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198-128
Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 InspectNo:susKPS250809174612 Well Pressures (psi): Date Inspected:8/9/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:9/8/2019 #318-241 Tubing:0 IA:0 OA: Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/4/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT E-33 Permit Number:1981280 Wellhead Condition All Valves in working order and had good gauges on tubing and IA well is a monobore. Surrounding Surface Condition Area was in good condition with no debris or trash no visible sheen Condition of Cellar No water in cellar or debris no visible sheen Comments Location was verified with pad map Supervisor Comments Photos (3) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, September 22, 2025 2025-0809_Suspend_MPU_E-33_photos_ksj Page 1 of 2 Suspended Well Inspection – MPU E-33 PTD 1981280 AOGCC Inspection Rpt # sus250809174612 Photos by AOGCC Inspector K. StJohn 8/9/2025 2025-0809_Suspend_MPU_E-33_photos_ksj Page 2 of 2 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,793 feet 5,125 feet true vertical 4,404 feet N/A feet Effective Depth measured 5,125 feet feet true vertical 4,293 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / J-55 / EUE 8rd 5,037' 4,261' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: N/A 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 2,670psi 5,410psi 4,040psi 10,540psi Burst 5,380psi 7,240psi 4,810psi 10,160psi Surface Production 13-3/8" 7" 5-1/2' 38' 150' measured N/A Liner Casing Conductor Size Junk Length 5,508' MILNE PT UNIT E-33 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-128 50-029-22898-00-00 Plugs ADL0025518 /ADL0047437 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data WINJ WAG Water-Bbl MD 150' measured 38' 4,397' 4,404' 38' 2,339' TVD 150' Oil-Bbl measured true vertical Packer 7,792'3-1/2" 5,546' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:20 am, Oct 09, 2020 Chad A Helgeson 2020.10.01 10:19:24 -08'00' DSR-10/12/2020 RBDMS HEW 11/12/2020 Suspension MGR12OCT2020 SFD 10/12/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 0 OA NA Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Monobore well. Location verifed by Pad map WBS Pictures Area map Yes Yes Onshore 09/18/20 Subsequent Good, Clean, No leaks Good, Clean STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPE-33 (907)240-4383 Follow Up Actions Needed: Hilcorp 198-128 Condition of Surrounding Surface Location: 06/14/18 318-241 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPE-33 Suspended Well Inspection 9-20-20 DATE REV. BY COMMENTS MILNE POINT UNIT WELL E-33 KOP @ 300' Max. hole angle = 77 deg.@ PCP Hole angle thru' perfs = 90+ deg. 20" 91.1 ppf, H-40 115' 5.5" 15.5 ppf, J-55, Btrc. prod. casing ( drift ID = 4.950", cap. = 0.0238 bpf ) 2 3/8" 4.70” ppf, J-55, 8 rd EUE tbg.. ( drift ID =1.995 ", cap. = 0.00387 bpf ) eue 8rd T&B / 2" CIW H BPV profile O 5.5” Port Collar Cementer 1,047’ md 5.5" float collar 5.5" float shoe 5,461’ md 5,546’ md 08/27/98 MDO Drilled and ESP Completion Nabors 27E 7” 26#/ft L-80 7”x 5.5” X-Over38’ Camco 2 3/8" x 1" sidepocket KBMM GLM 140’ KUDU 100TP/1800 PCP, Centrilift seal section fst3dbilhspfsaflasuthsn Centrilift FMH series, 54 hp motor, 1020 v. / 35 amps. [ 9:01 Gear Box ] Centrilift PHD Camco 2 3/8" x 1" sidepocket KBMM GLM 4,649’ Centrilift flex shaft 4,747’ 4,735’ 4,733’ 4,687’ 2-3/8” HES XN-Nipple ( 1.791” id )4,675’ 3,500’ Centrilift heat trace Baker Float shoe 7,792’ 3.5” 9.3 #/ft slotted liner 5,609’ - 7,729’ Baker 5.5” x 3.5” C-2 setting sleeve 5,453’ intake tvd 4,098’ 90 deg. + 5,700’ to pbtd Note: The liner was set with the Drop and plop method !!! No Cement 4405’ TVD 4404’ - 4408’ TVD 4403’ TVD 4390’ TVD 4418’ TVD Kill String - to +/-4,900' md 3-1/2", 9.2#, L-80, 8rd EUE TOC @ 5,125' SLMD Kill String Tail 5,037' SLMD I Suspended Well Inspection Review Report inspectNo: susBDB200921140321 Date Inspected: 9/20/2020 Inspector: Brian Bixby Type of Inspection: Initial Well Name: MILNE PT UNIT E-33 Date AOGCC Notified: 9/18/2020 " Permit Number: 1981280 Operator: Hilcorp Alaska, LLC Suspension Approval: Sundry 318-241 Operator Rep: Jon Arend Suspension Date: 9/8/2019 Wellbore Diagram Avail? Location Verified? W Photos Taken? ❑� If Verified, How? Other (specify in comments) ' Offshore? ❑ Well Pressures (psi): Tubing: 0 - Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Wellhead Condition All of the valves on the appeared in good working order with working gauges on the Tubing, IA and OA. There are no VR Plugs or BPV installed. Condition of Cellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. rr=.!r ling Surface Condition Everything looked good. I did not see debris or sheen around the pad. Comments I verified the location using the pad map. No OA (monobore completion). ' Supervisor Comments Photos (2) attached Monday, September 28, 2020 r_ O L) W Q C5 N 0) 0 0 (N m D m U) 4t U Q) � C C) CL QU N O 0 00 N co rn D H a. MEMORANDUM TO: Jim Regg 1eh, 16115111 P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 25 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Bill Kruskie Bottom - Casing/Tubing Data (depths are MD): Conductor: 13 3/8" - O.D. Shoe@ Surface: O.D. Shoe@ Intermediate: O.D. Shoe@ Production: 7" x 5 1/2" ' O.D. Shoe@ Liner: 31/2" O.D. Shoe@ Tubing: O.D. Tail@ Plugging Data Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 8, 2019 SUBJECT: Well Bore Plug & Abandonment MPU E-33 — Hilcorp Alaska LLC PTD 1981280; Sundry 318-241 13N Range: 10E Meridian: Umiat - n/a Total Depth: Bottom - Lease No.: ADL 025518 ' 5250 ft MD Suspend: X P&A: N/A N/A Casino Removal: 150 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet Feet Csg Cut@ Feet 5546 Feet Csg Cut@ Feet 7729 Feet Csg Cut@ Feet Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bottom - 7792 ft MD 5250 ft MD N/A OA N/A N/A N/A Initial 15 min 30 min 45 min Raoult Tubing 1696 1594 1539 ` IA 1732 1634 " 1570 P OA N/A N/A N/A Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Witnessed a passing pressure test of a well suspension plug. Well has 3 1/2" kill string installed to 4900 ft MD. Attachments: none rev. 11-28-18 2019-0908_Plug_Verification_MPU_E-33_bn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug PerforatonsTT Fracture StimulateLi Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑� Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well[—] Re-enter Susp Well ❑ Other: Res. Abandon ❑ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Stratigraphic ❑ Exploratory ❑ Service ❑ 198-128 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22898-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL00255181 ADL0047437 MILNE PT UNIT E-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 7,793 feet Plugs measured 5,125 feet true vertical 4,404 feet Junk measured N/A feet Effective Depth measured 5,125 feet Packer measured N/A feet true vertical 4,293 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 150' 150' N/A N/A Surface 38' 7" 38' 38' 7,240psi 5,410psi Production 5,512' 5-1/2" 5,546' 4,397' 4,810psi 4,040psi Liner 2,351' 3-1/2" 7,792' 4,404' N/A N/A Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-3/8" 6.4# / J-55 / EUE 8rd 5,037' 4,261' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:1 0 0 0 0 0 Subsequent to operation: 10 0 0 0 0 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory E] 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 Q SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-241 Authorized Name: Chad Helgeson .,,/ Contact Name: Taylor Wellman' '''- Authorized Title: Operations Manager Contact Email: twellman(Whllcorp.com Authorized Signature: Date: 9/17/2019 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 3kI - 1-2-. Ili RBDMS'!'"'"5EP 2 01019 Submit Original Only Tree, 2 1/16" 5M Gray I ad: 71/16"5M Gray Tbo.. Hng: 2 3/8" x 7" Gray w/ 2 3/8" eue 8rd TB,B / 2" CIW H BPV profile 20" 91.1 ppf, H40 115 KOP @ 300' Max. hole angle = 77 deg.@ PCP Hole angle thm' perfs = 90+ deg. Kill String - to +/-4,900' and 3-1/2", 9.2#, L-80, 8rd EUE 5.5" 15.5 ppf, J-55, Btrc. prod. casing ( drift ID = 4.950", cap. = 0.0238 bpf ) Kill String Tail 5,037 SLMD TOC @ 5,125' 5.5" float collar 5,461'and 46'and5.5floa5 4418' TVD 08/27/98 1 MDO Prillec 10/16/98 NDC Repls 9113/2018 TDF Place MPU E-33 Ong. GL Elev. = 23.10' (N 27E) 7—REDF csg. hng. = 31.70' (N 27E) 7" 26#/ft L-80 F3W]7"x 5.5" X -Over 5.5" Port Collar Cementer 1,047' and I Baker 5.5" x 3.5' C-2 setting sleeve 5,453' . 4390'TVD 3.5" 9.3 #/ft slotted liner 4404'- 4408' TVD 90 deg. t 5,700'to pbtd 4405' TVD Baker Float shoe 7 792 4403' TVD Note: The liner was set vnth the Drop and plop method !1! No Cement MILNE POINT UNIT and ESP Completion Nabors 27E WELL E-33 :e heat trace, move pc Nabors 4 ES API NO: 50-029-22898 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Project Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 I-Rig 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Operations Summary: The overall scope of this operation was to perform a reservoir abandonment of MPU E-33 for drilling the re-development of the Schrader OA sands in the area. The lateral section of MPU E-33 was isolated in 2018 using the I-Rig and coil tubing. The initial tag and pressure test of the cement in the lateral failed with ^'S' of the slotted liner uncovered. Coil tubing then laid in another plug to bring the TOC to 5,125' and (top of slotted liner is at 5,609' md). Cement was laid over the entire lateral, where an MIT was conducted before cement was set up and didn't initally pass. The cement was allowed to cure and subsequent pressure tests of the cement plug to 1,500psi passed on 8/21/19 as well as an AOGCC witnessed CMIT-TxIA to 1,500psi on 9/8/19. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 ]-Rig 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations: 7/3/2018 -Tuesday No activity to report. 7/4/2018 - Wednesday No activity to report. 7/5/2018 - Thursday No activity to report. 7/6/2018 - Friday No activity to report. 7/7/2018 -Saturday No activity to report. 7/8/2018 -Saturday No activity to report. 7/9/2018 -Sunday Continue hooking up interconnects. Lay herculite, set rig mats and cuttings box. Hook up and turn steam and water on. On high -line power at 08:30. Scope derrick. Bridle down. Prep pipeshed for tubing laying out herculite. Took on 290 bbls of sea water and begin heating. Floow lines and prime pumps. Work on rig acceptance checklist. Check pressure on well, 100psi on tubing, 0 on annulus. Spot flow back tank and hook up. Rig up on tree and establish circulation down the tubing 1 bpm 575psi staging up to 3.5 bpm 1,050psi. Once mostly seawater is observed at surface stage pumps up to 4.25 bpm/1,200psi to try and clean well up. Pump a total of 300 bbls monitoring returns in the cellar, 8.4 ppg returned. Shut down and monitor. Opsi on tubing 30psi on annulus. Bleed off annulus. check pressure Opsi. Open bleeder - well is static. Rig down and blow down kill lines. Install BPV. N/D tree. Inspect hangerthreads. Prep cellar to N/U. N/U BOPE. Install 7-1/16" x 11" DSA, spacer spool and 11'x 13-5/8" DSA. Set BOPE and torque flanges. N/U choke and kill lines. Install riser. Obtain RKB's. C/O upper pipe rams to 2-3/8" solid. Rig up accumulator lines and function test. Pull BPV. Set TWC. Make up test joint, Dart, TIW, side entry, X0. Rig up testing equipment. Flood stack and fill lines. Bleed air. Attempt to shell test, valve on test manifold leaking. C/O valve, purge air. Test BOPE's 250/2,500psi on 2-3/8" and 3-1/2" test joints. AOGCC right to witness test waived by Matt Herrera. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 I-Rig 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations: 7/10/2018-Tuesday Continue test BOP to 250/2,500psi. Test UPR to 2-3/8" Pipe size. Test VBR's to 2-3/8" & 3-1/2" Pipe size. IBOP Failed. C/O same and Retest Pass. Accumulator Test: Innitial 3075psi, After close 1,500psi , 200psi build 20 sec, Full recovery 96 sec. Test Gas alarms and PVT System All Pass. Test W itnes waived by Matt Herrera. R/D test equipment. Pull TWC. M/U landing joint to Tbg Hanger. MU Top Drive to landing Joint. Circulate well with 120 deg sea water, pump Dn Tubing take returns through IA to flow back tank @ 5 bpm/1,500psi. Circulate 170 bbls total with clean SW @ surface. B.O.L.D.S. Pull tubing hanger off seat @ 67K. Pull hanger to floor. Monitor well on Trip tank while Rig up to lay down ESP/Heat trace x 2-3/8" tubing. Blow down circulating line to flow back tank. Rig down Hawk Jaw tongs, remove same from floor. Rig up Weatherford and Centrilift equipment. Loss rate to formation about 7 bph. PJSM W/ all parties. POOH L/D 2-3/8" X 7" Gray W/ 2-3/8" EUE 8 Rd T & B Hanger. L/D 2-3/8" 4.7#, J-55, 8 Rd EUE Tubing, Cable Guards, Flat MLE Cable and Heat Trace F/ 4,715 to 4,607' MD , Run ESP and Heat Trace over sheave to spooler unit. L/D One Camco 2-3/8" X 1" sidepocket KBMM GLM and pups. Cont. to L/D 2-3/8" F/ 4,607' to 3,822' MD. While POOH and using air chisel to remove bands and guards, chisel 6" long and 3/4" OD came out of air gun and fell down hole past hole cover and Herculite. Shut down and drain stack. Inspected the possum belly, flow line and BOP body cavities. Was unable to see chisel. Decision was made to Cont. to POOH. Cant to POOH L/D 2 3/8" 4.7#,1-55, 8 Rd EUE Tubing, Cable Guards, Flat MLE Cable and Heat Trace F/ 3,822' to 1,461' MD 105 Joints) Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 I -Rig 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations: 7/11/2018 - Wednesday Continue POOH from 1,461'to 71'. Total Flat gaurds recovered(585). Total Steel Bands Recovered(2049) Calculated hole fill 9.1 bbls actual 72.2. Initial loss rate @ 7.5 bph Dn to 5 bph.With top of ESP Mtr just below wellhead, attempt to look for and retrieve Chisel that had fallen down hole. Could not see chisel. Did see waded up Mtr Lead. Continue POOH and found Chisel wedged in between Mtr Lead and Mtr Lead clamps. Recovered lost Chisel. Continue to L/D pump assy.Clean and Clear Rig Floor. R/D Baker Centrilift equipment. R/U Weatherford and 3 1/2" Handling equipment.TIH P/U 3 1/2" Eue 8 rd L-80, 9.3# Kill String to 5,021' MD. M/U TRQ 3,100#. P/U 72K, SLK 66K, P/U M/U Hanger with TWC and landingjoint. Blow down surface lines and drain stack. Land hanger at 5,026' MD with 31K. Fluid lost 22.4 bbls. R/D Weatherford tools and Equip. Clean and clear rig floor.0/O 2 3/8" Rams to 2.875" X 5.5" Variable Pipe Rams. Pull Riser and install air boot saver. Remove Choke and Kill lines F/ Stack and flange together, flush through MP #1 & 2. Flush Kill line, choke manifold, both MP Pop Offs and blow down. Install Bridge Cranes.Remove safety chains. Unflange Stack F/ DSA and set back on stand and secure. Remove both DSA's and spacer spool, prep cellar to install Tree.PJSM Install Tree as per NOS. R/U Test Equip. Test neck seal and void to 500 PSI low and 5,000 PSI high for 5 Min. Test Tree to 500 PSI low and 5,000 PSI high on chart. All witnessed by DSM onsite. SIMOPS Bridle up to scope down Derrick.PJSM Scope Derrick down, secure lines, stage weight bucket on sub Ianding.Off load 100 bbl H2O, blow down water lines. R/D Mez inner connect mud lines. Prep Pipe Shed for move. Prep cellar to move. Shut in Boiler and blow down lines. Prep roof tops for move. Drain MP 1 & 2. R/D cutting box and stage for move. 7/12/2018 -Thursday No activity to report. 7/13/2018 - Friday No activity to report. 7/14/2018 -Saturday No activity to report. 7/15/2018 -Sunday No activity to report. 7/16/2018 - Monday No activity to report. 7/17/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 CTU#6 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations: 8/8/2018 - Wednesday No activity to report. 8/9/2018 - Thursday No activity to report. 8/10/2018 - Friday No activity to report. 8/11/2018 -Saturday MIRU CTU #6 w/ 2" coil.. Perform BOPE body test and function rams to 250 psi and 3,500 psi high. No leaks. M/U BHA #1: 2" Dimple connector, 2" DFCV, 2" xo, 2x 2" weight bar, 2" Jet swirl nozzle. DAL = 9.84'. M/U injector and PT to 250 psi and 4,000 psi. Good test. Open well. RIH and tag hard at 587'. IA pressure climbing from 550 psi to 800 psi and continuing to climb to 1,000 psi without pumping or RIH. Bleed IA from 1,000 psi to 50 psi in 1 minute. Fluid returns. Begin pumping 1% KCL at 1.5 BPM. Begin jetting at 2 BPM and setting 5k down. RIH at 1 to 5 fpm. When hot water was circulated IA pressure broke instantly from 200 psi and climbing to going on a vac. Likely ice in IA that was thawed. Continue to jet on probable ice at 1.5 BPM while holding 1,000 psi on tubing. RIH at 0.5 to 2 fpm. Setting down 7k -lbs. Decision made to POH and M/U motor and mill. POH from 708'. M/U motor and mill. P/T to 250 low and 4,000 psi high. RIH w/ motor and mill to 708'. Circulate at 1.5 BPM. Mill ice from 708' to 1,630' break through. Continue RIH from 1,630' without pumping to TD'. Tag TO at 7,782'. POH to 5,400'. At 5,400', come online at 1.5 BPM. Circulate 50 bbls and get 25 bbls in returns. POH to surface at 80 fpm. At surface. Close Swab. Break and L/D BHA. Make up ball drop nozzle BHA. SDFN. 8/12/2018 -Sunday M/U injector and PT to 250 psi and 4,000 psi. Good test. Open well. WHP = 0 psi. RIH to TD. P/U at 4,800' is 16,500 -lbs. Unable to pass into 3.5" liner at 5,433'. Line up LRS on the IA and pump 60 bbls of diesel. Attempt to enter liner while LRS bullheads diesel. Unable to pass into 3.5" liner at 5,433'. POH to cut pipe. Cut pipe and rehead. M/U 2" ball drop nozzle BHA: 2" Dimple connector, 2" xo, 2 x 2" Straight Bar, 2 x 2" Straight Bar, 2" xo, 2" ball drop JSN. M/U injector and PT to 250 psi and 4,000 psi. Good test. Open well. WHP = 17 psi. RIH to TD. Unable to pass into 3.5" liner at 5,433'. POH to surface. M/U 2" ball drop nozzle BHA: 2" Dimple connector, 2 x 2" Straight Bar, 2.28" Centralizer, 2" xo, 2" ball drop ISN. DAL = 14.02". M/U injector and PT to 250 psi and 4000 psi. Good test. Open well. WHP = 0 psi. RIH to TD. Tag TD at 7,782'. Pump 15 bbl gel sweep. Chase gel sweep out of hole to surface. 75% returns. RBIH to TD. R/U Cementers. PJSM. Mix cement. Tag TD at 7,782'. Pump 11 bbls of diesel down tubing. Pump 5 bbls fresh water. P/T cementing hardline to 250 psi and 4,000 psi.Pump 33.5 bbls of 15.8 ppg cement while taking returns to IA and to tank. Pump 15 bbls fresh water. Once 1 bbl of cement out of nozzle, laid in the rest 1:1. Pump 30 bbls PowerVis. Pause at 5,600' and squeeze 3.5 bbls of cement. Pressure built 50 psi. POH to 5,000' and squeeze 3.5 bbls of cement away.IA and Tubing built from 240 to 440 psi. RIH and contaminate down to 5,250'. POH chasing returns to surface. At surface. Close swab. Rinse BOP stack. Stand back injector. SDFN. 8/13/2018 - Monday M/U Injector. P/T to 250 psi low and 4,000 psi high. RIH and tag TOC cement at 5,640'. POH to surface. Freeze protect IA with 30 bbls of McOH. Freeze protect tubing with 24 bbls of McOH. RDMO. 8/14/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 CTU #6 50-029-22898-00-00 198-128 7/9/2018 1 9/8/2019 Daily Operations: 9/5/2018 - Wednesday No activity to report. 9/6/2018 - Thursday No activity to report. 9/7/2018 - Friday No activity to report. 9/8/2018 -Saturday No activity to report. 9/9/2018 -Sunday No activity to report. 9/10/2018 - Monday MIRU SLB CTU 6. Pressure test PCE to 300psi low/4,050psi high. Make up Cement BHA with stinger to get into liner. Laid in 9 bbls of class G 15.8 # Cement from 5,640 to 5,115'. Squeeze in .75 bbls. Pressure up to 500 psi. Bleeding slowly down to 99 psi.. Clean out hole above plug and RD CTU. Wait on cement to tag and pressure test. 9/11/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 SL & Pump 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations: 9/12/2018 - Wednesday No activity to report. 9/13/2018 - Thursday WELL 5/1 ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/1,500H. TAG CEMENT AT 5,125' SLM WITH 2/75" CENT AND SAMPLE BAILER (small amount of cement in bailer bottom). TAG BOTTOM OF KILL STRING WITH 3-1/2 TEL AT 5,037' SLM. T/1=30/55 Inj Test/ CMIT TAA (Cement) Pump 0.7 bbls 60/40 tbg pressured up to 1,000psi. CMITTxIA Inconclusive to 1,000psi F W H Ps=260/260. 9/14/2018 - Friday No activity to report. 9/15/2018 -Saturday No activity to report. 9/16/2018 -Sunday No activity to report. 9/17/2018 - Monday No activity to report. 9/18/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 Slickline 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 Daily Operations, 8/14/2019- Wednesday No operations to report. 8/15/2019 -Thursday T/1=vac/vac CMIT TxIA PASSED to 1,000 psi (PT surface Equip. 250/1,500 psi) Pumped 0.88 bbl diesel down the IA to test. T x IA lost 47/44 psi 1st 15 min & 21/22 psi 2nd 15 mins Bled back to 0 psi (-0.8 bbl back) 8/16/2019 - Friday No operations to report. 8/17/2019 -Saturday No operations to report. 8/18/2019 -Sunday No operations to report. 8/19/2019 - Monday No operations to report. 8/20/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-33 Slickline 50-029-22898-00-00 198-128 7/9/2015 1 9/5/2019 Daily Operations. 8/21/2019 - Wednesday T/1=0/0 OMIT TAA (PASSED) to 1500 psi(P&A) (PT surface Equip. 250/2500 psi) Pump 1.2 bbls diesel down IA to test. 1st 15 min Tbg/IA lost 84/80psi. 2nd 15 min Tbg/IA lost 46/47psi. See log for pressures. Bled back —1.2 bbls FWHPs=0/0 8/22/2019 - Thursday No operations to report. 8/23/2019 - Friday No operations to report. 8/24/2019 -Saturday No operations to report. 8/25/2019 -Sunday No operations to report. 8/26/2019 - Monday No operations to report. 8/27/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API NumberWell Permit Number Start Date End Date MP E-33 Slickline 50-029-22898-00-00 198-128 7/9/2018 9/8/2019 9/4/2019 - Wednesday No operations to report. 9/5/2019 - Thursday No operations to report. 9/6/2019 - Friday No operations to report. 9/7/2019 -Saturday No operations to report. 9/8/2019 -Sunday AOGCC CMIT-TxIA to 1500 psi (PASSED) (Witnessed by Bob Noble) (PT surface Equip. 250/2500 psi) Pump 1 bbls Dsl to reach Test pressure. 1st 15 Min Tbg/ IA lost 101/98 psi. 2nd 15 Min Tbg/IA lost 56/56 psi. End Tbg/IA = 1539/1578psi. Bleed IA down w/ 0.9 bbls Dsl returned. 9/9/2019 - Monday No operations to report. 9/10/2019 -Tuesday No operations to report. �V OF TFJ� • • w �� s THE STA Alaska Oil and Gas �, of/® Conservation Commission LAsKik � tstt�t _ == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-8572 AF * P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager L U l Hilcorp Alaska, LLC SCANNED JUN 2 0 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-33 Permit to Drill Number: 198-128 Sundry Number: 318-241 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Commissioner DATED this • day of June, 2018. RBD vis z_i 142018 • • RECEIVED STATE OF ALASKA 6// i 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION p� APPLICATION FOR SUNDRY APPROVALS O�„,jj GCC 20 AAC 25.280 i 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdpwn❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other.Res.Abandon E. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 198-128 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22898-00-00 . 7.If perforating: 8,Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 • Will planned perforations require a spacing exception? Yes ❑ No LI MILNE PT UNIT E-33• 9.Property Designation(Lease Number): �Ay 10.Field/Pool(s): ADL00474371/41>Z-Ce)2-61577 MILNE POINT/SCHRADER BLUFF OIL 11. e�4,i(,j 3 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,793' . 4,404' . 7,790' 4,404' 1,236 N/A N/A' Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 150' 150' N/A N/A, Surface 38' 7" 38' 38' 7,240psi 5,410psi Production 5,512' 5-1/2" 5,546' 4,397' 4,810psi 4,040psi Liner 2,351' 3-1/2" 7,792' 4,404' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-3/8" 6.4#/J-55/EUE 8rd 4748 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development❑✓ Service l 14.Estimated Date for 15.Well Status after proposed work: 6/23/2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑., 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman "Trreit Authorized Title: Operations Manager Contact Email: twellman( hilcorD.com Contact Phone: 777-8449 Authorized Signature -- Date: S53%,..-- L t.1 ' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 ci ��^ Zu l Plug Integrity BOP Test Mechanical Integrity Test Li Location Clearance ❑ Other: eCieL r 8ao TCST %(�° 2-57,0?'/' n I La'R 4,4zD �4 c. aSiiz 4) ey) ArE %c RE -s7 f /v7 W.i- 'E� 6 ,� ,�©G Ge- Post GPost Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: fi;19,../....4-7-4---- / APPROVED BY Approved by: CV .L. COMMISSIONER THE COMMISSION Date: rp -1 —1 S RiDMSNQ Iz so"'-2g� ORIGINAL 641 Submit Form and Form 10-403 e d'4/2014 24 Approved application is valid for 12 months from the date of approval. Attach ents in Duplicate 4-l/fe •• • Reservoir Abandonment Well: MPU E-33 Ililwrt)Alaska,LL Date: 06/06/2018 Well Name: MPU E-33 API Number: 50-029-22898-00 Current Status: SI Oil Well [ESP] Pad: MPE-Pad Estimated Start Date: June 20th, 2018 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-128 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: WellEZ Entry Required: Yes Current Bottom Hole Pressure: 1,636 psi @ 4,000'TVDss (SBHPS 02/21/18/7.9 ppg EMW) Maximum Expected BHP: 1,636 psi @ 4,000'TVDss (SBHPS 02/21/18/7.9 ppg EMW) MPSP: 1,236 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPE-33 was drilled and completed in October 1998. The well was completed as a monobore ESP producer in the Schrader OA sands. The well seemed to be very baffled and isolated from any reservoir pressure support as the pressure and production declined rapidly. The ESP failed in September of 1999 and was briefly able to be brought back online from July-November 2000 before fully failing. The well was deemed uneconomic for RWO ✓ and has remained shut in since this time. Notes Regarding Wellbore Condition • The 5-1/2" casing has not been tested since original installation in October 1998. Objective: To abandon the entire horizontal lateral with cement. The planned redevelopment pattern for the E-Pad Schrader reservoir requires this wellbore to be isolated to help prevent potential MBE's. Pre-Rig Procedure: r CpgGGrA ‘(01 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Reservoir Abandonment Well: MPU E-33 Hilcorn Alaska,LL1 Date:06/06/2018 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-3/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5ppg seawater as needed. 15. RU spoolers and MU landing joint or spear and PU on the tubing hanger. a. The PU/SO weights during the 1998 ESP install were 43k/42k. Block weights were not noted. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-3/8" tubing. Tubing will be re-used for the kill string. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over-torqued connections from previous tubing runs. c. ell e.s 3,500' of heat trace; 4,747' of ESP cable, 535 flat guards and 1943 flat bands. 18. RIH w/2-. kill string to ±4,900' md. gr 19. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Pump a short freeze protect down the well (Tbg and IA) to 500' and (±llbbls). II Reservoir Abandonment Well: MPU E-33 IIilcorn Alaska,LL1 Date:06/06/2018 21. Bleed tubing to 0 psi. 22. Lay down landing joint. Set BPV. Post-Rig Procedure: 23. Begin RD of ASR. RD BOPE house. 24. RU crane. ND BOPE. 25. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 26. RD crane. Move to next well location. Move 500 bbl returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. 29. Pump truck to freeze protect well to 2,500' and (±56bbls). Coil Tubing Procedure: 30. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 31. Pressure test BOPE to 250psi low/3,500psi high, 10 min each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 32. RIH w/ 1.75" nozzle and begin FCO of liner. a. Attempt to circulate and gain full returns to surface w/seawater and gel sweeps. b. If unable to gain returns, circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. I 1 W5 33. MU ball drop cementing nozzle and RIH to TD or d pest depth reached during FCO. 34. Bullhead ±60bbls of diesel down the IA and + Is of diesel down the CTxTbg. This should provide ^'100psi positive wellhead pressure after the cementing is completed. 35. Begin to mix cement. Once blend is up 15.8ppg, pump ±35bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. Line up to take returns from the IA. 36. Allow"1bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle. b. Pause at 5,600' and and attempt to squeeze some cement(±5bbls) until a bump in pressure is observed. c. Estimated TOC @ 5,045' and if laid in 30bbls of cement. 37. PU to safety and attempt to squeeze away±5bbls of cement. a. Estimated TOC @ 5,255' md. 38. Swap to contaminate and RIH to cleanout to 5,250' md. 39. POOH and circulate coil tubing clean as needed. �f a. Freeze protect well on way out of hole. �'// `/ J 40. Wait on cement to gain 1000psi compressive strength. z7fi octrNo�,ae714O6eC b* LIO`�� Pressure test casing to 1,500psi for 30 min charted. /5" ,,O5iG��z"� fest 7 42. Contingency: If failed pressure test of the casing and cement plug. rQ C. a. MU logging tools and conduct leak detect log. b. Re-squeeze cement down into liner as needed. • Reservoir Abandonment Well: MPU E-33 Hileorp Alaska,LL Date: 06/06/2018 43. RD CT unit. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen & Foam Flow Diagram 6. Blank RWO Sundry Change Form S • Tree: 2 1/16"5M Gray Orig.DF Elev.= 56.61'(N 27E) Wellhead: 7 1/16"5M Gray MPU E-33Orig.GL Elev.=23.10' Tbq.Hng: 2 3/8"x 7"Gray w/2 3/8" ' DF csg.hng.=31.70'(N 27E) eue 8rd T&B/ 2" CIW H BPV profile 7"26#/ft L-80 20" 91.1 ppf,H-40 115' 38' 7"x 5.5"X-Over KOP @ 300' Camco 2 3/8"x 1" 140' sidepocket KBMM GLM Max.hole angle=77 deg.@ PCP Hole angle thru'pelf's=90+deg. a 0 5.5"Port Collar Cementer 1,047'and 2 3/8"4.70"ppf,J-55,8 rd EUE tbg.. (drift ID=1.995",cap.=0.00387 bpf) 3,500' Centrilift heat trace 5.5"15.5 ppf,J-55, Btrc.prod.casing (drift ID=4.950",cap.=0.0238 bpf) I 3 Camco 2 3/8"x 1" I sidepocket KBMM GLM 4,649' I 2-3/8"HES XN-Nipple(1.791"id) 4,675' KUDU 100TP/1800 PCP, 4.687' Centrilift flex shaft intake tvd 4.098' Centrilift seal section fst3dbilhspfsaflasuthsn 4 733' Centrilift FMH series, IL 54 hp motor,1020 v./35 4,735' amps.[9:01 Gear Box] IMP mg Centrilift PHD 4.747' It 5.5"float collar 5,461'and �: Baker 5.5"x 3.5"C-2 setting sleeve 5,453' 5.5"float shoe 5,546'and 1 4390'TVD 4418'TVD 3.5"9.3#/ft slotted liner 5,609'-7,729' 4404'-4408'TVD 90 deg.+5,700'to pbtd 4405'TVD A Baker Float shoe 7,792' 4403'TVD Note:The liner was set with the Drop and plop method!!! No Cement DATE REV.BY COMMENTS MILNE POINT UNIT 08/27/98 MDO Drilled and ESP Completion Nabors 27E WELL E-33 10/16/98 MDC Replace heat trace,move pc Nabors 4 ES API NO: 50-029-22898 Hilcorp Alaska, LLC • • Tree: 2 1/16"5M Gray MPU E-33 Orig.DF Elev.= 56.61'(N 27E) Wellhead: 7 1/16"5M Gray Orig.GL Elev.=23.10' Tbg.Hng: 2 3/8"x 7"Gray w/2 3/8" I — DF csg.hng.=31.70'(N 27E) eue 8rd T&B/ 2" CIW H BPV profile Ill 7"26#/ft L-80 20" 91.1 ppf,H-40 115' A 38' 7"x 5.5"X-Over KOP @ 300' Max.hole angle=77 deg.@ PCP Hole angle thru'perfs=90+deg. 0 5.5"Port Collar Cementer 1,047'and Kill String-to+/-4,900' and 2 3/8", 4 7",--J-55, 8rd EUE 5.5" 15.5 ppf,J-55,Btrc.prod.casing J-+ (drift ID=4.950",cap.=0.0238 bpf) G • Cj-a s#1 (6 5 • <v it 1/410 3`g TOC @+/-5,250' and API 5.5"float collar 5,461'and Baker 5.5"x 3.5"C-2 setting sleeve 5,453' 5.5"float shoe 5,546'and 4390'TVD 4418'TVD 3.5"9.3#/ft slotted liner 5,609'-7,729' 4404'-4408'TVD 90 deg.+5,700'to pbtd 4405'TVD Baker Float shoe 7,792' 4403'TVD Note:The liner was set with the Drop and plop method!!! No Cement DATE REV.BY COMMENTS MILNE POINT UNIT 08/27/98 MDO Drilled and ESP Completion Nabors 27E WELL E-33 10/16/98 MDO Replace heat trace,move pc Nabors 4 ES API NO: 50-029-22898 Hilcorp Alaska, LLC • • Tree: 2 1/16"5M Gray MPU E-33 Orig.DF Elev.= 56.61'(N 27E) Wellhead: 7 1/16"5M Gray Orig.GL Elev.=23.10' Tbq.Hnq: 2 3/8"x 7"Gray w/2 3/8" DF csg.hng.=31.70'(N 27E) eue 8rd T&B/ 2" CIW H BPV profile 7"26#/ft L-80 38' Tx 5.5"X-Over 20" 91.1 ppf,H-40 115' KOP @ 300' Max. hole angle=77 deg.@ PCP Hole angle thru'perfs=90+deg. 0 5.5"Port Collar Cementer 1,047'and Kill String -to+/-4,900' and 3-1/2", 9.2#, L-80, 8rd EUE 5.5" 15.5 ppf,J-55, Btrc. prod.casing (drift ID=4.950",cap.=0.0238 bpf) TOC @ +/-5,250' and 5.5'float collar 5,461'and = Baker 5.5"x 3.5"C-2 setting sleeve 5,453' 74 5.5"float shoe 5,546'and �z a � 4390'TVD 4418'TVD 3.5"9.3#/ft slotted liner 5,609'-7,729' ���o. 4404'-4408'TVD 90 deg.+5,700'to pbtd 4405'TVD ' ire Baker Float shoe 7,792' 4403'TVD Note:The liner was set with the Drop and plop method!!! No Cement DATE REV.BY COMMENTS MILNE POINT UNIT 08/27/98 MDO Drilled and ESP Completion Nabors 27E WELL E-33 10/16/98 MDO Replace heat trace,move pc Nabors 4 ES API NO: 50-029-22898 Hilcorp Alaska, LLC .11 . •ne Point ASR Rig 1 BOPE fish.ip aim.ka.U. R. 2018 11" BOPE Stripping Head 4.48' vr ° ' ydril G ° 11" - 5000 lit Ill Ill !hal iii is!iii 111 i11 " 06 U ri 4.54' : 1111,011111 M�No° VBR or Pipe Rams MC ME :_. � 11"-: 500 0 Blind 11.i Mint't ' 1 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves - i1P111'11Pi11'111 iI -00 ;! .! 2.00' 1. . �II( ;'!�� . �, i k \ ,.ifi _ 111 -No) - It1.rIi.11 r Il6IE1'i Manual ' Manual111. Manual HCR Updated 1/05/2018 • . 11 • • STANDARD WELL PROCEDURE }Wog) ib ka.iii: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. i bumpproperly 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and tested p ope y to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 • 11 I Nil MN :1"...*: .. . . > ti 7. > _ ,-- a• E d w z ce 0, ce z ce . 0 w o. 0 wFt Cs 4:•: : :--- w u i P 0---2 P u o [r.., 0 •4002, 8 3 .4 0 „ 2 _____ m z ,.. ,.I iE La U. , Ce I C 6.7 ."•,. 0 ..% _ ) — .•: • 2 2 o I) . ._ . __. • . •,. Ft Fe 5 LI 7 z bk -,- E 7 o. q 0 e '... V (.9 •.. Z ri. 0 74 q > 2 ..0 2 •'-' .... _. IN MINIMMIN ".% . 03 co 2 : 2 i•••" '-'I "LE CS a' r: k. F, = o o :•-•..-:, ce o o in •• a x _ 4 iz 5 u 3 0 .c (.., ..,. • es A 4 4 .0.--- 4.- NM la PP- Z 1111IIMA -MC> . / A —1 > Ill e 51 rl..° Vo a• . 0 . 41(•-=1.. run 1 .----14 •. '.1'I h FilliMilli la I I' III I Ira -MSOlk dal 5. g = • . N Z i MI 4 1 ce a .... •-• co ,LE 1;-, ' 0 o ce V 111 Z—c--- . Ce 1.11 LLI i•-• 2 ct--- gm u• z Ill 1.1.1 •g( .... _.. I- '2 = _. 0 m an 2 o o. o D un -.1 0 0 o a I .:-. • • • X60 a)/ \ ƒ 2 oco ° _ / / >Ooto 0 2 2 2 §• o « ......- E -C. .....-E £ • c o . = 0 a) § Ytf cu d f- %f 0. % a » E < m / m =o \ \ 22 > Yat «m \ � 2e aD I a) cO � m CU •® °ra' % : 7 ca /0 k % % 27 / -' CD ka \ § 0 = E q \ 2 & Lu kf / ko � / /m " 41f) \ 2 k L. E § a_ O o ° 2 0 .g § / / L. . II _ /to ca c CO CU a 2 2 9 / ) a a ). Q R o 0 0 C.4 p .. ® 7 / % \ C.) § E / 2 CO ;2 U 0 $ C C 0 < a. f • • Rixse, Melvin G (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, June 12, 2018 11:15 AM To: Rixse, Melvin G (DOA) Cc: Schwartz, Guy L (DOA) Subject: MP E-33 (PTD #198-128) Reservoir Abandonment Sundry Application Attachments: MPE-33 PROPOSED Schematic 06-11-2018.pdf Mr. Rixse, I recently submitted a sundry application for the reservoir abandonment of well MP E-33 (PTD#198-128). As part of the abandonment it will require the ASR to pull the ESP completion and run a kill string. The kill string planned to be used was the existing 2-3/8" tubing. I would like to make a revision to this to run a 3-1/2" kill string. This will aide with the next portion of the job which is a coil tubing clean out/cementing the liner. any let me know if this email and attached updated schematic is enough or if you would like a y further information to accompany. Also the Sundry Change Form will be updated. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com • xoo Barrels of Oil per Month or Barrels of Water per Month o tp 0 CO LO ti O O 0 O 0 O O N m 1 oO O o o m .1 .1 .-1 .1 .4 .i w a 3 Fp 10 i � l � . �e.00 4Pr 2I 0 i 00 oI C° a Crla00 v a vv51 V U 7 7 r l 13 O K O O O. 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They are available in the original file and viewable by direct inspection. / / ~/ File Number of Well History File PAGES TO DELETE RESCAN Complete [] 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 Mildred Dareth~ Lowell Date: ""'~/'~ / Is~ ~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: ~si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder L 9 114\PE- - 3 3 Alaska Oil and Gas Conservation Commission - ° 333 West 7 Avenue Anchorage, Alaska 99501 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 external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, 2 ; Mehreen Vazir BPXA, Well Integrity Coordinator • 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/1012011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ I 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 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 -13B 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 9/6/2011 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 -weii compiianc Report File on Left side of folder 198-128-0 MILNE POINT UNIT SB Roll #1: Start: Stop Roll #2: MD p077_93 _ TVD 04404 Completion Date: E-33 50- 029-22898-00 Start Stop 10/15/98 Completed Status: 1-OIL BP EXPLORATION (ALASKA) 1NC Current: Name D 8731 L 4 ARM CALIPER L DGR/EWR4-MD L DGR/EWR4-TVD 1-5 R SRVY RPT Daily WelIOps _ ' -- Was the well cored? yes no Comments: Interval 2-5 SPERRY MPT/GR/EWR4 OH 11/18/98 11/18/98 FINAL 100-1820 CH 5 10/22/98 10/22/98 1-5 120-7793 OH 11/18/98 11/18/98 120-4407 OH 11/18/98 11/18/98 Sent Received T/C/D . SPERRY 0-7793. OH A2/18/98 12/21/98 Are Dry Ditch Samples Required? ye~:~/ And Received? yes no Analysis Description Received? yes (.~ Sample Set # Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well Classification °~fi~i~ [~Oil [~Gas I--I Suspended I--iAbandoned I--] Service 21 Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-128 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22898 4. Location of well at surface i .';.~. :.r~ i:~'~;','"; 9. Unit or Lease Name 4041' NSL, 2073' WEL, SEC. 25, T laN, R10E, UM ' .,z/~;~.~U/¢~. ~~~×..~/.- ~T------------'~.,: Milne Point Unit At top of productive interval i. . J ~"~Z-~... t 10. Well Number 407' NSL, 3092' WEL, SEC. 24, T13N, R10E, UM '~'~ ~~i MPE-33 At total depth ' i~ 11 Field and Pool 3060' NSL, 3549' WEL, SEC. 24, T13N, R10E, UM '~,........ Milne Point Unit / Schrader Bluff !5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and KBE = 56.61'I ADL025518 12. Date Spudded8/7/98 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband115' Water depth' if Offsh°re I 16' NO' °f COmpletiOns8/19/98 10/15/98 N/A MSL, One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 7793' 4404 FT 7790' 4404 FTI []Yes [] NoI N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 72# L-80 36' 150' 16" 260 SX Arctic Set (Approx.) 5-1/2" 15.5# J-55 34' 5546' 6-3/4" 891 sx Coldset III, 100 sx Foamed, 75 sx 'G' 3-1/2" 9.3# J-55 5441' 7792' 4-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 2-3/8", 4.7#, J-55 4748' N/A MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 48 bbls diesel 27. PRODUCTION TEST ~ ~ ! ~ ! I~, Date First Production I Method of Operation (Flowing, gas lift, etc.) U ~ i ~ I I~ ~ L October 24, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE ]GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Schrader Bluff 'N' Sands 5072' 4274' Top Scharder Bluff 'O' Sands 5586' 4405' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32.1 hereby cert/j~ t/hat t!~.,e for~is tr/u~///a~, d correct to the best of my knowledge 2~ .~/q Signed (.~./1Z¢~.(, .~, _/~ /./~~-,~ i-,- ..,, ,-ff Charles R. Mallary ~r~Nn *"' ~'~ /''1 Title Acting Engineering Supervisor Date M P E-33 ,'~-¢'~'~, -, c,--- 9~.~ 28 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 07 Aug 98 08 Aug 98 09 Aug 98 10 Aug 98 11 Aug 98 12 Aug 98 13 Aug 98 14 Aug 98 M Pt E Pad Progress Report Well MPE-33 Rig Naborsf~ Page Date 06:00-12:00 12:00-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-06:00 06:00-21:00 21:00-22:00 22:00-00:30 00:30-01:30 01:30-03:30 03:30-05:00 05:00-06:00 06:00-06:00 06:00-13:30 13:30-15:00 15:00-19:00 19:00-19:30 19:30-21:30 21:30-23:00 23:00-02:30 02:30-04:00 04:00-06:00 06:00-08:00 08:00-10:30 10:30-11:00 11:00-17:00 17:00-18:00 18:00-01:00 01:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-08:30 08:30-11:30 11:30-12:30 12:30-13:30 13:30-19:00 19:00-20:00 20:00-02:00 02:00-06:00 06:00-08:00 08:00-10:30 10:30-12:30 12:30-13:30 13:30-16:00 16:00-21:30 21:30-23:00 23:00-00:00 00:00-01:00 01:00-03:30 03:30-04:30 04:30-06:00 Duration 6 hr 3-1/2 hr 1 hr 1-1/2 hr 1/2 hr 1-1/2 hr 10hr 15hr 1 hr 2-1/2 hr 1 hr 2 hr 1-1/2 hr 1 hr 24 hr %1/2 hr 1-1/2 hr 4hr 1/2 hr 2hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 2 hr 2 hr 2-1/2 hr 1/2 hr 6hr 1 hr 7 hr 1-1/2 hr 2 hr 1 hr 1/2 hr 2-1/2 hr 3 hr 1 hr 1 hr 5-1/2 hr lhr 6 hr 4 hr 2 hr 2-1/2 hr 2 hr 1 hr 2-1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 1 hr 2-1/2 hr 1 hr 1-1/2 hr Activity Rig moved 100.00 % Rigged up Divertor Held safety meeting Made up BHA no. 1 Tested Divertor Made up BHA no. 1 Drilled to 1004.0 ft Drilled to 2916.0 ft Circulated at 2916.0 ft Pumped out of hole to 135.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 2916.0 ft Drilled to 3007.0 ft Drilled to 5150.0 ft Drilled to 5570.0 ft Circulated at 5570.0 ft Pumped out of hole to 1500.0 ft Serviced Top drive R.I.H. to 5570.0 ft Circulated at 5570.0 ft Pulled out of hole to 72.0 ft Pulled BHA Conducted electric cable operations Conducted electric cable operations Rigged up Casing handling equipment Held safety meeting Ran Casing to 3343.0 ft (5-1/2in OD) Washed to 3343.0 ft Laid down 3343.0 ft of Casing R.I.H. to 1870.0 ft Reamed to 2658.0 ft R.I.H. to 3326.0 ft R.I.H. to 5570.0 ft Circulated at 5570.0 ft Pulled out of hole to 840.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 3345.0 ft (5-1/2in OD) Ran Casing to 3382.0 ft (5-1/2in OD) Laid down 3382.0 ft of Casing R.I.H. to 3540.0 ft R.I.H. to 5570.0 ft Circulated at 5570.0 ft Pulled out of hole to 862.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 5546.1 ft (5-1/2in OD) Rigged up Cement head Circulated at 5546.0 ft Held safety meeting Mixed and pumped slurry - 207.800 bbl Rigged up Tubing handling equipment Ran Tubing in stands to 1047.0 ft 1 14 December 98 Facility Date/Time 15 Aug 98 16 Aug 98 17 Aug 98 18 Aug 98 19 Aug 98 20 Aug 98 M Pt E Pad Progress Report Well MPE-33 Rig Nabors,..4~~~ Page Date 06:00-09:00 09:00-11:00 11:00-12:30 12:30-13:30 13:30-17:00 17:00-20:00 20:00-22:00 22:00-00:00 00:00-06:00 06:00-11:00 11:00-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-20:30 20:30-01:00 01:00-04:30 04:30-06:00 06:00-07:00 07:00-11:00 11:00-17:00 17:00-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-00:00 00:00-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-00:00 00:00-02:00 02:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-22:30 22:30-00:00 00:00-01:00 01:00-03:00 03:00-04:30 Duration 3 hr 2 hr 1-1/2 hr 1 hr 3-1/2 hr 3 hr 2 hr 2 hr 6 hr 5 hr 1-1/2 hr 1 hr 1 hr 1/2 hr 5-1/2 hr 4-1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 4 hr 6 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 2 hr 2-1/2 hr 1-1/2 hr 2 hr 1/2 hr 1 hr 10-1/2 hr 1/2 hr 1-1/2 hr 1 hr 3 hr 2 hr 4 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 7-1/2 hr 1 hr 3 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 2 hr 1-1/2 hr Activity Circulated at 1047.0 ft Pulled Tubing in stands to 1047.0 ft Ran Tubing in stands to 1047.0 ft Circulated at 1047.0 ft Mixed and pumped slurry - 151.000 bbl Rigged down Divertor Installed Casing head Rigged up BOP stack Rigged up BOP stack Rigged up BOP stack Laid down 103.0 ft of Casing Serviced Top drive Repaired BOP stack Tested Casing Rigged down Bell nipple Tested BOP stack Ran Drillpipe to 0.0 ft (2-7/8in OD) Rigged up Bell nipple Rigged up Bell nipple Made up BHA no. 5 R.I.H. to 5335.0 ft Circulated at 5335.0 ft R.I.H. to 5456.0 ft Drilled installed equipment - Float shoe Drilled to 5583.0 ft Circulated at 5583.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 6 R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 5583.0 ft Drilled to 6091.0 ft Held safety meeting Drilled to 6155.0 ft Repaired Downhole measurement tools Pulled out of hole to 200.0 ft Pulled BHA R.I.H. to 6155.0 ft Held safety meeting Drilled to 6784.0 ft Held safety meeting Drilled to 7382.0 ft Held safety meeting Drilled to 7792.0 ft Circulated at 7792.0 ft Pumped out of hole to 5515.0 ft Held safety meeting Serviced Block line R.I.H. to 7792.0 ft Circulated at 7792.0 ft Pumped out of hole to 5515.0 ft Circulated at 5515.0 ft Pulled out of hole to 200.0 ft Pulled BHA 2 14 December 98 Facility Date/Time 21 Aug 98 22 Aug 98 23 Aug 98 24 Aug 98 M Pt E Pad Progress Report Well MPE-33 Rig Nabors~S~ ~~ Duration Activity 04:30-05:30 05:30-06:00 06:00-06:15 06:15-07:30 07:30-13:30 13:30-14:00 14:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-23:00 23:00-02:00 02:00-06:00 06:00-14:00 14:00-16:30 16:30-20:30 20:30-00:00 00:00-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-06:15 06:15-08:00 08:00-12:00 12:00-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-06:00 06:00-06:30 06:30-23:00 23:00-06:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-12:00 1 hr 1/2 hr 1/4 hr 1-1/4 hr 6 hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 3 hr 3 hr 4 hr 8 hr 2-1/2 hr 4 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 1 hr 1/4 hr 1-3/4 hr 4 hr 1-1/2 hr 1-1/2 hr 3 hr 1/2 hr 2 hr 9-1/2 hr 1/2 hr 16-1/2 hr 7 hr 1 hr 2 hr 1-1/2 hr 1-1/2 hr Serviced Drillfloor / Derrick Held safety meeting Held safety meeting Ran Liner to 2350.0 ft (3-1/2in OD) Ran Drillpipe to 2350.0 ft (2-1/16in OD) Circulated at 2362.0 ft Ran Drillpipe in stands to 5545.0 ft Circulated at 5545.0 ft Ran Drillpipe in stands to 7792.0 ft Circulated at 7792.0 ft Set Liner hanger at 7792.0 ft with 0.0 psi Circulated at 7792.0 ft Circulated at 7792.0 ft Cleared Mud pumps Filter Brine Filter Brine Circulated at 7792.0 ft Rig waited · Materials Filter Brine Laid down 2350.0 ft of Drillpipe Circulated at 5440.0 ft Laid down 5440.0 ft of 2-7/8in OD drill pipe Laid down 200.0 ft of 2-1/16in OD drill pipe Held safety meeting Laid down 2300.0 ft of 2-1/16in OD drill pipe Laid down 2200.0 ft of 2-7/8in OD drill pipe Rigged up Top ram Rigged up Handling equipment Rigged down Handling equipment Held safety meeting Tested ESP Ran Tubing to 2200.0 ft (2-3/8in OD) Held safety meeting Ran Tubing to 5300.0 ft (2-3/8in OD) Serviced Electrical submersible pumps Ran Tubing to 5300.0 ft (2-3/8in OD) Rigged down BOP stack Installed Xmas tree Freeze protect well - 45.000 bbl of Diesel Page Date 3 14 December 98 Facility Date/Time 13 Oct 98 14 Oct 98 15 Oct 98 M Pt E Pad Progress Report Well MPE-33 Page Rig Nabors 4ES Date Duration Activity 08:30-10:00 10:00-16:00 16:00-18:00 18:00-18:15 18:15-19:30 19:30-20:00 20:00-20:30 20:30-21:30 21:30-21:45 21:45-22:00 22:00-22:30 22:30-00:00 00:00-02:00 02:00-02:30 02:30-03:00 03:00-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-09:30 09:30-11:30 11:30-14:00 14:00-16:30 16:30-18:00 18:00-18:15 18:15-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-08:00 08:00-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-14:00 14:00-14:30 14:30-15:00 15:00-16:30 16:30-17:00 1-1/2 hr 6 hr 2hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 1 hr 2 hr 2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/4 hr 11-3/4 hr 1/4 hr 1/4 hr 1 hr 1/2 hr 3 hr 1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr Rigged down Drillfloor / Derrick Rig moved 100.00 % Installed Drillfloor / Derrick Held safety meeting Installed High pressure lines Tested High pressure lines Retrieved Hanger plug Circulated at 5200.0 ft Flow check Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Retrieved Hanger plug Retrieved Tubing hanger Rigged up Tubing handling equipment Laid down 94.0 ft of Tubing Held safety meeting Serviced Drillfloor / Derrick Laid down 458.0 ft of Tubing Pulled Tubing in stands to 2134.0 ft Serviced Electric cable Pulled Tubing in stands to 4050.0 ft Rigged up sub-surface equipment - Electric cable Ran Tubing in stands to 4359.0 ft Held safety meeting Ran Tubing in stands to 4655.0 ft Held safety meeting Serviced Drillfloor / Derrick Ran Tubing in stands to 4728.0 ft Installed Tubing hanger Serviced Electric cable Ran Tubing on landing string to 4748.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Freeze protect well - 48.000 bbl of Diesel Cleared Chicksan lines 1 14 December 98 Milne Point Unit Alaska State Plane Zone 4 Milne Point E Pad MPE-33 Ru. CclvED S£P ! 7 t998 BPXA PDC ORIGINAL S UR VEY REPORT September, ~998 Your Ref: API-500292289800 Last Survey Date 19-August-98 Job# AKMM80328 KBE- 56.61' DRILLING SERVICES Survey Ref: svy2206 Milne Point Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (fi) (fi) 0.00 0.000 0.000 -56.61 0.00 199.52 0.370 285.790 142.91 199.52 291.52 0.280 311.190 234.91 291.52 381.02 1.360 321.330 324.40 381.01 470.35 2.030 322.360 413.69 470.30 561.32 2.680 336.530 504.58 561.19 651.36 3.050 339.320 594.51 651.12 744.19 2.910 349.990 687.21 743.82 843.90 3.020 319.190 786.80 843.41 940.00 1.790 303.210 882.81 939.42 1035.60 1.390 292.270 978.37 1034.98 1130.64 4.630 309.370 1073.27 1129.88 1225.99 4.960 313.920 1168.29 1224.90 1321.43 3.280 327.330 1263.48 1320.09 1418.53 3.290 332.220 1360.42 1417.03 1513.33 3.090 338.860 1455.07 1511.68 1608.86 4.140 311.310 1550.42 1607.03 1703.61 3.630 315.790 1644.95 1701.56 1799.62 3.560 310.540 1740.77 1797.38 1894.98 3.390 311.300 1835.96 1892.57 1990.61 5.070 318.830 1931.32 1987.93 2087.47 8.080 320.860 2027.54 2084.15 2181.51 12.190 322.440 2120.09 2176.70 2278.98 15.320 315.800 2214.76 2271.37 2374.40 16.510 314.260 2306.52 2363.13 2469.75 19.370 312.550 2397.22 2453.83 2564.17 19.750 314.530 2486,20 2542.81 - 2659.72 23.350 316.360 2575.05 2631.66 2755.53 23.740 319.220 2662.89 2719.50 2851.65 26.320 321.740 2749.98 2806.59 Sperry-Sun Drilling Services Survey Report for MPE-33 Your Ref: API-500292259800 Local Coordinates Nothings (fi) 0.00 N 0.18N 0.40 N 1.38 N 3.46 N 6.68 N 10.86 N 15.49 N 19.97 N 22.71N 23.96 N 26.83 N 32.14 N 37.30 N 42.10 N 46.89 N 51.57 N 55.98 N 60.09 N 63.88 N 68.92 N 77.43 N 90.43 N 107.82 N 126.32 N 146.48 N 168.25 N 193.29 N 221.63 N 253.02 N Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/t00ff) 0.00E 6016577.35N 569069.07E 0.00 0.62W 6016577.52 N 569068.45 E 0.185 0.37 1.07W 6016577.74 N 569067.99 E 0.182 0.74 1.90W 6016578.71N 569067.15 E 1.213 1.93 3.53W 6016580.78 N 569065.51E 0.751 4.43 5.36W 6016583.98 N 569063.65 E 0.954 8.08 7.05W 6016588.14 N 569061.92 E 0.439 12.58 8.33W 6016592.76 N 569060.60 E 0.615 17.37 10.49W 6016597.22 N 569058.40 E 1.582 22.31 13.40W 6016599.93 N 569055.46 E 1.446 25.86 15.72W 6016601.17 N 569053.13 E 0.523 27.81 19.75W 6016604.00 N 569049.07 E 3.500 31.85 25.70W 6016609.25 N 569043.08 E 0.528 38.82 30.14W 6016614.36 N 569038.58 E 2.018 45.16 32.94W 6016619.14 N 569035.74 E 0.289 50.62 35.13W 6016623.91 N 569033.51 E 0.443 55.86 38.65W 6016628.56 N 569029.95 E 2.094 61.44 43.31W 6016632.92 N 569025.24 E 0.626 67.14 47.69W 6016637.00 N 569020.82 E 0.350 72.47 52.06W 6016640.74 N 569016.42 E 0.185 77.49 56.97W 6016645.74 N 569011.47 E 1.847 83.87 64.08W 6016654.18 N 569004.27 E 3.116 94.25 74.31W 6016667.09 N 568993.92 E 4.380 109.90 89.57W 6016684.34N 568978.51E 3.592 131.36 108.07W 6016702.67 N 568959.84 E 1.323 154.93 129.42W 6016722.62 N 568938.30 E 3.050 181.01 152.33W 6016744.18 N 568915.19 E 0.809 209.13 176.92W 6016768.99 N 568890.37 E 3.832 240.88 202.62W 6016797.09 N 568864.41E 1.260 276.12 228.45W 6016828.24 N 568838.28 E 2.904 314.29 Comment Alaska State Plane Zone 4 Milne Point E Pad Continued... 14 September, 1998 - 13:36 - 2- DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPE-33 Your Ref: API-500292289800 Alaska State Plane Zone 4 Milne Point E Pad Measured Depth Incl. (ft) 2944.03 27.820 3039.11 30.060 3135.13 31.440 3231.21 34.220 3326.18 36.450 3421.21 38.800 3516.93 41.630 3614.10 45.190 3709.41 46.940 3804.50 48.010 3900.76 47.680 3996.94 49.330 4093.77 49.410 4186.58 51.660 4284.08 52.730 4379.91 53.460 4475.91 56.240 4571.98 57.720 4667.85 58.280 4762.86 59.490 4858.90 61.950 4954~21 64.690 5049.64 67.190 5144.10 70.820 5238.71 74.160 5336.45 77.150 5431.36 77.750 5509.02 77.920 5570.00 77.920 5615.70 83.120 Azim. 323.400 323.800 322.260 320.760 319.750 321.720 323.850 327.940 328.870 329.970 330.300 329.490 329.140 329.880 329.860 330.800 332.780 335.720 336.550 337.480 338.230 339.440 340.350 340.650 340.190 341.320 343.450 344.180 344.180 344.310 Sub-Sea Depth (fi) 2832.24 2915.44 2997.96 3078.69 3156.16 3231.42 3304.51 3375.10 3441.23 3505.50 3570.11 3633.83 3696.88 3757.14 3815.68 3873.23 3928.49 3980.85 4031.66 4080.75 4127.72 4170.51 4209.42 4243.25 4271.72 4295.93 4316.56 4332.92 4345.68 4353.21 Vertical Depth (fi) 2888.85 2972.05 3054.57 3135.30 3212.77 3288.03 3361.12 3431.71 3497.84 3562.11 3626.72 3690.44 3753.49 3813.75 3872.29 3929.84 3985.10 4037.46 4088.27 4137.36 4184.33 4227.12 4266.03 4299.86 4328.33 4352.64 4373.17 4389.53 4402.29 4409.82 Local Coordinates Northings (ft) 286.41 N 323.44 N 362.66 N 403.40 N 445.62 N 490.55 N 539.78 N 595.08 N 653.54 N 713.87 N 775.76 N 838.07 N 901.27 N 964.34 N 1029.60 N 1096.18 N 1165.35 N 1237.90 N 1312.25 N 1387.13 N 1464.72 N 1544.13 N 1625.96 N 1709.07 N 1794.07 N 1883.46 N 1971.75 N 2044.66 N 2102.03 N 2145.40 N Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (fi) (fi) (fi) (°/t00ff) 253.99W 6016861.39N 568812.44E 1.818 354.24 281.29W 6016898.17N 568784.80 E 2.365 398.21 310.82W 6016937.11N 568754.90 E 1.655 444.97 343.25W 6016977.55 N 568722.09 E 3.014 494.15 378.38W 6017019.45 N 568686.58 E 2.427 545.60 415.07W 6017064.03 N 568649.47 E 2.778 600.13 452.41W 6017112.91N 568611.67 E 3.287 658.93 489.77W 6017167.86 N 568573.81 E 4.666 723.47 525.72W 6017225.99 N 568537.32 E 1.966 790.52 561.36W 6017285.99 N 568501.11E 1.412 859.24 596.90W 6017347.54 N 568465.01 E 0.427 929.39 633.04W 6017409.52 N 568428.29 E 1.828 1000.15 670.54W 6017472.37 N 568390.20 E 0.286 1072.19 707.67W 6017535.09 N 568352.49 E 2.448 1143.98 745.54W 6017600.00 N 568314.01 E 1.121 1218.09 783.47W 6017666.22 N 568275.47 E 1.093 1293.46 820.55W 6017735.05 N 568237.75 E 3.351 1371.00 855.52W 6017807.27 N 568202.11 E 2.993 1451.02 888.41W 6017881.31 N 568168.53 E 0.938 1532.07 920.17W 6017955.89 N 568136.08 E 1.525 1613.24 951.74W 6018033.18 N 568103.79 E 2.650 1696.89 982.47W 6018112.31 N 568072.32 E 3.090 1782.00 1012.42W 6018193.85 N 568041.62 E 2.761 1869.12 1041.85W 6018276.69 N 568011.42 E 3.854 1957.30 1072.08W 6018361.40 N 567980.40 E 3.561 2047.51 1103.28W 6018450.50 N 567948.37 E 3.258 2142.19 1131.32W 6018538.53 N 567919.52 E 2.280 2234.79 1152.48W 6018611.24 N 567897.69 E 0.945 2310.59 1168.73W 6018668.45 N 567880.90 E 0.000 2370.11 1180.97W 6018711.71 N 567868.26 E 11.382 2415.08 Comment Continued... 14 September, 1998 - 13:36 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for MPE-33 Your Ref: AP1-500292289800 Milne Point Unit Alaska State Plane Zone 4 Milne Point E Pad Measured Depth Incl. (ft) 5711.26 90,860 5743.10 92.740 5776.62 92,690 5805.31 93.260 5837.61 89,600 5869.99 89,290 5900.41 89.320 5931.35 87.600 5962.86 87,590 5995.99 87.720 6028.67 87,840 6060.07 89,720 6116.44 90.060 6149.36 90,400 6185.08 91.910 6216.90 92.550 6248.41 92.250 6280.13 92,710 6312.07 94.000 6344.00 95,610 6373.72 95.400 6405.54 94.530 6437.30 93.890 6468.27 91.850 6500.59 91.750 6531.53 91.790 6563.54 91.630 6590.84 91.420 6624.02 92.220 6655.43 90,340 Azim. 351.270 353.890 353.620 353.540 354.190 352.790 353.980 353.110 352.590 350,980 351.580 353.68O 354.090 353,730 354.320 354.530 354.150 354.940 357.600 355.990 352.090 355.3OO 354.970 354.760 355.200 354.620 354.39O 354.750 354.000 353.080 Sub-Sea Depth (ft) 4358.23 4357.23 4355.64 4354.15 4353.34 4353.66 4354.O3 4354.86 4356.18 4357,54 4358.80 4359.47 4359.58 4359.45 4358.73 4357.49 4356.17 4354.80 4352.93 4350.25 4347.40 4344.65 4342.31 4340.76 4339.75 4338.79 4337.84 4337.11 4336.06 4335.38 Ve~ical Depth (fi) 4414.84 4413.84 4412.25 4410.76 4409.95 4410.27 4410.64 4411.47 4412.79 4414.15 4415.41 4416.08 4416.19 4416.06 4415.34 4414.10 4412.78 4411.41 4409,54 4406.86 4404.01 4401.26 4398.92 4397,37 4396.36 4395.40 4394.45 4393.72 4392.67 4391.97 Local Coordinates Nothings (fi) 2238.54 N 2270.10 N 2303.38 N 2331.85 N 2363.95 N 2396.12 N 2426.34 N 2457.07 N 2488,30 N 2521.07 N 2553.34 N 2584.47 N 2640.52 N 2673.26 N 2708.77 N 2740.42 N 2771.75 N 2803.29 N 2835.11N 2866.87 N 2896.29 N 2927.80 N 2959.36 N 2990.16 N 3022.34 N 3053.14 N 3084.99 N 3112.16 N 3145.16 N 3176.37 N Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (~) (fi) (fi) (°/100~) (fi) 1201.10W 6018804.66 N 567847.27 E 10,882 2509.65 1205.21W 6018836.18 N 567842.86 E 10.124 2540.79 1208.85W 6018869.42 N 567838.91E 0.818 2573.41 1212.06W 6018897.87 N 567835.45 E 2.006 2601.34 1215.51W 6018929.93 N 567831.70 E 11,508 2632.78 1219.18W 6018962.06 N 567827.73 E 4.428 2664.35 1222.68W 6018992.25 N 567823.95 E 3,913 2694.03 1226.16W 6019022.94 N 567820.18 E 6,229 2724.18 1230.08W 6019054.14 N 567815.98 E 1.649 2754.96 1234.81W 6019086.86 N 567810.94 E 4,871 2787.45 1239.76W 6019119.09 N 567805.69 E 1.871 2819.55 1243.78W 6019150.18 N 567801.38 E 8.975 2850.26 1249.79W 6019206.17 N 567794.85 E 0.945 2905.15 1253.28W 6019238.87 N 567791.06 E 1.504 2937.20 1257.00W 6019274.35 N 567787.01 E 4.538 2971.95 1260.09W 6019305.97 N 567783.63 E 2.117 3002.84 1263.19W 6019337.27 N 567780.23 E 1.536 3033.43 1266.21W 6019368.79 N 567776.93 E 2.880 3064.20 1268.28W 6019400.58 N 567774.56 E 9,243 3094.92 1270.06W 6019432.33 N 567772.49 E 7.118 3125.49 1273.13W 6019461.71 N 567769.14 E 13.081 3154.27 1276.61W 6019493.18 N 567765.37 E 10,415 3185.15 1279.30W 6019524.72 N 567762.39 E 2.266 3215.83 1282.06W 6019555.50 N 567759.34 E 6.622 3245.82 1284.89W 6019587.65 N 567756.21E 1.395 3277.13 1287.63W 6019618.43 N 567753.19 E 1.878 3307.11 1290.70W 6019650.24 N 567749.83 E 0,875 3338.18 1293.28W 6019677.39 N 567746.99 E 1.526 3364.68 1296.53W 6019710.36 N 567743.44 E 3.304 3396.90 1300.06W 6019741.53 N 567739.61 E 6.663 3427.52 Comment Continued,.. 14 September, 1998 - 13:36 - 4 - DrillQuest Milne Point Unit Sperry. Sun Drilling Services Survey Report for MPE-33 Your Ref: API-500292289800 Alaska State Plane Zone 4 Milne Point E Pad Measured Depth Incl. (ft) 6687.03 90.030 6718.32 90,800 6750.32 90.710 6784.09 90.280 6813.97 88,890 6844.50 87.880 6877.32 87.470 6908.65 87.110 6938.88 88.740 6971.70 88.490 7003.29 88.640 7034.20 88.430 7066.90 88.460 7098.80 87.660 7130.08 87,130 7162.14 84.450 7190.26 84.210 7223.09 83.430 7255.47 85,220 7287.51 86.860 7317.84 88.180 7349.91 89,630 7381.67 89,380 7412.97 89.440 7444.59 90.250 7476.60 89.880 7506.80 90,460 7538.38 90.400 7569.29 92.060 7602.01 93,020 Azim. 352.890 354,750 352,170 352.020 350.940 349.910 349,330 349,OOO 350.760 350.020 350.190 350.530 350.540 350,090 350.080 350.230 35O.24O 348.420 350.160 350,250 351,400 351.890 352.470 349,44O 351.150 351.160 351.120 351.230 351.620 351.770 Sub-Sea Depth (fi) 4335.25 4335.03 4334.60 4334.31 4334.53 4335.39 4336.72 4338.20 4339.30 4340.09 4340.88 4341.67 4342.56 4343.64 4345.06 4347.41 4350.19 4353.73 4356.93 4359.14 4360.45 4361.07 4361.34 4361.66 4361.75 4361.71 4361,62 4361.39 4360.72 4359.27 Ve~ical Depth (fi) 4391.86 4391.64 4391.21 4390.92 4391.14 4392.00 4393.33 4394.81 4395.91 4396.70 4397.49 4398.28 4399.17 4400.25 4401.67 4404.02 4406.80 4410.34 4413.54 4415.75 4417.06 4417.68 4417.95 4418.27 4418.36 4418.32 4418.23 4418.00 4417.33 4415.88 Local Coordinates Nothings (fi) 3207.73 N 3238.83 N 3270.62 N 3304.07 N 3333.62 N 3363.71N 3395.96 N 3426.70 N 3456.44N 3488.79 N 3519.90 N 3550.36 N 3582.61N 3614,03 N 3644.81N 3676.31N 3703.89 N 3735.96 N 3767.62 N 3799.12 N 3829.03 N 3860.75 N 3892.22 N 3923.12 N 3954,29 N 3985.92 N 4015.76 N 4046.96 N 4077.52 N 4109.86 N Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/t00ff) (fi) 1303.92W 6019772.85 N 567735.46 E 1,151 3458.39 1307.29W 6019803.93 N 567731.81E 6.433 3488.87 1310.94W 6019835.68 N 567727.87 E 8,067 3520.07 1315.58W 6019869.08 N 567722.91 E 1.349 3553.17 1320.01W 6019898.59 N 567718.21 E 5.891 3582.53 1325.08W 6019928.63 N 567712.86 E 4.724 3612.61 1330.99W 6019960.83 N 567706.65 E 2.163 3645.00 1336.87W 6019991.51N 567700.48 E 1,558 3675.96 1342.18W 6020021.20 N 567694.90 E 7.932 3705.78 1347.66W 6020053.50 N 567689.12 E 2.379 3738.12 1353.09W 6020084.55 N 567683.41 E 0,718 3769.28 1358.26W 6020114.97 N 567677.95 E 1.293 3799.74 1363.64W 6020147.16 N 567672.28 E 0.097 3831.95 1369.00W 6020178.54 N 567666.62 E 2,877 3863.38 1374.38W 6020209,27 N 567660.96 E 1,695 3894.21 1379.85W 6020240.71N 567655.20 E 8.372 3925.75 1384.59W 6020268.25 N 567650.20 E 0,854 3953.35 1390.63W 6020300.26 N 567643.86 E 6.002 3985.62 1396.62W 6020331.86 N 567637.58 E 7.691 4017.48 1402.06W 6020363.31N 567631.85 E 5.126 4049.00 1406.89VV 6020393.17 N 567626.74 E 5.770 4078.83 1411.55W 6020424.85 N 567621.79 E 4,772 4110.31 1415.87W 6020456,27 N 567617.18 E 1,989 4141.43 1420.79W 6020487.13 N 567611.97 E 9.682 4172.23 1426.12W 6020518.25 N 567606.35 E 5,984 4203,41 1431.04W 6020549.83 N 567601.14 E 1.156 4234.89 1435.69W 6020579.62 N 567596.21E 1.925 4264.59 1440.54W 6020610.78 N 567591.07 E 0.397 4295.64 1445.15W 6020641.30 N 567586.18 E 5.517 4326.00 1449.87W 6020673.60 N 567581.16 E 2,970 4358.09 Comment Continued... 14 September, 1998 - 13:36 .5 - DrillQuest Sperry-Sun Drilling Services Survey Report for MPE-33 Your Ref: API-500292289800 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/t 00ft) (ft) 7633.80 94,470 352.240 4357.20 4413,81 7665.87 94.250 352.280 4354.76 4411.37 7695.15 93,640 352,540 4352.74 4409.35 7727.80 93.140 351,830 4350.81 4407.42 7793.00 93,140 351.830 4347.24 4403.85 4141.28 N 1454.28W 6020704.97 N 567576.46 E 4.794 4389.20 4172.96 N 1458.59W 6020736.61N 567571.86 E 0.697 4420.53 4201.92 N 1462.44W 6020765.53 N 567567.73 E 2.264 4449.13 4234.21N 1466.88W 6020797.78 N 567563.00 E 2.657 4481,07 4298.65 N 1476.13W 6020862.13 N 567553.15 E 0.000 4544.95 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 340.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7793.00ft., The Bottom Hole Displacement is 4545.03ft., in the Direction of 341.048° (True). Comments Measured Depth (ft) 0.00 7793.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 0.00 __ 0.00 N 0.00 E Tie-on Survey 4403.85 4298.65 N 1476.13 W Projected Survey Comment Projected Survey Alaska State Plane Zone 4 Milne Point E Pad 14 September, 1998 - 13:36 - 6 - DrillQuest WELL LOG TRANSMITrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPE-33, )ac-m -8o3:8 November 18, 1998 MPE-33: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22898-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22898-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSM1TYAL LE~FER TO THE ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: Si~ed: BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WEIJ~ LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPE-33, AK-MM-80328 November 18, 1998 1 LDWG formatted Disc with verification listing. API#: 50-029-22898-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETIIgR TO TltE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 -~,~ ~..--~ :~.~'~ ~, ~ . C~'~ .~ .; . ._.-.~, ~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company GeoQuest 3940 Arctic Blvd Anchorage. AK 99503 ATTN: Sherrie NO. 11592 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 10/22/98 Well Job # Log Description Date BL Sepia LIS Tape MPB-03 PRODUCTION PROFILE 980823 1 1 MPB-03 GAS LIFT SURVEY 980823 1 1 MPB-03 DIGITAL FLUID IMAGER 980823 1 1 MPB-04 PRODUCTION PROFILE 980823 1 1 MPB-04 GAS LIFT SURVEY 980823 1 1 MPB-04 DIGITAL FLUID IMAGER 980823 1 1 MPB- 10 PRODUCTION PROFILE 980823 1 1 MPB-10 GAS LIFT SURVEY 980823 1 1 MPB-10 DIGITAL FLUID IMAGER 980823 1 1 MPB- 15 PRODUCTION PROFILE 980825 1 1 MPB-15 GAS LIFT SURVEY 980825 1 I MPB-15 DIGITAL FLUID IMAGER 980825 1 1 , , MPE-21 FOUR ARM CALIPER 980829 1 1 MPE-30 FOUR ARM CALIPER 980731 1 1 MPE-33 FOUR ARM CALIPER 980811 1 1 MPG-01 WATER FLOW LOG 980717 1 1 MPH- 10 GAMMA RAY/COLLAR LOG 980825 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 -ONY KNOWLE$, GOVERNOR .~LASKA OIL A~ND GAS CONSERVATION COMMISSION _'-.301 PORCUPINE DRIVE ~NCHORAGE, ALASKA 99501-3192 --'HONE: :.907') 279-1433 =AX: 9.07) 276-7542 JuN 29. 1998 T. Brcnt Reeves Drilling Engineering Supervisor BP Exploration (Alaskal Inc. POBox 196612 ..\nchorag¢, ,AK 99519-6612 R.c: Milnc Point Unit MPE-33 BP Exploration tAlaska). Inc. Permit No. t)8-128 Sur. Loc. 4041'NSL. 2073'\VEL, Sec. 25. TI3N. RIOE. UM Btmnholc Loc. _767'NSL. 3473'\VEL, Sec. ,4, TI'~N, R10E. UM Dcar Mr. Rcevcs: Enclosed is thc approvcd application for pcrmit to drill thc above rcfcrcnccd xvcll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from other govcrnmcntal agcncics, and docs not authorizc conducting drilling operations until all other rcquircd permitting dctcrminations arc made. Blowout prevention equipment (BOPE) must be tcstcd in accordance with 20 AAC 25 035. Sufficicnt noticc (approximatclv 24 hours) must bc given to allow a. rcprcscntativc of thc Commission to ~A'itncss a test of BOPE installcd prior to drilling ncxx-holc. Noticc may bc givcn by contacting thc Commission pctroicum field inspcctor on thc North Slope pagcr at 650-3607. Robcrt N. Christcnson. P.E. Commissioncr BY ORDER OF THE COMMISSION dlffEnclosurcs cc; Dcpartmcnt of Fish &Gamc. Habitat Section xv/o cncl. Dcpartmcnt of Environmental Conscrvation xx.,'o cncl. ,_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 ^^C 25.005 la. Typeofwork []Drill [~]Redrill Ilb. Typeofwell FI Exploratory [] Stratigraphic Test ~;~ Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of OPerator " 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond- (See 20 AAC 25.025) 4041' NSL, 2073' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1216' NSL, 3348' WEL, SEC. 24, T13N, R10E, UM MPE-33 At total depth 9. Approximate spud date Amount $200,000.00 2767' NSL, 3473' WEL, SEC. 24, T13N, R10E, UM 08/01/98 12. Dis{ance to nearest prop~r~y line113. DistanCe to nearest well 14. Number of acres in property 15. Proposed depth iMD ~r~d TVD) ADL 025518, 2767'I MPE-02, 31.84' at 496.83' MD 2560 7533' MD /4450' TVD 16. To be completed for deviated wells 1'7'. Anticipated' pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 400' MD Maximum Hole Angle 92.720° Maximum surface 1498 psig, At totaldepth (TVD) 4316' / 1930 psig lb. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD' MD TVD (include stage data) ' ' 16" 13-3/8" 72/t Lo80 BTC-Mod 12.0'' ... 31.' 31" 151' 151' 250 sx Arcticset I (Approx.) 6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 5770' 30' 30' 5800' 4417' [438 sx'CS III, 90 sx FOamed, 101 sx 'G' 4-3/4" 3-1/2" 9.3# J-55 8-RD SCC 1833' 5700' 4405' 7533' 4450' Uncemented Slotted Liner 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 MD TVD Structural Conductor Surface Intermediate[ IJpLIF A'[E Production ~ ~~~ ~¢~:''~ .... -~ ~'" Liner , 2 7 Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ..... Contact Engineer Name~Number'. R George Scott 564-5862~.4~t Tom Maunder. 564-4429 Prepared By Name/Number: Kathy Campoamor, 564-5122 121.1 hereby. ~__~ __ .~---ce~f°reg°in§ (S tr~C~~orroct tO~o b~st of my knowleO§e '-,~.~~s'--'~-", /',/ .//r.,...,,~r~rf~c_-,,c,~r,.~-Title Drilling Engineering Supervisor Date Commission Use Only PermitNumber I APINumber [ 'ApprovalDate _ I Seecoverletter ~-/.2.- ~ 50- O .2- ~'-- 2_ 2- ~:> c~ ~ ~ --, ¢?~ f-, ~' ~ for other requirements Conditions of Approval: Samples Required []Yes ~No Mud Log Required []Yes J~No Hydrogen Sulfide Measures []YesJ~No Directional Survey Required J~Yes rmlNo Required Working Pressure for BOPE []2M; []3M; x~.5M; []10M; []15M Robert N. ChliSt~rlsorl by order of./ Approved By Commissioner the commission Date--"' Submit In Triplicate STATE OF ALASKA ALASKA ~.,-L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill I-]Redrill Ilb. Typeofwell ['-I Exploratory I-]StratigraphicTest I~DevelopmentOill [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 21'" Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name il 1. Type Bond (See 20 AAC 25.025) 4041' NSL, 2073' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 1216' NSL, 3348' WEL, SEC. 24, T13N, R10E, UM MPE-33 At total depth 9. Approximate spud date Amount $200,000.00 2767' NSL, 3473' WEL, SEC. 24, T13N, R10E, UM 08/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 2767'I MPE-02, 31.84' at 496.83' MD 2560 7533' MD / 4450' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 400' MD Maximum HoleAngle 92.720° Maximum surface 1498 psig, At total depth (TVD) 4316'/1930 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement 'Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 16" 13-3/8" 72# L-80 BTC-Mod 120' 31' 31' 151' 151' _~50 sx Arcticset I (Approx.) 6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 5770' 30' 30' 5800' 4417' 438 sx CS III, 90 sx Foamed, 101 sx 'G' 4-3/4" 3-1/2" 9.3# J-55 8-RD SCC 1833' 5700' 4405' 7533' 4450' Uncemented Slotted Liner 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 MD TVD Structural Conductor Surface Intermediate LPirn°edructi°n 0 RI G!~ A L Perforationdepth:measured JUL 2 7 998 true vertical '~aska Oil & Gas C0~s. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Progra/~0h0~l~q8 [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: R~eorge Scott, 564-5862 _~1~ Tom Maunder, 564-4429 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certi~4/,.t.h"a~,,t4 e~foregoing is t~.g~'orrect tb-t~,e best of my knowledge ~,¢¢~ ~', ~/'/' :,,/'{~,-'4'~-4-~'/_-~--'~--2'~ Title Drilling En g in earing Supervisor Date Commission Use Only Permit Number APl Number Approval Date I See cover letter ~"/2. ~' 50- O ~.. ~;> -- ~ ~- ~' ~' F 7 '"~' f ~ BI for other requirements Conditions of Approval: Samples Required []Yes ~'No Mud Log Required []Yes '~No Hydrogen Sulfide Measures []Yes ';~ No Directional Survey Required ~[Yes~ No Required Working Pressure for BOPE []2M; [] 3M; J~,5M; [] 10M; [] 15M Other: ~'~ ~ ~(~:2.,~ by order of .Approved By OmR_I2I~N.A.L_SIGNED. Ety Commissioner the commission Date '~"C:~ ¢"' Form 10-401 Rev. 12-01-85 e~t N. Onnstenso~ Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): R. George Scott IMP E-33 I Well Plan Summary I Schrader Bluff Horizontal Producer 564-5862 Surface Location: 4041' FSL, 2073' FEL, S25 T13N R10E UM Target Location: 1216' FSL, 3348' FEL, S24 T13N R10E UM Bottom Hole Location: 2767' FSL 3473' FEL, S24 T13N R10E UM I AFE Number: I 337137.1 I Estimated Start Date: I 1 August 98 I Rig: I Nabors 27E I I Operating days to complete: 17533' I ITvD: 14450, I IKBE: I Schrader Bluff Producer ,~ I Well Design: Formation Markers: 112.0 [57ft Formation Tops MD TVDSS KOP 400 344' Base of Permafrost 1834' 1755' Top of Ugnu 4214' 3987' Top M Sand 4594' 4046' Top NA (Target) 5192' 4235' Top of the N-A (EMW 8.6 ppg) 5-1/2" Casing Shoe 5800' 4361' (Picked by Geologist) Top "OA" 5976' 4372' Geo-steering will be required to keep in"OA" Base "OA" 6599" 4396' Top "OB" 7014' 4408' Expected to be wet. TD 7533' 4394' TD Casing/Tubing Program: Hole §ize Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 16" 13-3/8" 72# L-80 BTC-MOD 120' 31 '/31' 151' / 151' 6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 5770' 30'/30' 5800'/4417' 4-3/4" 3-1/2" 9.3# J-55 8-RD. SCC 1833' 5700'/4405' 7533'/4450' Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/E) to the reservoir at +4316' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1930 psi (8.6 ppg EMW), is 1498 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top 2 joints in the 5-1/2" surface casing consists of 2 joints of 7" 26# BTC-MOD L-80, this is required to accommodate the penetrater offset. This will require a X-over to the 5-1/2" 15.5# J-55 BTC-MOD Casing. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151" ~ (*% Collapse-S410psi, Burst-7240psi, Yield-604M lbs. The 3-1/2" 9.3# liner has an ID of 2~)'~~t ~'¢ ~' 4.180", Drift-2.867", collapse-7400psi, Internal Yield-6980psi, Yield-109.37M lbs. JUL 2 7 1998 Alaska 0il & Gas..C~ s.. C,0mmi¢0~ MP E-33 Well Plan PAGE 3 ,z~?~0~ 98 Logging Program: Open Hole Logs: Surface: FINAL: Cased Hole Logs: MWD directional only from surface to 2500' MD. 4-Arm Caliper Log From 5800'MD to 151' M.D. (Base of 13-3/8" Conductor.* MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr. MWD Directional and LWD GR/RES. 5800'MD-7533'MD. (TD) None Mud loggers are NOT required for this well. *A conditioning trip may be made if required to assure running of the caliper. Mud Program: Special design considerations An inhibitive polymer mud is planned from surface to 5800'MD. Solids control is critical to the success of the system. A drill in Mud with calcium carbonate to limit fluid invasion from 5800'-7533'MD Surface Mud Properties' I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties' I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 The surface casing will be drilled out to +/- 20' of new hole then the mud changed out to drill in mud for horizontal section. Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diverter with 10" Diverter Line. This Rig is equipped with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer used for drilling the horizontal section and for the completion, capable of handling maximum potential surface pressures. Note it is planned to test the BOPE to 3500psi with a cup tester, and the 5-1/2" casing to 3500psi as the anticipated maximum BHP is 1930 psi. Directional: I KOP: 1400' MD Maximum Hole Angle: Close Approach Well: 92.720° @ 7300'md ! JUL 2 7 Close Approach To MPE-02 A SHUT IN WATF~$k~ 0il& Gas C0ns. C0mmL~i~ INJECTOR WELL. 31.84' @ 496.83' md. Waste Management: Cuttings Handling' All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and comPletion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned. MP E-33 Well Plan PAGE 4 26 July 98 MP E-30 Proposed Summary of Operations 1. Drill and Set 13-3/8" Conductor. Weld landing ring assembly on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 27E rig. , NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. 4" D.P. 2-7/8" work string and 2-7/8" drill pipe will have been stood back prior to spud. . Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to +/- 2500'MD. POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. Drill 6-3/4" hole to 5800' as per directional plan. Stand back drill string and run 4-Armed Caliper from the 5800'M.D. to the bottom of the 13-3/8" conductor. Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing using innerstring method. Refer to attached Detailed Cement Program and Back-up Port Collar Operating Procedure. . 10. Following the cementing of the well and the landing of the 7" landing joint rig down cementers. N/D diverter, MU casing head to top joint of 7" csg. (9500 fi-lbs torque.) Install BOPE with 2-3/8" rams. Test BOPE and Casing individually to 3500 psi, 74% of burst of 5-1/2# J-55 Casing. PU 4-3/4" directional BHA and drill out cement collar and shoe and 20' of new hole. Circ. & Cond. Mud, no LOT will be required. Pump a 20 bbl. High visc. pill (70 Y.P.) sweep ahead of drill in fluid. (See Mud Program). 11. Short trip as required before POOH for 3-1/2" liner. Circ and condition wellbore POOH for 3-1/2" liner. NOTES: Hold a "pre-reservoir" meeting as per page 20 of Drlg. Policy Manual. Record on Morning Report. Monitor torque and do not exceed 80% of DP torque. Pump Iow/Hi visc. sweeps every 500' of new hole. Maintain adequate flow rates to clean hole. 12. Run 3-1/2" pre-slotted liner as per attached liner procedure. 13. Displace hole to Kill weight brine. POOH. It is planned to complete this well with Rig 27E. A separate Completion program will be issued. POST DRILL AND CASE: Nabors Rig 27E will run the completion on this well. JUL 2 7 MP E-33 Well Plan PAGE 5 26 July 98 DRILLING HAZARDS Aw-..J RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. Specific potential hazards for this well are outlined below. The MPU PE group will be perforating, hydraulic fracturing and Cleaning out this as per the completion program. ,,,/// 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If encountered mud will be treated with 1-1.5 ppb Lechithin (See Attached Mu~d Program). 2. Close Approach: There is a close approach problem ~n ~ne~E-02 water i,~_Tj.d~ Well. Confirm that this well is shut-in and secured while drilling. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There' have been several STUCK PIPE incidents on' Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section,, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1930. psi in the middle of the Schrader Bluff at 4316' TVDSS. 6. Directional Drillinq Concerns MP E-33 will be an ultra slim 6-3/4" hole drilled to a depth of 5800' md. Followed by 4-3/4" horizontal leg to TD. KOP is 400' md and a variable build rate from that point will yield a sail angle of 84.489 o at 5800' md. The maximum inclination of 92.72 deg. is reached at 7300' MD and held to TD. Departure is 4244'. 7. Cement The surface hole will be cemented to surface with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The excess will be run in the Cold Set III. The top of the Class G is planned for 500' above the top of the Schrader Bluff Sands. A back up port collar will be run approximately 200' below the permafrost the exact position determined from the caliper log. This is a full gauge tool and will be placed using the caliper in a slightly over gauge section. - ...... -' MP E-33 5-1/2"" SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 ppg. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD:1.74 ft3/sx MIX WATER: 6.06 gal/sk APPROX #SACKS: 438 Cold Set III THICKENING TIME: Greater than 6 hfs at 50° F 90 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF Cold Set III CEMENT Port Collar +/- 2200'MD to surface +40% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: FLUID LOSS: FI-33-.4%, CD-32-.3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8 ppg YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk 101 THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 5800 FEET 500' TVD ABOVE SCHRADER BLUFF + 80'md 5-112"", 15.5# capacity for float joints. EST TOC 4300' md (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg YIELD:1.92 ff3/sx MIX WATER: 11.63 gal/sk 438 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 40% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE' ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Spiral Glide 5-1/2" X 6-3/4" centralizers are planned for the 5-1/2" casing The number to be determined by the Caliper log, and also on the joint of casing above and below port collar. See attached Weatherford centralizer program in cementing section. 2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer program will be issued following receipt of the results of the 4-Arm Caliper Log. MP E-33 Well Plan PAGE 7 25 July 98 N 1800,00 + 2600.00 22 · i3 · g'· 11 18 20 2¢ 14. 1§ · I · · · · 1 ·5 m6 17 II 16 1.23 · 19 j al 21 I17 NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 2. GEODETIC COORD[NATE:S ARE NA0 27. $. MEAN PAO SCALE FACTOR O.999905¢$+. ,t.. HORIZONTAL ANO VERTICAL CONTROL iS BASE0 ON MONUMENTS CFP-3 and E-l. 5. OATE OF SURVEY: MAY 16, 1998. 6. REFERENCE FIELD BOOK: MP98-05 Pgs. 6{3-63. 7. ELEVATIONS ARE BASED ON BPX MILNE POINT DATUM (M.S.L.). , A\PAD)I .. (. ~..,1~ ' ,--"'-. ~'<r--,q'q; ti ! * SURVEY AREA~.,,. I ~ ! t \ i ' ~ 1.1 I ,.~ T.l'3U - .13N. VICINITY MAP ,. N.T.S. LECEND + ~S-aUILr ~U. CONouCToR · EXISTING -V~LL.CONOUCTOR [] AS-STAKED WELL CONDUCTOR .. SURVEYOR'S CERTIFICATE [ HEREBY CERTIFY THAT { AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING [N THE STATE OF ALASKA-AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION ANO THAT AL_L DIMENSIONS AND OTHER 0E-TAILS ARE CORRECT AS OF' MAY 16, 1'998. LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N., R. 10 E., UM[AT MERIDIAN ALASKA - wELL '' A.S,'P, ' PLAN? "' GEODETIC GEODETIC .... cELLAR.. SECTION NO. COORDINATES COORDINATES POS[TION(DMS) POS[TION(D.OD) BOX ELEV, OFFSETS ,,. Y=6,O16,577.55 N. 2,400.04 -70'27'20.345" 70.4556514' 4,0¢1' FSL MPE-55 X= 569,069.07 E. 1,¢49.50 149'26'10.812" 149.4565367' 25.1' 2,075' FEL J0'cl £00'ON 81:'0~5 86,61: XUN c~^~- STOLL _ c.~c~o: LOH 5/19/g8 "=200' L BP EXPLORATION MILNE POINT UNIT- E PAD AS-BUILT WELL CONDUCTOR WELL MPE-35 'QI linch = BI)Oft ~ 7533.41 MD _ _ ./ ,;45o.lo TVD I I J I ~~. 1~1~ ~ 800 t 600 2~0 3200 ~00 Ve~i~! Section s~;=n ~muth; ~.711' (Truo No~h) 3600 3000 24OO :~q'l rio0 1200 - 'Eastings Inch = 8OGYt _,,,po -.1,o r 4450.10TVD. - _ ~ - ~ I -12O0 .600 o Scala: ~i.~-h = 600ft Referance i. True North East:ing~ 4.2oo ~600 34~00 1800 Z t200 600 !1 ] DrillQuest' Uilne Point Unit Measured Depth Mci, Azim. Sub-Sea Depth Vedical Depth 0.00 e.O00 0.000 -56.10 0.00 100.00 O.O00 0,000 43.90 100,0~ 200.00 0.000 0,000 143.90 200,00 300.00 0,0~0 0.000 243,90 300.00 400.00 I),O00 0,000 343.90 400.00 500.00 0500 920.000 443.90 500.00 600.00 1.000 320.000 543.89 599.99 700.00 1,500 320.000 643,87 699~97 800,00 2.001) 320.000 743,82 799.92 900,00 ~.000 320.000 843,72 899.82 1000,00 4:000 320.000 943.53 999.63 1 I00,00 4.000 320.000 11)43,29 1099,39 1200,00 4.000 320.000 1143.05 1199.15 1300.00 4.000 320.000 1242.80 1298,90 1400,00 4.000 320,~0 1342.56 1398,66 1500.00 4000 320,000 1442.32 1496.42 1600.00 4..000 320,000 1542.07 1598,17 1700.00 4.000 320,009 1641.83 1697.93 1800.00 ¢.000 320.000 174159 1797.69 1833.50 4.000 320,000 1775.00 1831.10 ~900.00 4,000 320.000 1841.34 1897.44 1902.56 4.000 320.000 1843,90 1900.00 2000.00 6.436 820.000 1940,92 1997.02 2~00.00 8:9.~6 ..q20.000 2040,02 2096.12 2200.00 11,435 320.000 2138.43 2194.53 2300.00 13.936 320,000 ?_.235~99 2292.09 2342.56 15,000 320.000 2277,20 2333.30 2400,00 16.421 319.245 2332A9 2388.59 2SO0.~O 16.901 318.196 2427.77 2483,87 2600,00 21.385 317.382 2521,64 2577.74 Sperry-Sun Drilling Services Proposal Report for MPE-33 (98-3) - MPE-33 (98-3) WP4 Local Coordinates GlobalCoordinates Dogleg Vedical Northings Eastings Northings Eastings Rate S~ction (~) (fl) (~t) pt) ("/100f~) o,o0 N 0.00 E 6016577,35 N 569069.07 E 0.OD 0,00 PI 0.00 E 6016577,35 N 569069.07 E 0.000 0,00 0.00 Iq 0.00 E 6016577.35 N 569069.07 E 0.000 0,00 0.00 N 0.0o E 6016577.35 N 569069,07 E 0.000 0.00 0.00 N 0.0o E 6016577.35 N 5691)69.07 E 0.000 0.00 0.33 N 0.28 W 6016577.68 N 569068.79 E 0.500 0.¢1 1.34 N 1.12 W 6016578.68 N 569067.94 E 0,500 1.63 3.0l N 2.52 W 6016580.33 N 569066.52 E 0.500 3.67 5.35 N 4.49 W 6016582,66 N 569064.53 E 0,500 6.53 8.69 N 7.29 W 6016585.97 N 569061.70 E 1,000 10.61 13,37 N 11.21 W 6016590,61 N 569057,73 E 1.000 16,32 18.71 N 15.70 W 6016595,91 N 569053,20 E 0.000 22,84 24.05 N 20.18 W 6o16601,21 N 569048,67 E 0.00D 29.37 29A0 N 2¢.67 W 6016606,52 N 569044,13 E 0.000 35.89 34,74 N 29.15 W 6016611.82 N 569939,60 E 0,000 42.42 40.08 N 33,63 W 6016617.12 N 569035.07 E 0.000 48.94 45.43 N 38,12W 6016622.42 N 559030.53 E 0.000 55.47 50.77 N 42.60W 6016627,72 N 569026.00 E 0,000 61,99 56.11 N 47,09W 6016633.03 N 5$9021.47 E 0,000 68,52 57.90 N 48.59 W 601663¢.80 N 559019.95 E 0,00O 70,70 61.46 N 51.57 W 6016638.33 N 569016.93 ~: 0.000 75,04 61.60 N 51.68 W 6016638,46 N 569016.82 E 0.000 75.21 68.38 N 57.38 W 6016645.20 Iq 569011.06 E 2.500 83.50 78.63 N 65.98 W 6016655,36 N 569002.37 E 2.500 96-01 92.17 N 77.34 W 6016666,80 Fl 568990,88 E 2.500 112.55 108,99 N 91.46 W 6016685.49 N 568976.61 E 2.500 133.09 117.14 N 98.29 W 6016693,57 N 56~969,70 E 2.500 143.03 128.99 N 108,37 W 6016705.32 N 5t~5959,51 E 2500 157.54 151.77 N 128,40 W 6016727.92 N 568939,27 E 2,500 185.6~ 17726 N ~51 54 W 6016753.20 N 568915.89 E 2500 217,37 Comment Base Permalrost Alaska State Plane Zone 4 Milne Point E Pad C~ntlnued... 27 duty, 1998.9:39 Sperry-Sun Drilling Services Proposal Report for JVIPE-33 (98-3) - MPE-33 (98-3) WP4 Uilne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Do~leg Veil[cai Depth Incl. Azim. Depth Depth Northtngs Easting9 Nm'things Eastings Rate Section Corement (It) (fl) (ft) (It) (It) (ft) (It) (°/lOOft} (fl) 2701),00 23,873 316,7:31 2613.94 2670.04 205A2 N 17726 W 6016781.11 N 568889,41 E 2,500 252,61 2800,00 26362 316.196 2704-,48 2760.58 236.18 N 207.01 W 6016811.60 Fi 568859,88 E 2,500 291.31 2900.00 28.854 315.748 2793.08 2849.18 269.49 N 239.22 W 6016844.61 Pi 568827,37 E 2,500 333,39 301)0.00 31.346 315.365 2879,59 2935.69 305.29 N 274.33 W 6016880.08 N 568791.92 E 2.500 378,78 3100.00 33.640 315.033 2963,84 3019.94 343.51 N 312.29 W 6016917.95 N 568753.61 E 2.500 427,39 3200.00 36.334 314.742 3045,66 310126 384,07 N 353.02 W 6016958.13 lq 568712.51 E 2.500 479.12 3300.00 38,830 314.463 3124,90 3181.00 426.89 N 396.43 W 6017~00.55 N 568668.69 E 2.500 533.89 3400.00 ¢l.325 314.251 3201,41 3257.51 471,91 N 442,46 W 6017045,13 N 568622.26 E 2.500 591.58 3427.75 42.016 314.190 3222.14 3278,24 48428 N 455,68 W 6017057,86 N 568608.91 E 2.500 608.09 3500.00 42.018 314.190 3275.62 3331,92 518,48 N 490,36 W 6017091.26 N 568573.93 E 0.000 651.36 3600.00 42.0t8 314.190 3350.11 3406,21 565,14 N 538,35 W 6017137.46 N 568525.50 E 0,01)0 711.25 3646.13 42,O18 314.190 3384.38 3440,48 586,66 N 560,49 W 6017158.79 N 568503,16 E 0,O00 738.88 3700:00 42,881 315.722 3424.'[3 3480,23 612,35 N 586,22 W 6017134.24 N 568477,20 E 2,500 771.63 3800.00 44.535 318.436 3496.42 3552,52 662,96 N 633.24 W 60t7234.41 N 568429,71 E 2.500 834,93 3900.00 46,249 320.992 3566.65 3622.75 717.27 N 679.25 W 60'17288.29 N 568383,20 E 2,500 901.39 4000,00 41L017 323,404 3634.68 3690.78 775.19 N 724.15 W 6017345.79 N 568337.77 E 2.500 970,88 4100,00 49,833 325,684 3700.39 3756.49 836,59 N 767.85 W 6017406.79 N 568293.50 E 2.500 1043.28 4200',00 51,691 327,844 3763.65 3819.75 901.38 N 810.28 W 6017471.18 N 568250.47 E 2.500 1118,45 4213,51 51,945 328,127 3772.00 3828,10 910.38 N 815.91 W 6017480,13 N 568244.75 E 2.500 112B.81 Top U~nu 4300,~ 53,567 329,895 3824.33 3880.43 969.41 N 851.35 W 6017538.83 N 666208.77 E 2.500 1196.23 4400.~ 55,516 331,847 3882.33 3938.43 1040.57 N 890,90 W 6017609,62 N 568168.4.7 E 2.500 1276.49 4500.00 57,475 333.710 3937.53 3993.63 1114,72 N 929,11 W 6017683,41 N 568129.66 E 2.500 1359.07 4594.44 59,349 335.396 3987.00 4043.10 1 ~87.36 N 963,66 W 6017755.73 N 568094.44 E 2.5{)'1) 1439.04 Top M Sand 46F,),00 59.460 335.493 3989.83 4045.93 1191,71 N 965,65 W 6017760.06 N 568092,41 E 2.50~ 144,3.81 4700,O0 61.468 337,204 4039,13 4095,23 1271.41 N 1000,54 W 6017639.43 N 568056,79 E 2.501) 1530,55 48~0,00 53.497 338.851 4085.33 4141,43 1353.65 N 1033.7'[ W 6017921,36 N 566022,86. E 2,500 1619,13 4900,1)0 65.545 340.441 4128,35 4184.,45 1438.28 N 1065.09 W 601801:)5.70 N 567990,69 E 2-50[} 1709,38 50~),1)0 67.608 341.979 4168,10 4224.,20 1525.15 N 1094.64 W 6018092,28 N 567960.34 E 2.50i) 1801,13 5!00,00 69.685 343.473 4204,51 4260,61 1614.08 N i122.28 W 6018180.95 N 567931.87 E 2,500 1894.20 5192.1)0 71.608 344.811 4235.00 4291,10 1697,57 N 1145.99 W 6018264.22 N 567907.39 E 2.500 1980.84 T~ N-A Alaska State Plane Zone 4 Milne Point E Pad 27 Ju~y, 1998 - 9:39 .2. DrillQues! Sperry-Sun Drilling Services Proposal Report for MPE-33 (98.3). MPE-33 (98.3) WP4 Milne Point Unit Alaska State Plane Zone 4 Uilne Point E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl, Azlm, Depth Depth Nmthings Eastings NorthJngs Eastings Rate Section Comment (ft) (it) (~t) (It) (~) (~t) (~t) (°/~O0~t) (fl 5200.(X) 71_775 344.926 4237.51 4293,61 1704.90 N 11¢7,98 W 6018271.53 N 5679053¢ E 2,5{X) 1988,41 5300,00 73.876 346.345 4267.04 4323,14 1797.45 Iq 1171,67 W 6018363.56 rd 567880.79 E 2,500 2083.59 5400.00 75.985 347.735 4293.04 4349.14 1891.54 iq 1193.32 W 6018457.75 N 567858.27 E 2,500 2179.56 5500,00 78.103 349.005 4315.46 4371.56 1987.01 N 1212.88 W 6018553.03 iq 567837.82 E 2,500 2276.I2 5600.00 80,227 350.441 4,3,34.26 439036 2083.65 N 1230.32 W 60~8649.51 N 567819.49 E 2.500 2373.11 5700,00 82,356 351.767 4349.40 4405,50 2181.31 N 1245,60 W 6018747.01 N 567803.30 E 2.500 2470.32 5800,00 84_489 353.079 4360.85 4416.95 2279.77 N 1258.70 W 6018845.35 N 567789.29 E 2.500 2567.59 5900.00 86.625 354.382 4368.60 4424.70 2378.87 N 1269.58 W 6018944.35 N 567777.49 E 2.500 2664.72 $976.10 8e.252 355370 4372.00 4428A0 2454.59 N 1276.37 W 6019020.00 N 567770.00 E 2.500 2739.43 To DA Ta~et: MPE-33 TOP DA T1, Geological 6000,00 88.217 355.370 4372.74 4425.84 2478.40 N 1278.30 W 60'19043.79 N 567767.85 E 0.148 2761.54 6100.00 86.069 355.370 4375,98 4432.08 2578,02 N 1286.36 W 6019143.33 N 567758.86 E 0A48 2858.23 6200.00 87.921 355.370 4379.48 4435.58 2677,63 N 1294.43 W 6019242.86 N 567749,87 E 0.148 2954,92 6300,00 87274 355.370 4393,23 4439.33 2777,23 N 1302.50 W 6019342.39 N 567740,86 E 0.148 3051.5!) 6400.00 87.626 355,370 4387,24 4443.34 2876,83 N 1310.56 W 6019441.90 N 567731.69 E 0.148 3148,26 6500.00 87.479 355.370 431)1,51 4447.61 2976A1 N 1315.63 W 6019541,41 N 567722.9I E 0.148 3244.91 6599,10 87.333 355.370 4396.00 4452.10 3075.05 N 1326.62 W 6019640.00 N 567714.00 E 0.148 3340.61) Talgei'. MPE-3,1EIASE tiP SAND, Geological 6600,00 87.346 355.371 4396,04 4452,14 3075,98 N. 1326.69 W 6019640,90 N 567713,92 E 1.500 3341.56 6673.07 88,441 355.416 4396,73 4454.83 3148.76 N 1332.56 W 6019713.62 N 567707,38 E 1.500 3412.19 6700.00 88.441 355.416 4399,45 4455.56 3175,60 N 1334.71 W 6019749,44 N 567704.98 E 0.000 3438.23 6800.00 68.441 355.416 4402.18 4456.28 3275,24 N 1342.70 W 6019840.00 N 567696.07 E 0.000 3534.92 6900.00 88_441 355.416 4404,90 446'[.00 3374.88 N 1350.69 W 6019939,57 N 567657.15 E 0,009 3631.61 7000.00 88.441 355.416 4407,62 4463.72 3474.53 N 1358.68 W 6020039.13 N 567678.24 E O,t)l)D 3728.30 7013.93 68.441 355.416 4406,00 4464.10 3488,41 N ' 1359.79 W 6020053.00 N 567677.00 E O,ODO 3741.77 Target MPE-33 TOP LOW SAlqD, Gel)logical 7100.00 69_732 355.383 4409,37 4465.¢7 3574.19 N 1366,69 W 6020136.71 N 567669.30 £ 1.500 3925.01 7200.00 91.231 355.345 4405,53 4464.63 3673,65 N 1374-.7'/W 61)20238,31) N 567660.30 E 1,501) 3921.75 7299.25 92,720 355.307 4405,11 4461.21 3772.72 N 1382.86 W 6020337,05 N 567651.30 E 1.500 4017.74 7300,00 92.720 355.307 4405,1)7 4465.17 3773.46 N 1382,92 W 6021)337.83 N 567651.23 E 0,000 4018.46 7400.00 92.720 355.307 4400,33 4456.43 3873.01 N 1391.09W 6020437.30 N 567642.13 E 0.000 4115.12 7500.00 92.720 355.307 439,5,59 4451.69 3972.56 N 1399,26 W 6020536.77 N 567633,04 E 0.000 42tl.78 7533.4.1 92.720 355.307 43~.1)0 4450,10 4005.82 N 1401.99 W 602057{).00 N 567630.00 E 0,000 4244.08 3 1/2' liner . Target: MPE-33(98-3) TD, Geological Continued.,, 0 27July, 1998 - 9:39 -3. DrtltQuest Sperry-Sun Drilling Services Proposal Report for MPE-33 (98-3)- MPE.33 (98-3) WP4 Milne Point Unit All data is in leer unless otherwise stated. Directions and coordinates are relalive !o True Norlh. Vertical depths are relative to Welt. Norlhings and Eastin[Is are relalive Io Well. The Dogleg Severity is in Degrees per lOOft. Vertical Sedion is Imm Well and calculated along an Azimuth ot 340.711° {'[rue). Based upon Minimtzm Cuwature type calculations, at a Measured Deplh of 7533.41f1., The Boltom Hole Displacemenl is 4244.081t., in ~he Direction o1340.7'11° (True). Alaska State Plane Zone 4 Uiine Point E Pad 0 Z 27 July, 1995 - 9:39 .4- DriltQue$! Shared Services Drilling Contact: I Well Name: R. George Scott IMP E-33 Well Plan Summary . IType of Well (producer or injector): Schrader Bluff Horizontal Producer 564-5862 Surface Location: 4041' FSL, 2073' FEL, S25 T13N R10E UM Target Location: 1216' FSL, 3348' FEL, S24 T13N R10E UM Bottom Hole Location: 2767' FSL 3473' FEL, S24 T13N R10E UM I AFE Number: 1337137.1 I {Estimated Start Date: I 1 August 98 I I Operating days to complete: I 12.0 IMD: 17533' I ITVD: 14450' I IKBE: Rig: I Nabors 27E 157ft I Well Design: ! Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS KOP 4OO 344' Base of Permafrost 1834' 1755' Top of Ugnu 4214' 3987' Top M Sand 4594' 4046' Top NA (Target) 5192' 4235' Top of the N-A (EMW 8.6 ppg) 5-1/2" Casing Shoe 5800' 4361' (Picke,d by Geologist) Top "OA" 5976' 4372' Geo-steering will be required to keep in "OA" Base "OA" 6599" 4396' Top "OB" 7014' 4408' Expected to be wet. TD 7533' 4394' TD Casing/Tub in9 Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151' 6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 5770' 30'/30' 5800'/4417' 4-3/4" 3-1/2" 9.3# J-55 8-RD. SC'C 1833' 5700?4405' 7533'/4450' Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4316' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1930 psi (8.6 ppg EMW), is 1498 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top 2 joints in the 5-1/2" surface casing consists of 2 joints of 7" 26# BTO-MOD L-80, this is required to accommodate the penetrater offset. This will require a X-over to the 5-1/2" 15.5# J-55 BTO-MOD Casing. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151", Collapse-5410psi, Burst-7240psi, Yield-604M lbs. The 3-1/2" 9.3# liner has an ID of 2.992", OD of 4.180", Drift-2.867", collapse-7400psi, Internal Yield-6980psi, Yield-109.37M lbs. MP E-33 Well Plan PAGE 3 26 July 98 Logcjinc. I Program: Open Hole Logs: Surface: FINAL: Cased Hole Logs: MWD directional only from surface to 2500' MD. 4-Arm Caliper Log From 5800'MD to 151' M.D. (Base of 13-3/8" Conductor.* MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr. MWD Directional and LWD GR/RES. 5800'MD-7533'MD. (TD) None Mud loggers are NOT required for this well. *A conditioning trip may be made if required to assure runninc~ the caliper. Mud Program: of Special design considerations An inhibitive polymer mud is planned from surface to 5800'MD. Solids control is critical to the success of the system. A drill in Mud with calcium carbonate to limit fluid invasion from 5800'o7533'MD Surface Mud Properties: I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 9.0 50 30 14 16 8.5 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 The surface casing will be drilled out to +1- 20' of new hole then the mud changed out to drill in mud for horizontal section. Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diverter with 10" Diverter Line. This Rig is equipped with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer used for drilling the horizontal section and for the completion, capable of handling maximum potential surface pressures. Note it is planned to test the BOPE to 3500psi with a cup tester, and the 5-1/2" casing to 3500psi as the anticipated maximum BHP is 1930 psi. Directional: I KOP: 14oo' MD I Maximum Hole Angle: 92.720° @ 7300'md Close Approach Well: Close Approach To MPE-02 A SHUT IN WATER INJECTOR WELL. 31.84' @ 496.83' md. Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned. MP E-33 Well Plan PAGE 4 26 July 98 MP E-30 Proposed Summary of Operations 1. Drill and Set 13-3/8" Conductor. Weld landing ring assembly on conductor. 2. Prepare location for rig move. . MIRU Nabors 27E rig. NU and function test 13-3/8"" diverter. Spud Mud Will Have been Built as per Mud Program. 4" D.P. 2-7/8" work string and 2-7/8" drill pipe will have been stood back prior to spud. 5. Drill a 6-3/4" surface hole as per directional plan. Run,Directional MWD from surface to +/- 2500'MD. . POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. Drill 6-3/4" hole to 5800' as per directional plan. Stand back drill string and run 4-Armed Caliper from the 5800'M.D. to the bottom of the 13-3/8" conductor. . Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing using innerstring method. Refer to attached Detailed Cement Program and Back-up Pod Collar Operating Procedure. . Following the cementing of the well and the landing of the 7" landing joint rig down cementers. N/D diverter, MU casing head to top joint of 7" csg. (9500 fi-lbs torque.) Install BOPE with 2-3/8" rams. Test BOPE and Casing individually to 3500 psi, 74% of burst of 5-1/2# J-55 Casing. 10. PU 4-3/4" directional BHA and drill out cement collar and shoe and 20' of new hole. Circ. & Cond. Mud, no LOT will be required. Pump a 20 bbl. High risc. pill (70 Y.P.) sweep ahead of drill in fluid. (See Mud Program). 11. Shod trip as required before POOH for 3-1/2" liner. Circ and condition wellbore POOH for 3-1/2" liner. NOTES: Hold a "pre-reservoir" meeting as per page 20 of Drlg. Policy Manual. Record on Morning Report. Monitor torque and do not exceed 80% of DP torque. Pump Iow/Hi visc. sweeps every 500' of new hole. Maintain adequate flow rates to clean hole. 12. Run 3-1/2" pre-slotted liner as per attached liner procedure. 13. Displace hole to Kill weight brine. POOH. It is planned to complete this well with Rig 27E. A separate Completion program will be issued. POST DRILL AND CASE: Nabors Rig 27E will run the completion on this well. MP E-33 Well Plan PAGE 5 26 July 98 DRILLING HAZARDS AND RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. Specific potential hazards for this well are outlined below. The MPU PE group will be perforating, hydraulic fracturing and Cleaning out this as per the completion program. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If encountered mud will be treated with 1-1.5 ppb Lechithin (See Attached Mull Program). 2. Close Approach: There is a close approach problem with the E-02 water injector Well. Confirm that this well is shut-in and secured while drilling. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There have been several STUCK PIPE incidents on' Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1930 psi in the middle of the Schrader Bluff at 4316' TVDSS. 6. Directional Drillinq Concerns MP E-33 will be an ultra slim 6-3/4" hole drilled to a depth of 5800' md. Followed by 4-3/4" horizontal leg to TD. KOP is 400' md and a variable build rate from that point will yield a sail angle of 84.489 o at 5800' md. The maximum inclination of 92.72 deg. is reached at 7300' MD and held to TD. Departure is 4244'. 7. Cement The surface hole will be cemented to surface with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The excess will be run in the Cold Set II1. The top of the Class G is planned for 500' above the top of the Schrader Bluff Sands. A back up port collar will be run approximately 200' below the permafrost the exact position determined from the caliper Icg. This is a full gauge tool and will be placed using the caliper in a slightly over gauge section. - ...... -' ... MP E-33 5-'112"" SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.4;3 ppg. STAGE'I LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD:1.74 ft3/sx MIXWATER: 6.06 gal/sk APPROX #SACKS: 438 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F 90 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF Cold Set III CEMENT Port Collar +/- 2200'MD to surface +40% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: FLUID LOSS: FI-33-.4%, CD-32-.3%, R~1-.1% FP-6L lghs. WEIGHT: 15.8 ppg YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk 101 THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 5800 FEET 500' 'FVD ABOVE SCHRADER BLUFF + 80'md 5-112"'", 15.5# capacity for float joints. EST TOC 4300' md (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg YIELD:1.92 ft3/sx MIX WATER: 11.63 gal/sk 438 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 40% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN, WEIGHT: 12.2 ppg YIELD: 1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Spiral Glide 5-1/2" X 6-3/4" centralizers are planned for the 5-1/2" casing The number to be determined by the Caliper Icg, and also on the joint of casing above and below port collar. See attached Weatherford centralizer program in cementing section. 2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer program will be issued following receipt of the results of the 4-Arm Caliper Log. MP E-33 Well Plan PAGE 7 25 July 98 ~ N 2600.e0 N ~ 800.00 NOTES 1. ALASKA STATE PLANE COOROINATES ARE ZONE 4, NAD 27. 2. GEODETIC COOROINATI~S ARE NAD 27. 5. MEAN PAD SCALE FACTOR O.999905~3¢. ¢. HORIZONTAL ANO VERTICAL CONTROL BASED ON MONUMENTS CFP-5 end 5. DATE OF SURVEY: MAY 16, 1998. 6. REFERENCE FIELD BOOK: MP98-05 Pgs. 60-63. 7. ELEVATIONS ARE BASEO ON BPX MILNE POINT DATUM (M.S.L.). VICINITY M.AP .. N.T.S. LEGEND · + AS-BUILT WELL CONDUCTOR · EXISTING .WELL. CONDUCTOR [] AS-STAKED WELL CONDUCTOR SURVEYOR'S CERT[FICATE [ HERESY CERTIFY THAT [ AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY OIRECT SUPERVlSlON AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 16, 1'998. 3N. i LOCATED WITHIN PROTRACTED SEC. 25, T. 1..3 N., R. 10 E., UM[AT MERIDIAN, ALASKA wE~EL .... A.S.P. PLANT GEODETIC GEODETIC' ' ' CELLAI~" 'SECTION NO. COOROINATES COORDINATES POS[T[ON(DMS) POS[TION(D.OD) BOX ..ELEV. OFFSETS Y= 6,0i'6,577.35' N I' '~' ~'~ ' 7~'27'20,345',: 70.4556514' , la 15/19/9 ISSUED FOR INFORMATION i_ ~0'd £00'ON 8~'0~ 86,6~ AUN STOLL c.Ec,~o: LOH 1",,,2OO'i iBPEXPLORATION MILNE POINT UNIT- E PAD AS-BUILT WELL CONDUCTOR WELL MPE-35 lo¢1 '0I I DrillQuest- ;O0.OO 0 ~,,"talo: 1Inch = fiOOft 800 t600 2~0 3200 Venial Section s~;on ~mu~h; 420O 3600 3000 -- 2400 -- ~1800 -- 12Q0 -- H ~ o I I 200 .600 o · inch -- 600ft Reference is True North Eastings 3000 1800 ~ 600 l DrillQuest- Sperry-Sun Drilling Services Proposal Report for MPE-33 (98-3) - MPE.33 (98.3) WP4 Uilne Point Unit Measured Sub-Sea Vedical Local Coordinates Global Coordinates Dogleg Veal[cai Depth lncl, Azlm. Depth Depth Northings Eastings Nodhlngs Eastings Rate S~ction Comment Ct) (ft} (ft) (~) (ft) (tt) (ft) ("/100rt) 0.00 0,000 0,000 -56.10 100.00 0.000 0,000 437J0 100,00 200.00 0.000 0,000 143.90 200.00 300.00 0.O00 0,000 243.90 300.01) 400.00 I),000 0,00O 343.90 480.00 500.00 0,500 320.000 443.90 500.00 600.00 1,000 320.000 543.89 599.99 700.00 1,500 320.000 643,87 699.97 800,00 2.D00 320.000 743,62 799.92 900,00 3.000 320,000 843,72 899.82 1000.00 4.000 320.000 943.53 999.63 1100.00 4.1:O0 320.000 11)43.29 1099,39 0,00 N 0.00 E 6016577,35 N ,56906g.07 E 0.0D 0,00 N 0.00 E 6016577,35 N 56906%07 E 0.000 0.00 0.00 PI 0.00 E 6016577,35 N 569069.07 E 0.000 0.00 0.00 N 0.00 E 6016577.35 N 569969,07 E 0.000 0.00 0.60 N 0.00 E 6016577.35 N 569069,07 E 0.000 0.00 0.33 N 02.8 W 6016577.68 N 569068.79 E 0.500 0.4-1 1.34 N 1.12 W 6016578.68 N 5690~,94 E 0.500 1.63 3.0! N 2.52 W 6016580.33 N 569086.52 E 0,500 3.67 5.35 N 4.49 W 6016582,66 N 569064.53 E 0,5® 6.53 8,69 N 7.29 W 6016585.97 N 569081.70 F.. 1,0~ 10,61 13,37 N 11.21 W 8016590,61 N 569057.73 E 1.ODD 16,32 18.71 N 15.70W 6016595,91 N 569~53,20 E 0.000 22,64 1200,00 4.000 320.000 1143.05 1199.15 24,05 N 20.18 W 601660121 N 569{)48,67 E 0.000 29.37 1300,00 4`000 320.000 1242.80 1298,90 29.40 N 24..67 W 6016606,52 N 569044,13 E 0.000 35.89 1400,00 4.000 320,000 1342.56 1398,66 34.74 N 29.15W 6016611.82 N 569039.60 E 0,000 42.42 1500.00 4,000 320,000 1442.32 1498,42 40.08 N 33,63 W 6016617.12 N 569035.07 E 0.000 48.94 1600.00 4-.000 320,000 1542.07 1598,17 45.43 N 38,12 W 6016622.42 N 569030.53 E 0,00O 55.47 1700.00 4.000 320,01)0 1641.83 1697.93 50.77 N 42.60 W 61)16627.72 N 569026.00 E 0.0~ 61.99 1800.00 ~,.O00 320.000 1741.59 1797.69 5611 N 47,09W 6015633.03 N 5~9021.47 E 0,00O 66,52 1833.50 4.060 320,000 1775.00 1831,10 57,90 N 48.59 W 601663¢.80 N 5590'19.95 E O,000 70,70 Base Permalmst 1900.00 4.060 320,000 1841.34 1897.44 1902.56 4,000 320.000 1843,90 1900.00 2000.00 6,436 320.000 1940,92 1997.02 2[00.00 6,936 320.000 20~,02 2096.12 2200,00 11,436 320.000 2138,43 2194.53 61.46 N 51.57 W 6016638,33 N 569016.93 E 0,000 75,04 61.60 N 51.68 W 6016638,46 N 569016.82 £ 0.000 752'[ 68.36 N 57.38 W 6016645,20 N 569011.06 E 2.500 83.50 78.63 N 65.98 W 6016655,36 hi 569602.37 E 2,500 96.01 92.17 N 77.34 W 6016668,80 N 568990,88 E 2.500 112.55 2300,00 13.936 320,000 2235,99 2292.09 108,99 N 91,46 W 6016665A9 N 5~8975,61 E 2.500 133.09 2342,,56 15,000 320.000 2277,21) 2333.30 117,14 N 98.29 W 6016693,57 N 568969,70 E 2.500 143.03 2400,~ 16.421 319.245 2332.4~) 2388.59 128,99 N 108.37 W 601671)5.32 N 56Ii959,51 E 2500 157.54 2500.00 18.901 318.196 2427.77 2483,87 151.77 N 128.40W 6016727.92N 56893927 E 2.500 185.66 2600.01) 21.385 317.382 2521.64 2577.74 177.26 N 1,51.54 W 6016753.20 N .566915.69 E 2,5~ 217,37 Alaska State Plane Zone Milne Point E Pad Con,hued,,. 27 July, 1998 Sperry-Sun Drilling Services Proposal Report for MPE.33 (g8-3) - MPE-33 (98-3) WP4 Uilne Point Unit ~easured Sub-Sea Vertical Local Coordinates Globsl {:;oon:linates Dogleg Vetl[cal Depth Incl. Azim. Depth Depth Northings Eastings Nm'things Eastings Rate Section Comment (~) (~t) (~t) (ft) (~t) (ft) (ft) (°/'tOOtt} 270l).0D 23,573 316.731 2613.94 2670.04 205.42 N 177,76 W 6016781.11 N 568889.41 E 2,500 252,61 2800.00 26362 316.195 2704,48 2760.58 236.1. B N 207.01 W 6016811.60 N 568859.68 E 2,500 291.31 290{).00 21~.554 315.745 2793.08 2849.18 269.49 N 239.22 W 6016844.6t N 568827.37 E 2.500 333,39 3000.00 31.346 315.365 2879.59 2935.69 305.29 N 274.33 V¢ 6016880.08 N 568791,92 E 2.500 378,78 3100.00 33.840 315.033 2963,84 3D19.94 343.51 N 312.29 Vi/ 6016917.95 N 565753.61 E 2,500 427,39 3200.00 36,334 314.742 3045,66 3101.76 384,07 N 353.02 W 6016858.13 N 565712.51 E 2.500 479.12 3300.00 38.830 314.483 3124,90 3181.00 426.89 N 396.43 W 6017~X)0.55 N 568668.69 E 2.500 533.89 3400.00 4.t.325 314.255 3201,41 3257.51 471,91 N 442,46 W 6017045,13 N 566622.26 E 2.500 591.58 3427.75 42.018 314.190 3222,14 3278,24 484.78 N 455,68 W 6017{)5'/,65 N 566608.91 E 2.500 608.09 3500,00 42.018 314390 3275.82 3331,92 518,48 N 490.36 W 6017091,26 N 558573.93 E 0.000 651,36 3600.00 42.016 314.190 3350.11 3406,21 565,14 N 538,35 W 6017137.46 N 568525.50 E 0.0IX) 711.25 '' 3646.13 42.018 314390 3384.36 3440.48 586,66 N 560.49 W 6017156.79 N 568503,16 E 0,OI)0 738.88 3700.00 42,88! 315.722 3e,24.1,3 3480,23 612,35 N 58622 W 6017184.24 N 568477,20 E 2,500 771.63 3800.00 44.535 318.436 3496,42 35.52,52 662,96 N 633.24 W 6017234.41 N 558429,71 E 2,500 834,93 3900.00 46,249 320.992 3566.65 3622.75 717.27 N 679.25 W 601728629 N 568383,20 E 2,500 901.39 4000.00 49,017 323,404 3634.68 3690,78 775.19 N 724.15 W 6017345.79 N 568337.77 E 2.500 970,68 4100,00 49,833 325,684 3700.39 3756.49 636.59 N 767.85 W 601'/'406.79 N 668293.50 E 2.500 1043.28 4200,00 51,691 327,844 3763.65 3819.75 901.38 N 810.26 W 6017471.18 N 565250.47 E 2.500 1116,45 4213.51 51.945 328.127 3772.00 3828.10 910.38 N 815.91 W 6017480.13 N 565244.75 E 2.500 1126.81 Top Ugnu 4300.00 53,567 329,8~)5 3824.33 3880.43 989.41 N 851.35 W 6017538.83 N 56~08.77 E 2.500 1198.23 4400.00 55,516 331,847 3882.33 3938.43 1040.57 N 890.9~)W 601760~),62 N 568168.4,7 E 2.500 1276.49 4500,00 57,475 333.710 3937.53 3993.63 1114,72 N 929,11 W 6017683,41 N 561~'i29.66 E 2,500 1559.07 4594,44 59,349 335,396 3987.00 4043.10 1 I87.36 N 963,66 W 6017755,73 N 568094.44 E 2.509 1439.04 Top M Sand 46~.00 59.460 335.493 3989.83 4045.93 1191,71 N 965,~W eO1T/60.08N 568092,41 E 2.500 1443.81 4700,00 61.466 337,204 4039,13 4095.23 1271.41 N 1000,54 W 6017639.43 N 588056,79 E 2,500 1530,55 48~0,00 63Ag7 338.851 4085.33 4141,43 1353.65 N 1033.7t W 6017921,36 N 568022,86 E 2,51~ 1819,13 49~,00 65.545 340.441 4128,35 4184,45 1438.28 N 1065.09 W 6018005.70 N 587990,69 E 2,500 1709,38 5000.00 67.608 341.979 4161t,10 4224,20 1525.15 N 1094.54 W 601S092,28 N 567960.34 E 2.500 1801,13 5100, D0 89.685 343.473 4204,51 4260.61 1614.08 N 1122.28 W 6018180.95 N 567931.87 E 2.500 1894.20 5192.00 71.608 344.811 4235,00 4291,10 1697,57 N 1145.99 W 6018264.22 N 567~07.39 E 2.500 1980.84 Top N-A Alaska State Plane Zone 4, Uilne Point E Pad o ¢ontinu~... o 27 July, 1998 - 9:39 · 2. Dri#Ouest Sperry-Sun Drilling Services Proposal Report for MPE.33 (98.3)- MPE-33 (98.3) WP4 Milne Point Unit Alaska State Plane Zone 4 Nlilne Point E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl, Aztm. Depth Depth Northings Eastings Norlhtngs Eastings Rate Section Comment 5200,00 71_775 344.926 4237,51 4293,61 3704.90 N 114.7,98 W $016271.53 N 567905.34. E 2,500 1988,41 5300,00 73.876 346.345 4267.04. 4323,14 1797.45 N 1171,67 W 6018363.66 N 567660.79 £ 2,500 2083.59 5400,00 75.985 347.?35 4293.04 4340.14 1891.54 iq 1193.32 W 60111457.75 iq 567658.27 E 2,500 2179.56 5500,00 78,103 349.098, 4315.46 4371.56 1987.0! iq 1212.81] W 6018553.03 N 567837.82 F_. 2,500 2276.12 5600.00 80,227 350.441 4334..26 4390.36 2083,65 [,,i 1230.32 W 60t 8649.51 N 567819.49 E 2.5~ 2373.'[t 5700.00 82.356 351.767 4349.40 4405,50 2181.31 N 1245,60 W 60'[8747,01 N 567803.30 E 2.500 2470.32 580(3,00 84.489 353.079 4360,85 4416.95 2279.77 N 1258.70 W 6018845,35 N 567789.29 E 2.500 2567.59 5900.00 86.625 354.362 4368.60 4424.70 2378.67 N 1269.58 W 6018944.35 N 567777A9 E 2.500 2664.72 5976.10 88.252 355,370 4372,~ 4428.10 2454.59 N 1276,37 W 6019020.00 N 56"n70,~ E 2.500 2738.43 ToD Ok Tat'get: MPE-33 TOP O^ T1, Geological 6000,00 88.217 355.370 4372,74 4428.84 2478,40 N 1278.30 W 6019043.79 N 587767,85 E 0.148 2761.54 6100.00 81).069 355.370 4375,96 4432.08 2578,02 N 1286.36 W 6019143.33 N 567758,86 E 0.I48 2858.23 6200.00 87.921 355.370 4379,48 4435.58 2677,6,3 N 1294.43 W 6019242.86 N 567749,87 E 0.148 2954,92 6300.00 87,774 355.370 4383,23 4439.33 2777.23 N 1302.50 W 6019342.39 N 567740,88 E 0.148 3051.50 6400.00 87.826 355.370 4397,24 4443.34 2876.83 N 1310.56 W 6019441.80 N 567731,69 E 0.148 314825 6500.00 87.479 355,370 439151 4447.61 2976A1 N 1318.63 W 6019541,41 N 567722.91 E 0.148 3244,91 6599,10 87.333 355.370 439~,01) 4452.10 3075,06 N 1326.62 W 6019640.00 N 587714,00 E 0.148 3340.69 3'alget: MPE-33BASE. UP SAND, Geologlcal 6600,00 87,346 355.371 43~,04 4452,14 3075,98 N 1326.69 W 601964{),,90 N 567713,92 E 1.500 3341,.56 6673.07 88,441 355.416 4396.73 4454.83 3146.76 N 1332.56 W 6019713,62 N 567707,38 E t.500 3412.19 6700.00 88,441 355.416 4399.46 4455.56 3175,60 N 1334.71 W 6019740,44 N 567704.98 E 0.000 3438.23 6800.00 88.441 355.416 4402,18 4458.28 3275.24 N 1342.70 W 6019840,00 N 567696.07 E 0.0® 35;34.92 6900.00 88_441 355.415 4404,91) 4461.00 3374.86 N 1350.69 W 6019939,57 N 567687.15 E 0,0.0.t)3631.61 7000.00 88,441 355.416 4407,62 4463.72 3474,53 N 1358.68 W 6020039,13 N 567678.24 E 0.{)~ 3728.30 7013,93 81],441 355.416 441~.00 4464.10 3486,41 N 1359.79 W 60201)53.00 N 567677,00 E 0,00,{) 3741.77 Target: MPE-33 TOP LOW SAND, Geological 7100.00 89_732 355.383 4409,37 4465.4.7 3574.19 N 1366,69 W 6020136.71 N 567669.30 F. 1,5~ 3625.01 7200.00 91.231 355.345 4401),,53 4464,63 3673,65 N 1374..77 W 60202.35,30 N 567660.30 £ 1,509 3921.75 7299.25 92,720 355.307 4405,11 4461.21 3772.72 N 1362.86 W 60203.37,08 N 567651.30 E 1.501) 4017.74 7300,00 92.720 355.307 4405,07 446~.17 3773.46 N 1382,92 W 6~0837.63 N 567651.23 E 0,000 40! 8.46 7400.00 92.720 355.307 44~,33 4456.43 3673.01 N 1391.09 W 6020437.30 N 567642.13 E 0.00D 4115.12 7500.00 92.720 355.307 4395,59 4451.69 3972.56 N 1399,26 W 6020536.77 N 567633,04 E D.000 42tl.78 7533.4.1 92.720 355.307 43~.1)0 4450,10 4005.8,2 N 1401.99 W 6020570.00 N 567630.00 E 0,000 4244.08 3 1/2' Liner Target: MPE-33(98-3) TD, Geolog[cal z 27 Juty, 1998 - 9:39 - 3. DrttlQues~ Sperry-Sun Drilling Services Proposal Report for MPE-33 (98-3)- MPE-33 (98-3) WP4 Milne Point Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Welt. Norlhings and Eastings are relslive to Well. The Dogleg Severity is in Degrees per lOOft. Vertical Section is from Well and calculated along an Azimuth o1340.7110 O'me). Based upon Minimum Curvature type calculations, at a Measured Depth o17533.41ff., The Bottom Hole Displacement is 4244.081t., in 1he Direction o1340.711° (True). Alaska State Plane Zone 4 Milne Point E Pad 27 July, 1998.9:39 .. 4- ~rillOues! DATE I CHECK NO. H 13 7 16 8 04/24/98 00137168 -, ~ VENDOR ALASKAST i 4 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 042298 CK042298C I00. O0 iO0. O0 HANDLINg- INST: S/H KATHY CAMPOA'~OR X 512-'2 ....... ~,,~ ~u~ ~ ~ ~ v · WELL PERMIT CHECKLIST COMPANY ,~/~) WELL NAME ./,¢//~.~" -~__~ FIELD & POOL ~'"_~...~'/'.~, INIT CLASS ~Z~ .//-,.~...~,/ GEOL AREA PROGRAM: exp [] dev,J~r redrll [] serv [] wellbore seg II ann. disposal para req II UNIT# ////, 7 ~ ? ON/OFF SHORE d'~,',J ADMINISTRATION ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling 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 ........... 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 abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N JN 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... ~yY ~~ 32. Seismic analysis of shallow gas zones ............. ~_ ,. 33. Seabed condition survey (if off-shore) ............. ,~/'~,~_AP~ _P R. _ _ DzD~AT F__,,,,4;~*~/-~// 34. C o~tact.na m. e/phOlexplora,ory only]ne for weekly progress repo rts ....... ./ Y N ANNULAR DISPOSAl_ 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y ~~~ APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y to surface; y/~NN (C) will not impair mechanical integrity of the well used for disposal; N (D) will not damage producing formation or impair recovery from a pool; and / (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: RPC.~___~ BEW ....--"~"'"-~ WM__ DWJ ~ J DI,4~-_~ RNC CO Comments/Instructions: M:chel~list rev 05129198 dlf: C \r]lsof fi(:o\wo~ dian\dir~n,'~\checklist 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Nov 11 16:49:54 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/11/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record 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: MWD RUN 2 AK-MM-80328 J. MARTIN P. LOCKWOOD MPE-33 500292289800 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES il-NOV-98 MWD RUN 3 AK-MM-80328 R. MCNEILL P.LOCKWOOD MWD RUN 4 AK-MM-80328 R. MCNEILL P.LOCKWOOD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 5 AK-MM-80328 R. MCNEILL J. PYRONE 25 13N 10E NOV 18 1998 FNL: FSL: 4041 FEL: 2073 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 56.60 GROUND LEVEL: 23.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 6.750 13.375 120.0 PRODUCTION STRING 4.750 7793.0 REFLARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 4. MWD RUNS 3 THROUGH 5 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 5. A CHANGE FROM DUAL GAMMA RAY (DGR) TO SCINTILLATION TYPE GAMMA RAY (NGP) OCCURRED AT 5525'MD, 4393'TVD. 6. ONLY SMOOTHED RATE OF PENETRATION (SROP) UTILIZED FROM MWD RUN 3. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM KATIE NITZBERG OF BP EXPLORATION (ALASKA), INC. ON 29 OCTOBER, 1998. 8. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7793'MD, 4403'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NLIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2872 5 7724.0 FET 2879 5 5532.5 RPD 2879 5 5532.5 RPM 2879 5 5532.5 RPS 2879 5 5532.5 RPX 2879 5 5532.5 ROP 2918 0 7793.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2918.0 5570.0 3 5570.0 5587.0 4 5587.0 6157.0 5 6157.0 7793.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 ROP MWD FT/H 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 RPD MWD OMMM 4 1 68 FET MWD HOUR 4 1 68 24 28 Name Min Max Mean Nsam DEPT 2872.5 7793.5 5333 9843 GR 5.6038 176.392 85.7734 9704 RPM 0.3822 58.0562 7.00068 5307 ROP 5.3495 871.072 175.964 9752 RPS 0.493 54.014 7.24342 5307 RPX 0.5434 38.2836 6.76447 5307 RPD 0.3735 61.8099 7.18819 5307 FET 0.1104 8.812 0.576059 5307 First Reading 2872.5 2872.5 2879.5 2918 2879.5 2879.5 2879.5 2879.5 Last Reading 7793.5 7724 5532.5 7793.5 5532.5 5532.5 5532.5 5532.5 First Reading For Entire File .......... 2872.5 Last Reading For Entire File ........... 7793.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2872.5 FET 2879.5 RPD 2879.5 RPM 2879.5 STOP DEPTH 5525.5 5532.5 5532.5 5532.5 RPS 2879.5 RPX 2879.5 ROP 2918.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~XY EWR4 $ 5532.5 5532.5 5570.0 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/gDOFF (IN) : EWR FREQUENCY (HZ): REFLARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 10-AUG-98 ISC 5.07 DEPII(2.22A) , SP4 (5.04) MEMORY 5570.0 2918.0 5570.0 27.8 77.9 TOOL NUMBER P1043GR4 P1043GR4 6.750 6.8 KLAGARD / POLYMER 9.30 59.0 8.5 6500 10.8 .8OO .580 .600 1.000 37.2 .5 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 2 API 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 FT/H 4 1 68 MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 2872.5 5570 4221.25 5396 GR 5.6038 128.841 68.7083 5307 RPX 0.5434 38.2836 6.76447 5307 RPS 0.493 54.014 7.24342 5307 RPM 0.3822 58.0562 7.00068 5307 RPD 0.3735 61.8099 7.18819 5307 ROP 6.5109 551.824 194.162 5305 FET 0.1104 8.812 0.576059 5307 First Reading 2872 5 2872 5 2879 5 2879 5 2879 5 2879 5 2918 2879.5 Last Reading 5570 5525.5 5532.5 5532.5 5532.5 5532.5 5570 5532.5 First Reading For Entire File .......... 2872.5 Last Reading For Entire File ........... 5570 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 5570.5 $ 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 5586.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 16-AUG-98 ISC 5.07 DEPII (2.22A) , SP4 (5.04) MEMORY 5587.0 5570.0 5587.0 .0 .0 TOOL NUMBER PCG 11 4.750 4.8 FLO PRO 9.40 52.0 9.5 25000 6.3 .000 .000 .000 .000 23.4 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 5570.5 5586.5 5578.5 33 5570.5 ROP 12.3805 92.988 27.8768 33 5570.5 Last Reading 5586.5 5586.5 First Reading For Entire File .......... 5570.5 Last Reading For Entire File ........... 5586.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5526.0 ROP 5587.0 $ 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 MINIM~,I A/~GLE: MAXIMUM ANGLE: STOP DEPTH 6055.0 6156.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE ~ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 17-AUG-98 ISC 5.07 DEPII(2.22A) , SP4 (5.04) MEMORY 6157.0 5587.0 6157.0 83.1 93.3 TOOL NLTMBER PCG 42 4.750 4.8 FLO PRO 9.30 53.0 9.5 28000 5.5 .000 .000 .000 .000 30.0 .3 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5526 6156.5 5841.25 1262 5526 GR 73.6 176.392 116.712 1059 5526 ROP 10.2472 368.873 129.032 1140 5587 Last Reading 6156.5 6055 6156.5 First Reading For Entire File .......... 5526 Last Reading For Entire File ........... 6156.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6055.5 ROP 6157.0 $ 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 7724.0 7793.5 19-AUG-98 ISC 5.O7 DEPII(2.22A), SP4 (5.04) MEMORY 7793.0 6157.0 7793.0 83.4 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NA~ GAMMA PROBE $ TOOL NUMBER PCG 11 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4.750 4.8 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO PRO 9.20 550.0 9.5 21000 4.8 .000 .000 .000 .000 32.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REFLARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6055.5 7793.5 6924.5 3477 6055.5 GR 72.0895 165.333 103.09 3338 6055.5 ROP 5.3495 871.072 164.312 3274 6157 Last Reading 7793.5 7724 7793.5 First Reading For Entire File .......... 6055.5 Last Reading For Entire File ........... 7793.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/11 Origin ................... STS Scientific Technical Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Scientific Technical Physical EOF Physical EOF End Of LIS File
