRON ~ADL-25517 _ ET AL 3 AC. ADL-25518 ADL-28231 1 I I I ~ ~ ~ ~ I I DIYERTER S'fACK FOR 13 318' CONDUC]'OR .... O~tO~ LIN! · - t' ~ ~~ ~ DIVERTOR QUICK CONNECT ASSEMBLY STARTIkO · RECEIVED JAN 1 5 i99; Alaska Oil & Gas Cons. Commissior~ Anchorage l FULL OP~ WIFE VALVES . 1. The hydraulic control system will be in accordance with API specifications and AOGCC requirements. 2. The HCR valve will open when the preventer closes. A single 10" relief line will run off of the drilling spool HCR and go straight out the back of the sub base to reserve pit or open pad area (safe area). Down wind diversion will be accomplished with a tee with two knife valves on both sides of the tee and they will be linked together to enable one to always be open and the other to be closed. CONgCO ]NC,--I,,IABORS R'rG 22B 13-5/8" 58888 Flli Llne ^VI 13-~8' ~ A~ 13-5~ 5H x 11' 5H APl 11' 5M 1-breodod Correction Flow Line Annubr Preventer. Rom Choke Ltne~ 3" 5000~ Manuat & 3" HCR VALVE Kttt Line: Two 3" 5000~ Hanuat · . - Vatves Ram Tubing Spoo! Cas.lng Spoo! 9-5/8" Side Outlets Side Outlets Suet:ace .Casing 13-3/8" Conducton Casing BOP Gate SYSTEM Valve -..< BOP STACK SIZE EAT:lNG MEETS APl RP53 & SPEC 6A FOE CLASS 5M BO?E TO BE OPERATED EACH TRIP AND TESTED ~'EEKL¥, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STAT]ON CONTROL MANIFOLD LOCATED REMOTE W:[TH 168 OALLON ACCUMULATOR, RESERVOIR UN]T, & AUXILIARY ENERO¥ SOURCE FOR SYSTEM ACT]VAT]O~4, MINIMUM ONE SET BLIND RAMS &. TWO SETS APPR. OPR]ATE PIPE RAMS, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY TO MEET AP] RP 53 CLASS 5M REQUIREMENTS, ~'OT£: ! N~'~;.)LJC CC.~TROL S~T£~ FOR 8C~ Sl~C~ 6 C~O~ ~T~L Io ~E ~CAIED Ok' ~IG FLOOR. ( C~[ ~LNIEO~ SlZ~ - r~T~G 3'- S~ ADJUSTABLE CHOKE KiLL "'"'FOLD ~Y~r~uuc cO~t~cLLeD re~ote oPer~teo .. -- VARIABLE CHOKE __ CONTROL ,_,,~.~N 1 5 !993 ~/L~I$1~& Gas Cons. Co, Anchorage · ~7{~ ~DRAULIC CONTROLLED _R E~(OTE OPE. RATED REMOTE PRESSURE GAGE SENSOR TO ATMOSPHERIC 'I~UD/GAS_ SEPARATOR GET-AWAY LINE TO RESERVE PIT AOJUST~BIF CHOKE CHOKE MANIFOLD · CHCKE S KILL H,A/,'IFOLDS FOR ciS/8'~ 8 7" OD CAS)NG BOP STACK [~OP t,iANIFOLD LAYOUT - CONOCO, INC. · · t '-.,; · tmissior~ MUD PITS - NABORS 22E The mud processing system totals 1200 barrels including one 80 barrel trip tank and one 20 barrel slug tank. All compartments have separate PVT probes. Nabors has changed the piping and added additional equipment to the circulation system of the 22E Rig. A schematic will be submitted as an attachment to the Permit upon completion. RECEIVED JAN 1 5 1995 Alaska 0il & 6as Cons. Anchorage January 13, 1993 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: PERMITS TO DRILL Dear Mr. Johnston, Attached are Permits to Drill, Form 10-401, and associated information for Milne Point Unit Wells L-11, L-12 and L-13. Aisc attached is check number 1037 in the amount of $300.00 to pay the fee identified in AAC 25.005. In addition to the attached, the following two informational items will be provided to the Commission as soon as they are available: 1. Certified plats of the surface locations of Wells L-12 and L-13 will be provided. These locations will be surveyed prior to mobilization of the drilling rig. 2. Schematic drawings of the recently redesigned pit system utilized on the Nabors 22E drilling rig will be provided. Nabors is currently in the process of producing these schematic drawings. Please direct any questions regarding this application to our Drilling Engineer, Mr. Jeff Allison, at 564-7662. Sincerely, Tom Yeager SHEAR Specialist attachments CC: JLA, CVL, TJY L-11 Well File L-12 Well File L-13 Well File Chevron Occidental RE£EIVEO JAN 1 5 199;~ .0il & Gas Cons. Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR · 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Feburary 4, 1993 William L Brister, Div Mgr Expl/Prod NA Conoco Inc 3201 C St Ste 200 Anchorage, AK 99503-2689 Dear Mr Brister: We received your February 2, 199'3 correspondence requesting an interpretation of the intent of Rule 3 in Conservation Order No. 173. The intent of Rule 3 is to provide a standoff of at least 500 feet from the unit boundary to any point of drainage in a wellbore. Therefore, the Commission concurs with your assessment that the proposed program for well MPU L-11 is consistent with the intent of Rule 3. Yours very truly, Russell A Douglass Commissioner RPC/jo STATE OF ALASKA ALASKA (~'"'i AND GAS CONSERVATION CC MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ][ Redritl -----I lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil ~' Re-Entry -- Deepen~ Service ~--_ Developement Gas ~ Single Zone ;-; Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO Inc. 56~ MSL (35~AGL) feet Kuparuk River Field 3. Address 6. Property Designation 3201 C Street, Suite 305; Anchorage, AK 99503 ADL 2.5509 4. Location of well at surface 2023" FNL, ~71' Fl, fL, Sec. 8, T13N, RIOE, U.M., NSB, AK At top of productive interval 816' F'NL, 687' FEL, Sec. 5 At total depth q63' FNL, ~63~ FEL, Sec. 5 12. Distance to nearest I property line ~63' @ TO feet 16. To be completed for deviated wells Kickoff depth 500' feet Maximum hole angle 18. Casing program size Casing 13 3/8" Hole 30" 12-1/q" 9-5/8" 13. Distance to nearest well 60~ @ surface feet 8-1/2" 7" 5~° 7. Unit or property Name Milne Point; Unit 8. Well number L-11 9. Approximate spud date April 1, 1993 14. Number of acres in property 2533 Acres 11. Type Bond (see 20 AAC 25.025) B1 anket: Number 8086-15-5q Amount $200,000 15. Proposed depth IMD anO TVO~ 11,328' MD/7333~ TVD feet 17. Anticipated pressure (see 20 AAC 25.035 Maximum surface 2700 psig Al total deplh f'rVD) 3210 psig Setting Depth Specifications Weight! Grade I Coupling 5~.5 ! K-551 BTRS · 7 I N-801 BTRS 26 i.L-801 BTRS ILength 80' -693~', 11293' Top Bottom MD ! TVD I MD 1 TVD 35' I 35' ! 115' I 115' Quantity of cement (include stage data) :L-G00 sx Permafrst C ±1900 sx Permafrost E +~00 sx Class G 7333' :1:300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen O )erations. Dram Squeeze: Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet · d~O0 sx Pe~frost C ± rd) Bbls Diesel Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth True Vertical depth RECEIVED /.~nch0ra¢~e 20. Attachments Filing fee [] Property plat [] BOP Sketch I~ Diverter Sketch '~ Drilling program ~3 Drilling fluid program E~ Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements -- 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Permit Number ! APl number I 50-- Conditions of approval Samples required Hydrogen sulfide measures ~ Yes ~ No Required working pressure for BOPE Other: Title Drilling Engineer Date 1/5/93 Commission Use Only IApproval date E3 Yes ~ No Mud log required ~ Yes Directional survey required ~ Yes ~ No C2M; © 3M; .~ 5M; ~ 10M; L-3 15M Approved by ISee cover letter for other requirements ~3 No Commissioner by order of the commis,$i,T,r~ Form 10-401 Rev. 12-t-85 Sjb?r:it in ',.ri:::,-" MPU WELL L-ii PROPOSED WELLPATH 2000 1000 2000 4000 6000 7000 BOO0 1000 2000 3000 4000 8000 8000 7000 8000 BO00 10000 D:I:SPLACEMENT (feet) William L. Brister Division Manager Exploration Production, North America February 2, 1993 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: MPU L-11; REQUEST FOR INTERPRETATION OF AOGCC REGULATIONS Dear Mr. Johnston, Conoco, Inc. requests that the Commission make an interpretation of AOGCC regulations as they relate to our recently submitted Permit To Drill, Form 10-401, for Milne Point Unit development well L-11. The need for this interpretation arises because of a slight deviation in the language of Conservation Order No. 173 Rule 3 from the language in 20 AAC 25.055(a)(3). 20 AAC 25.055(a)(3) clearly indicates that the distance from a section line to the point in a well bore that is open to an oil pool may not exceed 500 feet. The language in Conservation Order 173 Rule No. 3, however, has recently been interpreted by the Commission's technical staff as implying that no portion of the well bore may be closer than 500 feet from a section line. The proposed drilling program for MPU L-11 is such that the location of the perforations in the well bore is greater than 500 feet from the nearest quarter section line, but the proposed bottom hole location is slightly less than 500 feet from the nearest section line. Mr. David Johnston February 2, 1993 Page 2 We believe that the proposed drilling program for MPU L-11 is consistent with the intent of the regulations to protect the correlative rights of lease holders. In the case of MPU L-11, it should also be noted that the lease holder of the adjacent property is an interest owner in the Milne Point Unit. We appreciate your prompt attention to this matter, and we also appreciate the assistance we have received from your staff on this matter. Please direct any requests for additional information to myself at 564-7601 or to Mr. Tom Yeager at 564-7660. Sincerely, m William L. Brister Division Manager cc: Mr. Blair Wondzell, AOGCC Mr. Bob Crandal!, AOGCC Mr. Mike Minder, AOGCC Alaska Oil & (".:;~ c;c::s, oor~'~,.,r~issiv, MPc ' ~ L-, 1 ..~,Lb Fi-~id: State Permit Condu. c~ 80,000 -J.M, MUM 584,000 0,000 O, O00 ~AO00 ~.-6~b 6,934,000 12,258 !,900:000 2..~0 3,~5,000 3~ _r_-,, 080. !,!-~] 345,C~ 34E000 0,~ O,_~_-O 0280 4,240,080 !.952 0,000 O. OOO o.r~o 0,000 O. O00 0,000 O..gOO 0000 0.000 O. OOO 8.000 0,000 ~.DiV/Oi -Fee~ : inche~ ~.! ~2 ~2 ~2 .,~ ....~ ~ _. _.% _ Cmen~ - YWW Cemen~ - Cubic ~t C~r& - Cu~ ~t / Vol iniermedia~e :Ii2 0.000 0,000 O. O0 0.00 O, O0 O. O0 o, O0 .= MM 0,00 0.00 O.~ 0.00 0.00 0.00 0.00 ~na~mi Lq¥iu! Production !!,328,000 8,.500 300.00 1,15 345.00 345:00 O:OO 0.00 0.00 O. O0 0,00 O. OO O.[(1 0,00- 345.00 2,720,68 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee /~¢/g~_. $//~/~ ( 2 ) Loc /~74 ~//~/¢._~ [2 thru 8] r8]]b tz-%3 [9 thru 13] [10 & 13] (3) Admin [14 thru 22] [23 thru 28] Company YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. ~ 3 Is well located proper distance from property line ........ : .......... 4. Is well located proper distance from other wc. lls ..................... _~_ 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated $ is wellbore plat included ................... Ac 7. Is operator the only affected party .................................. A2. 8. . 10. 11. 12. 13. 14. 15. Can permit be approved before 15-day wait ............................ 16. 17. 18. !9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval ,needed .................................... Is lease nLrnber appropriate~ ......................................... Does well have a unique nam¢$ nLrnber ................................ Is conductor st ring prov i ded ......................................... 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 & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all kno~a productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore .................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~¢42C~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... ( 6 ) 0 t h e r A¢~ [29 thru 31] (7) Contact~ [32] (8) Addl geology' engineering: DWJ MTM/~ RAD ~j) ~I- RPC BEW JDH LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' MERIDIA.IXJ' UM ;X, · SM TYPE' Exp~~ Redr i 1 1 Rev 0 u~ ,( ** CHECK LIST FOR NEW WELL PERI4ITS ITEM APPROVE DATE (2) Loc A~/~ .½/~/~. ,/.~ t r 13] [10 S 13] [14 thru 22] [23 thru 28] (5) BOPE Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ ~ e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & ncrnber ................................ Is conductor string provided ......................................... Wil 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all knov~ productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to 3Ooo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other ~f~_ ~ '[~9 thru 31] (7) Contact . J;32 ] (8) Addl geol ogy' eng i neer i ng: DWJ MTM_~ RADS] ~ RPC?~'.~,~j DEW dDH~/-f~/~ LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLOP~TORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nc~nber of contact to supply weekly progress data ...... Additional requirements ........................................... Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' MERIDIAFI: UM SM WEL~ TYPE: Exp D~e-v~) X. Redr i 1 I Inj Rev o Ezz 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 eft'od has been made to chronologically organize this category of information. LIS VERIFICATION USTING FOR: CONOCO, INC. L-11 MILNE POINT UNIT BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR CONOCO, INC. L-11 BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: Bulk Density Compensated [RWD] Bulk Density Time Since Drilled [RWD] Bulk Density Data Density Integrated [RWD] Conductivity (AT) Dielectric Corrected [RWD] Conductivity (PD) Dielectric Corrected [RWD] Calculated Dielectric Constant Density Long Space Apparent [RWD] Photoelectric Effect [RWD] Density Porosity Limestone Matrix [RWD] Density Porosity Sandstone Matrix [RWD] Delta Rho Correction [RWD] Density Short Space Apparent [RWD] Gamma Ray (APl) [RWD] Gamma Ray Borehole Corrected [RWD] Neutron Far Base [RWD] Neutron Near Base [RWD] Neutron Porosity Time Since Drilled [RWD] Neutron Porosity Data Density Integrated [RWD] Neutron Porosity (LS) Borehole Corr [RWD] Neutron Porosity (SS) Borehole Corr [RWD] Neutron Porosity Ratio Borehole Corr. [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Phase Difference Data Density Integrated [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected for Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling g/cc mins pts mmho/m mmho/m g/cc B/e p.u. p.u. g/cc g/cc MWD-API MWD-API cps cps mins. pts. p.u. p.u. p.u. deg deg mins pts. ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 30 SEP 93 1:22p != = ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ~ Automatic Curve renaming: 0=OFF, 1 =ON 2 AUTOFILE = 0 , ~ Automatic FILE= generation: 0=OFF, 1 =ON 3 COMMENTS = I , ! Decode US Comment records: 0=OFF, 1 =ON 4 INFORECS = 1 , ! Decode US Information records: 0=NO,1 =YES 5 LISTMETHOD = 0 , ~Usting Method: 0=depth units 1 =tape units 6 LISTFREQ = 100, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0 = OFF, 1 = ON 9 FORCETYP = 0 , ~ (1 =BIT,2=US ... thru 35=Army Accoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRITETAP = 1 , ~ Write Tape-lrnage File: 0=NO,1 =YES 12 SPLITLIS = 1 , ~ If I and WRITETAP on, split US logical files to physical 13 SUBFILES = /0/, ! Tape Subfile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ~ Set up for TAPE2WDS to Interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 100, LISTMAX = 0 , STATS = 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES = /0/, INTERPOLATE = 'YES' END SUBFILES(69) = -gggg. O0 SUBFILES(71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(77) = -9999.~ SUBFILES(79) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(83) = -9999.~ SUBFILES(85) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.~ SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(70) = -ggcJg.00 SUBFILES(72) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILE$(86) = -9999,00 SUBFILES(88) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 !-- STRING PARAMETERS INTERPOL= YES Tape Subtile I is type: US **** REEL HEADER **** MWD 93/9/30 1225 01 **** TAPE HEADER **** MWD 93/9/30 1225 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shred and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 6654.0 11634.0 $ BASELINE CURVE FOR SHIFTS: GRI CURVE SHIFT DATA (MEASURED DEPTH) ~ EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH BDCM BDEM CADE DLAM 10680.0 10680.0 10680.0 10680.0 10680.0 10680.0 10701.0 10700.0 10700.0 10700.0 10700.0 10700.0 10796.0 10796.0 10796.0 10796.0 10796.0 10796.0 10818.0 10818.0 10818.0 10818.0 10818.0 10818.0 10849.0 10849.0 10849.0 10849.0 10849.0 10849.0 10900.0 ' 10898.0 10898.0 108,98.0 10898.0 10898.0 11000.0 10998.0 10998.0 10998.0 10998.0 10998.0 11080.0 11078.0 11078.0 11078.0 11078.0 11078.0 11097.0 11096.0 11096.0 11096.0 11096.0 11096.0 lJ170.0 11169.0 11169.0 11169.0 11169.0 11169.0 11200.0 11199.0 11199.0 11199.0 11199.0 11199.0 11211.0 11211.0 11211.0 11211.0 11211.0 11211.0 11236.0 11236.0 11236.0 11236.0 11236.0 11236.0 11260.0 11258.2 11258.2 11258.2 11258.2 11258.2 11288.0 11288.0 11288.0 11288.0 11288.0 11288.0 11509.0 11509.0 11509.0 11509.0 11509.0 11509.0 $ -- BASEUNE DEPTH NFBM NPIM NPSM 10680.0 10680.0 10680.0 10680.0 10701.0 10700.0 10700.0 10700.0 10796.0 10796.0 10796.0 10796.0 10818.0 10818.0 10818.0 10818.0 10849.0 10849.0 10849.0 10849.0 10900.0 10898.0 10898.0 10898.0 " 11000.0 10998.0 10998.0 10998.0 11080.0 11078.0 11078.0 11078.0 11097.0 11096.0 11096.0 11096.0 -, 11170.0 11169.0 11169.0 11169.0 11200.0 11199.0 11199.0 11199.0 11211.0 11211.0 11211.0 11211.0 11236.0 11236.0 11236.0 11236.0 11260.0 11258.2 11258.2 11258.2 11288.0 11288.0 11288.0 11288.0 DPSM RACM ROPS 10680.0 10680.0 10700.0 10700.0 10796.0 10796.0 10818.0 10818.0 10849.0 10849.0 10898.0 10898.0 10998.0 10998.0 11078.0 11078.0 11096.0 11096.0 11169.0 11169.0 11199.0 11199.0 11211.0 11211.0 11236.0 11236.0 11258.2 11258.2 11288.0 11288.0 2 3 4 5 6 7 8 91011 1213141516 O0 0 1 0000000 I 000 1 Rep Code Count Bytes 68 10 40 Sum: 10 40 40 fndun a [F ] 1.00000000 3 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 23 FRAMES * DATA RECORD (TYPE# O) 1018 BYTES * Total Data Records: 434 Tape File Start Depth = 6654.000000 Tape File End Depth = 11634.0(0X)00 Tape File Level Spacing = 0.5000(X) Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14802 datums Tape Subtile: 2 555 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S): 40.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1000 FLUID LOSS ((33): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: 0.000 MUD CAKE AT MT: 0.000 0.000 0.000 0.0 0.0 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: ALL DATA ON THE LOGS HAS BEEN DEPTH SHIFTED TO THE WlREUNE CASED HOLE GAMMA RAY LOG AT THE CUSTOMERS REQUEST. INTERVAL FROM 6700 TO 6711 FT (4409 TO 4415 FT TVD) WAS LOGGED 74 HOURS AFTER BEING DRILLED DUE TO CASING RUN AND CEMENTING. THIS HOLE SECTION IS ALSO 12 1/4 INCH HOLE. ANY DATA PRESENTED ABOVE 6700 FT WAS LOGGED THROUGH CASING. INTERVAL FROM 11575 TO 11630 FT (7393 TO 7423 FT TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET. $ CN : Conoco Inc. WN : L-11 FN : Milne Point COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 3 THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 BDCM MWD 68 I G/CC 4 2 BDEM MWD 68 I MINS 4 3 BDIM MWD 68 1 PTS 4 4 CADE MWD 68 1 MMHO 4 5 CPDE MWD 68 1 MMHO 4 6 DCCM MWD 68 I 4 7 DLAM MWD 68 1 G/CC 4 8 DPEM MWD 68 1 MINS 4 9 DPLM MWD 68 I PU 4 10 DPSMMWD 68 1 PU 4 11 DRHM MWD 68 1 G/CC 4 12 DSAMMWD 68 1 G/CC 4 13 GRAMMWD 68 1 GAPI 4 14 GRCMMWD 68 1 GAPI 4 15 NFBMMWD 68 I CPS 4 16 NNBMMWD 68 1 CPS 4 17 NPEMMWD 68 I MINS 4 18 NPIM MWD 68 1 PTS 4 19 NPLMMWD 68 I PU 4 20 NPSM MWD 68 1 PU 4 21 NRCM MWD 68 1 4 22 PDCM MWD 68 1 DEG 4 23 PDDC MWD 68 1 DEG 4 24 PDEM MWD 68 1 MINS 4 25 PDIM MWD 68 I PTS 4 26 RACM MWD 68 I OHMM 4 27 RADE MWD 68 1 OHMM 4 28 ROPA MWD 68 1 FPHR 4' 29 ROPS MWD 68 1 FPHR 4 30 RPCM MWD 68 I OHMM 4 31 RPDE MWD 68 I OHMM 4 32 TCDM MWD 68 1 DEGF 4 128 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 -- Tape Subtile 4 is type: US **** TAPE TRAILER **** MWD 93/9/30 1225 01 **** REEL TRAILER **** MWD 93/9/30 1225 01 Tape Subtile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 30 SEP 93 1:25p Elapsed execution time = 3 minutes, 1.1 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: US DEPTH FCNT RP 7800.0000 25.2891 3.2928 7900.0000 27.1875 3.4454 8000.0000 26.2969 2.9710 8100.0000 26.4356 3.1316 8200.0000 27.9189 3.0138 8300.~ 27.7678 3.2346 8400.0000 31.3736 3.1711 8500.0000 31.0491 3.9395 8600.0000 31.1922 3.6157 8700.0000 31.0847 2.8418 8800.0(X)0 31.7206 2.6336 8900.0000 29.2684 2.6155 9000.0000 31.4387 2.5527 9100.0000 30.2881 2.5582 RHOB NCNT 2.3801 7030.7510 2.3792 7177.0000 '2.3910 7151.2510 2.4134 7148.2021 2.3990 7171.5957 2.4134 7347.5830 2.3941 7115.0371 2.3786 7280.4277 2.4194 7261.8574 2.3919 7180.2041 2.4240 7272.6211 2.3946 7215.6250 2.3772 7209.6484 2.3820 7226.3271 PEF NPHI 3.0149 36.9635 2.9063 34.5937 2.9724 35.9184 3.0826 36.6761 3.0395 33.5162 2.9668 34.7942 3.0292 28.7885 2.6322 29.9571 3.1964 29.7149 3.0272 29.4237 3.2164 29.1636 3.0736 31.8166 2.8025 29.1717 3.0900 30.5843 DRHO RA 0.0517 3.2768 0.0576 3.7624 0.0636 3.0327 0.0663 3.3072 0.0530 3.1441 0.0579 3.2285 0.0566 3.5459 0.0475 4.2165 0.0260 3.7879 0.0400 3.0435 0.0014 2.8694 0.0479 2.7746 0.~24 2.~ 0.0257 2.6905 GR ROP 112.3199 206.6064 102.6439 201.5093 101.6043 157.4968 104.8689 163.1054 116.7960 177.1 942 83.0976 155.9424 103.2165 244.6899 96.5113 89.3197 101.5590 228.3772 115.9308 201.5093 110.8019 171.7023 109.8893 95.7806 107.7367 145.3975 110.7020 228.3772 DEPTH RHOB PEF FCNT NCNT NPHI RP 10600.0000 2.4638 4.1654 31.2108 7077.4990 29.3479 3.0944 10700.0000 2.5086 4.4165 26.2828 7025.2451 35.7898 1.7473 10800.0000 2.4771 4.1946 24.5221 6877.2217 38.0622 1.1981 10900.0000 2.4269 4.2417 20.4883 6956.7832 49.3034 1.9639 11000.0000 2.4040 3.4503 27.2161 6992.0059 34.0461 2.5006 11100.0000 2.3415 3.7930 30.8458 7206.4922 30.5044 7.0998 11200.0000 2.3036 2.7084 34.9442 7370.7012 26.9674 12.9518 11300.0000 2.4026 3.1139 32.4378 7356.5889 29.4217 8.9716 11400.0000 2.4028 3.6536 24.0629 7047.3145 40.6412 4.2013 11500.O0(X) 2.5203 3.5972 29.7614 7196.5459 31.8202 4.0462 11600.0000 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 11634.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DRHO RA 0.0337 2.5019 0.0389 1.9384 0.0415 1.2314 0.0733 2.1209 0.0575 2.6309 0.0642 10.2760 0.0207 17.3919 0.0583 12.6897 0.0437 4.1552 0.0634 4.3713 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 6854.000000 Tape File End Depth = 11634.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet GR ROP 178.2840 442.9855 133.5116 142.7358 142.2127 46.9268 148.2834 40.1913 138.8671 48.5814 97.9661 55.5932 95.0286 53.0741 119.0047 37.3390 112.9805 70.8777 -999.2500 46.9001 -999.2500 70.8829 DEPTH CPDE DPSM NFBM NPSM PDIM RPCM 7100.0000 331.8144 21.5705 23.5845 40.3071 833.0000 2.9106 7200.0000 351.1246 19.7496 21.7500 44.9382 1070.0000 2.7520 7300.0000 276.0440 16.4958 27.9375 33.1240 1250.0000 3.4900 7400.0000 312.1473 17.2337 28.5625 32.3859 1435.7500 3.0907 7500.0000 316.5024 18.7122 26.4375 35.8771 1595.6667 3.0497 7600.00(X) 317.6064 17.1409 27.0590 34.5732 1763.0(X)0 3.0389 BDCM DCCM DRHM NNBM NRCM RACM RPDE 2.2941 133.0032 0.0909 7025.2773 271.9615 3.5765 3.0137 2.3241 136.5950 0.1172 7035.0010 295.3083 3.0931 2.8480 2.3778 122.0321 0.0508 7118.0000 232.6,532 3.2535 3.6226 2.3656 129.26,33 0.0788 7119.0010 228.2295 3.6752 3.2036 2.3412 130.0862 0.0392 7186.3291 248.1772 3.6679 3.1595 2.3672 130.3056 0.0623 7128.7773 240.8109 3.5181 3.1486 BDEM DLAM DSAM NPEM PDCM RADE TGDM 29.5000 2.2031 2.1425 35.0000 14.2776 3.3482 95.5464 49.0000 2.2069 2.1291 51.7500 14.7718 2.9202 99.5000 29.4286 2.3268 2.2974 31.5000 12.7690 3.0806 98.6225 28.0000 2.2870 2.2345 30.0000 13.76,33 3.4396 102.2000 29.0000 2.3021 2.2760 31.0000 13.8765 3.4321 103.6625 41.0000 2.3013 2.2636 42.0000 13.9066 3.3020 106.1375 BDIM DPEM GRAM NPIM PDDC ROPA 328.5000 2.9168 86.9117 643.0000 13.9828 227.4785 415.0000 2.8261 103.9540 881.2498 14.4725 101.8530 476.5714 3.0616 94.9226 1022.5000 12.4818 126.6258 536.8571 2.8826 90.5844 1113.5002 13.4688 207.4736 593.3750 2.8064 102.5156 1225.3,333 13.5839 236.1427 652.6250 3.0260 97.1039 1340.8892 13.6130 278.0824 CADE DPLM GRCM NPLM PDEM ROPS 298.6671 24.3224 89.9352 36.3566 24.0000 222.2030 342.4391 22.5654 107.5703 40.9784 44.0000 118.1226 324.6168 19.4256 98.2247 29.2798 23.000O 96.3713 290.7334 20.1378 93.7356 28.5633 24.0000 236.2815 291.3643 21.5644 108.0819 31.9793 24.00(X) 236.0907 302.8452 20.0482 100.4819 30.7012 36.0000 265.4715 DEPTH CPDE DPSM NFBM NPSM PDIM RPCM 8300.0000 309.1616 14. ,.'.'.'.'.'.'.'.'.'~ 1 27.7678 34.7942 3121.6665 3.1212 8400.0000 315.3484 15.5071 31.3736 28.7885 3321.3330 3.0604 8500.0000 253.8371 16.4512 31.0491 29.9571 3571.7998 3.7927 8600.0000 276.5750 13.9767 31.1922 29.7149 3747.1426 3.4856 8700.0(X)0 351.8845 15.6423 31.0847 29.4237 3954.5000 2.7485 8800.0000 379.7034 13.6955 31.7206 29.1636 4161.5000 2.5493 BDCM DCCM DRHM NNBM NRCM RACM RPDE 2.4134 128.6627 0.0579 7347.5830 242.0116 3.4317 3.2346 2.3941 129.8689 0.0566 7115.0371 207.0541 3.7992 3.1711 2.3786 117.3296 0.0475 7280.4277 214.0891 4.5544 3.9395 2.4194 122.1046 0.0260 7261.8574 212.6280 4.0637 3.6157 2.3919 136.6793 0.0400 7180.2041 210.8923 3.2340 2.8418 2.4240 141.6675 0.0014 7272.6211 209.3244 3.0424 2.6336 BDEM DLAM DSAM NPEM PDCM RADE TCDM 28.6667 2.3572 2.3191 31.2500 13.6807 3.2285 119.9750 26.0000 2.3375 2.2998 54.0000 13.8465 3.5459 119.7500 40.1250 2.3310 2.2993 42.0000 12.1266 4.2165 121.2125 35.0000 2.3813 2.3838 38.0000 12.7830 3.7879 124.0250 34.0(XX) 2.3519 2.3252 37.0000 14.7867 3.0435 124.2500 41.0000 2.4231 2.4263 45.0000 15.4727 2.8694 126.4775 BDIM DPEM GRAM NPIM PDDC ROPA 1147.3333 2.9668 83.0976 2369.2495 13.3894 156.4738 1216.1665 3.0292 103.2185 2526.0000 13.5535 227.4861 1316.8750 2.6322 96.5113 2771.4282 11.8418 96.2157 1375.9998 3.1964 101.5590 2874.7500 12.4954 224.9942 1454.6001 3.0272 115.9308 3080.0000 14.4902 150.~ 1528.0000 3.2164 110.8019 3267.0000 15.1728 162.2456 CADE DPLM GRCM NPLM PDEM ROPS ,.'.'.'.'.'.'.'.'.~. 7~ 17.3438 85.9884 30.9191 24.0000 155.9424 282.0128 18.4717 106.8092 25.0605 20.0000 244.6899 237.1640 19.3827 99.8687 26.1942 25.2000 89.3197 263.9960 16.9950 105.0920 25.9592 15.0000 228.3772 328.5711 18.6022 119.9637 25.6763 19.5000 201.5093 348.5(X)6 16.7237 114.6564 25.4241 33.5000 171.7023 DEPTH CPDE DPSM NFBM NPSM PDIM RPCM 9500.0000 369.9882 17.1992 30.1406 30.9563 5850.5000 2.6156 9600.0000 524.1294 18.9600 24.9675 38.5991 6053.0000 1.8540 9700.0000 410.0735 13.3876 25.3227 37.4929 6315.3330 2.3622 9800.0000 336.0954 13.2736 30.4735 30.2650 6616.0000 2.8745 9900.0000 275.0736 9.4482 33.1247 28.1316 6837.5000 3.5030 10000.0000 290.0397 9.8380 31.8911 29.3676 7064.00(X) 3.3240 BDCM DCCM DRHM NNBM NRCM RACM RPDE ' 2.3662 139.9430 0.0295 7253.1719 219.9750 3.3733 2.7028 2.3372 164.9908 0.0089 7191.1973 262.9645 2.0701 1.9079 2.4291 146.9164 0.0133 7074.8506 255.0811 2.6318 2.4386 2.4310 133.7936 0.0555 7153.0566 214.5760 3.4632 2.9753 2.4941 121.8183 0.0479 7325.9932 201.9226 4.9530 3.6354 2.4877 124.8790 0.0508 7311.6533 209.3232 3.8829 3.4478 BDEM DLAM DSAM NPEM PDCM RADE TCDM 31.7143 2.3367 2.3170 33.1667 15.2356 3.1608 133.3850 34.0000 2.3283 2.3223 37.0000 18.6795 1.9806 135.6125 102.7500 2.4155 2.4071 109.0000 16.1921 2.4998 137.1875 55.0000 2.3751 2.3386 54.2500 14.3869 3.2484 135.0500 25.0000 2.4462 2.4142 28.0000 12.7407 4.5376 1 38.0875 28.0000 2.4370 2.4078 30.0000 13.1609 3.6272 139.8875 BDIM DPEM GRAM NPIM PDDC ROPA 2150.2852 2.8929 96.3201 5118.6320 14.9373 122.4975 2222.3330 2.8863 100.9588 5303.0000 18.3690 153.3688 2345.7495 3.0512 111.6924 5656.0000 15.8900 145.5472 2451.9995 2.9700 119.4574 5996.2500 14.0920 61.6909 2526.1670 3.3225 124.5939 6181.0010 12.4538 208.7843 2603.3994 3.5015 136.6817 6413.0000 12.8709 224.2711 CADE DPLM GRCM NPLM PDEM ROPS 316.3789 20.1045 99.6709 27.1670 26.0(X)0 109.3613 504.8901 21.8035 104. 4709 34.6638 26.0000 183.1055 400.0294 16.4266 118.6911 33.5709 65.0000 141.7554 307.6422 16.3167 126.9426 26.4945 48.0000 60.0658 220.3790 12.6255 132.4010 24.4246 19.0000 244.6898 275.6960 13.0016 145.2463 25.6218 21.0(X)O 228.8818 DEPTH CPDE DPSM NFBM NPSM PDIM RPCM 10700.0000 572.2963 8.5719 26.2828 35.7898 8749.0000 1.6991 10800.0000 834.6528 10.4766 24.5221 38.0622 9013.5000 1.1 733 10900.0000 509.1831 13.5242 20.4883 49.3034 9335.0000 1.9075 11000.0000 399.9027 14.9114 27.2161 34.0461 9721.0000 2.4213 11100.0000 140.8493 18.6970 30.8458 30.5044 10093.0000 6.7772 11200.0000 77.2093 20.9947 34.9442 26.9674 10472.6680 12.2434 BDCM DCCM DRHM NNBM NRCM RACM RPDE 2.5086 172.0550 0.0,389 7025.2451 244.0400 2.0279 1.7473 2.4771 2O5.7229 0.0415 6877.2217 256.O504 1.2725 1.1981 2.4269 162.7514 0.0733 6956.7832 310.0083 2.2236 1.9639 2.4040 145.1909 0.0575 6992.0059 234.5561 2.7773 2.5006 2.3415 89.4382 0.0642 7206.4922 213.3035 12.3495 7.0998 2.3035 68.2875 0.0207 7370.7012 192.5768 23.2696 12.9518 BDEM DLAM DSAM NPEM PDCM RADE TCDM 51.0000 2.4520 2.4115 55.0000 19.6482 1.9384 144.2187 53.4000 2.4369 2.4067 59.0000 24.2988 1.2314 145.9625 102.5000 2.3546 2.3023 114.0000 18.3708 2.1209 148.55(X) 90.3.3,33 2.3464 2.3079 97.000O 15.9561 2.6309 150.9125 125.5000 2.2740 2.2248 135.0000 8.3220 10.2760 151.7000 1057. ~.~.0 2.2947 2.2819 113.0000 5.5168 17.3919 150.3500 BDIM DPEM GRAM NPIM PDDC ROPA 3243.7495 4.4165 133.5116 8142.0000 19.3336 153.5337 3346.7998 4.1946 142.2127 8497.0000 23.9759 70.9441 3562.5000 4.2417 148.2834 8882.000'0 18.0615 37.3997 3806.3330 3.4503 136.8671 9282.0000 15.6535 46.0153 4025.5000 3.7930 97.9661 9678.0000 8.0701 51.7836 4253.5557 2.7084 48.7495 10077.6680 5.3045 42.1944 CADE DPLM GRCM NPLM PDEM ROP$ 515.8975 11.7799 145.6991 31.8933 41.0000 142.7358 812.0635 13.6178 155.1945 34.1330 45.5(X)0 46.9268 471.5070 16.5584 161.8193 45.3790 77.0(X)0 40.1913 380.0972 17.8970 149.3610 30.1821 72.0000 48.5814 97.3144 21.5497 108.9089 26.7258 101.0000 55.5932 57.4979 23.7669 54.3428 23.2997 88.0000 44.9922 " Tape Subtile 4 is type: US