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195-212
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,768'feet 12,663 feet true vertical 7,522'feet N/A feet Effective Depth measured 12,663'feet N/A feet true vertical 7,423'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 11,901' 6,711' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: Taylor Wellman twellman@hilcorp.com 907-777-8449 321-541 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 350 Gas-Mcf MD 110' 6,690' TVD 42 0 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 139 280 Casing Pressure Tubing Pressure 1,029 200 MILNE PT UNIT F-14 measured true vertical Packer Representative Daily Average Production or Injection Data Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-212 50-029-22636-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0355018 MILNE POINT / KUPARUK RIVER OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Length 72' 6,654' Size Conductor Surface Intermediate 20" 9-5/8" Production Liner 12,716' measuredPlugs Junk measured N/A 7,504'12,749'7" Burst Collapse N/A 3,090psi 110' 4,520' 5,410psi N/A 5,750psi 7,240psi Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 8:59 pm, Nov 09, 2021 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.11.09 16:26:24 -09'00' David Haakinson (3533) RBDMS HEW 11/10/2021 ADL0025509, ADL0388235, SFD 11/15/2021 SFD 11/15/2021 DSR-11/10/21 SFD MGR27DEC2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 ASR Rig #1 50-029-22636-00-00 195-212 10/18/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary Raise the derrick and pin. Set up rig floor, spot catwalk and containment. Finish Torque & N/U the BOP stack. Install stairs, landings and hand rails around the rig. R/U the ESP cable sheave in the derrick. RU the pits and service lines. Position heaters and insulate cellar. Begin warming BOP stack and all lines. Bring on 40 bbls fresh water for BOP test. Continue warming BOP stack, lines and cellar. Hunt for cold & draft spots and mitigated. RU BOPE testing equipment. Flood the coke manifold & BOP stack with fresh water and purge the air. PU and MU the 2-7/8" test joint. Shell test the BOPE to 250/2,500 psi (good test). Test BOPE as per Sundry and AOGCC reqmts. Pipe rams (2-7/8” x 5” VBR’s) with 2-7/8” & 3-1/2” test joints, annular with 2-7/8” test joint. All tests performed with fresh H2O against test plug to 250 psi low and 2500 psi high, for 5 min and charted . Gas Alarms Tested. AOGCC rep Austin McLeod waived witness on 10/19/21 at 13:09 hours. Tests: 1. Annular with 2-7/8” test joint, 2-7/8" dart valve , C8, C9 & C10 (passed),2. 2-7/8”x5” VBR with 2-7/8” test joint, C1 & K1 (passed), 3. 2-7/8”x5” VBR with 3-1/2” test joint, 2-7/8” FOSV, HCR Choke, K2 (ULDS Gland Nut leaking on high test), Attempt to tighten leaking gland nut with no success. Call out Wellhead Rep to troubleshoot. BOLDS and tighten gland nut, RILDS., 3. 2-7/8”x5” VBR with 3-1/2” test joint, 2-7/8” FOSV, HCR Choke, K2 (tighten gland nut and retest passed), 4. C5, C6 & K3 (passed), 5. C4, C7 & C11 (passed), 6. C13, C14 & C15 (fail ),Troubleshoot leak during test #6. Grease choke valves & process of elimination, isolating valves. Find that Kill manifold valves #6 & 7 leaking. Rebuild both valves,6. C13, C14 & C15 (passed), 7. Blind Rams, C12 & C16 (passed), 8a. Manual adjustable choke (passed)8b. Hydraulic super choke (passed). Accumulator Test: System pressure = 3150 psi, Pressure after closure = 1750 psi, 200 psi attained in 15 seconds, Full pressure attained in 67 seconds, N2 4 Bottle Average = 2225 psi, Rig down test equipment, Blow down lines. Bring on 192 bbls 8.4 ppg source H2O to pits. Pull plug from BPV. Open IA and observe slight vac. Stab into BPV open, no pressure observed, pull BPV. Make up FOSV and XO to 2-7/8" landing jt. Engage Hanger & BOLDS. Pull Tubing Hanger Free, Unseat @ 91k PUW. Pull Hanger to Rig floor w/ 85k free travel wt. Rig up chains and binders, Center BOP stack to hanging tubing string. Install slips on stack Rig up ESP tools to POOH with 2 7/8" ESP completion. Lay down Landing Jt & Hanger. POOH f/ 11901' t/ 10885' laying down 2- 7/8" ESP completion tubing. Add double calculated pipe displacement hole fill every 15 jts. Rig crew finishing maintenance and painting on Rig at A pad. SimOps: Mobilize LRS and 8.4 ppg source H2O to F pad. Spot and RU LRS. PT lines to 250/2500 psi (good test). Initial well pressures: tubing = 300 psi, IA = 336 psi & OA = 220 psi,Bleed gas off the tubing and IA . No fluid observed with pressures down to 0 psi. Tubing = 0 psi, IA = 0 psi & OA = 220 psi,Begin well kill by pumping 67 bbls, 8.4 ppg source H2O down the Tbg with full open line from IA to the kill tank with no pressure or returns observed. Bullhead source H2O down IA @ 4.5 BPM, no pressure observed for 180 bbls. Pressure increase to 400 psi on both IA and Tbg. Open Tbg and take returns to Kill Tank for next 150 bbls pumped, with 40 bbls returned to tank. Send Vac Truck for more source H2O. Shut in IA and bullhead 70 bbls down Tbg for flush @ 4.5 BPM. ICP = 0 psi, FCP= 670 psi. Shut down and shut in to monitor the pressure, the tubing & IA on a vac, the OA pressure @ 203 psi. Rig down lines and Install BPV. Mobilize Stack, Cellar Hut, Rig floor, Mud boat and pushers shack from A pad. N/D Tree. Install the plug off tool into the BPV and test - Good. Check the tubing hanger lift thread - good. Spot the crane. Set the BOP stack onto the wellhead and secure. Fly the well house into position over well. Fly the rig floor on top of the well house and secure. Layout the koomey lines and RU. N/U the BOP stack. Mobilize the rig from A-pad tent. Spot and level the rig. 10/19/2021 - Tuesday 10/18/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 ASR Rig #1 50-029-22636-00-00 195-212 10/18/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary 10/21/2021 - Thursday Rack and Tally 3-1/2" WorkString. Make up 7" Test Packer and run in the hole picking up 3-1/2" WorkString from surface to 10530'. 92k PUW, 33k SOW, Kelly up to string. Set YellowJacket 7" Test Packer @ 10530' w/ 15k wt on Packer. Fill hole w/ 66 bbl 8.4 ppg source water. Rig up and line up to test Csg. Bleed air from system. Test 7" casing against VBR's t/ 1500 psi for 30 charted min - Good Test. Release Packer. Fluid level in stack drop from sight. Bleed air from workstring. Break out from Kelly and lay down 3 jts. Blow down lines. POOH laying down 3-1/2” work string f/ 10530' to 3250'. Add double calculated pipe displacement to hole fill every 15 jts. 10/22/2021 - Friday POOH laying down 3-1/2” work string f/ 3250' to surface. Add double calculated pipe displacement to hole fill every 15 jts. Lay down Yellow Jacket 7" test packer. Packer looked good with no issues. Clear rig floor. Nipple down spools and flow line. Nipple up shooting flange for E-line. Disconnect pipe skate and catwalk and move to middle of pad for repairs. Spot and rig up Halliburton E-line with pressure control. Make up and run in the hole with 3.5" OD Drift BHA on E-line and run in the hole. Unable to get past 6750'. Made multiple attempts with no progress. Wellbore inclination at 6750' is 73.87°. Discuss with Engineer and attempt to pump down past this depth. Pump at 2 bpm and make multiple attempts with no progress. Toolstring stops at the same point each time with no discernable difference from previous attempts. Decision made to pull out of the hole and forgo the additional perfs. Pull out of the hole and lay down drift assembly. Rig down Halliburton E-line. Nipple down shooting flange and nipple back up spools and flowline. Spot and reinstall catwalk and skate. Mobilize Centrilift equipment and rig up for ESP, M/U Baker Centrilift 5.85" centralizer, Zenith Motor Gauge, 562XP 250/2505/61 motor, tandem seals, Gassep and 538PMSXD Pump to 57'. Centrilift Rep service motor and seal assembly. Install motor lead to pump and M/U ported sub and Bolt on discharge head. SimOps: Start rack and tally 2-7/8" 6.5#, L-80 tubing.,Pick up 1st jt 2- 7/8" 6.5# L-80 tubing & test ESP cable. OHM and MEG tests good. RIH with 2-7/8" 6.5# L-80 ESP completion per program and Baker Centrilift f/ 101' t/ 3129'. Torque connections to 2100 ft/lbs . Install Cannon clamps on 1st 10 joints then every other joint. Test ESP cable at 2000' – Good. 10/20/2021 - Wednesday POOH f/ 10885' t/ 8503' laying down 2-7/8" ESP completion tubing. Add double calculated pipe displacement hole fill every 15 jts. Two personnel from night crew reported not feeling well at end of tour. Sent to Medic for Covid testing: 1 came back positive, 1 negative. Discuss with Anchorage team and MPU Wells Foreman to develop plan for quarantining / monitoring night crew and mitigations. Mobilize tubing hanger back to location to suspend operations while testing remainder of personnel on location. Secure and cut ESP cable. Make up tubing hanger, landing joint and FOSV to string. Land tubing hanger in bowl and secure well. Toolpusher sent to medic for testing. Toolpusher tested negative and returned to rig to watch well while day crew reported to medic for testing. All personnel tested negative. Pull and lay down landing joint and tubing hanger. Rig up to ESP cable per Baker. POOH f/ 8503' t/ surface laying down 2-7/8" ESP completion tubing. Add double calculated pipe displacement hole fill every 15 jts. 370 jts pulled, 2x GLM and XN nipple. 44 joints bad due to damaged threads/overtorque. No excessive corrosion or scale observed, all undamaged tubes reusable. Lay down ESP assembly. Pump locked up. Upper Tandem Seal had contaminated oil, lower Seal to Motor showed clean oil. Total 192 CC cannon clamps, 2x flat clamps and 4x Protectolizers pulled. Clean and clear rig floor. Remove ESP cable trunk. Change out handling equipment to 3-1/2". Mobilize YellowJacket 7" packer to floor. Start Rack and Tally 3-1/2" WorkString. Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 ASR Rig #1 50-029-22636-00-00 195-212 10/18/2021 Future Hilcorp Alaska, LLC Weekly Operations Summary RIH with 2-7/8" 6.5# L-80 ESP completion per program and Baker Centrilift f/ 3129' t/ 7823'. Torque connections to 2100 ft/lbs. Install Cannon clamps on 1st 10 joints then every other joint. Test ESP cable every 2000' until hole inclination greater than 70°. Test ESP cable every 1000' thereafter per Baker Centrilift recommendations for deviated hole. Perform reel-reel ESP cable splice at 7823' and test - Good, Cont. RIH with 2-7/8" 6.5# L-80 ESP completion per program and Baker Centrilift f/ 7823' t/11863'. 36k SOW. Torque connections to 2100 ft/lbs . Install Cannon clamps every other joint. Test Cable every 1000', Make up Hanger with BPV installed. Make up 2-7/8" Landing joint and XO. Centrilift measure, cut cable & Terminate ESP cable to Hanger. 10/24/2021 - Sunday Terminate ESP cable to Hanger w/ BPV pre-installed and land 2-7/8" tubing with ESP completion at 11,901' RILDS and lay down landing joint. Total of 372 joints of 2-7/8", 6.5# EUE tubing, (1) XN assembly, (2) GLM assemblies, 193 Cannon cross- collar clamps, 2 flat clamps and 4 LaSalle clamps (pump neck clamps) ran. 36 klbs SOW on hanger, Rig down ASR rig. Blow down and rig down all lines. Rig down pipe racks, pipe skate and catwalk. Rig down rig floor and pump. Lay over derrick. Move rig off location to A-Pad. Nipple down BOPE: break stack down into individual components for shipping to Yellow Jacket, Nipple up 2-9/16" ESP Tree. Pressure test tubing hanger void to 500/5000 psi - Good test. Centrilift perform final checks - Good test. Pull BPV. Release rig and continue to RDMO all equipment to A-Pad. Rig Released to Storage on A Pad. 10/23/2021 - Saturday _____________________________________________________________________________________ Revised By DH 11/9/2021 SCHEMATIC Milne Point Unit Well: MPU F-14 Last Completed: 10/24/21 PTD: 195-212 TD =12,768’ (MD) / TD = 7,522’(TVD) 20” 7” Short Joint from 12,124 to 12,144’ Orig. KB Elev.:45.45’/ GL Elev.:12’(N27E) RT to Tbg. Spool = 33.45’ (N 27E) 7” 10 9 9-5/8” 1 PBTD =12,663’ (MD) / PBTD = 7,423’(TVD) 2 KUP Sands 3 4 5 6 7 & 8 9 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 110' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 6,690’ 0.0759 7" Production 26 / L-80 / BTC 6.151 Surface 12,749’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5# / L-80 / EUE 8rd 2.441 Surface 11,901’ 0.0058 JEWELRY DETAIL No Depth Item 1139’GLM STA# 2: 2-7/8” GLM w/ Dual Port OV 2 11,699’GLM STA #1:Camco 2-7/8” GLM w/1” Dummy Valve 3 11,789’ 2-7/8” XN Nipple w/ 2.205” No-Go 4 11,842’ Discharge Head: B/O PMP 513 2.87 X 8 EUE 5 11,843’ Pump: 538PMSXD 119 P23 M FER NO_PNT 6 11,861’ Gas Separator: Gas Master Extreme 538GS 7 11,866’ Upper Tandem Seal GSBDB H6 SB/AB PFSA 8 11,873’ Lower Tandem Seal GSBDB H6 SB/AB PFSA 9 11,880’ Motor 562XP 250/2505/61_208/2090 10R 10 11,896 Zenith E7 Motor Gauge 11 11,899’ 6 Fin Centralizer – Bottom @ 11,901’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A Sands 12,334’ 12,414’ 7,113’ 7,188’ 80 3-3/8” Open Ref Log: 2/13/19996: AWS GR/ CCL – 22gm Jumbo Jet charges @ 60° phasing, 0.76” EHD OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 1287 sx PF ‘E’, 250 sx Class ‘G’, 210 sx PF ‘C’ 12-1/4” Hole 7” 325 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 900’ Max Hole Angle = 71° to 75° from 4,800’ – 10,300’ Hole Angle through perf interval = 21° DLS = 4 Deg./100’ @ 10,788’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22636-00-00 Drilled and Cased by Nabors 27E - 1/26/96 ESP Completion by Nabors 4ES - 3/26/1996 RWO ESP by Nabors 4ES - 10/30/2001 RWO ESP by Nabors 3S - 2/14/2006 RWO ESP by Doyon 16 - 12/16/2012 RWO ESP by Doyon 14 – 2/15/2017 RWO ESP by ASR #1 – 10/24/2021 STIMULATION SUMMARY 2/26/96 – 120.7 M lbs. 16/20 sand behind pipe. Pumped design plus excess and got full displacement 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,768'N/A Casing Collapse Conductor N/A Surface 3,090psi 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: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,522'12,663'7,423'2,220 12,663' 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: AOGCC USE ONLY Taylor Wellman twellman@hilcorp.com 907-777-8449 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: N/A and N/A N/A and N/A See Schematic See Schematic 10/20/2021 2-7/8" PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 195-212 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22636-00-00 Hilcorp Alaska LLC MILNE PT UNIT F-14 MILNE POINT / KUPARUK RIVER OIL C.O. 432D 110' 6.5# / L-80 / EUE 8rd TVD Burst 11,901 N/A 5,750psi 7,240psi 4,520' 7,504' 6,690' 12,749' Length Size 110' MD 12,716' Perforation Depth MD (ft): 72' 20" 9-5/8" 7" 6,654' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:33 pm, Oct 13, 2021 321-541 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.10.13 14:24:58 -08'00' David Haakinson (3533) DSR-10/13/21DLB 10/13/2021 X BOPE test to 2500 psi. 10-404 MGR14OCT2021 JLC 10/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.14 21:50:06 -08'00' RBDMS HEW 10/19/2021 ESP Change Out Well: MPU F-14 Well Name:MPU F-14 API Number:50-029-22636-00 Current Status:Oil Well [Failed ESP]Pad:F-Pad Estimated Start Date:October 20, 2021 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:195-212 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Current Bottom Hole Pressure: 1,220 psi @ 6,660’ TVD (SBHPS 10/11/2021 / 3.52 ppg EMW) Maximum Expected BHP:2,886 psi @ 6,660’ TVD (Normally pressured Kuparuk A1B) MPSP:2,220 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-14 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a recent power bump that shut down Milne Point on October 10, 2021. Notes Regarding Wellbore Condition x CO 390A: A packer is not required on this ESP completion as the reservoir pressure of 3.6 ppg EMW is less than 8.55 ppg EMW. x Last CSG Test (6,766’ – surface) 2,500 psi – 12/14/2012 Objective: Pull failed ESP, pressure test casing and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.6 ppg NaCL water down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 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. -00 DLB ESP Change Out Well: MPU F-14 Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 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/ 8.6 ppg NaCl 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 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 joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to the returns tank. Pull TWC. Kill well with 8.6ppg NaCl as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2017 ESP swap was 115 K lbs to free pipe, 105K up wt. after free. The current completion was landed with an up wt of 108k. b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. ESP Change Out Well: MPU F-14 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 failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous tubing runs. 18. PU and run 7” casing scraper to 12,500’ md. During TOOH reciprocate around 10,500’ md. 19. PU test packer and run on 3-1/2” workstring to 10,500’ md. a. TOC in 7” x 8-1/2” OH is 10,501’ md / 5,701’ TVD based on 30% washout. 20. Test casing to 1,500psi for 30 minutes (charted). 21. RU EL and PT PCE to 2,500psi. 22. RIH and perforate the Kuparuk A1B sands from ±12,419’ – ±12,434’ md. a. Roller bogies are suggested as the well reaches 72deg at 4,900’ – 10,200’ md. b. Contact Almas Aitkulov at 979-739-3133 or John Salsbury at 907-350-1088 for correlation confirmation. 23. POOH and RD EL. 24. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ a. Base of ESP at ± 11,890’ MD b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 2 joint of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. ± 363 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 160’ MD with 0.25” OV h. ± 4 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 25. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 26. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: ESP Change Out Well: MPU F-14 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By TDF 3/9/2017 SCHEMATIC Milne Point Unit Well: MPU F-14 Last Completed: 2/15/17 PTD: 195-212 TD =12,768’ (MD) / TD = 7,522’(TVD) 20” 7” Short Joint from 12,124 to 12,144’ Orig. KB Elev.: 45.45’/ GL Elev.: 12’ (N27E) RT to Tbg. Spool = 33.45’ (N 27E) 7” 10 9 9-5/8” 1 PBTD =12,663’ (MD) / PBTD = 7,423’(TVD) 2 KUP Sands 3 4 5 6 7 & 8 9 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 110' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 6,690’ 0.0759 7" Production 26 / L-80 / BTC 6.151 Surface 12,749’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 11,901’ 0.00579 JEWELRY DETAIL No Depth Item 1110’GLM STA# 2: 2-7/8” x 1” GLM w/ SO 2 11,659’GLM STA #1:Camco 2-7/8” x 1” GLM w/DGLV 3 11,802’ 2-7/8” XN Nipple w/2.205” No-Go 4 11,845’ Discharge Head - GPDIS 5 11,845.5 Pump - 119 P23 6 11,863’ Gas Separator - GRS FER N AR 7 11,866’ Upper Tandem Seal - GSB3DB SB/SB PFSA 8 11,873’ Lower Tandem Seal - GSB3DB SB/SB PFSA 9 11,880’ Motor - XP-200 10 11,897 Sensor - WELLlift 11 11,899’ 6 Fin Centralizer –Bottom @ 11,901’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A Sands 12,334’ 12,414’ 7,113’ 7,188’ 80 3-3/8” Open Ref Log: 2/13/19996: AWS GR/ CCL – 22gm Jumbo Jet charges @ 60° phasing, 0.76” EHD OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 1287 sx PF ‘E’, 250 sx Class ‘G’, 210 sx PF ‘C’ 12-1/4” Hole 7” 325 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 900’ Max Hole Angle = 71° to 75° from 4,800’ – 10,300’ Hole Angle through perf interval = 21° DLS = 4 Deg./100’ @ 10,788’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22636-00-00 Drilled and Cased by Nabors 27E - 1/26/96 ESP Completion by Nabors 4ES - 3/26/1996 RWO ESP by Nabors 4ES - 10/30/2001 RWO ESP by Nabors 3S - 2/14/2006 RWO ESP by Doyon 16 - 12/16/2012 RWO ESP by Doyon 14 – 2/15/2017 STIMULATION SUMMARY 2/26/96 – 120.7 M lbs. 16/20 sand behind pipe. Pumped design plus excess and got full displacement _____________________________________________________________________________________ Revised By TDF 10/12/2021 PROPOSED Milne Point Unit Well: MPU F-14 Last Completed: 2/15/17 PTD: 195-212 TD =12,768’ (MD) / TD = 7,522’(TVD) 20” 7” Short Joint from 12,124 to 12,144’ Orig. KB Elev.: 45.45’/ GL Elev.: 12’ (N27E) RT to Tbg. Spool = 33.45’ (N 27E) 7” 10 9 9-5/8” 1 PBTD =12,663’ (MD) / PBTD = 7,423’(TVD) 2 KUP Sands 3 4 5 6 7 & 8 9 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 110' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 6,690’ 0.0759 7" Production 26 / L-80 / BTC 6.151 Surface 12,749’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±11,901’ 0.00579 JEWELRY DETAIL No Depth Item 1 ±110’GLM STA# 2: 2-7/8” x 1” GLM 2 ±11,648’GLM STA #1:Camco 2-7/8” x 1” GLM 3 ±11,791’ 2-7/8” XN Nipple w/ 2.205” No-Go 4 ±11,834’ Discharge Head: 5 ±11,834.5 Pump: 6 ±11,852’ Gas Separator: 7 ±11,855’ Upper Tandem Seal: 8 ±11,862’ Lower Tandem Seal: 9 ±11,869’ Motor: 10 ±11,886 Sensor: 11 ±11,888’ 6 Fin Centralizer – Bottom @ 11,890’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Kup. A Sands 12,334’ 12,414’ 7,113’ 7,188’ 80 3-3/8” Open Kup A1B Sand ±12,419’ ±12,434’ ±7,193’ ±7,207’ ±15 3-3/8” Future Ref Log: 2/13/19996: AWS GR/ CCL – 22gm Jumbo Jet charges @ 60° phasing, 0.76” EHD OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 1287 sx PF ‘E’, 250 sx Class ‘G’, 210 sx PF ‘C’ 12-1/4” Hole 7” 325 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 900’ Max Hole Angle = 71° to 75° from 4,800’ – 10,300’ Hole Angle through perf interval = 21° DLS = 4 Deg./100’ @ 10,788’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22636-00-00 Drilled and Cased by Nabors 27E - 1/26/96 ESP Completion by Nabors 4ES - 3/26/1996 RWO ESP by Nabors 4ES - 10/30/2001 RWO ESP by Nabors 3S - 2/14/2006 RWO ESP by Doyon 16 - 12/16/2012 RWO ESP by Doyon 14 – 2/15/2017 STIMULATION SUMMARY 2/26/96 – 120.7 M lbs. 16/20 sand behind pipe. Pumped design plus excess and got full displacement Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head STATE OF ALASKA ADSKA OIL AND GAS CONSERVATION COSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations Li Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well El Re-enter Susp Well El Other: ESP Swap Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development El Exploratory ❑ 195-212 3.Address: Stratigraphic Service ❑6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22636-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT F-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): I V E N/A MILNE POINT/KUPARUK RIVER OIL RECE 11.Present Well Condition Summary: MAR 1 0 Z{U'7 Total Depth measured 12,768 feet Plugs measured 12,663 feet true vertical 7,522 feet Junk measured N/A feet Effective Depth measured 12,663 feet Packer measured N/A feet true vertical 7,423 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 72' 20" 110' 110' N/A N/A Surface 6,654' 9-5/8" 6,690' 4,520' 5,750psi 3,090psi Production 12,716' 7" 12,749' 7,504' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic `1r, R Jt True Vertical depth See Attached Schematic 117 �C�NNE° .P Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/EUE 8rd 11,901' 6,711' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 660 0 Subsequent to operation: 164 61 1,385 240 250 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 121 Exploratory❑ Development❑ Service ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16.Well Status after work: oil Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ 0 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: 316-592 Contact Paul Chan ` Email pchanCa7hilcorp.com Printed Name /,,//Boo York Title Operations Manager /,:1 �� Signature sC Szr ev /-,14 Phone 777-8345 Date 3/9/2017 7e-" RBDMS tiu MAR 2 2 2017 Form 10-404 Revised 5/2015 ,74- 7 Submit Original Only , ll • • Milne Point Unit Well: MPU F-1a SCHEMATIC Last Completed:2/15/17 llpAlaska .LLCPTD: 195-212 TREE&WELLHEAD Orig.KB Elev.:45.45'/GL Elev.:12'(N27E) Tree Cameron 2-9/16"5M RT to Tbpi Spool=33.45' (N 27E) Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH <' ; L414 Acme on top and 2-7/8"EUE 8rd on bottom,2.5"CIW BPV Profile 20' . OPEN HOLE/CEMENT DETAIL 4t m 20" 250 sx of Arcticset I(Approx)30"Hole 1 04 9-5/8" 1287 sx PF'E',250 sx Class'G',210 sx PF'C'12-1/4"Hole & 7" 325 sx Class'G'8-1/2"Hole CASING DETAIL 14 Size Type Wt/Grade/Conn Drift ID Top Btm BPF i,,; 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' .0355 9-5/8" Surface 40/L-80/BTC 8.679 Surface 6,690' 0.0759 7" Production 26/L-80/BTC 6.151 Surface 12,749' 0.0383 TUBING DETAIL 16 AI il 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 11,901' 0.00579 '= WELL INCLINATION DETAIL `° KOP @ 900' Max Hole Angle=71°to 75°from 4,800'—10,300' : Hole Angle through perf interval=21° ako DLS=4 Deg./100'@ 10,788' € STIMULATION SUMMARY 9-5/8"4 IV 2/26/96-120.7 M lbs.16/20 sand behind pipe. € Pumped design plus excess and got full displacement € JEWELRY DETAIL No Depth Item 1 110' GLM STA#2:2-7/8"x 1"GLM w/SO 2 11,659' GLM STA#1:Camco 2-7/8"x 1"GLM w/DGLV 3 11,802' 2-7/8"XN Nipple w/2.205"No-Go 4 11,845' Discharge Head-GPDIS 5 11,845.5 Pump-119 P23 6 11,863' Gas Separator-GRS FER N AR 2 7 11,866' Upper Tandem Seal-GSB3DB SB/SB PFSA 8 11,873' Lower Tandem Seal-GSB3DB SB/SB PFSA 9 11,880' Motor-XP-200 Vt 10 11,897 Sensor-WELLIift To ,i 3eit 11 11,899' 6 Fin Centralizer— Bottom @ 11,901' In i rotPERFORATION DETAIL I4 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Status 11, Kup.A Sands 12,334' 12,414' 7,113' 7,188' 80 3-3/8" Open 5 Ref tog:2/13/19'996:AWS GR/CEL—22 m Jumbo Jet charges ges 60"phasing 0.76"END III 6 GENERAL WELL INFO ko 788ot, to API:50-029-22636-00-00 Drilled and Cased by Nabors 27E -1/26/96 I ESP Completion by Nabors 4ES-3/26/1996 g RWO ESP by Nabors 4ES-10/30/2001 RWO ESP by Nabors 3S-2/14/2006 V RWO ESP by Doyon 16-12/16/2012 II I)' 10 RWO ESP by Doyon 14—2/15/2017 tii 11 T'Short Joint from 12,124to12,144 44 -i KUP Sands rj TD=12,768'(MD)/TD=7,522'(WD) PBTD=12,663'(MD)/PBTD=7,423'(TVD) Revised By TDF 3/9/2017 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 Doyon 14 50-029-21999-00-00 195-212 2/12/17 2/15/17 Daily Operations: 2/8/2017-Wednesday No activity to report. 2/9/2017-Thursday No activity to report. 2/10/2017- Friday No activity to report. 2/11/2017 Saturday No activity to report. 2/12/2017-Sunday Release the rig from MPU L-03 at 06:00 hrs. Skid Rig Floor into moving position. Move Rig off of L-03. Move small rig mats off of L-03 and transport to F-pad. Move Rig from L-Pad to F-Pad. Spot Rig over F-14. Shim & Level same. Place support boards under Pipeshed. Skid Rig Floor into drilling position. Prep Rig Floor. Prep Cellar for pumping.Take on fluid to Pits. RU Lubricator. Pull BPV. RD Lubricator. NOTE: Accept Rig onto F-14 at 16:00 hrs. Line up to pump, blow air through circulating lines,fill lines w/diesel and test to 1,500psi (good test) Bleed pressure off of IA and TBG to flowback tank. Initial TBG pressure = 50psi, and IA pressure = 650psi. Line up and pump down TBG @ 4.5BPM w/ 1,480psi taking returns out the IA to flowback tank. Good returns seen after 25bbls pumped. Continue to circulate for a total of 530bbls pumped w/410bbls in returns to the flowback tank, FCP= 1640psi @ 4.5BPM. Shut down and monitor well, both TBG and IA on a vac. B/D circ lines. Hilcorp Wellhead Tech's Greg and Johnny on location to set TWC. Hilcorp Wellhead Tech's Greg and Johnny, bleed down hanger void, N/D production tree, secure tree in cellar, function LDS, plug hanger penetrators, M/U crossover to hanger threads and verify how many turns to M/U. N/U 7-1/6" x 13-5/8" adapter spool, N/U 13-5/8" x 13-5/8" spacer spool, N/U BOPE, install kill and choke lines. Continue to N/U BOPE stack, install riser, mouse hole, measure RKB.Slip and cut 60' of drilling line, inspect breaks/saver sub/deadman anchor brass. R/U to test BOPE.Test BOPE to 250psi low f/5 charted mins, 3,000psi high f/5 charted mins w/2-7/8" test joint as per Doyon 14 BOPE test procedure.AOGCC rep Guy Cook waived witness to testing @ 3:19pm on 2/12/17. . � • o Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 Doyon 14 50-029-21999-00-00 195-212 2/12/17 2/15/17 Daily'Operations: ' n' At. 1 2/13/2017- Monday Continue to test BOPE to 250psi low f/5 charted mins, 3,000psi high f/5 charted mins w/2-7/8" test joint as per Doyon 14 BOPE test procedure.AOGCC rep Guy Cook waived witness to testing @ 3:19pm on 2/12/17. RD test equipment. Blow down lines. RU T-Bar. Wellhead Rep dry rod out TWC. PU Landing joint&XO. Engage hanger. Screw in Top Drive. Pull hanger w 1 g / 15k. Pull hanger to rig floor w/105k. Fill IA(23 bbls to fill). LD hanger and landing joint. M/U ESP cable splice, U Centrilift/ in preparation for pulling ESP completion, L/D hanger. POOH w/ ESP completion on 2-7/8" EUE 6.5# L- 80 tubing, racking stands back in the derrick f/12,046'md to 61'md. PUW= 105kIbs, SOW=90klbs. Remove cannon clamps every other joint, drop 2.32" drift w/100'tail @ 12,046'md, drift found in XN nipple. Cut ESP cable at motor assembly, spool ESP cable back on ESP spool in spooling unit, drain ESP motor, L/D ESP completion. Clean and clear rig floor of clamps and hardware. 200 Cannon clamps recovered, 2 half clamps, 5 protectrolizers, 3 flat guards. Continue to clear rig floor of Cannon clamps and hardware, stage new cannon clamps on floor, C/O ESP cable reels in spooling unit, pull new ESP cable over sheave. M/U ESP motor/pump assembly,fill w/CL-5 oil.Tie in ESP MLE, and clamp, RIH to 97'md and test ESP for conductivity. 2/14/2017-Tuesday RIH w/ESP completion on 2-7/8" 6.5# EUE tubing f/Derrick. f/66'to 8,188' (85 stands in). Add Cannon Clamps on every joint for first 10 joints and every other joint after.Test for cable conductivity at±500' and every±1,000' after. Perform ESP cable splice at 8,188'. Clean rig floor, test ESP splice (good test) Continue to RIH w/ESP completion on 2-7/8" 6.5#EUE tubing f/Derrick.f/8,188'md to 9,902'md, installing clamps every other joint,testing ESP cable every 1,000'md Run out of ESP cable on spliced spool, locate new spool, load in spooling unit, perform reel to reel splice of ESP cable. Clean rig. Continue to RIH w/ESP completion on 2-7/8" 6.5# EUE tubing f/Derrick. f/9,902'md to 11,868'md, installing clamps every other joint, testing ESP cable every 1,000'md. PUW= 108klbs, SOW= 72klbs, M/U torque= 2,250ft-lbs. Test ESP cable prior to cutting(good test) Hilcorp wellhead tech Dean and Johnny on location to M/U and orient TBG hanger, Baker Centrilift perfrom ESP penetrator splice. SIMOPS: remove GBR handling equipment, R/D and remove Centrilift equipment from rig floor. Land TBG hanger, B/O landing joint and L/D, set BPV. N/D BOPE • 11) Hilcorp Alaska, LLC 4 Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-14 Doyon 14 50-029-21999-00-00 195-212 2/12/17 2/15/17 Daily Operations: 2/15/2017 -Wednesday ND BOP and stand back. NU Tree. Well head Rep test tree to 500 psi low (5 min), 5,000 high (15 min). Good test. Pull BPV. Centrilift Rep. perform final checks- Good. Secure tree.Tubing=0 psi- IA=0 psi -OA= 200 psi. NOTE: Release rig at 09:00 on 2/15/17. Prep rig floor&skid same to moving position. Pull rig off F-14 and spot on pad. Install Boosters on rig. NOTE: LRS freeze protected F-14 down IA and tubing w/diesel to 2,000'. 2/16/2017-Thursday No activity to report. 2/17/2017 - Friday No activity to report. 2/18/2017 -Saturday No activity to report. 2/19/2017-Sunday No activity to report. 2/20/2017 - Monday No activity to report. 2/21/2017-Tuesday No activity to report. y of Tit • 4wa�� Iyyy THE STATE Alaska Oil and Gas ,4,, -.1,i--.-....7,A,; o f T q Conservation Commission ALtl�� . t . ;£i 333 West Seventh Avenue + "' Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 L 5' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York scAtita FEB 27 2017. Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-14 Permit to Drill Number: 195-212 Sundry Number: 316-592 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, Cathy I . Foerster /e--L-- Chair DATED this23 day of November, 2016. RBDMS uL/ NOV 2 8 2816 / e r E STATE OF ALASKA NOV 17 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 117S- M../ Z 'C jeL 20 AAC 25.280 :0 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well E• Operations shutdown El Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing Q. . Change Approved Program El Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: ESP Swap Mi 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory El Development D, 195-212 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-029-22636-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D I Will planned perforations require a spacing exception? Yes 0 No ❑ / MILNE PT UNIT KR F-14 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355018 . 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): 12,768' , 7,522' ` 12,663' ' 7,423' 2,498 12,663' N/A Casing Length Size MD TVD Burst Collapse Conductor 72' 20" 110' 110' N/A N/A Surface 6,654' 9-5/8" 6,690' 4,520' 5,750psi 3,090psi Production 12,716' 7" 12,749' 7,504' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic 4 See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 12,110 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A - 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑;' Service El 14.Estimated Date for 15.Well Status after proposed work: 12/6/2016 ❑ 0 WDSPL ❑ Suspended 0 Commencing Operations: OIL , WINJ 16.Verbal Approval: Date: GAS El WAG El GSTOR El 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. Contact Paul Chan t , Email pchant7a.hilcorp.corn Printed Name Bo York Title Operations Manager Signatures \. Phone 777-8345 Date 11/16/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -kck— �92 Plug Integrity El BOP Test Mechanical Integrity Test El Location Clearance ❑ Other: � o rs t. fs c.!" / �s. El Post Initial Injection MIT Req'd? Yes ❑ No ❑ 11, 11:31k . Spacing Exception Required? Yes ❑ No ❑/ Subsequent Form Required: /0 ,-Yv` APPROVED BY Approved by: P _ COMMISSIONER THE COMMISSION Date: /1 2,3 / 1) iiii0C- c (� A ' A Lalid Submit Form and Form 10-403 Revised 11/2015 ORpic tl Ip6Rda1� for 12 months from the date of pproval. Attachments in Duplicate `��iiiLJtt1l �l ///"""111 ` ` (7b Well Prognosis Well: MPU F-14 Hileorp Alaska,LU Date:11/16/2016 Well Name: MPU F-14 API Number: 50-029-22636-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: December 7th, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-212 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: ESP Repair Current Bottom Hole Pressure: 3,198 psi @ 7,000'ND (SBHPS 11/13/2016/8.80 ppg EMW) Maximum Expected BHP: 3,198 psi @ 7,000' ND (No new perfs being added) MPSP: 2,498 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-14 was drilled in January 1996 and completed in March 1996 as a Kuparuk River producer. ESP installation history: March 1996 (initial),October 2001, February 2006, and December 2012. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing tested to 2,500 psi on 12/14/2012 down to 6,766' MD. • As per CO 390A,an ESP packer will be run as part of the completion. J51. Objective: Replace failed ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 9.2 ppg NaCI/KCI brine down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. 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/9.2 ppg NaCI/KCI brine prior to pulling BPV. Set TWC. • • Well Prognosis Well: MPU F-14 Hilcorp Alaska,LL, Date:11/16/2016 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 to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor 1 the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking (7," �� 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/9.2 ppg NaCI/KCI brine 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. (includes 40K block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. c. Contingency Casing Jack Procedure: If the tubing hanger will not come off seat or the ESP will not come off bottom after circulating lubricant, RU casing jacks as follows: i. PU Casing Jacks via the beaver slide and Tugger winches to rig floor ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. iii. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point iv. 100%Yield strength of 2-7/8", 6.5#, L-80= 145K lbs v. Cycle jacks up and down to ensure proper function (dry run without being connected to 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 failed ESP. • • Well Prognosis Well: MPU F-14 Hilcora Alaska,LI) Date:11/16/2016 a. Replace bad joints of tubing as necessary and note on tally. b. Caliper run c. Look for over-torqued connections from previous Doyon 16 tubing runs. 18. PU & RIH with 7" 26#scraper assembly to^2700' MD on workstring. Reciprocate scraper across packer setting depth of 2500' MD. Circulate the well clean. 19. POOH. L/D scraper assembly and workstring. 20. RU control line spooler. PU new ESP and RIH on 2-7/8"tubing. Set base of ESP at±11,915' MD. a. GLM #4 @ ± 141' MD w/SO b. GLM#3 @ ±2450' MD w/SO c. ESP Packer w/annular vent valve @ ±2,500' MD d. X profile @ ±2,550' MD w/RHC ball catcher e. GLM#2 @ ±2,600' MD f. GLM#1 @ ±11,651' MD g. 2-7/8" XN Nipple @ ±11,805'MD h. Base of ESP @ ± 11,915' MD 21. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off)weights on tally. ,22. Freeze protect IA. Drop ball/rod and set ESP packer. Pressure test IA to 1000 psi for 10 minutes. 23. Freeze protect tubing. Note: This step may be done as part of the t-"ri p ocedure. 24. Lay down landing joint. 25. Set BPV. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Wellhead/tree schematic 5. Blank RWO MOC Form • • Milne Point Unit II PROPOSED Well: MPU F-14 Last Completed: Hilcorp Alaska,Elk PTD: 195-212 TREE&WELLHEAD Orig.KB Elev.:45.45'/GL Elev.:12'(N27E) Tree Cameron 2-9/16"5M 20" RT to Tb&Spool=33.45' (N 27E) 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH r Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"CIW BPV Profile OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(Approx)30"Hole , fil 1 1 9-5/8" 1287 sx PF'E',250 sx Class'G',210 sx PF'C'12-1/4"Hole 7" 325 sx Class'G'8-1/2"Hole CASING DETAIL size Type Wt/Grade/Conn Drift ID Ton Btm BPF Iffi I 2 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' .0355 3 k' ?� ll , 9-5/8" Surface 40/L-80/BTC 8.679 Surface 6,690' 0.0759 c 7" Production 26/L-80/BTC 6.151 Surface 12,749' 0.0383 4 TUBING DETAIL 6.5/L-80/EUE 8rd I 2._ 11,915' 0.00579 5 WELL INCLINATION DETAIL KOP @ 900' Max Hole Angle=71°to 75°from 4,800'—10,300' Hole Angle through perf interval=21' DLS=4 Deg./100'@ 10,788' STIMULATION SUMMARY 95/8" 4 Oh 2/26/96-120.7 M lbs.16/20 sand behind pipe. Pumped design plus excess and got full displacement JEWELRY DETAIL No Depth Item 1 ±140' GLM STA#4:2-7/8"x 1"GLM 2 ±2,450' GLM STA#3:2-7/8"x 1"GLM 3 ±2,500' ESP Packer w/Annular Vent Val, 4 +2,550' X profile w/RHC ball catcher 5 -c"' cl_M STA#2:2-7/8"x 1"'_ ".' 6 M STA#1:2-7/8"x 1 6 7 _11,805' 2-7/8"XN-Nipple(2.205"No-Go; 8 .11,915' Base of ESP e, t° 7 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Status Kup.A Sands 12,334' 12,414' 7,113' 7,188' 80 3-3/8" Open Ref Log: 2/13/19996:AWS OR/CCL—22gm Jumbo Jet charges @ 60°phasing,0.76"EHD tx GENERAL WELL INFO API:50-029-22636-00-00 ` Drilled and Cased by Nabors 27E -1/26/96 ' ` r ESP Completion by Nabors 4ES-3/26/1996 RWO ESP by Nabors 4ES-10/30/2001 RWO ESP by Nabors 3S-2/14/2006 8 RWO ESP by Doyon 16-12/16/2012 7"Short Joint from 12,124 to 12,144' .----E----KUP Sands 7"A 11' TD=12,768'(MD)/TD=7,522'(1VD) PBTD=12,663'(MD)/PBTD=7,4231TVD) Revised By PC 11/22/2016 • Well Prognosis Well: MPU F-14 Hilcorp Alaska,LL Date: 11/16/2016 Well Name: MPU F-14 API Number: 50-029-22636-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: December 7th, 2016 Rig: ASR Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 95-212 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) _ Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: ESP Repair Current Bottom Hole Pressure: 3,198 psi @ 7,000' TVD (SBHPS 11/13/2016/8.80 ppg EMW) Maximum Expected BHP: 3,198 psi @ 7,000' TVD (No new perfs being added) ✓ MPSP: 2,498 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-14 was drilled in January 1996 and completed in M. ch 1996 as a Kuparuk River producer. ESP installation history: March 1996 (initial), October 2001, F-bruary 2006, and December 2012. The ESP has failed. • Notes Regarding Wellbore Condition • The 7" production casing tested to 2, 10 psi on 12/14/2012 down to 6,766' MD. • The current reservoir pressure is :.80 ppg EMW from the November 13, 2016 static pressure survey and has increased from the Ma 016 survey due to: o No offtake from the • F-14 location V o Continu- • °n°ectionto offs- , • MP F-26. MP F-26 injection rate was reduced when the F-14 ESP failed. • Reservoir pressure hist. y:2013 to November 13, 2016 o ESP pump pre.sure of 6.8 ppg was read on August 5,2013 o ESP failure: April 30,2016 o Static bottom hole pressure survey of 6.99 ppg was measured on May 10,2016 o Static bottom hole pressure survey of 8.80 ppg was measured on November 13,2016 • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion. Hilcorp Alaska will manage the reservoir pressure to be below 8.55 ppg by adjusting the offtake and injection support for the producer injector pair(MP F-14 and MP F-26, respectively)as demonstratedn y by the reservoir pressure history from 2013 to 2106. e„:„.' �O"" � Objective: L.J- (Le- 4e' Replace failed ESP. 031 P 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. II • • Well Prognosis Well: MPU F-14 I3ilcorp Alaska.Li) Date: 11/16/2016 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 9.2 ppg NaCI/KCI brine down tubing,taking re ns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or esel. 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. Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 0 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed o any residual pressure off tubing and casing. If needed, kill well w/9.2 ppg NaCI/KCI brine pri to pulling BPV. Set TWC. etc',:, Q 12. Test BOPE to 250 psi Low/t.3,580'�si igh, annular to 2 0 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator ire-charge pressures and chart tests. flP a. Perform Test per ASR 1 BOP Test Procedur- sated 11/03/2015. b. Notify AOGCC 24 hours in advance of BO' test. c. Confirm test pressures per the Sundry onditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10 24 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger on't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corrode. 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 well,ead situation prior to performing the rolling test. AOGCC may elect to send an inspector to itness test. b. With stack out of the est path, test choke manifold per standard procedure �� c. Conduct a rolling te.t: Test the rams and annular with the pump continuing to pump, (monitor y►� the surface equip ent for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surf.ce.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record he pumping rate and pressure. e. Once the B ram and annular tests are completed,test the remainder of the system following the normal est procedure (floor valves, gas detection, etc.) f. Record ar 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/9.2 ppg NaCI/KCI brine 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. (includes 40K block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. c. Contingency Casing Jack Procedure: If the tubing hanger will not come off seat or the ESP will not come off bottom after circulating lubricant, RU casing jacks as follows: a7/1` 1,.5Vk • • Well Prognosis Well: MPU F-14 Hilcarp Alaska,LL" Date:11/16/2016 i. PU Casing Jacks via the beaver slide and Tugger winches to rig floor ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. iii. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pre :ure relief high point r iv. 100%Yield strength of 2-7/8", 6.5#, L-80= 145K lbs v. Cycle jacks up and down to ensure proper function (dr un without being connected to hanger). 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new ha ger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. T- t 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 ?6G down failed ESP. p� a. Replace bad joints of tubing as necessary a . note on tally. b. Caliper run c. Look for over-torqued connections fro' previous Doyon 16 tubing runs. 18. PU new ESP and RIH on 2-7/8"tubing. Set b.se of ESP at± 11,915' MD. a. Upper GLM @ ± 141' MD w/SO • b. Lower GLM @ ±11,653' MD c. 2-7/8" XN Nipple @ ±11,807'MD d. Base of ESP @ ± 11,915' MD 19. Land tubing hanger. RILDS. Lay ►own 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 ouse. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" ,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 560 bbl returns tank and rig mats to next well location. 25. Replace gauge(s if removed. 26. Turn well over o production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Wellhead/tree schematic 5. Blank RWO MOC Form • II 4111 Milne Point Unit Well: MPU F-14 Last Completed: SCHEMATIC >« _,��•LLC PTD: 195-212 TREE&WELLHEAD Orig.KB Elev.:45.45'/GL Elev.:12'(N27E) Tree Cameron 2-9/16"5M RT to Tbk Spool=33.45' (N 27E) 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH 204 "4 « Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"CIW BPV Profile g OPEN HOLE/CEMENT DETAIL ; 20" 250 sx of Arcticset I(Approx)30"Hole Lli 1 Itt 9-5/8" 1287 sx PF'E',250 sx Class'G',210 sx PF'C'12-1/4"Hole 7" 325 sx Class'G'8-1/2"Hole V i 04 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF t 20" Conductor 91.1/NT8OLHE/N/A N/A Su e 110' .0355 is 9-5/8" Surface 40/L-80/BTC 8.679 .rface 6,690' 0.0759 1a7" Production 26/L-80/BTC 6.151 Surface 12,749' 0.0383 ,' TUBING DETAIL tl 2-7/8" Tubing 6.5/L-80/EUE 8rd 47 Surf 12,110' 1 0.00579 ot„ WELL INCLINATI0 DETAIL KOP @ 900' if Max Hole Angle=71° 75°from 4,800'—10,300' Hole Angle through .erf interval=21° DLS=4 Deg./101'@ 10,788' ,,, S ST ULATION SUMMARY 9-5/8" A le' 2/26/96— 0.7 M lbs.16/20 sand behind pipe. Pumped .esign plus excess and got full displacement JEWELRY DETAIL No Depth Item 1 141' GLM STA#2:2-7/8"x 1"KBMM w/DPSOV 11,846' GLM STA#1:2-7/8"x 1"KBMM w/Dummy 3 12,000' 2-7/8"XN-Nipple(2.250 No-go ID) 4 12,042' _ WeIILift Discharge Gauge Unit 5 12,046.7' Discharge Head:GPDIS 2 6 12,047' Pump:119-P23 7 12,065' Gas Separator:GRSFTX AR H6(400 internals) ik 8 12,070' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 9 12,076' Lower Tandem Seal:GSB3DBLT SB/SB PFSA r. „; 10 12,083' Motor:MSP1—294Hp/2,315V/77A 3 11 12,106' Sensor:WeIILift MGU 12 12,108' Centralizer—Bottom @12,110' I 5 PERFORATION DETAIL 6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Status Kup.A Sands 12,334' 12,414' 7,113' 7,188' 80 3-3/8" Open 7 Ref Log: 2/13/19996:AWS GR/CCL-22gm Jumbo Jet charges @ 60"phasing,0.76"EHD Ii 8&9 GENERAL WELL INFO r API:50-029-22636-00-00 Drilled and Cased by Nabors 27E -1/26/96 \'n 10 ESP Completion by Nabors 4ES-3/26/1996 LtRWO ESP by Nabors 4ES-10/30/2001 11&12 RWO ESP by Nabors 3S-2/14/2006 RWO ESP by Doyon 16-12/16/2012 7"Short Joints from :,, 12,124 to 12,144' °x AlKUP Sands 7'j a( TD=12,768'(MD)/TD=7,522'(TVD) PBTD=12,663'(MD)/PBTD=7,423'(TVD) Revised By TDF 11/16/2016 • • Milne Point Unit PROPOSED Hilcory Alaska,LLC Well: MPU F-14 Last Completed: PTD: 195-212 TREE&WELLHEAD Orig.KB Elev.:45.45'/GL Elev.:12'(N27E) Tree Cameron 2-9/16"5M RT toTbg,Spool=33.45' (N 27E) 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH ( 3 Wellhead Acme on top and 2-7/8"EUE 8rd on bottom,2.5"CIW BPV Profile 14 20' OPEN HOLE/CEMENT DETAIL ti / 20" 250 sx of Arcticset I(Approx)30"Hole 1 9-5/8" 1287 sx PF'E',250 sx Class'G',210 sx PF'C'12-1/4"Hole 4; +I~. 7" 325 sx Class'G'8-1/2"Hole IA A i*- CASING DETAIL K 64 Size Type Wt/Grade/Conn Drift ID Top Btm BPF if. 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' .0355 9-5/8" Surface 40/L-80/BTC 8.679 Surface 6,690' 0.0759 « 7" Production 26/L-80/BTC 6.151 Surface 12,749' 0.0383 is TUBING DETAIL rii 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf ±11,915' 0.00579 /- WELL INCLINATION DETAIL KOP@900' Max Hole Angle=71°to 75°from 4,800'—10,300' +$' Hole Angle through perf interval=21° DLS=4 Deg./100'@ 10,788' STIMULATION SUMMARY 9-5/8"'• IL 2/26/96—120.7 M lbs.16/20 sand behind pipe. Pumped design plus excess and got full displacement JEWELRY DETAIL No Depth Item 1 ±141' GLM STA#2:2-7/8"x 1"KBMM w/DPSOV 2 ±11,653' GLM STA#1:2-7/8"x 1"KBMM w/Dummy 3 ±11,807' 2-7/8"XN-Nipple(2.250 No-go ID) 4 ±11,837' WeIILift Discharge Gauge Unit 5 ±11,841' Discharge Head:GPDIS 6 ±11,842' Pump:119-P23 2 7 ±11,860' _ Gas Separator:GRSFTX AR H6(400 internals) 8 ±11,875' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 9 ±11,881' Lower Tandem Seal:GSB3DBLT SB/SB PFSA 10 ±11,888' _ Motor:MSP1—294Hp/2,315V/77A 3 11 ±11,911' Sensor:WeIILift MGU II 12 ±11,913' Centralizer—Bottom @±11,915' 4 5 PERFORATION DETAIL 6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Status Kup.A Sands 12,334' 12,414' 7,113' 7,188' 80 3-3/8" Open 7 Ref Log: 2/13/19996:AWS GR/CCL—22gm Jumbo Jet charges @ 60°phasing,0.76"EHD Ii , s&9 GENERAL WELL INFO r API:50-029-22636-00-00 it ` Drilled and Cased by Nabors 27E -1/26/96 _ 10 ESP Completion by Nabors 4ES-3/26/1996 _ RWO ESP by Nabors 4ES-10/30/2001 .11&12 RWO ESP by Nabors 3S-2/14/2006 RWO ESP by Doyon 16-12/16/2012 7"Short Joint from ,',* 1 12,124 to 12,144' irk 40 P. *:KUP Sands i" 7' "; TD=12,768'(MD)/TD=7,522'(TVD) PBTD=12,663'(MD)/PBTD=7,423'(TVD) Revised By TDF 11/16/2016 • • I II Milne Point ASR Rig 1 BOPE ttikorp 41404a.LIR: 11" BOPE \ Stripping in Head / . 1 3.98' Shaffer 11"_ 5000 ltl lit OHM! II i I in illI . , CI i -U ; '" 4.54' °� , .,- VBR or Pipe Rams ,m 11" 5000 � �.: Blind t. illi°r lotAMMfflirammenswx di lil lit tit Iii 2 1/16 5M Kill Line Valves A 21/16 5M Choke Line Valves o Il1.1'" i ill iii , ,� - , 2.00 14,076, 1 i : fg i c, Manual Manual Manual HCR Updated 8/19/2015 • I 11 EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Ilileorp Alaska,LU: Tree Cap Aiiiii as^is. co, 0 Tree Valve 2-9/16" 5M u. Tree Cross 2-9/16" 5M O(°)0) Tree Valve 2-9/16" 5M SSV 2-9/16" 5M O 0 0, Heat Trace Tree Valve 2-9/16"' 5M '(o.i O0- ESP Cable ► ,��"�, Tubing Adapter ....rinal . , 1 JR= -•., Tubing Head Ili— ! poi 11'" 5M Top x 11" 5M Btm �= iso I 11111 1 1 Ai /IllllAi :) �� lei li MI 111 'I- Casing Head , t 11" 5M Top x 11" 5M Btm ��1��� � gnu �� ����` )4.1 D . • 0 1121 -o > @ > > @ @ O 0 F13 73 R 0 17 r 7 a q2 Q 2 .. O a. 1-0 Nt 0 0 / n 2 $ � © fg g o > CD CD = = CD 0 IT cp == o\ - ■a) D �= 0 -1 7 0 g 7f p CO k X/ \ - n § � E O � - \ § �. K, 0. co / or� k x. 5o CD 2 C m ] 3 CD § % / 0 C 0 o) ƒ \ c � o_ n « ■ a) — 0 \/ ' ° 2 0_ 0 - CD / 0 c a * CD » r m / /k vco g co E § � "0 .0f ^ M" I e-0 J13 > � 8 � CX / O Ec CE al > /Q ^2 = 6 \ M. q7 � � 3CD § ] / § 2 D n C. aa0 / _ 00 = E § CO n 52 / 0.Oct CD ■ Zf ( C Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //--] ~,~- ~)~','~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages.~'~..~ Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other COMMENTS: Scanned by:~Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Be~edy Dianna Vincent Nathan Lowell Date: /si • STATE OF ALASKA A•KA OIL AND GAS CONSERVATION C•ISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS JAN 0 9 2013 1. Operations Performed: GCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ 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. ❑ Exploratory ❑ Stratigraphic r 195 - 212 3. Address: ® Development ❑ Service 6. API Numbe" P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 22636 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: - ADL 355018 - MPF - 14 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: Total depth: measured 12768 feet Plugs:(measured) None feet true vertical 7522 feet Junk: (measured) None feet Effective depth: measured 12663 feet Packer: (measured) None feet true vertical 7423 feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 110' 110' 1490 470 Surface 6654' 9 -5/8" 6690' 4520' 5750 3090 Intermediate Production 12716' 7" 12749' 7504' 7240 5410 Liner SCANNED JAN 16 2013 Perforation Depth: Measured Depth: 12334' - 12414' feet True Vertical Depth: 7113' - 7188' feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 12110' 6904' Packers and SSSV (type, measured and true vertical depth): None 4„,„,„, j. V No ne None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 202 83 848 320 251 Subsequent to operation: 204 87 1266 200 236 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ¢ ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service IN Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: " ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 Email: David.Bjork @bp.com N/A Printed N - - Joe La a Title: Drilling Technologist Signature: ` JAN 1 g P � h t o � ne: 564 -4091 Date: i /q 115 _A U i11W Form 10 -404 Re 10/2012 �� JA N Submit Ori 9 inalOnl Only • • a m Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00X0E- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:00AM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 12/11/2012 06:00 - 10:00 4.00 MOB N WAIT PRE PJSM, MOVE RIG FROM MPF -61 TO MPF -14 WEATHER RELATED OPERATIONAL NOTE: - AS OF 4:00, AMBIENT TEMP IS - 42 DEGREES - WELL SUPPORT WAS SCHEDULED TO INSTALL BPV ON MPF -14 PRIOR TO US MOVING ON THE WELL - THEY WERE UN -ABLE TO COMPLETE THE JOB THAT THEY WERE ON AND MOVE TO MPF -14, BECAUSE OF THEIR BOOM TRUCK COLD WEATHER RESTRICTIONS - AS SOON AS THE TEMP FALLS WITHIN THEIR GUIDLINES, THEY WILL RIG DOWN, MOVE TO MPF -14 AND INSTALL BPV 10:00 - 12:30 2.50 MOB P PRE PJSM, RIG MOVE. - LAY MATS ON MPF -14. _ -( -35 DEG) -46 DEG WIND CHILL. 12:30 - 16:00 3.50 MOB P PRE NOTIFY PAD OPS OF PULL OFF MPF -61. - TEST ESD. - JOCKEY TO MOVE OFF WELL ON MATS STACKED TWO HIGH. - WSL / DDI SUPT / TOOL PUSHER PRESENT. MOVE AROUND PAD. - LAY SECOND LAYER OF MATS ON MPF -14. - STAGE KILL SKID AND EQUIPMENT BEHIND WELL. -SPOT RIG OVER MPF -14 - LEVEL RIG. - AOGCC INSPECTOR L. GRIMALDI WAIVED STATES RIGHT OF WITNESS BY E -MAIL @ 15:28 HRS. 16:00 - 18:00 2.00 MOB P PRE -SPOT CREW AND FUEL TRAILERS - SET CUTTINGS BOX AND WINTERIZE CELLAR - TAKE ON FLUID IN MUD PITS - RIG ACCEPTED AT 18:00 HRS 18:00 - 22:00 4.00 WHSUR P DECOMP - RIG UP CIRCULATING LINES / CELLAR CHOKE MANIFOLD TO FLOW BACK TANK - PRESSURE TEST 250/3500 PSI 22:00 - 00:00 2.00 WHSUR P DECOMP -R/U DSM LUBRICATOR AND TEST 250 / 3500 PSI. -PULL BPV -OA = 80 PSI -IA = 820 PSI -TBG = 480 PSI 12/12/2012 00:00 - 00:30 0.50 WHSUR P DECOMP PJSM, CREW CHANGE. - UD DSM LUBRICATOR. - SECURE ALL TREE VALVES. Printed 12/26/2012 9:57:43AM WS: :J �` 4 V ,,, "Vy'VelZ1V.eiii0e4gititgree4 , c4-4-Xv%$4,Vr,.. 40," ,a r em° �� Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- OOXOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 00:30 06:00 5.50 WHSUR P DECOMP WAIT FOR DAY LIGHT WELL KILL. - CLEAN RIG. - PERFORM GENERAL MAINTENANCE. RIG EVAC DRILL WITH NIGHT CREW -AAR: DISCUSSED DDI RIG EVAC PROCEDURE: COLD WEATHER CONDITIONS AND NEW MEMBER OF THE CREW ROLLS AND RESPONSIBILITIES. 06:00 06:45 0.75 WHSUR P DECOMP PJSM ON WELL KILL. WSL. TOOLPUSHER, RWO ENGINEER, RIG CREW, MI ENGINEER AND CH2 VAC TRUCK DRIVERS IN ATTENDANCE. - REVIEWED DDI WELL KILL SOP AND COLD WEATHER OPS. Printed 12/26/2012 9:57:43AM „ a . �; ,. .. ... ... .. ,,. . _ _ s . xxx yr p• • • • Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00XOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:45 - 11:30 4.75 WHSUR P DECOMP WELL KILL WITH 9.7 PPG HEATED BRINE.. - WSL / TOOL PUSHER VERIFY VALVE ALIGNMENT. - SITP = 440 PSI, SICP = 900 SIOA = 80 PSI - PUMPED 70 BBLS 120 DEG. 9.7 PPG BRINE AT 3 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. - ICP = 650 PSI - FCP = 650 PSI - BULL HEAD 30 BBLS DOWN THE TBG AT 3 BPM / 1100 - 1600 PSI. MONITOR . - SITP AFTER 5 MINUTE = 300 PSI. PUMPED 70 BBLS 120 DEG. 9.7 PPG BRINE AT 5 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. - ICP = 3 BPM / 1000 PSI. 5 BPM / 2000 PSI. - PUMPED 530 BBLS KWF AT 5 BPM AND STARTED TO GET 8 PPG FORMATION WATER IN RETURNS. - AFTER PUMPING 140 BBLS KWF. NOTIFY TOWN RWO ENGR. - BLOW DOWN HARD LINE TO VERIFY NO ICE PLUG - SHUT IN WELL WHILE VAC OUT FLOW BACK TANK. - TBG ON A VACUUM AND SICP / 450 PSI. - CONTINUE CIRCULATING 5 BPM / 1850 PSI. - 9.7 PPG BRINE AT SURFACE AFTER PUMPING 380 BBLS - 530 TOTAL BBLS PUMPED. FCP =1890 PSI - SITP = SLIGHT VACUUM. IA = LESS THAN 15 PSI.. SHUT IN AND MONITOR FOR 30 MINUTES. - TBG AND IA ON A VACUUM. - TOTAL LOSSES DURING WELL KILL - 30 BBLS BULLHEAD PLUS 105 BBLS - —160 BBL CRUDE OIL SENT TO RECYCLE. CPF -1 EXPERIENCED MINOR CHOKE RESTRICTION. - WHEN THE CHOKE SKID WAS R/D - OBSERVED DEBRIS DOWN STREAM SIDE OF CHOKE. - 2” CHOKE SENT TO PBU VALVE SHOP. 11:30 - 13:00 1.50 WHSUR P DECOMP PJSM, P/U DSM LUBRICATOR. - PRESSURE TEST LUBRICATOR 250 / 3500 PSI FOR 5 CHARTED MINUTES. PASSED. - INSTALL TWC. - L/D DSM LUBRICATOR. 13:00 - 13:15 0.25 WHSUR P DECOMP PJSM N/U BOP. - R/U SECONDARY KILL LINE TO FILL THE ANNULUS DURING N/D. Printed 12/26/2012 9:57:43AM , ' -_ `�:' sr . 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'e f y'. a- a # .fi r r"a ,�, 'aF"+ tt''�' " c` v �`� r dry m; S Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00XOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:15 - 14:00 0.75 WHSUR P DECOMP PJSM, PRESSURE TEST TWC. - PUMP 20 BBLS TO FILL IA. - PERFORM ROLLING TEST FROM BELOW. - PUMP 12 SPM (1.02 BPM) AT 520 PSI FOR 10 CHARTED MINUTES. PASSED. - TEST FROM ABOVE 250 / 3500 PSI FOR 5 CHARTED MINUTES. PASSED. 14:00 - 14:30 0.50 WHSUR P DECOMP PJSM, BLOWN DOWN KILL LINES. - R/D CELLAR CHOKE MANIFOLD AND KILL LINES. 14:30 - 15:30 1.00 WHSUR P DECOMP PJSM, N/D 2- 9/16" 5M PRODUCT IN TREE. - N/D TREE. - FMC REP INSPECT / CLEAN HANGER / THREADS. _ - 3" L.H. ACME W/ 6 TURNS BY HAND. 15:30 - 17:00 1.50 BOPSUR P DECOMP PJSM, N/U 13 -5/8" 5M BOPE. - M/U 13 -5/8" 5M BY 7 -/16" 5M SPOOL ADAPTER. - N/U BOP STACK. - R/U TURNBUCKLES AND SAFETY LINES. _ - MAKE -UP KOOMEY HOSES. 17:00 - 00:00 7.00 BOPSUB P DECOMP PJSM, TESTING BOPE EQUIPMENT � -R/U 2 7/8" AND 4" TEST EQUIPMENT W �` - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES 1 - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST UPPER AND LOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN • TEST. - NO FAILURES. - LOU GRIMAIDI OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST - MAINTAIN CONTINUOUS HOLE FILL TO THE IA AT 12 -8 BPH DURING TEST. - LOSSES TO WELL 79 BBLS TOTAL LOSS TO THE WELL 299 BBLS 12/13/2012 00:00 - 01:30 1.50 BOPSUB P DECOMP - CONTINUE TESTING BOPE 250/3500 PSI - ACCUMULATOR DRAW DOWN TEST - NO FAILURES. 01:30 - 02:00 0.50 BOPSUB P DECOMP - RIG DOWN TEST EQUIPMENT - BLOW DOWN CHOKE AND KILL LINES 02:00 - 04:00 2.00 WHSUR P DECOMP - PJSM WITH DSM - RU OFFSET LUBRICATOR AND TEST 250/3500 PSI - PULL TWC - TBG ON A SLIGHT VACUUM. Printed 12/26/2012 9:57:43AM ` '� '7"c rf9 b_ riraligaggeaggaiti Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00XOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) _ (ft) 04:00 - 05:00 1.00 WHSUR P DECOMP -PJSM MAKE UP XO AND FOSV AND SCREW INTO HANGER - PULL HANGER FREE_AT 120K FREE WT = 105K (INCLUDES TOP DRIVE WT)- - CENTRILIFT REP CHECKED CONDUCTIVITY. CUT ESP CABLE - LAY DOWN HANGER AND LANDING JT. 05:00 - 06:00 1.00 PULL P DECOMP R/U TO CIRCULATE TBG VOLUME - CLOSE ANNULAR AND CIRCULATE A TBG VOLUME THROUGH GAS BUSTER. - CIRC @ 5 BPM WITH 1780 PSI. (95 BBLS) _ - MONITOR WELL- STATIC. 06:00 - 09:30 3.50 PULL P DECOMP PJSM, HANG ESP CABLE SHEAVE AND ELEPHANT TRUNK. - POH W/ ESP COMPLETION ON 2 7/8" EUE 8 RD. TBG. F/ 12101' MD. T/ 7400' MD - 6 -8 BPH STATIC LOSS RATE. 09:30 - 12:00 2.50 PULL N WSEQ DECOMP WAIT ON MPU INCLEMENT RISK ASSESSMENT - (TEMP -42 DEG ) - TO USE LOADER TO CHANGE OUT FULL REEL OF ESP CABLE - FROM SPOOLING UNIT. STATIC LOSS RATE = 6 BPH 12:00 - 16:30 4.50 PULL P DECOMP CONTINUE POOH W/2 7/8" . TBG AND ESP CABLE _e - 195 LASALLE CALMPS / 3 FLAT GAURDS / 6 PROTECTORLIZERS. 16:30 - 18:30 2.00 PULL P DECOMP -PJSM LAY DOWN ESP PUMP MOTORS ASSEMBLY. - CENTRILIFT REP INSPECT AND DRAIN ASSEMBLY. 18:30 - 19:00 0.50 PULL P DECOMP - CLEAR AND CLEAN RIG FLOOR - REMOVE CLAMPS FROM FLOOR. - 6 -7 BPH LOSS RATE 19:00 - 19:30 0.50 WHSUR P DECOMP -PJSM INSTALL WEAR RING - ID = (6 1/8 ") 19:30 - 20:30 1.00 CASING P DECOMP -PJSM RIG DOWN ESP TRUNK _ - AND INSPECT SHEAVE. 20:30 - 00:00 3.50 CASING P DECOMP -PJSM WITH HES REP AND RIG CREW -PU 7" CHAMP IV PACKER AND RIH T/ 5347' MD - PU WT = 70K DN WT = 65K (INCLUDES 40K TOP DRIVE WT) - LOSSES TO THE WELL LAST 24 HRS = 167 BBLS 9.7 PPG BRINE - AVG LOSS = 7 BPH -OA PRESSURE = 120 PSI 12/14/2012 00:00 - 01:30 1.50 CASING P DECOMP -PJSM CONTINUE TO TIH WITH 7" CHAMP PACKER - T/ 6773' MD - PU WT =67K DN WT= 65K 01:30 - 03:00 1.50 CASING P DECOMP - CIRCULATE B/U - @ 3 BPM = 520 PSI - WITH TOP DRIVE AT RIG FLOOR TO ALLOW IT TO WARM UP IF NEEDED. - AMBIENT TEMP -40 DEG Printed 12/26/2012 9:57:43AM • : Firx fi a Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- OOXOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:00 1.00 CASING P DECOMP PJSM, MIT -IA, 7" CSG BY 2 -7/8" ANNULUS 7 3E1 7" CHAMP PKR - WSL CONFIRMED SETTING DEPTH - PRESSURE TEST CSG TO 2500 PSI FOR 30 / . MIN - PUMPED 22 STK (1.8 BBLS) T/ 2,500 PSI FOR 30 CHARTED MINUTES. , - DISCUSS W/ TOWN RWO ENGINEER. ,1 (PASSED TEST) - MIT -IA TEST, MEETS BP STP CRT- AK -10 -45 - RECEIVED PERMISSION TO PROCEED FROM WTL. - SEE ATTACHMENTS 04:00 - 05:30 1.50 CASING P DECOMP PJSM, CBU THROUGH GAS BUSTER. - FILL GAS BUSTER - CLOSE ANNULAR. - PUMP 3 BPM / 560 PSI. - PUMP 204 BBLS 9.7 PPG BRINE. - MONITOR WELL ON A VACUUM. - OPEN ANNULAR. 05:30 - 08:00 2.50 CASING P DECOMP PJSM POH W/ 7" CHAMP IV TEST PACKER. - -'8 BPH LOSS RATE WITH CONTINUOUS HOLE FILL. RACK 2 -7/8" TBG IN DERRICK - F/6773' MD. T/ SURFACE. 08:00 - 08:30 0.50 CASING P DECOMP DRAIN BOP STACK - M/U RETRIEVING TOOL. - PULL WEAR RING - L/D RUNNING TOOL. 08:30 - 10:00 1.50 CASING P DECOMP PJSM, CUT AND SLIP DRILL LINE. - M/U 15' PUP TO TOP DRIVE. - HANG BLOCKS. - CUT AND SLIP 40' DRILL LINE. - L/D 15' PUP. 10:00 - 10:30 0.50 RUNCOM P RUNCMP R/U TO RUN ESP COMPLETION. - LOAD CANNON CLAMPS TO RIG FLOOR. - PULL ESP CABLE OVER SHEAVE IN DERRICK. 10:30 - 16:00 5.50 RUNCOM P RUNCMP PJSM, WITH CENTRILIFT REP. - PU /MU AND SERVICE ESP PUMP AND MOTOR ASSEMBLY. - M/U I -WIRE. - 1 JT 2 -7/8" TBG AND 'XN' NIPPLE (2.250" ID) - CENTRILIFT REP CHECK CONDUCTIVITY OF ESP ASSEMBLY. 16:00 - 23:30 7.50 RUNCOM P RUNCMP RIH WITH ESP COMPLETION. - ON 2 7/8" 6.5# EUE 8 RD TUBING - FROM DERRICK - FROM ESP ASSY 83' - TO 7525' MD - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON FIRST 9 JTS THEN EVERY OTHER COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 - 1 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL W/ 9.7# BRINE. - 5 -6 BPH LOSS. Printed 12/26/2012 9:57:43AM c^` 4„ gi 3441 c ° r fA,ktp y r � i 4 ,rte s 0 Common Well Name: MPF-14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00X0E- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (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 RUNCOM P RUNCMP CENTRILIFT REP PERFORM ESP CABLE REEL TO REEL SPLICE. - FLUSH PUMP WITH 5 BBLS 9.7 KWF, 1 BPM @ 1050 PSI -TOTAL 24 HR LOSS = 128 BBLS AVG 5.3 BPH - 7525' MD 12/15/2012 00:00 - 03:00 3.00 RUNCOM P RUNCMP CENTRILIFT REP PERFORM ESP CABLE REEL TO REEL SPLICE @ 4274' MD - FLUSH PUMP WITH 5 BBLS OF 9.7 KWF, 1 BPM 03:00 - 06:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH FROM 7525' MD WITH ESP COMPLETION. - ON 2 7/8" 6.5# EUE 8 RD TUBING - FROM DERRICK - FROM ESP ASSY 83' - TO 12,079' MD - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON FIRST 9 JTS THEN EVERY OTHER COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 - 1 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL W/ 9.7# BRINE. - 5 -6 BPH LOSS. 06:00 - 06:30 0.50 RUNCOM P RUNCMP PJSM, P/U 7- 1/16" X 11" 5M TBG HANGER AND ORIENT SAME. - WSL VERIFIED ORIENTATION. - TERMINATE ESP LINE TO TBG HANGER PER CENTRILIFT REP. 06:30 - 08:00 1.50 RUNCOM P RUNCMP CENTRILIFT REP TERMINATED ESP CABLE - M/U ESP CABLE TO HANGER AND TEST CONDUCTIVITY THRU PENETRATOR 08:00 - 08:30 0.50 RUNCOM P RUNCMP LAND FMC 7- 1/16" X 11" 5M TBG HANGER. - PU WT. = 110K INCLUDING 40K TOP DRIVE / BLOCK WT. - SO WT. = 73K. - FMC REP RILDS. CHANGED OUT 2 LDS ON TBG SPOOL. - UD LANDING JT. - BOTTOM CENTRALIZER SET @ 12109' MD. 08:30 - 09:30 1.00 RUNCOM P RUNCMP PJSM, FMC REP INSTALL TWC. - PERFORM ROLLING TEST F/ BELOW T/ 500 PSI. PUMPED @ 1 BPM / 600 PSI. - CHART TEST F/ 10 MINUTES. PUMPED AWAY 17 BBLS. - TEST F/ ABOVE 250 / 3500 PSI. - CHART EACH TEST 5 MINUTES. PASSED 09:30 - 10:00 0.50 BOPSUR P WHDTRE BLOW DOWN LINES. - R/U 2" CHECK VALVE IN HARD LINE TO FILL THROUGH THE IA - DURING ND / NU OPS. 10:00 - 11:30 1.50 BOPSUR P WHDTRE PJSM N/D BOPE - REMOVE FLOW NIPPLE AND TURNBUCKLES. - LOTO KOOMY AND REMOVE HOSES. - REMOVE 11" BY 7 -1/16" SPOOL. - SET BACK BOP STACK Printed 12/26/2012 9:57:43AM f Common Well Name: MPF -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/11/2012 End Date: 12/16/2012 X4- 00XOF- E:DRILL (1,650,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/15/1996 12:00:OOAM Rig Release: 12/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:30 1.00 WHSUB P WHDTRE - N/U FMC GEN 5 11X 2 9/16" ADAPTER - 2 9/16" CAMERON TREE - MP WELL SUPPORT VERIFY TREE ALIGNMENT. 12:30 - 14:30 2.00 WHSUB P WHDTRE PJSM, FMC REP PRESSURE TEST HANGER VOID. - 250 PSI LOW, 30 MIN, 5000 PSI HIGH, 30 MINUTES, PASSED. - TEST TREE 250 / 5000 PSI F/ 5 CHARTED MINUTES. PASSED. 14:30 - 17:00 2.50 WHSUB P WHDTRE PJSM, P/U DSM LUBRICATOR AND TEST TO 250 / 3500 PSI. - CHART RECORD EACH FOR 5 MIN. - PULL TWC PER WELL SUPPORT REPS. - SET BPV WITH TESTED LUBRICATOR. WELL SUPPORT SUPERVISOR ON LOCATION FOR RETRAINING / EVALUATIONS. 17:00 - 17:30 0.50 WHSUB P WHDTRE -TEST BPV - ROLLING TEST F /BELOW @ 1 BPM = 500 PSI FOR 10 MIN AND CHART. PASSED. 17:30 - 18:00 0.50 WHSUB P WHDTRE -BLOW DOWN TEST LINES - AND R/D TEST EQUIPMENT - SECURE ALL TREE VALVES. 18:00 - 21:00 3.00 WHSUR P WHDTRE -WAIT ON LITTLE RED - CLEAN OUT SLOP TANK / INSTALL HAND CHOKE ON KILL MANIFOLD - REMOVE MUD HOPPER FOR REPAIRS _ - WAIT ON WEATHER 21:00 - 00:00 3.00 WHSUR P WHDTRE - PJSM R/U LITTLE RED AND TEST LINES 250/3500 PSI - FREEZE PROTECT ANNULAS W/ 75 BBLS OF CRUDE 1 BPM =1000 PSI - FREEZE PROTECT TBG W/ 15 BBLS OF CRUDE 1 BPM = 1800 PSI - SECURE WELL AND CELLAR AREA ✓ - 24 HR LOSS TO THE WELL 81 BBLS / AVG 3.4 BPH 12/16/2012 00:00 - 06:00 6.00 RIGD N WAIT WHDTRE WAIT ON WEATHER -43 DEG. F - PREP FOR RIG MOVE - PERFORM RIG MAINTIANCE. 06:00 - 08:00 2.00 RIGD P PRE PJSM, BRIDLE UP DERRICK TO LAY OVER MASK. - LOWER DERRICK. RELEASE RIG AT 0800 HRS 12/16/2012 FOR MOVE TO MPC -PAD. Printed 12/26/2012 9:57:42AM ' + Tree: Cameron 2 9/16" 5M MP F -14 • > Wellhead: 11" x 7 1/16" 5M FMC Gen Orig. KB Elev. = 45.45' (N 27E) 5A, w/ 2 7/8" FMC tbg. hng., 3" LH 0 Orig. GL Elev. = 12' acme on top and 2 7/8" EUE 8 rd on 0 x RT To Tbg. Spool = 33.45 (N 27E) bottom, 2.5" CIW BPV profile 0 20" 91.1 ppf, H -40 0 . 115' k; Camco 2 7/8" x 1" KOP @ 900' 0 ._ sidepocket KBMG GLM 141 Max. hole angle = 71 to 75 deg. 0 ;. f/ 4800' to 10300' j Hole angle thru' perfs = 21 deg % DLS = 4 deg. /100' @ 11257' 9 5/8 ", 40 ppf, L -80 Btrc. 6690' and , 0 0 0 0 0 0 0 0 7" 26 ppf, L -80, BTC production casing 0 ( drift ID = 6.151 ", cap. = 0.0382 bpf) 0 1 Camco 2 7/8" x 1" 11846' sidepocket KBMG GLM 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf) HES 2 -7/8" "XN" Nipple 12000' 2.205" No -Go r Well Lift Gauge Unit 12042' 0 Tandem Pump, SXD 119 -P23 12047' /- w/ discharge head GPDIS II Gas Separator / _ Model - GRS AR H6 12065` /% " Intake TVD 6861' I, Tandem Seal Section 12070' / a Model - GSB3DB UT /LT SB /SB PFSA F Motor MSP1, rerated 210HP 12083' Stimulation Summary = 2145 volts / 59 amps 02/26/96 - Frac stimulation -120.7 M # mmt III 16/20 sand behind pipe. Pumped design Well Lift MGU 12106' plus excess and got full displacement. I I PumpMate w/6 fin Centralizer 12108' Perforation Summary • PumpMate TVD 6895' Ref log: 2/13/96 AWS gr/ccl 7" short joint from 12,124' to 12,144' Size SPF Interval (TVD) 3 3/8" 6 12334'- 12414' (7100'- 7175') 22 gm Jumbo Jet charges @ 60 deg. phasing, 0.76" EHD mid -perf = 7137' tvd 12374' and 7318' tvd 7" float collar (PBTD) 1 12,663 and 7" float shoe 12,747 and DATE REV. BY COMMENTS MILNE POINT UNIT 1/25/96 DBR 7" csg run by N27E 03 / 26 6 F Initial ES ESP 9 B completion by Nabors 4ES WELL F -14 10/30/01 GMH RWO - Replace ESP - Nabors 4ES API NO: 50- 029 - 22636, 2/10/06 L Hulme RWO - Replace ESP - Nabors 3S 12/16/2012 B. Bixby Doyon 16 / RWO ESP Changeout BP EXPLORATION (AK) • by BP Exploration (Alaska) Inc. 4 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 SL NE --� FEB 7 ZU1Z Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ` � West 7 Avenue ' r Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, L/71 Mehreen Vazir BPXA, Well Integrity Coordinator .....- , . m „ -,,., .,..rW , ewa..,.pmrrex> .� ,; ...y,y.r -„y F H4'• . w xf 4., c.� r I ID BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 , 1.3 N/A 1.3 N/A 13.6 8/92011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 "-lib. MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top Job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 WA 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 WA 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF - 848 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA .. ALAS.IL AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 1m Repair Well 1m Pull Tubing 45.75 12768 7522 12663 7423 Length 72' 6654' 12716' Change Out ESP o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver 1m Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 umber: 195-212 6. API Number: 50-029-22636-00-00 9. Well Name and Number: MPF-14 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) feet Junk (measured) feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 9-5/8" 6690' 4520 5750 3090 7" 12749' 7504' 7240 5410 12334' - 12414' 7113' -7188' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl .". ~21 07' lID 2-7/8", 6.5# L-80 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: - !20 ~cn ::rClO o n ... 0 I» :::J CCI " (I). o ('o..:! = = en <: m CJ i ¡;;. '" Re resentative Dail Gas-Mcf Water-Bbl :::J Tubin Pressure o Copies of Logs and Surveys run 1m Daily Report of Well Operations 1m Well Schematic Diagram 17. Printed Name Sondra Stewman 1m Development 0 Service o WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: Title Technical Assistant Phone 564-4750 Datec:::3;l<o MAR 20 ZO~ Prepared By Name/Number: ondra Stewman, 564-4750 Submit Original Only IGINAL Tree: Cameron 2 9/16" 5M Wellhead: 11" x 71/16" 5M FA3en 5A, w/2 718" FMC tbg. hng., ~ acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 1115' KOP @ 900' Max. hole angle = 71 to 75 deg. fl 4800' to 10300' Hole angle thru' perfs = 21 deg OLS = 4 deg.l100' @ 11257' 95/8",40 ppf, L-80 Btrc. 6690' md I 7" 26 ppf, L-80, BTC production casing (drift 10 = 6.151", cap. = 0.0382 bpf) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf ) Stimulation Summary 02/26/96 - Frac stimulation -120.7 M # 16/20 sand behind pipe. Pumped design plus excess and got full displacement. Perforation Summary Ref loa: 2/13/96 AWS ar/ccl Size SPF Interval (TVD) 33/8" 6 12334'-12414' (7100'-7175' 22 gm Jumbo Jet charges @ 60 deg. phasing, 0.76" EHO mid-perf = 7137' tvd 12374' md MP F-14 Orig. KB Elee 45.45' (N 27E) Orig. GL Elev. = 12' RT To Tbg. Spool = 33.45 (N 27E) Cameo 2 7/8" x 1" sidepocket KBMG GLM 203' Cameo 2 7/8" x 1" sidepocket KBMG GLM I 11843' I HES 2-7/8" "XN" Nipple 2.205" No-Go I 11987' I Tandem Pump, 82GC2900 82GC2900, Model GPMTAR 1:1 Gas Separator Model - GRSFTX AR H6 Intake TVO Tandem Seal Section Model - GSB3DB UT/L T AB/HSN Motor, 209 HP, 2385 volt, 53 amp, Model - KMH 12029' 12064' 6861' 12069' 12083' PumpMate w/6 fin Centralizer 12101 ' PumpMate TVO 6895' 7" short joint from 12,124' to 12,144' 7" float collar (PBTO) 7" float shoe 7318' tvd 112,663 mdl 112,747 mdl DATE REV. BY COMMENTS MILNE POINT UNIT 1/25/96 OBR 7" csg run b N27E WELL F-14 03 I 261 96 JBF Initial ESP completion b Nabors 4ES API NO: 50-029-22636 10/30/01 GMH RWO - Replace ESP - Nabors 4ES 2/10106 L Hulme RWO - Replace ESP - Nabors 3S BP EXPLORATION (AK) , BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPF-14 Common Well Name: MPF-14 Spud Date: 1/15/1996 Event Name: WORKOVER Start: 2/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/13/2006 Rig Name: NABORS 3S Rig Number: N3S Hours i Task ¡ i Date From - To Code I NPT I Phase Description of Operations , I .-- ...- ... ... -. -... ".- ...- .-------.-- 2/8/2006 11 :00 - 00:00 13.00 RIGD P PRE Release Rig from MPF-94 @ 0600 hours. Cleanout Mud Pits with 50-Bbls hot water and Super Sucker Truck. NaBr/NaCI precipitated out in the bottom of the Pits requiring manual labor and hot water to remove from pits. RID Modules and prepare to move from MPF-94 to MPF-14. Waiting on weather to move rig. 2/9/2006 00:00 - 01 :30 1.50 RIGD P PRE Wait on weather to RDMO MPF-94. Wind steady at 18 mph with gusts to 29 mph at 0130 hrs. 01 :30 - 02:00 0.50 RIGD P PRE Wait on weather to RDMO to MPF-94. Wind laid down about 0200 hrs. 02:00 - 07:00 5.00 RIGD P PRE RDMO MPF-94. Derrick on Headache Rack @ 0300. Wait on Trucks. 07:00 - 12:30 5.50 RIGD P PRE Rig-Down Pipe Shed and Mud Pits from Rig Sub. Move Rig Sub off MPF-94. Move Pipe shed and Mud Pits away from rig sub. Clear snow drift from area surrounding MPF-14 Cellar. 12:30 - 17:00 4.50 RIGU P PRE Level area immediately around MPF-14 Cellar. Re-align Rig Sub to Tree, back-off, and Roll-out Herculite. Spot and level Rig Sub Mats around Cellar. Move Rig Sub onto Rig Mats and level Rig Sub. Connect Pit and Pipe shed Modules to Rig Sub. Raise and telescope Derrick. AOGCC - Jeff Jones waived witness BOPE test. 17:00 - 21 :00 4.00 RIGU P PRE Rig up primary unit. Pre-tour meeting wi night crew. Discussed plan forward. 21 :00 - 00:00 3.00 RIGU P PRE Rig accepted @ 2200 hrs. 2/10/2006 00:00 - 02:00 2.00 KILL P DECOMP Finish rigup primary unit. Rig up hardline to displacement tank. Hook up choke line to annulus. 02:00 - 03:30 1.50 KILL P DECOMP SITP = 900 psi. SICP = 1400 psi. Shot annulus fluid level @ 4000 ffs. Notified MPU Front Desk of gas venting operations. Bled off casing to 100 psi. to displacement tank. SICP = 100 psi. SITP = 1100 psi. 03:30 - 05:00 1.50 KILL P DECOMP P/U lubricator. Pull BPV. UD lubricator. 05:00 - 08:00 3.00 KILL P DECOMP Hook up kill line to Production Tree and prep to displace tubing to seawater. Take on Seawater to Pits. Hold PJSM. Check lines. 08:00 - 09:30 1.50 KILL P DECOMP Prepare to Bleed Down well. TP = 11 OO-psi; CP = 240-psi. Start circulating with hot seawater 2-BPM (42-Strokes / Bbl), 800 psi. Discovered seawater leaking from flowline @ 0910 hours. Seawater was leaking down onto the Tree and into the Cellar around the Wellhead. Immediately SID the operation and secured the well. See more info in Remarks. 09:30 - 11 :00 1.50 KILL P DECOMP Troubleshoot, then break out and replace Lo-Torq Valve in Mud Manifold and lubricate all other Valves in the Manifold. 11 :00 - 15:30 4.50 KILL P DECOMP Bleed down Tubing and Casing and resume Well Kill Circulation with TP = 20-psi and CP = 120-psi @ 3-BPM. Continue circulating @ 3-BPM and see TP increase to 510-psi and CP decrease to 60-psi after -350-Bbls circulated long way. All returns taken to the 360-Bbls Blowdown Tank. Returns clean after 700-Bbls circulated through well bore. SID pump and monitor well; both sides on vacuum. Hauled 500 Bbis of returns to disposal at Pad-3. -200-Bbls of clean, hot seawater were lost to the formation. 15:30 - 18:30 3.00 WHSUR P DECOMP P/U TWC and install and test. Nipple Down Tree. 18:30 - 20:30 2.00 BOPSUF P DECOMP N/U BOPE. e Printed: 2/21/2006 10:55:24 AM e BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-14 MPF-14 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/9/2006 Rig Release: 2/13/2006 Rig Number: N3S Spud Date: 1/15/1996 End: Date i ~ ' From - To ¡ Hours ' Task ¡ Code ¡ NPT Phase Description of Operations ...- - -... - .. ----....-...---..--......-.- .._..n .. ",_.. on _ _ _ .. 2/11/2006 20:30 - 21 :00 0.50 BOPSUF P PRE 21 :00 - 00:00 3.00 BOPSUF P DECOMP 00:00 - 08:00 8.00 BOPSUF P DECOMP 08:00 - 09:00 1.00 BOPSUF P DECOMP 09:00 - 13:00 4.00 BOPSUF P DECOMP 13:00 - 14:00 1.00 BOPSUF P DECOMP 14:00 - 18:00 4.00 BOPSUF P Crew change - Pre-Tour HSE meeting wlall crew. N/U BOPE. Phase 1 weather conditions at 2200 hrs. N/U BOPE. Phase 2 weather conditions @ 0000 hrs. Phase 1 weather conditions @ 0400 hrs. Prepare BOPE test pump, fill lines, pressure up and check for leaks. Test BOPE 250 psi low and 3,500 psi high. All tests passed. Jeff Jones waived AOGCC right to witness the BOPE tests. Rig Down BOPE test equipment, drain lines and prepare to P/U lubricator to pull TWC. Did not have correct XO for pulling the TWC, although do have the same threaded XO in heavyweight pipe to pull the Tubing Hanger. Nabors 4ES had correct XO: 3-1/2" BTC x 3" LH Acme and is sending it via Tool Services. A multiplicity of rig moves in GPB area has Nabors Rig 7ES stopped on the Spine Road near the S-Pad access and FMC and Tool Services are consequently blocked from getting to our location. DECOMP Wait on Rig moves. R/U all Centrilift equipment: Sheave with Drain Line, Elephant Trunk, and Spooling Unit. Lay down Herculite between Rig and Spooling Unit. 2/1 0/2006 18:00 - 20:00 2.00 BOPSUF P DECOMP PUMU lubricator. Pull TWC. SITP = vacuum. SICP = vacuum. LID lubricator. PUMU landing it. Screw into tubing hanger. BOLDS. Unland tubing hanger. P/U wi. to unland hanger = 75K. P/U wi. after hanger free = 69K. Filled hole with 53 bbls. seawater prior to laying tubing hanger down. Pit volume after fill - 157 bbls. Pull and LID landing it. and tubing hanger. FMC transported tubing hanger to their shop to redress and will return it when we are ready to land completion. 20:00 - 21 :00 1.00 PULL P DECOMP String ESP cable over cable sheave and connect to cable spool in cable spooler. LID third it. out and remove from string - bad thds. Will leave out of completion per engineering request to land completion -30 ft. higher to eliminate possibility of ESP unit being previously landed in dogleg. Ordered 290 bbls heated seawater (120F). 21 :00 - 00:00 3.00 PULL P DECOMP POH with ESP completion standing doubles back in derrick. Filling hole very 10 its. with double tubing/ESP cable displacement - approx. 1 bbl. per 10 its. 2/12/2006 00:00 - 08:00 8.00 PULL P DECOMP POH with ESP completion standing doubles back in derrick. Filling hole every 10 jts. with double tubinglESP cable ! displacement - approx. 1 bbl. per 10 jts. Fluid losses = 100 bbls. Day crew used 11-Bbls to fill hole when ESP was at the surface. Recovered 184 LaSalle Clamps, 6 Protectolizers, and 3 Flat-Guards. 08:00 - 12:00 4.00 PULL P DECOMP LID old ESP assembly and place in transport boxes. Unload used cable reels from cable spooler. place used reels in drip trays. 12:00 - 12:30 0.50 PULL P DECOMP Clear and clean Rig Floor. Remove Elephant Trunk from Sheave. Prepare to RIH wI new ESP Assembly. 12:30 - 17:00 4.50 RUNcmfP RUNCMP P/U. M/U, Service, and test new ESP Assembly. Pull new I Cable over sheave and connect Motor Lead to the Motor. 17:00 - 00:00 I 7.00 RUNcmfP I RUNCMP RIH w/ new Centrilift ESP completion using Best-O-Life Pipe I Printed: 2/21/2006 10:55:24 AM \ . e BP EXPLORATION Operations Summary Report Legal Well Name: MPF-14 Common Well Name: MPF-14 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date I From - To 1 Hours Task Code I NPT , Phase 2/12/2006 17:00 - 00:00 2/13/2006 00:00 . 02:00 02:00 - 05:00 05:00 - 10:00 10:00 . 14:00 14:00 - 15:00 15:00 - 15:30 15:30-20:30 20:30 - 23:59 2/14/2006 00:00 - 06:00 7.00 RUNCO RUNCMP 2.00 RUNCO RUNCMP RUNCMP 3.00 RUNCO RUNCMP 5.00 RUNCO RUNCMP RUNCMP 0.50 BOPSU P RUNCMP 5.00 BOPSU P 3.48 WHSUR P RUNCMP RUNCMP 6.00 DEMOB P POST Start: 2/9/2006 Rig Release: 2/13/2006 Rig Number: N3S Page 3 of 3 Spud Date: 1/15/1996 End: Description of Operations ---- --.--- -- -- ----------.. Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Attempted to rerun Lasalle cable clamps pulled from this well. Clamps found to be mechanically unsound. Decision made to run in hole with refurbished clamps from MPU stock. Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. RIH wI new Centrilift ESP completion using Best-O-Life Pipe Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' cable ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. Centrilift service tech. make reel to reel cable splice at 8244 ft. in hole. Resume RIH w/ new Centrilift ESP completion using Best-O-Life Pipe Dope and Optimum Torque of 2,300 ft·lbs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' cable ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. P/U Landing Joint made up on 3-1/2" box x 3"·IF pin XO (heavy-weight) and M/U to new FMC 3" LH Acme x 2-7/8", EUE 8-Rd Tubing Hanger. M/U Hanger to Completion String and space out cable to Hanger penetration. Perform cable splice to Penetrator. Land Tubing Hanger. P/U wt. = 62K. SO wt. = 32K. RILDS. Back out Landing Joint and break off XO pup joint and UD both. Install and test TWC. N/D BOPE. While pulling the Pitcher Nipple with the Driller-side Tugger, a hydraulic line at the Off-Driller-side Tugger burst, spraying hydraulic oil onto the Rig Floor under the Super-Choke Panel. The Motorman, who was assisting with NID immediately S/D the hydraulic system. The fluid drained down the inside wall to the cellar and also drained down the outside wall. The area immediately under the wall and inside the Cellar was covered with Herculite. All fluid was picked up with Absorb--estimated that 1-gallon was lost. Resume N/D BOPE. N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Good test. P/U lubricator. Pull TWC. Set BPV. UD lubricator. Secure well. Secure cellar. Released rig @ 0000 hrs. RDMO primary unit to MPL-40. Released rig @ 0000 hrs. 2/13/06. Derrick on Headache Rack at 0430 hrs. Peak Base contractors were called to bring gravel and equipment to L-pad to re-do their earlier attempts to level the area around the L-40 Tree. Printed: 2/21/2006 10:55:24 AM - - STATE OF ALASKA-- 1/28/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ¡im reç¡Q@¿admín.state.ak.us aOQcc prudhoe bav@adm;n.state.ak.us bolJ f¡eckenste;n@¿admín.state.ak.us Contractor: Nabors Rig No.: 3S DATE: 2/11/2006 Rig Rep.: Greco/Fritts Rig Phone: 670-3270 Rig Fax: 670-3269 Operator: BPX Op. Phone: 670-3268 Op. Fax: 670-3269 Rep.: Rooney/Hefley Field/Unit & Well No.: MPU-F-14 PTD # 1952120 Meridian: Location: Section: Township: Range: Operation: Drlg: Workover: X Explor. : Test: Initial: X Weekly: Other: Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign p Upper Kelly 0 Housekeeping: P Drl. Rig p Lower Kelly 0 PTD On Location P Hazard Sec. p Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 P Quantity Test Result Pipe Rams 1 2-7/8 x 5 P No. Valves 13 P Lower Pipe Rams NA Manual Chokes 1 P Blind Rams 1 P Hydraulic Chokes 1 P Choke Ln. Valves 1 31/8" p HCR Valves 2 31/8",2-1/16 P ACCUMULATOR SYSTEM: Kill Line Valves 1 2-1/16" P Time/Pressure Test Result Check Valve 0 NA System Pressure 2900 P Pressure After Closure 1300 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 30 sec. P Trip Tank P P Full Pressure Attained 2min 29sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 @ 1875 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: Q Test Time: § Hours Components tested ALL Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ¡im reç¡g@¿admín.state.ak.us Remarks: 24 HOUR NOTICE GIVEN YES X NO Waived By Lou Grimaldi Date 02/03/06 Time 21:00 Witness Rooney/Greco Test start 8:30 Finish 13:00 êC¿'~J¡,Wi"íELI F .1 Ii A TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid wastes. There are no other well annulii on this 'pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ,SCANNED NOV ! $ 2002- ANNULAR INJECTION DATA ENTRY SCREEN Asset MilD.e. .......................................... Rig Name ~.{l~.Qr.~..~2,F,, ............................. Inj Well Name U..P...F.:..1..~. ..................................... Sur Csg Dep §.0.8.0. ................ Cumulative Data Legal Desc ~.e.c..0.6.,.'['.X;~.~,.B.1.0E..I,I.M ....................................................................... Research ....................................................................................................................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Well Total Mud/Ctg Permit End ....... ~.~:~J.~l.~ ....... ......... ,~13/.8Z....~ .... Permit Start ....... .12,./~§l.9.5 ....... ......... f~/31.86 .......... Rig Completion Formation intermittant Final Wash Fluids FlUids Freeze Freeze Seuce We~ Dated · Freeze / Freeze. Daly Annulus M P F-06 01/28/96 90 MPF-06 01/29/96 188 40 228 MPF-06 01/30/96 165 165 MPF-06 275 Daily Data 90 275 547 270 01/31/96 60 960 ................................................................................................................................................... ~";66'~ ........................ ............. 660 ............ 70 255 100 550 550 MPF-06 02/01/96 547 MPF-06 02/02/96 270 .......................................................................................................... ~ ..................... ~ ...................... ..~ ......................................... MPF-06 02/03/96 545 545 IMPF-10i 05/28/~6 70 .............. I IMPF- 10i 05/29/96 255 :MPF-10i 05/30/96 100 MPF-10i '05/31/96 550 MPF-18 06/07/96 550 MPF-18 06/10/96 200 / MPF-18 06/11/96 475 475 MPF-18 06/12/96 105 105 MPF-18 06/13/96 147 147 MPF-18 06/14/96 290 290 MPF-18 06/15/96 650 :60 710 Rig Nabors 27E Rig Nabors 27E Rig Nabors 27E Rig Nabors 27E Rig Nabors 27E ................................ -~i'{j'-~'-~' ............................................................ Rig Nabors 27E RiG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RiG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E RIG NABORS 22E MPF-29 07/07/96 550 550 RIG NABORS 22E MPF-29 07/08/96 1,000 1,000 RIG NABORS 22E ~'¢~'~:~ ........................ 6~)'6~i?~i~ ...................... -i":~i~i~ ........................................................................................................................................................................................................................................................... i':~i~b ........................................................................ I~"~'1~:~'{~ ....................... 0'~/':~'~2~'(~ ...................... :i';'~'§~ ......................................................................................................................................................................................................................................................................................... . :J";'~§i~' .......................... 3 1500 MPF-29_ 07/11/96 515 I 515 3 1500 RIG NABORS 22E MPF-29 07/12/96 125 . 125 . 3 1500 RIG NABORS 22E MPF~29 07/13/96 75 75 -- 150 2.5 1700 RIG NABORS 22E MPF-29 07/14/96 110 110 2.5 1750 RIG NABORS 22E MPF-29 07/15/96 340 150 ~ 490 2.5 ~ 700 RIG NABORS 22E '- MPF-29 07/16/96 100 100 2.5 1700 RIG NABORS 22E MPF-29 07/17/96 -300 360 660 2.5 1650 ~IG NABORS 22E MPF-29 07/18/96 200 95 295 2.5 1600 RIG NABORS 22E MPF-29 07/19/96 'i~,~ ...................... I ............................... ....................... :i'~(J ............ ~i',~ ...................... i~J ....................... ~i~ NAB(~R~ 22~ ..... 3 1700 .0...p...e...n' ........................... .R..!...G.....,N..,?....o..R.,...S......2...2...E' ................................................................... . : __ __ -- - ,~CANNE[~ i, iOV i" """" 0 /UU~. -- -- · · ........................................................................................................................................................... ~._/.::_._' ., ,. ............................................................................................. "}:."'""~' :.;i~ ,' i,.':, ..~' ' ....,.. :...;¢:. .:. I ........... · ared rvices rilling 900 East Benson Boulevard, MB 8'1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request DEC 141998 Dear Ms. Mahan: Naska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with Our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the ssD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to yoU in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because 'the waste materials generated, frOm these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disPosal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled · after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular dispoSal: ~ ,Annular Disposal Letter .', 12/14/98 · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - ~-~o ~4 ,~, ' · MilnePointwellsF-06, H-05, H-06, J'13, L-24 - · PBU wells-18-30, 18-31, 14-~,~43, E-34, E-36, G-~A, ~d S-33- · Individual logs are provided to ~ou fo~ t~ese ~ogs as we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5 ! 83, or Karen Thomas, Enviromental Advisor at 564-4305. Sincerely, . Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED Aneh0ra~e uedo '. /_6/8 L/i~ 96/8 ~/i~ 00 t 989 gB~ 81~!;'8 t B09'6 t :4 t t I::IN~ t~'B0'oe$ '9:::IM,00 L~'qSN,BI~9f; 80!;B /_ L-Nd~ 3Z pesolo /_6/9~/~ 96/9~/~ 9gL'L 0B9'l~ 9BZ'g :li~ld 'N61 '6~ 'oas '33-1 ,Z90~ '9S-1,!;l~ 98~I~ B# q§nopJnos P lC paqoeoJB 96/[S~[ g6/Lg/8 0~;[ 69/_'6 6/_B'6 3911:i 'Ng[l'9g oeS U'ado ..... g6/~s~[ 96/09/6 0gt '°og "0'9 ~' [ ~09'09 ~80'gg 39t ~'Ng[ .... uad'o" '96)9~L' s6i9~L 0~ Z66 8~g'Z 096'8 a9LU' 'NZLI"9g 'oas 0009 8L'I/6L'L ~L uo~, ~lOOlP~ lelO.L wno oseo le§e9 snlelS pu~3 ~els ezeeJ:l ezaeJ=l sp!nl-1 sp!nl..-I qseNI s§lo ~ snlnuuv po!Jarl lesods]Q leu!-1 tuno tUJalUl tun:) tuJo:l [uno IdtUoO uJno §!~ '"no pnl~l l~nO qldac] Ile~ !Ul 6u!seo a3epns ~odal:l a^p, elntun B66L Jeqtuaoeo IP, un S661. 'g~ satunlo^ uo~,oalUl ~e~J~uu 6U!llHO ~o,4~as p~eq N]dO 96/L)9 Z6/L~g 09 [ Lg' [ ~ e6ed uedo Z6/~ 96/~ OC~ 9~Z'L 9C9'~ gI~6'G 38 ~t~'N8 LI'ggO~]S"I3~,cogt?"ISN, t tg~ ,tZLC C~-S 39L s~oqst 90 I,';~ 9~17'~ 1,9997 'N I, 1,1 iC;~ 'O39 "]3M ,/.90 I, '-ISN ,996~ ~C gC-O 6 uo/[o( uedo /.6/01,Iff. 96/0~/~ 0gl, 0~i, 3BH=I 'Nt ti '9~ 'O39 91,~C l,g-O 6 uoAo( uedo /.6/i,~/i, 96/LB/L 0Pl, gg0't 9/.~', L I, [B'g ~9~'g 'NI, Ll 'g~ 'O39 '93M ,9901, '9SN ,g~9g ,99P8 0g;O 6 uoXo( uedo 96/BL~L g6/BL~L ~i, t/.~'8 6gg' I, B66'~ ~96'9 3gl,B 'N L [I'~ oes '93M,B/.B~ 'gSN,g~9g L69~ 9~-~ 3B uedo Z6/l,g/g 96/[g~ 091, 99P 099 gBI, B9~'I, 3gi,B 'NI, 1,1'g oes '9~M,~/.l,g 'gSN,~ggg 0/.9~ gg-~ 39 VOA uedo 96/i,~ t 96/Zg/i, I, 0/- 9BB g9t 0~'i, 006'~ 06/-'9 301,B 'NBI,I'B oeS '93M,0B ~ 'gSN,~9B 9t99 ~g-gd~ 3/.~ sJoqB~ uedo ,96/L~ L 96/L8//- I-BI, LBS'ZL ~99'/-i, 301,B 'NCr1'9 oas '93~,B09Z '99N,6/.6 L Bt99 9P-~d~ 3Z~ sJoqeh uedo 96/LB~L 96/9~t 9/- /-91,'6 ~B~'6 301,~ 'N~I,~'9 oes '93M, I,~Z~ '99N,~66 L L99B B~-~d~ 3/-~ sJoqeh uedo g6/L~L 96/9~/Z 9Z 0/- ZBB'9 ~0'/- 301,H 'N~ I,~'9 oes '9~M,~9~ 'gSN,t~6~ L~99 Z~-~d~ 3/-~ sJoqeh ............... ~'~'a~ ................. ~"i~'[ ................... ~'~'i~*'i ............ ~'~J 9917'9 999'9 ~19:101,1:1 'NS[/'90 ::)eS I,t,99 ~;~-:ldl/4~ ........................ ' ............................. :!/_~ s~oq~l~ uedo uedo uedo 'uedo snlnuuv Z6/L~/9 '96//-[/9 9~' 061' "' Z6/9~/t 96/9~/t 96 L pu~ ~lS ezeeJ~ ezeej~ sp!nl~ sp!nl~ po!Jed I~sods!o leU!~ uJn~ uaJelUl [uno LUJOq [uno IdU~o3 uJn~ ~BC ~ I,/-'/. BB~'B 30~ 'NB 1,1'I~ oaS '93M,B~0~ 'gSN,~BB~ 9~C9 90-Hdl/;I 3~ sJoqeN "g~Z ~6Z'BL sZz'6t 30~B 'NC[1'9 oeS' '93M,~69~ 'gSN,6g[~ 616z 0L-~d~ ~ sJoqeN "0~;[ ' Z0~,Z~ "Z[~'B~ ~fi 30~B 'N~[~'90 oas 0699 H-~d~ ~ sJoqeN .... tCL't '~6,[ 30tB 'N~L1;90'~as 99Z~ 90-dd~ 3~ sJoqeN ~ ~no pn~ ~no 6u~s~O e3~ns IJodelj e^!lelnLuno B66 t Jaqmeoeo I!lun ~66 t 'S~ ~[Inr sauJnlOA UO,loelul Jelnuuv Shared ~ei~vice Dr. illing Ann'bi~'r injection Volumes July 25, 1995. until December 1998 Cumulative Report Surface Casing Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Rig Inj Well Depth Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End Status Nabors 28E B-33 3504' 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 Broached Nabors 28E E-34 3664 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open Nabors 28E E-36 3648 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open Na_b_.o.l~_s..28E E-37 3810 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open Nabors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 Open Nabors 28E G-21 3509 2911'NSL, 2368'WEL. Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 70 62 9/8/95 12/31/95 Open Nabors 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open Nabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open Nabors 28E S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21 ,T11N, R 13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open ~labors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open SCANNED NOV 1 3 200 Page 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ ACIDIZED FORMATION Pu, tubing _ Alter casing _ Repair well _ :' Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 45 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Miline Point Unit 4. Location of well at surface 3432' FNL, 2837' FEL, Sec. 06, T13N, R10E, UM (asp's 541727, 6035299) MPF-14 At top of productive interval 9. Permit number / approval number 2600' FNL, 1689' FEL, Sec. 36, T14N, R09E, UM (asp's 537683, 6041389) 195-212 At effective depth 10. APl number 2527' FNL, 3661' FEL, Sec. 36, T14N, R09E, UM (asp's535711, 6041452) 50-029-22636-00 At total depth 11. Field / Pool 2503' FNL, 3684' FEL, Sec. 36, T14N, R09E, UM (asp's 535688, 6041475) Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12768 feet Plugs (measured) true vertical 7522 feet Effective depth: measured 12663 feet Junk (measured) true vertical 7423 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 250 sx Arcticset I (Approx) 110' 110' Surface 6650' 9-5/8" 1287 sx PF 'E', 250 sx 6690' 4520' Class 'G' Intermediate 12690' 7" 325 sx Class 'G' 12749' 7504' Perforation depth: measured Open Perfs 12334' - 12414' true vertical Open Perfs 7113' - 7188' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12071'. PHD w/6 fin Centralizer @ 12154'. Packers & SSSV (type & measured depth) No Packer in well. 2-7/8" x 1" sidepocket KBMM GLM Camco @ 159' & 11891' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used 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 04/17/2002 745 215 735 397 Subsequent to operation 04/23/2002 704 178 716 399 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended _ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ __C'~/~,~/..~,~~.~~~[/~ Title: Technical Assistant Date April 25, 2002 DeWayne R Schnorr~ Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ MPF-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/18/2002 04/18/02 ACIDIZE FORMATION EVENT SUMMARY HB&R RIGGED UP AND PUMPED 240 BBLS DEAD CRUDE DOWN THE IA TO FILL IT. PUMPED AT 2 BPM FROM 450 TO 1050 PSI. DOWELL RIGGED UP AND PUMPED 150 BBLS OF 12.5% DAD ACID DOWN TUBING, PUMPED AT 2 BPM FROM 450 TO 1663 PSI. SWITCHED TO SOURCE WATER FOR DISPLACEMENT, PUMPED 48 BBLS AT 2 BPM FROM 1663 TO 2535 PSI. SWITCHED TO METHANOL TO FINISH DISPLACEMENT AND FREEZE PROTECT TUBING. PUMPED 25 BBLS AT 2 BPM FROM 2535 TO 2436 PSI. NOTE: THE IA WAS AT 450 AND ONLY WENT TO 525 THROUGHOUT THE JOB. JOB WAS COMPLETED WITH NO PROBLEMS. WELL WAS LEFT TO SOAK FOR 3 HOURS AND THEN FLOWED TO A TANK UNTIL THE SOLIDS AND THE PH CLEANED UP. FLUIDS PUMPED BBLS DISCRIPTION 25 METHANOL 2 DEAD CRUDE 48 SOURCE WATER 150 12.5% DAD ACID 225 TOTAL Page 1 ..... - STATE OF ALASKA ALASKA ~,iL AND GAS CONSERVATION COMMIoSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 45.46' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Maine Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1848' NSL, 2873' WEL, SEC. 06, T13N, R10E, UM MPF-14 At top of productive interval 9. Permit Number / Approval No. 195-212 96-119 2600' SNL, 3590' EWL, SEC. 36, T14N, R09E, UM 10. APl Number At effective depth 50-029-22636 2527' SNL, 1618' EWL, SEC. 36, T14N, R09E, UM 11. Field and Pool At total depth Maine Point Unit / Kuparuk River 2503' SNL, 1595' EWL, SEC. 36, T14N, R09E, UM Sands 12. Present well condition summary Total depth: measured 12768' feet Plugs (measured) true vertical 7522' feet Effective depth: measured 12663' feet Junk (measured) true vertical 7423' feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 6650' 9-5/8" 1287 sx PF 'E', 250 sx 'G'. 210 sx 6690' 4520' Intermediate Production 12690' 7" 325 sx Class 'G' 12749' 7504' Liner Perforation depth: measured 12334'- 12414' ' ' ~.....,~ . . ,.~ . true vertical 7113' - 7188' .. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 12158 ....... ~;- P.:i ,~. ¢ ..... ..... )~ .... Cui;~i~ij,: 'Jr:,: , ,,, Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci 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 Si~lned So~ Title Technical Assistant Date Prepared By Name/Number: Sondra Stewrnan, 564-4750 ~,"'~, r'~ ~ ~'~_ t ~ ~ ~ i ........ Form 10-404 Rev. 06/15/88 ~-~ i R!GIItAL, ~r~'~ Submit In Duplicate ~ :::: :!: Operati0nS::Summary Report Legal Well Name: MPF-14 Common Well Name: MPF-14 Spud Date: 1/15/1996 Event Name: WORKOVER Start: 10/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: !: :Date(::l;Fro~i;~6 ~H0UrS ActiVi~ :Code:NPT Phase Description of Operations 10/27/2001 14:00 - 22:00 8.00! REST P DECOMP MOVE RIG FROM MPG-10 TO MPF-14. RAISE AND SCOPE DERICK UP. 22:00 - 00:00 2.00 REST P DECOMP RIG UP AND BERM TIGER TANK. TAKE ON HEATED 8.5 PPG SEAWATER IN THE PITS. 10/28/2001 00:00 - 02:00 2.00 REST P DECOMP RU LUBRICATOR AND PULL BPV. CONTINUE RIGGING UP LINES TO TREE. TEST LINES 3500 PSI. 02:00 - 07:00 5.00 REST P DECOMP OPEN WELL. 510 PSI TBG; 850 PSI ANNULUS. PUMP DOWN TBG @ 40 SPM WITH 3000 PSI. PUMPED 600 BBLS . NO GOOD RETURNS TO SURFACE-ONLY OIL AND GAS. SHUT IN WELL. 07:00 - 09:30 2.50 REST P DECOMP WAIT ON 600 BBLS WARM SEAWATER. 09:30 - 12:00 2.50 REST P DECOMP BULLHEAD TOTAL ANNULUS VOLUME INTO FORMATION. 5 BPM WITH 500-1400 PSI. 12:00-12:30 0.50 REST 3 DECOMP MONITORWELL-STATIC. SETTWC. 12:30 - 13:30 1.00 REST ~ DECOMP ND TREE 13:30 - 15:30 2.00 REST :~ DECOMP NU BOPS 15:30 - 22:00 6.50 REST ::) DECOMP CHANGE OUT PISTON SEALS AND ELEMENT ON ANNULAR PREVENTER 22:00 - 23:00 1.00 REST 3 DECOMP FINISH NIPPLING UP BOPS 23:00 - 00:00 1.00 REST :~ DECOMP TEST BOPS. VALVES 250/3500 PSI. ANNULAR 250/2500 [:)SI. CHUCK SHEVE W/AOGCC WAIVED WITNESSING TEST. 10/29/2001 00:00 - 02:00 2.00 REST P DECOMP COMPLETE DOPE TEST. 00:00 - 02:00 2.00 REST P DECOMP FINISH TESTING DOPE. STATE WAIVE RIGHT TO WITNESS TEST. 02:00 - 03:00 1.00 REST P DECOMP MU LUB AND PULL TWC. WELL ON VAC. 02:00 - 03:00 1.00 REST P DECOMP PU LUBRICATOR AND PULL TWC. LD LUBRICATOR. WELL QN VACUUM. 03:00 - 04:00 1.00 REST P DECOMP MU LANDING JT. BOLDS. PULL HANGER (105K) TO FLOOR AND LD. 03:00 - 04:00 1.00 REST 3 DECOMP MU LANDING JT. BOLDS. PULL TBG HANGER TO FLOOR. 04:00 - 06:00 2.00 REST 3 DECOMP :TEST ESP CABLE. FINISH RU SPOOLING UNIT. 04:00 - 08:30 4.50 REST ~ DECOMP START PULLING OUT OF HOLE WITH 2 7/8" TBG AND ESP ASSY. 06:00 - 08:30 2.50 REST 3 DECOMP START POOH WI2 7/8"TBG AND ESP ASSY. 08:30 - 09:30 1.00 REST 3 DF:COMP CHANGE OUT ESP CABLE SPOOLS. 08:30 - 09:30 1.00 REST ~ DECOMP CHANGE OUT REELS IN SPOOLING UNIT. 09:30 - 12:00 2.50 REST 3 DECOMP FINISH POOH WITH TBG AND ESP ASSY. !09:30 - 12:00 2.50 REST P DECOMP FINISH POOH WITH TBG AND ESP ASSY. 12:00 - 15:00 3.00 REST P DECOMP INSPECT AND LAY DOWN ESP ASSY.CLEAN AND CLEAR FLOOR. 12:00 - 15:00 3.00 REST P DECOMP INSPECT AND LD ESP ASSY. CLEAR FLOOR. 15:00 - 19:00 4.00 REST P DECOMP PICK UP AND SERVICE NEW ESP ASSY. 15:00 - 19:00 4.00 REST P DECOMP SERVICE NEW ESP ASSY. TEST. 19:00 - 00:00 5.00 REST P DECOMP START TO RIH WITH 2 7/8" TBG AND ESP ASSY. 19:00 - 00:00 5.00 REST P DECOMP START RIH W/ESPASSYAND 2 7/8" TBG. TESTAT 2000-FT INTERVALS. 10/30/2001 00:00 - 01:00 1.00 REST :) DECOMP CONTINUE RIH WITH ESP ASSY. STOP AT 8200-FT. 01:00 - 04:00 3.00 REST 3 DECOMP CHANGE OUT CABLE SPOOLS AND SPLICE CABLE. TEST. 04:00 - 06:30 2.50 REST :~ DECOMP STOP AT 11600-FT. NOT ENOUGH ESP CABLE TO COMPLETE JOB. FOOTAGE WAS MIS-MARKED ON SPOOL. 06:30 - 08:30 2.00 REST N HMAN DECOMP CHANGE OUT CABLE SPOOLS AND SPLICE CABLE. TEST. Printed: 11/5/2001 10:48:11 AM ::]:, :]]i:il~ ;~:i:: : :: :: ::ii :iI :]::]~;:~ ~::BP EXPLORATION Page2 of 2 ~ ~ ~, ~?:~ i~ -~ i: ~i~ ~: ~: OperationS Summary Report Legal Well Name: MPF-14 Common Well Name: MPF-14 Spud Date: 1/15/1996 Event Name: WORKOVER Start: 10/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: ~ Date:~: ;~From~T6 H°Ur§~ ActivitY C°deI NPT ~ Phase i~ :~::~:?::~ ~i :~ !~ ~:: :i: ~ :~ ~: ::,: :l Description of Operations 1013012001 08:30-09:00 0.50 REST P DEOOMP FINISH RIHWITH ESPASSYANDTBG. 09:00 - 09:30 0.50 REST P DEOOMP i MAKE UP LANDING JT. AND HANGER. INSTALL PENETRATOR. 09:30 - 11:30 2.00 REST P DECOMP MAKE EFT SPLICE. CONECT AND TEST. 11:30 - 12:00 0.50 REST P DECOMP LAND HANGER. RILDS. SET AND TEST TWC. 12:00- 13:30 1.50 REST P DECOMP REMOVE BOPE. 13:30- 14:30 1.00 REST P DECOMP INSTALLX-MASS TREE. 14:30 - 15:00 0.50 REST P DECOMP TEST ADAPTOR FLANGE AND TREE TO 5000PSI. TEST ESP PEETRATOR. 15:00 - 15:30 0.50 REST P DECOMP PU LUBRICATOR AND PULL TWC. INSTALL BPV. LD LUBRICATOR. i15:30 - 16:00 0.50 REST P DECOMP FREEZE PROTECT WELL. RELEASE RIG AT 16:00 HRS. Printed: 111512001 10:48:11 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON BEFORE JANUARY 03 2001 M PL A T E E IA L U N D W E R T H IS M A R K E R C:LO~E.M.DOC AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS 95-212 CCL ~SEPIA 95-212 GR/CCL ~/SEPIA 95-212 GR/CCL/PERF ~SEPIA 95-212 PLS (STAT) ~L/SEPIA 95-212 CDR-MD ~L~544~=12786 95 - 212 CDR- TVD 140 - 7~3 95-212 7450 ~:CDR/CDN 95-212 6996 L~+W. ATLAS 5435-12768 GR Page: 1 Date: 03/12/98 RUN RECVD 1 04/09/96 1 02/20/96 1 02/20/96 1 02/20/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 1,2 09/05/96 1 03/11/96 10-407 ~R/~OMPLETION DATE ~/,A6 /7(,, / DAILY WELL OPS R ] / ["('/ f6/ TO '2/,2c,, /~/ Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~_~.Analysis----&~,~}eser~i.pt-ion-.-rec-e~red-.~ ~ Are well tests required? /yes_ Well is in compliance ~-~ Initial COMMENTS ~--~ Received? Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 29, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth shifted CDR/CDN, CDR/CDN TVD'S for well MPF-14 Job # 96054 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1. Depth. shift display -..... State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 1 OH LIS Tape. 1 Blueline each" 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 464 · PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED SEP 0 5 1996 Date Delivered: Received By: Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-212 96-119 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22636 4. Location of well at surface 9. Unit or Lease Name 1848' NSL, 2837' WEL, SEC. 6, T13N, R10E i C0;~!?-L~;¥,.)~ I ~ Milne Point Unit 2675' NSL, 3609' WEL, SEC. 36, T14N, R9E Well Number MPF-14 ~ ...... - .......... .~:~.: Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Ser Sands KBE = 45.46' I ADL 355018 12. Date Spudded01/15/96 !13' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' water depth' if °fish°re ' 16' N°' °f C°mpleti°ns01/23/96 03/26/96 N/A MSLI One 17. Tota112768,Depth (MD+~T~/, D)17522 F~ 18. Plug12663Back ,,Depth7423,(MD+TVD)~19.FT~ []YesDirecti°nal I-INoSurvey120'1 Depth where SSSVN/A set ~21.MD, Thickness1800, (Approx.)°f Permafrost 22. Type Electric or Other Logs Run LWD, GR/RES/NEU/DEN 23. CASING, LINER AND CEMENTING RECORD CASING SE-I-rING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT80LHE 38' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 6690' 12-1/4" 1287 sx PF 'E', 250 sx 'G', 210 sx PF 'C' 7" 26# L-80 33' 12749' 8-1/2" 325 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", L-80 12134' N/A MD TVD MD 'I-VD 12334'-12414' 7113'-7188' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/70 bbl diesel Frac'A' Sand, 12334'-12414' 109000# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 05/16/96 I ES P Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing PressureCALCULATED . OIL-BBL GAS-MCF WATER-BBL O~L GRAVn'Y-API (CORR) Press. 24-HOUR RATE -- 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ~\~;' Submit In Duplicate Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) TKA3 12322' 7056' TKA2 12338' 7071' TKA1 12360' 7092' TMLV 12432' 7159' .. 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true and,coF(~ct//j to the best of my knowledge __~ 'Rm Schofiield Title Senior Drilling Engineer Date ~ . - Prepared By Name/Number: Kathy Cam~oa~or, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases-in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P F- 1 4 Rig Name: 2 7 E AFE: 3 3 7 0 0 4 Accept Date: 01/1 4/96 Spud Date: 01/1 5/96 Release Date: 01/25/96 Jan 14 1996 (1) Rig moved 80 %. Jan 15 1996 (2) Rig moved 100 %. Rigged up Divertor. Tested Divertor. Racked back drill pipe. Repaired Drillstring handling equipment. Racked back drill pipe. Made up BHA no. 1 Held safety meeting. Drilled to 262 ft. Jan 16 1996 (3) Drilled to 262 ft. Made up BHA no. 1 Pulled out of hole to 1000 ft. · Drilled to 3000 ft. Circulated at 3000 ft. Jan 17 1996 (4) .. Pulled out of hole to 500 ft. R.I.H. to 3000 ft. Drilled to 4772 ft. Circulated at 4772 ft. Pulled out of hole to 3000 ft. R.I.H. to 4772 ft. Drilled to 5060 ft. Jan 18 1996 (5) Drilled to 5500 ft. Circulated at 5500 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 5500 ft. Drilled to 6144 ft. Jan 19 1996 (6) Drilled to 6710 ft. Circulated at 6710 ft. Pulled out of hole to 5000 ft. R.I.H. to 6710 ft. Circulated at 6710 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 450 ft (9.625 in OD). Page ! Jan 20 1996 (7) Ran Casing to 6690 ft (9.625 in OD). Circulated at 6690 ft. Mixed and pumped slurry- 556 bbl. Displaced slurry- 502 bbl. Mixed and pumped slurry- 35 bbl. Rigged down divertor. Installed casing spool. Rigged up BOP stack. Tested BOP stack. Jan 21 1996 (8) Tested BOP stack. Made up BHA no. 3 . Serviced Drillfloor/Derrick. Repaired Drillstring handling equipment. Singled in drill pipe to 65500 ft. Circulated at 6550 ft. Tested Casing. Drilled cement to 6720 ft. Circulated at 6720 ft. Performed formation integrity test, 12.5 ppg EMW. Drilled to 7026 ft. Circulated at 7026 ft. Drilled to 7960 ft. Jan 22 1996 (9) " Drilled to 8180 ft. Circulated at 8180 ft. Pulled out of hole to 6650 ft. Serviced Block line. Repaired Mud pumps. R.I.H. to 8090 ft. Reamed to 8180 ft. Drilled to 8444 ft. Repaired Top drive. Drilled to 8709 ft. Repaired Top drive. Drilled to 9951 ft. Jan 23 1996 (10) Circulated at 9951 ft. Pulled out of hole to 8180 ft. R.I.H. to 9951 ft. Drilled to 10325 ft. Rig waited: Orders. Drilled to 11730 ft. Jan 24 1996 (11) Circulated at 11730 ft. Pulled out of hole to 10083 ft. R.I.H. to 11730 ft. Drilled to 12768 ft. Circulated at 12768 ft. Pulled out of hole to 12768 ft. R.I.H. to 12768 ft. Circulated at 12768 ft. Jan 25 1996 Circ, cond mud & hole to run 7" cag. Monitor well. Pump pill. LD DP. Check for flow @ 9-5/8" shoe. Cont to LD DP & BHA to MWD. Unload sources. Finish LD BHA. Pull WR. Change bails & RU csg tools. Run 7' csg. Circ 7" csg volume @ 9-5/8" shoe. check for flow. Run 7" csg. Page 2 Jan 26 1996 Run 7" csg. MU LJ. Land csg. MU cement head & hook up cement line. Break circ, build rate. Switch to Howco, do cement job. Pump freeze protection. Displace cement. CIP @ 1500 hrs. Test csg, LD csg tools. Rd lines, LD cement head, blow down lines, LD LJ, change bails. Install 7" packoff. ND flowline, choke & kill lines & BOPE stack. Install tbg spool, adaptor flange, hanger, test packoff, set 2-way check. Install tree, test. Pull 2-way check. Set BPV. Secure well. Release rig 01/25/96 @ 0400 hrs. Page 3 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P F- 1 4 Rig Name: 4 E S AFE: 3 3 7 0 0 4 Accept Date: 03/22/96 Spud Date: Release Date: 03126/96 Mar 23 1996 MIRU. Rig accepted 03/22/96 @ 0800 hrs. Load pipeshed w/DP & test RBP. Wait on adaptor flange, NU BOP's & test. Install wear bushing. Test waived by John Spalding w/AOGCC. MU RBP retrieving tool & PU 3-1/2" DP. Circ FP methonal out w/brine. PU 3-1/2" DP. Mar 24 1996 Cont PU 3-1/2" DP. Viscosify system up w/zanvis & add liquid csg, circ down to bridge plug @ 12097', equalize fluid w/5K on plug & release plug, RIH t/12128' & circ out oil & gas influx below plug. POOH w/RBP & retrieving tool, LD same. MU BHA, RIH. Cut drlg line & adj brakes. Cont RIH t/12182' tag sand. Wash frac sand f/7", 12182'- 12376'. Reverse circ, circ DP volume up each 60'. Mar 25 1996 Rev frac sand. Circ all frac sand from well bore & run csg. Wash as per program & displace well w/9.7 ppg until NTU 15. Monitor well. LD DP to top of perfs. Spot 40 bbl zanvis sweep w/5#bbl liquid csg. POOH, LD DP. Install 2-7/8" rams & test. RU, PU & MU pump assy & test. RIH w/ESP compl on 2-7/8" tbg. Mar 26 1996 RIH w/ESP completion, install lasalle clamp. Splice ESP cable. Cont to RIH w/ESP assy. Splice ESP cable at hanger. MU hanger & land same & RILDS. Change rams in BOP's to 3-1/2" & ND BOP's. NU tbg tree & test same. Pull TWC. Freeze protect well with 70 bbl diesel in annulus & 15 bbl down tbg, set BPV & install blind flange. Secure well. Rig release 03/26/96 @ 0600 hrs. Page ! ann inj-N27E-MP F-14 Rig Name ~ 'Legal Desc ~ InJ. Well Name (Sec, T, R) Sud Csg Dep 6690' Well Cum Total Cum Mud/Ctg Cum Brine Cum Water Cum Die~P VOLUME (BBLS' Method of dlsplosal=Pumping down outer annulus SOURCE WELL DATE OF MUD/CTGS BRaE WATER DIESEU FRE~E ~ COMPLICATIONS, COMME~S NU~ER I~E~ON PROT. MP F-06 1/28/96 90 MP F-06 1/29/96 188 40 MP F-06 1/30/96 165 MP F-06 1/31/96 275 MP F-06 2/1/96 547 MP F-06 2/2/96 270 MP F-06 2/3/96 545 MP F-06 2/4/96 2000 .130 MP F-06 2/5/96 INJ-N22E-MPF-14 ' .¢~ Rig Name :~;~;m,a ~,~~(~ ~.~'~,..,~ Legal Desc ~ ?..~ ~ ,. ,;~,,,~ ~:.~..:,, ~:.~:~;~..,~. Inj. Well Name I Surf Csg Dep 8766 Well Cum Total ~;~~~? Cum Mud/Ctg ~,~x~ :.,~.~ ~ ...... "'~ ' :' ~¢~¢~!~;;~~ Cum Brine Cum Water VOLUME (BBLS) Method of disp/osal=pumping down outer annulus i SOURCE WELL DATE OF MUD/CTGS BRINE WATER DIESEU FRE~E NUMBER I~ECTION PROT. Daily Cum. Total COMPLICATIONS, COMMENTS I I M PF-06 4 / 20 / 96 900 60. 00 MPF-IOi 5~23/96 960 40. O0 MPF-IOi 5/30/96 100 M P F- 10i 5 / 31 / 96 550 M P F- 18 6 / 7 / 96 550 MPF-18 6/1 0~96 200 MPF-18 6/11/96 475 MPF-18 6/1 3/96 147 MPF-18 6 / 14/96 290 MPF-18 6/15/96 650 60.00 Page 1 ********* ********** ********* ANAgRIg~ ********** ********* ~L~E~ ~**~**** *************************--************** COMPAHY BP ~L~ NAM£ MPF-14 U3CA~ION 1 MILN~ PT LOCATION 2 ALASKA NA694~IC D~LINAIIOH U.66 GRID CONVB~GJ~JCE ANGLE 0.00 DATB: 14-JAN-96 WI~LL HUMB~ 0 API#· 5002~22636 ~ ~AD LOCATION: LAT(N/-S) ,.IOB NLIMB~ 37567 AZIMUTH FROM ROTARY TAB~ TO TAk'~IZI' I$ TIE IN POINT(TIP) : I~:ASLIB~ DI~PTH 112o00 TRUE VERT DEPTH 112,00 INCLINATION 0,00 AZIMUTH 0,00 LATITUD~(H/-S) 0~00 D~PARTdRE(&/-W) 0.00 DEP(5/-W/ 315,89 ~'F-14 DIE'TH 112,00 154.70 ~'27,12 416,22 ~7,15 596,12 ~8,03 ~,75 ~0,53 9~,49 1057,82 I153,04 12~,24 1344,12 ft ft 0,0 ~.9 150,90 85,1 236,00 ~1,1 327,11 89.1 416.21 90,9 507,13 2.04 0,96 89,0 596.09 2,08 0.49 91,9 668,00 1.96 0,21 87.7 775,72 1,60 0,55 94.8 870,50 1,53 0,42 TAE~T SIATIOH AZIMUTH I~TITU~£ S~CTIOH INCLN, ft 6eg Eeq ft 0,~ 0.00 0.~. 0,00 0,12 0.37 ~'5.24 0.~ 0;~ 0,58 264,~ 1,16 0.48 2~,79 0,04 1.67 0,68 258,71 -0,10 , 231,~ ~1,78 ~,03 3,45 93,0 963,43 3,32. 2.08 94,3 1057,65 7,57' 3,52 · 95,2 1152,68 13.08 3.56 ~.2 1247.65 19,62 4,57 95.9 1343,11 -28,37 6,01 DEF'ARTUR£ DISF'LAC~ENT at E./-W ft ft 0,00 0,00 -0,11 0.13 -0,79 0.80 -1,62 1.62 -2,51 2,51 AZIMU?H 0.00 295,24 279.27 271,52 267.72 DLS d~ lOOft 0.00 0,95 0,36 0.11 0.23' -0,68 -3,63 3.69 259.40 0.52 -1,43 -4,47 4.69 252,28 0.54 -1,69 -4.56 4,87 249,67 0,72 -1,64 -3.99 4.31 247,61 0.40 -1.27 -3,51 3,73 250,13 0,70 ~8,~ 310.50 321,58 324.39 324.17 338,52 0,65 -4.10 4,15 22~.70 4.94 -5~78 7,60 ~3,32 10.30 -8,17 13,15 327+19 16,13 -11,~ 19,84 3'21,02 2'3,24 -16,78 28.67 1.53 0,35 1.16 1.60 1424.78 1529,39 1623.76 1716,57 1810,74 ~,7 1433,06 29,69- 8,26 94.6 1526,~0 54,53 9,70 94.4 1619,36 71,29 10,77' 92,8 1710.17 90,42 13.06 94,2 1801,79 112,09 13,66 315.~ 31.66 -24,26 39//4 316,69 42,39 -24,62 . 54,72 318,24 54,75 -45,94 71.47 319,71 6%22 -~,50 90,63 321,96 86,10 -72,23 112.38 322.43 320,77 320,00 319,~ 220,01 2,69 1,42 1,17 2,49 0,84 1903,40 .19:77,45 2091,17 2185,06 2280,64 92,7 1891,62 134,75 14,75 94,0 1982,60 158,55 14.59 93,7 2072,92 183.55 16,315 93,9 2162,47 211.68 18.57 95,6 2252,09 244,61 ~.06 31B,84 103.59 -&6.73 13~,11 318+10 121,42 '-102,53 156,92 318.08 140',~ -119,24 162,93 320,54 161.44 -137,58 212,11 324,50 187,81 -157,69 245.23 320.0/.. 319,82 319.59 319,56 319,98 1,44 0.26 1.90 .2,46 3,93 2372.~ 2467'.F/ 2652,74 27~.~ 92,2 2337,13 279.70 23.27 95,2 2423,~ 318,41 25,29 91.8 2506+22 358,64 27,27 9'2,9 258~.06 402.15 ~.27 95,8 2670,90 449,82 31.12 324.9I 216.80 -178,21 280.64 323,78 248.59 -201,03 319.70 224.65 281.57 -~4,79 360,30 '324,45 317,43 -250,33 404.26 324,32 3~6,61 -278.29 452,41 320,58 321,04 321,40 321.74 322.02 1,32 2,17 2,~ 2,15 1,93 2841,94 LxF24.11 202~,51 3123.89 ~17.25 93,4 2750,13 4?8.74 32,74 92,2 2826,72 549,71 34,86 95,4 2904,17 '605,21 36.59 94,4 2978.53 662,11 39.42 93,4 3~9.78 723,11 41,07 323,01 296,38 321.12 436,~ 2'20,46 479,95 2'21.16 525,00 32,2,18 5'72,31 -~7.~ 501,76 -339,19 553,03 -374,41 6O6,72 -411.12 6~,81 -4~.52 727,13 222.18 322,I7 222,04 321,94 321,91 1,87 2,57. 1.66 3.03 1,91 3310,50 3401,73 3493,~ 35~,40 3&~0,44 ~3,3 3119.91 784,18 41.29 91,2 3187,2~ 845,16 43.20 91.6 3253.08 908,66 45.19 93,1 2217.82 975+37 46,73 94,0 33~0,76 1044,90 49,16 322,55 3"~,52 669,71 -321,54 720,06 319,59 771,74 ~1,26 825,52 ! -486,05 788,59 321,95 0,42 -523,29 849,97 321,99 1,99 -562,69 913,64 321,99 2,29 -605.22 980.75 321.90 2,23 -649,63 1050.48 321,80 2,~) ,., MF'?- ! 4 , ******~****** ANAl)RIll. ************** SUE~J~ CALCULATIONS ************* CIRCULAR ARC MKI'HOI)******** TARG~ STATION AZIMUTH LATITUI)E S~CTION INCLN, N/-S ft. deg cJeg ft 1115.30 51.27 320.72 860,44 1189.45 53,45 321,76 938,52 1265,00 54.65 321.62 990,10 1340.8I 56.23 321,94 1057,98 141%00 57.29 3~.53 1119.21 DEPARTURE DISPLACEMENT at AZIMUTH EJ-W ft it deg -694,13 1121,16 321,75 -740.75 1195,63 321.72 -787,82 1271,56 321,72 -634.98 1347.78 321,72 -664,t6 1426,31 321,69 DLS lOOft 2,35 2.46 1.29 1,73 1,69' 4241,13 4334,49 4427,16 4521,90 4614,39 i . 470?-,.34 4802,61 4896.38 4991,24 51~3.19 94.4 3705,64 93.4 3751,56 92.7 379.4,20 9'4.7 3635,55 '9215 38,73,85 95.0 3910.97 93,5 3943,7E, 93.6 35'73.30 94,9 4002,97 91,9 4031 o51 1499.07 59.36 320,60 1181,26 1580,03 61,71 321,39 1244,42 1661.92 63,50 321,50 1308,77 1746,68 64,74 322,44 1375,90 1630,18 66,34 323,91 1443,29 1916,96 67,64 321.45 1512,79 2004.11 71.26 320.54 1580,78 2092,68 71.91 319,27 1648,69 2182.71 71,64 316,89 1715,73 2270.11 72,20 314,71 1778,39 -935,19 1506,63 321.63 -9~6,34 1587,91 321,60 -1037,62 1670,19 321.59 -1090.13 1755,42 321,61 -1140,56 113~,57 321,68 -1193,56 1926,95 321,73 -124~,64 2014,44 321,70 -1305,63 2103,19 321,62 -1366.02 2193,12 321,47 -1426.96 2280.11 321,26 2.19 2.63 1,93 1.59 2,25 2.75 4,00 1,45 2,40 2,33 5176,40 5270,11 5364.36 5458.02 5551.51 93,2 4059.89 93,7 4086,12 94,2 4116,66 93,7 4145,52 93,5 4174,41 2356.69- 72,34 ' 315,69 1841,40 2448,21 72,59 313.13 1903.93 253Z.94 72.16 313,34 1965,46 2626.96 71.94 314,04 2027,01 2715.63 72.06 313.66 20B8.62 -1469.52 2366.42 321,03 -1553,34 2457.19 320,79 -1616.78 2546.26 320,52 -1683,20 2634,76 320.29 -1747,31 2723.13 320,06 1.01 2,62 0.51 0,74 5646,51 5741,40 5636,3.1 5930,53 6024.22 95.0 4203,76 94,9 4233,65 94.9 4263,66 94.2 4292,60 ?3.7 4321.32 2806.11 71,95 313,58 2150.96 2696.07 71.34 312.61 2212.50 2985.95 71.80 312.41 2273,34 3075,40 72,44 311,43 2333,26 3164,32 71.85 311.49 2392,34 -1812,70 2812,92 31%88 -1876,47 2902,38 319.67 -1944.85 2991,74 319,45 -2011,54 3060.65 319.23 -2078,34 3169,04 319,02 0,15 1,17 0,52 1,15 0.62 6117,01 6211,43 6305,11 6396.53 6489,12 92,6 4349,7S 94,4 4377,63 93,7 4405,40 91,4 4433.03 92,6 4461,59 3252.36 72,42 311,26 2450,71 3342.19 73.02 310.76 25(79,87 3431.46 72.75 312.20 ' 2569,17 ~518,49 72.07 313,78 2628.59 3606,51 72.00 314.40 2669,87 -2144,62 3256,59 318,~1 -2212,65 3345.93 318.60 -2279,73 3434,79 318,42 -2343,47 .3521,55 318,28 -2406,73 3609.40 318,18 0,66 0,81 1,5P 1,80 0.64 6562 6626.43 6769.16 6863.64 69qB. ,91 , 7053.66 7146.35 7240.06 7332,31 ' 7425,94 · · ?3,6 4469,?~ 43,7 45O2,62 142,7 4542,47 94,5 4568.64 95,3 4595,02 94,8 4620,~6 92,7 4646,10 93.7 4673.14 ~2.3 4700,82 93,6 4730,49 3695.70 72.69 314.42 2752,31 -3737.50 73.70 314,84 2.781.6~ 3674,52 73.67 314.29 2877,86 3965,27 73,97 314,38 2941.30 4056,79 73.89 314.47 4147.93 74.59 313.71 3068,83 4237.05 73,66 314,68 3130,98 4326,74 72,78 314,24 3193,82 4414,71 72,31 314,26 3255,23 4503,47 70,73 314,20 3317.17 -2470,46 3698,43 318,09 · -2500,21 3740.16 318.05 -2597,66 3676,98 317,93 -2662,79 3967,56 317,85 -2.728,16 4058,97 -317,77 -2./93,6& 4149,97 317,69 -2857o56 4238,96 317,61 -2921,62 4328.55 317.55 -2984,66 4416,42 317,48 -3048,29 4505,07 317.42 0.74 2,49 0,39 0,14 0,13 1.07 1,40 1,05 0.52 1,68 SLMUEY MF'F-14 VmTiC DEP~ 1)EF~I'~ ft ft ft 75~,53 94,6 4761,63 7613.96 ~.4 4792,13 ~.94 95,0 48~.10 7~.07 96.1 ~5~,49 7896,58 91,5 4679,54 TARGET STATION AZIMUTH LATITUDE SI~TION INCLN, 4592,74 70.83 '313,91 3379,28 4681.00 71.06 313,80 3440.46 4771t09 72,16 315,01 - 3503,52 4862.60 72.~ 314,60 3568.02 494%6~ 72,07 3~4,7~ 3629,2~ DEPARTURE DISPLAC~ENT at ~-W ft ft -3112,46 4594.24 -3176o16 %82,39 -3240,55 4772.40 -3305,48 -3~7,41 4950,(~7 AZIMUTH 317.35 317,29 317,23 317,19 317,14 deg/ lOOft 0.30 0,28 1,67 0,41 0,25' 7~0,44 0083,90 8176.97 8270,66 836.4,78 8552,16 8647,34 8739.37 ~,9 49(X147 93,5 4937,~ ~,1 4965,S2 93,7 4994,36 94,1 5023,54 94,0 5052,31 93,3 5080,01 95,2 5108,09 ~.0 5134,97 93,8 5162,27 5036,94 72.03 313.95 ~91,72 5127.81 72,04 314,73 3753.~5 5216,39 72.28 315.05 ~16.38 5305,62 72,25 315,31 3879,68 5395,09 71.63 314.00 3942.57 5484.59 72,73 314,94 4005,29 5573,69 72.74 314.20 5&6~,60 72.95 314,21 4~31,24 5'752.59 73,09 315.06 4193,08 5642.33 73.0~ 314,43 4~6o28 -3431,24 5040,06 317,09 -3494,~2 5128.~ 317,05 -3557,58 5217.39 317,01 - -3620.49 5306,58 316,98 -3684,14 5395,99 316,94 -3748,03 5485,44 316.K) -381L,53 5574,50 316,86 -3376.73 5665,35 316,~2 -~39,35 5753,30 316,79 -4003,0~ 5842,~/ 316,76 0,84 0,79 0.42 0,26 1,47 1,51 0,76 0,22 0,91 0,66 8926,57 ?017,21 9108.33 ~00,22 93B9,10 9481.84 9575.24 9668,64 · 97~,99 93.4 5189.44 90,6 5215,86 91.1 5242,63 91,9 5271,03 94.7 5301,66 · 94,1 5331,96 92,7 5361.85 93.4 5~2.11 ~.4 5421,3~ 75.3 5450,46 5931,66- 73,10 314,66 4319,07 6018.35 73.00 315.52 4380,57 6105.45 72,63 314.7~ 4442,33 615~Z.~l 71.16 314.46 4503,71 6282.44 71,12 314.31 45~,43 ~71,54 71,32 314,79 6459,32 71,~ 315.06 6547.66 71.11 314,62 4753,26 6636,30 72,36 313.24 4614,79 6727.03 72.13 313.66 4677,36 -4066,65 5932,2~- 316.72 -4127,75 6016.95 316.70 -4189,18 6106,03 316.68 -4251.3~ 6193,36 316,65 -4315,46 6282,95 316,62 -4376,98 6372,01 316,59 -4441.I3 6459,77 316,57 -4503,77 6548,09 316,54 -4567,65 66.36,69 316,51 -4&q3,46 677.7,37 316,47 0,44 0,71 0,79 1,86 0.15 0,52 0,39 0,46 1.94 0,67 9855,0~ 9949,52 10041.58 10134,81 10226,76 10322.64 10414,15 10507.76 10694,33 9[.1 5478.70 .~13.57 71.76 313,41 94,4 5506,31 6~3.13 71.70 312,54 ~,t 5537,37 699Q.~ 71,50 313,62 93,2 5566.98 7078,74 71,47 314,35 ?2.0 55;96,25 7165,85 71,40 313,35 95.9 5628,21 7256,18 69.65 314,14 91,5 566.2,16 7341,13 66,79 315,26 93,6 5700.79 7426,37 64,47 315,89 94,2 5743.03 7510.53 62.22 314.40 ?2,4 5766,71 7570,61 56,51 314,46 4937.13 '-4696,14 ~13,88 316,43 4998,26 -4761,74 6903,3? 316,39 5056,03 -4825,44 6990,.~ 316.35 5119,53 -~88,94 7078,94 316.32 5179,92 -4951,80 7166,02 316,29 5242,42 -5017,11 7256,33 316,26 5302,16 -5077,51 7341.2.7 316,24 5363,07 -5137,1~ 7426,52 316,23 5422,73 -5196,53 7510,65 316.22 5476o~ -5253,88 7590~93 316.20 0,62 0.89 1,3~ 0,54 1,04 3.32 2.56 2.77 4,02 ,10787,W 10880,44 10774,6~ 11069,33 11163,01 · · 99.7 5640,09 7669,03 54,93 312,64 92,4 5894,91 7743,32 52,33 312,07 94,2 5554,02 7B16.42 49.90 311,10 94,7 6017,12 78.~,~ 46,54 312,68 93.7 6083.46 7952,88 43,28 312,79 b'532,70 -5310,60 7669.12 316.17 b"50.3,05-5365,60 7743,39 316.14 5631,71 -5420,43 7816,47 316,10 5678,84 -5473,02 768.6,?0 316,06. 5723,71 -5521,59 7952,91 316,03 4,16 2,85 2,70 3,77 3.48 f'c ft ft 11257.~- 94.5 6154,39 11351,95 94,4 6229,03 11446.12 94,2 J306.50 11541,53 95,4 6367 11632,94 91,4 6467,69 11720,41 11021.46 11915.84 12009.09 12101.31 121~.46 1238t.42 12475.36 12~,72 12766.00 95.5' 6553,72 93,1 6636,47 94,4 6724.69 93,2 6810,36 92,2 6695,75 94.2 6983.51 93,7 7071.09 92.2 7157,49 93,? 7245,74 93.4 7333.68 95,9 7424.33 103,3 7522,46 SU~V)~Y CALCULATIOHS w****w******w CIRCULAR ARC ~l'HOI>***w,~ TA~G~T STATIDH AZIIIU~H LATITUI)E SECTI~ INCLN, 601~.22 39.4~ 313.6I ~.41 8073.~ . ~.13 315,~ 8126.~ 33,17 317.16 6176.~ ~.~ 3~5.97 ~1,87 8~.50 27.4~ 315.~6 6262.25 24,49 313,14 5942.37 8300.68 24.32 314.~ 5969,07 6339,02 23.64 313,76 5995,~6 8375.63 22.88 313.77 6021.34 8410,64 21,49 314,98 6444.74 20,99 315.~ 6069.9~ 6478.11 20.73 317.06 6094,17 8510.38 20.24 316.~1 6117,75 8542,61 19.89 315,98 6141,09 8574.13 19.55 316.37 6163,83 (S605.52- 18.66 315,62 6186,41 **** PROd'~r~-~II~ lO Il) ..... ~637.73 17,70 314,73 6209,27 I')P?-14 I)~TLIF~ I)ISPLACP.~I~T at EY-W ft ft -b'567,10 B015 -5608,40 8073.06 -5645,45 6126,59 · -5679,B1 8176.57 -b'710,56 8220.52 AZIMUTH DLS ~ lOOft 316.01 4,13 316.00 3,65 316,00 3.34 316.00 3,33 316,00 2,93' -5740.50 B262,26 315.99 3.19 -b'766,16 6300.69 315,9B 0,78 '5795.61 8339.03 315.97 0,85 '5622,21 6375,63 315,96 0,81 '5647,10 B410o64 1315.96 1.59 '~71.04 8444,75 315,95 0,64 -~9~.03 B478,12 315,96 0,53 -5916,06 8510,38 315,96 0.54 -59"J~L~ 8542.61 3~5,96 0,47 -5960,12 8574,:3 315.96 0.39 -5981,92 B605.53' 315.96 0.96 -6(X)4.63 8637.74 315.96 0.96 96 03:49PM SHRRED SERVICES DRILLIMG ALASK, ~LAND GAS CONSERVATION COb, .... SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request' ~ Aban~lon [] Suspend [] Plugging [] Time Extension [] Perforate ' [] Alter Casing [] RepalrWell [] Pull Tubing I'1 Verfane~ [] Other [] Change Ap_proved Program [] Operation Shutdown [] Re. Enter Suspended Well [] Stlmulete Annular Pumpln._~g 2. Name of Operator 15. Type of well: 6, Datum El~/ation (DF or KB) BP Exploration (Alaska) Inc, / ~ Development KBE -- 45.46' ~ Exploratory 7. Unit or Property Name ,3. Addre~ [] Stratigraphic Milne Point Unit P,O, Box 196612, Anchorage, Alaska 99519-6612 · []Service 4. Location of well at sudace 1848' NSL, 2837' WEL, SEC. 6, T13N, RIOE At top of productive interval 2576' NSL, 3,609' WEL, SEC, 36, T14N, RgE At effective depth 2754' NSL, 3685' WEL, SEC. $$, T14N, R9E At total depth 2777' NSL, 3708' WEL, SEC. 36, T14N, RgE ?-iiGINAL 8. Well Number MPF-14 -9. Permit Number 95.212 10, APl Number 50-029-22636 __. 11. Field and Pool Milne F'Olnt Unit / Kuparuk River Sands 12. Present well condition summary Totaldepth; ' measured 12768' feet true vertical 7522' feet Effective depth: measured 12663' feet true vertical 7423' feet Plugs (measured) Junk (measured) Casing Length Size Cemented MD TVD Structural Conductor 80' ~.0" 250 ax Arcticset I (Approx,) 110' 110' Surface 6650' 9-.-.~8" t~a? sx PF'E', ~.~0 ~ '<3', ~0 ~x PF 'C' 6690' 4520' Intermediate Production 12690' 7" 325 sx Class ~G' 12749' 7604* Liner Perforation depth: measured 12334~ - 12414' R E C E ~V true vertical 7113' - 7188' JUN 0 3 ~996 Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing w/Centriliff ESI= a~$embly to 12134' MD Alaska 0il & (~a~ Con~, Coral Packers and SSSV (type and measured depth) N/A Anchorage 13, Attachment~ [] Description summary of proposal [] Detailed operation~ program [] BOP sketch 4. Estimated date for oommencing06/03/g6operation 115. Status of well classifications as: 1'~, If proposal was verb~ily"~proved ......... I I~ Oil [::] Gas [] Suspended ~ame of appmv~.~ ...... D~te a~provedI ~ont~ct Engineer Nam~be~ Jam~ RobeSon, ~4.61~ P~a~d ~y Nam~Number Kathy Campoamor, ~:~ hereby certify that ~e forej;loing is true f~r~l Gorreot to the beet of my knowledge Signed "~/';"~~'~~" ~/~1/~.~, Title Senior Drillin~ Engineer Commission Use Only Conditions of Approval: Notify Commission so representer'rye may witness Date ) ission __ IApproval No. ~'~6 /_.7___ -' Submit In Triplicate Plug integrity ~ BOP Test Mechanical Integrity Test ~ Approved by ord?~r.,of the Commission Form 10-403 Rev. 06/15/88 Location ¢learanoe ,,_ Subsequent form required 10- /.fo '7 Original Signed By David W. JohnstO~" Commissioner ."~ '"';/ed Copy R~turned '96 03:56PM SHRRED SERVICES D~ILLIMG Operator Bp ExploriUon Field Miln¢ PoinL Morning Drilling Report P.1 Well MPF- 14 Rig Nabors 271q 06:00-06:15 06:15 06:1~-11:30 06:15-11:00 11:00 11~00-11:30 11:30 11:30-L3:00 11:30-12:00 12:00 12:00-18:00 12:00-17:30 17:30 17:30-18:00 18:00 18:00-18:30 18:00-18:30 18:30-20:30 18:30-20:00 20:00 20~00-20=30 20:30 ~o-21.oo 20:30-21:00 21:00 06t00 21:00-23:00 23:00 23:00-25:30 23:30 23:30-06:00 Report 8, pa~e 3 Da~e 06:00, 21 lan 96 RECEI NO Accidentz*No Spills*224 Days No LTA'~ Tested BOp stauk Teste~ ~OPE to 250/~000 psi; annular to 250/3500 9si. Witnessin~ waived by John S~auldin~-AOGCC Field I~pectOr. Pressure te~E con%Dieted successfully - 5000.000 psi ~HA run no. $ Made up BHA no, 3 Strap ~HA. PU same. Orient MWD. Load sources in LWD. MU BHA. T~S~ ~. B~ no. 3 made up S~rvice~ Drillfloor / Derrick E~ipment work R~air Re~aired Drillstrin~ handling e~tDment Repair broken tor~ a~ on Iron Roughneck, E~fpmen/ work c~leted B~ run no, ~ Singled in d~ill pipe to 65500.0 ~t ~icked up 144 ]t~ ,~, ~ 36 J=s 'S' DP. ~SM-a~vi~w STOP 180 Joints Picked Up CirCUlated at 65~0.0 f: Hole displaced with Water based ~u~ - 110.00 % P~rfo~ integrity test T~sted Casing Test c~g to 3000 psi f 30 ~n-OK, Pressur~ =e~t ~o~leted successfully - 3000.000 psi . B}~ r~ no. 3 ~rilled cemen~ to 6720.0 f~ Drill ~,, c~en~, pS, ~ 10' ne~ hole. ~C ~op 0~ n~w hole seo~ion : 6720.0 fL Ciroulated a~ ~720.0 ~ Hole displaced wi~ Wa~er baged mud ~ 120.00 % displaced Perform integrity tes~~:-~-..-.,~ ............. Performe~ fo~ation integrity t~t .......... Obtained re~ired level of inz~grity - 11.500 ppg BHA run no. 3 ~~.'~=~rr,-m~-,-:.:-~.,~.:%. :.. ....... ..... -..-...~~ Drilled to 70~6.0 ft Shakers loading up. Reached limitations of Circulation rate "~ circulated at 702g.0 ft CBU $ reduced za~e to clear shakers. NSsk~,, Anchorag, ~oZe df~lac~d with Wa~er ba~e~ mud - 120,00 % di~Dlaeed ~T~-Hous~keeRin~. .~' .,. ~ FIT RECEIVEC MAY ;5 11996 ED ~96 Commissio. Alaska 011 & Gas Cons, Commission Anchorage '96 OB:49PM SHRRED SERVICES DRILLIMG P,3 Request to AOGCC for Annular Pumping Approval for MP F-14: 1, Approval is requested for Annular Pumping into the MP F-14, 9-5/8" x 7" casing annulus. After reviewing records it has been determined that; MP 1:.'-14 ALREADY HAS A PROBLEM FREE ANNULAR INJECTION TRACK RECORD HAVING A CUMULATIVE TOTAL OF 5,1300 BBL OF INJECTION. THERE ARE NO OTHER WELLS WITHIN ~00' OF THE SHOE THE CASING SHOE MEETS'I'HE SHARED SERVICES DRILUNG SET DEPTH CRITERIA. NO WORKOVERS HAVE BEEN DONE ON THE WELL NO CASING WEAR PROBLEM SHOULD BE PRESENT SINCE THE WELL WAS DRILLED POST 1994 WITH ARNCO 200XT HARDBANDING, FULL RETURNS WERE RECEIVED DURING SURFACE CASING CEMENTING. THE CALCULATED TOP OFTHE TAIL CEMENT IS :1:200 TVD FT ABOVE THE BASE OF THE SCHRADER BLUFF SAND, 2, The base of the Permafrost for all wells located in the Milne Point Unit is :1:1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II inje~tion activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injeotlon Order #10, There are no domestic or industrial use water wells located within one mile of the project area. 3, The g-5/8" casing shoe is set at 6,690' md (4,475' tvd ss) which is a minimum of 500' tvd below the Permafrost and into the Seabee/Colville formation which has an established history of annular pumping at Milne Point. 4. 'There are :1:24 wells on Milne Pt. 'F' Pad, There may be additional unidentified wells within one quarter mile distance from the subject well, There are no domestic or industrial water use wells located within one mile of the project area, 5, The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES", 6. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# LB0 casing is 4,325 psig. The break down pressure of the Seabee/Colville formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling "Recommended Cuttings Injection Procedure", 7. A deterr~ination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone, 8, The cement design for this well en=ures that annular pumping into hydrocarbon zones will not occur. JUN 0 0il & B~ Cons. Ancho[~e ANNULA~ P.4 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY I$ 17.0 PPG BURST PRESSURE 9-5/8" 40# L-80 CASING; COLLAPSE 7", 26#, L-80 CASING: $750 PSI 5410 PSI 9-5/8" SURFACE CASING SHOE DEPTH: 6,690' MD/4,475' TVD ss HYDROSTATIC PI~.ESSUR.E__@._4,611 TVD WITH VARIOUS DENSITY FLUIDS: (0,0'52) X (4475) X (FLUID DENSITY) -- HYDROSTATIC PRESSURE 80% OF 7" COLLAPSE PRESSURE = (5410 PSI) X (0.8) = 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PS1 AT ANY SURFACE CASING SHOE DEPTH (TVD ss); 4,4 7 $ i HYDROSTATIC MAXIMUM ALLOWABLE PRESSURE AT SURFACE 7" COLLAPSE ANNULAR INJECT[ON FLUID DENSITY CASING SHQE DEPTH PRESSURE (80%) SURFACE PRESSURE (PPG) ,,. (PSI) (PSI) (PSI) 8 1881 ,.60 4328 2000 g 2094.30 4328 2000 ....1 0 2327,00 ,,4328 2000 I 1 2,.5_,59.70 4328 1 768 1 2 2792.40 4328 1536 i ii I 3 3025,10 4328 1303 ,1, 4 3257.80 4328 1 070 1 5 3490,50 4328 838 ,1,6 ' 3723.20' .,..4..328 605 ....... _~ ~L 17 3955,90 4328 372 Disposal: 1 ) Cuttings EIVED JUN 0 199 Alaska 0ii & Ga~ Con~. Anchorage Utilize Milne Point Reserve Pit at "A' Pad, Refer to Milne Point Field Operating Procedures/Beneficial Product Reuse and Waste Management Procedures for specifics. Please be aware that: 2) · Pre-approval by the A-Pad Operator is required prior to off loading ,Fluid Transfer permit is required prior to off-loading · Contact Milne Point Environmental (Nell or Vic=) at x6473 for assistance prior to sending. Class II Fluids 22E may use annular disposal as per normal procedure. We (BPX) DO have a Ballot Sharing agreement with Kuparuk (Ballot KRU 236) which allow for disposal of exempt, Class II liquid waste. Therefore, the Class I! clisposal well at Kuparuk may be used for liquid Class II (downhole) material from Milne. MPU Environmental Tachs will be trained as Certified Waste Generators for the bridge-out period, so coordinate all Kuparuk well disposal activities with Nell and Vic, Note,; The Kuparuk Disposal well has a solids limitation of <2%, If frac sand can not meet this limitation, pits will be constructed to contain the material, 3) Class I Fluids. Pad 3 will not be accessible during breakup, Temporary pits will be constructed to =ontain cement rlnaate if the rlnsate can not be annular injected. Contact Nell/Vic prior to placing material in the pits. Re- Use these fluids as appropriate. Boiler Blow-down has been approved to be re- used as mud make-up water, Cement dnsate Re-use options must be approved on a case-by case basis from MPU Environmental. _ '96 03:48PM SHARED SERVICES DRILLIMG BP EXPLORATION (ALAS._A) PRUDHOE BAY, ALASKA FAX # (907) 564-5193 P.1 TO: COMPANY; LOCATION: Blair Wondzell I AOGCC _ ._ Anohorage FAX #: 276-7542 - FROM; LOCATION: PAGES TO FOLLOW: 3 COMMENTS: Kathy Campoamor SHARED SERVICES DRILLING ANCHORAGE, ALASKA PHONE #: 564-5122 DATE; 6-31-96 10-403 for MPF-14. Annular pumping request. Please let me know if anything else is needed. I'll be here until 5:00 today. JUN 0~ 1996 IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) 564-5122 ~ ~6 ~:~O~M B~ E×PLOR~TIOM $'~ 21'96 6:2~ ~No.O09 1S~g aO0~ ;eob E7g~ ~OOI 1801 ' \~'~J/~' '_~Vell Name: :M-.P-U F'14 TT -- ~ Dale: 1/20/.0 , )/' ~u,~v,,or, ro~ ~,:~,,,, --. .... ~ 1, .~1 1, ~, .... - , -- . - , .//. /' ~' ' :.. ..... .,' .'- .. 'o.os~=~ ~/'/ ?." .~..,,,o,o. x.,.",,...,'.-- ' , , .' /" LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP ¢ ~ MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CCL FINAL BL+RF Date: RE: 19 March 1996 Transmittal of Data ECC #: 6596.01 Sent by: HAND CARRY Data: CCL Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 9 Anchorage, AK 99518 O7) 563-7803 Received by: Date: RECEIVED APR 0 9 1996'. Alaska Oil & Gas Cons. Corr~mission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION Date: 28 February 1996 Transmittal of Data MPF-22 i LDWG TAPE+LIS Run ~ 1 Run $ i Sent by: HAND CARRY ECC No. 6595.00 6596.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 to (907) 563-7803 Received by: Date: ~'~/~&~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive A~chorage Alaska 99501-3192 Re: THE APPLICATION OF BP EXPLORATION (ALASKA) INC. for an order granting an exception to spacing requirements of Conservation Order 205 to provide for the drilling of the BP Mi!ne Point Unit F-14 development oil well. Conservation Order No. 366 BP Exploration (Alaska), Inc. Milne Point Unit F-14 December 22, 1995 IT APPEARING THAT: . BP Exploration (Alaska), Inc. submitted an application dated December 1, 1995 requesting exception to the well spacing provisions of Conservation Order 205 to allow drilling the BP Milne Point Unit F-14 development oil well to a producing location within the southwest quarter of section 36 T14N RgE Umiat Meridian , Notice of opportunity for public hearing was published in the Anchorage Daily News on December 6, 1995 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: , The BP Milne Point Unit F-14 well as proposed will be a deviated hole drilled from a surface location 1848' from the south line (FSL) and 2838' from the east line (FEL) of Section 6, T13N, R10E, UM to a proposed producing location 2663' FSL and 3578' FEL of Section 36, T14N, R9E, UM. , Offset owners Oxy USA, Inc. and Arco Aklaska, Inc. have been duly notified. . The proposed producing location for the subject well is in close proximity to the southwest quarter of section 36 T14N R9E UM, which contains the Milne Point Unit F-13 development oil well. . An exception to the well spacing provisions of Conservation Order 205 will be required if the BP Milne Point Unit F-14 development oil well is inadvertently drilled to a producing location within the southwest quarter of section 36 T14N R9E UM. Conservation Order--~%. 366 December 22, 1995 CONCLUSION: Granting a spacing exception to allow drilling of the BP Milne Point Unit F-14 well to the sQuthwest quarter of section 36, T14N R9E UM will not result in waste nor jeopardize correlative rights. NOW, T~EREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc.'s application for exception to the well spacing provisions of Conservation Order 205 for the purpose of drilling the Milne Point Unit F-i4 well is approved. DONE at Anchorage, Alaska and dated December 22, 1995. jAlaska. Oil n~servation Commission David Norton, P.E., ommissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that with/n 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely fried. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or marls (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Super/or Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court hms from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing ',vas filed). 05:1~PM ~RCO ~K L~MD DEPT BP EXPLORATION November I7,1995 ARCO Alaska Inc. Attn: James R. Wincgamer, Senior Landman P.O. Box 100360 Anchorage AK 99510-0360 Vax: BP Explorallon (Alaska) Inc. got) E~t Beneon Boulevard RO. BOX 196612 Anchorage, Alaska g9519-6612 (907) 551-~111 Post-ItTM brand fax transmittal memo 7671 Re: Letter of Non-Objection for MPF-14 Well Gentlemen: The AOGCC has requested that we obtain a letter of Non-Objection from ARCO for the Dfilting of our MPF-14 weft as the wellbore witl cross the northeast portion of ADL 355023, which is owned by ARCO. We would ti~e to note that BP is in negotiation with ARCO to acquire the eastern portion of this lease, AS part of these &iscussions, BP has agreed to let ARCO review BP's well data just offsetting this lease i~cluding MPF-14. the foregoing is acceptable, please so indicate by signing ~ud ~etu~ag this letter a~eement to the undersigned. Thank you for your prompt attention to this matter. Sincerely, Mark S. Bendersky Milne Point Commercial Manage~ Telephone 564-5672 Fax 564-4440 Accepted and agreed to this By: ,day of TONY KNOWLE$, GOVERNOFI ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 26, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPF-14 BP Exploration (Alaska), Inc. 95-212 1848'NSL, 2837'WEL, Sec 06, T13N, R10E, UM 2838'NSL, 3787'WEL, Sec 36, T14N, R09E, UM Dear Mr. Schofield: 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, David W John Chairman BY ORDER OF THE COMMISSION ljb/encl c: Dept offish & Game, Habitat Section - w/o encl Dept of Environmental Conservation- w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratoryi-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 45.2 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1848' NSL, 2837' WEL, SEC. 06, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2663'NSL, 3578' WEL, SEC. 36, T14N, R9E MPF-14 2S100302630-277 At total depth 9. Approximate spud date Amount 2838' NSL, 3787' WEL, SEC. 36, T14N, R9E 01/01/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 355023 2442 feet No Close Approach feet 5083 16180'MD/7564' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle 68 o Maximum surface 3005 psig At total depth (TVD) 7035'/3758 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NTSOLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 6626' 31' 31' 6655' 4525' 1284 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 M-Bt 12113' 30' 30' 12413' 7360' 309 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECF;IV'ED Conductor Surface Intermediate ~0V ~ 01 ~9~ Production Liner jll~ 011 & Ga~ Corts, Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl'-I 20 AAC 25.050 requirements[] 21. I hereby cedif~hat~ f~regoing.~ ~ true and correct to the best of my knowledge /t Signed , Tit I e Senior Drilling Engineer Date I Commission Use Only Permit Number I~PI number Approval date j See cover letter ~,_~"-..~..,/'.2--- 150- 0.7._¢--' Z 2 ~' -~' .~' //%/'Z.(-¢ __//¢~.. for other requirements Conditions of approval Samples required [] Yes ..~No Mud Icg reqbired I'lYes .]~ No Hydrogen sulfide measures [] Yes ~'I No Directional survey required J~ Yes [] No Required working pressure for DOPE [] 2M; 1-13M; ~5M; I-IIOM; i-115M; Other: Original Signed By by order of Approved by Oavid W. Johnston commissioner tne comm,ssion Date Form 10-401 Rev. 12-1-85 Submit in triplicate BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From' Date: Subject: Bob Crandall, AOGCC Chris West, BPX (Shared Services Drilling) November 29, 1995 Application for Spacing Exception for the Milne Point Well F-14 (20 AAC 25.055) The MPF-14 well is planned to drill into the Kuparuk River formation in the west half of Section 36, T14N and R9E. This section is located to the south of the Milne Point Unit boundary. This section is bounded on the south by quarter sections within ADL 355023 for which the operator is ARCO 100%. The MPF-14 well is planned as a high angle producer to be completed with an electric submersible pump. Entry point in the Kuparuk formation (C1 Sand) is 2663' NSL and 3578' WEL in Section 36, T14N, R9E and TD at 2838' NSL and 3787' WEL, Section 36, T14N, R9E. We have notified ali owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4466. Respectfully, ChC'is West cc: BPX ARCO Alaska Inc tkEC, EI'VED NOV ;5 0 1995 Alaska Oil & Ge~ Cons. Commi~ And'~rage CRW/klc WELL PERMIT CHECKLIST FIE ,D Poo,. PROGRAM: exp [] dev~ redrll [] serv [] /! ADMINISTRATION REMARKS 1. Permit fee attached .................. '~'~"~ 2. Lease number appropriate .................. 3. Unique well name and number .............. ~ N 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary..~ N 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ...... Y 8. If deviated is we!lbore plat included ........ 9. Operator only affected party ............... y 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ~' N ENGINEERING . 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ -~ N 16. CMT vol adequate to circulate on conductor & surf cng. .~ 17. CMT vol adequate to tie-in long string to surf cng . · ·~;~Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... .~Y N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... N 26. BOPE press rating adequate; test to ~--~>t~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential o v er pressure zones ..... 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDN ~ Comments/Instructions: HOW/lib - A:/FORMS%cheklist rev 11/95 i~.RTH SLOPE ERD WELL ]Well Name: ]MPF-14 I Well Plan Summary I Type of Well (producer or injector): I KuparukProducer I Surface Location: 1848' FSL 2837' FEL Sec 06 T13N R10E UM., AK. Target Location: 2663' FSL 3578' FEL Sec 36 T14N R9E UM., AK. Bottom Hole 2838' FSL 3787' FEL Sec 36 T14N R9E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1330199 I I Rig: I Nabors 27E I I Estimated Start Date: IJan 1' 1996 Operating days to drill and case: 115 I IMD: ] 12413' I I TVD: 17360' BKB I IKBE: 146' I IWell Design (conventional, slimhole, I Ultra Slimhole, 7" Longstring etc.): I Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1804' 1795' n/a NA (Top Schrader) 5286' 3975' 1653 psig / 8.0 ppg OA ' ' 1744 psig / 8.0 ppg Base Schrader Bluff 6455' 4445' 1848 psig / 8.0 ppg Top HRZ 11496' 6662' n/a Base HRZ ' ' n/a Kupark D Shale 11789' 6882' n/a Kuparuk C ' ' 3598 psig / 9.6 ppg Target KUP A3 11988' 7035' 3616 psig / 9.6 ppg Total Depth 12413' 7360' n/a Casing/Tubing Prol,ram. Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 6626' 31/31 6655/4525 8 1/2" 7" 26# L-80 M-Bt 12383' 30/30 12413/7360 N/A (tbg) 2-7/8" 6.5# L-80 EUE 11660' 29/29 11689/6802 8rd Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7035' TVD. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: [Open Hole Logs: Surface Intermediate Final iCased Hole Logs: LWD GR/Resistivity LWD GR/Resistivity/Neutron/Density None Oil & Gas cons. Commission Ancflomge A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. AP1 # 50-029- November 29, 1995 RTH SLOPE ERD WELL Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. This well a long departure well Milne point and therefore we should be vigilant in monitoring all stuck pipe and hole cleaning properties. Torque and drag will be monitored and recorded for hole cleaning issues and for future well planning. See mud section for additional detail. Surface Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 9.9 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The well control manual should be reviewed for a refresher. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I I OV: 1800' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 66 degrees < 4 degrees 40° Degrees No - See Traveling Cylinder report There are no flowing close approach wells for drilling MPF-14. There are other well in the area but do not enter a flowing close approach condition. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. ERD Aspects: This well is an extended departure at this depth and should be drilled with due attention to ERD drilling practices. The lessons learned on MPF-38 and MPF-30 should be used to drill this well as efficiently as possible. APl # 50-029- November 29, 1995 ,, ~RTH SLOPE ERD WELL Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. pit can be opened in emergencies by notifying Karen Thomas (564-4305) The Milne Point reserve with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request to AOGCC for Annular Pumping Approval for MPF-14 1. Approval is requested for Annular Pumping into the MPF-14, 9-5/8" x 7" casing annulus up to a maximum of 35,000 BBL of a density of 17 PPG. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 6656" md (4525' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 1987 psi for a 10.4 ppg fluid in this well. MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 12/31/95 Milne Point 1/1/95 - 12/31/95 Milne Point F-25 230 35,000 1/1/95 - 12/31/95 Milne Point F-37 0 35,000 1/1/95 - 12/31/95 Milne Point F-38 0 35,000 1/1/95 - 12/31/95 Milne Point F-45 0 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 - 12/31/95 Milne Point F-61 0 35,000 1/1/95 - 12/31/95 Milne Point F-6g 0 35,000 1/1/95 - 12/31/95 Milne Point F-78 0 35,000 1/1/95 - 12/31/95 Milne Point F-70 0 35,000 1/1/95 - 12/31/95 Milne Point F-30 0 35,000 1/1/95 - 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. t0V 30 1995 AP1 # 50-029- November 29, 1995 [ ~- ~TH SLOPE ERD WELL DRILLING HAZARDS AND RISKS: See both the updated Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Several F- Pad wells lost varying amounts of mud (up to 1000 BBL per day) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing, followed by the well flowing back whole muds. See a discussion of this in the Formation Pressure section. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Lack of proper hole cleaning parameters appears to have contributed to this problem. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.2 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. Several wells from F pad have exhibited "breathing" of mud, alternating loss and flow back of uncontaminated muds volume. No oil, gas, or other formation fluid influx have been confirmed even when large fluid influx have been measured. In spite of this we will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. When this occurs, the drilling superintendent should always be quickly notified and kept appraised. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. RECEIVED I 0V 3 0 B95 Alaska Oil & C-,as Cons, C~nrnl~ AP1 # 50-029- November 29, 1995 ~,RTH SLOPE ERD WELL MP F-14 Proposed Summary of Operations 12866 Feet Displacement , . . . . . 10. 11. 12. 13. 14. 15. 16. 17. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. Prepare location for fig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill a VERY SMOOTH "ERD" BUILD UP 12-1/4" surface hole to 6656' md (4525' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Ensure the mud is suited for ERD wells with lubrication, monitored for Torque and drag. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to TD at 12413' MD (7360' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. MAke sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to MPF-6. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the ESP completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. RIH with ESP completion on 2-7/8" EUE 8rd tubing. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK . Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. 2. A CBL/GR/CCL is not required on this well. . An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. , The drilling rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. AP1 # 50-029- November 29, 1995 MPF-14 Cement Calculator Milne Point Cement and Centralizer Calculations Well [MPF-70 J Surface (1 Stage) Cement Job I cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 BPF + 30% 0,0725 BPF + 100% 0.1116 ~ Depth I BBLS Cu. Ft. Sacks Top of Cemenl Shoe Depth ~ Calculated G Tail Volume 623 51.2 288 250 6033 E Lead Volum~ 1500 167.3 940 433 4533 E Tail Volume 4533 328.7 1846 851 0: Total E 1 284 ~Total G 2 5 0 9-5/8" Bows I 0 Production 1-Stage Cement Job Cement yeild Hole Size 8.5 G ST1 Slurry 1.15 Casing Size 7 BPF 0.0226 BPF + 30% 0.0294 Stage 1 BBLS Cu. Ft. Sacks Formation /op~ 63 356 309 . ~- .~ TD ~~ Centralizers 6 5 Turbulators Total G ST1 309 Total ST Blade~ 6 6 Page 2 IVORTH SLOPE ERD WELL MPF-14 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 1284 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS' 250 FLUID LOSS: 100-150 cc YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. AP1 # 50-029- November 29, 1995 )RTH SLOPE ERD WELL MPF-14 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 309 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kupamk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9- 5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8"" x 8-1/4" Straight Blade Turbulators needed is 35. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm until the plug bumps, but not more than to displace cement just above the production zone. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kupamk Sands with 30% excess over a guage hole. F E. CP21VED AP1 # 50-029- November 29, 1995 Alaska StaLe Pl. ane'/Xone4 Milnc I:)t,' MPI.i' M[)ti' 14 WP] I.)I{ELIMINAR¥ WEI_,I,I)],AN BURTON 11/15/95 7:32 am cR[ r,:a, '.a[.t"o^r^ _ _ . r[£ [N K~P ' S .....00 0 ~: 3;~0.00'B00 0 N 0 1.00'/100 rt START D[ ~I/[LD IlO0 3 00'320.00' 1100 6 N 5 ~ 1.50'/100 START OF BUILD 1400 7 90'320.00' 1399 27 N23 t e.~0'/100 END OF ~UILD tTO0 13-50' 320 00' 1693 69 N 58 B~se 1805 13.50' 320 00' 119'3 88N 73 STAR[ 0F' 1900 13.50' 320-00' 1888 105 NBB CuRvE e 2.DO'/~O0 Ft STARt oF 3163 45.00' 325.00' E916 5% ~ 448 CURVE ~ a.50'/100 r~ END ~F' CURVE 407a 66.30' 3tS.a6' 3487 ll6a N 931 ~ i~n~s §~86 66.30' 3tS.a6' 3975 195aN17t4 B,se S .... deP 6456 66 30' 315.~6' 4445 2712~ N 246B ;TART 0F 1035866.30' 315.26' 6014 5251N4983 CURV~ ~.00'/100 Ft END OF C~VE1 16B9 40.09' 310.00' 6805 5971N 5754 TKUD [1789 40.00' 3tO.OO' 6882 6013 N 5B03 7035 6095 N S90I TARGET ~9B9 ~0.00' 3~0.00' 703S GOgS N sg0t T~LV t2t~3 ~0.00' 3~0-00' 7~30 6t~6N VERTICAL ~E;¥ SCALE 1000 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD o--e o oo' ~ o ~D TIE IN HORIZONTAl, VIEW (TRUE NOR'I'll) SCALE 1000 l't. ~ DIVISION SURVEY RI':I": WI',I,I,III!;AI) 7000 6000 5000 4000 3000 2000 1"*.-~ ~ 0 7000 ---6000 --5000 ---4000 --3000 --aooo --lOOO t 800~ 0 00' 8 803 MD KDP / START OF BUILD @ 1.00'/I00 Pt "n' ~2~ 0 ' ,~ MD F BUILD ~ 1.50'/100 Pt 1399--~ 7 50' ~ 14Ou MD START OF BUILD e 2.00'/lu0 Ft 9 5/8 j ~ a3.46' a aaoo HD Target Nome I ~ 33.44' 2 2700 MD }ARGET ~ ~5.00' a 3163 ND START OF CURVE ~ ~.50'/100 ~t i 739 ~51.94' ~ 3463 MD ~- . ~ ~%66.30' ~ 5a86 MD NA SamOs 4445 ~ ~9 o/o ~ ~685 Mu 3665 ~~0' z = CASING PDINT DATA i M9 lnc Az~ TVD N/S E/W 6656 66.30' 315.26' 4525 2842 N 2597 W 12413 40.00' 310.00' 7360 6270 N 6110 Wi TVD NS EW Grid X Grid Y 7035 6095 N 5901 W 535795 6041363. -~__~ 66.30' i 10358 HO ST*~T OF CURVE ~ 8.00°/100 Pt - ~'~,58.37'-' @ 10758 MD '~.44' ~ 11058 MD '~43.79' ! 1[496 MD THRZ ~40.00' i 1t689 ~O END OF CURVE m%40.00' ! ti/B9 ND TKUD ~40.00' ~ t~989 ND TKUA3 TARGET ~40,00' ~ loll3 HD THLV ~ 7 ~ ~D I ND 7360 TVD $000 -- 666a 7360 8000 7238 8!64 8755 1000 2000 3000 4000 5000 6000 7000 ' I 80oo 29000 VERTICAL SECTION PLANE: 315.74 PROPOSED BHL TVD 7360.01 MD 12413.09 VS 8755.17 N~S 6270,41 N E/W 6110.23 w !D~%e PLotted Create~ By Checke~ By Approve~ By ~ D~e 11115/95 A(c~sl-<(~ ~'L~ Lc, MiLn(.> I >'L : MPt- Mi'--I-'. 1 4 WI>1. tCRELIH.[NAI,!Y WLI_.I..Pl. AN HDRI/IINFAI. VIEW ('IR(ii-: NBRTH) SCA I I(){X} rt. / I)IVI'SI[N SU~Vl Y kYY, WLI.LI-~_'.^I) ! i : I' ! 1/15/0'.) ?:4G ctm 7OOO WELLS STATUS D~'te Rotted O~e~ B~ App¢ove~ By D~te ? 11/15/g5 : Survey Reference: Wg:.LIHEAD Reference World Coordinates: Lat. 70.30.26 N - Long. 149.39.31 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Rcfcrencc GRID Coordinates: (ft): 6035299.27 N 541727.60E North Aligned To: TRUE NORTH Vcrtical Section Rcfcrence: WELLHEAD Closure Reference: WI~I J-H~AD TVD Reference: Wl:J J.HEAD Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 3 i 5.74 deg. I 0¥ 3 0 1995 Nas~ O~t & Gas Cons. P~cl Date: I 1/15795 Time: 7:47 am Wellpath ID: MPF-14 WPI Last Revision: i 1/15/95 BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-14 WPI PRELIMINARY WELLPLAN Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hot Dir. Vcrt Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool TIEIN 0.00 0.00 0.00 -45.20 0.00 0.00 0.00N KOP/START OF BLIR~ @ 1.00 deg/100 ft 800.00 0.00 0.00 754.80 800.00 800.00 0.00N 900.00 1.00 320.00 854.79 899.99 100.00 0.67N 0.00E 6035299.27 541727.60 0.00E 6035299.27 541727.60 0.5t3hr 6035299.93 541727.04 0.0~@ 0.00 0.00 0.00 0.00 O.OC@ 0.00 0.00 0.00 0.00 0.87@320.00 0.87 i.00 0.00 0.00 0.0 0.00N 0.00 0.0 0.00N 1.00 1.0 0.67 N 0.00 E 0.00 0.00 0.00 0.130 MWD 0.00E 3.85 3.85 0.00 1.89 BPHG-PBD 0.5ON 4.23 4.23 50.00 2.14 BPHG-PBD 1000.00 2.00 320.00 954.76 999.96 100.00 2.67N START OF BUILD @ !.50 deg/100 ft 1100.00 3.00 320.00 1054.66 1099.86 100.00 6.02N 1200.00 4.50 320.00 1154.45 1199.65 100.00 II.03N 2.24W 6035301.93 541725.34 3.4g@ 320.00 3.48 1.00 0.00 5.0YW 6035305.25 541722.52 7.85@320.00 7.83 1.00 0.00 9.2_%V 6035310.24 541718.29 14.3g@320.00 14.35 1.50 0.00 1.00 2.0 2.67N 1.00 3.0 6.02N 1.50 4.5 I 1.03N 2.24W 4.62 4.62 50.00 2.39 BPHG-PBD 5.0-%V 5.02 5.01 50.00 2.65 BPHG-PBD 9.25W 5.43 5.41 50.00 2.91 BPHG-PBD 1300.00 6.00 320.00 1254.02 1299.22 100.00 18.03N 15.12*W 6035317.22 541712.37 23.54@320.00 23.48 1.50 0.00 START OF BUILD @ 2.00 deg/100 ft 1400.00 7.50 320.00 1353.33 1398.53 I00.00 27.04N 22.6gW 6035326.18 541700.76 35.3C@320.00 35.20 1.50 0.00 1500.00 9.50 320.00 1452.22 1497.42 100.00 38.36N 32.1gW 6035337.44 541695.20 50.08@320.00 49.94 2.00 0.00 1.50 6.0 18.03N 15.1JW 5.85 5.80 50.00 3.19 BPHG-PBD 1.50 7.5 27.04N 22.6gW 6.27 6.19 50.00 3.47 BPHG-PBD 2.00 9.5 38.36N 32. IgW 6.72 6.58 50.00 3.78 BPHG-PBD 1600.00 11.50 320.00 1550.54 1595.74 100.00 52.32N 43.90,V 6035351.34 541683.41 68.312@320.00 68.11 2.00 0.00 END OF BUILD 1700.00 13.50 320.00 1648.17 1693.37 100.00 68.90N 57.81W 6035367.84 541669.41 89.9,1@320.00 89.69 2.00 0.00 Base Permafrost 1804.52 13.50 320.00 1749.80 1795.00 100.52 87.59N 73.5Ohr 6035386.44 541653.62 114.34@320.(10 114.02 0.00 0.00 2.00 ! 1.5 52.32N 43.9CW 7.17 6.95 50.00 4.10 BPHG-PBD 2.00 13.5 68.90N 57.81W 7.65 7.31 50.00 4.45 BPHG-PBD 0.00 13.5 87.59N 73.5(.W 8.17 7.74 50.00 4.72 BPHG-PBD START OF CURVE @ 2.50 dcg/100 ft 1900.00 13.50 320.00 1842.64 1887.84 95.48 104.66N 87.8~'3V 6035403.43 541639.20 136.63@320.00 136.25 0.00 0.00 2000.00 15.99 321.07 1939.34 191M.54 100.00 124.32N 103.9[;W 6035422.99 541622.93 162.0'~@320.09 161.61 2.49 1.07 2100.00 18.47 321.86 2034.85 2080.05 100.00 147.50N 122.4~'3V 6035446.06 541604.36 191.68@320.31 191.08 2.49 0.79 0.00 13.5 104.66N 87.82W 8.65 8.14 50.00 4.98 BPHG-PBD 2.50 16.0 124.32N 103.9~ 9.18 8.46 50.56 5.38 BPHG-PBD 2.50 18.5 i 47.50N ! 22.42W 9.74 8.77 51.07 5.82 --BPHG-PBD 2200.00 20.97 322.46 2128.98 2174.18 100.00 174.15N 143.11W 6035472.59 541583.53 225.41@320.59 224.60 2.49 0.61 2300.00 23.46 322.94 2221.55 2266.75 100.00 200.22N 166.01W 6035502.54 541560.46 263.1g@320.89 262.12 2.49 0.48 2400.00 25.95 323.34 2312.39 2357.59 I00.00 237.67N 191.01/W 6035535.84 541535.21 3¢M.95@321.20 303.57 2.49 {).39 2.50 21.0 174.15N 143.1 IW 10.34 9.05 51.52 6.29 BPHG-PBD 2.50 23.5 2(M.22 N 166.0 IW . 10.98 9.30 51.91 6.79 BPHG-PBD 2.50 26.0 237.67N 191.O/:W I 1.68 9.52 52.25 7.32 BPHG-PBD 2500.00 28.45 323.67 2401.32 2446.52 100.00 274.42N 218.2{W 6035572.43 541507.83 350.62@321.50 348.86 2.50 0.33 2.50 28.5 274.42N 218.2{W 12.43 9.72 52.55 7.87 BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: ! i115/95 Wcllpath ID: MPF-14 WPI Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hot Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/10Ofi) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2600.00 30.95 323.95 2488.18 2533.38 100.00 314.40N 247.51W 6035612.24 541478.36 400.12@321.79 397.91 2.50 2700.00 33.44 324.19 2572.80 2618.00 100.00 357.54N 278.7~3V 6035655.20 541446.86 453.37@322.06 450.62 . 2.50 2800.00 35.94 324.40 2655.01 2700.21 100.00 403.75N 311.9Lq~ 6035701.23 541413.40 510.24@322.31 506.90 2.50 0.28 0.24 0.21 2.50 31.0 314.40N 247.5 IW 13.24 9.88 52.81 8.45 BPHG-PBD 2.50 33.5 357.54N 278.7~'W 14.12 10.01 53.05 9.06 BPHG-PBD 2.50 36.0 403.75N 3 ! 1.98,V 15.08 i0.1 ! 53.26 9.69 BPHG-PBD 2900.00 38.44 324.59 2734.67 2779.87 100.00 452.96N 347.0~fi/ 6035750.23 541378.03 570.64@322.54 566.63 2.50 3000.00 40.93 324.76 2811.62 2856.82 100.O0 505.05N 384.0(W 6035802.12 541340.82 634.45@322.75 629.71 2.50 3100.00 43.43 324.91 2885.72 2930.92 100.00 559.94N 422.613V 6035856.79 541301.85 701.5~@322.95 696.01 2.50 0.19 0.17 0.15 2.50 38.5 452.96N 347.0~V 16.1 i 10.17 53.46 10.33 BPHG-PBD 2.50 41.0 505.05 N 384.0(W 17.24 10.20 53.63 ! 1.00 BPHG-PBD 2.50 43.5 559.94N 422.67W ! 8.46 10.19 53.80 ! 1.67 BPHG-PBD START OF CURVE @ 2.50 deg/100 ft 3162.75 45.00 325.00 2930.69 2975.89 62.75 595.77N 447.7gW 6035892.47 541276.53 745.2~;@323.07 739.20 3262.75 47.30 323.64 2999.97 3005.17 100.00 654.33N 489.Se'W 6035950.79 541234.14 817.38@323.18 810.51 3362.75 49.61 322.37 3066.28 3111.48 100.00 714.09N 534.91W 6036010.29 541188.77 892.22@323.16 884.74 3462.75 51.94 321.19 3129.52 3174.72 100.00 774.94N 582.8_'%V 6036070.87 541140.50 969.6~@323.05 961.77 3562.75 54.28 320.08 3189.55 3234.75 100.00 836.75N 633.5~/ 6036132.39 541089.43 1049.5{~@322.87 1041.45 3662.75 56.62 319.03 3246.26 3291.46 100.00 899.42N 687.01W 6036194.76 541035.66 1131.7~;@322.63 1123.62 3762.75 58.98 318.04 3299.54 3344.74 100.00 962.82N 743.04W 6036257.85 540979.28 1216.2C@322.34 1208.14 3862.75 61.34 317.10 3349.30 3394.50 100.00 1026.84N 801.5e3~I 6036321.53 540920.42 1302.65@322.02 1294.83 3962.75 63.71 316.20 3395.43 3440.63 100.00 1091.34N 862.4~V 6036385.69 540859.16 1391.0~@321.68 1383.53 4062.75 66.08 315.33 3437.85 3483.05 100.00 1156.21N 925.64W 6036450.21 540795.65 1481.0~;@321.32 1474.08 END OF CURVE 4071.71 66.30 315.26 3441.47 3486.67 8.96 1162.04N 931.4Obr 6036456.00 540789.85 1489.24@321.29 1482.27 NA Sands 5286.45 66.30 315.26 3929.80 3975.00 1214.74 1952.06N 1714.3~,V 6037241.67 540002.71 2597.9~@318.71 2594.49 2.50 O. 14 2.30 -I.36 2.31 - ! .27 2.33 -1.18 2.34 -I.l I 2.35 -I.05 2.36 -0.99 2.36 -0.94 2.37 -0.90 2.37 -0.86 2.38 -0.85 0.00 0.00 · 2.50 45.1 595.77N 447.7gW 19.27 10.17 53.89 12.11 BPHG-PBD 2.50 47.6 654.33 N 489.813,V 20.66 10. ! 4 53.44 12.78 BPHG-PBD 2.50 50.1 714.09N 534.91W 22.17 10.07 52.97 13.46 BPHG-PBD 2.50 52.6 774.94N 582.8YsV 23.80 9.98 52.50 14.15 BPHG-PBD 2.50 55.1 836.75N 633.5~/ 25.57 9.85 52.01 14.85 BPHG-PBD 2.50 57.6 899.42N 687.01W 27.50 9.70 51.53 15.55 BPHG-PBD 2.50 60.1 962.82N 743.04W 29.60 9.53 51.00 16.25 BPHG-PBD 2.50 62.6 !026.84N 801.513ht 31.91 9.32 50.54 16.95 BPHG-PBD 2.50 65.1 1091.34 N 862.4 t%V 34.45 9.10 50.03 17.65 BPHG-PBD 2.50 67.6 I ! 56.21N 925.6dW 37.28 8.87 49.52 18.33 BPHG-PBD 2.50 67.8 1162.04N 931.4CW 37.53 8.85 49.48 18.39 BPHG-PBD 0.00 67.8 1952.06N 1714.34W 73.81 12.20 47.50 23.69 BPHG-PBD Base Schradec 6455.59 66.30 315.26 4399.80 4445.00 1169.14 2712.42N 2467.8S3hr 6037997.93 539245.20 3667.11@317.70 3664.97 0.00 0.00 CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 6655.59 66.30 315.26 4480.20 4525.40 200.00 2842.49N 2596.8Ohr 6038127.31 539115.63 3850.0~@317.59 3848.08 0.00 0.00 0.00 67.8 2712.42N 2467.8gW 109.59 15.60 46.78 28.93 BPHG-PBD 0.00 67.8 2842.49N 2596.8CW 0.00 0.00 0.00 0.00 BPHG-PBD 6685.00 66.30 315.26 4492.02 4537.22 29.41 2861.62N 2615.7_°N 6038146.33 539096.57 3876.9~;@317.57 3875.01 0.00 0.00 0.00 67.8 2861.62N 2615.7.q~/ ! 16.64 16.27 46.69 29.~6 BPHG-PBD 7685.00 66.30 315.26 4894.03 4939.23 1000.00 351 i.98N 3260.2gW 6038793.26 538448.73 4792.02@317.13 4790.62 0.00 0.00 START OF CURVE @ ZOO deg/lO0 ft 10358.33 66.30 315.26 5968.71 6013.91 2673.33 5250.61N 4983.3.'~r 6040522.97 536717.10 7238.9~@316.50 7238.33 0.00 0.00 10458.33 64.31 314.97 6010.49 6055.69 I00.00 5314.98N 5047.4YsV 6040587.01 536652.67 7329.7E@316.48 7329.17 -!.98 -0.29 0.00 67.8 3486.60N 3285.8gW 134.36 19.38 46.46 35.61 BPHM-PBD 0.00 67.8 5157.39N 5077.353hr 229.78 29.14 45.78 55.46 BPHM-PBD 2.00 69.8 5219.28 N 5 ! 43.9gW 233.89 30.2 ! 45.75 55.90 BPHM-PBD 10558.33 62.33 314.66 6055.38 6100.58 100.00 5377.96N 5110.8-%V 6040649.67 536588.99 7419.1£@316.46 7418.51 -I.98 -0.30 10658.33 60.35 314.35 6103.34 6148.54 100.00 5439.47N 5173.4(W 6040710.87 536526.12 7506.7~;@316.44 7506.24 -!.98 -0.31 10758.33 58.37 314.03 6154.30 6199.50 100.00 5499.44N 5235.05W 6040770.53 536464.14 7592.7~@316.41 7592.24 -i.98 -0.33 2.00 71.8 5279.83N 5209.71'fi~r 237.92 31.3 ! 45.72 56.30 BPHM-PBD 2.00 73.8 5338.98N 5274.6YN 241.87 32.45 45.69 56.65 BPHM-PBD 2.OO 75.8 5396.67N 5338.5.%V 245.73 33.61 45.66 56.97 BPHM-PBD 10858.33 56.39 313.69 6208.20 6253.40 I00.00 5557.79N 5295.8~"W 6040828.58 536403.14 7676.9£(~'316.38 7676.42 -!.98 -0.34 10958.33 54.41 313.33 6264.98 6310.18 lO0.O0 5614.47N 5355.5~"W 6040884.96 536343.17 7759.11@316.35 7758.67 -!.98 -0.36 11058.33 52.44 312.96 6324.56 6369.76 I00.00 5669.38N 5414.11W 6040939.58 536284.32 7839.2~@316.32 7838.89 -!.98 -0.37 2.00 77.8 5452.81N 54OI.3gW 249.50 34.79 45.62 57.25 ..- BPHM-PBD 2.00 79.8 5507.34N 5463.1 IW 253.15 35.99 45.58 57.48 BPHM-PBD 2.00 81.8 5560.20N 5523.61W 256.70 37.20 45.53 57.68 BPI-LM-PBD 11158.33 50A6 312.56 6386.88 6432.08 IOO.00 5722.48N 5471.5~'3Ar 6040992.39 536226.66 7917.34@316.28 7916.98 -I.98 -0.39 11258.33 48.48 312.15 6451.86 6497.06 100.00 5773.69N 5527.6~V 6041043.32 536170.26 7993.1~@316.25 7992.86 -I.97 4).42 11358.33 46.51 311.70 6519.42 6564.62 !00.00 5822.95N 5582.52W 6041092.31 536115.18 8066.6ECa~316.21 8066.41 -I.97 -0.44 2.00 83.8 5611.33N 5582.8_':W 260.12 38.41 45.49 57.84 BPHM-PBD 2.00 85.8 5660.65 N 5640.7(W 263.42 39.62 45.44 57.95 BPHM-PBD 2.00 87.8 5708.12N 5697. I,ilAr 266.59 40.83 45.39 58.03 BPHM-PBD Measured lnel Drift Subsea TVD Course Depth Dir. Depth (fl) (deg,) (deg.) (fl) (fl) Length 11458.33 44,54 3 ! !.23 6589.48 6634.68 100.00 5870.20N 5635.9gW T/-fP.Z 11496,42 43.79 311.04 6616.80 6662.00 38.09 5887.66N 5655,9hW 11558.33 42.57 310.72 6661.94 6707.14 61.91 5915.39N 5688.01W 11658.33 40.60 310.18 6736.73 END OF CURVE 6781,93 ! 00.00 5958,46N5738,51W-0.50 11689.08 40.00 310.00-1.97 TICUD 6760.19 6805.39 30.75 5971.27N -l.97 43.51 !!789.09 40.00 310.00 6836.80 6882.00 -1.97 .0.55 TI(UA3 100.01 6012.59N 5802.99W 6041280.86 535893.86 8356'1~@316'02 8356.08 i!988.81 40.00 310.00 -I.97 -0.88 TARGET 6989.80 7035.00 199.73 6095.11N5901.32W 6041362.90 535795.138483.8~@315.93 8483.82 11989.08 40.00 310.00-0.000.00 TMLV6990.00 7035.20 0.26 6095.22N 5901,4~Wff 6041363.00 535795.00 8484.02@315.93 8483.99 12113.09 40.00 310.00 7085.00 7130.20 124.01 6146.46N 5962.51W 6041413.94 535733.70 8563.32@315,87 8563.30 0.00 0.00 c_ ~n~o vo//v/- OD_-7 in. -o.oo .0.00 12413,08 40.00 310.00 - ID~6'28in, Weight=26.001bfft. 0.01 0.00 7314.80 7360.00 299.99 6270.41N6110.2,%V 6041537.17 535585.42 8755.1~@315.74 8755.16 0.00 0.00 12413,09 40,00 310.00 7314.81 7360.01 0.01 6270.41N6110.2~W~r 6041537.17 535585.41 8755.15@315.74 8755.17 0.00 0,00 Halliburton Energy Services T o T A L ~--- p ' Drilling Systems PSL -~-~---~- rOposal Report Rectangular Offsets GRID Coordinates (fl) Nonhing Eas~ing Closure (fl) Vertical Build Walk DIS .... Dist. Dir. Section Rate Rate Cum. (f0 (deg.) (fl) (dg/lOOfo (dg/lOOft) (dgllOOfo (deg) (f0 (It) (fl) (fl) (deg.) Dogleg Expected Total Max Hot Min I-/or Dir. Vert Rectangular Coords Error Error Max Err Error 8137'7~@316'17 8137.57 '!.97 ~0.47 2.00 89.8 5753.68N 5752.0fW 269.62 2.00 90.6 5770.50N 42.03 45.34 5772.6.~/ 270.76 42.49 45.32 2.00 91.8 5797.24N 5805.5~'W 272.55 43.23 45.28 2.00 93.8 5838.79N 5857.3(W 275.31 44.40 45.23 2.00 94.4 5851.14N 5872.8,cW 276.14 44.76 45.21 0.00 94.4 5890.99N 5923.3~%V 6041139.30 536061.50 6041156.66 536041.43 8164.22@316.15 8164.02 6041184.23 536009.27 8206.42@316.12 8206.23 6041227.04 535958.57 8272.47@316.08 8272.32 5753.7Ln, V 6041239.78 535943.29 8292.25@ 3 I6.06 8292. ! 2 278.86 45.24 45.!6 0.00 94,4 5970.55N 6024.2 iW 284.29 46.22 45.05 0.01 94.4 5970.65N 6024.34W 284.30 46,22 45.05 0.00 94.4 6020.06N 6086,9~%V 287.69 46.83 44.99 0.00 94.4 6270.41N 6110.22W 0.00 0.00 0.00 0.00 94.4 6/39.57N 6238.4CW 295.91 48.31 44.84 Page 3 Date: ! 1/15~5 Wellpath ID: MPF~ 14 WP I SUrvey Tool 58.07 BPH-NI-PBD 58.08 BPI'L.M-PIB D 58.08 BP/-I~I-PBD 58.05 BPH. bI~Pi~D 58.04 Bp/.iM.PBD 58.51 Bp/.ov/.pBD 59,46 BpH34,pBD 59,46 BPHM-PBD 60.05 BPI-tM,pt~ D 0.00 BPI'/M-pBD 61.47 BPI-LM-PBD RECEIVED 1995 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Date: Subject: Bob Crandall, AOGCC Chris West, BPX (Shared Services Drilling) November 29, 1995 Application for Spacing Exception for the Milne Point Well F-14 (20 AAC 25.055) The MPF-14 well is planned to drill into the Kuparuk River formation in the west half of Section 36, T14N and R9E. This section is located to the south of the Milne Point Unit''/,~'d /~. boundary. This section is bounded on the south by quarter sections within ADL 355023 for which the operator is ARCO 100%. The MPF-14 well is planned as a high angle producer to be completed with an electric submersible pump. Entry point in the Kuparuk formation (C1 Sand) is 2663' NSL and 3578' WEL in Section 36, T14N, R9E and TD at 2838' NSL and 3787' WEL, Section 36, T14N, R9E. We have notified all owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055. Thank you for your assistance in this matter. at 564-8466. Please direct any questions to Mark Bendersky Respectfully, ChFis West i ECEIV'ED liOV 15 0 1995 CC: BPX ARCO Alaska Inc CRW/klc · II Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organiZe this category of information. RECEIVED SEP 05 1995 /~ska Oil & (~as Co~s. Commisst~ Anchorage . * · ALASKA COMPUTING CENTER * . . ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF- 14 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22636-00 REFERENCE NO : 96054 M E OFILM D * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF-14 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22636-00 REFERENCE NO : 96054 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:36 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 9 ORIGIN : FLIC REEL NAME : 95054 CONTINUATION # : PREVIOUS REEL : CO~4ENT . BP EXPLORATION, MILNE POINT MPF-14, API # 50-029-22636-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 9 ORIGIN : FLIC TAPE NAME : 95054 CONTINUATION # : 1 PREVIOUS TAPE : COgeNT · BP EXPLORATION, MILNE POINT MPF-14, API # 50-029-22636-00 TAPE HEADER MILNE POINT ~¢D LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NE~4BER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 96054 DENNETT ANGLEN WELL CASING RECORD 1 ST STRING 2ND STRING MPF-14 500292263600 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 9-AUG-96 BIT RUN2 ......... 96054 RUMINER ANGLEN BIT RUN 3 6 13N IOE 1848 2837 46.20 46.20 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 8.500 9.625 6700.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:~6 3RD STRING PRODUCTION STRING REMARKS: Well drilled 17-JAN through 24-JAN-96 with CDR/CDN. All data was collected in two bit runs. CDR was run alone on bit run one. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/08/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-U-MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUPmLa=~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5436.0 12780.0 BASELINE DEPTH 88888.0 12632.5 12625.5 12615.5 12606.0 12605.0 12576.5 12570.5 12555.5 12532.0 12519.0 12510.0 12478.5 12474.5 12470.5 12461.0 12452.0 12421.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 88900.5 12645.0 12638.5 12628.5 12621.0 12619.5 12592.0 12586.0 12572.5 12547.0 12534.5 12524.5 12491.0 12488.5 12485.5 12476.5 12464.0 12436.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12406.0 124 O1.5 12391.5 12387.5 12381.0 12370.0 12368.5 12356.5 12344.5 12337.0 12318.5 12294.5 12285.5 12252.5 12242.5 12225.0 12217.5 12200 5 12194 5 12182 0 12166 5 12160 5 12139 0 12106 5 12043.5 12017.5 12015.0 11997.0 11984.5 11967.0 11941.0 11939.5 11932.0 11928.0 11923.5 11913.5 11883.0 11869.0 11862.5 11832.0 11826.5 11810.5 11805.5 11803.0 11787.5 11782.5 11765.5 11751.5 11723.5 11691.0 11672.0 11663.0 11654.5 11647.5 11624.0 12420.0 12415.5 12405.0 12402 0 12395 0 12384 0 12382 5 12370 0 12358 5 12351.0 12332.5 12307.5 12298.5 12265.5 12256.5 12237.0 1223 O. 5 12214.0 12210.0 12197.5 12179.0 12173.0 12151.5 12119.0 12056.0 12028.5 12026.0 12010.0 11994.5 11978.5 11953.0 11950.5 11942.5 11940.0 11934.5 11924.0 11896.5 11881.5 11874.0 11843.0 11839.5 11824.5 11818.5 11815.5 11798.5 11793.5 11775.0 11758.0 11731.0 11703.0 11684.5 11677.5 11669.0 11660.5 11637.0 9-AUG-1996 13:36 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13 :~6 PAGE: 11579.5 11577.5 6696.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 11591.5 11590.0 6696.0 BIT RUN NO. MERGE TOP MERGE BASE 1 5436.0 6717.0 2 6717.0 12780.0 The depth adjustments shown above reflect the MWD GR to the CH GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 RA ~D OHdV~ O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13 :~6 PAGE: 5 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RP MWD OH~4M VRA MWD VRP ~D OH~4 DER ~ OIff4M ROP MWD FPHR FET MWD HR GR M~ GAPI RHOB MWD G/C3 DRHO MWD G/C3 PEF ~WD BN/E CALN ~4~W-D ~N NPHI ~ PU-$ CRCH TIE CAPI O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 12778.500 RA.MWD -999.250 RP.MWD -999.250 VRA.~D VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 130.480 FET.~'/D GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MCWD -999.250 NPHI.MWD -999.250 GRCH. TIE -999.250 DEPT. 12000.000 RA.MWD 2.200 RP.MWD 1.950 VRA.MWD VRP.MWD 1.919 DER.MWD 2.032 ROP.MWD 138.807 FET.~D GR.$~VD 122.509 RHOB.MWD 2.501 DRHO.MWD 0.049 PEF.~gD CALN.MWD 8.933 NPHI.MWD 37.100 GRCH. TIE 69.188 DEPT. 10800.000 RA.MWD 2.353 RP.MWD 2.515 VRA.~D VRP.MWD 2.511 DER.MWD 2.450 ROP.MWD 215.236 FET.~D GR.MWD 90.544 RHOB.MWD 2.382 DRHO.MWD 0.058 PEF.MWD CALN. MWD 8.587 NPHI.MWD 33.100 GRCH. TIE -999.250 DEPT. 9600.000 RA.MWD 2.404 RP.MWD 2.688 VRA.M~ VRP.MWD 2.674 DER.MWD 2.568 ROP.MWD 229.802 FET.~D GR.M~VD 89.984 RHOB.MWD 2.357 DRHO.MWD 0.012 PEF.~D CALN. MWD 8.736 NPHI.MWD 31.700 GRCH. TIE -999.250 DEPT. 8400.000 RA.MWD 3.478 RP.MWD 3.336 VRA.~D VRP.MWD 3.463 DER.MWD 3.382 ROP.MWD 193.313 FET.~gD CR.MWD 79.308 RHOB.MWD 2.102 DRHO.MWD -0.013 PEF.~D CALN. MWD 10.080 NPHI.MWD 35.800 GRCH. TIE -999.250 DEPT. 7200.000 RA.M~D 4.247 RP.MP~ 4.191 VRA.~D VRP.MWD 4.061 DER.MWD 4.209 ROP.MWD 394.978 FET.MWD GR.MWD 72.029 RHOB.MWD 2.303 DRHO.t~D 0.044 PEF.~ff~D CALN.MWD 8.859 NPHI.MWD 36.200 GRCH. TIE -999.250 -999.250 -999.250 -999.250 2.141 0. 596 3. 911 2.421 0.899 2.999 2. 442 0.517 3. 062 3. 449 2. 006 2. 565 4.051 0.309 2.853 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:~o PAGE: DEPT. 6000. 000 RA. MWD VRP . MWD 3.397 DER . ~D GR.~PWD 111.364 RHOB.MWD CALN . MWD -999.250 N PHI . ~4WD DEPT. 5436.000 RA.~D VRP.~D -999.250 DER.MWD GR.MWD 106.324 RHOB.MWD CALN.~ffgD -999.250 NPHI.MWD 4.163 RP.MWD 3.575 ROP.~D -999.250 DRHO.MWD -999.250 GRCH. TIE -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. TIE 3.378 79.294 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 VRA.~WD FET. ~WD PEF. N~WD VRA . ~WD FET. ~D PEF. ~D 4.249 0.871 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE · 96/08/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NDY4BER: 1 DEPTH INCR~24ENT: O. 5000 FILE SUN~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH M~D 5436.0 6717.0 $ LOG HEADER DATA DATE LOGGED: 24-JAN-96 SOFTWARE: SURFACE SOFTWARE VERSION: FAST2.5 DOWNHOLE SOFT~gARE VERSION: 4.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:~o PAGE: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) '. BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MTID VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OP2~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) : MUD AT ~ CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): MEMORY 12768.0 0.0 12768.0 100 71.3 73.7 TOOL NUMBER RGS904 12.250 LSND 9.90 46.0 6. 875 60.0 3.143 60.0 R~S: ******* RUN1 - CDR ONLY ************* DRILLED INTERVAL 5500' - 6717' RES TO BIT: 54.89'; GR TO BIT: 65.31' Rm=2.27@66 DEG, Rmf=2.09@64 DEG ******* RUN2 - CDR/CDN ************* RES TO BIT: 62.84'; GR TO BIT: 73.26' NEUT TO BIT: 123.44'; DENS TO BIT: 116.46' DRILLED INTERVAL 6717' - 12768' $ LIS FORMAT DATA 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13 ~ ~o PAGE: 8 ** DATA FOR2~AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 28 66 1 0.5 FT 36 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE IVTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 I 4 68 0000000000 RA LW1 OHMM O0 000 O0 0 2 1 1 4 68 0000000000 RP LW1 OItb~l O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 FPHR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. ROP.LW1 6717. 000 RA. LW1 -999. 250 RP. LW1 -999. 250 DER. LW1 -999. 250 224 . 469 FET. LW1 -999. 250 GR. LW1 -999. 250 DEPT. 6000.000 RA.LW1 4.163 RP.LW1 3.378 DER.LW1 ROP. LW1 79. 294 FET. LW1 O. 871 GR. LW1 111 . 364 3. 575 DEPT. 5435. 500 RA. LW1 -999. 250 RP. LW1 ROP. LW1 -999.250 FET. LW1 -999.250 GR. LW1 -999. 250 DER. LW1 111. 742 -999.250 * * END OF DATA * * LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13.~6 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 96/08/ 9 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves a~d log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUM~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 6585.0 12768.0 LOG HEADER DATA DATE LOGGED '. SOFTWARE '. SURFACE SOFTWARE VERSION: DOWNHOLE SOF~gARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDN NEUT./DENS. CDR RESIST./GR $ 24-JAN-96 FAST2.5 4.0 MEMORY 12768.0 0.0 12768.0 90 18.7 73.7 TOOL NUMBER NDS035 RGSO 35 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13 :~6 PAGE: 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 12.250 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S) : 46.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 6. 875 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 3.143 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ******* RUN1 - CDR ONLY ************* DRILLED INTERVAL 5500' - 6717' RES TO BIT: 54.89'; GR TO BIT: 65.31' Rm=2.27@66 DEG, Rmf=2.09@64 DEG ******* RUN2 - CDR/CDN ************* RES TO BIT: 62.84'; GR TO BIT: 73.26' NEUT TO BIT: 123.44'; DENS TO BIT: 116.46' DRILLED INTERVAL 6717' - 12768' $ LIS FORMAT DATA 60.0 60.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:~6 PAGE: 11 TYPE REPR CODE VALUE 9 65 FT !1 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 RA LW2 OH~k~ O0 000 O0 0 3 1 1 4 68 0000000000 RP LW2 OH~I O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OH~2~ O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 FPHR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LW2 BN/E O0 000 O0 0 3 1 1 4 68 0000000000 CALN LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 NPHI LW2 PU-S O0 000 O0 0 3 1 I 4 68 0000000000 ** DATA ** DEPT. 12768.000 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 132.257 FET.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF.LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 DEPT. 12000. 000 RA. LW2 2. 053 RP. LW2 1 . 773 DER. LW2 ROP. LW2 127. 815 FET. LW2 O. 601 GR. LW2 118. 274 RHOB. LW2 DRHO. LW2 O. 042 PEF. LW2 4 . 066 CALN. LW2 8. 927 NPHI. LW2 DEPT. 10800.000 RA.LW2 2.554 RP.LW2 2.565 DER.LW2 ROP.LW2 325.206 FET.LW2 O. 798 GR.LW2 86. 843 RHOB. LW2 DRHO.LW2 0.070 PEF.LW2 2.864 CALN. LW2 8.500 NPHI.LW2 DEPT. 9600. 000 RA. LW2 2. 484 RP. LW2 2. 704 DER. LW2 ROP. LW2 97.189 FET. LW2 O. 391 GR. LW2 94 . 185 RHOB. LW2 DRHO.LW2 O. 019 PEF.LW2 3. 029 CALN. LW2 8. 500 NPHI. LW2 DEPT. 8400.000 RA.LW2 3.151 RP.LW2 3.145 DER.LW2 ROP. LW2 196. 061 FET. LW2 2. 019 GR. LW2 86. 483 RHOB. LW2 DRHO.LW2 -0. 021 PEF.LW2 2. 489 CALN. LW2 10. 137 NPHI. LW2 -999.250 -999.250 -999.250 1. 863 2. 552 34. 000 2. 561 2.293 34.900 2. 614 2. 365 31. 000 3.147 2.078 33.300 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-AUG-1996 13:~6 PAGE: 12 DEPT. 7200. 000 RA. LW2 ROP. LW2 394. 978 FET. LW2 DRHO. LW2 O . 046 PEF. LW2 4. 292 RP. LW2 O. 338 GR. LW2 2.826 CALN. LW2 4.243 77.292 8.887 DEPT. 6585. 000 RA. LW2 -999. 250 RP. LW2 -999. 250 ROP. LW2 -999. 250 FET. LW2 -999. 250 GR. LW2 - 999. 250 DRHO.LW2 -999.250 PEF.LW2 -999.250 CALN. LW2 -999.250 DER. LW2 RHOB. LW2 NPHI. LW2 DER. LW2 RHOB. LW2 NPHI. LW2 4.259 2.331 34.200 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O0!CO1 DATE : 96/08/ 9 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 9 ORIGIN : FLIC TAPE NAME : 95054 CONTINUATION # : 1 PREVIOUS TAPE : COY24ENT : BP EXPLORATION, MILNE POINT MPF-14, API# 50-029-22636-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/08/ 9 ORIGIN ' FLIC REEL NAME : 95054 CONTINUATION # : PREVIOUS REEL : CO~4~ENT · BP EXPLORATION, MILNE POINT MPF-14, API # 50-029-22636-00 Logging Services ~pe Subfil~ 2 i~ type. ~IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF-14 500292263600 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 28-FEB-96 6596.00 K. BRUNNER D. ROBERTSON 6 13N 10E 1848 2837 46.20 12.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9. 625 6690.0 PRODUCTION STRING 7 . 000 12748 . 0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 2 1 13-FEB-96 WALS ......... EQUIVALENT UNSHIFTED DEPTH GRCH BASELINE DEPTH $ REMARKS · GR/CCL · · TIED INTO GR-CCL RUN 13-FEB-96. 40.00 26.00 RAN 2 - 3 3/8" ROLLERS WITH 4.5" WHEELS AND A 3 1/2" WEIGHT BAR ABOVE PRODUCTION LOGGING TOOLS, TO GET DOWN THRU HIGH ANGLE. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 W~ NOT DEPTH SHIFTED SINCE REFERENCE FOR THIS WELL. S 1 IS THE DEPTH FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ .5OOO START DEPTH 11555.0 STOP DEPTH 12645.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: MAIN PASS. NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 14 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F i Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 18 1022 BYTES * Tape File Start Depth = 11565.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4343 datums Tape Subfile: 2 114 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11553.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ROL ROLLERS SBAR SINKER BAR ROL ROLLERS PCM GR P/T CENT $ STOP DEPTH 12666.0 PULSE CODE MODULATOR GAMMA RAY PRESSURE/TEMPERATURE CENTROLLER 13-FEB-96 FSYS REV. J001 VER. 1.1 1120 13-FEB-96 12663.0 12650.0 11600.0 12646.0 2400.0 YES TOOL NUMBER 8250EA/8248EA 8220XA 8255XA 8257LA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12748.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): WATER/DIESEL 0.00 0.0 182.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX-. MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZON~ TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : MPF - 14 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves-. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 1 1 F/MN 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 88 Tape File Start Depth = 11560.000000 Tape File End. Depth = 12650.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21806 datums Tape Subfile: 3 165 records... Minimum record length: 62 bytes .~aximum record length: 1006 bytes Tape Subfile 4 is type: LIS 96/ 2/28 O1 **** REEL TRAILER **** 96/ 2/28 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 FEB 96 4:47a Elapsed execution time = 11.15 seconds. SYSTEM RETURN CODE = 0
