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Home My WebLink About194-143STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 2 9 2020 1. Operations Abandon Lj Plug Perforations Lj Fracture StimulateLi Pull Tubing ✓j per i s down Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casin 9 ❑ Change Approved Program ❑ Plugfar Redrill ❑ arforate New Pool ❑ Repair We](—_] Re-enter Susp Well ❑ Other: ESP Change -out Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Stratigraphic❑ Exploratory ❑ Service ❑ 194-143 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22521-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025518 & ADL0028231 MILNE PT UNIT E-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 14,225 feet Plugs measured N/A feet true vertical 7,327 feet Junk measured 13,199 feet 3,865, 13,200 & Effective Depth measured 14,084 feet Packer measured 13,248 feet 3,016, 6,799 & true vertical 7,241 feet true vertical 6,820 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,070' 9-5/8" 4,100' 3,117' 5,750psi 3,090psi Intermediate 13,360' 7" 13,387' 6,883' 7,240psi 5,410psi Liner 979' 5" 14,220' 7,323' 8,290psi 7,250psi 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 FILE 8rd 13,132' 6,771' Viking Hyd Set,FB- 1 Packer & 5" Packers and SSSV (type, measured and true vertical depth) Baker N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: NIA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 340 0 Subsequent to operation:[81 27 1,516 180 219 14. Attachments (required per 20AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Q 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 ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foreg� s tru a d correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Few 319-457 Authorized Name: Chad Helgeson` Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(@hiIcorp.com Authorized Signature: Date: 1/6/2020 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 �/�� o MMS IJAN 1 3 1010 Submit Original Only n corn Alaeku, LLC Orig.KB Elev.: 54.40'/ Q Elev.: 24.70' TD =14,225 (NID) /TD=7,327'(TVD) PBTD=14,064' (ND) / PBiD= 7,241'M) Milne Point Unit Well: MID SCHEMATIC Last Completed: 12/21/19 PTD: 194-143 TREE & WELLHEAD Tree Cameron 2-9/16" SIM Wellhead 7-1/16"SM FMC W/2-7/8" WKM Tubing Hanger w/3"L.H. ACME x 2-7/8" 8rd Btm Thread , 2.5" COW H BPV profile. OPEN HOLE / CEMENT DETAIL P20" Cr -rt w/ 250 sks of Arcticset I (Approx) in 24" Hole 9-5/8" Cmt w/ 804 sks PF "E", 250 sx Class "G" in 12-1/4" Hole 7" Cmt w/ 307 sks Class "G" in 8-1/2" Hole 5" Cmt w/ 130 sks Class "G" in 6" Hole CASING DETAIL TUBING DETAIL 2-7/8" Tubing 6.5//EUE Brd 2.441" Surface 13,139' 0.00579 L-80 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =60-67 deg. f/ 3,100'too 13,704 Hole Angle through perforations =57 deg. JEWELRY DETAIL No Type Wt/Grade/Conn ID Top Btm 11 BPF IFSize 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 9-5/8" Surface 40/L-80/BTC 8.835" Surface 4,100' 0.0759 7" Intermediate 26/L-80/NSCC 6.276" 1 Surface 13,387' 1 0.0383 5" Liner 15/13CR-80/FL4S 4.408" 1 13,241' 14,220 1 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5//EUE Brd 2.441" Surface 13,139' 0.00579 L-80 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =60-67 deg. f/ 3,100'too 13,704 Hole Angle through perforations =57 deg. JEWELRY DETAIL No Depth Item Top (TVD) Btm (TVD) GLM Detail: Camco KBMG 2-7/8' x 1" 1 135' ST 3: Side pocket,W/Dummy & BK Latch 2 3,810' ST2: Side pocket,W/Dummy&BK Latch 3 3,865' Viking Hyd Set ESP Packer W/Dual vent valve 4 12,964' STI: Side pocket,W/Dummy & BK Latch 5 13,022' 2-7/8" "XN" Nipple, ID= 2.205" (Preload w/ RHC Plug) 6 13,074.7 Bolt on Discharge Head: 400 FPDIS 7 13,075' Discharge Head: PRESS PORT400P 8 13,076' Pump: 538PMSXD 119 P23 M FER 9 131093' parator: GRS FER N AR 513 10 13,097' Tandem Seal Section: GSB3DB H6 SB/AB PFSA 11 13,103' andem Seal Section: GSB3DB H6 SB/AB PFSA 12 13,110' 562XP 250 HP, 2505 Volts, 61 Amps 13 13,127' Motor Guage & Centralizer—Bottom @ 13,132' 14 13,127' cker (Drift 3.875" during 2000 RWO) MBrIdge 35 13,200' ing Sleeve 16 13,241' r Packer 17 13,248' r Liner Hanger 18 13,720' therford Cast Iron Bridge Plug set 12/26/2000 PERFORATION DETAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Kup.CSands 13,630' 13,694' 7,000' 7,031' 64 1/06/1995 2qe Kup.0 Sands 13,644 13,684 7,007 7,026 40 5/04/2002 Kup.BSands 13,732' 13760' 7050' 7064' 28 1/06/1995 GENERAL WELL INFO API: 50-029-22521-00-00 Drilled, Cased and Perfed by Nabors 22E - 1/8/1995 ESP RWO by Nabors 4E5-12/27/2000 ESP RWO and Re -Pert by Nabors 4ES —5/08/2002 Tubing Patch -10/20/2006 ESP RWO by Nabors 3S-3/27/2007 ESP RWO by Doyon 16 —3/01/2013 ESP RWO by ASR#1 — 12/21/2019 Revised By: TDF 1/6/2020 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-10 ASR#1 50-029-22521-00-00 194-143 12/16/2019 12/21/2019 12/11/2019- Wednesday No operations to report. 12/12/2019 -Thursday No operations to report. 12/13/2019 - Friday No operations to report. 12/14/2019 -Saturday No operations to report. 12/15/2019 -Sunday No operations to report. 12/16/2019 - Monday Torque up the BOPE. Make up 2-7/8" and 3.5" test joint, winterize test joint after sticking in the stack. Shell Test Connection Leaking @ Speed head to 7'x11" Adapter spool.Tighten up and get a good shell test. BOPE Test as per Sundry 250/low 2,500/high on annular, 250/low 3,000/high Rams. 12/17/2019 -Tuesday Cont. test BOPE, as per Hilcorp & AOGCC requirements, witness waived by AOGCC inspector Matthew Herrera, test with 2- 7/8" & 3-1/2" TJ, Working through issues, had leak on 11" flange tighten flange retest good, continue troubleshoot pressure loss while attempting to test, c/o TWC. Had Rig issues loss of communication to gauges & erratic idle, troubleshoot. VMS troubleshoot, found went down on low voltage, re-start/investigate no issues found & system charging. Re -flood lines & eq. cont. test BOPE troubleshooting pressure loss. resolve leak at hanger, move forward testing BOPE as per procedure. Crew Change. Good BOPE Test, 250/1-aw 2,500/high annular, 250/low 3,000/high. Blow down lines and RD BOPE test equipment. Alternator Not running at full capacity De -rating the rig, Change out alternator. MU landing Jnt, BOLDS, Pull hanger to the Floor. Disconnect the ESP cable and BO landing Jnt. Pull TWC, Lay down the landingjnt and the hanger. Start pooh with ESP run ESP cable over the sheave and connect to the Spooler. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-10 ASR#1 50-029-22521-00-00 194-143 12/16/2019 12/21/2019 12/18/2019- Wednesday Cont. POOH I/d 2-7/8" completion, L/D 104jts. Cont. POOH I/d 2-7/8" completion, found hole in tubing @ jt 135 (4,150'—), pitting on collars starting @ jt 140, I/d 216 jts total. Crew Change Service and inspect the Rig and equipment. Cont. POOH I/d 2-7/8" completion, L/D 237 jnts. ESP Reel Swap. Cont. POOH I/d 2-7/8" completion, 412 total jnts 2 GLM Pumping single displacement. L/D ESP assy. found slight scale on assembly & corrosion on motor lead. 12/19/2019 - Thursday Clear rig floor from pulling eq., prep floor to p/u ESP assy. stock clamps, hang sheave w/ cable. P/U P/U Centralizer, Mtr Gauge, Motor assy, lower tandem seal, upper tandem seal, gas separator, pump, discharge head, Bolt on discharge head w,10' pup=67.13', service component's & test same good up/ do wt 3k. RIH p/u joint 2-7/8" EUE 6.5# L-80 tubing, xn nipple wpups top & btm, loaded w/RHCP plug, 2-7/8" jt tubing, GLM w/pups top & btm, loaded w/1" dummy valve, cont. RIH w/ 2- 7/8" EUE tubing/ EOT @ 1908'. Crew Change, Service and inspect the rig and Equipment. RIH/w 2-7/8" EUE 6.5# L-80 tubing with ESP Cable From 1908'to 7919' 670'/hr clamping Every other jnt. ESP Reel swap and Cable Splice. 12/20/2019 - Friday Crew change, perform tourly rig services/inspections. SIMOPS: Baker Centrilift continue to perform cable to cable splice on ESP cable. Continue to RIH w/ ESP completion on 2-7/8" EUE pipe down to 9258'md (629'/hr). P/U Viking dual vent valve ESP completion PKR and M/U to TBG stump. Fill annulus to verify fluid level prior to performing ESP cable splice. 5bbls required to see fluid level below wellhead. SIMOPS: Baker Centrilift prep equipment for performing ESP splices. Baker Centrilift perform two ESP splices. One splice from the penetrator pig tail back to the ESP cable currently in the hole, the other splice from the remaining ESP cable on the reel to the cable plug which mates with the penetrator. SIMOPS: Remove fluids from pits # 3&4 and begin prep for cleaning pits prior to coating pits. Remaining crew prep ASR tent for stacking out rig at end of well. Verify Viking dual vent valve ESP completion PKR is set up, as per recommendations. Pull 3/8" control line from spooler over sheave in prep for connecting to vent valve. Rig floor lights tripped out from burnt fuse, replace fuse and regain rig floor lights. Attempt to M/U JNT to pup above vent valve, unable to get tongs on pup to TO. M/U w pipe wrenches and cheater bars. (2K ft -lbs desired f/ 2-7/8" EUE). M/U control lines to dual vent valves. Pressure up system. Seemed to have air in the system. Pump through the control line and purge any potential air from line. Reconnect line to control line "T" coming off of dual vent valves. Pressure up system to 2K psi and watch for leaks. Continue to pressure up to 3k psi and see clear indication of vent valve opening up. Continue to pressure up to 5K and hold for 15min (good test). Continue to RIH w/ ESP completion and Viking dual vent valve f/ top of PKR @ 9,273'md on 2-7/8" EUE pipe to 9,550'md. Operator noticed he had missed GLM in pipe tally running order. Call Co Rep and discuss. Decision made to POOH to top of PKR and run GLM. M/U GLM and continue to RIH w/ ESP completion and Viking dual vent valve on 2-7/8" EUE pipe. Clamp every otherjoint after clamping initial 10joints. Crew Change, service and inspect. continue to RIH w/ ESP completion and Viking dual vent valve on 2-7/8" EUE pipe. Clamp every otherjoint. @ jnt 403 12,425' 12, Reel splice on Cap tube, Had to get new reel from A Pad brought over. Pressure up system to 2K psi and watch for leaks. Continue to pressure up to 3k psi and see clear indication of vent valve opening up. Continue to pressure up to 5K and hold for 5min (good test). continue to RIH w/ ESP completion and Viking dual vent valve on 2-7/8" EUE pipe, M/U GLM on top ofjnt 420 (12,980'md) 140.75' from surface. PU/MU FMC, 7" x 4" left hand ACME lift threads on top. 2.5" BPV prep. 2 Control line ports one capped, with ESP and 2-7/8" seal sub. Make ESP Penetrator splice to hanger. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-10 ASR#1 50-029-22521-00-00 194-143 12/16/2019 1 12/21/2019 12/21/2019 -Saturday Open IA and RIH w/ TBG hanger as per wellhead rep. 5' landing joint to ensure proper landing depth. RILDS, verify all LDS are ran in the proper length. Final ESP set depth = 13,132'md. Remove TIW from landing joint, drop ball and rod, remove landing joint and close blinds. SIMOPS: Roads and Pads on location to begin shuffling equipment to A pad for stack out. Chase ball and rod with 9.3ppg brine from pits. Catch pressure after 5bbls away, walk pressure up to PKR start to set pressure (-2,100psi) watching for indication of PKR start to set, (No noticeable indication at surface) continue to pressure up to 3,100psi. Perform MIT -T for 30mins. (Good Test). Bleed pressure off to 0 psi and then cycle up to 3,000psi for 5mins as per Viking PKR setting procedure. Blow down. R/U to IA with derrick valve cement hose and perform MIT -IA to 1 500psi. Walk pressure up in increments in order to prevent rapid pressurization on ESP cable. Hold 1,500psi for 30mins (Good Test). Bleed down pressure in slow increments in order to prevent rapid depressurization of ESP cable. Blow down lines and prep for R/D M/O to A -Pad. Well head rep install BPV. R/D ASR from E-10. 12/22/2019 -Sunday No operations to report. 12/23/2019 - Monday No operations to report. 12/24/2019 -Tuesday No operations to report. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU E-10 Permit to Drill Number: 194-143 Sundry Number: 319-457 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J M. rice Chair DATED this I day of October, 2019. RBDMS I4'wpCT 1 01019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS gn onr oG inn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing R . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service El 194-143 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22521-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT E-10 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0028231 MILNE POINT/ KUPARUK RIVER OIL ' 11. /�, 0: 1,9 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,225' 7,327' 14,084' 7,241' 2,561 N/A 13,199' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,070' 9-5/8" 4,100' 3,117' 5,750psi 3,090psi Intermediate 13,360' 7" 13,387' 6,883' 7,240psi 5,410psi Liner 979' 5" 14,220' 7,323' 8,290psi 7,250psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-80 / EUE 8rd 13,139' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): FB -1 & LTP HPLPO and N/A 13,248 MD/ 6,820 TVD & 13,200 MD/ 6,799 TVD and N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/1/2019 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman 'T"T.,/ Authorized Title: Operatlons;_Mauager Contact Email: twellman hllcor .Com Contact Phone: 777-8449 Authorized Signature: Date: r COMMISSION USE ONLY Conditions of approval: Notify CbrinmIrsion so that a representative may witness Sundry Number: Plug Integrity F1 BOP Test u Integrity Test ❑ Location Clearance ❑ /Mechanical Other. OOv � S L .!J Ci •� Post Initial Injection MIT Req'd? Yes ❑ No F-13BDMS O`' C Spacing Exception Required? Yes rT 20,9 No Subsequent Form Required: `v' —Ltoq APPROVED BY 46 4 (j Approved by: N COMMISSIONER THE COMMISSION Date: U e-1-- /0-F./ ORIGINAL 9� Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Menls in Duplicate .P1- R i`cL K Hileoro Alpska, M ESP Change -Out Well: MPU E-10 Date: 10-04-19 Well Name: MPU E-10 API Number: 50-029-22521-00 Current Status: Shut In -ESP Producer - Pad: E -Pad Estimated Start Date: November 1, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-143 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: Maximum Expected BHP: MPSP: Max Inclination Max Dogleg: BPV Profile: 3,233 psi @ 6,719' TVDss 3,23 si @ 6,719' TVDss 2,561 67.6° @ 7,166' and 6.61°/100ft @ 8,028' and 2-1/2" CIW Type H BHP Gauge 3 yr SI (06/17/19) 9.25 PPG BHP Gauge 3 yr SI (06/17/19) 9.25 PPG Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU E-10 was drilled and completed as a Kuparuk B and C sand producer in 1995. The well has been an ESP artificially lifted well and has had RWO's in 2000, 2002, 2007 and 2013. In April 2016 the ESP experienced a quick Amp and Hz spike which resulted in a suspected twisted shaft. The well currently is unable to surface fluids at any economic rate. Notes Regarding Wellbore Condition • The 7" casing passed an MIT to 3,000 prig on 2/27/13 (during the original completion) to 8,621' md. Objective: • Pull 2-7/8" Tubing String and ESP. • Install new Baker Hughes ESP and new 2-7/8" tubing. Pre -Rig Procedure (non-sundried operations): 1. RU Slickline unit / a. Pull DGLV from GLM @ 12,889' and leave open. " b. Run BHP Survey w/ stops at 12,842' and/6,600' TVDss; 12,595' and/6,500' TVDss; 12,347' and/6,400' TVDss; and 11,374' and/6,000' TVDss. 2. RU LRS and PT lines to 3000 psi. 3. Circulate at least one wellbore volume with 9.3ppg brine down tubing while taking returns down the flowline. Bleed off remaining pressure to the 500bbl returns tank. 4. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 5. RD Little Red Services. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU crane. Set BPV. NO Tree. NU BOPE. RD Crane. ESP Change -Out Hilcorp Al"kp. LU Well: MPU E-10 Date: 10-04-19 9. NU BOPE house. Spot mud boat. Brief RWO Procedure (Approved Sundry required prior to proceeding): 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/ 9.3ppg brine prior to pulling BPV. 12. Set TWC. 3 000 3. Test BOPE to 250 psi Low si 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. Notify AOGCC 24 hours in advance of BOP test. Q b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. \ e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: The tubing hanger has a possibility of failing a pressure test due to a leak from the IA to adaptor flange via threads on the capillary string. If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 9.3ppg brine as needed. 16. Rig up spoolers for ESP #1 RD cable. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2013 ESP completion was 98K lbs / SOF = 77K lbs. b. Weights documented prior to setting of packer. (Doyon 16 Block weight = 40K lbs). c. If needed, circulate (long or reverse) pill with lubricant, seawater, and/or baraclean pill prior to laying down the tubing hanger. 18. 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. 0 Ililc.0 Alaska, LU ESP Change -Out Well: MPU E-10 Date: 10-04-19 a. Evaluate pulled tubing hanger for possible thread damage or source of past leak. If any damage is found on penetrators or cap string threads, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 2-7/8" tubing. Lay down ESP. a. Inspect GLMs and if mandrels are in satisfactory condition, send to G&I for cleaning for future re- use. Mark each mandrel with the type of valve in pocket (DV, OV, etc.) b. Recover the XN-Nipple for re -use on the new completion. c. Send all tubing to G&I for washing and disposal. d. Recover cable clamps that are in proper working condition. i. Reusable clamps should be sent to G&I for cleaning and to the materials warehouse for future reuse. e. The completion has the following amount of clamps/guards: i. 225 Cross Collar Cannon Clamps ii. 5 Protectolizers iii. 3 Flat Guards j 20. PU new ESP and RIH on 2-7/8" 6.5# L-80 tubing. Set base of ESP assembly at± 13,150' MD. 4}Iy a. Station #3: 2-7/8"x 1" Side -pocket GLM @ ± 200' MD with 7/16" DPOV b. 2-7/8" tubing &161- c. Verify need -Dependent upon reservoir pressure: CO 3(o,4 i. Station #2: 2-7/8"x 1" Side -pocket GLM with dummy GLV 1'1a ii. 1 joint of 2-7/8" tubing iii. ESP Packer @ 2,250' and with vent valve and control line d. 2-7/8" tubing e. Station #1: 2-7/8"x 1" Side -pocket GLM with Dummy GLV f. 3 joints of 2-7/8" tubing g. 2-7/8" XN (2.205" No -Go) Nipple h. 1 joint of 2-7/8" tubing i. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. j. Pump#1 (119 -stage 538P) k. Gas Separator I. 250 HP Baker Hughes 562XP Motor m. Motorgauge n. Base of ESP centralizer @ ± 13,150' and 21. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 22. Drop ball and rod and allow to fall on seat. 23. Pressure up tbg as per Service Supervisor and set the ESP packer. ,24. Test tbg to 3,OOOpsi for 30 min (charted). Test the IA to 1,500psi for 30 min (charted). Bleed all pressures to Opsi. 25. Set BPV. ESP Change -Out Well: MPU E-10 Ililmvu Alaek,, LL' Date: 10-04-19 Post -Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. Set BPV Plug (converts BPV to a TWC). RU crane. ND BOPE. 28. NU existing Cameron 2-9/16" 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 29. Pull BPV plug and BPV. 30. RD crane. Move 500 bbl returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. Blank RWO MOC Form K IIilrnru Alselca. LLC Orig.KB Elev.: 54.4U/ GL Elev.: 24.70' TD= 14,225(MD)/TD= 7,327'(TVD) PBTD=14,084' (MD) / PBTD = 7,241'(TVD) SCHEMATIC Milne Point Unit Well: MP E-10 Last Completed: 3/01/13 PTD: 194-143 TREE & WELLHEAD Tree Cameron 2-9/16" SM Wellhead 7-1/16"5M FMC w/2-7/8" WKM Tubing Hanger w/3"L.H. ACME x 2-7/8" 8rd Bt m Thread , 2.5" CIW H BPV profile. OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I (Approx) in 24" Hole 9-5/8" Cmt w/ 804 sks PF "E", 250 sx Class "G" in 12-1/4" Hole 7" Cmt w/ 307 sks Class "G" in 8-1/2" Hole 5" Cmt w/ 130 sks Class "G" in 6" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 9-5/8" Surface 40/L-80/BTC 8.835" Surface 4,100' 0.0759 7" Intermediate 26/L-80/NSCC 6.276" Surface 13,387 0.0383 5" Liner 15/ 13CR-80/ FL4S 4.408" 13,241' 14,220 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5/L-SO/EUE Brd 2.441" Surface 13,139' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 60 -67 deg. f/ 3,100' too 13,704 Hole Angle through perforations = 57 deg. JEWELRY DETAIL No Depth Item GLM Detail: Camco KBMG / BK Latch / 1" 1 139' ST 2: Port= 0, VIv= Bury, TVD= 139', Date= 9/17/16 2 12,889' ST1:Port= 0, VIv=Dmy, TVD=±6,673', Date=3/23/18 3 13,035' 2-7/8" "XN" Nipple, ID=2.250" 4 13,077' Discharge Head 5 13,077' Pump PMSXD/ 161P11 6 13,099' Gas Separator GRSFTX, ARI -16 Intake 7 13,104' Tan dem Seal Section 8 13,118' Motor MSP -1, 210 HP, 2380 Volts, 53 Amps 9 13,137' Centralizer with MGU Sensor 10 13,200' FB -1 Packer (Drift 3.875" during 2000 RWO) 11 13,241' 5" Setting Sleeve 12 13,248' S" Baker Packer 13 13,254' S" Baker Liner Hanger 14 13,720' S" Weatherford Cast Iron Bridge Plug set 12/26/2000 PERFORATION DETAIL Sands Top (MD) Piton (MD) Top (TVD) Btm (TVD) FT Date Status Kup.CSands 13,630' 13,694' 7000' 1 7031' 1 641/06/1995 Squeezed KuD.CSands 13.644 13.684 7nn7 7nma I an cid nnio" n --- GENERAL WELL INFO API: 50-029-22521-00-00 Drilled, Cased and Perfed by Nabors 22E - 1/8/1995 ESP RWO by Nabors 4ES —12/27/2000 ESP RWO and Re -Pert by Nabors 4ES — 5/08/2002 Tubing Patch —10/20/2006 ESP RWO by Nabors 3S —3/27/2007 ESP RWO by Doyon 16 — 3/01/2013 Revised By: TTW 6/14/2019 KPROPOSED SCHEMATIC eoru Aleeka, LLC Orig. KB Elev.: 54.40'/ GL Elev.: 24.70' To= 14,225' (MD)/TD=7,327(TVD) PBTD=14,084' (MD) / PBTD= 7,241'(TVD) Milne Point Unit Well: MP E-10 Last Completed: 3/01/13 PTD: 194-143 TREE & WELLHEAD Tree Cameron 2-9/16" SM Wellhead 7-1/16" SM FMC W/ 2-7/8" WKM Tubing Hanger w/ 3" L.H. 7" ACME x 2-7/8" 8rd Btm Thread , 2.5" CIW H BPV profile. OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I (Approx) in 24" Hole 9-5/8" Cmt w/ 804 sks PF "E", 250 sx Class "G" in 12-1/4" Hale 7" Cmt w/ 307 sks Class "G" in 8-1/2" Hole 5" Cmt w/ 130 sks Class "G" in 6" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 9-5/8" Surface 40/L-80/BTC 8.835" Surface 4,100' 0.0759 7" Intermediate 26/L-80/NSCC 6.276" Surface 13,387' 0.0383 5" Liner 15/ 13CR-80/ FL45 4.408" 13,241' 14,220 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5/I.-80/EUESrd 1 2.441" 1 Surface 1 13,139' 1 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =60-67 deg. f/ 3,300'too 13,704 Hole Angle through perforations = 57 deg. JEWELRY DETAIL No Depth Item GLM Detail: Camco KBMG / BK Latch / 1" 1 ±140' ST 3: Port= 0, VIv= Dmy, TVD= 139', Date= xx/xx/xx 2 ±2,200' ST 2: Port= 0, VIv= Dmy, TVD=139', Date= xx/xx/xx 3 ±2,245' WFD Vent Va lve 4 ±2,250' 7"x2-7/8" Dual bore Packer 5 ±12,889' ST 1: Port= 0, VIv= Dmy, TVD=±6,673', Date= xx/xx/xx 6 ±13,035' 2-7/8" "XN" Nipple, ID= 2.250" (Preload w/ RHC Plug) 7 ±13,077' Discharge Head 8 ±13,077' Pump 538P/1195tage 9 ±13,099' Gas Separator 10 ±13,104' Tandem Seal Section it ±13,118' Motor, 250 HP, 2505 Volts, 61 Amps 12 ±13,137' Centralizer with MGU Sensor 13 13,200' FB -1 Packer (Drift 3.875" during 2000 RWO) 14 13,241' S"Setting Sleeve 15 13,248' 5" Baker Packer 16 13,254' 5" Baker Liner Hanger 17 13,720' 5" Weatherford Cast Iron Bridge Plug set 12/26/2000 PERFORATION DETAIL Sands p (MD) Btm (MD) Top (TVD) BIT (TVD) FT Date Status Ku 30,_ CSands To13,630' 13,694' 7,000' 7.031' 64 1/06/1995 Snueezed 7 GENERAL WELL INFO API: 50-029-22521-00-00 Drilled, Cased and Perfed by Nabors 22E - 1/8/1995 ESP RWO by Nabors 4ES -12/27/2000 ESP RWO and Re-Perf by Nabors 4ES-5/08/2002 Tubing Patch -10/20/2006 ESP RWO by Nabors 3S-3/27/2007 ESP RWO by Doyon 16-3/01/2013 Revised By: TTW 6/17/2019 ii 0 am Oi NN Cl) T 3 :S ro v m :a 0 =dw N > R ❑ w U13 Q a U R U> c N i O a as a 'a N N jp Y o Q c = a" am .a N Y '25 .- _ � c C CLm d R r U m a m v 0 IL R ❑ d R a CL m y C CD CD 1 R c R 2 N c O R d m Y R d d c Cc L H c O N `m a C XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~ L/_ / (/'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned bY: Bevedy~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ . t STATE OF ALASKA Alk • OSKA OIL AND GAS CONSERVATION CIIIPIMISSION a . ` ,, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ 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 • 194 - 143 3. Address: ® Development ❑ Service 6. API Numbe • P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028231 - MPE -10 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 14225' feet Plugs:(measured) 13720' feet true vertical 7327' feet Junk: (measured) 13199' feet Effective depth: measured 14084' feet Packer: (measured) 13200' feet true vertical 7241' feet Packer: (true vertical) 6799' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32' - 112' 32' - 112' 1490 470 Surface 4069' 9 -5/8" 31' - 4100' 31' - 3117' 5750 3090 Intermediate Production 13355' 7" 30' - 13385' 30' - 6882' 7240 5410 Liner 979' 5" 13241' - 14220' 6817' - 7323' 10140 10490 Perforation Depth: Measured Depth: 13644' - 13760' feet True Vertical Depth: 7006' - 7064' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 13139' 6774' Packers and SSSV (type, measured and true vertical depth): FB- 1 Packer 13200' 6799' 12. Stimulation or cement squeeze summary: Intervals treated (measured): A SCANNED APR 2013 u 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: 90 19 1204 100 180 Subsequent to operation: 94 16 845 100 177 14. Attac ❑Copies of Logs and Surveys run 15. Well Class after work: - ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® 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: Sean McLaughlin, 564 -4387 Email: Sean.McLaughlin @bp.com Printed Na - q Joe Last Title: Drilling Technologist ) Signature: Phone: 564 -4091 Date: ✓ I I3 Form 10 -40Ra i- n 12 ©1$R \1i 2013 ��D VF L , ^0 1 )11)3 0 0 Submit Original Only I • Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/22/2013 00:00 - 01:00 1.00 MOB P PRE R/D AND BLOW DOWN ALL CELLAR LINES - SECURE TREE AND ATTACH GAUGES - FUNCTION TEST MOVING SYSTEM AND CHECK ALL HYDRAULIC LINES - E -MAIL NOTIFICATION GIVEN TO AOGCC FOR BOP TEST ON MPE -10, 2/21/13 AT 09:22 01:00 - 03:30 2.50 MOB P PRE PJSM, BRIDLE UP DERRICK - NOTIFY PAD OPERATOR OF MOVE OFF WELL - PREP RIG FLOOR TO LAY OVER DERRICK - MOVE CUTTINGS TANK, CREW TRAILER AND AUX FUEL TANK.AWAY FROM RIG - RAISE RIG AND REMOVE SHIMS PREPARE TO PULL OFF MPH -19 03:30 - 06:30 3.00 MOB P PRE PJSM, PULL OFF WELL MPH -19 - REPOSITION RIG ON PAD TO LAY DERRICK OVER WTH THE WIND. - CONDUCT HAZARD ASSESSMENT WITH WSL AND TOOL PUSHER FOR LOWERING DERRICK DUE TO WIND SPEED. LAY DERRICK OVER WITH WIND DIRECTION 06:30 - 12:00 5.50 MOB P PRE 1 CALL OUT MILNE POINT HEAVY DUTY LOADER TO ASSIST WITH BOOSTER FRAME. - REPOSITION RIG TO ALLOW WORK OUT OF THE BLOWING SNOWAND WIND. - INSTALL FRONT BOOSTER FRAME - INSTALL FRONT BOOSTER WHEELS AND FUNCTION TEST - LOAD WSL OFFICE ON TRUCK AND MOVE TO MPE PAD MOST OF THE WORK IS CONDUCTED OUTSIDE OF THE CONFINES OF THE RIG AMBIENT TEMP - 28 F WIND CHILL -60 F WIND SPEED 20 -25 MPH 12:00 - 16:00 4.00 MOB P PRE PJSM, DISCUSS HAZARDS RELATED TO WORKING IN COLD TEMPERATURES WITH CREW, WSL AND TOOLPUSHER - REPOSITION RIG OUT OF THE WIND TO ALLOW WORK IN THE CELLAR - TEMP IS -37, WIND CHILL IS -71 DEGREES - REMOVE BOP STACK FROM CELLAR AND SECURE ON TRANSPORT CRADLE - INSTALL REAR BOOSTER WHEELS AND FUNCTION TEST 16:00 - 22:00 6.00 MOB P PRE PJSM FOR RIG MOVE - MOVE RIG FROM MPH PAD TO MPE PAD - SPOT RIG ON MPE PAD TO ALLOW ACCESS TO REMOVE BOOSTER WHEELS AND RAISE DERRICK 22:00 - 00:00 2.00 MOB P PRE PJSM, R/D REAR HYDRAULIC LINES ON BOOSTERS - REMOVE REAR BOOSTER WHEELS FROM CELLAR Printed 3/11/2013 10:58:18AM • • b th America - A` Operation Summary Repo Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) C Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date /Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ _ (ft) 2/23/2013 00:00 - 02:00 2.00 MOB P PRE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - INSTALL BOP STACK ON STUMP IN CELLAR - INSTALL SPACER SPOOL ON BOTTOM OF BOP 02:00 - 05:00 3.00 MOB P PRE LAY RIG MATS AROUND MPE -10 - DIG WELL HEAD EQUIPMENT OUT OF SNOW — BANK AND SPOT BEHIND WELL. DEEP SNOW DRIFTS ON THE PAD HINDERING LAYING MATS. MOST OF THE WORK IS CONDUCTED . OUTSIDE OF THE CONFINES OF THE RIG . AMBIENT TEMP - 31 F WIND CHILL -63 F 'WIND SPEED 20 -25 MPH, 5 05:00 - 09:00 4.00 MOB P PRE PJSM, BACK RIG OVER WELL • - NOTIFY PAD OPERATOR. SPOTRIG OVER MPE-10 - SHIM UP AROUND RIG AND LEVEL SAME - SPOT CUTTINGS TANK AND CREW CHANGE TRAILER 09:00 - 10:00 1.00 MOB t� P PRE PJSM, RAISE DERRICK - ONDUCT RISK ASSESSMENT WITH WSL A TOOLPUSHER TO RAISE DERRICK . AGAINST THE WIND. - RAISE DERRICK AND SECURE. - JEFF JONES OF AOGCC WAIVED STATES •, RIGHT TO WITNESS BOP TEST 10:00 - 18:00 8.00 KILLW' P'` ' DECOMP - RIG UP FLOOR. - RIG UP CELLAR. BERM AROUND CELLAR WITH SNOW - POSITION CHOKE SKID AND LINES. - RIG DOWN BRIDLE LINES FROM BLOCKS. - ATTACH BLOCKS TO TOP DRIVE. - RIG ACCEPTED AT 10:30 HRS - RECEIVE 8.7 PPG BRINE INTO PITS. 18:00 - 00:00 6.00 KILLW P DECOMP PJSM, R/U WELL KILL MANIFOLD IN CELLAR - R/U CIRCULATING LINES TO KILL MANIFLOD ANDFLOW BACK TANK - TEST KILL MANIFOLD AND ALL CIRCULATING LINES WITH DIESEL PER DOYON PROCEDURE - 250 / 3500 PSI, 5 MIN, CHARTED - BLOW DOWN LINES TO FLOW BACK TANK - AO = 0 PSI, IA = 360 PSI 2/24/2013 00:00 - 03:00 3.00 KILLW P DECOMP PJSM, SPCC AND EQUIPMENT CHECKS - FUNCTION TEST SSV VALVE - LOAD 440 JOINTS OF 2 7/8" EUE 8 ROUND TUBING INTO PIPE SHED 03:00 - 05:00 2.00 WHSUR P DECOMP PJSM, R/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, CHARTED - PULL BPV - R/D WELL SUPPORT - SECURE TREE, CLOSE ALL VALVES - IA = 340 PSI, TUBING = 350 PSI Printed 3/11/2013 10.58.18AM • Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 05:00 - 08:00 3.00 WHSUR P DECOMP LOAD 2 7/8" TUBING INTO PIPE SHED. DRIFT AND STRAP - MAINTAIN HAZARD AWARENESS WHILE LOADING PIPE SHED - PHASE 2, LEVEL 2, TEMP = -22 F, WIND CHILL = -53 F, 25 MPH WIND 08:00 - 10:00 2.00 WHSUR P DECOMP PJSM. WELL KILL PROCEDURE. COMMUNICATION. VAC TRUCK MOVEMENT. - BLEED 360 PSI GAS FROM IA TO 0 PSI. NO FLUID TO SURFACE. - CIRCULATE 80 BBL 8.7 PPG BRINE DOWN TUBING AT 3 BPM WITH 820 PSI. - FLUID TO. SURFACE AFTER PUMPING 3 BBL - PRESSURE WHILE CIRCULATING 820 TO 625 PSI. CLOSE CHOKE ON THE FLY AND BULLHEAD 30 BBL 8.7 PPG BRINE. - PRESSURE WHILE BULLHEAD 700 TO 1100 PSI. OPEN CHOKE TO CIRCULATE DOWN TUBING AND UP IA. - RETURNS TO THE FLOW BACK TANK IS ALL OIL. 10:00 - 12:00 2.00 WHSUR P DECOMP STRAP FLOW BACK TANK. SUCK OUT 288 BBL OIL TO SEND TO RECYCLE. - TOP OFF RIG PITS WITH NEW 8.7 PPG BRINE. 12:00 - 14:30 2.50 WHSUR P DECOMP CIRCULATE A TOTAL OF 600 BBL 8.7 PPG DOWN TUBING OUT THE IA. - ALL RETURNS GOING TO FLOW BACK TANK. - AFTER PUMPING 448 BBL RETURNS CHANGED TO OILY WATER - RETURNS CLEANED UP TO 8.7 PPG BRINE AFTER PUMPING —500 BBL. 14:30 - 15:00 0.50 WHSUR P DECOMP MONITOR WELL. TUBING PRESSURE 35 TO 0 PSI - IA PRESSURE 30 TO 0 PSI. - OPEN BOTH SIDES TO CONFIRM THE WELL IS DEAD. 15:00 - 16:30 1.50 WHSUR P DECOMP BLOW DOWN LINES IN THE CELLAR. - RIG DOWN LINES AND CHOKE MANIFOLD IN THE CELLAR. - RIG UP LINE TO FILL HOLE DOWN IA. - STATIC LOSSES AT 12 BPH. 16:30 - 18:30 2.00 WHSUR P DECOMP PICKUP WELL SUPPORT LUBRICATOR. - MAKE UP LUBRICATOR AND TEST TO 250/3500 PSI FOR 5 MINUTES - INSTALL TWC - R/D LUBRICATOR AND WELL SUPPORT EQUIPMENT 18:30 - 20:00 1.50 WHSUR P DECOMP PERFORM ROLLING TEST BELOW TWC T 2.5 BPM = 550 PSI, 36 BBLS PUMPED, 10 BBLS RETURNED - TEST TWC FROM ABOVF_ 254L-.35DQ RSJ -4- — MIN, _ CHARTED - R/D TEST EQUIPMENT 20:00 - 21:30 1.50 WHSUR P DECOMP PJSM, fiD TREEJMC REP. PRESENT - CHECK HANGER TREADS = 9 LH TURNS, 3" LH ACME THREADS - CLEAN AND INSPECT TUBING HANGER Printed 3/11/2013 10:58:18AM • • -gf f /' ' ifs !f %r/ f �r f /; , 0 00 -0 `° ( America - ACA 8 Operation Summary Repo "' Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 00:00 2.50 BOPSUR P DECOMP PJSM, N/U BOP - INSTALL 7 1/6" X 13" SPACER SPOOL - CONNECT KUMMI HYD LINES - OA = 0 PSI - LOSS RATE = 12 BPH - 24 HOUR FLUID LOSS = 88 BBLS 2/25/2013 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM, SPCC AND EQUIPMENT CHECKS N/U BOP AND FUNCTION TEST ALL RAMS SERVICE CHOKE MANIFOLD 02:30 - 03:30 1.00 BOPSUR P DECOMP PJSM, R/U TO TEST BOP - M/U TEST JOINT AND FLOOR VALVES - R/U TEST PUMP AND EQUIPMENT 03:30 - 12:00 8.50 BOPSUR P DECOMP PJSM, BOPE TEST TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES, - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED TEST 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, CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST - IT WAS NECESSARY TO BUMP UP THE PRESSURE ON SEVERAL TESTS DUE TO SUSPECTED LEAK -BY ON TWC. - JEFF JONES OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST 02/23/2013 AT 08:00 HOURS - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST, FLUID LOSS = 11 BPH 12:00 - 13:00 1.00 BOPSUR P DECOMP BLOW DOWN AND RIG DOWN BOP TEST LINES. - RIG DOWN BOP TEST EQUIPMENT. 13:00 - 15:00 2.00 WHSUR P DECOMP PJSM. INSTALL LUBRICATOR. PULLTWC - SUCK FLUID OUT OF BOP TO CLEAN AND INSPECT TWC PRIOR TO PULLING SAME. - MAKE UP LUBRICATOR EXTENSION TO TUBING HANGER. - MAKE UP LUBRICATOR AND TEST 250/3500 PSI FOR 5 MINUTES. - PULL TWC. - RIG DOWN LUBRICATOR AND LAY DOWN SAME. 15:00 - 17:00 2.00 PULL P DECOMP PJSM. PULL TUBING HANGER WITH LANDING JOINT - MAKE UP 3" LH ACME CROSS OVER TO LANDING JOINT WITH FOSV ON TOP. - MAKE UP TO TUBING HANGER. - SCREW INTO TOP DRIVE. - FMC REP BACK OUT LOCK DOWN SCREWS. - PULL HANGER FREE WITH 105 K INCI UDING 40 BLOCK WEIGHT. SLACK OFF WEIGHT 80 K Printed 3/11/2013 10:58:18AM • • Operation Summary Report Common Well Name: MPE-10 AFE No Event Type: VVORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4-00X8F-E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DO YON . Date/Time: 4/29/200 I I I - - e: 3/1/2013 Rig Contractor: DOYON DRILLING Active datum: Kelly Bushing / Rotary Table @54.0ft Date From - To Hrs (above Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 19:30 2.50 PULL P DECOMP PULL HANGER TO RIG FLOOR CUT ESP CABLE AT BOTTOM OF FIRST FULL JOINT - PUMP 40 BBL SOAP PILL SURFACE TO SURFACE THRU GAS BUSTER - 5 BPM = 1640 PSI, 50 BBL LOSS ON CIRCULATION 19:30 - 21:00 1.50 PULL P DECOMP ENSURE NO PRESSURE BELOW ANNULAR OPEN ANNULAR, MONITOR WELL 20 MINUTES L/D HANGER AND LANDING JT - BLOW DOWN TOP DRIVE, CHOKE AND KILL LINE 21:00 - 00:00 3.00 PULL P DECOMP PJSM, L/D 2 7/8" FtJF, §Rb }TUBING ESP COMPLE JON. t POOH FROM 13132'"1O 11644' � - - PUW7`= 100K, SOWT = 80K, INC. 40K BLOCK WT. - OA = 0 PSI - LOSS RATE = 8 BPH 24 HOUR FLUID LOSS = 215 BBLS 2/26/2013 00:00 - 00:30 0.50 - P11L1 P DECOMP -PJSM, PERFORM SPCC AND EQUIPMENT { CHECKS - SERVICE RIG 00:30 - 10:30 10.00 PULL'" P DECOMP PJSM, L/D 2 7/8" EUE 8RD TUBING ESP COMPLETION - POOH FROM 11644' TO 4883' - HOLE IN TUBING WAS FOUND ON JT 120, -3744' MD, -1/4" DIA. HOLE 10:30 - 12:00 1.50 PULL P DECOMP HOLD SAFETY MEETING WITH CREW, TOOLPUSHER, DRILLING OPERATIONS MANAGER, WELLS INTERVENTION MANAGER, AND ALASKA VICE PRESIDENT OF WELLS - MEETING FOCUS ON SAFETY AND PERFORMANCE OF CREWS AND RIG - GOOD HONEST DISCUSSION WITH THE MANAGERS CONCERNING ISSUES THAT ARE IMPORTANT TO THE HANDS AND TO BP - ACKNOWLEDGMENT OF SUPPORT FROM BP GIVEN TO HANDS TO TAKE TIME TO TRAIN NEW EMPLOYEES - VERY CONSTRUCTIVE MEETING 12:00 - 19:00 7.00 PULL P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - L/D 2 7/8" EUE 8RD TUBING ESP COMPLETION - POOH FROM 4883' TO ESP PUMP AND MOTOR ASSY - CLEAR ESP ASSEMBLY THRU ROTARY TABLE - MAINTAIN CONTINUOUS HOLE FILL WITH 8.7 PPG BRINE 19:00 - 20:00 1.00 PULL P DECOMP PJSM, R/D ESP EQUIPMENT - SPOOL REMAINING ESP CABLE INTO SPOOLING UNIT - R/D ESP SHEAVE AND CLEAR RIG FLOOR Printed 3/11/2013 10:58:18AM • . North America - ALAw .. � r f/� ovew ". 7/" O Summary Report �.., / Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E.DRILL (1,475,000 00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI Active datum: Kelly Bushing / Rotary Table @54.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:30 1.50 PULL P DECOMP L/D ESP PUMP AND MOTOR - PUMP WAS LOCKED UP AND CONTAINED SCALE AND CORROSION - LASALLE CLAMPS = 218 - PROTECTOLIZERS = 4 - FLAT GUARDS = 2 21:30 - 23:00 1.50 PULL P DECOMP "`" CLEAR, SCRUB RIG FLOOR INSTALL 6 1/8" ID WEAR BUSHING 23:00 - 00:00 1.00 EVAL P DECOMP PJSM, M/U 7" CHAMP PACKER - F7IH'' WITH NEW 2 7/8" 6.5# EUE 8RD TUBING - P/U 1X1 FROM PIPE SHED, AVG M/U TQ = 1950 FT /# - FROM SURFACE TO 465' -OA =0 PSI -- - LOSS RATE = 8 BPH - 24 HOAR FLUID LOSS = 247 BBLS 8.7 PPG BRINE 2/27/2013 00:00 - 01:00 1.00 EVAL P DECOMP -PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE SKATE AND DRAW WORKS 01:00 - 06:00 5.00 EVAL P DECOMP CONTINUE RIH WITH 7" CHAMP PACKER ON 2 7/8" 6.5# EUE 8RD TUBING - P/U 1X1 FROM PIPE SHED, AVG M/U TQ = 1950 FT /# - FROM 465' TO 4085' 06:00 - 12:00 6.00 EVAL -- P DECOMP CONTINUE RIH WITH 7" CHAMP PACKER ON 2 7/8" 6.5# EUE 8RD TUBING - P/U 1X1 FROM PIPE SHED, AVG M/U TQ = 1950 FT/# - FROM 4085' TO 8599' MD. - CONTINUOUS HOLE FILL WITH 6 BPH LOSS RATE. 8.7# BRINE. 12:00 - 12:30 0.50 EVAL P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE TOP DRIVE AND PIPE HANDLER 12:30 - 13:30 1.00 EVAL P DECOMP PJSM, TO SET AND PRESSURE TEST CSG. - OBTAIN PARAMETERS. - PU WT. = 73K INCLUDING 40K BLOCK WT. SO WT. = 68K. - CONTINUE RIH T/ 8621' MD. - P/U 1 JT 4" DP. - FLUSH ACROSS SETTING DEPTH 5 BPM / 940 PSI - SET HES PACKER PER HES REP W/ 20K DOWN WT. - WSL VERIFIED SET DEPTH. - WSL / TOOLPUSHER VERIFIED VALVE ALIGNMENT. Printed 3/11/2013 10:58:18AM • • r.�^M,f.�mr � .:r, f oitfl Atnenc8 - ALAsa B Operation Summary Rep¢ Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date. 2/22/2013 End Date. 3/1/2013 X4- 00X8F- E.DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 15:30 2.00 EVAL P DECOMP PJSM, MIT -IA, 7 ", 26# CSG BY 2 -7/8" ANNULUS. - PUMPED 37 STROKES (2.9 BBLS) TO 3,000 PSI, FOR 30 CHARTED MINUTES. - FILL THRU TBG DURING TESTING OPERATIONS. - 6 BPH LOSS RATE. MIT -IA TEST, MEETS BP STP CRT -AK -10-45 - RECEIVED PERMISSION TO PROCEED FROM WTL. ' DRILLER / WSL / TOOLPUSHER VERIFIED NO TRAPPED PRESSURE, OPEN-PIPE RAMS. RELEASE CHAMP PACKR. - MONITOR WELL FOR 10 MINUTES. - BLOW DOWN TEST LINES. 6 BPH LOSS RATE. - SEE ATTACHMENTS 15:30 - 18:00 2.50 EVAL P DECOMP PJSM, POH WITH 7" CHAMP TEST PACKER F/ 8621' MD. - WITH CONTINUOUS HOLE FILL -6 BPH LOSS RATE. - TO SURFACE 18:00 - 19:00 1. EVAL P - DECOMP PULL WEAR BUSHING - CLEAR CLEAN RIG FLOOR 19:00 - 20:30 1.50 RUNCOM P RUNCMP PJSM, HANG ESP CABLE SHEAVE AND R/U - MOBILIZE ESP CANNON CLAMPS AND CENTRILIFT EQUIP TO RIG FLOOR - R/U FLOOR TO RUN COMPLETION - STRING ESP CABLE OVER SHEAVE TO RIG FLOOR 20:30 - 23:00 2.50 RUNCOM P RUNCMP PJSM, RUN COMPLETION - M/U ESP MOTOR AND PUMP ASSY - M/U ESP CABLE TO PUMP AND MOTOR ASSY AND TEST FOR CONDUCTIVITY 23:00 - 00:00 1.00 RUNCOM P RUNCMP RUN 2 7/8" 6.5# EUE 8RD TUBING ESP_ COMPLETION - RIH WITH SANDS, FROM MOTOR ASSY TO 260' - INSTALL CANNON CLAMPS ON EVERY COLLAR FOR THE FIRST 9 JTS - TORQUE CONNECTIONS THAT HAVE PREVIOUSLY BEEN MADE UP TO 2300 FT/# - TORQUE NEW CONNECTIONS TO 1950 FT /# - OA =0PSI - LOSS RATE = 6 BPH - 24 HOUR FLUID LOSS = 144 BBLS OF 8.7 PPG BRINE 2/28/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE SKATE, DRAW WORKS AND TOP DRIVE Printed 3/11/2013 10:58:18AM • • e S ,, ! 3t �l. C AFE No ommon Well Name: MPE -10 Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 08:30 8.00 RUNCOM P RUNCMP RUN 2 7/8" 6.5# EUE 8RD TUBING ESP COMPLETION PER RUNNING ORDER RIH WITH STANDS, FROM 260' TO 5544' (AT 6:00 AM) it IA CANOAMPS EVERY FROM THER C OLLAR INSTALL NST CLAMPS NN ON CL EVERY ON COLLAR 41 4', ' - 4900', AND THA 5200' BECA USE OF 4600 DOG TOR - QUE 200 CONNECTIONS T HAVE PREVIOUSLY BEEN MADE UP, TO 2300 FT /# - TORQUE NEW CONNECTIONS TO 1950 FT /# - MAINTAIN CONTINUOUS HOLE FILL WITH 1/2 8.7 PPG BRINE CHECK CONDUCTIVITY EVERY 2000' AND BREAK CIRCULATION DOWN TUBING AT BPM TO FLUSH PUMP.' 1/2 BPM = 1210 PSI AT 6,000' MD. 08:30 - 12:00 3.50 RUNCOM ' P RUNCMP CENTRILIFT,REPPERFORM REELTO REEL ESP CABLE SPLICE - ON J A,' - CHECK OINT# CONDUCTI V ITY. 000 - DRESS NEW PRODUCTION TREE WITH 1502 WING FLANGE 12:00 - 12:30 0.50 RUNCOM P RUN - ERIVE - INSPECT PJSM, INSP PIP E HAND D LER. - WSL COMPLETED "WELL WORK TRANSFER PERMIT" - WITH A FACE TO FACE MEETING WITH MPL -PAD OPERATOR _-CE FOR NEXT WELL MPL -14. 12:30 - 20:30 8.00 RUNCOM P RUNCMP ONTINUE RUN 2 7/8" 6.5# TUBING SP COMPLETION PER RUNNING ORDER - RIH WITH SM 8000EUE " 8RD TO TUBI 8680' MD INSTALL CANNON CLA FROM PS ON EVERY OTHER COLLAR _ INSTALL CLAMPS ON EVERY LAR FROM 4 4200' 4600' - 4900', AND 5200 - 5400' BECAUSE OF DOG LEGS - TORQUE CONNECTIONS THAT HAVE PREVIOUSLY BEEN MADE UP, TO 2300 FT /# - TORQUE NEW CONNECTIONS TO 1950 FT /# - MAINTAIN CONTINUOUS HOLE FILL WITH 8 PPG BRINE - CNDTITY E0 BREAK CIRC UC DOWN TUBING G 200' AT AND /2 - .5 BPM = 1650 PSI AT 120 1 BPM TO HECK FLUSH PUMP. CONDUCTIVITY - CANNON CLAMPS = 225 - PROTECTOLIZERS = 5 - FLAT GUARDS = 3 P/U 2 -7/8" JOINTS 1X1 FROM PIPE SHED - STARTING FROM JOINT# 274 TO #413 - WSL RECEIVE HAND -OVER FOLDER FROM FACE TO FACE MEETING WITH MPU WELL OPS COORD. FOR MPL -14. Printed 3/11/2013 10:58:18AM • • fgcr rr/.+,,+;', F7'r'"/`,'/'' '.�i'7i! �!/ i"il"//,r�rL.'7 «, <: +�„ „ ..rc,: �. �� 7irrr �f North Am erica - ALASKA SF' Operation Summary Rep ®, Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 21:00 0.50 RUNCOM P RUNCMP M/U HANGER PER FMC REP - C/O ELEVATORS - M/U CROSSOVERS AND FOSV TO LANDING JOINT - M/U LANDING JT TO HANGER - INSTALL PENETRATOR, CUT ESP CABLE TO LENGTH 21:00 - 23:30 2.50 RUNCOM P RUNCMP ' CENTRILIFT REP TERMINATE ESP CABLE AT HANGER - TEST CONDUCTIVITY, CHECK DOWN HOLE GAUGES - MAINTAIN CONTINUOUS HOLE FILL AT 6 BPH 23:30 - 00:00 0.50 RUNCOM P RUNCMP LAND TUBING HANGER, RILDS - L/D LANDING JOINT INSTALL TWC PUWT = 98K, SOWT = 77 (INCLUDES 40K BLOCK WT) OA= 0 PSI - LOSS RATE= 6 BPH - 24 HOUR FLUID LOSS = 76 BBLS OF 8.7 PPG BRINE 3/1/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT .CHECKS - R/U TEST EQUIPMENT - TEST TWC FROM BELOW, 500 PSI, 10 MIN, CHARTED - 2.5 BPM = 500 PSI, PUMPED 23 BBLS AWAY - TEST TWC FROM ABOVE, 250 / 3500 PSI, 5 MIN, CHARTED 01:00 - 01:30 0.50 RUNCOM P RUNCMP PJSM, R/D CENTRILIFT - R/D ESP SHEAVE AND CLEAR CENTRILIFT EQUIPMENT FROM RIG FLOOR - BREAK OUT LANDING JT AND CROSSOVERS 01:30 - 05:00 3.50 BOPSUR P RUNCMP PJSM, N/D BOP - BLOW DOWN ALL LINES, SUCK OUT STACK - BREAK OUT XO'S FROM LANDING JT - REMOVE 7 1/6" X 13 5/8" SPACER SPOOL FROM BOP - REMOVE SPACER SPOOL FROM CELLAR - R/D SPOOLING UNIT AND EQUIPMENT - MAINTAIN CONTINUOUS HOLE FILLAT 6 BPH 8.7 PPG BRINE 05:00 - 06:30 1.50 WHSUR P RUNCMP N/U NEW 2- 9/16" 5M CAMERON TREE AND 7- 1/16" SKEWED ADAPTOR FLANGE. - CALL WELL SUPPORT TO VERIFY ALIGNMENT OF WING VALVE - WSL / DRILLER / FMC REP AND MPU WELL SUPPORT TECH PRESENT TO VERIFY PRODUCTION TREE ALIGNMENT TO FLOW LINE. Printed 3/11/2013 10:58:18AM • • Common Well Name: MPE -10 AFE No Event Type: WORKOVER (WO) Start Date: 2/22/2013 End Date: 3/1/2013 X4- 00X8F- E:DRILL (1,475,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/2002 12:00:00AM Rig Release: 3/1/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 12:00 5.50 WHSUR P RUNCMP FMC REP PRESSURE TEST ADAPTER VOID - 250 PSI FOR 5 CHARTED MINUTES, PASSED. - 5000 PSI FOR 30 CHARTED MINUTES. PASSED. - PRESSURE TEST PRODUCTION TREE - 250 / 5000 PSI, BOTH 5 MINUTES CHARTED. PASSED. WITNESSED BY DRILLER. - CENTRILIFT REP TOOK FINAL ESP READINGS WTLAND' RWO SUPERINTENDENT VISIT RIG AND HELD OPEN DISCUSSION WITH CREW. 12:00 - 14:00 2.00 WHSUR P RUNCMP PJSM, R/U AND TEST DW' :LUBRICATOR - TEST LUBRICATOR TO 250 / 3500 PSI, FOR 5 CHARTED MINUTES. - PULL TWC - RETEST LUBRICATOR, INSTALL 2 -1/2" TYPE BPV. - RID DSM LUBRICATOR. - TEST BPV PERFORM ROLLING PRESSURE TEST FROM -BELOW BPV PUMPED 34 BBLS AT 3 BPM FOR 10 CHARTED MINUTES TO MAINTAIN -500 PSI 14:00 - 15:00 1.00 WHSUR P RUNCMP R/D TEST EQUIPMENT - BLOW DOWN AND R/D ALL LINES IN CELLAR - R/D RIG FLOOR AND MUD MANIFOLD - OFF -LOAD AND CLEAN PITS AND CUTTINGS TANK 15:00 - 16:00 1.00 RIGD P OTHCMP SECURE TREE, INSTALL GUAGES - RIG DOWN AND BLOW DOWN ALL CIRC. LINES - SECURE CELLAR FOR RIG MOVE - CLEAN PITS AND CUTTINGS BOX - PREP RIG FOR MOVE OFF WELL - WHP = TUBING = 0, IA= 0. OA =0 PSI. RELEASE RIG AT 16:00 HOURS Printed 3/11/2013 10:58:18AM r Tree: 2 9/16" - 5M Cam* M P U E-1 0 Ori Elev. BL Elev. = 24 725 (N 22E) Wellhead: 7 1/16" 5M FMC RT Tbg. Spool = 28.55' (N 22E) w/ 2 7/8" WKM Tubing Hanger , w/ 3" L.H. Acme X 2 7/8" 8rd Btm Thread 2.5" CIW H BPV profile , 7.p I" 91.1 ppf, H -40 80' 11 Camco 2 7/8" x 1" KBMG GLM I 139' KOP @ 500' hole angle = 60 -67 deg. f/ 3,100' to 13,704' Hole angle thru' perfs = 57 deg 9 5/8 ", 40# /ft, L -80 Btrs. 4100' / , Q 8497' Halliburton ES cementer 2 7/8"' 8.5 ppf. LAC, 8rd EUE 114, I Cameo 2 -710'x 1" KIWIS 011/1 firtft f1*2,317•,oapr ODOb132 bpi) NEW a an3 1M " 2 -710" X N nipple I 13$136" I UMW r 26 ppf. LSO. NSCC production casing 2.25,0' "No - ID ( drift ID = 8.151 ', cap. rir ao3ea bpf ) _ XT -1 Pressure Head 13,076' I. Pump PMSX 0 / 18I P11 1a,d7i" Gas Separator GRSFTX, ARH6 • ` Intake 13,099' II Tandem Sell 'Section I 13,104' j 0s113fIIIUT /0s03 fl T m I MSp - 210 HP, IMMEI iir 2380 mss,53 imps Centralizer with &IOU Sensor I 121,137' I Sensor TVD 6771' ow 6 fin Centralizer lost in hole I 13,199' (dimensional drawing in well file) FB -1 Packer I 13,200' Motor Weal arp. MR 1'Laedllgc�o Wier 13A01" t' -2 13,210 4` Sea111udtcolldr IMIlli Mitt, pkr, IIPLPO I 132471 I r arm maul oe A lik Lae r lig, MAC OEMS Perforation Summary Ref log: Sperry EWR4 Weatherford cast iron bridge plug 13,720' Size SPF Interval (TVD) Set 12/26/00 by 4 -es. Kup C sands 2 7/8" 6 13,644' - 13,684' 7006' - 7026' 3 -3/8" 6 13,630'- 13,694' Sqi ed Baker landing collar I 14,085' Kup B sands 3 -3/8" 6 13,732'- 13,760' B/P Set, Sqz'ed Baker float collar 14,173' Baker float shoe I 14,220' I DATE ZEV. BY COMMENTS MILNE POINT UNIT 01/11/94 MEL CTU comp 01/15/95 JJM Initial Comp. Nabors 22E WELL E -10 12/27/00 MDO ESP RWO Remove Coil / Set BP 4-es 05/10/02 MJA Sqz off channel/ Re-perf/ change out ESP API NO: 50 -029 -22521 3/24/07 L. Hulme ESP RWO w/ 3S 3/03/2013 B. Bixby Doyon 16 ESP and Tubing Change Out BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 , :r Post Office Box 196612 Anchorage, Alaska 99519 -6612 WeakiNED FEB 2 2 ZO1 ` x December 30, 2011 VP+ _ 4- 3 YVVC 0 •M Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue s; . ,ulatranitm Anchorage, Alaska 99501 Cnr;.M la's Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -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 extemal 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, Mehreen Vazir BPXA, Well Integrity Coordinator • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job -p MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -138 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/642011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE-31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE-32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 Rte ~°- ~,~ . L~" STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ON ~~~ ''` .,, REPORT OF SUNDRY WELL OPERATIO.~;I ~ r~- /; , 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Othe~, ACID TREATMENT y Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Dritl Number: Name: Development Exploratory 194-1430 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22521-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54 KB MPE-10 8. Property Designation: 10. Field/Pool(s): ADLO-028231 t MILNE POINT Field/ KUPARUK RIVER OIL Pool , 11. Present Well Condition Summary: Total Depth measured 14225 feet Plugs (measured) 13720' true vertical 7326.51 feet Junk (measured) 13199' Effective Depth measured 13720 feet true vertical 7044 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20' 91.5# H-40 Surface - 112 Surface - 112 1490 470 Surface 4069 9-5/8' 40# L-80 Surface - 4100 Surface - 3117 5750 3090 Production 13355 7" 26# L-80 Surface - 13385 Surface - 9882 7240 5410 Liner 979 5" 18# L-80 13241 - 14220 6817 - 7323 10140 10490 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 13138' 0 0 - Packers and SSSV (type and measured depth) FB-1 PKR 13200' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: tft~ Intervals treated (measured): +~ti~~~' ,~i.~~`' ~ c"~ ~~l~-'~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 68 14 880 182 Subsequent to operation: 75 - 12 984 181 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil •Gas WAG ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/27/2009 Form 10-404 Revised 04/2006 ~R~~,~~ ~'~ ~ j E ,' I ~ ~~"~ ~ ubm~gin~al OOnly MPE-10 194-143 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE-10 1/6/95 PER 13,630. 13,694. 6,999.59 7,030.73 MPE-10 1/6/95 PER 13,732. 13,760. 7,049.59 7,063.7 MPE-10 12/26/00 BPS 13,720. 13,730. 7,043.6 7,048.59 MPE-10 4/30/02 SQZ 13,630. 13,720. 6,999.59 7,043.6 MPE-10 5/4/02 RPF 13,644. 13,684. 7,006.34 7,025.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP .BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPE-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ACTIVITYDATE I SUMMARY 5/14/2009 Acid Treatment Continued on 05-15-09 WSR Loaded fluids for job. 5/15/2009T/I/0=200/180/0 Acid treatment Pumped 10 bbls dead Crude followed by 10 bbls 10% DAD Acid and 70 bbls dead crude down tubing. Well to be left shut in for 30 minutes. Well to be POP to tank after soak. FWHP=0/160/0 Master, IA, OA, hand SSV open. Wing and Swab closed. FLUIDS PUMPED BBLS 80 DEAD CRUDE 10 10% DAD ACID 3 NEAT METH 93 Total . STATE OF ALASKA -~ ~ RECEIVED ALAYA OIL AND GAS CONSERVATION COMK~-V'" Átt Ai PR 1 8 2007 REPORT OF SUNDRY WELL OPERATIONS (þ~' I~¡a:;ka Oil & Gas Cons. Commission ... . 1. Operations Performed: Anchorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 194-143/ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22521-00-001 7. KB Elevation (ft): 54 <' 9. Well Name and Number: MPE-10 ~ 8. Property Designation: 10. Field / Pool(s): ./ ADL 028231 ¡ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 14225/ feet true vertical 7327- feet Plugs (measured) 13720' Effective depth: measured 13720 feet Junk (measured) 13199' true vertical 7044 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 4069' 9-5/8" 4100' 3117' 5750 3090 Intermediate Production 13355' 7" 13385' 6882' 7240 5410 Liner 979' 5" 13241' - 14220' 6817' - 7323' 10140 10490 SCANNED APR 2 7 2007 Perforation Depth MD (ft): 13644' - 13760' Perforation Depth TVD (ft): 7016' - 7064' 2-718",6.5# L-80 13138' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): FB- 1 Packer 13200' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 Printed Name Sondra Stewman Title Technical Assistant ~ DatlJ}n -01 Prepared By Name/Number: . i~ ~.5:;:~:;:\ Phone 5M...-4750 Signa re % ç') ____ Sandra Stewman 564-4750 Form 10-404 Revised 04/2006 ~nl IIUI~ gr-t. APR . Submit Ori inal Onl ORIGINAl 2 6 2007 g y O.B Elev. = 53.25' (N 22E) ° L Elev. = 24.7' RT Tbg. Spool = 28.55' (N 22E) Tree: 29/16" - 5M FMC M PU E-10 Wellhead: 7 1/16" 5M FMC wI 27/8" WKM Tubing Hanger, wI 3" Acme Top X 27/8" 8rd Btm Thread, 2.5" CIW H BPV profile 13 3/8" 91.1 ppf, H-40 80' KOP @ 500' hole angle = 60-67 deg. fl 3,100' to 13,704' Hole angle thru' perfs = 57 deg 95/8", 40#/ft, L-80 Btrs. I 4100' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) Marker RA Tag 10' jt. 13,291' 13,301' 13,343' 13,386' 7" Landing collar 7" Seal float collar 7" Seal float shoe Peñoration SUmmary Ref loa: Scerrv EWR4 Size SPF Interval (TVD) Kup C sands 27/8' 6 13,644' - 13,684' 7006' - 7026' 3-3/8" 6 13,630'-13,694' Sqz'ed Kup B sands 3-3/8" 6 13,732' -13, 760' B/P Set, Sqz'ed DATE EV.BY COMMENTS 01/11/94 MEL CTU compo 01/15/95 JJM Initial Comp. Nabors 22E 12/27/00 MOO ESP RWO Remove Coil I Set BP 4-es 05/10/02 MJA Sqz off channeV Re-perfl change out ESP 3/24/07 L. Hulme ESP RWO wi 3S . w. ..... Camco 2 7/8" X 1" KBMM GLM I 167' I 8497' I Halliburton ES cementer Cameo 2-7/8" x 1" KBMM GLM 2-7/8" XN nipple 2.205" No-.Go ID XT-1 Pressure Head Pump 145P11, PMSSD11:1 Intake GPINTXAR Tandem Seal Section GSB-"DBUT S81~ PFSA GSR<DBL T SBiSB FSA CL5 Motor, 152 HP, 2325 volt, 40 amp, Model KMHG Phoenix XT-1 Sensor w/6 fin centralizer and Anode Sensor TVD 6771' 6 fin Centralizer lost in hole (dimensional drawing in well file) FB-1 Packer 5" selling sleeve C-2 (5.25" ID) Liner top pkr. HPLPO Liner hng. HMC 13,240' 13248' 13,253' Weatherford cast iron bridge plug Set 12/26/00 by 4-es. Baker landing collar Baker float collar 14,085' Baker float shoe 12.880' I 13.032' I 113,086' [ I 13.086' I I 13.103' I I 13,103' I I 13.117' I I 13.132' 13,199' 13,200' I 13,720' MILNE POINT UNIT WELL E-10 API NO: 50-029·22521 BP EXPLORATION (AK) . . BP EXPLORATION Operations Summary Report Legal Well Name: MPE-10 Common Well Name: MPE-10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 38 Date I From - To I Hours I Task Code I NPT .._~__,____ v.J__..,,¥__v_..._ __.____ 3/19/2007 06:00.. 12:00 I 6.00\ RIGD P 12:00 - 22:00 10.00 RIGU P 22:00 - 00:00 2.00 RIGU P 3/2012007 00:00 - 02:30 2.50 RIGU P 02:30 - 03:30 1.00 DHB P .03:30 . 05:30 2.00 KILL i 05:30 - 07:45 2.25 KILL P 07:45 - 09:00 1.25 KILL P I I j 09:00 - 10:00 1.00 KILL P 10:00 - 18:30 8.50 KILL P , 18:30 - 21 :00 2.50 DHB P 21 :00 - 00:00 3.00 WHSUR P 3/21/2007 I 00:00 - 07:00 I 07:00 - 09:00 I I I 7.00 I BOPSUF P 2.00 i BOPSUF P I I 09:00 . 17:45 8.75 BOPSUF P 17:45 - 18:45 1.00 PULL P 18:45 - 20:15 1.50 PULL P Page 1 of 4 Start: 3/19/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 4/29/2002 End: 3/27/2007 ¡ Phase i i Description of Operations -.---.-------..-.---..-..".-..---.------ R/D rig components. Wait on Peak Trucks. Scope down and UD Derrick. Move C/l unit out of the way. Move components 210' NW and begin to R/U, spotting rig over welf. Raise and Scope Derrick. Accept Rig @ 2300-hrs. R/U berming for Tiger Tank. R/U Hard Line from Tiger Tank to IA DECOMP R/U Lubricator to Tree. pun SPV wI Wells Support on hand. T/I/O = 201100/0 psi. UD lubricator. Install double Valve on IA. R/U to Tree to Circulate. PJSM. Une up Seawater Trucks to take on seawater to pits. P!T lines to 2500 psi. Begin Well Kill circulation by pumping tubing volume (77-Bbls) the long way:1-BPM, TP 330-psi, CP O-psi; 2-BPM, TP 450-psi CP O-psi; 3-BPM, TP 720-psi, CP O-psi; 4-BPM, TP 10oo-psi, CP 50-psi. Get 75-Bbls retums to Tiger Tank of mostly crude oil and diesel. DECOMP Bullhead down tubing 77-Bbls: 1-BPM, 7oo-psi; 1-1/2-BPM, B80-psi; 2-BPM, 1310-psi. DECOMP Reverse Circulate 626-Bb!s @ 3.5 BPM and 800 psi. Had to shut down to repair Mud Pump in mid circulation. Discharge on Mud Pump was packing off with scale. Shut down and monitor well. T/I/O = 20/vac/0 psi. Bullhead 45 Bbls down Tubing at 3 BPM and 1800 psi. Shut down and monitor well. TII/O = O/vac/O psi. Lost a total 01 190 Bbls to formation (including the bulheaded volume). Dry rod TWC in per FMC instruction. P!T TWC from below to 1000 psi for 10 minutes and chart. P!T TWC from above to 3500 psi from above for 10 minutes and chart. P!T from above had to be conducted several times. DECOMP I N/D Tree. Attempt to M/U FMC crossover. Crossover will not fit on WKM Hanger. M/U new 3·1/2" IF x 3" lH Acme crossover ¡with 9.5 turns. Tree had to be broken at 7-1/16' Flange instead lof the anticipated 13-5/8" Flange due to 4 LOS on the upper 17-1/16" Flange. Call Nabors Yard to have 7-1116" Spool brought to the Rig for BOP Stack. Functioned the 10 LDS on the 13-5/8' Flange which are for the Reducer Bowl and also functioned the 4 LOS on the 7-1116" Flange which are for the Tubing Hanger. DECOMP PJSM. N/U BOPE. Break Hard Line and move Tiger Tank to edge of location. MIRU Centrilift ESP Spooler. DECOMP Function test BOPE. Trouble shoot hydraulic lines to HCR. Cycle hydril to warm up element. Measure stack and prep for pressure testing. DECOMP Pressure test BOPE to 250 psi low 13500 psi high. Test annular to 3500 psi. State witness of testing waived by John Crisp. Troubleshoot leaking HCR. Confirm with town acceptability of 2500 # test on HCR only. DECOMP RIH wI Opso-Lopso and M/U to Hanger. M/U Lubricator per Wells Support recommendationS. Pull TWC. T/IIO=vac/vac/vac psi. UD Lubricator and Opso-Lopso. PUMU 3-1/2" IF DP wI 3-1/2" IF x 3' LHACME corssover on bottom. MJU to Hanger with 9.5 turns. Install TIW Valve, PRE PRE PRE PRE DECOMP i DECOMP DECOMP I DECOMP i ¡DECOMP I Printed: 4/26/2007 10:29:34 AM Legal Well Name: MPE-10 Common Well Name: MPE-10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date I From - To Hours Task ___~__'_M_ .___.._,.__._~_. _...._.~.__.~ . , 3/21/2007 20:15 - 22:15 22:15 - 00:00 3/22/2007 00:00 .. 08:30 08:30 - 12:00 I I ¡ I I 12:00.. 12:30 ¡ 12:30.. 00:00 3/23/2007 00:00 - 08:30 08:30 - 12:30 I 12:30 - 15:30 15:30 . 16:00 16:00 - 17:30 17:30 - 00:00 . . BP EXPLORATION Operations Summary Report Page 2 of 4 . Start: 3/19/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 4/29/2002 End: 3/27/2007 2.00 PULL 1.75 PULL Code I NPT Phase Description of Operations 1._______. __._______.____ ________._._.___.._.. ..----..--... -..-.--.--.-- P DECOMP PJSM R/U Shieve and Elephant Trunk. P DECOMP T/I/O = vac/vacl vac. BOLDS. Free Hanger and POH 3' and monitor well. Pull Hanger to Floor. P/U weight to free Hanger = 90k-lbs. Free P/U weight = 90k·lbs. Centrilift cut cable from bottom of Hanger. FiIIlA wI 20 Bbls of seawater. Well starts flowing out Tubing. RIH so Hanger is below Annular Preventer. ¡Close TIW Valve. Close Bag. Alert appropriate parties. Clean Floor and Cellar. Install gauge on Tubing and read 75 psi. 25 '¡gallons spilt on Floor within containment. 1 gallon spilt on Pad ,outside containment. FilllA w/additional13 Bbls. 33 Bbls in total to fluid pack IA. T/I/O = 75/vac/vac psi. DECOMP Clean Rig Floor. 15 Bbllhr loss to formation. Crew change. Safety meeting with both crews to discuss incident. RU to circulate and kill well. DECOMP WHP's of 75 psi on Tbg, 0 psi on IA (on vac), 0 psi on OA. PJSM to discuss plan forward and potential risks and appropriate responses. Circulate down TBG, returns from JA through choke @ following rates: 1 BPM 1110 psi, 2 BPM I 290 psi, 3 BPM I 660 psi, 3 1/2 BPM I 860 psi. Circulate 80 Bbls (Tbg vol of 77 Bls). close choke and Bullhead 60 Bbls into formation @ 3 BPM 1800 psi on Tbg, 1400 psi on IA. (RH vol of 22 Bls). Open choke and circulate additional 550 Bls @ 3 1/2 BPM, 980 psi. Surface to surface vol of 467 Bls. Losses of 41 Bls to formation during circulation kill. Total losses including BH vol of 101 Bls of 8.5 #/gal SW. DECOMP Observe well. Tbg IIA on vacuum. 0 psi on OA. Monitor for 30 minutes. Load hole with 6 Bls for consistent losses of 12 Bls-Hr. Continuous hole fill with charge pump. DECOMP PJSM. Break out and lay down Tbg hanger. POOH laying down 2 7/8" tubing with ESP completion. Joint #68 has a -0.75" hole mid joint. No noticable external corrosion on joints #1-125.13 Bbl/hr losses to formation. DECOMP POOH laying down 2 7/8" tubing with ESP completion. Joint #68 has a -0.75" hole mid joint. No noticable external corrosion on joints #1-280. 13 Bbl/hr losses to formation. DECOMP Notify AOGCC, (Chuck Scheve), of upcoming test on annular. Witness of test waived by Chuck. Cointinue POOH laying down 2 718" tubing. Losses consistent @ 13 Bbl/hr with continuous hole fill. DECOMP Recovered 413 jts 2 7/8" Tbg, 2 GLM Assy's, 1 XN Assy, 213 LaSalle Clamps, 4 protectolators, and 2 flat guards. All of components recovered. Losses @ 13 Bbl/hr. Break out and lay down ESP Assy. On Pump section, hole of 1/2 in diameter in housing of pump. RUNCMP Clean and clear rig floor. RUNCMP PUMU 2 7/8" tubing, TIW valve, with FMC test plug for 7 1/16" FMC split hanger and set. RUNCMP ,BOPE testing of Annular preventer, HCR choke to 250 psi low, 13500 psi high. Annular Preventer is leaking. Troubleshoot. i Hydril Bag Element must be changed out. Consult with town. Cali HES for RBP, Nabors Yard for spare Bag, and 7ES for Potato Masher. Pull FMC Test Plug. Continually fill hole. losses at 14 Bbls/hr. 8.50 I PULL I 3.50 PULL N N 0.50 PULL N 11.50 PULL IP I I . 8.50 I PULL P 4.00 PULL P 3.00 PULL P 0.50 WHSUR P 1.50 WHSUR N 6.50 I WHSUR N I Printed: 4/26/2007 10:29:34 AM . , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: , Date From - To .______1._._.___...__. 3/24/2007 00:00 - 00:15 00:15 - 01 :00 01 :00 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 10:00 10:00 - 10:30 10:30 - 00:00 3/25/2007 00:00 - 04: 15 04:15 - 04:45 04:45 - 06:00 06:00 " 06:30 06:30 - 09:00 09:00·10:30 10:30 - 12:30 12:30 -14:00 14:00 -18:30 18:30 - 00:00 I 3/26/2007 00:00 - 06:30 . . BP EXPLORATION Operations Summary Report Page 3 of 4 . ...i ....... . MPE-10 MPE-10 WORKOVER Start: 3/19/2007 NABORS ALASKA DRILLING I Rig Release: 3/27/2007 NABORS 3S Rig Number: Hours Tas~.J.~~.~:..LN~.~J,"~~:~_l Description of Operations____ 0.25 BOPSU~ N I RUNCMP Discuss Change in Scope. 0.75 BOPSUï N RUNCMP PUMU RSP per HES recommendations. 4.50 BOPSU N I¡ RUNCMP RIH wI RBPon 2-7/8" Tubing while picking up singles from the Pipe Shed. Continuously filling hole. 30 jts in hole @ 0315-hrs. . ! 40 @ 0400-hrs. 9 Bbl/hr loss to formation. 1.50 RUNCO~ ! RUNCMP Set RBP. P/U and S/O = 17k-lbs. Turn string 1 turn to the left 'I i Sit down on RBP. P/U to 22k-lbs (5k-lbs over normal PIU). Sit I down on RSP. Turn 1/4 turn to the left. P/U off RBP. RBP set i wi center of element @ 2,482' and t.oJ.n. @ 2,478. 0.50! RUNCO~ RUNCMP Test RSP to 500 psi and chart for 10 minutes 2.50 RUNC0!If'N RUNCMP POOH w/2 7/8" Tbg, standing back in Derrick. No losses of .L , SW during trip. 0.50 RUNCO! RUNCMP Stand back RBP retrieving head. Close blind rams. PJSM for changing element in annular preventer. 13.50 RUNCO N RUNCMP Nipple down riser and air boot Utilize 5" HWDP "potatoe masher' for removing bonnet on hydril. Remove damaged rubber element and replace with new one. As making up new rubber element, the Stack and wellhead rotate clockwise 12 inches. Call FMC. Find that the incorrect rubber element was being installed. FMC conducts passing PPPOT-IC to 500 psi. Successfully test metal to metal seal above ACME nut to 500 psi. Decision made to leave wellhead in its moved position. C/O rubber elements. RU bonnet and riser Assy. RUNCMP Function test Annular Preventer. Hydraulic oil leaking from bottom seal ring within bonnet Break bonnet, replace Seal Ring, M/U bonnet.. Body test Annular Preventer. Test Successful. N/U Riser and Boot. PUMU 2 7/8" tubing, TIW valve, with FMC test plug for 7 1/16" FMC split hanger and set RUNCMP BOPE test Annular Preventer and HCR Choke to 250 psi low and 3500 psi high. BOLD test joint. PUMU RBP retrieving head. RIH to retrieve RBP from 2483' PJSM to review procedures and risks to pulling RBP. MU TIW valve, PU and SO wt of 17K #'s. Set down on RBP @ 2479', PU 5K #'s over pull. SO, rotate 1 RH turn, hold torque and PU 5K #'s overpull. Unseat RBP. Fluid level drop to take 6 Bbls to fill. Continuous hole fill as monitor losses @ - 20 Bbl/hr. RBIH below setting depth, remove TlW valve, RU airslips. Flow check well. RUNCMP POOH wI HES 7" RBP with continuous hole fill. Losses @ -18 Bbllhr, Total losses of 37 Bls. RUNCMP BOLD RBP retrieving head. Lay down elephant trunk and prep for running ESP. Continuous hole fill with charge pump. RUNCMP PJSM. PUMU Centrilíft ESP BHA. Run ESP cable over shleve and connect to motor RUNCMP RIH wI ESP assembly. Clamps on first 9 joints above ESP, and every joint thereafter to surface. Continuous hole fill as RIH. Losses @ -13 Bbls/hr. Conduct Kick While Tripping Drill. Check conductivity every -2000' RIH. RUNCMP RIH wI ESP assembly. 4- protectolators, 2- flat guards, I Clamps on first 9 joints above ESP, and every other joint thereafter to surface. Continuous hole fill as RIH. Losses @ Spud Date: 4/29/2002 End: 3/27/2007 4.25 BOPSUF N 0,50 BOPSUF N I RUNCMP , 1.25 BOPSUfI N 0.50 BOPSUF N 2.50 BOPSUF N 1.50 BOPSUF N RUNCMP RUNCMP RUNCMP 2.00 I BOPSUF N 1.50, RUNCOt 4.501 RUNCOrp 5.50 [ RUNCT 6.50 RUNCOMP Printed: 4/26/2007 10:29:34 AM 01\ " 22:30 - 23:30 23:30 - 00:00 3/27/2007 00:00 - 00:30 00:30 - 04:151 04:15 - 09:30 09:30 -13:30 13:30 - 15:30 15:30·18:30 18:30 - 19:00 19:00-21:00 . . BP EXPLORATION Operations Summary Report Page 4 of 4 3.75 DHB I I P Legal Well Name: MPE-10 Common Well Name: MPE-10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S ____ ~:te ~~ro~ - To ~~~~_~l~:~k I Code I NPT 3/26/2007 00:00 - 06:30 6.50 RUNCOtp 06:30 - 10:00 3.50 RUNCO~P 1'°'°0 - ,0,00 10.00 I RUNcorl p 120:00 - 20:30 I 0.50 RUNCO 20:30 - 22:30 1 2.00 RUNCOMP I I 1.00 RUN Cor 0.50 RUNCO~P 0.50 RUNCot 5.25 BOPSUF P 4.00 WHSUR P 2.00 WHSUR P 3.00 WHSUR P 0.50 WHSUR P 2.00, WHSUR P i I I .. Spud Date: 4/29/2002 End: 3/27/2007 Start: 3/19/2007 Rig Release: 3/27/2007 Rig Number: , Phase I ! ~.._-~-_..._--_..__..._.._._._.__.-.----- RUNCMP 1_10 Bbls/hr. 130 in @ 0030-hrs. 190 in @ 0330-hrs. 210 in @ 0420-hrs, 246 joints in hole @ 0615-hrs. RUNCMP Make cable splice. Fill tubing with 6 Bbls of SW, flush pump with additonal10 Bbls SW, 1 BPM, 1880 psi. Continuous hole fill as make cable splice, check conductivity of cable after splice I OK. RUNCMP RIH wI ESP on 2 7/8" Tbg from pipe shed. LaSalle cable clamps on every other joint to surface. Continuous hole fill wI losses @ -12 Bbls/hr. Check conductivity of cable every 2000'. RUNCMP Pump 10 Bbls down Tubing in order to flush ESP. RUNCMP ! P/U Tubing Hanger and set in Mouse Hole; P/U 3" LH AMCE landing joint and makeup to hanger. P/U landing joint and hanger and makeup and torque up to string. Get proper orientation for penetrator. Spaceout for ESP cable splice to Lower Field-Attachable Power Connector. Cut Cable and send over Shieve. Make ESP cable splice to Lower Field-Attachable Power Connector. RIH and set Tubing Hanger wI TWC installed. P/U = 58k-lbs. SlO = 31k-lbs. RILDS. Drain fluid on top the Hanger. 218 LaSalle Clamps run. RUNCMP RIH and set Tubing Hanger wI TWC installed. P/U = 58k-lbs. S/O = 31k-lbs. RILDS. POH and UD Landing Joint. Drain fluid on top the Hanger. 218 LaSalle Clamps run. Une up to test TWC from above and below. Test TWC to 1oo0-psi from above for 10-minutes and chart. Test is good. POH and UD Landing Joint. Drain Stack. MIU Kill Line to IA. Test TWC from below by pumping down IA. Pressure dropped from 1000 psi to 250 psi in 2 minutes. No signs of leak at surface. N/D BOPE. Remove Reducer Spool and install Spacer Spool. NU tree in proper alignment. Pressure test tree and tbg head adaptor to 5000 psi. Normal up tree. Final check on ESP: phase to phase· 370 meg/ohms I phase to ground 5.0 ohms / 2834 psi and 155 deg F @ 13086' MD. PU lubricator to floor, clean and clear cellar and floor. MPU operations to freeze protect weU after move. Phase 3 in MPU, unable to get WeU Techs on location to Pull TWC and set BPV. Pre-tour safety meeting with night crew and held PJSM with Well Support Techs on pulling the TWC and setting the BPV. Discussed roles and hazards with each crew member. Check IA and OA pressures. both at 0 psi. Pull TWC with the Lubricator and Welt Support Techs. The Tubing is still on a vac. Lubricate in the BPV - OK. LD Lubricator. Secure the Cellar and Tree. Rig was released at 21 :00 hrs on 3/27/2007. I I , I I I RUNCMP RUNCMP POST POST POST POST POST POST POST Description of Operations Printed: 4/2612007 10:29:34 AM . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Ave. Suite 1 00 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-895'-- 1) 2) 3) 4) 5) 6) 7) 1 EDE MPU E - 1 0 Caliper Report 2-Nov-06 /0'1 -/¿¡3 :ti /4 D39 (Ú "'i {:' ..... Print Name: f!.J )/1-/--- C j, n~<,f¡ IA P (}ilQ h 1/1 k PiA Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: WEBSITE: )Vir~2.N.;'R~7',i10R\¡UJ(J.;OlV1 0'\00. POSAi'iC-2006\Z _ W ordlDìstributionl Transmittal. Sheetsl Transmit. OriginaLdoc I I I I I I I I I I I I I I I I I I - . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP Exploration (Alaska), Inc. November 2, 2006 7621 1 2.875" 6.5 lb. L-80 EUE 8RD Tubing Well: MPU E-10 Field: Milne Point state: Alaska API No.: 50-029-22521-00 Top Log Intvl1.: Surface Bot. Log Intv/1.: 13,077 Ft. (MD) Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This log is tied into the IIXN" Nipple @ 13,039' (Driller's Depth). This log was run to assess the condition of the 2.875" tubing with respect to corrosive and mechanical damages. The 2.875" tubing logged appears to be in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 82% in joint 68 at 2,164' (2,146' - 2,165' tubing patch prior to logging). The damage appears in the forms of general corrosion and isolated pitting. Wall penetrations in excess of 20% are recorded in 193 of the 420 joints logged. The deeper penetrations are recorded in the interval between joints 33 (1,040') and 200 (6,330'), as illustrated in the Body Region Analysis Page of this report. No significant areas of cross-sectional wall loss are recorded in the 2.875" tubing interval logged. Light deposits are recorded in a number of joints, with a recorded minimum 1.0. of 1.90" in joint 413 (13,063'). Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 82%) Jt. 68 @ Corrosion ( 71%) Jt. 134 @ Corrosion ( 71%) Jt. 100 @ Corrosion ( 67%) Jt. 58 @ Corrosion ( 66%) Jt. 92 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: 2,164 Ft. (MD) 4,232 Ft. (MD) 3,157 Ft. (MD) 1,840 Ft. (MD) 2,919 Ft. (MD) No significant areas of cross-sectional wall loss (> 14%) are recorded. MAXIMUM RECORDED 10 RESTRICTIONS: Deposits Deposits 13,063 Ft. (MD) 3,671 Ft. (MD) Minimum 1.0. = 1.90" Minimum I.D. = 2.19" Jt. Jt. 413 @ 116 @ No other significant I.D. restrictions are recorded. I Field Engineer: J. Halvorsen & K. Miller Analyst: M. Tahtouh Witness: J. Rea I coRECEIVED Diagncsti'( Ser\J¡ces,l Box 1.369, 77497 (28.1 01" 565-·9085 Prudhoe Bay Fjeld ()ffiCt? NOV 1 4 2006 'Cf"-{-143 ~ 149Z3J ~Oit & Gas Cons. Commission Anchorage I I I Well: Field: Company: Country: MPU E-lO Milne Point BP Exploration (Alaska), Inc. USA I Tubing: Nom.OD 2.875 ins Weight 6.5 f Grade & Thread L-80 EUE 8 RD I I Penetration ami Metal loss (% wall) penetration body metal loss body I 400 300 200 100 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I M 1 to 10% I o o I I Damage Configuration ( body ) 200 I 150 100 I 50 () I isolated general Hne fing hole / pass pittíng corrosion corrosion corrosion ible hole I o I I PDS Repo Overview ody Region Analysis Survey Date: Tool Type: Tool Size: No, of Fingers: Anal sl: Nom.ID 2.441 ins November 2, 2006 MFC 24 No. 40665 1.69 24 M. T antouh Nom, Upset 2.875 ins Upper len, 1.2 ins Lower len, 1.2 ins Damage Profile (% wall) penetration body o o metal loss body 50 100 GLM 1 GLM2 Bottom of Survey = 414 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 2.875 in (-10.5' - 13071.5') Well: Field: Company: Country: Survey Date: MPU E·lO Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 Approx. Tool Deviation Approx. Borehole Profile CLM 1 3 1575 3154 4726 Õ (¡j ~ ...Q 6301 ..... E LL ::J c: Z ..c: 1:: ..... Q. 'õ Q) 7876 0 CLM 2 50 Damage Profile ('Yo wall) I Tool Deviation (degrees) I Bottom of Survey = 414 I I 9452 11024 12602 13071 100 I I PDS REPORT JOINT TABU EET I Pipe: Body Wall: Upset Wall: Nominal!.D.: 2.875 in 6.5 ppf L-80 EUE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Coun try: Survey Date: MPU E-10 Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I Joint Jt. Depth PC'11 Pen. ["en, ;¡ Min. Damag e Profile No. (Ft.) 'I Body I.D. Comments (% wall) (Ins) (Ins.) ~ (Ins.) 0 50 100 .1 -11 I) 0.03 2.39 PUP Shallow Dittim¡:. Lt. Deoosits. .2 -7 I) 0.03 2.37 PUP Shallow Dittim¡:. Lt. Deoosits. 1 3 I) 0.03 16 2.36 Shallow nittinc. Lt. Denosits. 2 35 I) 0.ü3 1'i 2.38 Shallow nittinc. 3 66 I) 0.03 15 h 2.36 Shallow nittinc. 3.1 98 0 0.ü3 16 h 2.38 PUP Shallow nitting.. 3.2 108 I) 0 0 I) NJA GLM 1 (No Deviation) 3.3 114 I) 0.03 1 ) 2.33 PUP Lt. Denosits. 4 125 0 0.03 ^I) 2.38 ~ 5 156 I) 0.03 Ph 2.37 Shallow nittimL U. Deoosits. 6 188 0 0.02 2.39 7 219 0 0.02 2.39 8 251 0 0.03 15 1 2.37 Shallow nitting. 9 282 I) 0.03 13 1 2.37 10 314 I 0.02 2 2.38 11 345 I 0.07 2.38 Isolated nittinQ. 12 377 ( 0.05 2.40 Isolated oittinQ. 13 409 ( 0.05 2.38 Isolated DittinQ. 14 440 I) 0.04 2( 2.37 Isolated nittinc. 15 472 0 0.04 III 1 2.37 Shallow nittinc. 16 504 I) 0.03 H 1 2.36 Shallow nitting. 17 535 I) 0.03 2.37 Shallow nitting. 18 567 I) 0.03 2.38 Shallow nittinQ. 19 598 I) 0.05 2.39 Isolated oittim¡:. 20 630 I) 0.06 2.37 Isolated nittinO'. 21 661 I) 0.08 311 2.38 Corrosion. 22 693 I) 0.04 H1 l 2.37 Shallow corrosion. 23 724 I) 0.06 27 I 2.39 Isolated nitting. 24 756 I) 0.04 19 1 2.36 Shallow nitting. Lt. Denosits. 25 788 I) 0.07 I 4 2.38 Corrosion. 26 819 I) 0.08 I') 4 2.39 Isolated nitting. 27 851 I) 0.04 20 ,; 2.37 Isolated oittinCf. 28 882 0 0.02 1 1 2.35 29 914 0 0.03 16 T 2.37 Shallow corrosion. 30 946 ( 0.09 S 2.38 Corrosion. 31 976 1)( In 0.10 9 2.39 Corrosion. 32 1007 ( 0.08 2.40 Corrosion. 33 1038 ( 0.10 ( 2.39 Corrosion. 34 1070 U 0.11 2.37 Corrosion. 35 1102 I) 0.07 2.39 Corrosion. 36 1133 I) 0.07 3 2.38 Corrosion. 37 1165 I) 0.04 Iß j 2.38 Shallow nitting. 38 1196 U 0.08 3' -,i 2.37 Corrosion. 39 1228 0 0.11 51 {) 2.39 Corrosion. 40 1260 0 0.04 2.36 Shallow corrosion. 41 1291 k 0.13 2.38 Corrosion. 42 1323 0.04 2.36 Shallow oittin2. Lt. Deoosits. 43 1354 0.11 2.38 Corrosion. 44 1386 0 0.06 2 2.37 Corrosion. 45 1417 ( 0.06 2 (, 2.37 Isolated nitting. I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SH I Pipe: 2.875 In 6.5 ppf L·80 WE 8 RD Well: MPU E·lO Body Wall: 0.217 in Field: Milne Point I Upset Wall: 0.217 in Company: BP Exploration (Alaska), Inc. NomlnaII.D.: 2.441 in Country: USA Survey Date: November 2, 2006 I Joint Jt. Depth Pel Pen. Pen, ! IV\eL\1 Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 I 46 1449 IU17 0.10 9 2.39 Corrosion. Lt. DeDosits. 47 1480 oon 0.08 7 2.39 Corrosion. Lt. Denosits. 48 1512 ow) 0.12 7 2.39 Corrosion. 49 1544 0 0.04 10 2.40 Shallow corrosion. I 50 1575 0 0.08 37 -::: 2.37 Isolated nittin<>. 51 1607 0.12 55 n 2.39 Corrosion. 52 1639 1 0.10 47 ;f fffi Isolated nittin<>. 53 1670 I 0.10 (I Corrosion. 54 1702 0·17 0.12 HJ 2.36 Corrosion. U. Denosits. I 55 1733 0.06 '\ 4 2.38 Isolated nittinQ. 56 1765 OOIJ OJO " n 2.38 Corrosion. Lt. Denosits. 57 1796 0 0.08 I 37 4 2.38 Isolated nittin<>. U. Deoosits. 58 1828 U 0.15 67 IT 2.37 Corrosion. Lt. Denosits. I 59 1860 007 0.07 3£ "4 2.38 Corrosion. 60 1891 0 0.11 49 'i 2.37 Corrosion. 61 1923 0.11 'il (¡ 2.36 Corrosion. 62 1954 012~ II 2.39 Corrosion. Lt. Denosits. I 63 1986 0.10 I) 2.38 Corrosion. Lt. DeDoslts. 64 2017 O,OIJ 0.12 10 2.36 Corrosion. Lt. Deooslts. 65 2049 0 0.10 T 2.37 Isolated nittim¡:. Lt. Deoosits. 66 2080 011 0.13 59 ¡) 2.36 Corrosion. Lt. Denosits. I 67 2112 OiY; 0.11 4 10 2.40 Corrosion. Lt. Denosits. 68 2144 I 0.18 I q 2.41 Corrosion. U. Denosits. 69 2175 oon 0.10 ¿ 10 2.39 Corrosion. Lt. Deooslts. 70 2207 009 0.11 I 11 ').36 Corrosion. U. Deoosits. 71 2239 0.11 I) 2.38 Corrosion. U. Deooslts. I 72 2270 010 0.12 II 2.38 Corrosion. Lt. Deoosits. 73 2302 () 07 0.14 64 ¡) 2.34 Corrosion. L1. Denosits. 74 I 2333 o IH\ 0.14 1 ¡c) 2.36 Corrosion. L1. Denosits. 75 2365 0 0.09 ., 2.36 I ·tting:. I 76 2396 o Oq 0.11 I 2.36 I' Corrosion. U. Deoosits. 77 2428 010 0.12 ! 2.36 Corrosion. Lt. Deoosits. 78 2460 011 0.13 ¡-¡ 2.35 Corrosion. 79 2491 0 0.11 51 9 2.35 Corrosion. Lt. Deposits. I 80 2522 0,07 0.10 47 q 2.35 Corrosion. It. Denosits. 81 2553 I) 0.10 IH 9 2.36 Corrosion. L1. Denosits. 82 2585 n 17 0.13 Iq I) 2.39 Corrosion. Lt. Denoslts. 83 2617 1 0.11 2.37 Isolated nlttlnQ. 84 2648 ° .') 0.12 2.38 ~. Lt. DeDosits. I 85 2680 í 0.12 2.36 nittinQ. Lt. Deoosits. 86 2711 IH17 0.12 2.38 Corrosion. U. Deoosits. 87 2743 í 0.12 2.37 Isolated oittimr. 88 2774 1711 0.12 14 In 2.37 Line corrosion. I 89 2806 I) 0.08 35 h 2.36 Isolated nittinº. Lt. Denosits. 90 2837 0 0.10 1"1 2.35 Corrosion. Lt. Denosits. 91 2869 oon 0.13 10 2.33 Corrosion. Lt. DeDosits. 92 2901 O,O'i 0.14 I 2.34 Corrosion. Lt. Deoosits. I 93 2932 o.on 0.10 q 2.37 Corrosion. U. DeDosits. 94 2964 0.06 0.13 11 2.35 Corrosion. Lt. Denosits. 95 2996 0,09 0.12 53 I) 2.34 Corrosion. U. Denosits. I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaIID.: 2.875 in 6.5 ppf L-80 WE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E·l0 Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I I Joint Jt. Depth Pen. Pen. Pen, I,l! Min. Damage Prof ¡Ie No. (Ft.) !~;::(;I Body 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 v~O'\A UR6MDB \AriWDf 0.11 13 c:; 2.36 Corrosion. 97 3059 0 0.08 jß " I 2.38 Isolated nittinO'. 98 3090 o Of, 0.12 16 I> 2.33 Corrosion. Lt. Denosits. 99 3122 0 0.12 ¡ 7 2.37 Corrosion. Lt. Deoosits. 100 3154 00 0.15 I 2.37 Corrosion. U. Deoosi ts. 101 3185 00 0.12 1 ~ Corrosion. Lt Deoosits. 102 3217 0 0.12 Ii Corrosion. Lt. Denosits. 103 3248 0 '5 gti 56 Corrosion. Lt. Deoosi ts. 104 3280 o OC¡ 1) 2.34 Corrosion. Lt. Denosi ts. 105 3310 01 I 0.12 54 I) 2.36 Corrosion. Lt. Denosi ts. 106 3342 o Oq 0.12 '111 q 2.36 Corrosion. Lt. Deoosits. 107 3374 0 0.06 I 2.31 Isolated oittinQ. Lt. Deoosits. 108 3405 o I [) 0.13 10 2.33 Corrosion. Lt. Deoosits. 109 3435 o on 0.08 n 2.37 Corrosion. Lt. Denosits. 110 3467 011 0.12 P 2.33 Corrosion. Lt. Deoosits. 111 3499 ~ 0.12 10 2.35 Corrosion. Lt. Deoosits. 112 3530 0.09 12 iT 2.38 Corrosion. Lt. Denosits. 113 1';62 0.12 i4 II 2.38 Corrosion. Lt. Denosits. 114 3593 0 0.09 41 .1 2.38 Isolated nittinQ. 115 3625 007 0.09 7 2.32 Corrosion. Lt. Deoosits. 116 3657 I )í)(, 0.12 1(, 2.19 Corrosion. Deoosits. 117 3688 0,07 0.12 I) 2.36 Corrosion. Lt. Deoosits. 118 3718 Oil 0.10 10 2.35 Corrosion. Lt. Denosits. 119 3750 012 0.11 '53 14 2.36 Corrosion. Lt. Deoosits. 120 3782 0 0.13 60 14 2.31 Corrosion. Lt. Deoosits. 121 3813 0 0.10 ¿ n 2.35 Corrosion. Lt. Denosits. 122 3845 0 0.11 ¡ 2.34 Isolated nittinQ. Lt. Deoosits. 123 3876 0 0.13 ¡ 2.33 Corrosion. Lt. Deoosits. 124 3908 0 0.10 2.36 Isolated oittim:!. Lt. Deoosits. 125 3940 oon 0.12 I 2.35 Corrosion. Lt. DeDosits. 126 3971 oon 0.11 I 11 I 2.33 Corrosion. Lt. Denosits. 127 4003 oon 0.10 47 11 2.36 Corrosion. Lt. Denosits. 128 4034 0 0.11 ¿ 7 h 2.37 Isolated nittinQ. Lt. Deoosits. 129 4066 01 D 0.12 10 2.34 Corrosion. Lt. Deoosits. 130 4096 0 0.12 7 2.37 Corrosion. 131 4128 ooc¡ 0.11 c¡ 2.39 Corrosion. Lt. Deoosits. 132 4160 0 0.10 f, 2.36 Isolated oittinQ. Lt. Deoosits. 133 4191 0.09 0.11 II! 2.37 Corrosion. Lt. Deoosits. 134 4223 0,09 0.15 II 2.36 Corrosion. Lt. Denosits. 135 4254 D.Oe 0.12 56 1-,::! 2.36 Corrosion. Lt. DeDosits. 136 4286 0,09 0.12 5'5 14 2.39 Corrosion. Lt. Deoosits. 137 4318 0 0.09 61 it 2.34 Isolated nittinQ. Lt. Deoosits. 138 4349 I 0.12 \) 2.36 Corrosion. 139 4381 I 0.06 4 2.35 Corrosion. Lt. Deoosits. 140 4412 00(, 0.10 )0 2.36 Corrosion. Lt. Deoosits. 141 4444 ! 0.07 1 2.34 Isolated oittinQ. H2 4475 ° 0.05 )1 2.37 Isolated nittin<>. 143 4507 0.09 0.13 60 11 2.39 Corrosion. Lt. Deoosits. 144 4537 o en 0.12 '16 14 2.39 Corrosion. Lt. Deoosits. 145 4569 007 0.12 57 L2 2.37 Corrosion. Lt. Deoosits. 130LOl DIIMd I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf 1.-80 EUE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E-lO Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I Joint )t. Depth Pel 1 Pen. Pen ¡Vle\;11 Min. Damage Prof He No. (Ft.) Body !.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 146 4600 0.10 47 7 2.38 Corrosion. 147 4632 0.12 10 2.39 Corrosion. 148 4663 0.11 '; 2.35 Corrosion. U. Deoosits. 149 4694 0.07 2.35 Isolated oittino. U. Deoosits. 150 4726 ( 0.10 2.37 Isolated Dittim2:. Lt. Deoosits. 151 4758 0 0.14 ( 2.38 Corrosion. 152 4789 0 0.12 2.37 Isolated oitting. L1. Deoosits. 153 4821 0 0.05 4 2.33 Corrosion. L1. Deoosits. 154 4852 010 0.14 65 2.35 Corrosion. L1. Deoosits. 155 4884 01 n 0.13 59 2.36 Corrosion. L1. Deoosits. 156 4914 ° \7 0.13 5ß 9 2.37 Corrosion. L1. Deoosi 15. 157 4945 0.11 6 2.33 Isolated oittim~. 158 4977 O. \7 0.12 9 2.30 Corrosion. L1. DeDosits. 159 5008 0.10 2.36 Isolated Ditting. 160 5040 ° 0.12 2.34 Corrosion. 161 5071 o Of{ 0.12 10 2.34 Corrosion. Lt. Deoosits. 162 5103 ° 07 0.11 52 r 2.34 Corrosion. L1. Deoosits. 163 5134 ° 0.12 'i3 ( 2.36 Corrosion. L1. Deoosits. 164 5166 ° 0.08 :9 4 2.35 Isolated Dittin2. L1. Deoosi15. 165 5198 0.07 0.14 ( a 2.34 Corrosion. L1. Deoosits. 166 5229 ° 0.07 2.30 Isolated oittíng. 167 5261 n03 0.12 2.34 Corrosion. L1. Deoosits. 168 5292 ° 0.05 2.34 Isolated pitting. 169 5324 \ 0.04 21 2.33 Corrosion. Lt. Deoosits. 170 5355 \ 0.06 29 2.34 Isolated oitting. Lt. Deoosits. 171 5387 \ 0.07 31 4 2.34 Isolated pitting. L1. Deoosits. 172 5418 ( 0.09 11 6 2.34 Corrosion. Lt. Deoosits. 173 5450 0 0.05 14 4 2.33 Isolated oitting. 174 5481 0 0.04 1 '¡ 2.33 Isolated oittim2:. L1. Deoosits. 175 5513 0,06 0.12 54 2.36 Corrosion. Lt. Deoosits. 176 5545 ( 0.07 31 4 2.36 Isolated pitting. 177 5576 0(1'') 0.11 57 \0 2.34 Corrosion. Lt. Deoosi15. 178 5608 0(1(\ 0.12 '16 B 2.29 Corrosion. Lt. Deoosi15. 179 5639 0.09 4 2.35 Isolated oiWng. Lt. Deoosits. 180 5671 0.06 2.36 Isolated oittin2. 181 5702 O.OB 0.12 2.37 Corrosion. Lt. Deposits. 182 5734 0.07 0.12 2.36 Corrosion. L1. Deoosits. 183 5765 ° 0.04 2.35 Shallow pitting. Lt. Deposits. 184 5797 0 0.08 2.35 Corrosion. Lt. Deoosits. 185 5828 0 0.07 3i 2.35 Corrosion. 186 5860 0,07 0.12 53 I 2.38 Corrosion. Lt. Deoosits. 187 5891 ° 0.05 4 2.33 Isolated pitting. Lt. Deoosits. 188 5923 ° 0.13 , 2.29 Corrosion. 189 5954 ° 0.04 2.36 Shallow corrosion. 190 5986 ° 0.08 2.34 Isolated pitting. 191 6017 ° 05 0.11 2.35 Corrosion. Lt. Deoosits. 192 6049 ( 0.09 4 2.35 Corrosion. 193 6080 ( 0.14 5 2.36 Corrosion. 194 6112 ( 0.04 9 2.35 Corrosion. 195 6143 O,OB 0.11 6 2.36 Corrosion. U. Deposi ts. I I I I I I I I I I I I I Body Metal Loss Body Page 4 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaIID.: 2.875 in 6.5 ppf L-80 WE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E·1O Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I I Joint Jt. Depth Pell Pen. Perl, \¡tetal Min. Damag e Profile No. (Ft.) \~:;:e: Body I !.D. Comments (% wall) (Ins.) (Ins.) 0 50 100 196 6175 n 17 0.09 4 (I 2~ Corrosion. Lt. Deoosits. 197 6207 0.03 2.35 Shallow corrosion. 198 h')'H, 0.05 2.35 Isolated nittinQ. U. Denosits. 199 6270 i 0.12 1 2.31 Corrosion. Lt. Deoosits. 200 6301 0 )9 0.09 I 2.36 Corrosion. Lt. DeDosits. 201 6333 0 0.05 2.35 Isolated nittim:!. Lt. Deoosits. 202 6364 0 0.05 24 ' ! 2.35 Isolated nittina. U.Denosits. 203 6396 0 0.07 32 2.37 Corrosion. LL Denosits. 204 6428 0 0.03 16 In 2.39 Shallow nitting. 205 6459 n 0.04 2.34 Isolated nittina. Lt Denosits. 206 6490 0.04 2.39 Shallow oittinQ. 207 6521 0.06 2.35 Corrosion. LL Denosits. 208 6553 0.06 2.36 Isolated nittiml. 209 6585 0.04 2.36 Shallow corrosion. 210 6616 0 0.07 I 2.37 Corrosion. Lt DeDosits. 211 6648 0 0.06 2.39 Isolated nittino. 212 6679 0 0.04 20 r, 2.37 Isolated nittina. 213 6711 n 0.06 ;> 2.37 Isolated nitting. Lt. Denosits. 214 6742 n 0.03 1 2.35 215 6774 n 0.03 II 2.38 Shallow nittínQ. 216 6806 n 0.06 2 2.37 Isolated nittim!. Lt. DeDosits. 217 6837 0 0.04 19 I "'1 2.32 Shallow nittina. Lt. DeDosits. 218 6869 n 0.03 I :.[ 2.34 Shallow corrosion. 219 6900 0 0.04 "I 2.33 Shallow nittinQ. 220 6932 0.05 " 2.35 Isolated nittinQ. Lt. Deoosits. 221 6962 1 0.03 ') 2.37 Shallow nittinQ. 222 6994 0.03 11 2.37 Shallow nittinQ. 223 7025 1 0.03 10 2.39 I 224 7057 0 0.04 2.37 Shallow nittim!. 225 7089 0 0.03 1 2.33 Lt. DeDosits. 226 7120 0 0.06 21 2.36 Isolated nittino. Lt. DeDosits. 227 7152 0 0.06 27 ;:¡ 2.37 Corrosion. Lt. Denosits. 228 7183 n 0.03 14 2.38 Lt. Denosi ts. 229 7215 n 0.03 14 2.38 230 7247 n 0.05 ! 1 2.33 Corrosion. Lt. Denosits. 231 7278 0 0.04 10 2.37 Isolated DittinQl. 232 7310 0 0.03 3 2.35 233 7341 0 0.04 h 2.37 Shallow oittinQl. Lt. Deoosits. 234 7373 0.03 ;; 2.36 Shallow nittina. 235 7404 0.03 1 ') 2.39 Lt. Denosits. 236 7436 0.03 I I 2.35 237 7467 0.03 I 4 2.35 Shallow nittinQ. I 238 7499 0.03 1 2.35 Shallow nittinQ. Lt. Deoosi ts. 239 7531 0 0.02 I Ii 2.38 U. Deoosits. 240 7562 01 0.05 2 2.34 Isolated nittim:!. Lt. Deoosits. 241 7594 n 0.03 14 2.31 Shallow nitting. 242 7625 n 0.02 I I 2.35 243 7656 n 0.03 I 4 2.36 244 7688 I) 0.03 1 q 2.38 245 7719 0 0.02 11 I 2.36 I I I I I I I I I I I I Penetration Body Metal Loss Body Page 5 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal I.D.: 2.875 in 6.5 ppf L·80 EUE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E-lO Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I Joint Jt Depth Pen Pen. Pen, (Vier: Min. Damage P rofile No. (Ft.) \~:::(;I Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 246 7751 0 0.05 2 2.36 Corrosion. 247 7783 0 0.03 I 2.38 248 7814 0 0.03 I 2~ 249 7845 0 0.03 1 II 2. Shallow corrosion. 250 7876 {' 0.02 11 4 2. ,j 251 7908 0 0.03 13 ;; 2.39 252 7940 0 0.03 15 ) 2.38 Shallow nittinQ. 253 7971 0 I 004 2 f 2.36 Corrosion. 254 8003 0 0.03 I 'j 2.34 " 255 8035 0 0.04 1 4 2.39 Shallow niHing. 256 8066 0 0.02 11 : 2.38 Lt. Denosits. 257 8098 0 0.02 I 1 2.35 Lt Denosits. 258 8129 0 0.03 15 11 2.36 Shallow corrosion. Lt. Denosits. 259 ±1}61 0 0.03 12 2.37 21)0 93 0 0.03 Jj 2.37 261 8224 0 0.02 2.38 262 8256 0 0.03 2.36 263 8287 0 0.02 2.38 264 8319 0.03 2.39 Shallow nittina. 265 8351 0.03 I 2.38 Lt. Denosits. 266 8382 0 0.03 14 r, 2.39 267 8414 0.03 1 I 2.36 Lt. Denosits. 268 8445 ( 0.03 I 2.36 269 8477 ( 0.03 1 ( 2.38 270 8509 ( 0.03 I 2.37 L t. Deaosi ts. 271 8540 0 0.02 ; 2.38 272 8572 0 0.02 I 2.33 Lt. Denosits. 273 8601 I 0.03 15 -iT 2.38 Shallow corrosion. 274 8633 ( 0.03 I ';:¡ 2.36 Shallow nittirw. 275 8665 0.04 1 7' 2.38 Shallow corrosion. 276 8696 0.04 2.37 Shallowaitiing. 277 8728 0.06 2.35 Isolated nitting. 278 8759 0.04 2.38 Shallow nitting. 279 8791 (J 0.03 ? 19 280 8823 0 0.04 I 2.38 Shallow nittin12. 281 8854 0 0.03 16 r: 2.35 Shallow corrosion. 282 8886 0 0.04 I '{ 2.34 Shallow nitting. Lt. Denosi ts. 283 8917 0 0.03 H 4 2.37 Shallow corrosion. 284 8949 0 0.03 I 2.35 Shallow nitting. Lt. Denosits. 285 8980 0 0.04 2 2.34 Isolated oittin12. Lt. Deoosits. 286 9012 0 0.06 2 2.37 Isolated oittin12. 287 9044 0 0.04 I ! 2.31 Shallow corrosion. U. Deoosits. 288 9075 0 0.04 111 2.31 Shallow corrosion. Lt. Denosits. 289 9107 0 0.02 10 2 2.36 290 9136 0 0.03 2.37 291 9168 0 0.02 2.35 292 9199 Ii 0.04 2.34 Shallow corrosion. Lt. Deoosits. 293 9231 0 0.03 2.37 Shallow oittim!. 294 9262 0 0.04 I 2.37 Shallow nittino. 295 9294 Ii 0.04 16 11 2.38 Shallow corrosion. I I I I I I I I II I I I I Body Metal Loss Body Page 6 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaIID.: 2.875 in 6.5 ppf L-80 EUE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E-lO Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I I Joint Jt. Depth Pell Pen. Pen, ! '\lleldl Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (Ins (Ins.) (Ins.) 0 50 100 296 9326 n 0.05 ) ] 2.36 Isolated nittina. Lt. Denosits. 297 9357 n 0.03 1 2.34 Lt. Denosi ts. 298 9389 n 0.03 I 2.38 Shallow corrosion. 2qq 9420 {) 0.04 I 2.3æallow corrosion. Lt. Denosi ts. 300 9452 0 0.02 ., 2.3 301 9482 i~= 0.02 I 2.38 It. Denosits. 302 9514 0.02 fn 2.35 I t. Denosi ts. 303 9545 1i1.02 -C) 2.37 304 9577 0 0.04 I ] 2.36 Shallow corrosion. U. Denosits. 305 9608 0 0.04 I 2.36 Shallow nittina. 306 9640 0 0.03 1 2.38 307 9671 n 0.03 1 2.36~OW nittirw. 308 9703 0 ~ 1 2.37 allow nitting. It. Denosits. 309 9734 íJ 11 I 2.36 Shallow nittina. 310 9766 n 0.02 10 J 2.36 311 9797 0 0.04 ¡q n 2.34 Shallow nittina. U. Denosits. 312 9829 n 0.03 14 7 2.37 Shallow nittina. 313 9861 0 0.02 2.38 314 9892 n 0.D2 II 2.37 315 9924 n 0.03 14 I 2.36 Shallow nittíng. 316 9956 n 0.03 1(1 2.34 Shallow nittina. 317 9987 n 0.03 I (¡ 'J 2.38 Shallow corrosion. 318 10019 n 0.04 16 :> 2.32 Shallow nittina. Lt. Denosits. 319 10050 n O.n? 9 2.37 320 10082 0 0.03 d 2.38 321 10113 n 0.02 2.38 I t. Denosi ts. 322 10145 n 0.02 2.38 323 10176 (I 0.02 1 2.37 324 10208 n 0.03 I 11 2.39 325 10239 n 0.02 'I 1 2.36 326 10271 I) 0.03 2.36 Shallow nittina. Lt Denosits. II 327 10303 n 0.03 C 2.39 Shallow corrosion. 328 10334 0 0.04 2.37 Shallow nittino. ill 329 10366 0 0.02 2.40 330 10398 C1 0.02 1 2.37 331 10429 0.01 2.38 332 10461 0.03 1 ,; 6 2.38 Shallow corrosion. 333 10493 1 0.03 I') 2 2.38 334 10524 ( 0.02 n 1 2.38 335 10556 I 0.01 2.37 I 336 10588 1 0.04 2.34 Shallow nittin<>. Lt. Denosits. 337 10618 0 0.03 2.36 Shallow nitting. 338 10649 0 0.04 2.36 Shallow corrosion. 339 10680 0 0.03 11 (' 2.36 340 10712 I) 0.03 I 2.40 341 10744 I) 0.03 2.31 Shallow nittin<>. Lt. Denosits. 342 10775 0 0.03 2.35 Shallow nittin<>. 343 10806 I 0.03 2.35 1; 344 10837 0 0.04 2.34 Shallow nitting. Lt. Denosits. 345 10868 0 0.04 IIi .1. 2.36 Shallow corrosion. U. Denosits. I I I I I I I I I I I I Body Metal loss Body Page 7 I I I I PDS REPORT JOINT TABU ONSH I Pipe: Body Wall: Upset Wall: NominaIID.: 2.875 in 6.5 ppf L-80 WE 8 RD 0.217 in 0.217 in 2.441 in Well: Eield: Company: Country: Survey Date: MPU E-lO Milne Point SP Exploration (Alaska), Ine. USA November 2, 2006 I Joint Jt. Depth Pet: Pen. Pen \¡Ielal Min. Damage Profile No. (Et.) Body I.D. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 346 10898 0.04 ,7 I) 2.39 Shallow corrosion. 347 10930 0.03 4 2.32 Shallow corrosion. Lt. De.....osits. 348 10961 0.04 (, 2.34 Shallow corrosion. Lt. De.....osits. 34"¡O993 0.Q3 2.36 Shallow.....ittin". Lt. De.....osits. 350 1024 0 0.03 2.35 Shallow nittin"'. 351 1056 () 0.02 2.36 352 11087 0 0.04 -1 2.34 Shallow.....iHin". 353 11119 0 0.04 1 2.33 Shallow.....inina. Lt. De.....osits. 354 11150 0 0.04 I 2 2.34 Shallow corrosion. 355 11182 0 0.04 2.36 Shallow corrosion. 356 11213 0 0.03 2.37 Lt. De.....osits. 357 11245 0 0.03 2.37 358 11276 0 0.04 2.34 Shallow corrosion. 359 11308 0 0.04 2.33 Shallow niHin"'. Lt. Denosits. 360 11340 0 0.03 1\ r¡ 2.38 361 11371 0 0.Q3 15 'j 2.38 362 11403 0.03 'I ) 2.36 Shallow.....inina. Lt. De.....osits. 363 11435 0.03 l' ; U 2.39 Shallow .....iHina. if.4 11466 0 0.03 1 2.36 365 11498 0 0.04 1" 2.33 Shallow ninin". 366 11530 0 0.03 I 2.36 367 11 561 0 0.ü2 1(1 I 2.36 368 11593 0 0.02 f I) 2.37 369 11624 0 0.04 1\ 3 2.34 Shallow corrosion. Lt. Deoosits. 370 11656 0 0.04 4 2.37 Shallow.....inin". 371 11 688 0 0.03 n 2.37 Shallow niHin". 372 11719 0 0.03 (, 2.36 Shallow corrosion. 373 11751 0 0.Q3 (, 2.33 374 11782 0 0.04 'I. 2.36 Shallow corrosion. 375 11814 0 0.02 10 4 2.33 376 11 844 0 0.01 i; II 2.36 377 11876 0 0.03 )4 ¡ 2.38 378 11908 0 0.02 i 1 i 2.37 379 11939 (I 0.04 17 2.38 Shallow nittin"'. 380 11971 (I 0.04 In 2.38 Shallow corrosion. 381 12003 (I 0.01 ;f 2.35 382 12033 0.03 4 2.33 Shallow.....ittin". Lt. Denosits. 383 12065 0.03 ,4 n 2.38 Shallow nininl:!. 384 12096 0.04 1 14 2.38 Shallow corrosion. 385 12128 ( 0.03 I L 2.37 Shallow ninin". 386 12160 ( 0.03 1 2.34 Shallow nittin". Lt. Dennsits. 387 12191 0 0.04 I 2.36 Shallow nittin"'. Lt. Denosits. 388 12223 0 0.04 I 2.29 Shallow corrosion. Lt. Denosits. 389 12254 I) 0.03 1 2.31 L t. Deoosi ts. 390 12286 (I 0.03 1 11 2.35 Shallow niHinQ. Lt Denosits. 391 12318 ( 0.04 17 7 2.35 Shallow corrosion. 392 12350 I I 0.03 1\ 4 2.35 Shallow.....ittina. Lt. Denosits. 393 12381 ( 0.03 1 2 2.33 394 12413 ( 0.03 1i h 2.34 Shallow.....iHin". Lt. Denosits. 395 12444 ( 0.03 1 4 2.32 Lt. Deoosi ts. I I I I I I I I I I I I I Body Metal Loss Body Page 8 I I I PDS REPORT JOINT TABULATION S I Pipe: Body Wall: Upset Wall: NominaIID.: 2.875 in 6.5 ppf L-80 EUE 8 RD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: MPU E·l0 Milne Point BP Exploration (Alaska), Inc. USA November 2, 2006 I I Joint Jt. Depth Pen Pen. Pen, Ilv''!e!al Min. Damage Profile No. (Ft.) Body 1.1). Comments (%wall) .) (Ins.) (Ins.) 0 50 100 396 12476 n 0.04 1 (j 2.33 Shallow corrosion. 397 12507 n 002 2.38 398 12539 n 0.04 ! 2.36 Shallow nittinQ. 399 12571 n 0.03 2.35 Shallow nittinQ. 400 12602 n 0.02 2.35 401 121!f n 0.03 2.32 Lt. Deoosits. 402 1266 0 0.03 1 2.33 Shallow nittin<>. U. Denosits. 403 126 n 0.03 1 2.36 404 12729 II 0.04 1 \ 2.33 Shallow nittinll. 405 12761 II 0.03 Í\ 2.32 U. Denosits. 406 12791 0 0.03 2.33 407 12823 0 0.03 2.31 Shallow nittinlI. Lt. Deoosits. 408 12855 () 0.02 í 2.35 Lt. Denosits. 4081 I 12886 I) 0.02 2.31 PUP LL Denosits. 408.2 12894 0 0 0 ¡¡ N/A GLM 2 (Latch @ 4:30) 408.3 12905 0 0.02 1 1 2.34 PUP U. Denosits. I. 409 12913 II 0.03 13 n 2.35 410 12944 n 0.03 Ib j 2.31 Shallow nitting. Lt. Denosits. 411 12975 0 0.04 19 {, 2.34 Shallow corrosion. U. Denosits. 412 13007 0 0.04 19 2.33 Shallow nittinQ. Lt. Denosits. 412.1 13039 0 0 I t 2.21 XN NIPPLE 413 13041 0 0.07 35 1.90 Isolated oittinQ. Deoosits. 414 13071 0 0.03 15 2.29 Shallow nittin<>. Lt. Denosits. I I I I I I I I I I I I I Page 9 I I ....-..-- --.......... .. .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : MPU E·lO Milne Point BP Fxploration (Alaska), Inc. USA 2.875 ins 6.5 f L·80 EUE 8 RD SUlvey Date: Tool Type: Tool Size: ,"10. of Fingers: Anal st: ,"Iovember 2, 2006 MFC 24 No. 40665 1,69 24 M, Tahtouh Cross Section for Joint 68 at depth 2163.71 ft Tool speed = 46 Nominal 10 = 2.441 Nominal 00 = 2,875 Remaining wall area = 88 % Tool deviation = 44 0 Finger 2 Penetration 0.178 ins Corrosion 0,18 ins = 82% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. ----.... Well: Field: Company: Country: Tubin : --..-...... .. .. PDS Report Cross Secti ns MPU E·1Q Milne Point BP ['<ploration (Alaska), Ine. USA 2.875 ins 6.5 f L·80 LUE 8 RD :\lovember 2, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: Cross Section for Joint 134 at depth 4231.943 ft Tool speed = 48 Nominal 10 = 2.441 Nominal 00 = 2,875 Remaining wall area = 88 % Tool deviation = 880 Finger 9 Penetration 0,154 ins Corrosion 0,15 ins = 71 % Penetration HIGH SIDE = UP Cross Sections page 2 - - .. .. ............ Well: Field: Company: Country: Tubin : .............. ...... .. .. .. S Report Cross Sections MPU [·10 Milne Point BP Exploration (Alaska), Inc. USA 2.875 ins 6.5 f L·80 [UE 8 RD Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: November 2, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh Cross Section for Joint 100 at depth 3156.61 7 ft Tool speed = 54 NominallD = 2.441 Nominal OD = 2,875 Remaining wall area = 90 % Tool deviation = 72 0 Finger 8 Penetration = 0.153 ins Corrosion 0,15 ins = 71 % Penetration HIGH SIDE = UP Cross Sections page 3 ------ Well: Field: Company: Country: Tubin : ------- - - -- .. - PDS Report Cross Sections MPU E-l0 Milne Point BP Exploration (Alaska), Inc. USA 2,875 ins 6,5 f L-80 EUE 8 RD November 2, 2006 MFC 24 No, 40665 1.69 24 M. Tahtouh Survey Date: Tool Type: Tool Size: ,No, of Fingers: Anal st: Cross Section for Joint 413 at depth 13063.35 ft Tool speed = 41 ¡NominallD = 2.441 Nominal OD = 2.875 Remaining wall area = 97 % Tool deviation = 94 0 Finger 21 Projection -0.449 ins Deposits Minimum I.D, = 1.90 ins HIGH SIDE =UP Cross Sections page 4 I I I KOP @ 500' hole angle = 60-67 deg. fl 3,100' to 13,704' Hole angle thru' perfs = 57 deg I I 9 5/8", 40#/ft, L-80 Btrs. I 4100' I I 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) I I I I I Marker RA Tag 10' it. 13,291' 13,301' 13,343' I 7" Landing collar 7" Seill nOHI CUllHI 7" Seal float shoe 13,386' I Perforation Summary Ref log: Sperry EWR4 I Size SPF Interval (TVD) Kup C sands 27/8" 6 13,644' - 13,684' 7006' - 7026' 3-3/8" 6 13,630'-13,694' Sqz'ed Kup B sands 3-3/8' 6 13,732'-13,760' BIP Set, Sqz'ed I DAlE .BY COMMENTS 01/15/95 JJM Initial Comp. Nabors 22E 01/11/94 MEl CTU compo 12/27/00 MOO ESP RWO Remove Coil I Set BP 4-es 05/10102 MJA Sqz off channell Re-perfl change out ESP I I I o B Elev. = 53.25' (N 22E) o L Elev. = 24.7' RT Tbg. Spool = 28.55' (N 22E) Cameo 2 7/8" xi" sidepocket KBMM GlM I 8497' I Halliburton ES cementer Cameo 2-718" x I" side po<:ket KBMM GLM 2-7/fr xn nipple 2,205" 10 Discharge Head GPDIS 1599"9" GCI150, GPMTARM 1:2 INtake GPINTXAR Tandem Seal Section GSB3DBUTILHGPFSHSNAJB GSB3DBL TH6HSN NB CL-5 Motor, 152 HP, 2325 vall, 40 amp, Model KMHG Pump Mate w/6 fin Centralizer 6 fin Centralizer lost in hole (dimensional drawing in well file) FB-1 Packer S" setting sleeve C-2 (5.25" ID ) liner lop pl<r. HPLPÓ Liner hng, HMC 13,240' 13248' 13,253' Tree: 29/16" - 5M FM MPU E 1 0 Wellhead: 7 1/16" 5M FMC - wI 2 718" WKM Tubing Hanger, wI 3" Acme Top X 27/8" 8rd Btm Thread 2.5" CIW H BPV profile 13 3/8" 91.1 ppf, H-40 80' Weatherford cast iron bridge plug Set 12/26/00 by 4-es. Baker landing eollar Baker float collar 14,085' 14,173' 14,220' Baker float shoe MILNE POINT UNIT WELL E-10 API NO: 50-029-22521 I 138' 12,890' 13,039' 113,081' 13,082' 13,101' 13,114' 13,132' 13,199' 13,200' I 13,720' I BP EXPLORATION (AK) . STATE OF ALASKA a ALAS Oil AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONSi\!,¡¡ska o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 3 490 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG # 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 54 KB 8. Property Designation: ADLO-028231 11. Present Well Condition Summary: Total Depth measured 14225 feet true vertical 7326.51 feet Effective Depth measured 14084 feet true vertical 7241 feet Casing Length Size MD Conductor 80' 20" 91.1# H-40 32' - 112' Surface 4069' 9-5/8" 40# L-80 31' - 4100' Intermediate 13555' 7" 26# L-80 30' - 13385' Liner 979' 5" 15# 13cr80 13241 ' - 14220' Perforation depth: Measured depth: 13630 - 13694 True Vertical depth: 6999.59 - 7030.73 13732 - 13760 7049.59 - 7063.7 Tubing: (size, grade, and measured depth) 2-7/8" 6.53# Packers and SSSV (type and measured depth) 7" HPLPO o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 40 SHUT IN x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble ~ \t_\./LJ V t=U i1 f' T 2c 4· ¿.... n ~ (". ~)\e" uUo (;~ G ~sIQ~iI~n Stimulate 0 Other ¡. . OOi~Patch WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 194-1430 Exploratory Service 6. API Number: 50-029-22521-00-00 9. Well Name and Number: MPE-10 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool Plugs (measured) None Junk (measured) None TVD Burst Collapse 32' - 112' 31' - 3117' 30' - 6882' 6817' -7323' ';:C',i.~,o¡~~r:Û NOV 0 lZ 2.D05 \<~\ò;;§..r-t:~ð~ - L-80 EUE - 13134' 13248' o o o Tubing pressure 173 o Service WINJ WDSPl Title Data Engineer Signature Phone 564-4944 Date 10/23/2006 Submit Original Only , . . MPE-IO DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1000 psi (RWO to return to MI) job in progress 0-18-06 1 000 FAILED (RWO to return to MI) (Shut in) Pumped 7.1 bbls of 60/40 meth water TBG to reach 1000 psi for MIT TBG 1st test 1st 15 min lost 950 psi. Blocked in choke on S-Riser. Attempted 2nd MIT TBG Pumped 3.2 bbls of 60/40 meth water to reach 1000 psi 1 st 15 mín lost 900 psi pumped 10.3 bbls total Final Whp's=0/20N AC *** SOME S-RISER TO WING STUDS NOT FULL NUT 2 IA HANGER STUDS NUT STUDS NOT FULL NUT********** 10/1 10,134 10,133.5 FT. DEVIATION 43 DEGREES AT PLUG SET. PLUG FAILED MIT 1000 LBS. 1X12' STRING SHOT OVER INTERVAL 10,026-10,038 FT. SET HES 3-1/2" FASDRILL @ 10,051 FT. LRS RIGGED UP AND PRESSURED UP FOR MIT TEST ON PLUG. PLUG PASSED MIT TO 1,000# PSI. GIH WITH 1- 11/16" TUBING PUNCHER LOADED WITH SMALL CHARGES TO PUNCH 2 FT. @ 4 JSPF. TIED IN TO TUBING TALLEY DATED 14 AUG 1988. SHOT PUNCHER FROM 9,980' TO 9,982 FT. AFTER OOH WITH TUBING PUNCHER GUN SHOWED GUN FIRED OK. START RIGGING UP 2-3/8" CUTTER. ***JOB CONTINUED ON 10/20/06 WSR*** 10/19/2006 = Vac/40/0 Assist E-Line Test Plug to 1000 psi. (PASSED) Pumped 4.2 bbls of neat methanol down Tubing to reach test pressure. Tubing lost 50 psi in 1 st 15 min and 0 psi in the 2nd 15 min for a total loss of 50 psi in the 30 min Final Whp's = 0/40/vac 10/20/2006 10037. CUT THE TOOLSTRING HUNG UP AND HAD TO WORK TOOL. PUT LRS STBY. WORKED TOOL TO MAXIMUM PULL AND TOOL CAME FREE. POOH. RELEASED LRS. INSPECTION OF CUTTER INDICATED GOOD RDMO AND CLEAN LOCATION. NOTIFIED DSO OF DEPARTURE. ***** JOB COMPLETE***** FLUIDS PUMPED BBLS I 55 DIESEL 55 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3873' NSL, 2141' WEL, SEC. 25, T13N, R10E, UM MPE-10 At top of productive interval 9. Permit Number / Approval No. 194-143 2043' NSL, 3217' EWL, SEC. 29, T13N, R11E, UM 10. APl Number At effective depth 50-029-22521-00 2028' NSL, 3315' EWL, SEC. 29, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1952' NSL, 3726' EWL, SEC. 29, T13N, R11 E, UM Sands 12. Present well condition summary Total depth: measured 14225 feet Plugs (measured) Weatherford Cast Iron Bridge Plug set 13720' (12/00) true vertical 7327 feet Effective depth: measured 13720 feet Junk (measured) 6 Fin Pump Centralizer lost in hole at 13199' (05/02) true vertical 7044 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 4069' 9-5/8" 804 sx PF 'E', 250 sx Class 'G' 4100' 3117' Intermediate 13355' 7" 307 sx Class 'G' 13385' 6882' Production Liner 979' 5" 130 sx Class 'G' 13241' - 14220' 6817' - 7323' Perforation depth: measured 13630' - 13694', 13732' - 13760' true vertical 7000' - 7031' 7050' - 7064' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 13133' Packers and SSSV (type and measured depth) FB-1 Packer at 13200' and a 7" Liner Top Packer 'HPLPO' at 13248' 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 Oil-Bbl Gas-Mcr Water-Etbl 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 fore_going is true and correct to the best of my knowledge Signed "Sond~~-~~le Technical Assistant Date ~) ~'[ L_~-/~ ~._ ~. .. Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 plicate Submit In Du : ::: i:I ::;: : :Operations sUmmary Report Legal Well Name: MPE-10 Common Well Name: MPE-10 Spud Date: 4/29/2002 Event Name: WORKOVER Start: 4/29/2002 End: 5/8/2002 Contractor Name: NABORS Rig Release: 5/8/2002 Rig Name: NABORS 4ES Rig Number: 4 :Date:::: : :: ::FrOm:: ~:TO 1 :HOurs t: :Task: : , C°de: I NPT :i Phase I Description of Operations 4/29/2002 04'00 10'00 6 00! RIGU P PRE MI/RU 8, SAFE OUT EQUIPMENT/RIG ACCEPT @ 1000 i10:00- 11:00 1.00i KILL Ip ' iDECOMP HRS. 04/29/2002 RIG LINES TO TREE & SPOT TIGER TANK & TAKE ON 9.9 ,I, ! i~ PPG. BRINE. i11:00- 11:30 I 0.50 KILL P DECOMP i RIG LUBRICATOR & PULL BPV 11:30-12:00 I 0.501 KILL P I DECOMP'ITEST LINES TO 3500 PSI. 12:00-19:00 7.00 KILL P I ~DECOMP CIRCWELL BORE WITH 9.g PPG. BRINESHUTDN& / I' ~ , MONITOR SEVERAL TIMES AND CONT NUE TO HAVE I SMALL FLOW USE SALT TO TONE & SMOOTH OUT ISYSTEM TO 9.9 SMOOTH SYSTEM MONITOR WELL i I (DEAD) 19:00-19:30 0.50 WHSUR P I IDEOOMP ISETTWC&TESTSAME 19:30-21:00 1.50 WHSUR/P i DECOMP NIPPLE DN TREE 21:00 - 22:30 1.50 BOPSUF~P~! DECOMP NIPPLE UP BOP 22:30-23:30 I 1.00 BOPSUR~P I DECOMP BODY TEST BOP TO 3500 PSI. (TEST WAIVED BY JOHN , , I SPAULDING WITH AOGC) 23:30 - 00:00 0.50~ BOPSURP ! DECOMP RIG LUBRICATOR & PULL BPV. P PULL LUBRICATOR & TWC. RIG 4/30/2002 00:00 - 00:30 0.50 BOPSUq DECOMP 00:30 - 09:00 8.50 PULL i P I I DECOMP PULL OUT OF HOLE WITH ESP COMPLETION 09:00 - 10:30 1.50 PULL P !I DECOMP LAY DN ESP 10:30-11:30 / 1.00 ZONiSOipil iCOMP MUWORKSTRING#1 MULE SHOE + 20- JTS. 2-3/8"TBG. ,11:30 - 17:00t 5.50 ZONISO P ~ COMP RIH WITH WORKSTRING #1 & 2-7/8" TBG. FROM i DERRICK.TO 13540' 17:00 - 19:00 2.00 ]I ! 13728' & SET DN 25K & REVERSE CIRC 2-BOTTOMS UP i,! iTO CONFIRM PLUG IN PLACE AND CLN-WELL BORE. 19:00 - 20:30 1.50 ZONISO P I COMP RIG HES & TEST LINES TO 2500 PSI.& ClRC IN PLACE A ! BALANCED SZQ. PLUG OF 15.8 PPG. PREMIUM CMT. · +0.2% CFR-3+.45% HALAD-344+HR-5 TOTAL SLURRY VOLUME OF 7-BBL. 20:30 - 00:00 3.50 ZONISO P COMP POH TO 13210' & PERFORM A HESITATION SQZ. TO A SZQ. PSI. OF 1000 PSI. WITH A TOTAL OF 6-BBL. & MONITOR SAME EACH STEP. 5/1/2002 00:00 - 02:30 2.50 Z©NISO P COMP RIH TO 13240' & REVERSE WELL BORE CLN OF CMT. 02:30 - 09:00 6.50 ZONISO P COMP POOH & LAY DN 2.375" SQZD. STRING. 09:00 - 16:00 7.00 ZONISO P COMP MU CLN-ASSY # 1 MIL+MTR+CIRC SUB+20-JTS. 2-3/8" TBG. & RIH & TAG CMT. STRINGER @ 13237' 16:00 - 23:30 7.50 ZONISO P COMP CLN-OUT CMT. SQZ. FROM 13237' TO 13725' DRILLING CMT STRINGERS & CMT. WAS FIRM TO VOID AND SOFT IN SPOTS 23:30 - 00:00 0.50 ZONISO P COMP DROP BALL & SHEAR CIRC. SUB & REVERSE CMT. FROM ~ i i WELL BORE. 5/2/2002 00:00 - 01:30 1.50: ZONISO i COMP REVERSE ClRC WELL BORE. 01:30 - 09:30 8.00! ZONISO COMP POOH WITH CLN-OUT ASSY NO. 1 & LAY DN SAME. 09:30 - 11:00 1.50~ PERFRE ! COMP RIG UP SWS & HOLD PJSM 11:00-15:00i 4.00!PERFRE iCOMP RUN#1 RIHWITH GIWCCL 13706' WLM & LOG UP TO 13150' POOH & LAY DN SAME. NOTE:HAD PROBLEMS WITH GETTING REPEAT LOGS DUE TO STICKING. AND I GETTING BACK TO ORIGINAL SET DN DEPTH, 15:00 - 19:30 4.50 PERFRE COMP MU 3.375" 20' PERF. GUN WITH 6- SPF & RIH TO 13200' POSITION OF BAKER FB-1 PKR & WAS UNABLE TO GET THROUGH PACKER STICKING WHEN PICK UP ON PERF GUN POOH & LAY DN SAME. · · I Printed: 5/13/2002 12:55:10PM oPerationS:Sum:mary Report Legal Well Name: MPE-10 Common Well Name: MPE-10 Spud Date: 4/29/2002 Event Name: WORKOVER Start: 4/29/2002 End: 5/8/2002 Contractor Name: NABORS Rig Release: 5/8/2002 Rig Name: NABORS 4ES Rig Number: 4 o : urSl Task Code NpT Phase Description of Operations 5/2/2002 19:30 - 00:00 ~ 4.501 CLEAN COMP !MU 2-7/8" MULE SHOE ON WORK STRING AND RIH WITH P ' COMP SAME. TO 13238' 5/3/2002 i00:00 - 04:30 4.50 CLEAN REVERSE CIRC. TO CLN-OUT LINER 13238' TO 13720' @ 14-BPM 04:30 - 07:00 2.50 CLEAN P COMP i CHANGE OUT WELL BORE FLUIDS TO CLN 9.9 PPG. @ 6.00~ 4-BPM REVERSING 07:00 - 13:00 PERFREI P ] COMP POOH WITH CLN-OUT STRING. 2-7/8" TBG. (NOTE: ALL - i COLLARS CATCH ON FB-1 PACKER THAT ARE RUN i i BELOW PACKER.> 13:00 - 16:30 3.50 PERFRE P COMP i RIG SWS & RIH WITH CCL & 20'-3-3/8" PERF GUN TO I i i i 13390'~ UNABLE TO GET DN. POOH & LAY DN SAME. ,16:30 - 18:00 1.50 PERFRE P COMP WAIT ON 2-7/8" PERF. GUN MAKE UP & RIH WITH 20' 2.875" PERF. GUN TO 13429' - MU 10'-2.875" PERF GUN & RIH WITH SAME TO 13230' NO 20:00 00:00 4.00 PERFRE P COMP UNABLE TO GET DN POOH & LAY DN SAME. , , I-GO POOH & RIG DN SWS E-LINF 5/4/2002 ~00:00 - 06:00 6.00~ PERFREI C COMP WAIT ON TCP GUNS AFTER EVALUATING THAT E-LINE 106'00' 0.501PERFRE P I WAS UNABLE TO PERF. DUE TO WELLBORE GEOMETRY. . 06:30 I 'COMP !MU 40' OF 2.88" TCP HSD PJ 2906 6-SPF.UING A HDF , ! 45100~!PERFREPJ , HEAD 06:30 - 11:30 COMP RIH WITH TCP GUNS TO 13725' ~ 11:30 15:30 PERFRE P I COMP RIG SWS E- LINE & RIH WITH GR/CCL & FOUND RA TAG 501 I COMP IN TBG. TO BE 28.1 ' LOW POOH & RIG DOWN E-LINE. 15:30 - 17:00 1. PERFRE P i MOVE GUNS INTO POSITION & PSI. TO 1400 PSI. & WAIT : FOR DELAY & GUNS FIRED & MONITOR WELL BORE f PERFRE.] P~' I 2906STATIC: PERFS. 13,644'/13,684' 6-SPF.W/2.88" HSD PJ 17:00 - 23:00 6.00 COMP POOH WITH PERF. GUNS -1.00 I~P MAKE UP ESP ASSY. 23:00 - 00:00 RUNCO COMP I 5/5/2002 00:00 - 01:00 1.00 RUNCOI~ ~COMP I MU ESP ASSY. 01:00 - 03:00 2.00 RUNCOI~P 'COMP I RIH WITH ESP ASSY TO 3912' (FOUND BAD ARMOR ON t ~ ESP CABLE ) 03:00 - 05:00 2.00 RUNCO. COMP MAKE SPLICE IN ESP & AFTER FARTHER INVESTIGATION I DETERMINE THAT ESP CABLE IS BAD 05:00 - 07:30 i 2.501 PULL , N COMP POOH TO ESP ASSY. 07:30 - 08:30 ! 1.00 RUNCOI~I COMP REMOVE FLAT GUARDS & PROTECTALIZERS & DRAIN SEAL 08:30 - 09:30 1.00 RUNCOP, i'4 COMP CHANGE OUT SPOOLS & MAKE MOTOR LEAD SPLICE. 09:30 - 11:30 2.00 RUNCOI~I COMP RE-SERVICE SEALS ATTACH CABLE & SECURE -TEST OK. 11:30- 15:30I 4.00 RUNCON~-- COMP RIHWITH ESPASSYTO 8100' 15:30 - 18:00 I 2.50 RUNCOI~:~ COMP MAKE REEL TO REEL SPLICE (AFTER RE-TEST ON CABLE / I DOWN HOLE PROBLEMS WERE DETECTED. 18:00 - 00:00 6.00 PULL N COMP POOH WITH ESP ASSY. 5/6/2002 00:00 - 01:30 1.50 PULL N COMP CONTINUE TO POOH WITH ESP ASSY. 01:30 - 02:30 1.00 PULL IN COMP INSTALL NEW REEL IN SPOOLER 02:30 - 05:00 2.50 PULL N I COMP PULL DRAIN PLUGS ON SEAL SECTION & CHECK MTR. DISCOVER THAT BLADED CENTRALIZER LOST OFF r BOTTOM OF PHD. 05:00 - 07:00 2.00.1 PULL N COMP REMOVE MOTOR LEAD & RE-SERVICE ESP SEALS. 07:00 - 13:30 6.501 FISH N COMP RIG HES SLICKLINE & RIH W/3.5" LIB & TAG @ 7818'& WORK DN HOLE TO 8218' & POOH WITH 3.5" LIB & RIH I WITH 5" GAUGE RING WITH STABILIZER & TAG @ 7818' & PUSH TO 8510 POOH & R G DN HES SL CKLINE Printed: 5/13/2002 12:55:10 PM Report Page 3 of 3 Legal Well Name: MPE-10 Common Well Name: MPE-10 Spud Date: 4/29/2002 Event Name: WORKOVER Start: 4/29/2002 End: 5/8/2002 Contractor Name: NABORS Rig Release: 5/8/2002 Rig Name: NABORS 4ES Rig Number: 4 iDate: :' From 'iTo~: s Task~ i Code' NPT :phase Description of Operations 5/6/2002 13:30- 14:30 1.00/FISH N I ICOMP ,LAY UN ESP ASSY. 14:30 - 19:30 FISH N I COMP MU 6" MAGNET ON 2-7/8" TBG. & RIH & TAG @ 8508' UNABLE TO PASS THROUGH. 5/7/20O2 5/8/2002 19:30 - 22:30 22:30 - 00:00 00:00 - 01:30 · 01:30 - 02:00 02:00 - 06:30 06:30- 13:00 13:00- 14:30 i14:30 - 17:00 17:00 20:00 20:00 - 21:30 21:30 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 09:30 09:30- 12:00 12:00- 15:00 15:00- 18:00 18:00 - 19:00 19:00 - 21:30 21:30 - 22:30 22:30 - 23:00 23:00 - 23:59 5.00 3.00 1.50 1.50 0.50 4.50 6.50 1.50 2.50 3.00 1.50 2.50 2.00 FISH N BOPSURN BOPSURP FISH N FISH N FISH N FISH N I RUNCO~ IN RUNCO1P PULL JN PULL /N RUNCOI~:~ 2. oI RuNco 5.001RUNCOI~ 2.50/ RUNCOI~ RUNCO~I:~ RUNCOr~P 1.001RUNCOI~ 2.50i BOPSUI~P 1.001WHSURIP 0.50 WHSURIP 0.98 WHSUR P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP POOH WITH 6" MAGNET & ANALYZE IMPRESSION ON SKIRT & DECISION MADE THAT SKIRT ON MAGNET WOULD NOT PASS THROUGH ESZV CEMENTER. TEST BOP TO 250 LOW / 3500 HIGH (TEST WAIVED BY CHUCH SHEVE WITH AOGC) TEST BOP 250 LOW/3500 HIGH (WAIVED BY CHUCK SHEVE) MU BHA MAGNET+JARS+3-DC. RIH WITH MAGNET PUSH CENTRALIZER FROM PHD TO 13205' POOH & LAY DN BHA (NO RECOVERY) RIG HES SLICKLINE & RIH WITH 3.5" SWEDGE TO 13205' & POOH & RIG DN SAME. MU ESP ASSY & SERVICE SAME. RIH WITH ESP ASSY TO 2914' (TEST CABLE SHOWED BAD) POOH WITH ESP ASSY. BREAK DN ESP EQUIPMENT MOTOR & MOTOR LEAD CHANGED OUT SPLICE CHECKED BAD. MU & SERVICE ESP SPLICE ESP CABLE TO MOTOR LEAD CABLE. RIH WITH ESP COMPLETION TO MAKE MID-LINE SPLICE IN ESP CABLE. CONTINUE TO RIH WITH ESP COMPLTION TO HANGER DEPTH 13132' MU HANGER & MAKE EFT CONNECTOR SPLICE & LAND HANGER & RILDS. INSTALL TWC & TEST TO 2500 PSI. NIPPLE DN BOP NIPPLE UP TREE PRESSURE TEST TREE TO 5000 PSI. RIG LUB & PULL TWC & SET BPV & RELEASE RIG @ 2359 HRS. 5/8/2002 Printed: 5/13/2002 12:55:10 PM STATE OF ALASKA ALASKA _,L AND GAS CONSERVATION COMIV,,..,$1ON 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 = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3873' NSL, 2141' WEL, SEC. 25, T13N, R10E, UM MPE-10 At top of productive interval 9. Permit Number / Approval No. 194-143 2043' NSL, 3217' EWL, SEC. 29, T13N, R11 E, UM 10. APl Number At effective depth 50-029-22521-00 2028' NSL, 3315' EWL, SEC. 29, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1952' NSL, 3726' EWL, SEC. 29, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 14225 feet Plugs (measured) Weatherford Cast Iron Bridge Plug set 13720' (12/00) true vertical 7327 feet Effective depth: measured 13720 feet Junk (measured) true vertical 7044 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 4069' 9-5/8" 804 sx PF 'E', 250 sx Class 'G' 4100' 3117' Intermediate 13355' 7" 307 sx Class 'G' 13385' 6882' Production Liner 979' 5" 130 sx Class 'G' 13241' - 14220' 6817' - 7323' Perforation depth: measured 13630'- 13694', 13732'- 13760' ~ %.;~._.,.~ .... true vertical 7000' - 7031', 7050'- 7064' t-~ ~ ~ 0 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 13134' Alaska Oil & G~s Anchor~rje Packers and SSSV (type and measured depth) 7" Liner Top Packer 'HPLPO' at 13248' 13. Stimulation or cement squeeze summary Intervals treated (measured) 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: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is tr~e and correct to the best of my knowledge Signed TerrieHubble.,~~ ~j~~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate : : : u dUUl : OPerati: S summary Report : : i:: Alaska Oil & Gas Con,,. Commission A,',chorage Legal Well Name: MPE-J 0 Common Well Name: MPE-10 Spud Date: 12/6/1994 Event Name: WORKOVER Start: 12/19/2000 End: 12/27/2000 Contractor Name: NABORS Rig Release: 12/27/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 : :~ate ]:: ~ro~:~:~ :~rsIi:: ~aSk::t:cS.c~dbe:::]~has~:' Descri of Operations :::::::: ::::: :::::: :: ~::!!~::::~ : :: : Ption 12/21/2000 06:00 - 09:30 3.50 MOB PRE MOVE FROM E-25 TO E-10. 09:30 - 11:30 2.00 RIGU PRE RAISE & SCOPE DERRICK. HOOK UP LINES. 11:30 - 13:30 2.00 RIGU PRE RIG UP TIGER TANK & HCR VALVE. TAKE ON 9.9 PPG KILL FLUID. 13:30 - 14:30 1.00 WHSUR DECOMP PULL BPV. W/LUBRICATOR. SITP 1000 PSI. 14:30 - 15:00 0.50 WHSUR DECOMP HOOK UP MUD LINES TO TREE. TESTLINES TO 2500 PSI. 15:00 - 22:30 7.50 KILL DECOMP OPEN WELL, SITP 800 PSI, SICP 1050 PSI. KILL WELL. PUMP 9.9 PPG KILL FLUID. RECOVERED 540 BBLS OIL. WELL ON SLIGHT VACUM. (DEAD) KILLED @ 3BPM 1300 PSI. 22:30 - 23:00 0.50 KILL DECOMP OBSERVE WELL, WELL DEAD. 23:00 - 23:30 0.50 WHSUR DECOMP INSTALL TWC & TEST TO 3500 PSI. 23:30 - 00:00 0.50 WHSUR , DECOMP BLEED HANGER VOID & N/D X-MAS TREE. 12/22/2000 00:00 - 00:30 0.50 WHSUR DECOMP N/D X-MAS TREE. 00:30 - 08:00 7.50[ BOPSUF DECOMP N/U ROPE. INSTALL BLIND/SHEAR RAMS. SHIM RIG 4" FOR HEIGHT CHANGE F1 EXTRA SPOOL. 08:00 - 10:00 2.00! BOPSUF DECOMP !PRESSURE TEST ROPE. LP 250 PSI, HP 3500 PSI. TEST WITNESSING WAIVED BY JOHN CRISP W/AOGCC. 10:00 - 11:00 1.00 WHSUR DECOMP M/U LUBRICATOR & PULL TWC VALVE. WELL DEAD. 11:00 - 13:30 2.50 KILL DECOMP CIRCULATE BO'I-I'OMS UP. 3 BPM 1200 PSI. MONITOR WELL. 13:30 - 14:00 0.50 WHSUR DECOMP M/U LANDING JT. BOLDS. PULL HANGER TO FLOOR. 81K. L/D SAME. 14:00 - 15:00 1.00 PULL DECOMP R/U TO CUT TBG & PULL COMPLETION. 15:00 - 00:00 9.00 PULL DECOMP PULLOUT OF HOLE, CUT TBG IN 19' LENGTHS & L/D. CUT & L/D 150 PIECES (2900') 12/23/2000 00:00 - 00:00 24.00 PULL DECOMP POOH, CUT & L/D COIL TBG.MADE A TOTAL OF 625 CUTS. 12/24/2000 00:00 - 06:30 6.50 PULL DECOMP POOH. CUT & L/D COIL TBG. 06:30 - 08:00 1.50 PULL DECOMP L/D & INSPECT ESP ASSY. 08:00 - 08:30 0.50 WHSUR DECOMP INSTALL WEAR BUSHING. 08:30 - 11:00 2.50 REST DECOMP CLEAR FLOOR& LOAD PIPE SHED W/DP. TALLY SAME. 11:00-12:30 1.50 REST DECOMP R/UTOP/U&RIHW/DP. 12:30 - 14:00 1.50 REST DECOMP P/U OVERSHOT, BUNPER SUB & JARS. P/U 9 DCS & CIRC SUB. RIH W/SAME. 14:00 - 00:00 10.00 REST DECOMP P/U TALL & RIH WI 3 1/2" DP. 12/25/2000 00:00 - 02:00 2.00 REST DECOMP P/U TALLY & RIH WI DRILLSTRING. 02:00 - 03:00 1.00 REST DECOMP P/U KELLY & TAG LLC @ 13188'. ENGAUGE LLC, ROTATE & UN SET LLC. EQUALIZE & PRESSUR UP TO INSURE TOOL IS ENGAUGED. 03:00 - 03:30 0.50 REST DECOMP STAND BACK KELLY & MONITOR WELL. PREPARE TO POOH. 03:30 - 10:30 7.00 REST DECOMP POOH W/LLC. 10:30 - 11:30 1.00 REST DECOMP L/D LLC VALVE & O/S ASSY. 11:30 - 13:00 1.50 REST DECOMP R/U SLICKLINE EQUIP. 113:00-19:00 6.00 REST DECOMP RIH W/ GR/JB TO TOP OF PKR @13192'. RIH W/ 3.875" DRIFT TO PBTD @ 14042'. R/D SLICKLINE EQUIP. 19:00- 21:30 2.50 REST DECOMP R/U E-LINE EQUIP. 21:30 - 00:00 2.50 REST DECOMP RIH W/BP ON E-LINECOULD NOT GET THRU FA-1 PHR. PUMP BP TRHRU PKR @ 1/2 BPM. PLUG PASSED THRU PKR. 12/26/2000 00:00 - 04:00 4.00 REST DECOMP RIH W/BP. HAD TO PUMP DOWN 2 BPM. SET BP @ 13720'. POHH & R/D E-LINE EQUIP. 04:00 - 08:30 4.50 REST DECOMP TIH W/3 1/2" DP. 08:30 - 18:00 9.50 REST DECOMP POOH & L/D 3 1/2" DP. 18:00 - 18:30 0.50 REST DECOMP POOH & L/D BHA. 18:30 - 19:00 0.50 RUNCOI~I COMP PULL WEAR BUSHING. 19:00 - 20:00 1.00 RUNCOI~I COMP R/U TO RUN COMPLETION, INSTALL REEL IN SPOOLING UNIT. 20:00 - 22:30 2.50 RUNCOI~I COMP MAKE UP ESP SERVICE & TEST SAME. Printed: 1/26/2001 4:24:15PM i 0perat! n :summa Report Legal Well Name: MPE-10 Common Well Name: MPE-10 Spud Date: 12/6/1994 Event Name: WORKOVER Start: 12/19/2000 End: 12/27/2000 Contractor Name: NABORS Rig Release: 12/27/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 :~r°~ ~ ~o' ~rs: Tas~ Description of Operations 1212612000 22:30 - 00:00 1.50 RUNCOI~ COMP P/U 2 7~8" TBG & RUN IN HOLE W/COMPLETION. 1212712000 00:00 - 07:00 7.00 RUNCOI~I COMP P/U 2 7/8" TBG & RIH. 07:00 - 10:30 3.50 RUNCON1 COMP CHANGE OUT CABLE SPOOLS & MAKE UP MID-RUN CABLE / SPLICE. 10:30 - 15:30 5.00 RUNCOI~I COMP P/U 2 7~8" TBG & RIH. (SEE TBG DETAIL RPT) 15:30 - 19:00 3.50 RUNCOI~'] COMP MAKE UP TBG HANGER & LANDING JT. P/U WT 83K, SIC WT 36K. MAKE UP CONNECTOR & TEST SAME. PJD FLOOR. LAND COMPLETION STRING @ 13134'. RILDS INSTALL TWC. 1 g:00 - 20:30 1.50 BOPSUF COMP DRAIN DOWN BOP STACK & REMOVE HARD LINES. CHANGE OUT BLIND/SHEAR RAMS TO BLIND RAMS. 20:30 - 22:00 1.50 BOPSUR COMP N/D BOPE. 22:00 - 00:00 2.00 WHSUR COMP INSTALL NEW ADAPTER FLANGE & N/U X-MAS TREE. TEST FLANGE & TREE TO 5000 PSI, OK. PULL TWO & INSTALL BPV. SECURE WELL & CLEAR CELLAR. RELEASE RIG @ 2400 HRS, 12-27-00. i i ! i i ' ~-'.' ~:: ~ '~.~,~' i~' ~ I FEB 0 7 7001 Alaska 0il & Gas Cons. Commission Anchorage ; i i i Printed: 1/26/2001 4:24:15PM oN OR BEFO c:bO~mM-'D°c ANNULAR INJECTION DATA ENTRY SCREEN A s s e t .M. il~e ...................................... :. Rig Name .~abnr. s..22E ........................... Inj Well Name .MEE:.1;a.;;:;; ............................ Permit Start ...... 2.L3.Lg.fi ...... Sur Csg Dep ..4..1.Qfi .............. · .............................. Cumulative Data Legal Desc .3ZO.5.'.ESL,...:I.I]O.0:EE.L...S.e~..25.,T..1.3.1LIt,...B.1.0.E ....................... Research ........................................................................................................................ CQrmcted.copy..submitted..t~.AO.GC.C..on .................. 2:.2fi.:.9.Z ..................................................................................... Permit E n d .....l.2L3..1.J..9.fi... · Rig Completion Formation ::lntermittant ::: :Final i :] Well Total Mud/Ctg Wash : Fluids Fluid§,: Freeze: :::Freeze:::::: Source , Well Daily Data iMud, Ctgs, Cmt I ~ [ Intermittant { Final Date of : i Contaminated / RigWash : Completion FOrmation/ ' Freeze ~:1 :: Freeze Injection ! Drlg MUd ~ i Fluids : Fluids I Fluids : protection I protection o o o 0 o 0 o 87o 47o '68o 75 4oo 63o 41o 3oo 465 MPE-10 200 :Mt~ E:"i' ~ ........... 220 MPE-13 02/1 7/95 02/19/95 0 02/20/95 270 02/21/95 0 _M......P...E.:.L3_ ...... j ~...~L.2_..._2_/.A~.._ 9_ ~_MPE-13 03/05/95 680 I0 o jo ......... 0 ........... 0 0 j45 '~ ................ j; ...................... I'~ ..... __.1 ] . .......................... status: :1 c°mments ComplEations .~ ................... ~.9....9...4......Y.....E.A..,.R_....,S_ .U......M....M....A....R....Y... .......................................................................... ................................ :L_99....5.._.Y..,I~ .A....R_,.S, .U._M_.M..,.A.I:3..Y. ............................................................ --, .... , __ __ P E R M l 'T /3, afr.:e: i i/'?0/'96 R LI i".~ F:, A 'FE ..... 17 E C V D 9 % ..... i ~ 3 96 ........ i a. 3 6726 ~r~<i 932B.~ 1~225 GR/CL..F-~T' 7~'i~ ~")~'i ~0 .... 'i 35a. 0 RL L/GRC/EWE/R,$,F' i (.')8/0 /95 'i 0 'i/' i '? / 9 ~''~: '1 0i/ 17/"95 DGR/'EWR~a- ~--. 685L~ .... 7327 TVD 'i 08/'02.,.'"9.5 Are dr'y PG R/ d"itch sainples Was the weii cor'ed? Ar"e we'l i tests r'equi~r'.ed? yes Wei'i is in compi Z n i' 't C () M M E N T S WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MP E-10 AK-RB-941239 August 1, 1995 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, f/G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 1 Magnetic Tape w/LDWG Listings 5631 Silverado Way, Su~tr ". Anchorage, Alaska 99518 · (9.07) 567'- .... '46 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 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) April 4, 1995 RECEIVED APR 4 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-$ 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Alaska Oil & Gas Cons. Commission Anchorage Tile following data of the ANADRILL MWD-GR for well MPE-10, Job # 95094 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape ~Alaska Oil & Gas-Gdnservation Comm. (' Attn: Larry ~Gr~t ",,,,~001 Porcupine Drive ' ,z~'rchorag~lask~95~ I OH LIS~'Tape.__ .... OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape Sent Certified Mail P 905 127 804 PLEASE NOTE: NO DEPTH CORRECTION WAS DONE ON THIS WELL. 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 ~1 Date Deliv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] t'~ ./~ SERVICE [] 2. Name of Operator - ,t f. //~~_. 7. Permit Number BP Exploration (Alaska) Inc. ~~'~ 94-143 P. o. Box 196612, Anchorage, Alaska 99519-6612 ~ ,- ," ~' ~ !~1 so-029-22521 4. Location of well at surface : ........ ~ ~" ~, r., ~i!~'~/~;;~ 9. unit or Lease Name ~ ' - '~'-',~." ~ ! '~ ~ -~i~ 3873 NSL, 2141 WEL, SEC. 25, T13N, RIO~ .~,~;~,; "--' ! ~ Milne Point Unit At Top Pro.,~g~i.0t~nterval :; //,~4~ i ,,^m 10. Number ~o~ NS~~w~, s~c. ~, ~N, R~O~ ~ ~ ~ytal D~~IPE? ;:;~;''~'~s~ 0it &~choraGas Cons. Commission ~. Field and Pool ,,~ ............. ~ ~At Milne Point Unit- Kuparuk River Sands 1961 NSL, ~ EWL, SEC. 2& T13N, R 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 54' ADL 28231 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore 16. No. of Completions 1~6/94 12/28/94 1/8/95~ N/A feet MSL One 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14225' MD/7329' TVD 14084' MD/7241' TVD ~ ~ ~ B~ LLCV ~ 13193' feet MD~ 1800' (Approx.) 22. Type Electric or Other Logs Run G~RES 23. CASING, LINER AND CEME~ING S~ING DE~ MD CASING SIZE ~. PER ~. G~E TOP ~ HO~ SI~ CEME~NG RE,RD ~OU~ PULLED 20" 91.1~ H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40~ L-80 31' 4100' 12-1/4" 804 sx PF "E'F250 sx "G" 7" 26~ L-80 30' 13385' 8-1/2" 307 sx Class "G" 5" 15~ 13CR80 13241' 14220' 6" 130 sx Class "G" 24. Pedorations open to Production (MD+~D of Top and Bottom and 25. TUBING RE,RD inte~al, size and number) SIZE DEP~ S~(MD) PACKER S~ (MD) Gun Diameter 3-3/8" 6 spf 2- 7/8", HS- 70 13143' 13200' MD 13630~13694' 7000'-7031' 26. ACID. F~CTURE, CEMENT SQUE~E, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUC~ON TEST Date First Production Method of Operation (FIo~ng, gas lift, etc.) 1/28/95 ESP Date of Test Hours Tested PRODUC~ON FOR DIL-BBL GAS-MCF WATER-BBL CHOKESI~ IGAS-OIL RATIO I ~ST PERIOD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HQUR 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 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB TKCl 13606' 6988' : TKUB 13693' 7030' TKB7 13735' 7051' TKB6 13804' 7086' RECEIVED MAR 28 1995 A!~sk~ Oil & Gas Cons. Commission Anchor~" 31. LIST OF A-I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t Title Drilling Engineer Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 , AAI SHARED SERVICE --. DAILY OPERATIONS PAGE: 1 WELL: MP E-10 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/06/94 06:00 SPUD: RELEASE: 01/08/95 07:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: 12/06/94 ( 1) TD: 112'( 0) RIG UP / INSTALL BERMS MOVE RIG FROM MP E-09 TO MP E-10. MW: 0.0 VIS: 0 12/07/94 ( 2) TD: 1090' ( 978) 12/08/94 (3) TD: 3530' (2440) 12/09/94 (4) TD: 4120' ( 590) SHORT TRIP MW: 0.0 VIS: 0 HOOK UP ELECTRICAL LINES. SPOT TIOGA. BUILD BERMS. TAKE ON WATER. MIX SPUD MUD. NU FLOWLINE. BUTTON UP COMPLEXES. PREP FLOOR TO DRILL. PU BHA TO RIG FLOOR TO THAW. NU BELL NIPPLE. CONNECT TURNBUCKLES. CONNECT FLOWLINE. MU BIT AND MOTOR. FUNCTION TEST DIVERTER. DIVERTER LINES BLOWN FULL OF SNOW. CLEAN OUT SAME. MU BHA. TAG BOTTOM AT 105'. BREAK CIRC. CHECK FOR LEAKS. DRLG TO 290'. POH 2 STANDS HWDP. MU REMAINING BHA. DRLG AND MWD SURVEY 12 1/4" HOLE F/ 290 - 1090'. KICK OFF AT 400'. CIRC. SHORT TRIP TO JARS. NO HOLE PROBLEMS. DRILLING MW: 0.0 VIS: 0 FINISH SHORT TRIP. NO PROBLEMS. DRLG AND MWD SURVEY 12 1/4" HOLE F/ 1090 - 2129'. CIRC SWEEP AROUND_ POH W/ 7 STDS. HOLE TIGHT AND SWABBING. RIH. CBU. OK. SHORT TRIP TO 1090' NO PROBLEMS. DRLG AND MWD SURVEY 12 1/4" HOLE F/ 2129 - 3164' CBU. 10 STD SHORT TRIP. WORKED TIGHT SPOT AT 2250'. DRLG AND MWD SURVEY 12 1/4" HOLE F/ 3164 - 3372'. HAD GAS BREAKING OUT AT SURFACE. CIRC AND INCREASE MUD WT F/ 9.8 TO 10.0 PPG. MONITOR WELL. WELL IS STATIC W/ NO GAS CUT MUD. DRLG AND MWD SURVEY 12 1/4" HOLE F/ 3372 - 3530' RIH W/ 7" CSG MW: 0.0 VIS: 0 DRLG AND MWD SURVEY 12 1/4" HOLE F/ 3530 - 4120'. CBU. DROP EMS. POH TO JARS. NO CORRECTION. HOLE TIGHT AND SWABBING F/ 2560 - 2220'. FILL THROUGH DP. RETRIEVE EMS TOOL. RIH. TIGHT F/ 2510 - 2520' REAM LAST STD TO BOTTOM. PUMP LO/HI VIS SWEEP. CI~C AND CONDITION MUD TO RUN CSG. MONITOR WELL. PUMP PILL. BLOW DOWN LINES. POH. NO HOLE PROBLEMS. LD BHA AND CLEAR FLOOR. CHANGE BAILS. RU CSG EQUIPMENT. RIH W/ 9 5/8" CSG TO 1400'_ REPAIR AND MONITOR DRAWWORKS TRACTION MOTOR. RIH W/ 9 5/8" CSG TO 3200'~ RECEIVED MAR 2.8 1995 Ai~,ska Oi~ & Gas Cons. Commission Anchor~" : MP E-10 OPERATION: RIG : NABORS 22E° PAGE: 2 12/10/94 ( 5) TD: 4120' ( 0) 12/11/94 ( 6) TD: 6198' (2078) 12/12/94 ( 7) TD: 7864' (1666) 12/13/94 ( 8) TD: 8760' ( 896) 12/14/94 ( 9) TD:10702' (1942) RIH W/ BHA #2 MW: 0.0 VIS: 0 FINISH RIH W/ 9 5/8" CSG. MU LJ AND HANGER. LAND CSG AT 4100'. RU CEMENT HEAD. BREAK CIRC. INCREASE RATE F/ 3 TO 11 BPM IN 1 BPM INCREMENTS. CIRC 1 1/2 ANNULAR VOLUMES. TEST LINES. PUMP 50 BBLS H20, 804 SX "E' PERMAFROST CEMENT, 250 SX "G" CEMENT AND DISPLACE W/ RIG PUMP. BUMP PLUG. CHECK FLOATS, OK. RD CEMENT HEAD AND LD LJ. RU AND PUMP 113 SK "E" PERMAFROST TOP JOB. ND DIVERTER. INSTALL FMC SPEED HEAD. NU 13 5/8" BOPE. INSTALL TEST PLUG. TEST BOPE. PULL TEST PLUG. BLOW DOWN ALL LINES. INSTALL WEAR BUSHING. LD LJ. PU BHA #2 TO FLOOR. SERVICE TOP DRIVE. STEAM BHA. CENTER STACK IN ROTARY. MU BHA #2. TEST MWD. PU "E" DP AND RIH. SHORT TRIP TO SHOE MW: 0.0 VIS: 0 FINISH PU "E" DP. TAG FLOAT COLLAR AT 4021'. TEST CSG. DRILL FLOAT EQUIPMENT, CEMENT AND 10' NEW FORMATION TO 4130'. CIRC AND CONDITION MUD. PERFORM LEAKOFF TEST. FORMATION HELD. DRAG AND MWD SURVEY 8 1/2" HOLE F/ 4130 - 5162'. CIRC LO/HI VIS SWEEP. MONITOR WELL. POH TO SHOE. HOLE TIGHT AND SWABBING. BACK REAM TO SHOE. RIH. REAM F/ 4317 - 4700' AND F/ 4867 - 4958'. REAM LAST STD DOWN. DRAG AND MWD SURVEY 8 1/2" HOLE F/ 5162 - 6198'. CIRC LO/HI VIS SWEEPS. MONITOR WELL. PREP TO SHORT TRIP AND GYRO. DRILLING MW: 0.0 VIS: 0 POH TO SHOE. HOLE TIGHT AND SWABBING. BACK REAM F/ 5760 - 4781' RIH TO TD. NO PROBLEMS. REAM LAST STD DOWN. CIRC AND CONDITION MUD. RU ATLAS WA. RUN GYRO DATA LOG F/ 5547' TO SURFACE__ PUMPED TOOL DOWN F/ 4700'_ RD ATLAS WA. DRAG AND MWD suRVEy 8 1/2" HOLE F/ 6198 - 7235' CIRC SWEEPS AND CONDITION MUD SHORT TRIP TO 6198' NO PROBLEMS. DRAG AND MW/) ~URVEY 8 1/2" HOLE F/ %235 - 7864'. DRILLING MW: 0.0 VIS: 0 DRAG AND MWD SURVEY F/ 7864 - 8087'. CIRC SWEEPS. MONITOR WELL. STATIC. POH, NO PROBLEMS. MONITOR WELL AT SHOE. MU BHA #3. RIH TO 3865'. CUT AND SLIP DRAG LINE. SERVICE TOP DRIVE. RIH. PU 114 JTS 'G' DP. REAM 90' TO BOTTOM. DRAG AND MWD SURVEY F/ 8087 - 8760'. DRILLING MW: 0.0 VIS: 0 DRAG AND MWD SURVEY 8 1/2" HOLE F/ 8760 - 9166'. CIRC LOW/HIGH CIS SWEEP. MONITOR WELL. 12 STD SHORT TRIP. NO PROBLEMS. DRAG AND MWD SURVEY 8 1/2" HOLE F/ 9166 - 10200'. CIRC LOW/HIGH VIS SWEEP. MONITOR WELL. 12 STD SHORT TRIP. NO PROBLEMS. DRAG AND MWD SURVEY 8 1/2" HOLE F/ 10200 - 10702'. RECEIVED MAR 2 8 199~ Ai~ska Oil & Gas Cons. Commission Anchor~ ', : MP E-10 OPERATION: RIG : NABORS 22E PAGE: 3 12/15/94 (10) TD:12182' (1480) 12/16/94 (11) TD:13204' (1022) 12/17/94 (12) TD:13406' ( 202) 12/18/94 (13) TD:13406' ( 0) 12/19/94 (14) TD:13406' ( 0) SHORT TRIP MW: 0.0 VIS: 0 DRILL 8 1/2" HOLE W/ 7 3/8" TURBINE F/ 10702 - 11237'. CIRC OUT SWEEP. MONITOR WELL. PUMP PILL. WIPER TRIP, 12 STANDS. NO PROBLEMS, NO FILL. DRILL 8 1/2" HOLE W/ 7 3/8" TURBINE F/ 11237 - 12184'. CIRC SWEEP AROUND AND MONITOR WELL. PUMP PILL. SHORT TRIP 44 STANDS TO 8000' TO P/U 45 JTS "G" PIPE. NO HOLE PROBLEMS. WIPER TRIP MW: 0.0 VIS: 0 PU 45 JTS 'G' DP AND RIH. NO PROBLEMS. DRILL 8 1/2" HOLE W/ 7 3/8" TURBINE F/ 12184 - 13204'. MONITOR WELL AND PUMP PILL. SHORT TRIP TO WIPE THRU HRZ ZONE. CIRC BOTTOMS UP MW: 0.0 VIS: 0 WASH AND REAM F/ 13031 - 13204'. DRILL 8 1/2" HOLE FROM 13204 - 13406'. PUMP LO/HI VIS SWEEP AROUND. SHORT TRIP TO CASING SHOE SLM, NO CHANGE. TIGHT SPOTS F/ 12082 - 12050', 11656 - 11507', 9130 - 7785', 7785 - 5847'. MONITOR WELL AND SERVICE TOP DRIVE. RIH TO 10750' HIT TIGHT SPOT. ATTEMPT TO WASH AND REAM THROUGH TIGHT SPOT @ 10750' COULD NOT PUT ANSY WEIGHT ON TURBINE, STALLING OUT. ~IRC BOTTOMS UP BEFORE PULLING OUT OF HOLE TO P/U 8 1/2" HOLE OPENER. REAMING TO BOTTOM MW: 0.0 VIS: 0 MONITOR WELL AND PUMP PILL. POH. LD BHA. CLEAR RIG FLOOR. SERVICE WEAR RING. REPLACE BOOT ON FLOW LINE. MU 8 1./2" HO WITH PORTED BULL NOSE AND RIH. HIT BRIDGE @ 10950'. TRYING TO PACK OFF. WASH AND REAM FROM 10950 - 11034'. RIH TO 12680'. HIT TIGHT SPOT. M/U TOP DRIVE AND WASH AND REAM F/ 12680 - 12750'. STILL TRYING TO PACK OFF. REAMING W/ HOLE OPENER MW: 0.0 VIS: 0 REAM FROM 12770 - 12919' W/ 80 RPM, 100 SPM AND 1300 PSI. POH TO 12600'. RE-REAM F/ 12600 - 12919' W/ 100 RPM, 140 SPM AND 2300 PSI, NO PROBLEMS. REAM 12919 - 12935'. . PACKING OFF AND STICKING WORKED PIPE FREE. POH TO 10900 TIGHT @ 11490 - 11300' PULLED 30 - 50K OVER. CIRC BOTTOMS UP. RIH. TIGHT @ 12880 - 12940'. 30 - 90K OVER. REAM F/ 12919 - 13014' WITH 100 SPM, 80 - 100 RPM WITH 1300 PSI. REAMED SECTION 7 TIMES. PUMPED HI-VIS PILL. WILL POH WHEN PILL COMES AROUND AND LOOK AT HOLE OPENER. RECEIVED MAR 2 8 1995 Alaska Oil & Gas Cons. Commission Anchor~:.. : MP E-10 OPERATION: RIG : NABORS 22E PAGE: 4 12/20/94 (15) TD: 13406' ( 0) 12/21/94 (16) TD:13406' ( 0) 12/22/94 (17) TD:13406' ( 0) 12/23/94 (18) TD:13406' ( 0) 12/24/94 (19) TD: 13406' ( 0) REAMING W/ HOLE OPENER MW: 0.0 VIS: 0 MONITOR WELL AND PUMP PILL. POH. ONE CUTTER ON HOLE OPENER LOCKED UP. NO HOLE PROBLEMS. M/U SMITH 8 1/2" HOLE OPENER AND NB STAB AND RIH TO CASING SHOE. SERVICE TOP DRIVE, CHANGE OUT SPINNERS, AND SLIP AND CUT DRILL LINE. ADjUST BRAKES. FINISH RIH WITH HOLE OPENER TO 13014'. NO PROBLEMS. REAM F/ 13014 - 13088'. STILL PACKING OFF. RE-REAM SECTION 3 TIMES. INCREASE MUD WT. REAM F/ 13088 - 13301'. NO MUD LOSSES. PUMPING HI-VIS SWEEPS EVERY STAND. POH TO RUN CASING MW: 0.0 VIS: 0 REAM F/ 13301 - 13406'. NO PROBLEMS. PULL 4 STANDS AND REAM BACK TO BOTTOM. NO PROBLEMS AND NO MUD LOSSES. CIRC HI-vIS PILL AROUND. MONITOR WELL AND PUMP PILL. POH TO CASING SHOE. TIGHT SPOT @ 12250 - 12030'_ MONITOR WELL AND SET STORM PACKER @ 77'. PULL WEAR RING AND SET TEST PLUG.. TEST BOPS. PULL TEST PLUG AND INSTALL WEAR RING. PULL STORM PACKER. THAW OUT CHOKE LINE AND BLOW DOWN SAME. RIH TO 13331' NO PROBLEMS. CIRC AND REAM F/ 13331 - 13406'. NO PROBLEMS. PUMP HI-VIS SWEEP AROUND. CIRC AND CONDITION MUD FOR CASING SPOT TERMA-THIN AND SOLTEX PILL ON BOTTOM. MONITOR WELL AND PUMP PILL. POH TO RUN CASING. WILL LAY DOWN DP AFTER CASING HAS BEEN RUN. RUNNING 7" 26# CASING MW: 0.0 VIS: 0 POH. LD BHA. PULL WEAR RING, CHANGE TOP SET OF RAMS, TEST DOORS. RUN 7" CASING TO 2455' THAW TOP DRIVE AND LAY DOWN LEFLEUR FILL UP TOOL. REPAIR LINK ADAPTER PLATE ON TOP DRIVE. RUN 7" CASING TO 4094' AT 1 JOINT PER MINUTE, CIRCULATED, NO LOSSES. CONTINUE TO RUN 7" TO 7000'. FILL EVERY 5 STANDS. TEST 3 1/2" RAMS MW: 0.0 VIS: 0 RIH AND LAND 7" CASING TO 13386' CIRCULATE. PUMP 5 BBLS _ H20, TEST LINES, PUMP 15 BBLS H20, 70 BBLS SPACER, 26 BBLS CMT, 4 BBLS H20, DISPLACE W/ RIG PUMP. BUMP PLUG. FLOATS DID NOT HOLE. HELD 1000 PSI ON CSG. RELEASE PRESSURE, FLOATS HELD, LOAD CLOSING PLUG. OPEN ES TOOL, CIRCULATE. TEST LINES. BACK OUT LANDING JT, R/D CASING EQUIP. INSTALL PACK OFF. CHANGE TOP RAMS AND TOP DRIVE TO 3 1/2". P/U TEST PLUG AND TESTING RAMS. RIH, P/U 3 1/2" DP MW: 0.0 VIS: 0 LAY DOWN 5" DRILL PIPE OUT OF DERRICK. CHANGE ELEV. AND IRON ROUGHNECK OVER 3 1/2" DP, THAW OUT AND RABBIT 3 1/2" DP. M/U BHA #6. P/U HWDP. REPAIR END COVERS ON SPLINE COUPLING OF TRACTION MOTOR "A". RIH TO 1160'. TEST MWD. POH, CHANGE OUT MWD, CHECK SPERRY SUN TOOL. RIH PICKING UP 3 1/2".DRILL PIPE TO 4110'. SLIP AND CUT DRILLING LINE. RtH W/ BHA #6, P/U DRILL PIPE. RECEIVED MAR 2 8 1995 Oil & Gas Cons. Commission Anchor~~ ,. : MP E-10 OPERATION: RIG : NABORS 22E PAGE: 5 12/25/94 (20) TD:13416' ( 10) 12/26/94 (21) TD:13545' ( 129) 12/27/94 (22) TD:13575' ( 30) 12/28/94 (23) TD:14004' ( 429) 12/29/94 (24) TD: 14225' ( 221) 12/30/94 (25) TD:14225' ( 0) DRLG 10' OF NEW HOLE MW: 0.0 VIS: 0 RIH P/U 3 1/2" DRILL PIPE. DRILL OUT ES CEMENTER, CIRC RUBBER OUT. CONTINUE P/U DRILL PIPE, TAG LC. DRILL OUT LC AND 42' OF CEMENT TO FC. CIRC AND COND MUD. TEST CASING. DRILL OUT FC AND 15' OF CEMENT. RIH. DRILL OUT SHOE AND 10' OF NEW HOLE TO 13416'. DRILLING AHEAD MW: 0.0 VIS: 0 DRILL 10' OF NEW HOLE F/ 13406 - 13416' CIRCULATE. DRILL F/ 13416 - 13453'. PULL BIT TO SHOE, C~ANGE OUT TRANSDUCER ON STAND PIPE. DRILL F/ 13453 - 13545' RIH W/ NEW BIT MW: 0.0 VIS: 0 DRILL F/ 13545 - 13575' POH FOR BIT AND MWD. L/D ANADRILL MWD SENSOR, CHANGE OUT BIT. DOWN LOAD SPERRY SUN TOOL. LOAD LOGGING TOOLS. RIH, CHECK SLIM 1 MWD @ 13487', RIH. DRILLING AHEAD MW: 0.0 VIS: 0 RIH'WASH AND REAM 30' TO BOTTOM. DRILL AND SURVEY F/ 13575 - 13743'. HOLE TIGHT DUE TO CUTTINGS, PUMP HI AND LOW VIS SWEEP, CLEAN HOLE, CHECK FOR FLOW. DRILL AND SURVEY F/ 13743 - 13930'. CIRCULATE AND CONDITION MUD. DRILL AND SURVEY F/ 13930 - 14004'. CIRC AND COND MUD MW: 0.0 VIS: 0 DRILL AND MWD SURVEY F/ 14004 - 14225' CIRC AROUND HI/LO VIS'SWEEPS. MONITOR WELL. PUMP PILL. POH TO SHOE. RIH. NO PROBLEMS. CIRC HI/LO VIS SWEEPS. HAD AIR/GAS CUT MUD W/ TRACE OF OIL AT BOTTOMS UP. MONITOR WELL. POH W/ 30 STDS. TIGHT HOLE AT 13727 AND 13656'. ACTS LIKE A LEDGE. MONITOR WELL. WELL IS STATIC. RIH SLOWLY. NO PROBLEMS. CIRC AND CONDITION MUD TO RUN LINER. RIH W/ 5" LINER MW: 0.0 VIS: 0 CIRC AND CONDITION MUD FOR LINER. HAD SMALL AMOUNT OF GAS/OIL. CUT MUD AT BOTTOMS UP. PUMP PILL. DROP DP RABBIT. POH TO SHOE. MONITOR WELL, OK. CONT POH TO 5500' CUT AND SLIP DRLG LINE. REPLACE STUDS ON DRAWWORKS. CONT POH. DOWN LOAD LWD. LD MOTOR AND LWD. RIH AND LD BHA WHILE PROCESSING SPERRY SUN LOG. RU TO RUN LINER. PU AND RIH W/ 22 JTS 5" LINER AND HANGER/PKR. RIH W/ .5" LINER ON 3 1/2" DP. FILL PIPE EVERY 10 STDS. RECEIVED MAR 28 1995 Ai~sk~ Oil & Ga~ Cons. Commission Anchor~ : NiP E-10 OPERATION: RIG : NABORS 22E PAGE: 6 12/31/94 (26) TD:14225' ( 0) 01/01/95 (27) TD:14225' ( 0) 01/02/95 (28) TD:14225' ( 0) 01/03/95 (29) TD:14225' ( 0) RIH W/ 6" BIT & SCRAPER MW: 0.0 VIS: 0 FINISH RIH W. 5" LINER TO SHOE. FILL PIPE EVERY 10 STANDS. CIRC. MU CEMENT HEAD AND STAND BACK SAME. RIH W. LINER TO 14225'. CIRC AND WORK THROUGH TIGHT HOLE F/ 13872' TO TD. CIRC AND RECIPROCATE PIPE FOR 3 ANNULAT VOLUMES. TEST LINES. BUMP PLUG AND PRESS DP. BLEED OFF. ROTATE AND RELEASE FROM HANGER. STING OUT OF LINER. REVERSE OUT SPACER. NO CEMENT VISBLE. RD CEMENT HEAD. POH 10 STDS DP. CLEAR FLOOR. PUMP PILL. POH W. DP AND SETTING TOOL. PULL WEAR BUSHING. INSTALL TEST PLUG. TEST BOPE. INSTALL WEAR BUSHING. MU 6" BIT AND SCRAPER. RIH. POH F/. POLISHING MILL MW: 0.0 VIS: 0 FINISH RIH W/ BIT AND SCRAPER. TAG LINER AT 13239'. CBU. POH W/ BIT. CLEAR FLOOR. RU 2 7/8" TOOLS. PU BHA. RIH TO TOL. CIRC AND ROTATE THROUGH LINER, DRILL OUT 74' CEMENT TO LC @ 14084'. CIRC AND CONDITION MUD. BLOW DOWN TOP DRIVE. TEST LINES. CHECK SURFACE EQUIPMENT, OK. RETEST. BLED. CBU, MONITOR WELL. PUMP PILL. POH. SLM. POH W/ POLISHING MILL MW: 0.0 VIS: 0 POH TO 7606' CUT AND SLIP DRILLING LINE. RIH TO TOL. CIRC AND CONDITION MUD. POH W/ 4 1/4" MILL. RIH W. BAKER POLISHING MILL ON 3 1/2" DP TO TOL. POLISH TIE BACK SLEEVE. CBU. POH. CLEAN UP HYD FLUID IN SUB MW: 0.0 VIS: 0 POH W/ POLISHING MILL. SERVICE WEAR BUSHING. MU PKR AND SEAL ASSEMBLY. SERVICE TOP DRIVE AND GREASE CROWN. RIH W/ BAKER PKR AND SEALL ASSY ON 3 1/2" DP. STING INTO TOL W/ SEALS. RU TO TEST LINER LAP. PRESS ANNULUS. BLED TO 2000 PSI INSTANTLY. OPEN RAMS. PRESS DP AND INSIDE LINER. HAD COMMUNICATION TO ANNULUS. SET PKR ABOVE TOL. PRESS ANNULUS. HAD SMALL COMMUNICATION TO DP. RELEASE PKR. PRESS ANNULUS. PUMP INTO TOL. CONFIRMED LINER TOP IS LEAKING. CIRC AND CONDITION MUD. MONITOR WELL. PUMP PILL. LD SINGLE. POH TO LAST STAND DP. HYDRAULIC LINE TO HCR CHOKE VALVE BLEW. REPAIR LINE. REFILL ACCUMULATOR, CLEAN UP HYDRAULIC FLUID IN SUB BASE. RECEIVED MAR 28 1995 Oil & Gas Cons. Commission Anchor~ : MP E-10 OPERATION: RIG : NABORS 22E PAGE: 7 01/04/95 (30) TD:14225' ( 0) 01/05/95 (31) TD:14225' ( 0) 01/06/95 (32) TD:14225' ( 0) 01/07/95 (33) TD:14225' ( 0) RIH W/ 4 1/4" MILL MW: 0.0 VIS: 0 FINISH POHW/ PKR AND SEAL ASSY. SERVICE WEAR BUSHING. LD 3 1/2" DC'S. RIH W/ BAKER LINER TOP ISOLATION PKR AND SEAL ASSY. STING INTO LINER TOP @ 13241' PRESS DP TO 3000 PSI, HOLD. PRESS DP TO 4500 PSI TO SET PKR. BLEED OFF AND RELEASE SETTING TOOL. PRESS 7" CASING AND 5" LINER. TOP PIPE RAMS LEAKED. HELD. BLEED OFF. RD TEST EQUIP, PUMP PILL. POH TO 7167' CUT AND SLIP DRLG LINE. REPLACE WASH PIPE ASSY. FINISH POH LD SETTING TOOL. INSPECT TOP PIPE RAMS. HAD WASHED RUBBER. REPLACE SAME AND INSTALL PIPE RAMS. PULL WEAR BUSHING. SET TEST PLUG. TEST PIPE RAMS. RE-INSTALL WEAR BUSHING. RIH W/ 4 1/4" MILL ON 3 1/8" DC'S, 2 7/8." DP AND 3 1/2" DP. RIH W/ TCP GUNS MW: 0.0 VIS: 0 FINISH RIH W/ 4 1/4" MILL TO LANDING COLLAR. CBU. PREP FOR CSG WASH. PUMP 30 BBL H20, 30 BBLS BAROVIS, 60 BBLS DIRT MAGNET, 30 BBLS BAROVIS, 120 BBLS H20 FOLLOWED BY 10.2 BRINE. CIRC AND FILTER BRINE. ADD 25 GALLONS/100 BBLS CORROSION INHIBITER. DROP RABBIT. POH W/ 3 1/2" DP. LD 2 7/8" DP AND DC'S. RIH W/ ATLAS TCP GUNS, 2 7/8" TBG, HALLIBURTON CHAMP PKR ASSY AND 3 1/2" DP. POH, CHANGE TOOLS MW: 0.0 VIS: 0 FINISH RIH. CHANGE BAILS. RU WESTERN ATLAS. RIH W/ 1 11/16" GR/CCL W/ 2 1/8" WHEELS. UNABLE TO WORK TOOL BELOW. RD CIRC SUB AT 12361' POH. REMOVE WHEELS. RIH W/ 1 11/16" GR/CCL TO TOP OF TCP GUNS. CORRELATE DP MEASUREMENT TO SPERRY SUN LOG. 1' CORRECTION. POH. RD ATLAS. SPACE OUT DP. SET PKR. OPEN BYPASS. TEST ALL SURFACE LINES. DISPLACE DP W/ N2. CLOSE BY-PASS. PRESS ANNULUS, PRESS DP TO FIRE FUNS. MONIOTR PRESS, BLEED TO FORMATION. RU ATLAS. TEST LUBRICATOR. RIH GR/PRESS TOOL. LD 2 7/8" TBG MW: 0.0 VIS: 0 RIH W/ PRESS TOOL TO 12150'. UNABLE TO. WORK TOOL DEEPER. MONITOR PREE. TAKE READINGS AT SEVERAL INTERVALS. POH. RD. RU SURFACE EQUIP. OPEN BYPASS. BULL HEAD 25 BBLS DOWN ANNULUS. REVERSE OUT N2 F/ DP UNTIL 10.2 BRINE AT SURFACE. CIRC CONVENTIONAL THROUGH CHOKE TO REMOVE N2. MONITOR WELL. WELL IS STATIC. CBU THROUGH FLOW LINE. MONITOR WELL, OK. PUMP PILL. POH TO DC'S. CIRC OUT N2 THAT IS BREAKING OUT OF GUNS. LD DC'S AND PKR ASSY. RU 2 7/8" TBG EQUIP. RECEIVED MAR 28 199,5 A!ask~ Oil & Gas Cons. Commission Anchor~ : MP E-10 OPERATION: RIG : NABORS 22E PAGE: 8 01/08/95 (34) TD:14225' ( 0) 01/09/95 (35) TD:14225' ( 0) POH LD 3 1/2" DP MW: 0.0 VIS: 0 LD 2 7/8" TBG AND GUNS. ALL SHOTS FIRED. CLEAR FLOOR. RD TBG EQUIP. RIH W/ BAKER 7" FB-1 PKR ON A J - HYDRAULIC SETTING TOOL. DROP BALL. SET PKR AT 13199'. CBU. PUMP PILL. POH. STAND BACK 49 STANDS. LD REMAINING DP. RIH W/ BAKER 7" WLR BRIDGE PLUG ON A J - HYDRAULIC SETTING TOOL. DROP BALL. SET PLUG AT 4500'_ TEST SAME. CIRC WELL TO BALANCE BRINE WT. POH LD 3 1/2" DP. RELEASE RIG MW: 0.0 VIS: 0 FINISH LD DP TO 2115'. FREEZE PROTECT WELL. SLIP AND CUT DRILLING LINE. FINISH POH L/D DP. PULL WEAR RING AND INSTALL FALSE BOWL. CHANGE TOP RAMS TO 5" AND N/D 13 5/8" BOPS. NU 7" FULL OPENING DRY HOLE TREE. PULL BPV AND TEST CASING AND DRY HOLE TREE. INSTALL BPV. CHANGE TOP DRIVE TO 5" AND FREEZE PROTECT 9 5/8" X7" ANNULUS WITH 90 BBLS DIESEL. RELEASE RIG @1900 HRS ON 01/08/95. SIGNATURE: (drilling superintendent ) DATE: RECEIVED t~/~R 2.8 199~ ~i~ka Oil & Gas Oons. commission Anchor~ ' M'ICROFILME ) ~,, .... l/Z/b/ ~.. ... RECEIVED NOV 2 6 1996 Alaska Oil & 13~s OonB. Oommission Anchorage ~dX.',. O0 100,0 59?,94 ~00,00 1(0,0 7f?,42 I(<0,00 100,0 ?97.85 1100.(0 lOO,O 10~S.53 12(~,00 i00,0 1194.3B 13~,00 i¢~,0 12/YI,13 14~3.00 100.0 20~.75 2162,~6 35&9.00 1~.0 2S51..A8 36~).00 100.0 2896.$4 37(¢.(~ 1~3.0 2742.10 .25~,00 : ICO.O- 2~Y87,14 TAE~: S?AT I ~N AZ:MLql4 LATITL~:E ft deg. deg ft ' 0,~3 0,00 0,(0 C-,O0 -O,z, 0,27 ~'=~ =' -0,,1 O..~. 347.0? 1.21 -0,54 0.26 17.47 1.76 ft -0,¢~ -0,!7 bLS deo/ ft deq ' t,r',':.- 0,00 0,00 0,(~ ;';,20 34~.,76 ,,,~.0 O:,Z,3'? 0,06 1,22 352.07 0,14 · ~,.,: .2~ 0,22 0.41 '" 1,11 65.21 2.05 O.&6 2.23 22.57 1.04 ~.J~ 2,51 '~ ~ Y~.,4v 1,90 4.C~ 4,42 ~,62 1,44 9,30 ~,!4 97.95 1,~ 9,75 9,~2 63,26 1,63 "~= ¥*',q~ 0,(G' 17,9~ 17.95' 89.71 1 ~= 26.dj 7.3~: 9~.61 -1.42 28.93 18.97 92.81 1.72 42,Z? 6,47 9~,12 56,E~ 10,36 !02,~7 · ~,=- 100.81 104.29 15,96 ??.64 15~,91 18,53 97.20 -3,41 42,51 .~..~ 94,59 1,17 -6.4~ ~a ~ -- - .~..~ >6,9'~ 96,29 2.~ - -10.61 78.0 70.~, - 97.69 2.93 -iS.O^ .... ~OJ,4: 104 ~ 98.29 2,72 - - .2£ -19,?1 laZ.b., i~.15 96,53 2,57 1..7,~, 2!,23 -w.60 ~D5,~ 23.70 _ ' 97,03 247.84 26,~ . 27i,96 26.63 L~J.lv 97.55 . -F5.47 -30,95 · _s- -40,87 245,74 t..6. Bt) ~4,95 ~r?1.76. ,, ~8,36..:,-... 511.!? 576.02 41 6q:.,.~ 43,50 - ~i',77 -.54,9A ~ 91' : .-. . - - · .. ~d, ic~,5'5 -M.TB ~ I01,25 -76.4B !~.62 -8S./-7 570,02 $q,42 -100,5i 16~.15 9~,71 ? -~ ~/U 246.E5 98,32 2.31 2~2.E~ 96.03 0,65 340,15 97,88 3,52 . :' 3i~.73 · ??,?? 450,34 98,27 3,73 Si2.~^ - ~'~ 5'6,~' 576,89 '?8,2.5 2,24 644,44 96,77 2,14 713.67 '= A" ~J../ 766,5i ~- 47,90 1020,99 55.91 --99.64 .. 100, ~.J.: 10) .30 100,~_0 102.04 '-112.26 705,76 -125,22 /-77,47 "-13~,~?' '651,54 -153,1~ .... -167.26 !(Q7.~2 714.63 99,04 2.1~ 767,47 ~" <= 662.7? 99,26 1,5'7 · ,~,,~ ??,~? lO21.'~j 5'9.53 3.36 ll(q.~4 56,15- 101,72 -1S5,5q 1089,91 '1190,74 60.1~' 102.65 -~4.A7 "-' ~ 12_78.45- 62,45 101,74 -223.20 1255',57 1367.52 63.,~ !~.90 -240.65 1346.91 1456.% E~.47 100.04 -256.94 142a.90 ~= -/ 5'.? lk .... /., ,71 2,26 i!~I'.54 99,~9 2.1~ 1279.20 1(O,05 2,41 136~.25 D0,1S 1,27 14~,72 1~,!5 0,77 154&21 63,~ 59.44 lEiS,3! ~2,~ 99,93 -2B7,C~ 1724,51 63,~ 101.20 -303.4? 1813,.~---~J,24" 97,82 ' '-31~,7F 1903.29 64,27 !C~,02 -q~5,22 152_2.73 1610,)2 I698,52 17&~.,31 Ia.74,65 1547,('~1 100,13 0,66 I.~,,21 l(O,11 0,48 1725,42 100.13 1,10 I~q14,70 100,15 1,23 1904,39 100,14 1.05 5010,Cr0 5040 5070 51'00,;~ 51~9,00 5!70.~ .. 5~Q.CO IHT~JAL VERTICAL DEPTH lOO,O C~074,~ 110,0 3121,~ C~,O 3t~4.21 34,0 3146,51 '~,0 3t56,75 T~GET ~ATi--3H ft deg. 19~, 47 64,42 2~)2,~ 64,97 21~,13 65,67 2147,47 65,93 2174,87 65,66 30,0 3171,~.) 2202,26 .~.3,0 3183,25 2229,64 65,83 ~o.O 31~5,56 ~.t~5..-'.~B65,69 - '~-- '~ i~ ~'~'~ ~.0 370;,c<. a:~4.'.j: 65 30,0 32~0,11 2311,73 ~..06 30,0 2252,3J ~,O 3257,(75 30,0 5-Q,O 32~,69 S~..O ~2~5,76 3-'3,0 3317 30,0 ~42,66 7_-K),O ??.,4,30 30,0 .~3,0 32,76,78 2-0,0 ~90,70 30,0 :--.;402,53 2.~9,10 65,97 ~.>~,42 65,50 2.3q3,72 65 2421,07 66,02 2446,47 66,07 .. 2475,8? &S,08 2..503,35 25~,78 2558,09 2612,8I .,~$,27 2.M0,27 &5,56 2E47,76 66,42 26?5,26 &6,76 2722,73 66,79 30.0 3414,34 2750,33 6.5,76 ~8.0 3426,16 2277,8? ~66,91 3Q.O 3437,?3 28~C6,44 &5.71 ~,0 3447,7! 2833,01 66,~ --q,q,O ~4A . . _. ~ .1,43 2&~O,A1 67,17 AZI~.rfH deg I01,14 !~,04 100,94 1CQ,SO LATI?dDE ft -3~ · .,., ,,,., ,, e -374 9EF'AF',II.$$ DISPI~Eh~ at E/-W ft ft !963,43 1994,53 £~61,2C.., 20'~,~7 2114,51 2148,54 21~1,40 21/-'5,~ 101.14 -o/z,27 ~..:<:,~ 2203.31 101,43 - 576,,.~3 2:75,15 !01.26 -a.?2,01 2~'~ !.97 2258,04 101,06 --v-'j7,3! 2'2,.{8 ,.'-'.0 ~.5,~? 7. '39,0 3473,15 2888,20 -56,:_a.3 30,0 3435,16 ~?!5,,~J ' S6,00 30,0 349-7,32 2'743,08 6.6.17 30,0 35CG',.44 '~='. ="- AA.lA £~.. kY*iV .. . 30,0 3521,57 2997,'72 ~. O~ 99,53 1CQ,35 1~.13 ICC,Z? 101,74 1¢~.62 '~.51 ¥,7£ -416,54 -470,97 -425.66 -4~,55 -4S5,53 -4~5 -45!',33 -456,!7 23'29,81 2356,71 2410 ' ~mO ;'~.:,7 24.A4,43 249I,~ ~_-s!8,28 ~J4,5,2! 22~7,54 2394,85 2422.21 2449,63 ~04,50 253!,74 2586,5? 30,0 353-3,75 30,0 3545,76 JC62,74 ~5,90 30,0 3558,29 3C44',07 ~5,54 30,0 3570,76 3!~7,35 . 65,35 ~,v .~.~,29 61 65 W,03 -474,53 -475.74 -483,17 2~2,25 .',fi,37 2.'-..2.5,4? 2653,67 2,.-%0 2614,02 2641,51 2669,02 2696,54 2724,10 iOQ.20 $8,63 1CQ,11 -4'F2,43 -496,75 -501,35 -506,!4 2705,07 2735,27 s'762,53 ~'7'20 .~ ,.,,,73 2751,67 2806,54 2834,43 2562,04 99,69 9? I01 -510 -515 -52~, 18 -524,75 2871 2::'?8,26 2525.~ -2_952.30 3~87.66 2717,15 2744,57 2972,01 !0!,17 101,$1 !00,88 -535 -545,26 ~-550,46 -555,83 2?7?, 2:.) ?C.96,10 3032,S'9 · ' ,,'-K'=' 7 -.:.,,.., / ,7: 3~,5.S,50 3026,~ 3081.61 31~,!4 AZi,UTH deg. 100,!3 100,18 103,21 100 100,~ 100,2.6 100,2.7 100,~ 100,24 1®o24 100,24 100,24 :00, .26 !00,17 lt,0,26 tOO 100,25 10,} 100,22 1®,21 t00,21 tOO,t? !03,17 100.16 1.90,18 10<).17 100,17 100.18 100,19 i(X),i? DLS d~/ 0,!7 i,!! ?, O? 0,46 1,07 0,98 0,70 0,7~ 5.38 0,..-'~. 2,00 2,5t 1,58 2,02 2,89 3,59 4,70 2,59 1,21 . 2,21 · 3,82 6,55 4, .32 1,5'3 4,84 2,24 1 !,37 t,'.:4 0,77 0,49' 4.4,5 0,16 1,14 2.41 5754,C0 5847,¢0 6~4,0:?. 6317 64.12.00 6&Ol,O0 67'5'1 6978~00 7072 : - 71.A5,C0 · 7260 7355,,CK.~ 7450,0C, 7545,00 ?~O.Cro 773-5.00 7628,00 7923,00 8016.00 8026,22 81EQ,40 SECTIO~ ft '"j ' l ,..]...1 3243,26 ,5970,65 D3,O 355E,,S5 3296,14 35,o .,6, 0,,,., 62 -'_<).0 E~..~.2.25 2.~53,!3 ~'""- ,.,~..,..y.~ ! 'o,..) c-.,,0 3674,17 ':.,'~r, 45.0 3712,25 3421 95,0 37_=0,67 398.69 94,0 37~6,60 3594,E6 93,0 3826.06 ~,79,78 55.0 3664,40 37,.%.69 94.0 3902,~ ~8,52,~ 96,0 3~77.18 4024.26 ~.0 0)17.I5 4109,15 95,0 4055,49 4!96.(~ .-,= .. 44~3,c:v ~o.v .. 42~3,15 94,0 4130,55 %,0 4165,21 95,0 4205,66 5~.0 4243,10 4369,47 4456,69 4543,90 4629,11 '4715.g:/ 94,0 4317,¢Y? 4E;01.84 94.0 4~2.'77 4M~,.65 94,0 474.9,11 4975,40 95,0 4426,00 ':/5,0 4¢f,2,~,2 5i50 95,0 4499,4i 95,0 ' 4537.14 95,0 4575,93 %.0 4613,69 95,0 4652.40 S'i'ATIDi AZiML~H LATITUDE ]NCLN, deg deg ft g,77 !~0,93 -560,77 6~.~ 102.37 .A4.,5~ 99,94 -571,70 65.53 103,50 -576,53 ~6,53 ~9,~3 -581,27 ~FJ AF:,U%. DiSF'LAC~ENT at E/-W ft ft 3113.20 3139.79 3190,47 3193,17 oZ2v,17 ~.4,51 99',43 -5%,71 66.67 100,17 -595,39 /:-.%51 100,33 -600,~9 66,10 I¢O.EO -607.85 3247,27 3274,36 '~'::fi I ,fl? 329'?,71 33Z7,22 33.=.4,75 *.'4,20 6/;...~ 66,10 99,~ -623,23 3454,60 lOt,~J -~8,91 3539,16 101,50 -655,8i 36~,59 101,10 -672,84 3707,~13 102,10 -6~,11 3791.98 5 .10, 37 3596,37 3E41,48 376P~,.% 3°,54,27 66,10 65,60 66,D ./v5,20 !02,50 -7(,¢.02 ~,74, !03,10 -77.7,43 101.40 -745,44 404.2,51 100,50 -761,95 41Z7.B4 1,.%,80 -778,05 42!3,% 40F._.5,51 41!0,66 4197,58 42,~4,70 ~3.0 4690,75 55,2 4735,21 94,6 4774,40 $5~l 4813,61 66.70 66,60 66,20 lOl,F.,~q. .-794,60 4??6,20 i01.10 -811,54 43,~3,75 I01,20 -g2,5,40 44..:..9,~ 103.i0, .~a~?..,,'~,~., 4552.64 99,70 -6C::, 37 4637,i2 4371,03 4458,24 4545.45 46D.63 4716,51 67 67,60 67 .D 67,10 $"?.~ -87-/. 89 4722,52 55',90 -892,.t0 i01,00 -9,;tB, 3~ 4E.73,48 101.90 .o~,,_.,,...?o 4979,28 1(.0.30 -94~,57 4803,42 4~.90,2'? -49~,07 5(,64,60 5152,17 5325,31 5411.94 54%,E5 ~S3,56 67, ~,00 ,.%.10 65,80 102.5(, -959,90 5151,i5 9?,20 -975,33 52~,,76 99,50 -t90,41 53."?,~ ~%.50 -1(X~1.44 101,10 -1019,95 5471,51 5Z55', ~3 532~,00 5413,70 5498,67 55~5,42 5765,69 5951,~ 5935,16 65.50 65,53 65.58. 65.81 98.30 -107~,23 55:,:,01 97,41 -10~5,75 5%6,03 97.65 -1047,10 5671,9~ -9~,46 ' -1059,i7 5757,23 91,61 -1072,C~ 5842,95 5470,13 5767,7E 5553,55 5940,48 AZIM~H 100,23 1(K~.23 !00,23 100,23 100,22 100.23 100.23 100,26 1(0,31 1N),41 100,45 100,% 100.46 1C13,47 100,4'? I00,53 10),53 100,52 100,53 100,55 190 ~. ~ !0:o.53 l(g: 100.51 1C0,50 100,46 100,42 100,40 r',l r. de-a/ 1C?;ft 1,71 4 7 ,% c,,56 4,66 2.77 2,77 ! '7*', O,y 0 1 .c-~ 1,16 1.75 0,15 0,44 0 0.4i 0,~ 1,79 0,67 0,69 0.~2 0,i4 0,75 0,31 1,16 0,88 !,57 2.1'( 3,61 0.36 0,11 1._,=7, 2,76 6,6! 0,23 0.77 0,3.5 f~ fr 8503.41 %,3 85'?~,~ 93.8 ~8~.9~ - 94,7 4'?~.% 8784.42 95.5 50¢02,28 ' 6&50.09 69'73,6? 9x)67,~ 9~.A,61 9~2,:~ - .9445, !3 9546,26 9634,46 7<. 10101,97 !0!97.17- .] '. !02"/2,46. - .. 103~.~,45 10575,~? 10762, !4 106~.47 10950,77- 11C44. 43 !1!37,.W 1!£~5.67 11424.75 I!519.55 lAC;O~ STATI'~ S~C3I~ fr' 6020,93 65,85 61~,74 6194,42 66,55 6251,07 63.~.,74 67,22 95.7 5039.05 6456.78 '?3.6 50,'5,516542.72 66.56 93.6 5!12.~3 &~23.43 66.6¢ 95,7 5151,2~ 6715.a6 65,61 ~.o.6 5189.46 - ~)l,Z7 &5.31 55.7 5~.7;65 92,8 5265,41 ~.1 5:D4,60 94,2 5343,20 92.4 5340,41 _ 93.2 5418.64 94.3. ~58.01 ~,.3 5497.81 '~.3 ~37.58 55.2 5577.~7 -6973,61- 70,50,14 71.46_ ,01 7~,,6 73!5,29 7400,94 7570,75 7657,02 9~,3 5617,46_ 7743.54 94,0 5656,42 7829,05 94.4 5695.0~ /,1~,~ 94,4 57~.06 '?~,5 5770,1! 8087,23 9~.4 584,6,43 8173,12 94.3 ~M3.63 94.3 5882,02 94,1 5719,70 a431,89 93.2 5957,~, ~ 8517,1A_ AZI~dTH LATITUDE 98,59 -tOM 96,89 -1¢96 .97.45 4107,02 97,53 '?7.M -11~,12 ft ft 5924,94 6023,36 ~312,19 6111,32 6057,51 6197,18 6183,6~ 62~,~ 6270,8i ,5371 .~.3 AZI~JTH DLS deg lOOft 100,37 0,02 1¢4,33 1 !~M,Z~` 0,62 100,~ 0,25 100,22 0,55 97,7 59?6,80 8606,14 94,8 ~4~,78 ~672,~.S 94,3 ~75,30 8777,81 94,8 6115.~ ~4&3.4! ?4,6 61~,/5 3949,07 93,4 6194,58 '~,7 62'13,11 96,2 69_72,3~ 95,6- 6311,17 93,7 00.¥,20 65,34 65.75- 66,37 _ 65.16 65,50 64,94 96,91 -I141,45 6353,41 64E4,05 .98,09 -1152.70 6443,87 0546,1~ I:)0,14 1,..~. 95,Z7 '-I!64,92 65%.'~ &~32,01 100.12 0,~ 100.07 -1~7~,8/ ,%t5, 6719,54 L00,z0 2,05 95,76 -!!92,85 66%',67 &505.03 l~,lO 1C4,26 9),19 -_ - t2,-.'4,46 67.?.6,56 M92,77 L'.>J,06 0,49 -1220,74 6~.9,93 6977,55 100,08 1,81 -tTJ5.27 6955-.,20 7064,14 100,07 1,23 '-12¢~,17 7040,35 715,0,14 100.05 0.5 -t2,~.4,817124,{~ 7~34,71 100,04 0.83 : 65.37 &5.4i 66.88 . '-7'7.99 !00.75 '-}"9 99,53 67,34 ~.4,32 "": 28 -' "" . b>~.45 -1.:.:. ;&i.95 .. :77.148,16 100.29 -13;..J,6777i4.10 7~,70 1C"J,63 -1~7o....,'~-:.:.. .77,'98,35 7919 59,S~ -!o'74,30 78.53,94 &~%, 1C~J ,03 1 1,>~ ,02 0,76 !':.~.03 1 100,03 1,2! 100.02 65,5'? 65,85 64,59 64,82 65,28 95,73 lC~.~ 98,79 101,i5 '70~,,_.,~7 '?119,21 ';S<:,6, '?5 -9?.;4 %:79.85 65,57 65,93 65,94 56,17 65,97 tO0,02 0,88. i~X~ ,03 0,3..~, LryO ,03 0,53 !';.Q,03 ! ,31 :.)0,02 1,01 -14~,40 $(h53,77 8178,C~ 100,00 0,59 -14.34.76 6139,18 8264,67 100,¢O 2,21 -!~9,12 8~4,19 83~,~ 99`,~k 1,58 -1¢M.04 gc.c~._.,, ,n7.,. M37,06 ~,99 2,30 -i475,29 ~3~.22 85~,42 '??,99 97,40 -14'¢3,51 8461 99',03 -1502,85 85,'.",7-, 1 ! $.6'97 ,':/2 98.26 -1515,72 " c~..~1,74 99,~ -1528,M 8,73~,, 98,46 -L542,10 99,35 -!555,25 '5'8,73 -i5~,66 8989,51 9125,35 r,O t ~ ~ ~09 ")7 ..'., ,., -i...,; ..... '?076,2~ 'F213,24) '5'2.,06 -.;~.,~t '?"...q ?300,77 99,2,~ -1605,43 9247,52 73&5,35 99,97 99,94 1,53 '79,93 1,05 99,'~ 0,97 '?'?,91 '?9 .'?0 0,70 '??. 5? 0:43 9'?,88 l,r'~ '?'?. ~7 1,20 RECEIVED NOV 2 6 1996 Alaska Oil & Oas Cons. Commission Anchorage DI~'TH ft 12176,74 12270.66 12459,65 12554,00 12649,09 t2_744,97 12840,49 12~34,,01 131z.,y4 1~14,56 13311,14 13412 1-3501 13~4,r~J !4103.,~ 14144,74 !42.75,CK) **~**.**** AJ~.DRILL 9]~J~ CA£CIF~AT iCeS ***~****** CIRCULAR · rNT~.VAL U~TICAL D~TH fr. ft B9,7 6385,44 93.? 6423,21 ?4,3 6461.2! ?4.7 94,4 6537,4B TAE~P.T S~ATIOH AZIMUTH LATII~Jl)P. SEC?ION INCH, N/-S it deg. d~ fr 9461,76 66,46 97.76 -1620,58 9547,56 66,12 98.64 -1632,85 9633,65 6~,33 $'.~,18 -1645,46 9720,21 66.13 'P~.56 -165~,~ 9~06,47 66,25 1~,02 -1,.473,51 DEBAR~~'~ DI~'L~ENT a~ AZI~EF~H D~ E/-W deg/ fr. fr deq lOOft 9328,67 91.~.~ ??,~ 1,65 7413,79 "7t54,35 '?9 ,~4 0,93 949?, 12 9640,58 $".;', ~3 O, 50 '95,9,4.78 9727,26 99,:.,_ 0'~ 1,36 ?~?,~4 98!3,56 59,~2 0,47 '~5,! 95,9 ~614,B~ ?5,5 ~53o50 93,5 ~,3 6729,5~ 96~o40 "65.~8 !01.66 -16B?,aj ~?~ n~ ~A,!4 1CQ,97 .-1707,09 !Os.X.6.35 66,19 $~,44 -17~,57 10153,~5 ~$,24 ~7,94 -17~,97 10240,95 66,~- 98.21 -[750,72 97b'5,23 9900,51 99,83 1,62 9841,15 9968,11 t).'24 0,70 '~..7,14 10075,q8 ??,84 1,46 !C.311,4~ i0161,~ 99,.M 0,49 1,X~7,Jt t0248,25 '~?,~4 !,66 ~..7 A767.03 10~5,54 ~2,6 ~Gf,52 104(79,71 96,6 .A848,C~ 10496,33 1~,9 68~5,25 1056_5.20 8?,0 $~7,'~ I~2.61 102,0 69~6,74 !0751,~ !01,2 70~6.82 lO~J,I6 · ??,8 7~6,32 99,8 7123,.,M .A6,06 9~,75 -17E~,22 64.~ 1C~,13 -!T/7,03 . 62,91 ~,61 -179!,90 6!,30 ii,BO -1803,B7 61,30 95,80 -!~11,76 61,:.q} 55.~ -1820.8I ~,,40 I00,~, -1~J3,4! ~,70 99.80 -1&63.69 54,59 1¢~,!0 10161,43 10332,96 99,~ 0,56 i0264,b'5 104!7,23 99,~2 10349.$5 10503,92' ¢?.~2 2,06 10438,2.5 105~Z,97 99,~0 3,70 10605,06 !07.$0,23 ?9,74 0,~ 10692,&3 10648 z .,.7 99.73 4,31 10777,29 b179S4,74 99,73 1,64 1¢0Y:.4,~ I1019,6! %',74 1,15 1~942,96 1t102,?$ 99,74 '41,7 80,3 7252,62 11174,37 53,!0 ... 10!,00...-16~,75 72.77,62 !!3)7,64 52,,~g !01,0) -!6~,26 7~ q-z lIL7~,.~ 52.~ !01,60 -!9i2,n? 1.1021,70 11,754,32 11116,76 ll!e3,CM 99,74 1,96 112!6,30 99,75 1,66 11280,02 ??,76 0,04 RECEIVED NOV 2 G 199G Alaska 0il & Gas Cons. commissiop Anchorage COMPANY BP WELL N~M~ MPE-iO LOC~TION ! MILNE POINT LOCAE[CN 2 ALASEA MA~N~!~ ~ECLINATIOH 29,01 DAT£: 12-D~C-94 WELL N~03~ 0 WELL H£AO LOCATION: LAT(N/-S) 0,00 AZIMUTH ?~OM ROTARY TA3LE TO TARGET IS TIE IN P3tHT(TIP) : INCLINATION 0,00 AZIMUTF LA?ITUD~(N/-S) 0.00 D~F'A~T~R~(E/-W) 0,00 ,MI'CROi:ILMED D£P(EY-~)) O,O0 102,00 RECEIVED MAR 28 1995 Oil & Gas Cons. Commission Anchor~ ' I:'AGE NO, MEASURED DEPTH 5565,00 5660,00 5754,00 5~47,00 5942,00 6036,00 612~,00 6224.00 6317.00 6412,00 6507,00 6601,00 669&,00 6791,00 6884.00 6978,00 7072,00 7166,00 726¢,00 7355,00 745¢.00 7545,00 764¢,00 7735,00 782~,00 7923,00 ~Ol&,O0 8028,22 ~12~,40 8218,05 5312,19 INT£RVAL 45,0 VERTICAL DEPTH 3712,25 SURVEY CALCULATIONS ~,~***~****** CIRCULAR ARC METHOD******** TqRCET STATION AZIMUTH LATITUDE S£CTIOH INCLN, N/-S 2421.85 66.10 100.80 %07.85 95.0 3750.67 3505.E9 66.20 99.60 -623'23 94.0 3788.60 259:.66 66.20 t01.40 -638.91 93,0 3826.06 367~.78 66.30 I01.50 -655.81 95.0 3864.40 37~6,69 66.10 I01.10 -672.84 94.0 3902.55 3852.60 66.00 102.10 -690.11 92.0 3939.90 2936.68 66.!0 102.50 -708.02 96.0 3979.18 ~24o26 65.60 103.10 -727.43 93,0 4017,15 4!>?,15 66,20 101,40 -745,44 95,0 4055,49 :i9~,06 66,20 100,50 -761,95 95.0 4093.37 42~3,!5 66,80 100.80 -778,05 ~4,0 4130,55 ~6?,47 66,60 101,30 -794,60 95,0 4168,21 4456,69 66.70 101,10 -811,54 95,0 4205.~6 4543.90 66,60 101,20 -828,40 93.0 4243.10 4629.11 66.20 I03,10 -846.34 94,0 4280.59 ~7!5,29 66,80 99,70 . -863,37 94,0 4317,09 4801,84 67,50 99,60 -877,89 94,0 4352.9? ~8~.65 67,60 99,90 -892,60 94.0 4389.11 4975.40 67.20 101o00 -908.34 95,0 4426.00 506~,94 67,10 101,90 -925,72 95.0 4462,82 5150,50 67,30 100,30 -942,59 95,0 4499,41 523~,16 67,40 102,50 -959,90 95,0 4537,14 5325,31 65.80 99,20 -976,33 95,0 4575,93 54!I+~4 66,00 99,50 -990,41 93,0 4613.69 54?6.85 66.10 99.50 -1004.44 95,0 4652,40 5583,56 65,80 101,10 -1019,95 93,0 !2.2 95,2 94,6 95,1 4690.75 4695,82 4735,21 4774,40 4813,61 5666,21 65,50 98,30 -1034,23 5E79,20 65,53 97,41 -1035,75 .,.:,69 65,58 97,65 -I047,10 5E5I,~4 65,50 98,46 -I059.17 593~,16 65,81 98.61 -1072,04 MPE-IO D~FA~TURE DISPLACEMENT at AZIMUTH ~/-W 3269.~9 3423.48 100.23 3~54,60 3510,37 100,23 3539,16 3596,37 100,23 3622,59 3681.48 100.26 3907.~3 3768.38 100.29 37~!,9~ 3854,27 100.31 3U4.13 393~.29 100.36 3959.55 4025.81 100.41 :C42.51 4110.66 100.45 ~7.84 4197.5~ 100.46 ~213.46 4284.70 100.46 42~B,20 4371,03 100,47 4~83.75 445B.24 100,49 4~9,33 4545,45 100.50 ~552.~4 4630.63 100.53 46S7,t2 4716.81 100+55 ~722.52 4803.42 100.53 48¢8.14 4890.29 100.52 :~93,48 4977,07 100,52 4979,28 5064,60 100.53 5C65.22 5152.17 I00.54 5[5!,[5 5229.83 100,56 5235,76 5327,00 100,56 5322.32 5413.70 100.54 5405.16 5498.67 100.53 5~!,51 5585,42 100,52 5575.01 5670.13 100.51 55~6,03 5681+24 100.50 ~;'~,93:.,, 5767.78 100.46 5757,23 5853,85 100,42 5~42,95 5940.48 100.40 DLS deg/ 1.32 1.16 1,75 0,15 0.44 0.98 0,41 0,77 1,77 0.87 0,69 0,53 0.22 0.14 1.92 3,38 0,75 0+31 1,16 0,88 1,57 2,14 3.61 0.36 0.11 1,57 2,76 6,61 0.23 0,79 0,36 RECEIVED MAR 2 8 1995 A~aska Oil & Gas Cons, Commission AnchorF. ' M£ASURED INTERVAL V£RTICA[ DEPTH DEP?N ft ft ft 5404,07 90,9 4850,83 8500,41 96,3 4889,._°~ 8594,25 93,8 4927,46 8688,91 94.7 4964,96 8784,42 95.5 5002,28 8880,09 8973,69 9067.27 9162.99 9256.61 9352,32 9445,13 954C,26 9634,46 972E,88 9820,04 9914,36 10008,70 10101,97 10197,17 10292,46 !0386,45 1048Co8) 1O575,29 I066~,75 10762.I4 !085E,47 10950,77 11044,83 11137,99 11235,67 11330,46 11424,75 11519,58 11614,20 11707,58 11801,32 11897,56 1t993,40 !2087,05 95,7 5039,05 93,6 5075,51 93,6 5112,63 95,7 5151,33 93,6 5189,46 95,7 5227,65 92.8 5265,41 95.! 5304,80 94,2 5343,20 92.4 5380,41 93.2 5418,64 94,3 5458,01 94.3 5497,81 93.3 5537,58 95,2 5577,67 95,3 5617,48 94,0 5656,42 94J4 5695.02 94.4 5733,06 93-~,, 5770.1! 93,4 5806.43 94,3 5843,83 94,3 5882,02 94,! 5919.7C 93,2 5957,01 97,7 5996,80 94,8 6035,78 94,3 6075,30 94,8 6115,83 94,6 6155,75 ?3.4 6194 To 93.7 6233,11 96,2 6272,38 95,8 6311,27 93,7 6349,26 *~o~********* ANADRILL ************** SURVEY CALCULATIONS *~*~********* CIRCULAR ARC METHO~******~* TARGET STATION AZIMUTH LATITU~£ S£CI!ON INCLN, N/-S ft deq deo ft E020,93 65.85 98,59 -1084,43 6105,74 66,28 96,89 -1096,29 E!9:,42 66,55 97,45 -1107,02 6281,07 66,78 97,53 -1118,36 c~o,,~ 67,22 97,54 '1130,12 645S,78 67,59 96,91 -1141,45 (542,72 66,56 98,09 -1152,70 6~-25,43 66,69 98,27 -I164,92 E~1~,86; .. 65,61 100.07 -1178,87 6~01.27 66,31 98,76 -1!92,85 E8%,90 66,65 99,11 -1206,48 6~73,~1 65,34 !00,26 -1220,74 7050,14 65,75 99,06 -1235,27 7145.01 66,15 98,19 -1248,17 7230,46 66,37 98,99 -I260,81 .:.~.:~ 65,16 99.30 -1274,31 7430,94 65,50 99,99 '1288,6B 7485,44 64,58 100,75 '1304,07 7570,75 64,94 99,56 '1318,94 7E57,02 65,25 99,53 -1333,26 7743,54 65,37 100,45 -1348,28 782P,05 65,68 I00,29 -I363,67 7915,20 66,08 100,63 -i379,33 8001,55 66,4I 99,33 -1394,30 ~0~7,23 66,88 98,44 -1407,56 ~173,12 67.36 98,73 -1420,40 e259,62 65,92 100,38 -I434,76 ~45,76 66,30 98,79 -1449,12 ~43),89 66,48 101,15 -1464,04 ~507,i8 66,32 98,20 -1478,39 ~636,14 65,59 97,40 -I490,51 ~.~,~o 65,85 99,03 '1502,85 ~777,81 64,5? ?~.26 '1515,72 ~63.4I 64,82 99.33 -1528,84 ~949,07 65,2~ 98,46 -1542,10 ?¢33,~, 0= 65,57 °~,35., -1555,25 9!19,21 65,90 98,73 -1568,68 9£05,~5 65,94 99.18 -1582,37 ~29:,39 66,17 9S,08 -1595,51 ?379,85 65,97 99,28 -1608,43 MPE-IO DISPLACEMENT at ft ft 5~24,~4 6023,36 ~012,t~ 6111,32 6~97,"~ 6197,18 5t83,68 6284,00 627~,~ 6371,~3 AZIMUTH deq 100,37 100.23 100,29 100,25 100,22 5o~8, 6460,05 100,18 6443,~7 6546,16 100,14 5528,9¢ 6632,01 100,12 6E~5,32 6719,54 100,10 56~9,67 6805,03 100.10 6785,S6 6892,77 100,08 66E9,93 6977,55 100,08 6~55,30 7064,I4 100,07 7040,35 7150.14 I00,05 .7124,¢0 7234,71 100,04 72C7,3~ 7319.64 I00,03 7292,37 7405,36 100,02 7376,50 7490,8~ i00,03 7459.54 7575,24 100,03 7544,6~ 7661.59 100,02 7E2~,95 774~.16 100,02 7714,t0 7833,70 100,03 779),~5 7919,88 100,03 7~3.94 8006,2? 100,03 7~6~,7~ 8092,07 100,02 ~053,79 8178,09 i00,00 6139,18 8264,67 100,00 ~224,t9 8350,8~ 99,99 $S09,07 8437,06 99,99 )3~3,22 8522,42 99,99 M81,59 8611+56 99.97 55E7,tI 8697.92 99.95 6(51,74 S783o50 B7~6,~ 8869,22 99,93 8~21,2! S954,99 99,92 DLS deo/ lOOft 0,02 1,68 0,62 0,25 0,55 0,98 1,60 0,23 2,05 1,48 0,49 1.81 1.23 0,95 0,83 1,33 0,76 1,21 1,21 0,33 0,88 0,36 0,53 1,31 1,01 0,59 2,21 1,58 2,30 2.90 1,06 1,58 1,53 1,05 0,97 )905, tl 9039,?0 99,9I 0.92 ~8~,51 912~ ~ .,~ 99,90 0,70 9076,30 9213,20 99,89 0,43 9162,~? 9300,77 99,88 1,08 9247,52 ?386,35 9?,87 1,20 FA~E HO, 3 HEASUREP IHTERUAL UERTICAL DEPTH DEPTH ft ft ft 12176,74 89,7 6385,44 1227C,66 93,9 6423,21 12364,92 ?4,3 6461,21 1245~,65 94,7 6499,39 12554,00 94,4 6537,48 I2649,09 12744,97 1284~,49 12934,01 13029,29 95.! 6575.99 95,9 6614,89 95.5 6653.50 93,5 6691,22 95,3 672~,59 13121,94 13214,58 13311,14 13412,00 13501,00 92,7 6767,03 92.6 6805,52 96,6 6848,05 100,9 6895,25. 89,0 6937,99 13603,00 13704,20 13804,00 13903,80 14004,00 102,0 6986,74 101,2 7035,82 99,8 7086,32 99,8 7138.84 100,2 7194,43 14103,00 99,0 I4144,74 41,7 PROJECTED TO TD 14225,00 80,3 7252,62 7277,82 7326,57 **)~********* ANADRILL ************** SURUEY CALCULATIOHS ~*~o~******** CIRCULAR ARC M£THOD*******~ ?ARC£T STATION AZIMUTH LATITUD~ E~CTIOH INCLN, N/-S f' deg deg ft 9461,76 66,46 97,76 -1620,58 ~547,56 66,12 96,64 -1632,85 9~33,~5 66,93 98,18 -1645,46 9720,21 66,I3 99,56 -1658,83 9806,47 66,25 100,02 -1673,51 98,~,40 65,98 101,68 '1689,88 ?081+02 .66,14 I00,97 -1707,09 ~0~6.35 66,19 99,44 -1722,57 10153,85 66,24 99,94 -1736,97 ]C240,95 66,27 98,21 '1750,72 10225,54 66,06 98,75 -1763,22 ]~4~9,71 64,84 100,13 -1777,03 I049~,33 62,91 99,61 -1791,90 ]0%~,20 61,30 95,80 -1803,87 10E-6~,8! 61,30 95,80 -1811,76 1C75],88 61,60 95,)0 -1820,8! 1084~,16 60,40 100,60 -1833,41 ]0926,20 58,80 100,20 -I848,95 1[¢-!I,0! 57,70 99,80 -186~,69 ]i09:,31 54,90 100,10 -1878,09 11174 q= ,~ 53,10 101,00 -1892,75 I12~7,64 52,60 101,60 -1899,26 11271,40 52,60 101,60 -1912,09 MPE-IO D~FA~TURE ~ISPLACEMEN? at AZIMUTH ~LS S/-V deg/ it ft dec lOOft 9328,67 9468,39 99,86 1,65 9413,79 9554,35 99,~4 0,93 ?~9,~2 9640,58 99,83 0,50 9584,78 9727,26 99,82 1,36 ,6..,84 9813,58 99,82 0,47 9755,23 9900.51 99.83 1,62 984!,15 99~8,11 99,84 0.70 ?~27,14 10075,48 99,84 1.46 !301!,~9 10161,05 99,84 0.49 10C97,Ei 1024S,25 99,84 1,66 ,~o 10322,9~ 99,83 0,58 10264,55 10417.23 99,82 1,89 13349,?5 10503,92 99,82 2,06 1043).25 10592,97 99,80 3.70 !0515,92 10670,85 99,78 0,00 10~05,C6 10760,23 99.74 0,29 !0612,62 10848,67 99,73 4,31 10777,..°v 10934,74 99,73 1,64 !9860,~6 11019,61 99,74 1,15 10g42,~6 11102,96 99,74 2,81 11021,70 11183,04 99,74 1,96 1]C54,22 11216+30 99,75 1,66 11116,78 11280,02 99,76 0,04 RECEIVED MAR 28 1995 N~ska Oil & Gas Cons. Commission AnchorF~ - 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) February 16, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD CDR. & CDR-TVD for well IVIPE-10, Job # 9501Z 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 1 Film Returning CDR, &CDR-TVD Field Film State o~.J~fa'~ka ~ % ~1 OH LIS Tape AI/a.st(a Oil &_Gas Con§epcation Comm. ¢-1 Blueline Grant '¢ 1 RFolded Sepia ~ttn: Larry :%~:}.~orcupine Drive Ancho~ag- , t OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 905 127 780 P i:: CFI\/J:: J') PBEA"3E'-RO'f'E;~NO DEPTH SHIFTING PER GENE PIEKENPROCK FEB '~ ~; 1995 AJaska 0il & Gas Oons. Commission PLEA¢~~NOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHHICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Received By: ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 11 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPE-10 __ 1 GR/CCL FINAL BL + RF ECC No. Run # 1 6342.00 Run # 1 6342.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 / Anchorage, AK 99518 Or FAX to (907) 563-7803 Received b ~///~~ Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~~ Chair~ THRU: Blair Wondzell, ~¢~(~a ! DATE: December 20, 1994 FILE NO: AWOILTBD.doc P. !. Supervisor FROM' Bobby Fost~r~'~J SUBJECT: Petroleum Inspector BOPE Test - Nabors 22E BPX - MPU - E-10 PTD # 94-143 Kuparuk River Field Tuesday, . December 20, 1994: ! traveled this date to BPX's MPU well E-10 being drilled by Nabors rig 22E and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows was 1 failure. The sensor unit on the choke manifold was not working. Brian, Nabors toolpusher, told me that a new electronic gauge had been ordered and should be in place with in 7 days. A gauge on the choke manifold can be used until the unit is replaced. Summary: I witnessed the BOPE test on Nabors rig 22E drilling BPX's MPU well E- 10 - test time 3 hours - 1 failure. Attachment: AWOILTBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: NABORS Rig No. Operator: BPX Well Name: E-lO Casing Size: 9.625" Set @ 4,100 Test: Initial Weekly X Other 22E PTD # Rep.: Rig Rep.' Location: Sec. 94-143 DATE: 12/20/94 Rig Ph.# 65g-6475/76 JIMMY PYRON BRAIN BUSBY 25 T. 13N R. 10E Meridian U MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Dri. Rig OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Pressure P/F 300/3,000 P 500/5,000 1 500/5,000 P I 500/5,000 P I 500/5,000 P 2 500/5,000 F/P I 500/5,000 P N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure 1 500/5,000 5OO/5,0O0 MUD SYSTEM: Visual Alarm Trip Tank NO NO Pit Level Indicators OK YES Flow Indicator OK YES Meth Gas Detector OK YES H2S Gas Detector "OK YES P/F P I 500/5, OOO I 500/5,000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 17 Test Pressure P/F 500/5,000 P 42 500/5,000 P 1 P Func~oned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3,100 P 1,450 P 0 minutes 37 sec. 2 minutes 56 sec. Blind Switch Covers: Master: YES Remote: YES Nitgn. Btl's: 4~ 2000 4~ ~800 Psig. Number of Failures: 1 ,TestTime: 3.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 7 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failure: The pressure sensor on the choke manifold is not working - Brian Busby said one was on order and should be here within 7 days - another gauge will be used on the manifold until the new eletronic gauges arrrive. The AOGCC offce orthe inspectors will be notified when the guages are installed NO TE: The pit watcher watches the trip tank when the fig is in the trip process and notifies the driller by intercom the fillup every 5 stands. Distribution: odg-Well File c- Oper./Rig c = Database c - Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) AWOILTBD.XLS STATE OF ALASKA A,_ _,KA OIL AND GAS CONSERVATION COMMIS,.,.ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown__ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing__ Variance__ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 3873'NSL, 2141' WEL, SEC. 25, T13N, RIOE At top of productive interval 1999' NSL, 2130' WEL, SEC. 29, T13N, R11E At effective depth At total depth 1919' NSL, 1670' WEL, SEC. 29, T13N, R11E 6. Datum elevation (DF or KB) KBE = 54' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPE- I O 9. Permit number 94-143 10. APl number 50- 029-22521 11. Field/Pool Milne Point -Kuparuk Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 1090 feet 1083 feet feet feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth OP': i:O!NAL RECEIVED DEC - 7 1994 Alasl~ 0il & Gas Cons, C0mmisslen Anchorage 13. Attachments Description summary of proposal X Detailed operations program__ BOP sketch 14. Estimated date for commencing operation 12/8/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certif~that th,e,e foregoing isttrue and correct to the best of my knowledge. // '' Signed /'~ ~ ~,~.~'~ TitJeDri//JngEngineerSupervisor ~, FOR COMMISSION USE ONLY Conditions of ap~broval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Mechanical Integrity Test__ Date 13-,/'//c~ Approved by order of the Commission Location ciearance J Approval No.,~,/7/,- ~,,~ 7 Subsequent form required 10- /-f ~ 7' Approved Copy Original Signed By Returned ...., David W. Johnston c~,,,,,,,~io,-,e,.Date ¢_.' ( , --orm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TO: Marion Sloan FROM: Joe Polya DATE: December 6, 1994 SUBJECT: Sundry Approval for the MPE-10 Well REQUEST: Please consider this uraent request to revise the MPE-10 Casing Program to reflect a shallower setting depth for the 9-5/8" surface casing: Surface Casing 9-$/8" Set at 4100' md or 3111' tvd Intermediate Casing 7" Set at 13301' md or 6824' tvd Liner 5" Set at 14059' md or 7131' md EXPLANATION: After careful evaluation of the MPE-09 drilling experience by the various disciplines involved in the Milne Point well planning process, we have concluded that is redundant to both 1) deep set the 9-5/8" surface casing, and 2) top set the 7" as an intermediate string. This kind of overkill in the Milne Point well designs is unnecessary and detrimental to the economics of future drilling at Milne Point. We are confident we can pick the 7" intermediate casing point and set the 7" casing without drilling into the Kuparuk Sands. The 7" casing setting depth will provide a sufficient LOT in the event abnormal pressure is encountered while drilling the Kuparuk sands (As was evidenced in the MPE-09 sidetrack and the MPC-22 wells which encountered reservoir pressures of 11.6 ppg and 12.6 ppg, respectively. Both of these wells employed 7" intermediate casing set above the Kuparuk Sands.) The confidence in successfully picking the 7" intermediate casing setting depth without penetrating the Kuparuk Sands is based on the following: 1) The 8.5" hole section will be drilled with real time Gamma Ray and Resistivity Logging-While-Drilling tools to verify the formation tops prognosed by geology. 2) There are 5 offset wells within a 2 mile radius of the MPE-10 target, one of which is the recently drilled MPE-09 bottom hole location and is only 2890 feet away. 3) The geological prognosis is based on 3-D seismic data. 4) The proposed 7" intermediate casing depth will be no closer than 100' tvd and will be adjusted upward if necessary based on the real time logging correlation of the HRZ, MK-19, and D Shale which are all very prominent geological markers. 5) The 7" intermediate casing setting depth was successfully picked while drilling the MPE-09 sidetrack wellbore which had a shallow set surface casing setting depth of 3814' md (3010' tvd). 6) A geologist will be on location to aid in picking the 7" casing setting depth. Page 1 of 2 RECEIVED DEC - 7 1994 Alaska 0il & Gas Cons. Commission Anchorage HISTORY' In the original permit to drill the MPE-IO well dated November 4, 1994, we submitted the following casing program: Surface Casing 9-5/8" Set at 7968' md or 4674' tvd Production Casing 7 Set at 14029' md or 7131' tvd This deep set surface casing setting depth was based on our experience drilling the MPE-09 well in which we drilled into higher than expected pore pressure and was intially thought to be around 11.1 ppg EMW. However, after running the MPE-09 with a 5" liner, the well was perforated and an 11.6 ppg static pressure was recorded on wireline. This higher reservoir pressure exceeds the permissible kick tolerance for the 12.5 ppg LOT at the 9-5/8" casing shoe. Therefore, we submitted the Application for Sundry Approvals dated November 30, 1994 to revise the MPE-10 casing program as follows: Surface Casing 9-5/8" Set at 7968' md or 4674' tvd Intermediate Casing 7" Set at 13301' md or 6824' tvd Liner 5" Set at 14059' md or 7131' md Finally, we submit the Revised Casing Program for the MPE-IO well shown in the REQUEST shown of Page 1. We are grateful for your patience in this matter and once again ask that you give this request your immediate attention since the well was spudded on Tuesday December 6 at about 4 PM and should reach the proposed casing setting depth sometime early AM on Thursday December 6, 1994. Thank You, Joe Polya Point Contact, Nabors 22-E Rig Page 2 of 2 REEEIVED DEC - 7 1994 Alaska Oil & Gms Cons. Commission Anchorage TO: Marion FROM; Joe Polya DATE: December 8, 1994 SUBJECT: Sundry Approval for the MPE-IO Wall Please consrder this uraent request to rev/se the MPE-IO Casing Program to reflect a shallower setting depth for' the 9-S/8" surface ca~ing: Surface Caeittg . 9.~/a' ~ at 4100' md er 3111' tvd Intermediate Casing 7" ;let at 13301' md or 6924' tvd Liner a" Set at 14069' md or 7t31' md After careful evaluation of the MPE-O!i drilting experience by the various dls~tpllnes involved in '~he M[Ine I~oi~t well planning process, we have concluded that is redundant to both 1) ~:ieep set the 9.5/8" surface casing, and 2) tel3 set the 7" ~ an intermediate string. This kind of overldll in the M[ine Point well desigr~ is unnecessary and detrimental to the egonomi¢s of future drilling at Milne Point. We are confident we can pick the 7" intermediate c.,asing point and set th? 7" casi.n,g, without al, tilling into the Kuparut~ Sands. The 7" ~.a~i _ng ~etting depth will prowde a ~fftcmnt LO'i' ~n the event abnormal pressure encountered while dr. illing the Kuparuk sands (As was evident;el in the MPE-09 sidetrack and the MPC.22 well~ which encountered reservoir ~essures of 11,6 13pg and 12.6 13pg, respeu-'tively. Both of these wells employed 7" intermediate ceasing set above the Kuparuk The confidence in su~$ssfully pi=king ~he 7" intermediate casing setting depth without penetrating the Kuparuk Sands ia based on the following: 1) The 8~$" hole sec;ion will be drilied with real time G~mma Ray and Resistivity Lc~ggi~-While-Dr[ll~ng toots to verify the formation tops prognoeed by geology, 2) There are 5 offset wells within a 2 mile radius of t,he MPE-IO tier;est, one o~ which is the recently drilled MPE-09 bottom hole ,o~tion and is only 2890 feet ;[way, 3) The geological prognosis is based on $-D seismic data, 4) The pro _l=,Oasd 7" intermediate casing depth will be no closer than. 100' tvd and will be adjusted upward if neu-e~ary based on the real time I~gging correJation of the HRZ, MK.19, and O Shale which are all very prominent geological markers, 5) T_h,,,e, 7'" intermediate casing setting depth was successfully plead while dnltmg the MPE-Og sidetrack wellbore which had a shallow set surface ge, sing setting depth of ,3914' mci (~01 O' tvd). 6)A geolc,;ist will be on location to aid in picking the 7" casing ~e~ng depth, Page 1 of 2 H191'ORY: In the original permit to drill the MPE.10 well dated November 4, 1994, we submitted the following ca.~.ing program: Surface (;eelrtg g-S/il" Set et 7968' md or 4674' tvd PrecluSion Casing 7 ;}et at 1402g' md or 7131' tvd Thio deep set surface casing setting depth was based on our experience drilling the MPE-09 well in whk3h we drBed into higher than exposed pore pressure and was intially thought to be around '1 t,1 ppg EMW. However, after running the MPE-0g with a S" liner, the well wac per~orated and an 11,6 ppg static pressure wa~ recorded on wireline. Thi~ higher reservoir ~e$~re exceeds the perrniaeible ki~k tolerance for the t2,5 ppg LOT et the 9.St8" ca~ng shoe, Therefore, we submitted the ApPlication for Sundry Api~ovals dated November ~0, 1994 to revise the MPE. 10 easing program as follow~: $1Jrface Casing g-S/ii" Set at 79M' md or 4674' tvd Intermediate Oasing ?" ~t at t3301' md or 6824' tvd Liner ~" ~t at 140S9' md or ~1~I' md FinaJly, we ~ubmit the Revised Casing Program for the MPE.10 well shown in the . ~ shown of Page 1. We are gratefu, i fol' your patlenoe in this matter and on~,e again ask that you give this request your ~mmecfiate attention since the well was ~udded on Tue~ay December 6 at about 4 PM and should reach the proposed easing setting depth sometime e~ly AM on Thursday Dec. ember 6, t994, Thank YoU, Joe Polya Polm Co.am, Nabors 22-E Rig Page 2 of 2 BP EXPLORATION BP Exploration (Alaska) Inc. P,O. Box 196612 Anohorage, Alaska 99519-6612 TO: TELECOPY SATELLITE UNIT Name:. Blair Wondzeli i __ Company: AOGGC Location: ~_. Anchora.ge 276-7542 · FROM: Name & Ex't,: Marian Sloan Ext. 5127 Ilia Il .--. I Department: Shared, _.. Services,.. Drilling NOTES: PAGES TO FOLLOW :, · I ~ECURi'I'~ CL~SglFICATION PRIVATE ! .~' ~ (Do not inc~iucte cover sheet) SECRET CONFIDENTIAL __ - . II SATELLITE FAX MACHINE · i FAX# , . CONFIRM# _, , ._ - MEMORANDUM TO: THRU: David John~n, Chairm ,~,~''' Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 6, 1994 FILE NO: EWOJLFBD.DOC FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector Diverter inspection Nabors rig # 22-E BPX well # E-10 Milne Point Unit PTD # 94-143 Tuesday, December 6, 1994: I witnessed the Diverter function test on Nabors rig #22-E, drilling BPX well # E-10 in the Milne Point Unit. The function test went well after cycling the Knife valve on the stack which at first acted as if there was some dry mud impeding its opening. After cycling the bag two times this seemed to clear up. The 10 inch vent line was bifurcated outside the rig with a set of 10 inch knife valves which were joined in a fashion as to prevent both lines from being closed at the same time. I found the layout of the lines to be sound and sturdy although there was some snow drifted in them. The rig hands cleared this and I passed the setup for spud. SUMMARY: I witnessed the Diverter function test on Nabors rig #22-E. Attachments: EWOJLFBD.XLS cc: Sam Lynch (Prudhoe Bay Drilling) STATE OF ALASKA ~'"-. ALASKA O1~. AND GAS CONSERVATION COMI~..,~SION Diverter Systems Inspection Report Date: 12/6/94 Operation: Development X Exploratory: Drlg Contractor: Nabors Rig No. 22-E PTD # 94-143 Rig Ph. # 6475 Operator: BPX Oper. Rep.: Donnie Lutrick Well Name: E-10 Rig Rep.: Leonard Schiller Location: Sec. 25 T. 13N R. 10E Merdian UM MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3000 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1800 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: ~min. 28 sec. Systems Pressure Attained: 1 min. 44 sec. Nitrogen Bottles: 8 bottles DIVERTER SYSTEM INSPECTION: Diverter Size: 21 in. Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 in. Vent Line(s) Length: 75 ft. Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: NO Turns Targeted / Long Radius: N/A 2000 average psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane Hydrogen Sulfide: DIVERTER SCHEMATIC Manifold Building WIND NORTH Non Compliance Items 1 Repair Items Withi N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Vent Lines packed with blown snow, cleared same Distribution orig. - Well File c- OpedRep c- Database c I c- Inspector AOGCC REP.: EWOJLFBD.XLS OPERATOR REP.: Louis R Grimaldi STATE OF ALASKA AL,-,$KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing_ Repair well__ Plugging __ Time extension__ Stimulate __ Change approved program X Pull tubing__ Variance__ Perforate__ Other__ 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska)/nc. Development x Exploratory __ 3. Address Stratigraphic__ 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ 4. Location of well at surface 8. 3873' NSL, 2141' WEL, SEC. 25, T13N, RIOE At top of productive interval 9. Datum elevation (DF or KB) KBE = 54' Unit or Property name Mi/ne Point Unit Well number MPE-IO Permit number 94-143 10. APl number 50- 029-22521 1999' NSL, 2130' WEL, SEC. 29, T13N, R11E At effective depth At total depth 1919' NSL, 1670' WEL, SEC. 29, T13N, R11E 11. Field/Pool Mi/ne Point -Kuparuk Sands feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) feet feet feet feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth ORIGINAL DEC ~i~ & GaS Cons. G0mmiss'~o~ Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 12/2/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby ~ertify that the foregoing is true and correct to the best of my knowledge. Signed .,(,. ~ -K'~ '//J'7~ ~' ~ Title Drilling Engineer Supervisor //// '~ ' FOR COMMISSION USE ONLY Conditions oY'approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance __ Mechanical Integrity Test Su~s~q.uen. t form required 10- ~ ~ 7 unglna~ Signed By _. David W. Johnston Approved by order of the Commission ~;~ ~o · I 1~' ~P,~r~)ved Copy / '7- turned .% ~ .~ ~ · 'Commission&r ~Date /'(~ , O Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Date: 11/30/94 Subject: Casing Design Change on the MPE-10 well. Based on the over pressure experienced on the MPE-09 well (11.6 ppg EMW), we have decided to top set the Kuparuk Reservoir on the MPE-10 well to avoid drilling complications. This over pressure is the result of communication with the MPE-05 injection well which is located two fault blocks to the west. We now plan to set a 7" intemediate casing 100' tvd above the Kuparuk reservoir, drill to TD with 6" hole, and set a 5" cemented liner. RECI I¥£D DEC, ~ 2 '~994 A~ska Oil & Gas Cons. Commission Anchorr_. ', ALASKA OIL AND GAS CONSERVATION COMMISSION November 10, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORA(3E, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-10 BP Exploration Permit No: 94-143 Sur. Loc. 3873'NSL, 2141'WEL, Sec. 25, T13N, R10E, UM Btmhole LoC. 1919'NSL, 1670'WEL, Sec. 29, T13N, RllE, UM Dear Mr. Clark: 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, Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc .* Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Red rill •I lb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) I10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54' feet Milne Point Unit- Kuparuk 3. Address 6. Property Designation River Sands P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28231 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 20 AAc 25.025) 3873' NSL, 2141' WEL, SEC. 25, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 1999' NSL, 2130' WEL, SEC. 29, T13N, R11E MPE- 10 2S100302630-277 At total depth 9. Approximate spud date Amount 1919' NSL, 1670' WEL, SEC. 29, T13N, R11E 11/11/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MDandTVD) property line ADL 28232-1670' feet No close approach feet 2560 14059' MD/7131' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 4o0 feet Maximum hole angle 66 o Maximum surface 2860 psig At total depth (TVD) 6964'/3560 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 7999' 31' 31' 7968' 46 74' 1536 sx PF "E"/250 sx "G"/250 sx PF "E" 8-1/2" 7" 26# L-80 NSCC 14059' 30' 30' 14029' 7131' 195 sx "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 ConductorRECEIVED Surface Intermediate NOV "4 1994 Production Liner Alaska Oil & Gas Cons. Commission Perforation depth: measured Anch0rag~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-] 21. I hereby certi~, that the foregoing is true and correct to the best of my knowledge Signed ~ 1~~.~_~...,~- ~.,,~.._~.,~ Title Drilling Engineer Supervisor Date Commission Use Only Permit Number IAPI number Approval date See cover letter 15o.oz?- .Z. ~-,5'-~-- / //-" / 0 "~'~ Ifor other requirements Conditions of approval Samples required [] Yes []No Mud Icg requiredI-lYes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey requ~reo [] Yes [] No Required working pressure for BOPE []2M; 1-13M; 1~5M; [-ll0M; ~15M; Other: Original Signed By by order of David W. Johrlstorl Commissioner tne comm,ssion_ ,Date//'-~/~."~¢ Approved by --orm 10-401 Rev. 12-1-85 Submit in triplicate I''' ''''~- I I Design (conventional, slimhole, etc.): I I [ Milne Point Ultra Slimhole 7LS nation Markers: ~rmation Tops MD TVD (bkb) p~rmafrost 1795 1754 7133 4334 Top of Schrader Bluff Sands (8.3 ppg) 7728 4574 (8.3 ppg) ee Shale 7852 4624 Base of the Schrader Bluff Sands · 12038 6314 High Resistivity Streak Kup 13028 6714 Kuparuk Cap Rock C1 Sand--Target 13548 6924 Target (9.9 ppg) B7 Sand 13687 6980 (9.9 ppg) Depth 14059 7131 tng/Tubing Program: ~ Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD ;4" 20" 91.1# H-40 Weld 80 32/32 112/112 1/4" 9 5/8" 40# L-80 btrc 7999 31/31 7968/4674 1/2" 7" 26# L-80 nscc 14059 30/30 14029//7131 xtal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a :olumn of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case ning a reservoir pressure of 3600 psi is 2980 psi, well below the intemal yield pressure rating of the ising. ling Program: ,n Hole Logs: 'ace ,hiediate ~d Hole Logs: MWD Directional Only N/A PDC Bit f/Surface Shoe to TD w/MWD Dir and LWD (GR/CDR/CDN). GR/CCL will be mn in 7" casing to coincide with Wireline Perforating Operations without a Rig on the well. CBL run only if necessary. I I I I I I .uction Mud Properties: I None- LSND freshwater mud ;lisity Marsh Yield 10 sec 10 min pH Fluid PG) Viscosity Point gel gel Loss )i0 40 10 3 7 8.5 6-8 :tO tO tO tO tO tO tO 0.4 50 15 10 20 9.5 4-6 Control: control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be 'led and is capable of handling maximum potential surface pressures. ,xter, BOPE and drilling fluid system schematics on file with AOGCC. ,ctional: I KOP: 1400 Maximum Hole Angle: Close Approach Well: 66 degrees MPE-09 -- 217' away at 3667' md and 2937' tvd which requires MPE-09 be shut-in with plug below this point. -posal: ':ings Handling: CC2A ~d Handling: All drilling and completion fluids can be annular injected. ~rwise, Haul to CC2A. Since the MPE-10 annulus will not be available for annular :tion until after the 7" casing is cemented, all drilling fluids will be hauled to CC2A. ]ular Injection: The MPE-10 annulus is permitted for drilling & completion fluid :tion. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (aBES) (aBES) ne Point MPE-09 0 35,000 6/1/94 to 12/31/94 lie Point MPE-10 0 35,000 6/1/94 to 12/31/94 EEZE PROTECTION: close attention to annuli being used for disposal so to avoid freezing. Sometimes the ali are kept open by ensuring that an adequate volume (+60 bbls) is injected every hours. This practice is rnore economical than pumping 60 bbls of diesel freeze :ction every time the pumps are shut down; however, if this practice is used, it is >rtant that the injection frequency into the annulus be adequate to prevent freeze -- the drillers must communicate to each other the last time the ulus was injected into to avoid freezing. NOV -' 4 1994 Alaska 0it & Gas Cons, Commission 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/ PDC bit on a turbine, Test 9-5/8" casing to 3500 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT. Drill 8.5" hole to 14059' md (7131' tvd), POOH, Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing -- Test Casing to 3500 psig. Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Run and Test 7" Pack-Off to 5000 psig. Change Pipe Rams to 3-1/2" & Run Wear Bushing. RIH while PU 3-1/2" drill pipe with 7" 26// tandem bit and scraper to PBTD and perform a casing wash with 10.2 ppg brine while filtering to 2 micron absolute. POOH with 3-1/2" drill pipe and LD Scraper and Bit. RIH with 3-1/2" drill pipe and TCP Perforating Guns and Perforate underbalance. Circulate the well dead, POOH while laying down the 3-1/2' drill pipe -- Freeze Protect the top 2000' tvd of hole. Pull Wear Bushing. ND BOPE and NU and Test Tree. RDMO Nabors 22E drilling rig to drill the MPE-13 . /ling Hazards and Risks: ................ · There was evidence of shallow gas/hydrates in the E-Pad area (E-7 and E-8 wells); therefore, the MW schedule requires 9.3 ppg by 2000' tvd. This practice was applied on the MPE-09 well and there was no evidence of hydrate problems while drilling the surface hole. ~'~ The MPE-09 encountered pore pressure in the Kuparuk that was 0.7 ppg above what was expected (10.8 ppg vs 10.1). This resulted trouble time and costs associated with the well kill incident being complicated with the Schrader Bluff sand exposed. As a result, the MPE-IO well design has been modified to set the surface casing below the Shrader Bluff Sands -- even though the prognosed pore pressure for MPE-IO BHL is 9.9 ppg. · No other drilling hazzards or risks have been identified for this well. R£C£1V£D NOV -'4 1994 ~'t~ska 0il & Gas Cons, Commission Anchora,.~,~, WEIGHT: 12.0 ppg APPROX #SACKS: 1536 YIELD:2.17 ft'"/sx MIX WA I EH: 11 .b3 gaLI/;~k 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% CaCI2 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 250 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE' Permafrost ADDITIVES: Retarder WEIGHT: 15.6 ppg APPROX NO SACKS: 250 E YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing from the FS to the NA Sand (24 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm 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. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME- 1. The Tail Slurry volume is calculated to cover 618' md above 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' rnd to sudace with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. NOV - 4- 199 L)[l & Gas Cons. Commission Anchora~. ~ WEIGHT: 15.8ppg ^F' F OX # s^c s: 195 YIELD: 1.15 cu fl/sk MIX WATER: 5.0 gal/sk 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 20 joints of 7" Casing (40 total). This will cover 300' above the LKI. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulators inside the 9-5/8" casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 41. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility pdor to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME' 1. The cement volume is calculated to cover 1000' md above the LK1 with 30% excess aboveguagehole. RECEIVED NOV -'4 199q A~ska 0it & Gas Cons. Commission Anchora,~ ~ Marker Identilicatio~ NO IlK8 SECrN INCLN A) K~ o o o a.oo B) KOP/£~ILD I/lO0 400 400 0 0.00 C) BUIL§ i.5/lO0 600 600 3 2.00 O~ BUILO 2/100 §00 899 26 6.50 El CURVE 2.5/~00 1300 ~292 98 14.50 FI END 2,5/100 £UFIVE ~389 2826 1409 66.59 G) CU~t~/E 2.5/t00 3848 3005 J822 66,59 It) END DF 2.5/100 CU~¥E 3929 3041 1903 66.19 . I) 9-5/6'CASIt~B POiNf 8199 4765 5810 66.19 J) ....... TAHC-ET ....... ~3548 6924 10704 66.19 K) fO ~4059 7131 1t~.71 66.19 <KB> 75 8 LZN'G "GROUp _, ii iiii ii ii1__ ~ i i i I Il I III _ -- MPE- t0 (P_16) VIEW ,,,,, , , ,,, ,,,,, VERTICAL SECTION ~ ~ ..... · , _ i, _ Section at: gg.BB TVD Scale.- 1 inch = i500 feet Oep Scale.' ~I inch = 1500 teet Dra~n ' :l 1/04/94 ........... section Depar(u're ............... _ _ ,. :~ i _ ii ii i i ii il i i~ J i iljl .... MPE-]O (Pi6) PLAN VIEW CLOSURE "' 1~17~ feet at Azimuth 100.03 DECL SCALE DflA~N _ Marker A} CI BUILD a] BUILt) E] CURVE F] G) Itt END KI fD ,, I .... PRuDH'o-E _ 700 O 70~ ~400 21~0 2BO0 3500 4200 4900 5600 6300 7000 7700 B4%1) 9100 BDO0 1050O lj200 11900 <- KESI ' EAST .-> 'i'~)~5 ~E~I6 Bt.~ ~:~]i,. ~) ..................... · t inch = 1400 feet ! I ........ i'~/04/94 .................... ! ............................. I~ ent~ ~ icat ~an ND N/5 [/~I .......... I .... ~ _ o o oJ i ., B 1.5/i00 600 0 3 m 8 2/100 900 2 26 ............................................ ! ......... I E 2.5/100 t300 9 98 2.5/lO0 CleaVE 33139 252 1386 . 'E 2.5/I00 3B40 340 1790 t i I I DF 2.5/100 C~ 3929 356 1070 ' ,- , ,, ~,,, B"CASIN6 POINT Btgg 1025 5719 ' ---IA~GET ........ 13fi4B t866 10540 ~4059 t946 I~OOO . i . ~~~ ~ ~ 200 FI rARBEI fl/)Ills . .. ___' , ......................... : .: . ~ 0 ~-' . ,. ~ ', g ~ ~ ' ~ ' ,,. or .... " I , I I ~ ~lm' ; j ~- J i , t i I I II -,, APPR 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING AP~PR 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............... 26. BOPE press rating adequate; test to ~ ~s~g] 27. Choke manifold complies w/kPI RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29 Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./ . Y [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB Comments/Instructions: HOW/jo - A:~FORMS~cheklist rev 03/94 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. _ Subfile 2 is ty~e: LIS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MWD RUN 1 6461.00 HENNINGSEN C. BALLARD MPE-10 500292252100 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 20-JUL-95 MWD RUN 2 MWD RUN 3 HENNINGSEN 25 13N 10E 3873 RECEIVED . o o 5 3,2 5 IU. aska .Off & ~s Cons, 2 4.7 0 Anchor~ge OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 13386.0 6.000 14225.0 MWD - DGR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 & 2 WERE RECORDED WITH SLIM PHASE-4 / GAMMA RAY. WELL TD AT 14225' MD. NO DEPTH SHIFTS WERE APPLIED AS THIS IS DEPTH REFERENCE FOR THIS WELL. MICROF, ILMED ~LE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 13283.0 13360.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 14182.0 14189.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 13324.0 13578.0 2 13578.0 14225.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data'Records: 68 Tape File Start Depth = 14250.000000 Tape File End Depth = 13200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16809 datums Tape Subfile: 2 149 records... Minimum record length: 62 bytes Maximum record length: 998 bytes ~ape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 13283.0 EWR4 13289.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE 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: STOP DEPTH 13536.0 13543.0 26-DEC-94 2.19A 1.12 MEMORY 13578.0 13324.0 13578.0 0 62.9 62.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0001SP4 P0001SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 6.000 13386.0 XANVIS 11.00 43.0 11.4 5OO 13.2 1.830 .870 1.750 2.450 69.0 153.0 69.0 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 1 (BIT #6). $ : BP EXPLORATION (ALASKA) : MPE-10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 ROP MWD 68 7 FET MWD 68 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHM/~ 4 1 O~ 4 1 FPHR 4 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 26 Tape File Start Depth = 13600.000000 Tape File End Depth = 13200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6409 datums Tape Subfile: 3 91 records... Minimum record length: 62 bytes Maximum record length: 998 bytes tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 13533.0 EWR4 13539.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE 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: STOP DEPTH 14182.0 14189.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 29-DEC-94 2.19A 1.12 MEMORY 14225.0 13578.0 14225.0 0 52.6 61.6 TOOL NUMBER P0001SP4 P0001SP4 6.000 13386.0 XANVIS 11.10 45.0 10.0 5OO 14.5 1.750 .850 1.700 2.400 73.0 158.0 71.0 71.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2 (BIT #7). $ : BP EXPLORATION (ALASKA) : MPE-10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMS4 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 49 Tape File Start Depth = 14250.000000 Tape File End Depth = 13500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28818 datums Tape Subfile: 4 114 records... Minimum record length: Maximum record length: 62 bytes 998 bytes £ape Subfile 5 is type: LIS 95/ 7/20 01 **** REEL TRAILER **** 95/ 7/20 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 20 JLY 95 10:30a Elapsed execution time = 4.12 seconds. SYSTEM RETURN CODE = 0 RECEIVED APR 41aska Oil & 6as Cons. Ancl~orage ,3-~,F'P-1995 I4:59 1S'r 13~ 3a73 2124 pa 't o .- ,. 14:59 PAdE: iJ F: p 'T'. [': t) ['i (,'.-. 'b (:: D I:;' P T. R 0 0 ,,.:. (} t.') u 1') *:': P T, 7 5 C, (>. t: O t) !.) F: P T. 7 t l (: O. t.; (': {.~ D .~'' F: T. 65. 0 (). U (! f.) E P"r. .q ~ O !.). o,. 2 -.. ~'' n 2.700 :I. 8 (.; 0 6.7 C' 0 C l.:: t' ',',i. r,~, ;', i.:,~ 6.70 ('t P C' P, f'.' ~' .D. 34.2CC) (; I:': T r:. ,"., ~,, l',~ 34.2C'D R C P. ~,~ :,,' f) °1., .6[:0 GF',J.'/;,!,I~L) 91 158.100 117.200 72.5O0 88,500 373.3P0 3~6.400 444.900 97..800 57.95O 1, 1, 2. 000 80°5(;.0 105.000 129.40 ~) 56. o 0 o -999.250 233.500 51.6.900 425.000 603.300 421.400 425.800 118.200 2O9°300 0o000 48.600 giles. IS ~'a, oe Verification chlum~erc;)er ~,laska Cc, mp',.,~t!nO Center 3-AFR-.1995 .I,,4:59 w ;.'.) 9 L 5 'r' h "., 5- 0 F' F (7 t k' .): 1 2. '" f) E C-, 9 4 8080 375 8o25,r? 0,0 0 9 (), (.i 0 9 0. (., 0 C) Oo 0 $ # PAGE: 66 73 66 73 66 69 66 1 (,), 5 158o lO0 Tape Ver!f~catlon [,istino ~hlumbe:r, qer_ A],a~K',a' C;)mpnt!r'~f~, Cent:er, Ro[,'F' ~wH 23.'] 5 o (,,~ ' ' D F P "Ir" R ~ P F' D, F P T. 4,. O 0 0.30 () G R. i~i I.~ I,'> I:{' C~ P K. ,v,, ~,i H 4, 25,00 U ::) ()U 0 D ..... F p m ,,. 3 ':' . ::,) C,,. R . ,,~.,', t,:~,. D R n p p. '~,,,., ~,~ 'H 603.30 t) t-~0 P F", i~, :.,~ H 421,4 n 0 425. ~ 0 ~.,:~ I) F p '!'. 1 b O t,). C~ 0 U O f.~. h', i..;, I3. [? n p f{'. ~,.': :.,: H 1. 18.20 ~.) ,3-AF'P-! 995 ~. :[ 2.7 00 a 6.70 0 ii:', ¢. 7 C', O 91,, 6 (,,' 0 -999. 250 1 12.000 80.5 (: 0 9 t,. () 0 0 129.4 (.; 0 1. 50.4(;0 56. OUO -990.250 1,4;59 G R, '4 W H G ['<. ~,'I W H G R . i,'i W H G P,. :"i ;*! h 112,700 8 1. R 00 86.700 86.70 o 3 4.2 () 0 9 1.60 0 92.8 () 0 57.950 ! 12 . 9 0 (,) 80.500 9 1.000 10 5.000 ]29.400 !, 50.49O 56. O00 0.000 -~99.250 R r'] p [.,,'1. P W D R 0 p E. ~ W P (..[ E. , R 0 P F:. ~,4 w D R 0 P E. ,~ W D R 0 P E. ,~'i ,,N O R r,') p Fi. ~ w D ROPE.~WO R 0 P F:: . M W D R (:I P E. ~1 W D R r.': ? E. ~.": ~ D R OP[:. H ~ D ROPF, MwD PAGE: 117.200 72.500 88.50O 373.30O 386.400 444.900 233.500 516.900 425.000 603.300 421.400 425.800 417.800 1!.8.200 209°300 0o000 4:8.600 IS ~a~e '¢er'!fication bistino Chlumberoer a],,esKa Comp,~t]ng Center 3-~P~,-1.995 .1.4:59 PAdE: !,,.P E- I 0, t:'! 1 !',, ~,i E POI f,tT, 50-029-2252., 1 * ALA6Ka COMPUTING CENTE~ * ****************************** *------- SChI,,U~BERGER .... ---, WE'Lb NAME : ~E~10" F.iELD N,A~E; : ~I[.,NE POINT BOROUGH : NORTH SLOPE BORC)UGB STATE : ALASKA API NI.J~,ER : 50-0~9-2~521 REFERENCE NO : 95012 :hlum ergerA'lask:a Co~putin~ Center 14-F[~]B- ~. 995 ~.6:37 RF~EI, ~A~E . ~ : 95o12 PREVIOUS REE~ CO~.~ENT : BP EXPLORATIOM, ~PE-10, ~I.LNE POINT, API 50'029'2~5~1 **** TAPE HEADER S~RVICE NA~E : EDIT ]DAT~ : 95/02/',1,4 ORIGIN : rblC TAPF..,, ~A~,'E : 95012 pREvIOUS TAPE : CO~t~ENT : ~P EXPLORATIO[~, MPE-IO, ~iLNE POINT, API 50-029-22521 T~PE HEADER ~4ND/NAD bOGS API NUNBER: OPERATOR: LOGGING COMPANY: TAPE CREATIOI~ DATE: ~Og DATA JOB LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE~ FNL: FSL: FEb: FWL: ELEVATION(MT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~ST STRING ~ND STRIMG BiT RUN 1 Nev.~.lle L 0 T R I C K ~PE-iO 500292:2521 B.P,. Exploration SCHLUMBERGER ELL SERVICES 14-FEB-95 BIT RUN 3 25 IOE 2141 54.40 24.70 OPEN HOLE C~SISG DRILLERS BIT SIZE (IN) 6IZE (IN) DEPTH (FT) g.500 9.625 4100.0 PAGE: IS ~e..~e Verification Ll. stina :blUmberger Alaska Computing CeDter 14-FEB-1995 16:37 3RD STRING PRODUCTION 8THING # R~MARK$: !3h!~; BIT RUN ~I'ITH ON[,,Y THE CDR,: NO DEPTH PR,I~ARY DEPTH Cf, NTROL GR ~VAI, LABI, E $ LIS FORMAT DiTA LIS FORMAT DATA **** FILE ~E,A, DER **** FILE NAME : EDIT ,001, SER¥ICE ~ FblC VERSION : O01CO1 ~X REC SIZE : 10~4 FILE TYPE : LO LAST FILE : PAGE: FILE ~EADER FILE NUMBER: 1 EDITED MERGED MWD DePth shifted and clipped curves; all bit runs merqed.. DEPTH IMCRE~ENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH ~WD'''''''''''''' '''~'''''79 0 B~SELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ~.ASELINE DEPTH $ ME,CED DATA SOURCE LDWG TOOI.~ CODE STOP DEPTH 34 IVA[.EN1 OH .. DEPTH--- ------ -- .... ----EQI~ '? ' UN I'FTED - MERGE BASE # REMARKS: NO DEPTH SHIFTS D[~E TO NP PRIMAPY DFPTt~ CONTROL GR AVAILABLE. $ LIS F~R~AT DATA Tape refill, cat!on =hlumberger AlasKa Computing Center ** ~ATA FOR~'!AT SPECIFICATION RECDR[) ** ** SET TYPE - 64EB ** TYPE REP~ CUI)E VAbUE 1 66 0 2 66 0 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 1~ 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 .** SET TYPE - CMAN ** · . NAME SERV UNIT SERVICE iPI AP1 AP1 APl: FIl,,f; NIj~:B Md~B SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUmB SAMP ELEh CODE (HEX) MT 619024 O0 000 O0 0 1 ! 1 4 68 0000000000 DEPT ROP FET MWD R& MWD RP MWD DER MWD 'V~A MWD GAPI 619024 O0 000 O0 0 1 FPH~ 619024 O0 000 O0 0 1 HR 619024 O0 000 O0 0 1 OHM~ 6190~4 O0 000 O0 0 OHM~ 619024 O0 000 O0 0 OH~ 619024 O0 000 O0 0 1 1 1 4 68 000.0000000 1 1 4 6~ 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 ! 4 68 0000000000 ! 1, 4 68 0000000000 ** [)AT~ ** DEPT. 13406.500 gR.MWIi) -99q.250 ROP.MWD RA.~WD -999.250 RP.MWD '999.250 DER.MWD VRP.MWD -999.250 45.500 FET,MWD -999.250 VRA.MWD DEPT. 13000.000 GR.MWD 1.14.050 ROP.MWD RA.MWD 2.105 RP.MWD 4.007 DER.MWD VRP.MWD 4.208 ~45.611 FET.~WD 2.738 VRA.MWD DEPT. 12500.000 GR.MWD 190.231 ROP.MWO RA.MWD 3.512 RP.MWD 6.485 DER.MWD VRP,~WD 6.491 151. 450 FET.MWD 41671 VRA.~D PAGE:: -999.250 -999,250 0.539 2.229 0,686 3.57B cblumberger Alas~.a Co~.put rig DEPT, 12000.000 R~.MWD ~,200 VRP.MWD 1 ,42! DEPT, lJ,,5OO,O00 R~,.MWD 3.773 VRP,MWD 4°775 DEPT,~wD 11000.000 R~.° 2,186 VRP°~WD 4,060 DEPT° 10500,000 R~.~D 3,238 R~°MWD 2.890 VRP,MWD 2,884 DEPT, 9500,000 RA,~WD 3,217 VRP.~WD 3.254 DEPT, ~000,000 R~,MWD 3'587 VRP,MWD 3,445 DEPT. 8500.000 RA ~WD 3,464 RA.MWD 3.389 VRP.~WD 3.468 DEPT, 7988.000 R~,WWD -999.250 VRP.~WD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILF NAME : EDIT ,001 SERVICE : FLIC VERSION : O01CO1 D~TE : 95/02/!4 ~X EEC SIZ~ : 1024 FILF TYPE ~ LO LEST FILE : Center 14-FEB-~,995 16:37 GR.MW'D 102,074 ROR,MWD ~30.282 RP,~:WD 10,07,4 [)ER'~WD 7.208 GR. MW:D 140 ~7 ROP.~WD 146.141 RP,MWD 4.i, 4 DER.M~D 4.318 GR,~WD !66,~4g ROP,MW[) 1.17,114 RP,~WD 4:.090 DER,~iWD 2,837 GR.~WD 93.6~1 ROP.MWD 181.643 RP.~WD 3.846 DER.~4wo 3.589 GR.~.~iWD 78,45~. ROP°i~wO 141,255 RP.~4WD 2,921 DER,~WD 2,910 GR,~WD 80.730 ROP,~wD 142,386 RP,MWD 3,994 DER,MWD 3,266 GR.~WD 105,679 ROP,MWD ~.65,912 RP.MWD 3.47~ DER.M~D 3.4.73 GR.MWD 96,543 ROP,MWD -999.250 RP.MWD 3,508 DER,~WD 3.465 GR.NWD 98.213 ~OP,MWU -999.250 RP,MWD -999,250 DER,MWD -999.250 FET,~WD VRA.M~D FET.~WD FET.MWO VRA.~D FET.~WD 'VRA.MWD FET.~D VRA.~WD VRA.~D FET.~WD VRA,H~D FET.~WD 0.481 8.493 0.628 3.794 0.974 2.269 0.294 3,4~9 0,628 2,862 0.694 3,181 0.540 3.290 0.302 3,562 -999.250 3.406 -999,250 -999.250 IS Tare Verificatf, on t.,,lst~.na ~hlU~:,.ergerb Alaska Computlnd Center 14-FEB-I, 995 16:37 PAGE: **** FILE HEADER FILE NAME : EDIT ,002 SERVICE : FBIC VERSION : O01COI DATE : 95/0~/~,.4 ~iAX REC SIZE : 1,024 FILE TYPE : LO LAST FILE F![~E HEADER FILE NUMBER 2 RA~ MWD Curves and loq header data :for each bit, run ~n separate ~iles. Bi~T RUN NUMBER: DEPTH INCREMENT: 0.5000 FILE SUmMArY LD~'G TOOL CODE START DE~TE STOP DEPTH 13.406.0 79S~,0 LOG HEADER DATA DATE LOGGED: 18-DEC-94 SOFTWARE: SURFACE $OET~AR, E YER$ION: FAST 2.5B005 DOWNHOLE SOFTWARE VERSION: v4.0C DATA TYPE (~E~ORY or REAL-TI~E): ~E~ORY TD D~ILLER (ET): 1,3406.0 TOP LOG INTERVA5 (ET): 79~8.0 FOTTO~ I}OG INT~RVA5 (FT): ~3349.0 B~T ROTATING SPEWED (RP~): 80 HOLE INCLINATION (DEG) M!NIMU~ ANGLE: 6~.9 MAXIMU~ ANGLE: 67.6 TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ................ ................ CDR A E ~ ATT[NUATION RES ~G$ 051 $ POREHOLE AND CASING DATA OPEN ~OLE SI~ SIZE (IN): DRILLERS CASING DEPTH (FT): ~REHOLE CONDITIONS NIJD !YPE: MUD DENSITY (LB/G): ~l!D VISCOSITY (S): ~UD P~: MUD CNLOKIDE$ 8.500 4100.0 LSND 10.40 42.0 23000 IS Tape. Verification :hlumberger AlasKa Computing Center 14-FEB-1995 16:37 gAXI[ !lt~ RECORDED TE~PER~,r.,IRE (DE(:,~ TIVlTY (OH~M) ~ ~,E~'PERATURE, DEGF): REStfUl) AT MEASURED-E~P~RA'rURE CAT): M'[]D AT ~'llX CIRCULATING TEMP~]RATURE : MUD FII.,TRATE AT MUD CAKE AT (~T): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL $'TA.,.,tDO~ F (IN EWR"' FREQtlE~!CY (~{Z):: 1,45,0 2,~10 2,680 O,O00 8.500 I. 000 Res To Bit: 57.46 ft gr To Bit,: 67.88 it Drilled Interval: 8083f to 13,14.061, CDR only !ogging tool iD BNA this Data fro~ downhole memory Downhole software $ IL, IS FORMAT DATA 68,0 6~,0 ,0 PACE: ** DATA FORNAT SPECIFICATION RECORD ** SET TYPE - 64EB ** ...-..-.,,,...-..--.-,,-..-- TYPE R COD~; LUE I 6 b 0 2 66 0 3 73 28 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 3~ 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 1. 0 66 1 Tape Verlftcatlon Listing chlumberger A].aska Co. Put ng Center 14-FEB-1995 16:37 PAGE: ** SET TYPE - CHAM ** APl F ROD N 0 2 0 2 0 2 0 2 0 2 0 2 0 2 NAME SERV UNIT I D D~PT FT 619 GR LWl GAPI 61.9 ROPE LW! F/HR 619 TAB LWl HR 619 ATR LW1 OHM~ 619 PSR LW1 OMM'M 619 DER LW1 OHMM 619 VICE AP1 APl APl ER # bOG TYPE CLASS 02.4 00 000 O0 024 00 000 00 024 00 000 00 024 00 000 O0 024 00 000 00 024 00 000 00 024 00 000 O0 NUMB NUmB SIZE REPR PRGCES~ SAMP. EbEM CODE. (HEX) 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 ** DITA ** DEPT 13406,500 ~TR.:,I,,W1 '999.250 DEPT 13000.000 D~PT. ~500.000 AT~,LWI 3,512 DEPT, 12000,000 ~T~..[,Wl 5,200 DEPT. 11500.000 ~T~.LWt 3.773 DEPT. i!.000.000 ATR,LW1 2,1~6 DEPT, 10500,000 5T~,LWl 3.238 DEPT, 10000.000 ~T~,I~W1 2.890 DEPT, 9500.00() ATR.bW! 3.217 DEPT, g000.00O AT~.LW~ 3.587 DFPT 8500.000 AT~:I, W1 3.464 DEPT. 8000.0C'U GR:.[.,W1 :999.250 ROPE.LWl 45.500 TAB.LWl PSR'I,,wl 999.250 DER.bWl -999.250 GR.UWl 114.050 R0PE.hWX 245 ~11 PSR,LWl 4.007 DER,IaWI 2:_ GR,LW! 190 2~1 ROPE,hWI 151,450 TAB,L~I PSR,Lw1 6~4 5 DER,I,w! 4,671 GR,LWI 102.0'74 ROPE,LW1 130.282 TAB,LWl PSR,LWI 10,074 DER.LWI 7.208 GR.,LWI ~40.237 ROPE,LWl 146,141 PSR,LWl 4,734 DER,LW1. 4.318 GR.LW1 1,66,849 ROPE,bW1 117.114 TAB,LW1 PSR.LWl 4.090 DER.LW1 ~.837 GR.LW1 93.661 ROPE.LWl 1.81.643 TAB.LW1 PSa.bWl 3.846 DER,LWl 3.589 GR,LWl 78.a51 ROPE.LWl 141.255 TAB.LWl PSR.LWl 2,921 DER.LWl 2,910 GR.LW1 80.730 ROPE.LW1 142.386 TA8,LW1 PSR,LW1 3,~94 OER,LW1 3,266 GR.LWl 8~,563 ROPE,LW1 1.68.581 TAB,LW1 PSR.I.,W1 3,502 DER,LWl 3.530 GR,LWI 105.679 ~OPE.LW1 165.912 TAB.LWI PSR,LW1 3.478 DER.L~I 3.473 GR.LWl 96.54t ~OPE.LWl -999,250 TA~.LWl PSa. LWl 3.508 I.)ER,LWl 3.465 -999,250 0.539 0,686 0.481 0,628 0.974 0.294 0.628 0.§94 0.540 0.302 -999.250 lumberger AlasKa Comput n~ Center DEPT. 988 000 GR.LWl AT~.LWI -999. :250 PSR.LWl END OF DATA 14-F~B.-!995 I6:37 98.213 ROPE.LW! -999.250 DER.5~!I -999.250 -999,250 PAGE: -999.250 FILE NAME : EDI1 ,002 $~:RVICE : FL!C VERSION : O0~CO1 DaTF : 95/02/1,4 ,~aX REC SIZE : 10~4 F!LV TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE: NAM, E : .EDIT DAT~',: : 95,102/1,4 ORIGIN : FLOC TAPE NA~ : 95012 CONTINUATION ~ : ~ PREVIOUS TAPE : COMMENT : BP EXPLORATION, MPE-IO, MILNE POI~T, API 50-029-22521 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/02/14 ORIGIN : FblC REEL NA~E : 95012 CONTINUATION ~ : PREVIOUS REEL COMMENT : BP EXPLORATION, MPE-1. O, MiLNE POIiqT, APl 50-029-22521