The URL can be used to link to this page

Home My WebLink About195-0941. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Reservoir Abandonment Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Completion w/ Screens 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 13,024 feet 4,032 feet true vertical 7,271 feet N/A feet Effective Depth measured 4,032 feet 3,350 & 12,275 feet true vertical 3,560 feet 3,166 & 6,958 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3# / 13 Cr / J-Bear 987' 987' 3-1/2" 9.3# / N-80 / EUE 3,249' 3,093' 4-1/2" 12.6# / JFE Bear 3,816' 3,454' Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / N-80 / MOD 8RD 12,313' 6,974' 7" X 4.4" Prm. Hydro Iso Packers and SSSV (type, measured and true vertical depth)7” x 4.5” Backer S-3 Packer N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: UGNU 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A 3,090psi 5,410psi 5,750psi 7,240psi13,024' 7,271' Burst N/A 4,240'Surface Production 20" 9-5/8" 7" 80' 4,209' MILNE PT UNIT E-23 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-094 50-029-22570-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518 & ADL0028231 MILNE POINT / UGNU measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 3,652' Casing Conductor 12,996' N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 650 4,000 1000 0 00 972 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-422 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WSW WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:15 pm, Sep 21, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.09.19 14:20:42 - 08'00' Taylor Wellman (2143) WCB 4-10-2024 DSR-9/21/23 RBDMS JSB 092623 _____________________________________________________________________________________ Revised By: TDF 9/19/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 TD =13,024’ (MD)/ TD =7,271’(TVD) 20” RKB - GL.: 24.9’/ KB Elev.: 54.1’ (Nabors 4ES) 7” 9-5/8” 15 PBTD =12,932’(MD) / PBTD =7,234’(TVD) HES ES Cementer 14 7” Stage 1 CBL TOC @ ±11,100’ 7”Stage 2 EST TOC @ 4,176’ TBG Punch f/ 12,250’ to 12,255’ TOC @11,017’ SLM 6/22/2023 2 & 3 4 8 6 &7 9 9 12 16 17 13 Tubing Cut @ 10,500’ 6/23/2023 1 5 10 11TOC @ 4,032’ ELM’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1# / H-40 19.124” Surface 113’ 9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 4,240’ 7" Production 26# / L-80 / BTC 6.276” Surface 13,024’ TUBING DETAIL 3-1/2” Tubing 9.3# / 13Cr / J-BEAR 2.992 Surface 987’ 3-1/2" Tubing 9.3# / N-80 / EUE 2.992” 987’ 3,249’ 4-1/2” Screens Assy 12.6# / JFE Bear 3.958” 3,346’ 3,816’ 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” 10,500’ 12,313’ JEWELRY DETAIL No Depth Item 1 3,031’ 3.5” XN-Nipple - Min ID 2.205 NO-GO 2 3,183’ Discharge Head: DSCHG B/O PMP 513 2.87X8 3 3,183.5’ Zenith Ported Sub: HEAD S/A B/O PRESS PORT 513/538 4 3,184’ Pump #1: 538PMSSD 075 FLEX80 H6 FER 5 3,208’ Intake: GPXARCINT FER H6 6 3,209’ Upper Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 7 3,216’ Lower Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 8 3,223’ Motor: 562XP MTR 562XP 450/3135/88/18R_375/2615 FER 9 3,244’ Motor Gauge and Centralizer –Btm @ 3,249’ 10 3,350’ 7" X 4.4" 23 - 32# Permanent Hyd. Isolation Packer 11 3,358 110-micron Ener-Armor Screens – Btm @ 3,804’ 12 3,813’ 4.5” Guide Shoe –Btm @ 3,816’ 13 4,400’ CIIBP 14 12,275 7” x 4.5” Backer S-3 Packer 15 12,302’ HES 3.5” XN Nipple 16 12,313’ 3.5” WLEG 17 12,650’ NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT STATUS Ugnu UG3 3,415’ 3,540’ 3,211’ 3,293’ 125 8/19/2023 3,670’ 3,840’ 3,372’ 3,467’ 170 8/20/2023 Kup C 12,520’ 12,620’ 7,061’ 7,104’ 100 SQZ Kup B7 12,706’ 12,766’ 7,140’ 7,165’ 60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7” 310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES - 9/13/1995 Plug Back, Perf and Install ESP by ASR – 8/22/2023 Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 ASR #1 50-029-22570-00-00 195-094 8/16/2023 8/23/2023 8/18/2023 - Friday RIH w/ E-line CBL to 4,700'. Log up to 2,200' TOC @ 3,885'. POOH. RIH with CIBP. Correlate depth from CBL run. CCL to center element 13.1' CCL stop depth 4386.9. CIBP @ 4,400' WLM. POOH. Rig down E-line. pressure test CIBP to 1,000 psi for 5 min. Good test. Fill pipe rack up with cement string. found holes and bad threads on multiple joints. Mobilize different cement string to location. RIH with 3-1/2" EUE cement string with mule shoe. From surface to 4,389' Tag CIBP w/ 3k dw. P/U to 4,371' for cementing. R/U HES cementing equip. Hold PJSM w/ crew & HES. Pump 15bbls w/ rig filling lines & ensuring cement string clear. HES cementers PT line to 5K (good test) Pump balanced cement pills as follows. 15 bbls water, 12 bbls 15.8 ppg lead cement, 5 bbls water spacer, rig displaced cement w/ 28.5 bbls of 8.4 ppg source water. Returns through out job choked back through choke & closed annular for 1:1 returns. Shut dw pump. Monitor. Well static / plug balanced. POOH w/ cement string slowly F/ 4,371' T/ 3,990'. P/U wt = 31.5K. No drag observed pulling through pill. Pump a surf to surf, ensuring cement string clean. Start circulation w/ foam pipe wipers in pipe. Pump at 3 bpm 230 psi. Pump a total of 165 bbls. Foam wiper not seen at surface. Small amount of contaminated returns observed at bottoms up wt = 8.45 ppg. Circ. till clean. POOH with 3-1/2" EUE cement string with mule shoe. f/ 3,990' T/ 1,600'. 8/16/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Function test BOPE. Complete rig acceptance checklist. Complete torque up of BOPE. Install bird bath. M/U TIW t/ test joint. P/U test joint, fill stack w/ fresh water perform shell test on BOPE equip. 8/17/2023 - Thursday Test BOPs 250 low 2500 high as per approved sundry. AOGCC witness waived by Austin McLeod. No failures. Rig down test equipment. Blow down fluid lines. Pull CTS and BPV. Perform 30 min negative drawdown test. AOGCC witness waived by Austin McLeod. Well Static. P/U M/U landing joint. BOLDS. Pull hanger to floor. Hanger off seat @ 42K. Pull up to 72K and pipe came free. P/U wt 61K. POOH w/ 3-1/2" 9.3# N-80 Cut tubing. F/ 10,500' T/ 7,638' Pump double displacement for trip. P/U wt = 48K. Pump down tubing to flush out diesel to tiger tank. Bring returns to pits after 12 bbls away, fluid returning clean source water 8.45 ppg. Pump a tubing volume for 70 bbls. Shut dw. Monitor well static. Line up for continuous hole fill. POOH w/ 3- 1/2" 9.3# N-80 Cut tubing. F/ 7,638' T/ 3,929' P/U wt = 28K Running continuous hole fill. Rig service, check equip. fluid levels. POOH w/ 3-1/2" 9.3# N-80 Cut tubing. F/ 3,929' T/ surface. L/D the cut joint. Cut JT length = 16.41'. Running continuous hole fill. Remove tubing equipment from floor. R/U Eline. POOH w/ 3- 1/2" 9.3# N-80 Cut tubing. F/ 7,638' T/ 3,929' RIH with CIBP. Correlate depth from CBL run. CCL to center element 13.1' CCL stop depth 4386.9. CIBP @ 4,400' WLM. POOH Tag CIBP w/ 3k dw. P/U to 4,371' for cementing. R/U HES cementing equip. Hold PJSM w/ crew & HES. Pump 15bbls w/ rig filling lines & ensuring cement string clear. HES cementers PT line to 5K (good test) Pump balanced cement pills as follows. 15 bbls water, 12 bbls 15.8 ppg lead cement, 5 bbls water spacer, rig displaced cement w/ 28.5 bbls of 8.4 ppg source water. Returns through out job choked back through choke & closed annular for 1:1 returns. Shut dw pump. Monitor. Well static / plug balanced. POOH w/ cement string slowly F/ 4,371' T/ 3,990'. P/U wt = 31.5K. No drag observed pulling through pill. Pump a surf to surf, ensuring cement string clean POOH w/ 3-1/2" 9.3# N-80 Cut tubing. F/ 3,929' T/ surface. L/D the cut joint RIH w/ E-line CBL to 4,700'. Log up to 2,200' TOC @ 3,885'. POOH Perform 30 min negative drawdown test. AOGCC witness waived by Austin McLeod. Well Static. P/U M/U landing joint. BOLDS. Pull hanger to floor. Hanger off seat @ 42K. Pull up to 72K and pipe came free. P/U wt 61K. POOH w/ 3-1/2" 9.3# N-80 Cut tubing. F/ 10,500' T/ 7,638' Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 ASR #1 50-029-22570-00-00 195-094 8/16/2023 8/23/2023 Hilcorp Alaska, LLC Weekly Operations Summary POOH W/ 3-1/2" EUE cement string F/ 1,600' T/ surface. WOC. Crews clean and organize location and replace service loop wraps. Rig up slickline. Prep to RIH to tag TOC w/ sample bailer. RIH w/ slickline sample bailer. Tag TOC 4,032 SLM. Witnessed by AOGCC Adam Earl. MIT 7" casing and cement 1500 psi charted for 30 min. Witnessed by AOGCC Adam Earl. (good test). RIH with 6.05" drift to 3,750' SLM, POOH. R/D slick line. R/U E-line. Install hanger w/ TWC, for testing PCE. Remove elevators & bails. Install dutch riser in BOPE stack. Install E-line to dutch riser. Test E-line PCE T/ 250 psi low & 2500 psi high for 5/5 charted mins. (good test). M/U E-line guns. CH, CCL-GmA, QC sub, 56'- 3.125" 6 SPF 60 phasing, .42" guns. RIH. Tag CIBP on depth 4,032' Correlate w/ past gamma log. Perf interval 3,840' - 3,748' No pressure change on choke after shots. OA pressure dropped f/ 105 to 75 psi. Monitored well via open hole well static. POOH. L/D Spent guns all shot fired. M/U 2nd gun run. While making up bottom guns set to 2nd threads observed to not M.U all the way. Remove guns from well & inspect threads. Gun thread sub damaged. E-line reps. changed out. Well observed out of balance with OA. Circ 50 bbls of 8.6 ppg brine down 7" returning from OA to tank. Pump at 2.5 bpm w/ 175 psi. Open choke (well static). M/U E-line guns, CH, CCL-GmA, QC sub, 56'- 3.125" 6 SPF 60 phasing, .42" guns. RIH. Tag CIBP on depth 4,032' Correlate w/ past gamma log. Perf interval 3,748' - 3,728' No pressure change on choke after shots. OA pressure dropped f/ 75 to 50 psi. Monitored well via open hole well static. POOH. L/D Spent guns all shot fired. 8/19/2023 - Saturday 8/20/2023 - Sunday M/U E-line guns, CH, CCL-GmA, QC sub, 58'- 3.125" 6 SPF 60 phasing, .42" guns. RIH. Tag CIBP on depth 4,032' Correlate w/ past gamma log. Perf interval 3,728' - 3,670' No pressure change on choke after shots. OA pressure dropped f/ 75 to 50 psi. Monitored well via open hole well static. POOH W/ E-line. Bullhead 50 BBLs 8.6 ppg brine down 7" 3.5 BPM @ 215 psi Shut down pump. Monitor well. Well on slight vac. L/D Guns. Discussion with OE and geologist, decision was made to add more perfs. E-line reps mobilize guns to location. Simops, crews clean and clear location, install service loop wrap. E-line arrive with guns. M/U E-line guns, CH, CCL-GmA, QC sub, 65.5' of 2.875" 6 SPF 60 phasing, .34" hole guns. RIH. Correlate w/ past gamma log. Perf interval 3,540' - 3,474.5' No pressure change on choke after shots. OA pressure dropped f/ 75 to 50 psi. Monitored well via open hole well static. POOH. E-line arrive with guns. M/U E-line guns, CH, CCL-GmA, QC sub, 59.5' of 2.875" 6 SPF 60 phasing, .34" hole guns. RIH. Correlate w/ past gamma log. Perf interval 3,474.5' - 3,415' No pressure change on choke after shots. OA pressure dropped f/ 50 to 40 psi. Monitored well via open hole well static. POOH. R/D E-line & PCE. Reattach bails, elevators. P/U landing joint. BOLDS. Pull test hanger & L/D. Service rig, check equip. P/U PKR & bumper sub torque to spec & stage on catwalk. Spot crane, R/D power tongs. Fly tongs & tong rack off floor. R/U GBR tongs & equip. Work reduced to minimal risk operations due to in field code 99 blue. Rack & tally Screen completion. P/U & M/U 4.5" 100 micron screen completion. Guide shoe / closed bullnose, 1 x 100 micron screens. No pressure change on choke after shots. OA pressure dropped f/ 105 to 75 psi. Monitored well via open hole well static. POOH. L/D Spent guns all shot fired. Perf interval 3,728' - 3,670' Perf interval 3,474.5' - 3,415' Perf interval 3,748' - 3,728 Witnessed by AOGCC Adam Earl M/U E-line guns. CH, CCL-GmA, QC sub, 56'- 3.125" 6 SPF 60 phasing, .42" guns. RIH. Tag CIBP on depth 4,032' Correlate w/ past gamma log. Perf interval 3,840' - 3,748' RIH w/ slickline sample bailer. Tag TOC 4,032 SLM Perf interval 3,540' - 3,474.5' Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 ASR #1 50-029-22570-00-00 195-094 8/16/2023 8/23/2023 Hilcorp Alaska, LLC Weekly Operations Summary Mechanic replaced NOX sensor on rig engine. RIH W/ 3-1/2" EUE and ESP completion F/ 74' T/ 2,261' checking cable and cap line every 1,000'. Swap over handling equipment for torque turn. RIH W / 3-1/2" 13 CR JFE Bear and ESP . Torque turn JFE Bear joints. T/ 3,348.5' ORKB adjusted. P/U M/U hanger. Splice ESP & chem. injection line to Hanger. Land hanger. Obtain final wts. P/U wt = 35K S/O wt = 28K. Land tubing hang w/ BPV installed. ESP electrical umbilical attached while landing, observed no drag, ESP tested good after landing. RILDS. B/O landing JT. R/D ESP sheave. Remove all well equip. from rig floor. Remove well fluid from pits. N/D flow & riser spool. Remove fluid from BOP stack. Bleed down accumulator & disconnect lines. RDMO E-23. Cont. to R/D, remove flow spools from floor. L/D derrick on head ache rack. Raise jacks prep rig to be move, Spot in crane. Remove floor & cellar. Mobilize rig to A-pad. Load out equipment on trucks & stage on E-pad. Remove pit landing, Hook truck to pits. Prep to Move off. P/U M/U 100 micron JFE Bear screens. Swap over handling equipment for packer and bumper sub. RIH with 3-1/2" workstring and screens F/ 471' to 3,815' to bottom of screens.W/ 457' of screens set top of packer @ 3,350'. P/U wt 36 K S/O wt 29 K. Drop ball. Swivel up. pressure up down DP to 4000 psi and hold for 30 min to set packer. P/U 15 K over. Pressure up on Backside to 1,500 psi for 10 min. to ensure packer set. Bleed off pressure. P/U to 36K and put 12 turns to the right. Release off packer. P/U out of PBR. POOH from 3,550' to surface with 3-1/2" workstring and packer running tool. L/D bumper sub & PKR running tool. Change out handling equip. for ESP completion. Prep to run ESP. hang ESP sheaves with cables run, tie off on floor. Stage ESP assy. on catwalk. Rack & tally pipe. P/U & M/U ESP. P/U & service motor, P/U seals & service. Tie in chem. cap line. Chem line valve opens at 3,300 psi. Bled off and hold 500 psi on cap line. Cont. P/U ESP assy. M/U intake, Pump, Ported sub, & DS head. RIH Secure all cables with clamps. Test ESP assy. RIH W/ ESP completion as per detail. F/ 75' T/ 106' Pump displacement for pipe tripped in. 8/22/2023 - Tuesday 8/21/2023 - Monday RIH W/ ESP completion as per detail Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 ASR #1 50-029-22570-00-00 195-094 8/16/2023 8/23/2023 No operations to report. No operations to report. 8/26/2023 - Saturday No operations to report. 8/29/2023 - Tuesday 8/27/2023 - Sunday No operations to report. 8/28/2023 - Monday 8/25/2023 - Friday No operations to report. 8/23/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD; M/U Hanger to string terminated 3/8 CCL into hanger S/B for penatrator splice. Landed hanger to RKB of 16.62 RILDS pulled landing joint set 3" BPV RDMO. N/U tree/adapter test void to 500 low 5000 high 5/15 min test good. Pulled BPV and secured well. 8/24/2023 - Thursday No operations to report. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230912 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 18RD 50133205840100 222033 9/6/2023 YELLOW JACKET GPT-PERF BCU 18RD 50133205840100 222033 8/24/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 8/28/2023 YELLOW JACKET PLUG-PERF BCU 18RD 50133205840100 222033 9/9/2023 YELLOW JACKET PLU-GPT-PERF BCU 18RD 50133205840100 222033 9/4/2023 YELLOW JACKET SCBL BRU 211-35 50283201890000 223050 7/31/2023 AK E-LINE CBL BRU 211-35 50283201890000 223050 8/19/2023 AK E-LINE GPT/Plug/Perf BRU 211-35 50283201890000 223050 8/10/2023 AK E-LINE Perf BRU 212-26 50283201820000 220058 8/20/2023 AK E-LINE GPT IRU 11-06 50283201300000 208184 8/1/2023 AK E-LINE Perf IRU 41-01 50283200880000 192109 9/3/2023 AK E-LINE GPT/Perf KTU 43-6XRD2 50133203280200 205117 9/4/2023 YELLOW JACKET CALIPER KU 42-12 50133206890000 220045 8/31/2023 YELLOW JACKET GPT-PERF KU 42-12 50133206890000 220045 8/20/2023 YELLOW JACKET SCBL MPU E-23 50029225700000 195094 8/18/2023 YELLOW JACKET CBL-PLUG MPU E-23 50029225700000 195094 8/20/2023 YELLOW JACKET PERF Paxton 12 50133207100000 223014 8/20/2023 AK E-LINE GPT/Perf Paxton 12 50133207100000 223014 8/14/2023 AK E-LINE Patch/Perf PBU L-240 50029237030000 221086 8/30/2023 READ IPROF Please include current contact information if different from above. T37983 T37983 T37983 T37983 T37983 T37984 T37984 T37984 T37985 T37986 T37987 T37988 T37989 T37989 T37990 T37990 T37991 T37991 T37992 9/13/2023 YELLOW MPU E-23 50029225700000 195094 8/18/2023 JACKET CBL-PLUG YELLOW MPU E-23 50029225700000 195094 8/20/2023 JACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.13 10:28:30 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:25 Township:13N Range:10E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:13040 ft MD Lease No.:ADL 025518 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 4240 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 13024 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 12313 Feet Tbg Cut@ 10300 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 4400 ft 4032 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1641 1590 1565 IA 175 150 150 OA na na na Remarks: Attachments: Aaron Haberthur Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to MPU E-23 to witness a tag and pressure test on a cement plug for converting the well to a Water Source producer. Tag top of cement @ 4032 ft MD. The slickline tool string consisted of 8 feet of 1 7/8-inch weight bar, 1 3/4-inch jars, spanges, and a 5-foot sample bailer for a total hanging weight of 175 lb. Sample came back with interface up top and decent cement on bottom. Pressure test went as per chart above. Note regarding Test Data: tubing had been pulled so 7-inch is tubing and 9 5/8- inch is IA. August 19, 2023 Adam Earl Well Bore Plug & Abandonment Milne Point Unit E-23 Hilcorp Alaska LLC PTD 1950940; Sundry 323-422 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0819_Plug_Verification_MPU_E-23_ae              Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Reservoir Abandonment Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Completion w/ Screens 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,040'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3.5" 3.5" 9.3# / L-80 / 8rd MOD 10,500' Baker S-3 Pacher and N/A 80' 20" 9-5/8" 7" 4,209' 12,996' 12,275 MD/ 6,958 TVD and N/A MD N/A 5,750psi 7,240psi 3,652' 7,271' 4,240' 13,024' Length Size Proposed Pools: 112' 112' 9.3# / L-80 / 8rd MOD TVD Burst 12,313' MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 & ADL0028231 195-094 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22570-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 8/10/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT E-23 KUPARUK RIVER OIL UGNU 7,278' 12,640' 7,112' 1,364 11,017' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:01 am, Jul 26, 2023 323-422 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.24 15:45:14 - 08'00' Taylor Wellman (2143) 1,364 UGNU Ugnu Undefined WTRSP, statewide rules apply *BOPE test to 2500 psi. * CBL to AOGCC upon completion. email: melvin.rixse@alaska.gov * 30 minute drawdown test. AOGCC for opportunity to witness. * Slickline tag and pressure test of surface casing shoe cement plugs. 10-404 DSR-7/26/23MDG 7/28/2023 Perforate New Pool MGR27JULY23GCW 07/28/2023JLC 7/28/2023 07/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.28 16:33:14 -06'00' RWO Well: MPU E-23 Date: 24 July 2023 Well Name: MPU E-23 API Number: 50-029-22570-00-00 Current Status: SI Inj Pad: E-Pad Estimated Start Date: August 10, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-094 First Call Engineer: Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1764 psi @ 4000’ TVD SITP: Reservoir Abandoned | 8.4 PPGE MPSP: 1364 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 69° @ 10,379’ MD Max Dogleg: 7.2°/100ft @ 6,000’ MD Brief Well Summary: MPE-23i is a WAG injector drilled and completed in September 1995 to support E-09, E-11 and E-22 in the B & C sands. In April 2021 the well began to pressure up in the IA while on gas injection. An AA was established in May 2021 stating that the well can continue injection on water only. to An IPROF ran in August 2020 demonstrated that all injection is going into the B7 perforations. A TTBP with a cement cap was placed in November 2023 in order to isolate the Kuparuk B7 sand. During a recent workover to change the ESP out on the MPE-15 water source well, subsidence buckling was encountered in the 7” casing at 300”. The well construction makes fixing this casing very difficult and we are choosing to convert MPE-23 into a new water source well. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 3000 psi on 6/22/2023. x Kuparuk is abandoned, slickline tagged top of cement at 11,017’. x Tubing is cut at 10,300’. Objective: Perform reservoir abandonment on the Kuparuk formation, perforate Ugnu M sands, run new lower screen completion, run ESP and convert well to water production. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 4. NU BOPE house. Spot mud boat. Brief RWO Procedure: Pull Tubing 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. . The well construction makes fixing this casing very difficult and we are choosing to convert MPE-23 into a new water source well. RWO Well: MPU E-23 Date: 24 July 2023 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with source water prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. Lubricate if pressure is expected. 5. Perform 30 minute negative drawdown test. a. Give AOGCC 24 hour notice to witness. 6. MU landing joint or spear and PU on the tubing hanger. 7. Recover the tubing hanger. 8. POOH and lay down the 3-1/2” tubing. Wash and trash all joints. Cement Surface Casing Shoe 1. MIRU eline unit with pack off. 2. MU and RIH with CBL tool. 3. Establish free pipe measurement. 4. Run CBL from 4700’ to TOC. 5. RIH and set CIBP at 4400’. 6. If CBL does not show cement behind 7” up to 4100’, RIH and punch into 7” 26# xX 9-5/8” 40# annulus directly above CIBP (or at highest depth of cement logged.) 7. RDMO eline. 8. If holes were punched establish circulation down 7” taking returns from the IA. 9. MIRU cementers and PT lines to 250 psi low / 4000 psi high. 10. RIH with cementing BHA on workstring and tag CIBP. 11. Lay in (and circulate if holes were punched) a cement plug from ~4400’ to 4100’. a. Confirm cement volumes with OE prior to pumping. 12. WOC to get to 1000 psi compressive strength. 13. MIRU slickline with line wiper and tag TOC with sample bailer. a. Give AOGCC 24 notice to witness. 14. Drift to 3700’ for 7” packer. 15. RDMO slickline. 16. Perform CMIT-TxIA to 1500 psi charted for 10 minutes. a. Give AOGCC 24 notice to witness. Perforate & Clean Out 1. MIRU eline. RWO Well: MPU E-23 Date: 24 July 2023 2. Flange up 7” shooting flange with 7” quick test sub to BOPs. 3. Install TWC in hanger profile. 4. Rig up eline lubricator and pressure test to 250 psi low / 2500 psi high. 5. Break open quick test sub and pull TWC. 6. Arm and RIH with 170’ of 3-1/8” perforating guns. 7. Make up lubricator to quick test sub and test connection. 8. RIH and perforating the following interval: a. 3670’-3840’ b. Correlate to Final LWD log dated 06-12 July 1995. c. Maintain hole fill during perforating operations as we will be establishing communication with the reservoir. 9. POOH and confirm well is dead. Bullhead source water as needed. 10. RDMO eline. Run Lower Screen Completion 1. Pick up and RIH with completion: a. 8 joints of 4-1/2” 110 micron Ener-Armor screens b. 7” x 4.5” mechanical set packer with a set depth of 3600’ 2. Set packer per vendor recommendations. 3. Release from packer and POOH. Run New ESP 1. Ensure that handling equipment is on-hand for running 3-1/2” 13Cr completion. 2. MU Spooler to run cable and capillary tubing. 3. PU new ESP with single cap string and RIH on 3-1/2” tubing, making electrical checks on the cable and pressure tests on the cap string every 2,000 feet a. Set base of ESP assembly at ~5050’. b. 1 joint of 3-1/2” Tubing c. 3-1/2” XN (2.750” No-Go) d. ~3400’ of 3-1/2” L-80 tubing e. 3-1/2” EUE x 3-1/2” J-BEAR crossover f. ~1000’ of 3-1/2” 13Cr tubing 4. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. 5. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. RWO Well: MPU E-23 Date: 24 July 2023 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. CTU BOPE Schematic 4. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 7/19/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 TD= 13,024’ (MD) / TD =7,271’(TVD) 20” RKB - GL.: 24.9’/ KB Elev.: 54.1’ (Nabors 4ES) 7” 9-5/8” 2 PBTD =12,932’(MD) / PBTD =7,234’(TVD) HES ES Cementer 1 7” Stage 1 CBL TOC @ ±11,100’ 7”Stage 2 EST TOC @ 4,176’ TBG Punch f/ 12,250’ to 12,255’ TOC @11,017’ SLM 6/22/2023 3 4 Tubing Cut @ 10,500’ 6/23/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1# / H-40 19.124” Surface 113’ 9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 4,240’ 7" Production 26# / L-80 / BTC 6.276” Surface 13,024’ TUBING DETAIL 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” Surface 10,500’ 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” 10,500’ 12,313’ JEWELRY DETAIL No Depth Item 1 12,275 7” x 4.5” Backer S-3 Packer 2 12,302’ HES 3.5” XN Nipple 3 12,313’ 3.5” WLEG 4 12,650’ NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT STATUS Kup C 12,520’ 12,620’ 7,061’ 7,104’ 100 SQZ Kup B7 12,706’ 12,766’ 7,140’ 7,165’ 60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7” 310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 _____________________________________________________________________________________ Revised By: TDF 7/24/2023 PROPOSED Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 TD =13,024’ (MD)/ TD =7,271’(TVD) 20” RKB - GL.: 24.9’/ KB Elev.: 54.1’ (Nabors 4ES) 7” 9-5/8” 13 PBTD =12,932’(MD) / PBTD =7,234’(TVD) HES ES Cementer 12 7” Stage 1 CBL TOC @ ±11,100’ 7”Stage 2 EST TOC @ 4,176’ TBG Punch f/ 12,250’ to 12,255’ TOC @11,017’ SLM 6/22/2023 2 3 4 5 &6 7 8 9 10 14 15 11 Tubing Cut @ 10,500’ 6/23/2023 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1# / H-40 19.124” Surface 113’ 9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 4,240’ 7" Production 26# / L-80 / BTC 6.276” Surface 13,024’ TUBING DETAIL 3-1/2” Tubing 9.3# / 13Cr / J-BEAR 2.992 Surface ~1,000’ 3-1/2" Tubing 9.3# / N-80 / EUE 2.992” ~1,000’ ~3,200’ 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” 10,500’ 12,313’ JEWELRY DETAIL No Depth Item 1 ~3,000 3.5” X Nipple 2 ~3,200 Discharge Head 3 ~3,220 Pump 4 ~3,280 Gas Seperator 5 ~3,290 Tandem Seals 6 ~3,300 Motor 7 ~3,320’ Sensor 8 ~3,330’ Centralizer 9 ~3,600’ 7” x 4-1/2” Packer 10 ~3,700 400’ 110-micron Ener-Armor Screens 11 ~4,400’ CIIBP 12 12,275 7” x 4.5” Backer S-3 Packer 13 12,302’ HES 3.5” XN Nipple 14 12,313’ 3.5” WLEG 15 12,650’ NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT STATUS Ugnu UG3 ~3,670’ ~3,840’ ~3,320’ ~3,420’ ~170 Future Kup C 12,520’ 12,620’ 7,061’ 7,104’ 100 SQZ Kup B7 12,706’ 12,766’ 7,140’ 7,165’ 60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7” 310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 SLB Stack Drawing Not Drawn To Scale--- For Reference Only BOP rams dressed for 1.75" Coiled Tubing. Blind/Shear ram blades: Texas Oil Tools NOV – 4.06" Shear seal Rams w/ Viton Seals, H2S -50F Flanged Plug Valve (Manual) Flanged Plug Valve (Manual) Kill Port Manual ram locking wheel CT BOP’s controlled by Coiled Tubing Unit with ~100 gal accumulator system Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Top Door Stripper – 1.75" Swab Valve 4.06" 10K Quad BOP C/W 2.06" 10K Flanged Plug Valves x 2" 1502 SSV 5K x 10K C062/CB44 Crossover Master Valve 7.06" 5K /4.06"10K Lubricator Section (Manual)(Manual) Slip & Pipe Ram dressed with 1.75" Inserts IA and OA Gate Valves Blind & Shear Ram Slip Ram Kill Port Blind & Shear Ram Pipe Ram Pump In Sub with 2 Flanged Gate Valves 2' 10K to 5K Crossover Provided by client Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Milne Point Injector MP E-23 PTD, 195-094 : Request for Administrative Approval to AIO 10B: Water Injection Operations Only Date:Wednesday, July 26, 2023 8:56:38 AM From: Wallace, Chris D (CED) Sent: Wednesday, May 19, 2021 11:49 AM To: Tom Fouts <tfouts@hilcorp.com> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: Milne Point Injector MP E-23 PTD, 195-094 : Request for Administrative Approval to AIO 10B: Water Injection Operations Only Tom, You are approved to continue water only injection while we finalize the administrative approval request. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Tom Fouts <tfouts@hilcorp.com> Sent: Wednesday, May 19, 2021 11:04 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: Milne Point Injector MP E-23 PTD, 195-094 : Request for Administrative Approval to AIO 10B: Water Injection Operations Only Chris, I submitted an Administrative Approval request on 5/14/2021 to continue water only injection operations for MP E-23. On 4/20/2021 you had approved a 28 day diagnostic and monitoring the well which ends today. I would like to know if we have authorization to continue with water injection at this time. Thanks, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205054 7/6/2023 YELLOW JACKET CBL KBU 22-06 50133205500000 205054 7/2/2023 YELLOW JACKET CBL/PERF KBU 33-06X 50133205290000 203183 6/14/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/29/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/13/2023 YELLOW JACKET PERF KU 12-17 50133205770000 208089 6/14/2023 YELLOW JACKET PERF MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey MPU E-23 50029225700000 195094 6/23/2023 YELLOW JACKET CUT MPU L-43 50029231900000 203224 6/27/2023 YELLOW JACKET PERF PAXTON 12 50133207100000 223014 6/28/2023 YELLOW JACKET PERF Please include current contact information if different from above. T37830 T37830 T37831 T37831 T37831 T37832 T37833 T37834 T37835 T37836 T37837 YELLOWMPU E-23 50029225700000 195094 6/23/2023 CUTJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.11 14:54:56 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:25 Township:13N Range:10E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:13040 ft MD Lease No.:ADL025518 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 4240 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 13024 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 12313 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 12265 ft 11017 ft 6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2680 2618 2587 IA 2690 2629 2598 OA 372 300 299 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Reservoir abandonment plug to convert MPU E-23 to water source well. Due to communication IA to tubing they did a combo MIT TxIA instead of separate MIT-T and MIT-IA. Cement sample was good from tag run. 3.6 bbls in and out for test. June 23, 2023 Kam StJohn Well Bore Plug & Abandonment MPU E-23 Hilcorp PTD 1950940; Sundry 323-345 none Test Data: P Casing Removal: rev. 11-28-18 2023-0623_Plug_Verification_MPU_E-23_ksj            1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Tubing Cut Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ 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 13,040 feet 11,017 feet true vertical 7,278 feet N/A feet Effective Depth measured 12,640 feet 12,275 feet true vertical 7,112 feet 6,958 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3.5" 9.3# / L-80 / 8rd MOD 10,500' 6,240' Tubing (size, grade, measured and true vertical depth)3.5" 9.3# / L-80 / 8rd MOD 12,313' 6,974' Packers and SSSV (type, measured and true vertical depth)7" x 4.5" Baker S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A 3,090psi 5,410psi 5,750psi 7,240psi13,024' 7,271' Burst N/A 4,240'Surface Production 20" 9-5/8" 7" 80' 4,209' MILNE PT UNIT E-23 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-094 50-029-22570-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518 & ADL0028231 MILNE POINT / KUPARUK RIVER OIL measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 3,652' Casing Conductor 12,996' N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 0 000 0 00 0 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-279 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:45 am, Jul 25, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.21 12:55:46 - 08'00' Taylor Wellman (2143) RBDMS JSB 072523 DSR-7/26/23WCB 3-8-2024 _____________________________________________________________________________________ Revised By: TDF 7/19/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 TD= 13,024’ (MD) / TD =7,271’(TVD) 20” RKB - GL.: 24.9’/ KB Elev.: 54.1’ (Nabors 4ES) 7” 9-5/8” 2 PBTD =12,932’(MD) / PBTD =7,234’(TVD) HES ES Cementer 1 7” Stage 1 CBL TOC @ ±11,100’ 7”Stage 2 EST TOC @ 4,176’ TBG Punch f/ 12,250’ to 12,255’ TOC @11,017’ SLM 6/22/2023 3 4 Tubing Cut @ 10,500’ 6/23/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1# / H-40 19.124” Surface 113’ 9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 4,240’ 7" Production 26# / L-80 / BTC 6.276” Surface 13,024’ TUBING DETAIL 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” Surface 10,500’ 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” 10,500’ 12,313’ JEWELRY DETAIL No Depth Item 1 12,275 7” x 4.5” Backer S-3 Packer 2 12,302’ HES 3.5” XN Nipple 3 12,313’ 3.5” WLEG 4 12,650’ NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT STATUS Kup C 12,520’ 12,620’ 7,061’ 7,104’ 100 SQZ Kup B7 12,706’ 12,766’ 7,140’ 7,165’ 60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7” 310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 CTU #9 50-029-22570-00-00 195-094 6/16/2023 6/23/2023 6/16/2023 - Friday Standby on Wells Support to RU location. Change Packoffs, Inspect injector / chains. MIRU. (3 hrs NPT). Function Test BOP. 6/14/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/15/2023 - Thursday No operations to report. No operations to report. Continue rigging the unit up. MU YJ milling assembly and 2.85" junk mill. Mill down to XN Nipple @ 12302' CTMD. Complete Injectivity Test. POOH. MU HES Memory Gamma/CCL logging tool and 2.25" JSN. RIH and tag cement/NEO plug 12,648' ctmd. Log up from 12,632' at 50 fpm. 12,200' flag coil. Log up to 12,000'. POOH. 6/17/2023 - Saturday Pump 19 bbls of 15.8 ppg Class G cement below the cement retainer. Untisting PUH to 10,750. Circ 66 bbls diesel followed by 219 bbls kcl down the coil up the IA. Pump 45 bbls 15.8 ppg class G cement down the coil and up the IA. Leaving estimated cement top 11,000' in the IA and tubing. Had diesel returns from the IA at the end of puming cement in place. IA freeze protected ~2500' with diesel. POOH. RDMO 6/20/2023 - Tuesday 6/18/2023 - Sunday Finish POOH w/ HES memory Gamma/CCL. Good data, -17' correction. MU HES 1.56" x 5' 0 degree phase tubing punch. RIH. Correlate to bottom shot. Punch 12250-12255. POOH. Complete 7-Day BOPE Test. Install BOP Back on Tree Stack. 6/19/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 CTU #9 50-029-22570-00-00 195-094 6/16/2023 6/23/2023 No operations to report. No operations to report. 6/24/2023 - Saturday No operations to report. 6/27/2023 - Tuesday 6/25/2023 - Sunday No operations to report. 6/26/2023 - Monday 6/23/2023 - Friday RIG YJOS WIRELINE. PT PCE 300 PSI LOW / 3000 PSI HIGH. RIH#1 W/ 1 11/16" WB, GR, JET CUTTER, 2.5" OD. CUT 3.5'' TBG AT 10500' MD, CCL TO CUTTER 7.3', CCL STOP DEPTH 10492.7'. 500 PSI ON WELL UPON CUT WENT TO 0 PSI. GOOD CUT INDICATION. RIH# 2 W/CHD,1 11/16"WB, GR-CCL TOOL. LOG GR FROM 5500' TO SURFACE GAMMA RAY LOG CORRELATED TO SLB CDR DATED 12-JULY-1995. COMPLETE LOG RIGDOWN . 6/21/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RAN 2.80" CENT BARBELL, 1-3/4" SAMPLE BAILER TO 10,765' SLM (target depth 11,000' slm) NO RECOVERY. TAG TOP OF CEMENT W/ 5' x 2.50" DRIVE DOWN BAILER AT 10,995' SLM (Recovered petri dish of cement). T/I/O= 10/0/300 MIT-T & MIT- IA (Post Cement) Pressured up IA to 500 psi with .8 bbls diesel. MIT-TBG PASSED @ 2527 psi. Pressured up TBG to 2645 psi with .8 bbls diesel. 1st 15 min TBG lost 91 psi. 2nd 15 min TBG lost 27 psi for a total loss of 118 psi in 30 min. Bled TBG to 500 psi. MIT-IA Inconclusive. Pressured up IA to 2703 psi. TBG slowly tracked. TBG gained 324 psi and IA lost 121 psi in 5 min. CMIT- TxIA PASSED to 2624/2634 psi. Pressure up T/IA to 2709/2718 psi with .35 bbls. 1st 15 min T/IA lost 31/30 psi. 2nd 15 min T/IAIA lost 20 psi. 3rd 15 min T/IA lost 19/19 psi. 4th 15 min T/IA lost 15/15 psi for a total loss of 85/84 psi in 60 min. Bled TBG and IA to 0 psi and recovered 3 bbls Final Whps=0/0/235. 6/22/2023 - Thursday T/I/O=115/126/300 AOGCC CMIT-TxIA PASSED @ 2587/2598 psi. (Witnessed by Kam StJohn) Pressured up TBG/IA to 2680/2690 psi with 3.6 bbls diesel. 1st 15 min T/IA lost 62/61 psi. 2nd 15 min T/IA lost 31/31 psi for a total loss of 93/92 ps i in 30 min. Bled T/IA and recovered 3.6 bbls. MIT-OA to 1500 psi Failed. Unable to reach test pressure. LLR of .7 bpm@ 1006 psi. Final Whps= 205/146/300. STATE WITNESSED TAG OF CEMENT AT 11,017' SLM W/ 5' x 2.50" DRIVE DOWN BAILER (Recovered 1 cup of cement). LRS PERFORMED STATE WITNESSED CMIT TxIA TO 2500psi (Passed). LRS PERFORMED FAILING MIT-OA. LLR @ .70bpm AT 1000psi. LRS PERFORMED STATE WITNESSED CMIT TxIA TO 2500psi (Passed). STATE WITNESSED TAG OF CEMENT AT 11,017' SLM W/ 5' x 2.50" DRIVE DOWN BAILER (Recovered 1 cup of cement). TAG TOP OF CEMENT W/ 5' x 2.50" DRIVE DOWN BAILER AT 10,995' SLM 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Tubing Cut Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ 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 13,040 feet 11,017 feet true vertical 7,278 feet N/A feet Effective Depth measured 12,640 feet 12,275 feet true vertical 7,112 feet 6,958 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3.5" 9.3# / L-80 / 8rd MOD 10,500' 6,240' Tubing (size, grade, measured and true vertical depth)3.5" 9.3# / L-80 / 8rd MOD 12,313' 6,974' Packers and SSSV (type, measured and true vertical depth)7" x 4.5" Baker S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A 3,090psi 5,410psi 5,750psi 7,240psi13,024' 7,271' Burst N/A 4,240'Surface Production 20" 9-5/8" 7" 80' 4,209' MILNE PT UNIT E-23 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-094 50-029-22570-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518 & ADL0028231 MILNE POINT / KUPARUK RIVER OIL measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 3,652' Casing Conductor 12,996' N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 0 000 0 00 0 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-345 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.21 12:55:11 - 08'00' Taylor Wellman (2143) By Grace Christianson at 9:39 am, Jul 25, 2023 DSR-7/26/23 RBDMS JSB 072523 WCB 3-8-2024 _____________________________________________________________________________________ Revised By: TDF 7/19/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 TD= 13,024’ (MD) / TD =7,271’(TVD) 20” RKB - GL.: 24.9’/ KB Elev.: 54.1’ (Nabors 4ES) 7” 9-5/8” 2 PBTD =12,932’(MD) / PBTD =7,234’(TVD) HES ES Cementer 1 7” Stage 1 CBL TOC @ ±11,100’ 7”Stage 2 EST TOC @ 4,176’ TBG Punch f/ 12,250’ to 12,255’ TOC @11,017’ SLM 6/22/2023 3 4 Tubing Cut @ 10,500’ 6/23/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1# / H-40 19.124” Surface 113’ 9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 4,240’ 7" Production 26# / L-80 / BTC 6.276” Surface 13,024’ TUBING DETAIL 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” Surface 10,500’ 3-1/2” Tubing 9.3# / N-80 / MOD 8RD 2.992” 10,500’ 12,313’ JEWELRY DETAIL No Depth Item 1 12,275 7” x 4.5” Backer S-3 Packer 2 12,302’ HES 3.5” XN Nipple 3 12,313’ 3.5” WLEG 4 12,650’ NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT STATUS Kup C 12,520’ 12,620’ 7,061’ 7,104’ 100 SQZ Kup B7 12,706’ 12,766’ 7,140’ 7,165’ 60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7” 310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 CTU #9 50-029-22570-00-00 195-094 6/16/2023 6/23/2023 6/16/2023 - Friday Standby on Wells Support to RU location. Change Packoffs, Inspect injector / chains. MIRU. (3 hrs NPT). Function Test BOP. 6/14/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/15/2023 - Thursday No operations to report. No operations to report. Continue rigging the unit up. MU YJ milling assembly and 2.85" junk mill. Mill down to XN Nipple @ 12302' CTMD. Complete Injectivity Test. POOH. MU HES Memory Gamma/CCL logging tool and 2.25" JSN. RIH and tag cement/NEO plug 12,648' ctmd. Log up from 12,632' at 50 fpm. 12,200' flag coil. Log up to 12,000'. POOH. 6/17/2023 - Saturday Pump 19 bbls of 15.8 ppg Class G cement below the cement retainer. Untisting PUH to 10,750. Circ 66 bbls diesel followed by 219 bbls kcl down the coil up the IA. Pump 45 bbls 15.8 ppg class G cement down the coil and up the IA. Leaving estimated cement top 11,000' in the IA and tubing. Had diesel returns from the IA at the end of puming cement in place. IA freeze protected ~2500' with diesel. POOH. RDMO 6/20/2023 - Tuesday 6/18/2023 - Sunday Finish POOH w/ HES memory Gamma/CCL. Good data, -17' correction. MU HES 1.56" x 5' 0 degree phase tubing punch. RIH. Correlate to bottom shot. Punch 12250-12255. POOH. Complete 7-Day BOPE Test. Install BOP Back on Tree Stack. 6/19/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP E-23 CTU #9 50-029-22570-00-00 195-094 6/16/2023 6/23/2023 No operations to report. No operations to report. 6/24/2023 - Saturday No operations to report. 6/27/2023 - Tuesday 6/25/2023 - Sunday No operations to report. 6/26/2023 - Monday 6/23/2023 - Friday RIG YJOS WIRELINE. PT PCE 300 PSI LOW / 3000 PSI HIGH. RIH#1 W/ 1 11/16" WB, GR, JET CUTTER, 2.5" OD. CUT 3.5'' TBG AT 10500' MD, CCL TO CUTTER 7.3', CCL STOP DEPTH 10492.7'. 500 PSI ON WELL UPON CUT WENT TO 0 PSI. GOOD CUT INDICATION. RIH# 2 W/CHD,1 11/16"WB, GR-CCL TOOL. LOG GR FROM 5500' TO SURFACE GAMMA RAY LOG CORRELATED TO SLB CDR DATED 12-JULY-1995. COMPLETE LOG RIGDOWN . 6/21/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RAN 2.80" CENT BARBELL, 1-3/4" SAMPLE BAILER TO 10,765' SLM (target depth 11,000' slm) NO RECOVERY. TAG TOP OF CEMENT W/ 5' x 2.50" DRIVE DOWN BAILER AT 10,995' SLM (Recovered petri dish of cement). T/I/O= 10/0/300 MIT-T & MIT- IA (Post Cement) Pressured up IA to 500 psi with .8 bbls diesel. MIT-TBG PASSED @ 2527 psi. Pressured up TBG to 2645 psi with .8 bbls diesel. 1st 15 min TBG lost 91 psi. 2nd 15 min TBG lost 27 psi for a total loss of 118 psi in 30 min. Bled TBG to 500 psi. MIT-IA Inconclusive. Pressured up IA to 2703 psi. TBG slowly tracked. TBG gained 324 psi and IA lost 121 psi in 5 min. CMIT- TxIA PASSED to 2624/2634 psi. Pressure up T/IA to 2709/2718 psi with .35 bbls. 1st 15 min T/IA lost 31/30 psi. 2nd 15 min T/IAIA lost 20 psi. 3rd 15 min T/IA lost 19/19 psi. 4th 15 min T/IA lost 15/15 psi for a total loss of 85/84 psi in 60 min. Bled TBG and IA to 0 psi and recovered 3 bbls Final Whps=0/0/235. 6/22/2023 - Thursday T/I/O=115/126/300 AOGCC CMIT-TxIA PASSED @ 2587/2598 psi. (Witnessed by Kam StJohn) Pressured up TBG/IA to 2680/2690 psi with 3.6 bbls diesel. 1st 15 min T/IA lost 62/61 psi. 2nd 15 min T/IA lost 31/31 psi for a total loss of 93/92 ps i in 30 min. Bled T/IA and recovered 3.6 bbls. MIT-OA to 1500 psi Failed. Unable to reach test pressure. LLR of .7 bpm@ 1006 psi. Final Whps= 205/146/300. STATE WITNESSED TAG OF CEMENT AT 11,017' SLM W/ 5' x 2.50" DRIVE DOWN BAILER (Recovered 1 cup of cement). LRS PERFORMED STATE WITNESSED CMIT TxIA TO 2500psi (Passed). LRS PERFORMED FAILING MIT-OA. LLR @ .70bpm AT 1000psi. RWO Well: MPU E-23 Date: 13 Jun 2023 7. Paint flag at 12,200’ and POOH. 8. RIH with BHA including ball-drop firing head and punch tubing at 12,255’. 9. While POOH open IA and swap well to source water. 10. RIH with FH one-trip cement retainer and set above packer 12,265’. 11. With IA shut in pressure up down CT x TBG backside to 1000 psi to confirm retainer is set. 12. MIRU cementers and IA returns tanks. 13. Pressure test lines to 250 psi low / 4000 psi high. 14. With IA shut in Pump the following schedule at max rate, do not exceed 5000 psi treating pressure. a. 5 bbl methanol b. 5 bbl source water spacer c. 20 bbls 15.8 ppg class G cement d. CT volume + 1 bbl source water displacement 15. Unsting from retainer and pull up to WCTOC @ ~10,750’. 16. Open IA and confirm 1:1 returns. a. Retainer acts as TWC once unstung. 17. Pump the following schedule taking returns to tanks while reciprocating pipe. a. 66 bbls IA diesel freeze protect b. CT volume source water spacer c. 45 bbls Class G cement d. CT volume + 2 bbl source water displacement 18. Begin to POOH and Shut in IA. a. This should put TOC at ~11,000’. CBL verified TOC behind the 7” is 11,100’ and the top of the HRZ confining shale is at 11,050’. 19. POOH pumping CT clean-up and displacement. FP tubing. 20. Wash up and RDMO cementers. 21. WOC. 22. MIRU eline and pressure test lubricator to 250 psi low / 2500 psi high. 23. RIH with JB / Gauge ring and tag TOC @ 11,000’. a. Give AOGCC 24 hour notice to witness. 24. RIH and cut tubing at 10,500’. 25. MIRU pumpers and establish circulation down tubing taking returns from the IA. 26. Perform reservoir abandonment CMIT TxIA to 2500 psi for 30 minutes charted. Point forward we will be establishing communication with the 8.48 ppg Ugnu formation. a. Give AOGCC 24 hour notice to witness. Pumping & Well Support 27. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 28. RD well house and flowlines. Clear and level area around well. 29. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 30. NU BOPE house. Spot mud boat. State inspectors should make one trip to well to witness tag and pressure tests. - mgr MIT-T and MIT-IA to 2500 psi. State to witness. -mgr RWO Well: MPU E-23 Date: 13 Jun 2023 Brief RWO Procedure: Pull Tubing 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with KWF prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. 5. Circulate 410 bbls source water down tubing taking returns from the IA. 6. Perform 30 minute negative drawdown test. a. Give AOGCC 24 hour notice to witness. 7. MU landing joint or spear and PU on the tubing hanger. 8. Recover the tubing hanger. 9. POOH and lay down the 3-1/2” tubing. Wash and trash all joints. Perforate & Clean Out 1. MIRU eline and pressure test lubricator to 250 psi low / 2500 psi high. 2. RIH with junk basket / gauge ring sized for 7” packer. 3. RIH and perforating the following intervals: a. 5480’-5550’ b. 5315’-5430’ c. Correlate to Final LWD log dated 06-12 July 1995. d. Maintain hole fill during perforating operations as we will be establishing communication with the reservoir. 4. POOH and RDMO eline. Run Lower Screen Completion 1. Pick up and RIH with completion: a. 8 joints of 4-1/2” 110 micron Ener-Armor screens b. 7” x 4.5” mechanical set packer with a set depth of 5150’ 2. Set packer per vendor recommendations. 3. Release from packer and POOH. Run New ESP No requirement for AOGCC to witness. RWO Well: MPU E-23 Date: 13 Jun 2023 1. Ensure that handling equipment is on-hand for running 3-1/2” 13Cr completion. 2. MU Spooler to run cable and capillary tubing. 3. PU new ESP with single cap string and RIH on 3-1/2” tubing, making electrical checks on the cable and pressure tests on the cap string every 2,000 feet a. Set base of ESP assembly at ~5050’. b. 1 joint of 3-1/2” Tubing c. 3-1/2” XN (2.750” No-Go) d. ~3400’ of 3-1/2” L-80 tubing e. 3-1/2” EUE x 3-1/2” J-BEAR crossover f. ~1000’ of 3-1/2” 13Cr tubing 4. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. 5. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. CTU BOPE Schematic 4. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: TCS 5/3/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1# / H-40 19.124”Surface 113’ 9-5/8"Surface 40# / L-80 / BTC 8.835”Surface 4,240’ 7"Production 26# / L-80 / BTC 6.276”Surface 13,024’ TUBING DETAIL 3-1/2"Tubing 9.3# / N-80 / MOD 8RD 2.992 Surface 12,313’ JEWELRY DETAIL No Depth Item 1 12,275’7” x 4.5” Baker S-3 Packer 2 12,302’HES 3.5” XN Nipple 3 12,313’3.5” WLEG 4 12,650’NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT STATUS Kup C 12,520’12,620’7,061’7,104’100 OPEN Kup B7 12,706’12,766’7,140’7,165’60 OPEN OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7”310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 _____________________________________________________________________________________ Revised By: TCS 5/3/2023 PROPOSED SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1# / H-40 19.124”Surface 113’ 9-5/8"Surface 40# / L-80 / BTC 8.835”Surface 4,240’ 7"Production 26# / L-80 / BTC 6.276”Surface 13,024’ TUBING DETAIL 3-1/2”Tubing 9.3# / 13Cr / J-BEAR 2.992 Surface ~1,000’ 3-1/2"Tubing 9.3# / N-80 / EUE 2.992”~1,000’~4,430’ 3-1/2”Tubing 9.3# / N-80 / MOD 8RD 2.992”11,000’12,313’ JEWELRY DETAIL No Depth Item 1 ~4,400 3.5” X Nipple 2 ~4,430 Discharge Head 3 ~4,940 Pump 4 ~4,960 Gas Seperator 5 ~4965 Tandem Seals 6 ~4,980 Motor 7 ~5,000’Sensor 8 ~5,010’Centralizer 9 ~5,150’7” x 4-1/2” Packer 10 ~5,550 400’ 110 micron Ener-Armor Screens 11 ~12,260 3-1/2” Cement Retainer 12 12,275 7” x 4.5” Backer S-3 Packer 13 12,302’HES 3.5” XN Nipple 14 12,313’3.5” WLEG 15 12,650’NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT STATUS Ugnu M 5,315’5,450’4,110’4,165’135 OPEN Ugnu M 5,480’5,550’4,177’4,207’70 OPEN Kup C 12,520’12,620’7,061’7,104’100 SQZ Kup B7 12,706’12,766’7,140’7,165’60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7”310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 SLB Stack Drawing Not Drawn To Scale--- For Reference Only BOP rams dressed for 1.75" Coiled Tubing. Blind/Shear ram blades: Texas Oil Tools NOV – 4.06" Shear seal Rams w/ Viton Seals, H2S -50F Flanged Plug Valve (Manual) Flanged Plug Valve (Manual) Kill Port Manual ram locking wheel CT BOP’s controlled by Coiled Tubing Unit with ~100 gal accumulator system Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Top Door Stripper – 1.75" Swab Valve 4.06" 10K Quad BOP C/W 2.06" 10K Flanged Plug Valves x 2" 1502 SSV 5K x 10K C062/CB44 Crossover Master Valve 7.06" 5K /4.06"10K Lubricator Section (Manual)(Manual) Slip & Pipe Ram dressed with 1.75" Inserts IA and OA Gate Valves Blind & Shear Ram Slip Ram Kill Port Blind & Shear Ram Pipe Ram Pump In Sub with 2 Flanged Gate Valves 2' 10K to 5K Crossover Provided by client Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Change to Approved Program Suspend Perforate Other Stimulate Pull Tubing Install TTBP Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,040'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY todd.sidoti@hilcorp.com 777-8443 Todd Sidoti Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.3# / L-80 / 8rd MOD 12,313' 5/26/2023 Baker S-3 Pacher and N/A 12,275 MD/ 6,958 TVD and N/A See Schematic See Schematic 3.5" Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 & ADL0028231 195-094 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22570-00-00 Hilcorp Alaska LLC C.O. 432E MILNE PT UNIT E-23 Proposed Pools: MILNE POINT KUPARUK RIVER OIL UGNU UNDEF WTRSP 7,278' 12,640' 7,112' 3,877 12,640' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 20"N/A 5,750psi 7,240psi 3,652' 7,271' 9-5/8" 7" 4,209' 12,996' MD 4,240' 13,024' Length Size 80' 112' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:20 am, Jun 15, 2023 323-345 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.14 15:33:45 - 08'00' Taylor Wellman (2143) * State to witness tag and pressure test of Tubing and IA to 2500 psi after cement abandonment of reservoir. * ASR BOPE pressure to 2500 psi after passing MIT-T to 2500 psi and MIT-IA to 2500 psi to assure reservoir isolated. MDG 6/19/2023 3,877 MGR19JUN23 10-404 DSR-6/15/23 then 1428 psi (Ugnu perfs) (pre Kuparuk abandonment) -mgr GCW 06/20/2023 06/21/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.21 09:39:14 -08'00' RBDMS JSB 062223 RWO Well: MPU E-23 Date: 13 Jun 2023 Well Name: MPU E-23 API Number: 50-029-22570-00-00 Current Status: SI Inj Pad: E-Pad Estimated Start Date: Jun 16, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-094 First Call Engineer: Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 4589 psi @ 7120’ TVD SITP: 1475 psi | 12.4 PPGE MPSP: 3877 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 69° @ 10,379’ MD Max Dogleg: 7.2°/100ft @ 6,000’ MD Brief Well Summary: MPE-23i is a WAG injector drilled and completed in September 1995 to support E-09, E-11 and E-22 in the B & C sands. In April 2021 the well began to pressure up in the IA while on gas injection. An AA was established in May 2021 stating that the well can continue injection on water only. to An IPROF ran in August 2020 demonstrated that all injection is going into the B7 perforations. A TTBP with a cement cap was placed in November 2023 in order to isolate the Kuparuk B7 sand. During a recent workover to change the ESP out on the MPE-15 water source well, subsidence buckling was encountered in the 7” casing at 300”. The well construction makes fixing this casing very difficult and we are choosing to convert MPE-23 into a new water source well. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 3000 psi on 4/8/2022. x SITP is 1475 psi. x Slickline tagged cement stringers on 6/9/2023 with 2.80“ gauge ring at 12,000’. Objective: Perform reservoir abandonment on the Kuparuk formation, perforate Ugnu M sands, run new lower screen completion, run ESP and convert well to water production. CTU, E-line & Cementers 1. MIRU CTU and pressure test BOPE to 250 Low/ 4,500psi Hi, 10 min Hi, 5 min Low 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. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 2. MU and RIH with BHA including 2.85” junk mill. 3. Mill cement stringers to XN @ ~12,302’ CTMD. 4. Pull up to 11,900’ and perform injectivity test down backside until pressures are stable at 0.5, 1 and 1.5 BPM. POOH. 5. MU and RIH with BHA including memory GR/CCL. 6. Drift to PBDT and log up to 12,000’ CTMD. POOH and correlate data to tubing tally. 4589 psi @ 7120’ TVD 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Install TTBP Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,040'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9-5/8" 7" 4,209' 12,996' MD N/A 5,750psi 7,240psi 3,652' 7,271' 4,240' 13,024' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,278' 12,640' 7,112' 3,877 12,640' 80' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 & ADL0028231 195-094 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22570-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT E-23 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.3# / L-80 / 8rd MOD 12,313' 5/26/2023 Baker S-3 Pacher and N/A 12,275 MD/ 6,958 TVD and N/A See Schematic See Schematic 3.5" Perforation Depth MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY todd.sidoti@hilcorp.com 777-8443 Todd Sidoti Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-279 By Grace Christianson at 3:21 pm, May 11, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.11 14:19:52 - 08'00' Taylor Wellman (2143) DSR-5/17/23 BOPE pressure test to 2500 psi. WSW * Reservoir abandonment plug to be 'negative pressure tested' with souce water ~8.66 ppg for 30 minute flow test to assure cement plug isolation and adjusted MPSP less than 2500 psi. 10-404 UGNU UNDEF WTRSP (525120) SFD SFD 5/19/2023 3,877 Perforate New Pool MGR15MAY23 X- X GCW 05/26/23JLC 5/26/2023 05/26/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.26 14:13:09 -08'00' RBDMS JSB 053023 RWO Well: MPU E-23 Date: 8 May 2023 Well Name: MPU E-23 API Number: 50-029-22570-00-00 Current Status: SI Inj Pad: E-Pad Estimated Start Date: May 26, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-094 First Call Engineer: Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 4589 psi @ 7120’ TVD SITP: 1475 psi | 12.4 PPGE MPSP: 3877 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 69° @ 10,379’ MD Max Dogleg: 7.2°/100ft @ 6,000’ MD Brief Well Summary: MPE-23i is a WAG injector drilled and completed in September 1995 to support E-09, E-11 and E-22 in the B & C sands. In April 2021 the well began to pressure up in the IA while on gas injection. An AA was established in May 2021 stating that the well can continue injection on water only. to An IPROF ran in August 2020 demonstrated that all injection is going into the B7 perforations. A TTBP with a cement cap was placed in November 2023 in order to isolate the Kuparuk B7 sand. During a recent workover to change the ESP out on the MPE-15 water source well, subsidence buckling was encountered in the 7” casing at 300”. The well construction makes fixing this casing very difficult and we are choosing to convert MPE-23 into a new water source well. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 3000 psi on 4/8/2022. x SITP is 1475 psi. Objective: Perform reservoir abandonment on the Kuparuk formation, perforate Ugnu M sands, run new lower screen completion, run ESP and convert well to water production. Eline & Cementers 1. MIRU eline and pressure test lubricator to 250 psi low / 4000 psi high. 2. RIH and punch tubing above packer at 12,270’. 3. POOH & RDMO eline. 4. MIRU cementers and IA returns tanks. 5. Pressure test lines to 250 psi low / 4000 psi high. 6. With IA shut in Pump the following schedule at 5 bpm, do not exceed 4000 psi treating pressure. a. 5 bbl methanol b. 5 bbl source water spacer c. 20 bbls 15.8 ppg class G cement d. Drop wiper dart sized for 3.5” XN subsidence buckling was encountered Combo MIT-IA Passed to 3000 psi on 4/8/2022. RWO Well: MPU E-23 Date: 8 May 2023 e. 107 bbls source water displacement 7. Once dart lands on nipple, pressure up and perform CMIT-TxIA to 2500 psi for 30 minutes charted. 8. Open IA and pump the following schedule taking returns to tanks. a. 66 bbls IA diesel freeze protect b. 224 bbls source water spacer c. 45 bbls Class G cement d. 74 bbls source water displacement e. 22 bbl diesel 9. Shut in IA and tubing. a. This should put TOC at ~11,000’. CBL verified TOC behind the 7” is 11,100’ and the top of the HRZ confining shale is at 11,050’. 10. Wash up and RDMO cementers. 11. WOC. 12. MIRU eline and pressure test lubricator to 250 psi low / 2500 psi high. 13. RIH with JB / Gauge ring and tag TOC @ 11,000’. 14. RIH and cut tubing at 10,500’. 15. MIRU pumpers and establish circulation down tubing taking returns from the IA. 16. Perform reservoir abandonment CMIT TxIA to 2500 psi for 30 minutes charted. Point forward we will be establishing communication with the 8.48 ppg Ugnu formation. Pumping & Well Support 17. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 18. RD well house and flowlines. Clear and level area around well. 19. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 20. NU BOPE house. Spot mud boat. Brief RWO Procedure: Pull Tubing 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with KWF prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. 24 hour notice for AOGCC to witness. 24 hour notice to AOGCC to witness. To assure no flow back from high BHP assure 1500 psi minimum surface pressure until 500 psi cement compressive strength. - mgr in tubing - mgr To assure no flow back from high BHP assure 1500 psi minimum surface pressure until 500 psi cement compressive strength. - mgr If risk of pressure release when pulling BPV, lubricate BPV from hanger profile. - mgr Perform 30 minute negative pressure test with source water. - mgr RWO Well: MPU E-23 Date: 8 May 2023 5. Circulate 410 bbls source water down tubing taking returns from the IA. 6. MU landing joint or spear and PU on the tubing hanger. 7. Recover the tubing hanger. 8. POOH and lay down the 3-1/2” tubing. Wash and trash all joints. Perforate & Clean Out 1. MIRU eline with line wiper/packoff. 2. RIH with junk basket / gauge ring sized for 7” packer. 3. RIH and perforating the following intervals: a. 5480’-5550’ b. 5315’-5430’ c. Correlate to Final LWD log dated 06-12 July 1995. d. Maintain hole fill during perforating operations as we will be establishing communication with the reservoir. 4. POOH and RDMO eline. Run Lower Screen Completion 1. Pick up and RIH with completion: a. 8 joints of 4-1/2” 110 micron Ener-Armor screens b. 7” x 4.5” mechanical set packer with a set depth of 5150’ 2. Set packer per vendor recommendations. 3. Release from packer and POOH. Run New ESP 1. Ensure that handling equipment is on-hand for running 3-1/2” 13Cr completion. 2. MU Spooler to run cable and capillary tubing. 3. PU new ESP with single cap string and RIH on 3-1/2” tubing, making electrical checks on the cable and pressure tests on the cap string every 2,000 feet a. Set base of ESP assembly at ~5050’. b. 1 joint of 3-1/2” Tubing c. 3-1/2” XN (2.750” No-Go) d. ~3400’ of 3-1/2” L-80 tubing e. 3-1/2” EUE x 3-1/2” J-BEAR crossover f. ~1000’ of 3-1/2” 13Cr tubing 4. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. 5. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. Perforating to be performed with PCE Pressure test PCE before perforating. -mgr RWO Well: MPU E-23 Date: 8 May 2023 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TCS 5/3/2023 SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1# / H-40 19.124”Surface 113’ 9-5/8"Surface 40# / L-80 / BTC 8.835”Surface 4,240’ 7"Production 26# / L-80 / BTC 6.276”Surface 13,024’ TUBING DETAIL 3-1/2"Tubing 9.3# / N-80 / MOD 8RD 2.992 Surface 12,313’ JEWELRY DETAIL No Depth Item 1 12,275’7” x 4.5” Baker S-3 Packer 2 12,302’HES 3.5” XN Nipple 3 12,313’3.5” WLEG 4 12,650’NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT STATUS Kup C 12,520’12,620’7,061’7,104’100 OPEN Kup B7 12,706’12,766’7,140’7,165’60 OPEN OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7”310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 _____________________________________________________________________________________ Revised By: TCS 5/3/2023 PROPOSED SCHEMATIC Milne Point Unit Well: MPU E-23 Last Completed: 9/13/1995 PTD: 195-094 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1# / H-40 19.124”Surface 113’ 9-5/8"Surface 40# / L-80 / BTC 8.835”Surface 4,240’ 7"Production 26# / L-80 / BTC 6.276”Surface 13,024’ TUBING DETAIL 3-1/2”Tubing 9.3# / 13Cr / J-BEAR 2.992 Surface ~1,000’ 3-1/2"Tubing 9.3# / N-80 / EUE 2.992”~1,000’~4,430’ 3-1/2”Tubing 9.3# / N-80 / MOD 8RD 2.992”11,000’12,313’ JEWELRY DETAIL No Depth Item 1 ~4,400 3.5” X Nipple 2 ~4,430 Discharge Head 3 ~4,940 Pump 4 ~4,960 Gas Seperator 5 ~4965 Tandem Seals 6 ~4,980 Motor 7 ~5,000’Sensor 8 ~5,010’Centralizer 9 ~5,150’7” x 4-1/2” Packer 10 ~5,550 400’ 110 micron Ener-Armor Screens 11 12,275’7” x 4.5” Baker S-3 Packer 12 12,302’HES 3.5” XN Nipple 13 12,313’3.5” WLEG 14 12,650’NEO TTBP w/ 10’ of cement (TOC: 12,640’) PERFORATION DETAIL SANDS Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT STATUS Ugnu M 5,315’5,450’4,110’4,165’135 OPEN Ugnu M 5,480’5,550’4,177’4,207’70 OPEN Kup C 12,520’12,620’7,061’7,104’100 SQZ Kup B7 12,706’12,766’7,140’7,165’60 SQZ OPEN HOLE / CEMENT DETAIL 9-5/8"850 sx Permafrost E lead followed by 250 sx Class G in 12-1/4” open hole. 150 sx Permafrost E top job. 7”310 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1400’ Max Hole Angle = 68 deg @ 4,050’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC w/ 11” FMC Tubing Hanger. 3.5” NSCT Threads. 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-22570-00-00 Drilled and Completed by Nabors 4ES 9/13/1995 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU,QVWDOO&,%3 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ" <HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU )LHOG3RROV 7RWDO'HSWK0'IW 7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH &RQGXFWRU 1$ 6XUIDFH SVL 3URGXFWLRQ SVL 3DFNHUVDQG66697\SH 3DFNHUVDQG66690'IWDQG79'IW $WWDFKPHQWV 3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV 2,/ :,1- :'63/6XVSHQGHG 9HUEDO$SSURYDO 'DWH *$6 :$* *6725 63/8* $2*&&5HSUHVHQWDWLYH*,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH &RQGLWLRQVRIDSSURYDO1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\ %237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ 6HH6FKHPDWLF 6HH6FKHPDWLF %DNHU63DFKHUDQG1$ 0'79'DQG1$ 3HUIRUDWLRQ'HSWK0'IW /HQJWK 6L]H 0' /UG02' 79' %XUVW 1$ SVL SVL 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ &HQWHUSRLQW'U6XLWH$QFKRUDJH$. +LOFRUS$ODVND//& 0,/1(3781,7( 0,/1(32,17.83$58.5,9(52,/ &2( 7XELQJ*UDGH 7XELQJ0'IW3HUIRUDWLRQ'HSWK79'IW 7XELQJ6L]H ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< 7RGG6LGRWL WRGGVLGRWL#KLOFRUSFRP $XWKRUL]HG7LWOH2SHUDWLRQV0DQDJHU 1$ U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 9:48 am, Aug 05, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 6)' $'/ 6)' '650*5$8* GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.12 14:25:42 -08'00' RBDMS JSB 081522 >ͲWůƵŐďĂĐŬ tĞůů͗DWhͲϮϯ ĂƚĞ͗ϯƵŐƵƐƚϮϬϮϮ tĞůůEĂŵĞ͗DWhͲϮϯW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϱϳϬͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗/ŶũĞĐƚŽƌWĂĚ͗ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗^ĞƉƚĞŵďĞƌϭ͕ϮϬϮϮZŝŐ͗^>͕> ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϱͲϬϵϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dŽĚĚ^ŝĚŽƚŝ;ϵϬϳͿϳϳϳͲϴϰϮϬ;KͿ;ϵϬϳͿϲϯϮͲϰϭϭϯ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ ϯϰϰϴƉƐŝΛϳϬϬϬ͛ds ^,W^͗ϳͬϮϯͬϭϯͮϵ͘ϱWW' DW^W͗ Ϯ͕ϳϰϴƉƐŝ 'ĂƐŽůƵŵŶ'ƌĂĚŝĞŶƚ;Ϭ͘ϭƉƐŝͬĨƚͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶϲϵΣΛϭϬ͕ϯϳϵ͛D DĂǆŽŐůĞŐ͗ϳ͘ϮΣͬϭϬϬĨƚΛϲ͕ϬϬϬ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWͲϮϯŝŝƐĂt'ŝŶũĞĐƚŽƌĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶ^ĞƉƚĞŵďĞƌϭϵϵϱƚŽƐƵƉƉŽƌƚͲϬϵ͕ͲϭϭĂŶĚͲϮϮŝŶƚŚĞΘ ƐĂŶĚƐ͘/ŶƉƌŝůϮϬϮϭƚŚĞǁĞůůďĞŐĂŶƚŽƉƌĞƐƐƵƌĞƵƉŝŶƚŚĞ/ǁŚŝůĞŽŶŐĂƐŝŶũĞĐƚŝŽŶ͘ŶǁĂƐĞƐƚĂďůŝƐŚĞĚŝŶ DĂǇϮϬϮϭƐƚĂƚŝŶŐƚŚĂƚƚŚĞǁĞůůĐĂŶĐŽŶƚŝŶƵĞŝŶũĞĐƚŝŽŶŽŶǁĂƚĞƌŽŶůǇ͘ƚŽŶ/WZK&ƌĂŶŝŶƵŐƵƐƚϮϬϮϬ ĚĞŵŽŶƐƚƌĂƚĞĚƚŚĂƚĂůůŝŶũĞĐƚŝŽŶŝƐŐŽŝŶŐŝŶƚŽƚŚĞϳƉĞƌĨŽƌĂƚŝŽŶƐ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ xŽŵďŽD/dͲ/WĂƐƐĞĚƚŽϯϬϬϬƉƐŝŽŶϰͬϴͬϮϬϮϮ͘ KďũĞĐƚŝǀĞ͗ ƌŝĨƚĂŶĚƐĞƚddWŝŶŽƌĚĞƌƚŽŝƐŽůĂƚĞƚŚĞ<ƵƉĂƌƵŬϳƐĂŶĚĂŶĚƐǁĞĞƉŵŽƌĞƐĂŶĚŽŝů͘ ^ůŝĐŬůŝŶĞ ϭ͘D/Zh^>ĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ƌŝĨƚƚŽWd;ΕϭϮ͕ϵϯϮ͛ǁŝƚŚϮ͘ϲ͟ĐĞŶƚƌĂůŝǌĞƌĂŶĚƐĂŵƉůĞďĂŝůĞƌ͘ ϯ͘ZDK^>͘ Ͳ>ŝŶĞ ϭ͘D/Zh>ĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚ͘ Ϯ͘Z/,ǁŝƚŚ^ƉŝƌĂůddWĂŶĚĐŽƌƌĞůĂƚĞƚŽ^ĞŐŵĞŶƚĞĚŽŶĚ>ŽŐĚĂƚĞĚϬϴͬϮϮͬϵϱ͘ ϯ͘^ĞƚƉůƵŐĂƚϭϮ͕ϲϵϱ͛͘ ϰ͘Z/,ǁŝƚŚWĚƵŵƉďĂŝůĞƌĂŶĚĚƵŵƉŐůĂƐƐďĞĂĚƐ͘ ϱ͘DĂŬĞWĚƵŵƉďĂŝůĞƌƌƵŶƐƚŽƉůĂĐĞϯϬ͛;ϰϴŐĂůůŽŶƐͿŽĨĐĞŵĞŶƚŽŶƉůƵŐ͘ ϲ͘WKK,ĂŶĚZDK>͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ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allace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Tuesday, April 20, 2021 3:23 PM To: David Haakinson Cc: Regg, James B (CED); Rixse, Melvin G (CED); tfouts@hilcorp.com; Chad Helgeson Subject: RE: MPU E-23 (PTD # 195-094) SI for TxIA while on Gas Inj. David, Water injection for up to 28 days is approved for diagnostics and monitoring. At the culmination of this period, if pressures indicate integrity to water, Hilcorp can apply to AOGCC for an Area Injection Order (A10) administrative approval (AA) to allow the well to continue on water only injection with a known TxIA to gas. The application must provide enough detail that AOGCC can determine that the wells condition does not compromise overall well integrity so as to threaten human safety or the environment. The application and administrative approval will detail the additional ongoing conditions of testing, monitoring, and reporting for the well. Samples of the AIO AAs can be found at http://aogweb.state.ak.us/WebLinkSearch . Looking at my records, the last AA for a MPU well was AID 1013.014 for MPU B-13 (PTD 1850930). Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: David Haakinson <dhaakinson@hilcorp.com> Sent: Monday, April 19, 20218:56 AM To: Regg, James B (CED) <iim.regg@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com> Subject: MPU E-23 (PTD # 195-094) SI for TAA while on Gas Inj. Jim, Milne Point Injector E-23 (PTD 195-094) was shut in yesterday 4/18/21, following slow pressurization of the IA while on gas injection. The injector was converted from water to gas injection on 4/9/21, and was exhibiting stable injection pressures while on water injection, but appears to have a slow TxIA leak while on gas injection. The last MIT -IA was completed on Hilcorp Alaska requests to swap E-23 to water injection and bring online on water injection for a 30 -day monitoring period. Assuming no further TAA on water, we propose to make E-23 a water -only injection well. MRk c- 23 Pry 650g4V Regg, James B (CED) From: David Haakinson <dhaakinson@hilcorp.com> Sent: Monday, April 19, 2021 8:56 AM To: Regg, James B (CED); Rixse, Melvin G (CED) Cc: Tom Fouts; Chad Helgeson Subject: MPU E-23 (PTD # 195-094) Sl for TxIA while on Gas Inj. Attachments: MPU E-23 TIO Plot 4-19-21.xlsx Jim, Milne Point Injector E-23 (PTD 195-094) was shut in yesterday 4/18/21, following slow pressurization of the IA while on gas injection. The injector was converted from water to gas injection on 4/9/21, and was exhibiting stable injection pressures while on water injection, but appears to have a slow TxIA leak while on gas injection. The last MIT -IA was i completed on Hilcorp Alaska requests to swap E-23 to water injection and bring online on water injection for a 30 -day monitoring period. Assuming no further TxIA on water, we propose to make E-23 a water -only injection well. r MPU E-23 Pressure Charts 4,500 4,000 3,000 .N 2,500 N 2,000 u a` 1,500 r� 1,000 Soo 0 1/14/20211/24/2021 2/3/2021 2/13/20212/23/2021 3/5/2021 3/is/20213/25/2021 4/4/2021 4/14/20214/24/2021 —Tubing —IA —OA Please let us know if you approve of our plans. David Haakinson Operations Engineer I North Slope Asset Team Hilcorp Alaska, LLC Office: (907) 777-8343 1 Cell: (307) 660-4999 dhaakinsonghi IcaU.com Wallace, Chris D (CED) From: Regg, James B (CED) Sent: Monday, April 19, 2021 10:21 AM To: Wallace, Chris D (CED) Subject: FW: MPU E-23 (PTD # 195-094) SI for TxIA while on Gas Inj. Attachments: MPU E-23 TIO Plot 4-19-21.xlsx Initial email Jim Regg Supervisor, Inspections AOGCC 333 W. Th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: David Haakinson <dhaakinson@hilcorp.com> Sent: Monday, April 19, 20218:56 AM To: Regg, James B (CED) <jim.regg@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com> Subject: MPU E-23 (PTD # 195-094) SI for TxIA while on Gas Inj. Jim, Milne Point Injector E-23 (PTD 195-094) was shut in yesterday 4/18/21, following slow pressurization of the IA while on gas injection. The injector was converted from water to gas injection on 4/9/21, and was exhibiting stable injection pressures while on water injection, but appears to have a slow TxIA leak while on gas injection. The last MIT -IA was completed on Hilcorp Alaska requests to swap E-23 to water injection and bring online on water injection for a 30 -day monitoring period. Assuming no further TxIA on water, we propose to make E-23 a water -only injection well. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-23 (PTD 195-094) Injection Profile 08/16/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 1950940 E-Set: 34247 Abby Bell 11/13/2020 MEMORANDUM TO: Jim Regg T� I P.I. Supervisor r"/ FROM: Matt Herrera Petroleum Inspector Well Name MILNE PT UNIT E-23 Insp Num: mitMFH2O0421141458 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 23, 2020 SUBJECT: Mechanical Integrity Tests Hilcmp Alaska, LLC &23 MILNE PT UNIT E-23 See: Inspector Reviewed By: P.I. Sup" Comm API Well Number 50-029-22570-00-00 Inspector Name: Matt Herrera Permit Number: 195.094.0 Inspection Date: 4/16/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-23 Type Inj w TVD 6958 Tubing _>059 2061 - 2062 2063- 2063 PTD 1950940 Type Test VF ',Test psi 1740 IA 144 2727 2702 2724 2726 BBL Pumped: 3A BBL Returned: 3.s OA 28 3n 330 0 iso Interval 4YRTST _ p/F 1 Notes: IA Pressure tested to 2700 PSI Per Operator based on Tubing pressure. Unstable injection temperatures resulted in inconsistent IA pressure readings. Field Inspector deemed integrity test Inconclusive but believes well casings have integrity. Inspector Supervisor deemed the test a pass. Thursday, April 23, 2020 Pace I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,September 07,2016 P.I.Supervisor tRe-e i q I/ (R.' SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-23 FROM: Chuck Scheve MILNE PT UNIT KR E-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR E-23 API Well Number 50-029-22570-00-00 Inspector Name: Chuck Scheve Permit Number: 195-094-0 Inspection Date: 9/4/2016 Insp Num: mitCS160906111555 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-23 (Type Inj W'TVD 6958 ' Tubing 1792 • 1792 - 1790 ' 1790 PTD 1950940 Type Test SPT Test psi I 1740 IA 283 2400 2350 2331 - --------------------------- InterVail4YRTST P/F P � OA 334 352 333 - 332 • Notes: SCANNED dura 2 020;7 Wednesday,September 07,2016 Page 1 of 1 r ,n F • �{ t-2 Re _ , JamesB (D_) Irl —O 1 PNS ►�J a /i5 -C / From: Brooks, Phoebe L (DOA) Sent: Tuesday, September 25, 2012 11:21 AM To: AK, D&C Well Integrity Coordinator (c t ('Z(t Cc: Regg, James B (DOA) Subject: RE: OPERABLE: Injector MPE-23 (PTD#1950940) Passed Witnessed AOGCC MIT-IA Attachments: MIT MPE-23 09-21-12 Revised.xls Jerry, Attached is a revised report for MIT MPE-23 09-21-12 based on the inspector's report.The inspector included two separate reports (with the first test through 45 min. including an "inconclusive" test result). Please let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator©bp.com] Sent: Saturday, September 22, 2012 7:23 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C) Subject: OPERABLE: Injector MPE-23 (PTD #1950940) Passed Witnessed AOGCC MIT-IA All, A1) -Z3 ict6Cct.40 Injector MP-B-2-3 (PTD # 1 '6") passed a witnessed AOGCC MIT-IA on 09/21/2012. The passing test confirms the presence of two competent barriers in the well. The well is reclassified as Operable. A copy of the MIT form is enclosed for review. «MIT MPE-23 9-21-12.xls» Please call if you have any questions. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator -. 1 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator(a)BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, September 17, 2012 2:19 PM To: AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R; Stone, Christopher; 'Regg, James B (DOA)'; Chris Wallace (chris.wallace@alaska.gov); AK, OPS MPU Well Ops Coord Cc: Walker, Greg (D&C); AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector MPE-23 (PTD #1950940) POI for AOGCC MIT-IA All, Injector MPE-23 (PTD # 1950940) was not tested for its 4 year AOGCC MIT-IA because the well was shut in. The well is ready to be placed on injection and has passed a pre-injection MIT-IA. The well is reclassified as Under Evaluation so it may be placed on injection for an AOGCC witnessed MIT-IA once stabilized. The MIT form for the pre-injection test is attached for reference: Thank you, Mehreen Vazlr BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 2 • • /4PVI E-23 i`i5 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Saturday, September 22, 2012 7:40 PM \.,eeteil(tSJIz- To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C) Subject: RE: OPERABLE: Injector MPE-23 (PTD#1950940) Passed Witnessed AOGCC MIT-IA- CORRECTED WELL NAME All, The previous e-mail was incorrect regarding the well name in the e-mail text. The injector MPE-23 (PTD# 1950940) was the well that was tested, not MPB-23 as the text of the e-mail referred. I apologize for this error. Gerald Murphy BP Alaska - Well Integrity Coordinator 111. WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, September 22, 2012 7:23 PM To: 'Regg, James B (DOA)'; Chris Wallace (chris.wallace@alaska.gov); Brooks, Phoebe L(DOA) (Dhoebe.brooks@alaska.gov); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, .PS MPU Wells Ops Coord 2; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; 'ismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engi,-er; Walker, Greg (D&C) Subject: OPERABLE: Injector MPE-23 (PTD #1950940) Passed Witnes -d AOGCC MIT-IA All, Injector MPB-23 (PTD # 1890160) passed a witnesses AOGCC MIT-IA on 09/21/2012. The passing test confirms the presence of two competent barrier 'n the well. The well is reclassified as Operable. A copy of the MIT form is enclosed for revi- . « File: MIT MPE-23 9-21-12.xls >> Please call if you have any que ions. Thank you, 1 • .MPS Regg, James B (DOA) ( 771 1 q5 - 0q4 - £) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, March 08, 2012 9:06 PM // To: Regg, James B (DOA) 3 l dli Cc: AK, D &C Well Integrity Coordinator; AK, OPS MPU Well Ops Coord Subject: Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) Due for 4 year MIT -IA Compliance Testing Shut -In for Adjacent RWOs and Reclassified as Not Operable Jim, Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) were due for 4 year compliance testing on 3/7/2012. The wells are currently shut in for rig workovers on MPE -09 and MPL -06 respectfully and are not scheduled to return to injection until approximately May timeframe. The wells have been shut in since January, 2012. The wells have been reclassified as o Op crritii a MIT -IA can be performed. The wells have been added to the Quarterly Not Operable well report. If you have any questions, or require any further information please let me know. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 ` trilA EC) MAR "� 3 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 December 30, 2011 1 95— O0f ri4 PE D--f Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 th 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, .... Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10.404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job 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 �1 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 ~~~~ STATE OF ALASKA ,~P~ ~ l~j•I'.I`1 ALAS OIL AND GAS CONSERVATION COMMI ION r ~ .., ~~ I PORT OF SUNDRY WELL OPERATIONS 1. Operations Ap ndon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ . Other ~ ACID/FCO - ~1tiC lt T `~ ~~ . i~ Performed: A ter~asing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 1~ Exploratory 195-0940. 3. Address: P.O. Box 196612 StratlgraphlC Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22570-00-00' 7. KB Elevation (ft): 9. Well Name and Number: 54.1 KB - MPE-23' 8. Property Designation: 10. Field/Pool(s): ADLO-028231 ~ Milne Point Unit Field/ Kuparuk River Sands Pool 11. Present Well Condition Summary: Total Depth measured 13038 feet Plugs (measured) None true vertical 7277.13 ~ feet Junk (measured) None Effective Depth measured 12392 feet true vertical 7234 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" Surface - 113 Surface - 113 Surface 4209 9-5/8"40# L-80 31 - 4240 31 - 3652 5750 3090 Production 12996 7" 26# L-80 28 - 13024 28 - 7271 7240 5410 r ~ "` Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# N-80 SURFACE - 12315' 0 0 - Packers and SSSV (type and measured depth) 7"X3-1/2" BAKER S-3 PKR 12275' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3437 2636 Subsequent to operation: 3478 2625 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~~~ Development r Service - Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG - GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-115 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature '~ Phone 564-4944 Date 4/14/2009 Form 10-404 Reviled 04/2006 ~ € ~ ~~ l~, ~~~ ~ ~~I)~ Submit Original Only !~ ~, ~ ~ ~ _ ~ "~~4 MPE-23 195-094 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE-23 9/3/95 PER 12,520. 12,620. 7,060.97 7,103.44 MPE-23 9/3/95 PER 12,706. 12,766. 7,139.86 7,165.09 MPE-23 4/9/09 FCO 12,300. 12,938. 6,968.2 7,236.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • MPE-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/8/2009 CTU # 5 Scope; FCO/SBG «interact publishing»perform step rate ;injection test w/ KCL @ 1 thru 3 bpm starting @ 2000 psi to 2600 psi. RIH w/ ?2.25" JSN jetting tbg w/SBG ~ "*job continued on WSR 04-09-09*" i 4/9/2009 CTU #5 1.75" CT continued from WSR 04-08-09 FCO/SBG «InterAct publishing» Let SBG soak and flush into perfs. RIH and dry tag PBTD @ ' 12939' .Pump gel sweeps from 12500 to 12939' and chase to surface. Pump ~ 19~ bbls 15% DAD acid w/ (10% Xylene) Recip across perfs.Preform infectivity test w / 54 bbls of 2% KCL @ 2 bpm 1925 psi -----Job complete-~--- FLUIDS PUMPED BBLS 45 50/50 METH 35 GEOVIS 39 XS 1 %KCL 157 SBG 276 Total `;~ ~ ~ [ ~ ~ ALASSA OIL A1~TD GA5 CO1~T5ERQA'TIOi~T COMD'IIS5IOK Torin Roschinger Pad Challenge Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 • SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASlCf) 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Il`~ Re: Milne Point Field, Kuparuk River Sands Oil Pool, MPE-23 Sundry Number: 309-115 1~: "'~!~' - APB Z~Q Dear Mr. Roshinger Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Comnussion to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considerec'. 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. A person may not appea). a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this ? day of April, 2009 Encl. . c~ ,~~ ~ ~ ~~~ ~ ~ ~oo~ '11.09 i~ STATE OF ALASKA ~O~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~41~ska &~~~ ~~ ~0~~. ~®t1UitISS10t1< ~~~ APPLICATION FOR SUNDRY APPROVAL l ~~ra~c6tt~,~~e 2n AAC 2s_2so ~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^ Plug Pertorations^ Stimulate C j Time Extension ^ ACID FCO Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 195-0940 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22570-00-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPE-23 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028231 54.1 KB - Milne Point Unit Field / Kuparuk River Sands Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13040 7278 - 12392 7234 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 80' 20" Surface 113' Surface 113' Surface 4209' 9-5/8" 40# L-80 31' 4240' 31' 3652' 5750 3090 Production 12996' 7" 26# L-80 28' 13024' 28' 7271' 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open perts12520 - 12620 7060.97 - 7103.44 3-1/2" 9.3# N-80 Surface - 12315' open perts12706 - 12766 7139.86 - 7165.09 - Packers and SSSV Type: 7"x3-1/2" Baker S-3 PKR Packers and SSSV MD (ft): 12275' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/13/2009 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Torin Roschinger Printed Name Torin Roschinger Title Pad Challenge Engineer Signatur~ '~ Phone 564-5703 Date 3/30/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity st ^ Location Clearance ^ Te ` ,. Other: '~SUO©S`~ d"~~ ~~ ~1"\V ~ C ~ ~~ ~ "~ ~ Subsequent Form 'red: (~„,t(~ ~~ \\~~++ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ,~,~ ~a t~ r~`'~ ~ r~ ~~QO Sub Qupl~at~ 9 • MPE-23 Fill Clean Out • by To: J. Sharp / M. O'Malley, MPU Well Ops Supervisors From: Ryan Rupert - MPB-Pad PE Torin Roschinger -MPH-Pad PE Subject: MPE-23 Fill Clean Out MKEPDWL23 March 28, 2009 Est. Cost: $100M IOR: 75 BOPD 1 C FCO Current Status: Injection Rate: Maximum Deviation: Minimum ID: Last Downhole Tag: Downhole Operation: Last BHP & BHT: 122 deg F Latest H2S: Objective: Operable -Injecting in Kuparuk B & C Sands 2.5MMSCF/day @ 3665 psi on 03/24/09 60-68 deg from 3900-13038' MD Tubing 2.75" - XN nipple at 12302' MD Liner 6.276" 04/12/2007 -Slickline tagged schmoo @ 12619' MD 04/12/2007 -Slickline ran SBHP & tagged TD @ 12619' MD 04/12/2007 - 2973 psi at datum 7000' TVDSS (.425psi/ft) & Unknown - no data The purpose of this program is to remove schmoo (313' 12 bbls) covering the B sand perfs down to TD ~ 12932' MD. History: MPE-23i is a WAG injector drilled and completed in September 1995 to support E-09, E-11 and E-22 in the B & C sands. On 08/19/96, an (PROF showed a 40/60 split injection into the B and C sands. In 2000, a 120 bbl 15% DAD acid job was performed after slickline was unable to drift below 12157' slm and found schmoo and scale in the bailer. The C sands took the majority of the stimulation due to schmoo covering the B sands and to regain pressure support in the B sands, a FCO was performed. In February 2005, slickline tagged at 11621' slm and recovered a bailer full of schmoo. Consequently, a ~130bb1 schmoo-be-gone treatment was performed followed by a second slickline tag at 12614' MD (near the bottom of C sand perfs). Though pumping SBG down the tubing proves to be successful opening the C sand perfs, the treatment is unable to reach the B sand perfs. Thus coil tubing will need to be used to cleanout down to the B sand perfs. • MPE-23 Fill Clean Out • Table #2 -MPE-23i Wellwork History DATE WELL OPERATION CODE COMMENTS 1 /8/1996 POI 8/19/1996 IPROF Performed PDS (PROF (40% B, 60% C) _-- 12/16/1999 (PROF Unable to get down tubing due to schmoo buildup _- ----- 06/16/2000 TAG Tagged 12157' wlm bailer full of scale and schmoo _ 07/01/2000 STIM Pumped 120 bbls 15% DAD Acid ----- 11/14/2000 FCO CT cleanout to remove fill. TD tag was at 12900' ctmd __ 11/16/2000 IPROF Performed PDS IPROF (results unkown) 02/18/2005 TAG Tag fill @ 11621' slm (thick schmoo recovered in bailer) -- ------ 10/18/2005 STIM Pumped 129 bbls schmoo-be-gone - - - 10/23/2005 TAG Tag fill @ 12614' and (bailer full of schmoo) 02/17/2007 TAG Tag fill @ 12610' and 04/12/2007 SBHP SBHP ~ 2949 psi @ 7000' TVDSS datum, tagged fill @ 12619' and Risk Discussion: It is important to note that the B sands have a higher perm than the C sands. This may create cross flow when coil reaches the top of the B sands perfs. 2. Though the velocity through the 3-1/2" tubing at 2 bpm is sufficient to carry solids to surface, the bhp is low and losses to the formation should be monitored closely with a return micro-motion meter. Current Plan: The objective of this intervention is to remove the schmoo blocking injection into the perforations for the B sands by performing a FCO. Once the schmoo has been removed, MPE-09 and MPE-22's productivity from the B sands should resume to a combined 75 IOR. Once the FCO is complete, please place the well on injection at 3500 bwpd. The plan is to do a FCO with 2% KCI to TD (12932' md) and jet across each zone of perfs with 15% DAD (10% Xylene). Once the FCO is complete, please place the well on injection at 3500 bwpd. For questions, please call C. Ryan Rupert at 564-5557 or cell 301-1736. cc: w/a: Well File 2 • MPE-23 Fill Clean Out -_ Coil (Fill Clean Out) 1) MIRU CTU, MU BHA with a 2.5" JSN and stab lubricator on well. Establish injectivity rate w/ 2% KCI. 2) With choke closed, start jetting SBG from surface to TT @ 1.5 bpm. Continue jetting into 7" casing ~2.5 bpm to within ~20' fill. PUH to TT and wait 30 minutes. With choke closed, start pumping 2% KCI water to displace tubing of SBG by injecting into perforations. 3) RIH and dry tag top of fill 12619' md. 4) Perform FCO using 2% KCI jetting @ 2 bpm down to 12932' and (PBTD) taking returns to tanks. Use gel sweeps every 50' and chase each sweep to the TT. If sufficient circulation (returns at 50% or better) cannot be maintained, then consider a "fluff and stuff" approach. This method was used successfully on the last CTU FCO in 2000. 5) When maximum depth is reached, chase returns to surface and prep to lay acid across perforations. 6) RBIH to 12776' md, close in choke and start jetting 15% DAD (10% Xylene) @ 1 bpm from 12766-12520' md, RBIH jetting acid evenly across the perfs until 15 bbls of 15% DAD (10% Xylene) has been displaced. 7) Tag TD and begin jetting 2% KCI @ 2 bpm from 12800' up to 12500' md, perform. injectivity test w/ 20 bbls 2% KCI. POOH, FP well. RDMO CTU notify operations (670-3359) to POI @ 3500 3 MPE-23 Fill Clean Out • T4~E: 3.118'-~ Aac rd 1 i" ~-1c Ting i~ 3B' N9Ci n+reads. 3° crvv x 9PV p~fde 20' 94.1 ppf. FIrW 113• - lcaP $190v ~.~~ ~-eaaea.~~-TD I B 918', 4itlr1lt. 4240' L-~ Btrc. MPU f-23i aa~. aF~v= 5a-rtN~1 cx~G. GL BEa/=2-t4f $122 RrT~r~~= 2a.s Ha9ibtuton "ES" 8568' I Cementer 3.5 9.3 ppF, N-80. mod_ 8rd_ {capacdy = 0.0087 bpf) Radioactive Marker 12.352" wlm 22.9' Shat Joint ~i2.368" - 12.388' md~ Stimuls~n Simmary Baker S-3 Packer 12,275' FIES 3.5" "XN" Landk,g 42,302' Npl. {w12.813" 1D w12.?9" No- I PerFO~raticNt SUf11n18fY Ref 1~: OS1Z2195 SBl 1 CCL 20' 14 112.7D6' 1 t04") 165'j I Afpha Jet cfiarges ®0 deg. phase decentralized, EHO = 0.28". TTP = i2.2" GATE . BY OlPS 09 d 13 195 JBF Completicm by N 4ES W LEG 12.313' EO 72,315' .A-~-~^-- t7FlG. PHiD 12,6CiT 7` 29Art, L-80. 13A24' HiftS MILNE POIf+IT UNIT WELL E -23i API NU: 5D-029-22570 eP exPLC~RaTioN a-K BP-GDB Survey Report -Geographic Company: BP Amoco Date: 3/26/2009 Time: 13:47:35 Page: I Field: Prudhoe Bay C o-ordinate(NE) R eference: Well: F-41 PB1, True N orth Site: PB F Pad Vertical (TVD) Reference: 44:41 11/28/1991 00:00 66.0 Well: F-41 PB1 Section (VS) Reference: User (O.OON,O.OOE,3t0.69Azi) Wcllpath: F-41 PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay i North Slope '; UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ~ Sys Datum: Mean Sea Level _ Geomagnetic Model: bggm2007 _ _ ___ I, Site: PB F Pad - -_ _ _ _ - --- - - -- _ - _ _ it ~, TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5972527.29 ft Latitude: 70 19 55.283 N From: Map Easting: 650960.70 ft Longitude: 148 46 31.468 W ~ ', Position Uncertainty: 0.00 ft North Reference: True ~ Ground Level: 0.00 ft Grid Convergence: 1.15 deg ', Well: F-41 PB1 Slot Name: 41 ' F-41PB1 ! Surface Position: +N/-S 2224.50 ft Northing: 5974772.17 ft Latitude: 70 20 17.160 N i ', +E/-W 1043.25 ft Easting : 651958.90 ft Longitude: 148 46 0.998 W Position Uncertainty: 0.00 ft ~ Reference Point: +N/-S 2224.50 ft Northing: 5974772.17 ft Latitude: 70 20 17.160 N li +E/-W 1043.25 ft Easting : 651958.90 ft Longitude: 148 46 0.998 W Measured Depth: 30.50 ft Inclination: 0.00 deg ', Vertical Depth: 30.50 ft Azimuth : 0.00 deg ', Wellpath: F-41 PB1 Drilled From: Well Ref. Point ', 500292220370 Tie-on Depth: 30.50 ft !, Current Datum: 44:41 11 /28/1991 00:00 Height 66.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/17/2000 Declination: 27.11 deg ', ~~ Field Strength: 57349 nT Mag Dip Angle: 80.72 deg I Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ 'i ft ft ft deg 30.50 0.00 0.00 310.69 Surve Pro ram for Definitive Well ath y - - - - i - ~ _- _ ~~ Date: 4/15/2000 Validated: ~ Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 60.00 607.00 1 : Schlum berger GCT multishot (60.00-100~6bI~IS Schlumberger GCT multishot - -~ ~ 607.00 11960.00 2 : MWD - Standard (607.00-11960.00) MWD MWD -Standard Survey Map i/Iap <---- Latitude ----> <--- Longitude ---> MD Incl Azim TVD +N!-S +E/-W Northing Easting Deg 14Iin Sec Deg Min Sec ', ft deg deg ft ft ft ft ft 30.50 0.00 0.00 30.50 _ 0.00 0.00 5974772.17 _ 651958.90 70 20 17.160 N 148 46 0.998 W !, i 60.00 0.00 0.00 60.00 0.00 0.00 5974772.17 651958.90 70 20 17.160 N 148 46 0.998 W 65.00 0.77 218.12 65.00 -0.03 -0.02 5974772.14 651958.88 70 20 17.160 N 148 46 0.999 W 73.50 0.70 219.38 73.50 -0.11 -0.09 5974772.06 651958.81 70 20 17.159 N 148 46 1.001 W !~ 85.80 0.48 227.46 85.80 -0.20 -0.17 5974771.96 651958.73. 70 20 17.158 N 148 46 1.003 W ~i 100.10 0.28 240.88 100.10 -0.26 -0.25 5974771.90 651958.66 70 20 17.158 N 148 46 1.005 W i 113.90 0.20 236.04 113.90 -0.29 -0.30 5974771.87 651958.61 70 20 17.157 N 148 46 1.007 W 127.70 0.20 214.09 127.70 -0.33 -0.33 5974771.84 651958.57 70 20 17.157 N 148 46 1.008 W ',' 141.70 0.27 198.55 141.70 -0.38 -0.36 5974771.79 651958.55 70 20 17.157 N 148 46 1.008 W 155.70 0.35 194.84 155.70 -0.45 -0.38 5974771.71 651958.53 70 20 17.156 N 148 46 1.009 W !. !i 169.70 0.45 197.77 169.70 -0.54 -0.41 5974771.62 651958.50 70 20 17.155 N 148 46 1.010 W i 183.80 0.52 200.21 183.80 -0.66 -0.44 5974771.51 651958.47 70 20 17.154 N 148 46 1.011 W ~' 197.80 0.58 201.69 197.80 -0.78 -0.49 5974771.38 651958.42 70 20 17.153 N i 148 46 1.012 W 211.70 0.67 204.14 211.70 -0.92 -0.55 5974771.24 651958.37 70 20 17.151 N 148 46 1.014 W 225.70 0.87 206.87 225.69 -1.09 -0.63 5974771.07 651958.29 70 20 17.150 N 148 46 1.016 W 239.70 1.17 209.82 239.69 -1.31 -0.75 5974770.85 651958.17 70 20 17.147 N 148 46 1.020 W '. 253.60 1.35 212.00 253.59 -1.57 -0.91 5974770.58 651958.02 70 20 17.145 N 148 46 1.025 W 267.60 1.33 210.87 267.58 -1.85 -1.08 5974770.30 651957.86 70 20 17.142 N 148 46 1.030 W ~I ~ BP-GDB ~ Survey Report -Geographic Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-41PB1 Wellpath: F-41PB1 Survey MD Iuct Azim TVD ft deg deg ft 281.50 1.32 208.45 281.48 295.50 1.28 210.77 295.48 309.60 1.17 214.31 309.57 I 323.70 1.03 214.37 323.67 !~ 337.80 0.98 211.88 337.77 351.80 1.05 212.91 351.77 365.80 1.08 216.39 365.76 379.80 1.03 216.53 379.76 393.70 1.00 214.34 393.66 407.80 1.02 211.85 407.76 ! 421.80 1.07 214.25 421.76 !, 435.70 I 1.07 216.87 435.65 449.70 1.05 214.52 449.65 463.70 1.05 210.26 463.65 475.00 1.50 218.00 474.95 ~ 607.00 1.80 201.00 606.89 !! 697.00 1.30 206.00 696.86 783.00 1.00 194.00 782.84 1274.00 0.80 211.00 1273.78 1814.00 1.80 238.00 1813.64 ~ 2086.00 2.00 265.00 2085.50 2272.00 0.80 283.00 2271.44 243 i .00 0.00 308.90 2430.43 ', 2739.00 2.00 334.00 2738.37 2834.00 4.80 317.00 2833.19 2920.00 5.50 306.00 2918.85 '~ 3023.00 8.80 313.00 3021.04 ! 3099.00 9.80 314.80 3096.04 3192.00 11.00 307.40 3187.51 ! 3285.00 13.20 301.80 3278.44 3379.00 17.00 301.10 3369.18 ~, 3473.00 19.00 301.60 3458.57 ~I 3566.00 21.40 302.10 3545.85 3646.00 23.70 300.70 3619.73 3740.00 25.80 300.40 3705.09 ', 3833.00 28.20 302.50 3787.95 !! 3925.00 29.90 302.10 3868.37 i 4018.00 32.30 301.80 3948.00 4111.00 34.00 302.50 4025.86 ! 4204.00 35.70 302.80 4102.18 4298.00 38.10 303.50 4177.34 ~~ 4392.00 39.70 304.60 4250.50 !, 4486.00 41.40 304.60 4321.92 ', 4579.00 43.90 304.90 4390.31 4672.00 47.00 305.60 4455.55 j 4766.00 49.00 308.10 4518.45 '~ 4860.00 49.70 310.20 4579.69 4951.00 50.30 308.80 4638.18 I 5045.00 51.00 307.40 4697.79 5139.00 51.00 308.10 4756.94 5232.00 51.40 307.70 4815.22 5325.00 51.70 308.10 4873.05 +N/-S ft -2.13 -2.41 -2.66 -2.88 -3.09 -3.30 -3.51 -3.72 -3.92 -4.13 -4.34 -4.55 -4.77 -4.98 -5.19 -8.48 -10.72 -12.33 -19.42 -27.15 -29.83 -29.82 -29.57 -24.74 -20.34 -15.28 -7.01 1.52 12.48 23.47 36.23 51.34 68.30 84.26 104.26 126.31 150.18 175.59 202.66 231.33 262.20 295.26 329.96 365.87 404.13 446.03 491.06 535.40 580.24 624.96 669.49 714.23 Date: 3/26/2009 Time: 13:47:35 Page: 2 Co-ordinate(NE)Keference: Well: F-41PB1, True North Vertical (TVD) Reference: 44:41 11/28/1991 00:00 66.0 Section (VS) Reference: User (O.OON,O.OOE,310.69Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Map <---- Latitude ----> <--- Longitude ---> +E/-W Northing Easting Deg Min Sec lleg Min Sec ft ft ft -1.40 5974769.04 651957.55 70 20 17.137 N 148 46 1.039 W -1.56 5974769.48 651957.40 70 20 17.134 N 148 46 1.043 W i -1.71 5974769.25 651957.25 70 20 17.132 N 148 46 1.048 W ! -1.85 5974769.04 651957.12 70 20 17.130 N 148 46 1.052 W ~! -1.98 5974768.83 651956.99 70 20 17.128 N 148 46 1.056 W ~! -2.13 5974768.61 651956.84 70 20 17.126 N 148 46 1.060 W i -2.28 5974768.40 651956.70 70 20 17.124 N 148 46 1.065 W -2.42 5974768.20 651956.56 70 20 17.122 N 148 46 1.069 W -2.56 5974767.99 651956.43 70 20 17.120 N 148 46 1.073 W ', -2.70 5974767.77 651956.29 70 20 17.118 N 148 46 1.077 W -2.85 5974767:56 651956.14 70 20 17.116 N 148 46 1.081 W ~'! -3.00 5974767.35 651956.00 70 20 17.113 N 148 46 1.086 W !, -3.14 5974767.13 651955.86 70 20 17.111 .N 148 46 1.090 W -3.28 5974766.92 651955.72 70 20 17.109 N 148 46 1.094 W -5.09 5974763.59 651953.99 70 20 17.077 N 148 46 1.147 W -6.04 5974761.33 651953.08 70 20 17.055 N 148 46 1.174 W -6.65 5974759.71 651952.50 70 20 17.039 N 148 46 1.192 W -9.45 5974752.56 651949.84 70 20 16.969 N 148 46 1.274 W 'I -18.59 5974744.65 651940.87 70 20 16.893 N 148 46 1.541 W -26.94 5974741.81 651932.57 70 20 16.867 N 148 46 1.785 W ! -31:44 5974741.73 651928.08 70 20 16.867 N 148 46 1.916 W -32.52 5974741.95 651926.99 70 20 16.870 N 148 46 1.948 W -34.87 5974746.74 651924.54 70 20 16.917 N 148 46 2.017 W -38.31 5974751.06 651921.01 70 20 16.960 N 148 46 2.117 W -44.10 5974756.00 651915.12 70 20 17.010 N 148 46 2.286 W ~', -53.86 5974764.07 651905.20 70 20 17.091 N 148 46 2.571 W !, -62.70 5974772.42 651896.19 70 20 17.175 N 148 46 2.829 W j -75.37 5974783.12 651883.30 70 20 17.283 N 148 46 3.199 W !, -91.44 5974793.78 651867.01 70 20 17.391 N 148 46 3.669 W ', -112.34 5974806.11 651845.86 70 20 17.517 N 148 46 4.279 W- -137.14 5974820.72 651820.76 70 20 17.665 N 148 46 5.003 W ', -164.41 5974837.12 651793.15 70 20 17.832 N 148 46 5.800 W -190.60 5974852.55 651766.64 70 20 17.989 N 148 46 6.565 W 'i -224.49 5974871.85 651732.36 70 20 18.186 N 148 46 7.555 W !, -260.49 5974893.17 651695.92 70 20 18.403 N 148 46 8.606 W I, -298.25 5974916.26 651657.69 70 20 18.637 N 148 46 9.709 W '; -339.01 5974940.85 651616.43 70 20 18.887 N 148 46 10.900 W j -382.06 5974967.03 651572.84 70 20 19.153 N 148 46 12.157 W -426.80 5974994.79 651527.53 70 20 19.435 N 148 46 13.464 W -474.05 5975024.69 651479.67 70 20 19.739 N 148 46 14.844 W '! -522.94 5975056.75 651430.12 70 20 20.064 N 148 46 16.272 W -573.25 5975090.42 651379.13 70 20 20.405 N 148 46 17.742 W '! -625.01 5975125.28 651326.65 70 20 20.758 N 148 46 19.254 W -679.12 5975162.42 651271.78 70 20 21.135 N 148 46 20.834 W -734.99 5975203.18 651215.07 70 20 21.547 N 148 46 22.466 W , -790.29 5975247.08 651158.88 70 20 21.989 N 148 46 24.082 W ': -844.08 5975290.31 651104.21 70 20 22.425 N 148 46 25.653 W -901.28 5975333.99 651046.11 70 20 22.866 N 148 46 27.324 W -959.04 5975377.53 650987.46 70 20 23.306 N 148 46 29.011 W ~, 1016.23 5975420.88 650929.38 70 20 23.744 N 148 46 30.682 W 1073.70 5975464.44 650871.02 70 20 24.184 N 148 46 32.361 W ' ~ BP-GDB Survey Report -Geographic Company: BP Amoco Fie-d: Prudhoe Bay Site: PB F Pad Well: F-41PB1 Wellpath: F-41P61 tiurvev Date: 3/26/2009 Time: 13:47:35 Page: 3 Co-ordinate(NE) Reference: Well: F-41P61, True North ~I Vertical (TVD) Keference: 44:41 11/28/1991 00:00 66.0 ~~ Section (VS) Reference: User (O.OON,O.OOE,310.69Azi) Survey Calculation Method: Minimum Curvature Dh: Oracle - Map Map <---- -- --- Latitude ----> <--- Longitude ---> MD Incl Azim TVD +N/-S +E/-W Northing 1';astiug Deg Min Sec Deg Min Sec ft deg deg ft ft ft ft ft 5419.00 52.00 307.70 4931.11 759.63 -1132.03 5975508.65 650811.79 70 20 __ 24.630 N 148 46 34.065 W 5512.00 53.40 307.70 4987.47 804.87 -1190.57 5975552.69 650752.36 70 20 25.075 N 148 46 35.775 W 5599.00 53.50 308.10 5039.28 847.81 -1245.72 5975594.50 650696.35 70 20 25.497 N 148 46 37.386 W 5694.00 54.00 308.80 5095.45 895.45 -1305.71 5975640.91 650635.41 70 20 25.966 N 148 46 39.139 W ', 5789.00 53.80 309.10 5151.43 943.70 -1365.41 5975687.94 650574.75 70 20 .26.440 N 148 46 40.883 W '' 5884.00 53.10 308.80 5208.00 991.68 -1424.76 5975734.70 650514.44 70 20 26.912 N 148 46 42.617 W 5977.00 53.10 308.40 5263.84 1038.07 -1482.88 5975779.91 650455.40 70 20 27.368 N 148 46 44.315 W 6070.00 52.60 308.40 5320.00 1084.12 -1540.97 5975824.76 650396.39 70 20 27.821 N 148 46 46.012 W 6163.00 53.50 309.10 5375.91 1130.64 -1598.93 5975870.09 650337.50 70 20 28.278 N 148 46 47.705 W ', ~I 6254.00 54.10 310.50 5429.66 1177.64 -1655.34 5975915.94 650280.15 70 20 28.741 N 148 46 49.354 W ', 6346.00 54.30 312.30 5483.47 1226.99 -1711.31 5975964.14 650223.20 70 20 29.226 N t48 46 50.989 W 6440.00 54.00 312.00 5538.53 1278.12 -1767.80 5976014.11 650165.69 70 20 29.728 N 148 46 52.639 W ', 6535.00 53.70 313.70 5594.57 1330.28 -1824.04 5976065.12 650108.42 70 20 30.241 N 148 46 54.282 W 'I ~~ 6627.00 52.30 312.30 5649.94 1380.39 -1877.76 5976114.13 650053.69 70 20 30.734 N 148 46 55.852 W 6722.00 51.80 312.00 5708.36 1430.67 -1933.30 5976163.26 649997.15 70 20 31.228 N 148 46 57.475 W i ' ', 6815.00 50.70 312.30 5766.57 1479.34 -1987.07 5976210.83 649942.40 70 20 31.707 N 148 46 , 59.046 W ' 6910.00 50.30 313.00 5827.00 1529.00 -2040.99 5976259.39 649887.50 70 20 32.195 N 148 47 0.622 W 7003.00 49.30 313.00 5887.02 1577.44 -2092.94 5976306.76 649834.58 70 20 32.671 N 148 47 2.140 W 7097.00 48.30 312.70 5948.94 1625.54 -2144.79 5976353.80 649781.77 70 20 33.144 N 148 47 3.655 W ' ~~ 7192.00 47.60 311.30 6012.57 1672.75 -2197.21 5976399.93 649728.41 70 20 33.609 N 148 47 5.187 W I~! 7276.00 47.60 311.60 6069.21 1713.81 -2243.70 5976440.04 649681.10 70 20 34.012 N 148 47 6.545 W ~ 7380.00 47.90 311.60 6139.14 1764.92 -2301.27 5976489.97 649622.51 70 20 34.515 N 148 47 8.227 W ~ 7475.00 48.00 312.00 6202.77 1811.94 -2353.86 5976535.91 649568.98 70 20 34.977 N 148 47 9.764 W ' 7571.00 47.80 311.30 6267.13 1859.28 -2407.08 5976582.15 649514.81 70 20 35.442 N 148 47 11.319 W 7665.00 47.90 311.60 6330.21 1905.41 -2459.32 5976627.21 649461.66 70 20 35.896 N 148 47 12.846 W I ~I 7759.00 47.60 310.90 6393.41 1951.29 -2511.63 5976672.02 649408.43 70 20 36.347 N 148 47 14.375 W !, 7852.00 47.80 311.30 6456.00 1996.51 -2563.46 5976716.17 649355.70 70 20 36.791 N 148 47 15.889 W ', 7948.00 47.70 311.30 6520.55 2043.41 -2616.85 5976761.98 649301.38 70 20 37.253 N 148 47 17.450 W 8042.00 47.50 311.60 6583.93 2089.36 -2668.88 5976806.86 649248.43 70 20 37.704 N 148 47 18.970 W 8136.00 47.50 310.50 6647.44 2134.87 -2721.14 5976851.30 649195.26 70 20 38.152 N 148 47 20.497 W 8230.00. 47.50 310.50 6710.95 2179.88 -2773.84 5976895.23 649141.66 70 20 38.594 N 148 47 22.038 W 8325.00 47.50 310.50 6775.13 2225.37 -2827.10 5976939.63 649087.50 70 20 39.041 N 148 47 23.594 W ~ ~ 8413.00 47.50 310.50 6834.58 2267.50 -2876.43 5976980.75 649037.32 70 20 39.456 N 148 47 25.036 W ' i~ 8418.00 47.50 310.50 6837.96 2269.90 -2879.24 5976983.09 649034.47 70 20 39.479 N 148 47 25.118 W '. 8608.00 47.20 310.90 6966.69 2361.02 -2985.18 5977072.04 648926.71 70 20 40.375 N 148 47 28.214 W j 8703.00 46.80 310.90 7031.48 2406.51 -3037.70 5977116.46 648873.28 70 20 40.822 N 148 47 29.749 W ii 8796.00 46.30 312.00 7095.43 2451.20 -3088.30 5977160.11 648821.79 70 20 41.261 N 148 47 31.228 W 'I 8891.00 45.70 312.30 7161.43 2497.06 -3138.97 5977204.93 648770.21 70 20 41.712 N 148 47 32.709 W 8985.00 45.30 313.00 7227.31 2542.48 -3188.28 5977249.34 648719.99 70 20 42.159 N 148 47 34.150 W 9077.00 44.50 313.70 7292.48 2587.06 -3235.51 5977292.94 648671.87 70 20 42.597 N 148 47 35.531 W 9160.00 43.90 312.70 7351.98 2626.67 -3277.68 5977331.69 648628.90 70 20 42.986 N 148 47 36.763 W 9255.00 44.30 311.60 7420.21 2671.04 -3326.70 5977375.05 648579.00 70 20 43.422 N 148 47 38.196 W i, 9362.00 44.00 309.80 7496.98 2719.63 -3383.20 5977422.49 648521.54 70 20 43.900 N 148 47 39.847 W ', !, 9455.00 44.00 308.10 7563.89 2760.24 -3433.43 5977462.07 648470.49 70 20 44.299 N 148 47 41.316 W 'I ', 9550.00 44.80 308.40 7631.76 2801.39 -3485.63 5977502.15 648417.47 70 20 44.704 N 148 47 42.842 W li ICI 9642.00 46.50 308.40 7696.07 2842.26 -3537.19 5977541.96 648365.11 70 20 45.105 N 148 47 44.348 W 9737.00 47.40 308.10 7760.92 2885.23 -3591.70 5977583.82 648309.73 70 20 45.528 N 148 47 45.942 W 9831.00 47.80 307.10 7824.30 2927.58 -3646.70 5977625.04 648253.89 70 20 45.944 N 148 47 47.549 W 9926.00 49.00 308.40 7887.38 2971.08 -3702.86 5977667.39 648196.86 70 20 46.372 N 148 47 49.191 W 10021.00 50.20 308.80 7948.95 3016.22 -3759.40 5977711.36 648139.43 70 20 46.815 N 148 47 50.844 W ~' 10115.00 50.80 309.50 8008.74 3062.01 -3815.65 5977756.01 648082.27 70 20 47.265 N 148 47 52.488 W 10208.00 51.10 309.80 8067.33 3108.10 -3871.26 5977800.95 648025.74 70 20 47.718 N 148 47 54.113 W ~, 10303.00 51.20 311.30 8126.92 3156.19 -3927.47 5977847.90 647968.57 70 20 48.191 N 148 47 55.757 W ~~ BP-GDB Survey Report -Geographic Company: BP Amoco __ - --- Date: 3/26/2009 Time: 13:47:35 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) R eference: Weil: F-41PB1, True North Site: PB F Pad Vertical ("fVD) Reference: 44:41 11/28/1991 00 :00 66.0 Well: F-41 PB1 Section (VS) Reference: User (O.OON,O.OOE,310.69Azi) Wellpath: F-41 PB1 __ Survey Calculation Method: Minimum Curvature Db: Oracle ~i Survev __ _ Map Map <---- Latitude ----> <--- Longitude ---> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ft ft ft ft ft 10399.00 51.00 311.30 8187.21 3205.50 -3983.60 5977896.05 647911.46 70 20 48.676 N 148 47 57.397 W j 10494.00 51.20 312.00 8246.86 3254.64 -4038.84 5977944.06 647855.23 70 20 49.159 N 148 47 59.012 W 10590.00 51.00 312.30 8307.15 3304.77 -4094.23 5977993.06 647798.84 70 20 49.651 N 148 48 0.632 W i, 10684.00 50.50 313.40 8366.62 3354.27 -4147.60 5978041.46 647744.49 70 20 50.138 N 148 48 2.192 W 110778.00 49.80 314.80 8426.86 3404.49 -4199.42 5978090.61 647691.66 70 20 50.632 N 148 48 3.707 W ', 10872.00 49.20 317.20 8487.91 3455.90 -4249.07 5978141.00 647640.98 70 20 51.137 N 148 48 5.159 W 10969.00 48.60 319.30 8551.68 3510.42 -4297.75 5978194.52 647591.22 70 20 51.673 N 148 48 6.582 W IC 11059.00 47.90 321.80 8611.62 3562.25 -4340 41 5978245.48 647547.52 70 20 52.182 N 148 48 I 7 829 W 1960.00 47.90 321.80 9215.67 4087.61 -4753 83 5978762.31 647123.57 70 20 57.347 N 148 48 19.920 W ~, ~,b~ Nav o s X007 STATE OF ALASKA ~,~vF'~" ~~~ ALASKA OIL AND GAS CONSERVATION COMM~c~iaska Oil & Gas Cons. Commiss+on REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Abandon ~ Repair Well ~ Plug Pertorations ~ Stimulated Other ~ Brightwater treatment Pertormed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Enhanced oil recovery Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~ 195-o9ao ~ 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-22570-00-00~ 7. KB Elevation (ft): 9. Well Name and Number: 54.1 KB ~ MPE-23 8. Property Designation: 10. Field/Pool(s): ADLO-028231 ~ Milne Point Unit Field/ Kuparuk River Sands Pool ' 11. Present Well Condition Summary: Total Depth measured 13040 ~ feet Plugs (measured) None true vertical 7278 ~ feet Junk (measured) None Effective Depth measured 12932 feet true vertical 7234 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" Surtace - 113' Surtace - 113' Surtace 4209' 9-5/8" 40# L-80 31' - 4240' 31' - 3652' 5750 3090 Production 12996' 7" 26# L-80 28' - 13024' 28' - 7271' 7240 5410 ~t~~ NCV ~ ~ 2007 Perforation depth: Measured depth: Open 12520 - 12620 Open 12706 - 12766 _ `. _ True Vertical depth: 7060.97 - 7103.44 7139.86 - 7165.09 _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# N-80 Surface - 12315' 0 0 - Packers and SSSV (type and measured depth) 7"x3-1/2" baker s-3 packer 12275' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2626 1726 0 Subsequent to operation: 2968 100 2124 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service ~` Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer .~sa~ Si t Ph 4 D t 5 4944 gna ure - one - a e 6 Form 10-404 Revised 04/2006 ~~" ~~~!~ ~ ~ ~~~~ Submit O ' ~nal O ~' "~~° • n Date Time Water bw h Pressure si EC9378 inches EC9378 al Chemical um ed al EC9360 inches EC9360 al Chemical um ed aI COMMENTS Refill 9378 Refill 9360 9/19!200 18:30 105 210 131 9135 158 11078 Start ~ob 9/20/2007 8:00 99 2100 122 8505 155 10868 9/2112007 8:00 98 2100 104 7245 148 10378 Found 9378 pump leak at 15:45. Shut off all chemical and water. Restarted water to flush well bore at 16:15. Shut off water at 17:15. Fixed pump and brou ht back all chemical and water at 18:15. 9/22/2007 2:00 94 2000 93 6493 138 9651 9/23/2007 8:00 98 2000 83 5810 128 8934 9/24/2007 8:00 95 2100 68 4778 120 8374 9/25/2007 8:00 100 2100 53 3675 112 7840 19:30 cut chemical rates and water injection in half due to 9378 um issues. 9!2612007 8:00 60 2100 43 2984 107 7464 9/26/2007 22:00 57 1600 39 2704 6431 104 7298 Refill 9378 at 23:30. 9/27/2007 Pum s down most of the da . 9/28/2007 3:00 103 1960 110 N/A N/A Refill 9378 at 0:30. 9/28!2007 23:30 105 2000 109 7639 100 7026 9378 pump problems at 16:30. Restart pump at 23:00. CHEMICAL SHUTDOWN?? WATER SHUTDOWN?? 9!29/2007 8:00 100 2033 84 5854 98 6878 9/30/2007 8:00 101 2054 86 6046 91 6370 10!1!2007 8:00 102 2065 75 5241 84 5889 Water and chemical shutdown for pigging at 9:35. All back on at 10:05. Problem with 9378 pump at 21:00. Restart at 22:30. WHAT ABOUT THE WATER AT THIS TIME??? 10(2!2007 8:00 103 2100 63 4419 78 5451 10/3/2007 8:00 100 2050 47 3290 71 4961 10/4/2007 10:00 103 2100 37 2599 5040 64 4480 9378 rate low by 50%. Tightened pump prv valve at 12:45. Rate back to normal. 10/4/2007 12:00 104 2100 107 7455 64 4454 Refill 9378 0/5/2007 :00 03 000 7 799 0 174 Shut down all chemical at 2:00 due to 9360 chemical plug/freeze in the supply line. Choked back water injection to 17 bwph. Fixed plugs and brought in heat to 9360 tank, pump, and supply lines. Turned chemical back on and water at 8 bw hat 10:00. Water rate back u at 20:00. 1016/2007 8:00 100 2050 82 5758 52 3649 1017/2007 8:00 98 2050 66 4646 45 3124 10(8/2007 8:00 96 2050 51 3544 37 2581 10/9/2007 8:00 99 2100 36 2485 4970 30 2065 9013 i oral Num etl 16441 9013 Remainder 0 0 t\.c,. IVlr U 11 a\"çl 1 Ç;'l '-" "-'" Tom, We'll definitely plan to keep you informed on the results. Thanks! Jennifer From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, February 27, 2007 3:29 PM To: McLeod, Jennifer D Cc: Ohms, Danielle H; Chesher, James R Subject: Re: MPU Tracer Test 5~NED fEE 2 8 2007 Jennifer, We always appreciate notice of impending "tests". According to AIO 10-B, tracer fluids have been approved for use in the Kuparuk and Schrader Bluff formations at Milne. Since the tracer fluids have been approved, there really isn't a need to seek approval. However some sort of communication seems appropriate to keep the Commission informed. I would disagree about no requirement to report. I'd expect that any tracer results would be reported as part of the the annual report required by 20 AAC 25.432 (2). I look forward to hearing further details. Call or message with any questions. Good luck with the proj ect. T om Maunder, PE AOGCC McLeod, Jennifer D wrote, On 2/27/20073:18 PM: Hi Tom, We are gearing up the planning for pumping Bright Water again this summer in a couple of patterns at Milne Point. To get some information on water breakthrough timing to help size a job in one of the patterns, we are hoping to pump a tracer test i!1 MPE-23i in the next few weeks. This tracer is a benign flourescent dye, the same as was used on the MPB-12i pilot pattern in 2003. If the timing isn't too quick, this will be one of the patterns treated this summer. Since this is not a stimulation, I don't think we have a requirement for reporting, but wanted to keep you informed as the 2007 Bright Water program progresses. Prior to pumping the Bright Water treatments, we plan to submit forms for approval. Please let me know if you have any questions. Thanks! \ ~S -()~~ Jennifer :McLeod MPU Production Engineer 564-5764 I of I 2/28/2007 3 :22 PM ( ~ State of Alaska MEMORANDUM RandY~--- ComtfÍissioner TO: Alaska Oil and Gas Conservation Commission TURU: Jim Regg P.I. Supervisor í«¥, 3/1 5'1 L;4,. { t DATE: Wednesday, March 10,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-23 MILNE PT UNIT KR E-23 FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-22570-00-00 InspN mitCS040309204520 Inspection Date: 3/9/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: E-23 Type Inj. G TVD 6958 IA 0 2000 1950 1950 P.T. 1950940 TypeTest SPT Test psi 1739.5 OA 300 300 300 300 Interval Four Year Cycle PIF Pass Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed and found stable. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SAL T WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=Internal Radioactive Tracer Survey Interval I=Initial Test A=Temprature Anomaly Surve D=Differential Temprature Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Wednesday, March 10, 2004 Page 1 of 1 S(ÇA¡~NE[t1i ¡MAR 1 (! 2004. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / E-pad 03/09/04 Lee Hulme 4 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT MPU E 3-9-04.xls 5CANNED MAR 1 ;¿ 2.00¡~. -"-"' STATE OF ALASKA ""~" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repeir well _ Ot-her_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorac, le, AK 99519-6612 4. Location of well at surface 1545' FNL, 1830' FEL, Sec. 25, T13N, R10E, UM At top of productive interval 3754' FNL, 3547' FEL, Sec. 29, T13N, R11E, UM At effective depth 3833' FNL, 3283' FEL, Sec. 29, T13N, R11 E, UM At total depth 3859' FNL, 3187' FEL, Sec. 29, T13N, R11E, UM 5. Type of Well: Development __ Explorato~._ Stratigraphic._ Service__X (asp's 569315, 6016273) (asp's 578149, 6014151) (asp's 578414, 6014075) (asp's 578510, 6014050) 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Milne Point Unit 8. Well number MPE-23 9. Permit number / approval number 195-094 10. APl number 50-029-22570-00 11. Field / Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4209' Production 12996' 13040 feet Plugs (measured) 7278 feet 12932 feet Junk (measured) 7234 feet Size Cemented 20" 250 sx Arcticset I (Aprox) 850 sx PF 'E', 250 sx 'G', 9-5/8" 150 sx PF 'E' 7" 540 sx Class 'G' Measured Depth True Ve~icalDe~h 113' 113' 4240' 3652' 13024' 7271' Perforation depth: measured Open Perfs 12520'-12620', 12706'-12766' true vertical Open Perfs 7061'-7104', 7140'-7165' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, N-80 Tubing to 12315'. 7" x 3-1/2" Baker S-3 Packer @ 12275'. No SSSV in well. ;;{ECEIVED MAR $ 2003 Alaska 0il & ~am Cam. Cc."~i0n A.,~.~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/16/2003 Subsequent to operation 02/20/2003 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 2023 3386 Casing Pressure Tubing Pressure 3170 2413 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~~/~_ ~.-_--" Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · RBD IS BFL ORIGINAL Date March 07, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE MPE-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/17/2003 WAG SWAP: GAS TO WATER INJECTION EVENT SUMMARY 02/17/03 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUED FLANGES TO SPEC. SERVICED TREE AND FLUSHED SENSING LINES. MIRU FESCO. PT'd TO 4600 PSI. PUMPED DOWN THE TUBING 5 BBLS METHANOL, 3500 PSI @ 1.4 BPM, AND 80 BBLS SOURCE WATER, 3500 TO 2600 PSI @ 2.0 BPM, THEN CAPPED WITH 2 BBLS OF METHANOL. RDMO. TURNED OVER TO OPERATOR TO PUT ON INJECTION. WELL WAS SWAPPED TO WATER AND PUT ON INJECTION @ 3000 BPD. FLUIDS PUMPED BBLS 7 METHANOL 80 SOURCE WATER 87 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1545' FNL, 1830' FEL, Sec. 25, T13N, R10E, UM At top of productive interval 3754' FNL, 3547' FEL, Sec. 29, T13N, R11E, UM At effective depth 3833' FNL, 3283' FEL, Sec. 29, T13N, R11E, UM At total depth 3859' FNL, 3187' FEL, Sec. 29, T13N, R11E, UM 5. Type of Well: Development __ Explorato~ Stratigraphic__ Service__X ~sp~ 56931~ 6016273) (asp's 578149, 6014151) (asp's 578414, 6014075) (asp's 578510, 6014050) 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Milne Point Unit 8. Well number MPE-23 9. Permitnumber/appmvalnumber 195-094 10. APInumber 50-029-22570-00 11. Field / Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical 13040 feet Plugs (measured) 7278 feet Effective depth: measured 12932 feet Junk (measured) true vertical 7234 feet Casing Length Size Cemented Conductor 80' 20" 250 sx Arcticset I (Aprox) 850 sx PF 'E', 250 sx 'G', Surface 4209' 9-5/8" 150 sx PF 'E' Production 12996' 7" 540 sx Class 'G' Measured Depth True VerticalDepth 113' 113' 4240' 3652' 13024' 7271' Perforation depth: measured Open Perfs 12520'- 12620', 12706'-12766' true vertical Open Perfs 7061'-7104', 7140'-7165' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 Tubing to 12315'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 12275'. No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/20/2003 Subsequent to operation 01/30/2003 OiI-Bbl 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Representative Daily Averaqe Production or Iniection Data Gas-Mcr Water-Bbl 2631 1088 I16. Status of well classification as: Suspended __ Oil __ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWar/ne R Schnorr sC/ NNED l gR 0 ? 2003 Form 10-404 Rev 06/15/88 · Casing Pressure Tubtng Pressure 2331 Sen/ice WAG INJECTOR 3506 Date January 31, 2003 Prepared by DeWayne R Schnorr 564-5174 SUBMIT IN DUPLICATE MPE-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/16/2OO2 07/1 O/2OO2 08/10/2002 01/23/2003 WAG SWAP: WAG SWAP: WAG SWAP: WAG SWAP: GAS TO WATER INJECTION WATER TO GAS INJECTION GAS TO WATER INJECTION WATER TO GAS INJECTION EVENT SUMMARY 05/16/02 WELL SUPPORT SWAPPED BLINDS AND TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 20 BBLS METHANOL FOLLOWED BY 90 BBLS SOURCE WATER. THEN PUMPED 20 BBLS METHANOL. PUMPED @ 2.5 BPM FROM 2600 TO 1600 PSI. WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. 07/1 O/O2 WELL SUPPORT TECHS SWAPPED BLINDS, FLUSHED SENSOR LINES, AND GREASED TREE. ALL FLANGES WERE TORQUED TO SPEC. HB&R RIGGED UP AND PUMPED 2 BBLS METHANOL DOWN THE WATER LEG AND PUMPED 20 BBLS METHANOL DOWN THE TUBING. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON INJECTION. 08/1 O/O2 WELL SUPPORT TECHS RIGGED UP AND GREASED VALVES, FLUSHED SENSOR LINES, AND SWAPPED BLINDS. ALL FLANGES WERE TORQUED TO SPEC. HB&R RIGGED UP AND PUMPED FROM 1.5 TO 2.3 BPM FROM 3500 TO 4050 PSI. SWITCHED TO SOURCE WATER, PUMPED 88 BBLS. PUMPED @ 2.5 BPM FROM 4050 TO 4100 PIS. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. 01/23/03 WELL SUPPORT TECHS SWAPPED BLINDS, FLUSHED SENSOR LINES, AND GREASED TREE. ALL FLANGES WERE TORQUED TO SPEC. HB&R RIGGED UP AND PUMPED 2 BBLS METHANOL DOWN THE WATER LEG AND PUMPED 20 BBLS METHANOL DOWN THE TUBING. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON INJECTION. FLUIDS PUMPED BBLS 97 METHANOL 178 SOURCE WATER 275 ~TOTAL CANNE[ 0 ? 2003 Page I TREE' 31/8" - 5M FMC WELLHEAD 11" 5M FMC, Gen 5 w/ 11" FMC Tubing Hanger, 3 5" NSCT hft threads, 3" CIW 'H' BPV profile 20" 91 1 ppf, H-40 ~ KOP @ 1400' Max hole angle 63 - 68 deg. f/4050' - TD 9 5/8", 40#/ft, 14240' L-80 Btrc 3.5 9.3 ppf, N-80, mod. 8rd. (capacity = 0.0087 bpf) Stimulation Summary Perforation Summary Ref Ioq: 08~22~95 SBL / CCL 2.0" /4 12,520'-~2,620'17061'-7104') Alpha Jet charges @ 0 deg. phasing decentrahzed, EHD = 0.28", TTP = 12.2" MPU E-23i ORIG. DF ELEV = 54.1' (N 22E) ORIG GL. ELEV = 24 9' (N 22E) RT To 7" csg hng. = 28 5' Halliburton "ES" Cementer Radioactive Marker @ 12,352' wlm 22.5' Short Joint (12,366'- 12,388' md) Baker S-3 Packer I 12,275' I HES 3.5" "XN" Land,ng I 12,302, I Npl. (wi 2.813" ID w/2.75" No- WLEG ~ EO [ 12,315,I ORIG. PBTD ~ 7" 26#, L-80, ~ BTRS DATE 09/13/95 COMMENTS Completion by N 4ES MILNE POINT UNIT WELL E - 23i APl NO: 50-029-22570 BP EXPLORATION STATE OF ALASKA ALASK/ _ AND GAS CONSERVATION COMf REPORT OF SUNDRY WELL OPERATION'S 31ON 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Fill Clean Out 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 53.55' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3735' NSL, 1830' WEL, SEC. 25, T13N, R10E MPE-23 At top of productive interval 9. Permit Number / Approval No. 195-094 1525' NSL, 1733' EWL, SEC. 29, T13N, R11E 10. APl Number At effective depth 50-029-22570 1452 NSL, 1997' EWL, SEC. 29, T13N, R11E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1426' NSL, 2091' EWL, SEC. 29, T13N, R11E Sands 12. Present well condition summary Total depth: measured 13040 feet Plugs (measured) true vertical 7278 feet Effective depth: measured 12933 feet Junk (measured) true vertical 7234 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 4209' 9-5/8" 850 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 4240' 3652' Intermediate Production 12996' 7" 540 sx Class 'G' 13024' 7271' Liner Perforation depth: measured 12520'-12620'; 12706'-12766' !i~? !:'~ {~" · ~., true vertical 7061'-7103'; 7140'-7165' Tubing (size, grade, and measured depth) 3-1/2", L-80 to 12315' Packers and SSSV (type and measured depth) Baker S-3 Packer at 12275' Anch0r;L,:j0 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure i4. '""Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water & Gas Injector [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed MichaetW,II,arns~~~y~ Title TechnicalAssistant Date ' : : :: : : Prepared By Name/Number: DeC/Va;ne/Schn'orr 564-5174 ~ ..... .. Submit In Duplicate Form 10-404 Rev. 06/15/88 ORIGI AL MPE.-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/14/2000 FCO SUMMARY MIRU DS CTU #3. WEEKLY BOP TEST. PIPE RAMS WOULDN'T TEST. BREAK INJECTOR OFF, INSPECT PIPE. PIPE IS DAMAGED WHERE PIPE RAMS CLOSED. RD BOPS. SET TREE CAP AND PUT WELL BACK ON INJECTION WHILE REPAIRING BOPS. WIND COMING UP. PREPARE UNIT FOR THE UPCOMING STORM. SDFN. FINISH REPAIRS TO SLIP RAMS. RU ON TREE. PT AND BOP RAM TEST. OK. PU 2.5" JSN. RIH WHILE CIRCULATING WATER FROM 1000' (WING SHUT IN - NO RETURNS). CIRC DOWN TO 12900' (NO TAG). DID NOT ENCOUNTER ANY OBSTRUCTIONS. ACID WASH FROM TT TO 12766' WITH 15 BBLS 15% HCL/10% XYLENE. DISPLACE WITH WATER. POH, RD DS CTU #3. RETURN WELL TO INJECTION. [FCO] Fluids Pumped BBLS. Description 33 60/40 MEOH 55 MEOH 280 1% KCL (DOUBLE SLICK) 15 15% HCL/10% XYLENE 383 Total 9 ~-,,- 09Z~,~. 95 .... 09,~,~ 95-.- 09t, ,..) 95 ....09 ~ AOGCC Ind-iv-¥dua'i Vteii Geolo,;;j'ica] i'4ater"iais Invenf::or"y DATA T DATA_.F'L, US 6823 "~' 10655~ i2876 GR CCL CI&~{ ~:,~.~.) ~ 12125 .... 1289,~ DIFF TEHF' GR/CCL~ '123L~i--12920 .Lc..I.~12i88-.~12892 ~i0700'--12906 GR/CrdL JEWL LO S B T / ,S R/' C C: L /~L.~ ~:TAT PRESSURE.) .'I 0--'-z~ 0 7 Z.--R COHPL ETZOi'..] [:,ATE ~/' /.~ r"e V./a s d r' y t: h e DALLY V/ELL OPS OR' 7/'0//q'37 TO d~tch samples r'equ~r'ed°~ '/es _~_~.~.And r"ece'ived well eot'ed? y e s ~____._~A n a 1 y s '¥ s & d e s c r' 'i p t '¥ o n r" e c e i' v ,:!-.: d '.:' r ::-.u - ."- Ar'~s W e 'i '1 weil 't;es'?..s r"equ'ir'ed? ti,/es 'is 'in cornpl"iance I n-i t 'i a ] C 0 H H E iq T S I~ Rece'¥ ved'? y e s ---m"t~.~ - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . ELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E]< WAG injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-94 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22570 4. Location of well at surface 9. Unit or Lease Name At Top Producing Interval ~ IL;"-' ~' ~'~,F|¢"~ 11 10. Well Number At Total Depth ! ~~-'~ ~ Mi/ne Point / Kuparuk River Sands 1426' NSL, 2091' EWL, SEC. 29, T13N, R11E ........... ~ 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.55' I ADL 028231 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/01/95 07/11/95 09/05/95 N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set ~1. Thickness of Permafrost 13040'MD/7278'TVD 12933'MD/7234'TVD YES [] NO []I N/A feet MD' ! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, CDR/CDN/GR/CCL/SBT/CNP, MWD, L WD 23. CASING, UNER AND CEMENTING RECORD SE'l-riNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 4240' 12-1/4" 850 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26# L-80 28' 13024' 8-1/2" 540 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 3-1/2", L-80 12315' 12275' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12520'-12620' 7061'-7103' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12706'-12766' 7140'-7165' Freeze protect w~ 72 bbls diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I 12/27/95 l injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. 0RIGINALRECEIVED JUL 1 2 199G Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE I 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) TKUP 12103' 6833' TKUC 12372' 6944' TKC 1 12509' 7002' TKUB 12632' 7054' RECEIVED JUL 1 2 1996 Alaska 011 & f~ Cons. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~"'~~l' Title $oniorDrillinaEnaineer Date '"7/'~-'A~;' · 1/ - _ / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 _.riP, ED SERVICE DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: MP E-23 NORTH SLOPE UNKNOWN UNKNOWN 50- ACCEPT: 06/30/95 05:00 SPUD: 07/01/95 03:00 RELEASE: 07/13/95 11:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 4ES 07/01/95 (1) TD: 270' ( 0) 07/02/95 (2) TD: 2782' (2512) 07/03/95 (3) TD: 4260' (1478) 07/04/95 ( 4) TD: 4260' ( 0) 07/05/95 (5) TD: 4872' ( 612) 07/06/95 ( 6) TD: 6488' (1616) DRILLING MW: 0.0 VIS: 0 LEVEL RIG/ACCEPT RIG @ 1700 HRS. NU DIVERTER. FUNCTION TEST. BOBBY FOSTER W/AOGCC WAIVED WITNESSING. SPUD & DRILL F/l12 T/270. DRILLING MW: 0.0 VIS: 0 DRILL T/1926. CBU. DRILL T/2261. CBU INCREASE THE MUD WT T/ll.4PPG. DRILL T/2782. SHORT TRIP MW: 0.0 VIS: 0 DRILL T/3069. CBU. DRILL T/3934. COULDN'T SLIDE. CBU & MIX PILL. POOH MOTOR LOCKED UP. MU NEW MOTOR. SERVICE THE TOP DRIVE. TIH & DRILL T/4260. CBU. SHORT TRIP T/CHK HOLE. NU BOPE MW: 0.0 VIS: 0 CIR & COND MUD. POOH LD BHA. RU CASG EQUIP. RUN 9-5/8" 40# L-80 BTC CASG T/SHOE @4240. CIRC & COND. MUD @ 15 BPM W/1000PSI & NO LOSSES. TEST LINES T/3500PSI. PUMP 70 BBLS SPACER. MIX & PUMP 850 SXS "E" @ 12. PPG. TAIL W/250 SXS "E" @ 15.8 PPG. PUMP 10 BBLS WATER & DISPLACE W/RIG PUMPS @ 15 BPM W/1000PSI. BUMP PLUG T/3000. FLTS HELD. CIP @ 2100 HRS. LD LND JT. ND DVRTR. RU & PUMP 150 SXS TOP JOB. INSTALL CSG HEAD & TEST PACKOFF. NU BOPE. DRILLING MW: 0.0 VIS: 0 RU & TEST BOPE 250/5000. NO INSPECTOR WAS ON THE SLOPE. UPPER & LOWER IBOP VALVE FAILED. CHANGE OUT. RU & RE-TEST. OK. MU BHA %3. TIH TAG FC @4152. CIRC & TEST CSG T/3000/30 MIN. DRILL FC, FS & 10' NEW HOLE T/4270. POOH MW: 0.0 VIS: 0 DRILL T/5349. SHORT TRIP T/SHOE. OK. DRILL T/6488. CBU. RU & RUN GYRO. CBU. POOH * DOWNLOAD CDR & LD MOTOR. RECEIVED JUl_ 1 2 199G Al~i~k~ 011 & ~ Oo~. Commi~,gim~ · MP E-23 _~TION: RIG : NABORS 22E PAGE: 2 07/07/95 ( 7) TD: 8055' (1567) 07/08/95 (8) TD: 9650' (1595) 07/09/95 (9) TD: 9778' ( 128) 07/10/95 (10) TD:l1830' (2052) 07/11/95 (11) TD:13040' (1210) 07/12/95 (12) TD:13040' ( 0) 07/13/95 (13) TD:13040' ( 0) 07/14/95 (14) TD:13040' ( 0) DRILLING MW: 0.0 VIS: 0 MU BHA#3, TEST ORIENT & RIH T/4183. CUT/SLIP DL & SERVICE THE TOP DRIVE. BENCHMARK SURVEY @5644 TIE-IN W/GYRO. DRILL T/8055. DRILLING MW: 0.0 VIS: 0 DRILL T/9236. CBU. DRILL T/9650. TRIP IN HOLE MW: 0.0 VIS: 0 DRIL T/9778· POOH T/CASG SHOE. NO HOLE PROBLEMS. REPAIR SCR PROBLEM. POOH & DOWNLOAD & INSPECT BIT. MU BHA. TEST MWD TIH. TAKE BENCHMARK SURVEY TIE-IN @ 5644. DRILLING MW: 0.0 VIS: 0 DRILL T/11830 DRILLING MW: 0.0 VIS: 0 DRILL T/11903. CBU. DRILL T/13040. TD. REACHED. RUN CASING MW: 0.0 VIS: 0 CBU. POOH LD DP.DOWNLOAD LWD. RU CASG EQUIP & RUN 7" 26# L-80 BTC. CBU MW: 0.0 VIS: 0 CIRC & CONDITION MUD F/2ND STAGE CMT. LOST 10 BBLS OF FLUID T/FORMATION. RELEASED RIG MW: 0.0 VIS: 0 CIRC AND CONDITION MUD FOR 2ND STAGE CEMENT JOE. PUMP 20 BBLS H20, 70 BBLS 11.6 SPACER, 310 SX CEMENT. DISPLACED W/ 75 BBLS DIESEL AND H20. BUMP PLUG. PRESS CSG TO 2500 PSI TO CLOSE ES CEMENTER. BLEED OFF PRESSURE. RD HALLIBURTON CEMENT HEAD. LD LANDING JT. INSTALL HANGER PACKOFF. WOULD NOT TEST. PULL PACKOFF. RELEASE. SET SCREWS ON JUNK RING. REINSTALL AND TEST. MU HANGER W/ 2 WAY CHECK. INSTALL SAME. TEST. ND BOPE. NU ADAPTER FLANGE AND TREE. HANGER NOT COMPATABLE WITH ADAPTER. PORTS DO NOT LINE UP. HANGER IS BORED WRONG. TEST. HANGER WILL BE REPLACED DURING COMPLETION. TEST ADAPTER AND TREE. FINISH PIT CLENAING. FREEZE PROTECT E-23 ANNULUS W/ 75 BBLS DIESEL. FREEZE PROTECT E-20 ANNULUS W/ 120 BBLS DIESEL. SECURE WELLS. RELEASE RIG 2300 HRS ON 07/13/95. · MP E-23 .~ZION: RIG : NABORS 4ES PAGE: 3 08/19/95 (15) TD:13023 PB:12933 08/20/95 (16) TD:13023 PB:12933 08/21/95 (17) TD:13023 PB:12927 08/22/95 (18) TD:13023 PB:12927 08/23/95 (19) TD:13023 PB:12933 08/24/95 (20) TD:13023 PB:12933 RU TO TEST BOP MW: 0.0 MOVE RIG L-PAD TO E-PAD. ND TREE & ADAPTER FLANGE. NU BOP & ADAPTOR FLANGE,CHANGE TO 3-1/2" RAMS. PULL HANGER & RU TO TEST. PU 3-1/2" DP MW: 0.0 TEST BOP HYDRIL 3500~. TEST RAMS,LINES & VALVES 250#-5000#. PULL TEST PLUG. INSTALL WEAR RING. PU BOTTOM HOLE ASSY & 3-1/2" DP T/2000'. DISPLACE DIESEL CAP WITH SOURCE WATER 5BPM. CONT TO PICK 3-1/2" DP,TAG CEMENT STRINGER @ 6546. DRILL CEMENT & ES CEMENTER 6546-6577· TAG ES CEMENTER 6559. WASH THRU CEMENT STRINGERS 6577-6763. CONT TO PU 3-1/2" DP. TEST CASING MW: 0.0 SERVICE RIG. CONT TO PU 3-1/2" DP. TAG SHUT OFF COLLAR 12927. CIRC MIX & PUMP 3,40 BBL XANVIS SWEEPS UNABLE TO GET CLEAN RETURNS. CLEAN PITS. TAKE ON 700 BBLS 8.4 SOURCE WATER. DISPLACE WELL WITH CLEAN FLUID. TEST CASING T/3500#. LOST 200# IN 30 MIN. ISOLATE PUMPS & STANDPIPE. RE-TEST. RUN SBT/GR/CCL MW: 0.0 TEST CASING T/3500# FOR 30 MIN. OK. SERVICE RIG. TOH LD 3-1/2" DP. PULLED 50K OVER 9663. CBU. CONT LD DP & BHA, 5 TO 30K OVER PULL. BLADE MISSING FROM 7" CASING SCRAPER. RU WESTERN ATLAS. RUN 6" JUNK BASKET & GAUGE RING. PUSH JUNK F/9200 T/10580. COULD NOT GET BELOW 10580. POOH RECOVERED SCRAPER BLADE, 5 SPRINGS & 4"X4" PIECE OF ES CEMENTER. ADD ROLLER & RERUN 6" JUNK BASKET & GAUGE RING. LOGGERS TD 12914. POOH RECOVER KEEPER 2 BOLTS & SMALL PIECES ES CEMENTER. RUN SBT/GR/CCL. RIG TO FREEZE PROTECT MW: 0.0 FINISH RUNNING SBT/GR/CCL. RD WESTERN ATLAS. TEST 7" CASING T/3500~. OK. PULL WEAR RING. RU FLOOR TO RUN TUBING. RUN 12314' 3.5 EUE MOD TUBING, BAKER S-3 PACKER, DOPE W/ SEAL LUBE. MU HANGER, LAND TUBING. ND BOP. NU ADAPTOR FLANGE & TREE. TEST PACKOFF,ADAPTOR FLANGE & TREE T/5000#. RU TO FREEZE PROTECT. TEST LINES T/4500#. RELEASED @ 1800 HRS,8/23 MW: 0.0 CIRC 252 BBLS SOURCE H20 WITH 25 GAL, 100 BBLS COREXIT 7726 DOWN ANNULUS WITH RETURNS OUT TUBING @ 3 BPM W/500 PSI. WO DIESEL FOR FREEZE PROTECTION. CIRC 72 BBLS DIESEL DOWN ANNULUS. U-TUBE TO TUBING. DROP PACKER SETTING BAR. SET PACKER & TEST TUBING T/4500 PSI FOR 30 MIN. OK. BLEED TUBING T/1500 PSI & TEST ANNULUS T/3500 PSI FOR 30 MIN. OK. WITNESSING OF MIT TEST WAIVED BY JOHN SPALDING,AOGCC FIELD INSPECTOR. SET BPV. RD & SECURE CELLAR. RIG RELEASED @ 1800 HRS.,08/23/95. PRUDHOE BAY DRILLING WELL: MPE-23 AFE NUMBER: 330131 JOB NUMBER: 36299 OBJECTIVE: 9453 FT. @ 103.87 AZ. Page 4 TRUE SUB-SEA SURVEY MEASURED COURSE DRIFT DRIFT VERTICAL VERTICAL VERTICAL NUMBER DEPTH LENGTH ANGLE DIRECTION DEPTH DEPTH SECTION N/S E/W DLS 59 11616 94 66.4 105.00 6689.42 6635.32 8163.82 1973.31S 7921.76E 1.02 60 11711 95 66.3 103.70 6727.53 6673.43 8250.84 1994.88S 8006.06E 1.26 61 11802 90 66.1 104.90 6764.09 6709.99 8333.72 2015.35S 8086.39E 1.23 62 11901 99 65.8 104.60 6804.56 6750.46 8424.39 2038.44S 8174.08E .41 63 11997 95 65.9 104.20 6843.51 6789.41 8511.26 2060.04S 8258.22E .40 64 12091 94 66.0 105.50 6881.86 6827.76 8597.17 2082.07S 8341.28E 1.27 65 12186 ~ 95 65.6 105.00 6920.80 , 6866.70 8683.80 2104.86S 8424.88E .64 66 12280 ~4 94 65.4 105.10 6959.99 ~9 6905 89 8769.77 2127.19S 8507.92E .23 67 12376 96 65.2 105.10 7000.19 6946.09 8857.15 2149.96S 8592.30E .21 68 12468 9] 64.8 105.00 7038.85 6984.75 8940.06 2171 . 49S 8672 . 38E .45 69 12562 94 64.9 105.90 7079.06 7024.96 9025.66 2194.30S 8754.92E .87 70 12656 93 64.9 104.60 7118.64 7064.54 9110.12 2216.52S 8836.43E 1.26 71 12750 94 65.2 105.10 7158.50 7104.40 9195.79 2238.48S 8919.25E .57 72 12847 96 65.4 106.20 7198.74 7144.64 9283.23 2262.08S 9003.49E 1.06 73 12943 96 66.0 105.40 7238.62 7184.52 9371.50 2286.13S 9088.47E .97 The following is a projection - 74 13038 94 66.3 105.56 7276.60 7222.50 9457.56 2309 .lis 9171.44E .44 Final Station Closure Distance: 9457.65 Feet; Direction: 104.13 Hu: 1 RECEIVED JUL 1 2 1996 Alaska 011 & 8.~s Cons. Commission Anchorage EX-W. ft ft 0,00 0 "'" 0,07 0,25 O ':"" 0,57 ~ ~._., -' .' ;., AZi~]TH de9 163,47 t-_51,27 NS, 10 DLS de.g/ 100ft O,OO 0,37 0.2? ,r, ...... 700,00 !00.~0 6??.9? 800.00 !(:~.~0 ..-,/-..-..-- r. a r. ~, ..-. r,~::-, ~:'? '.'Y ;./;j ~ tjiJ i~.)':-." + V ~77+7/ i,%,0.~©0 16<),0 c;5=~, 97 i,77 0+~.~ ....... 2+!4- · . :='T/ ~QC; - . 2 ~ n,70 '"" :' "-- ~_-v v i£v,,.,'t -Z +/[." 3.o,": 0 ,60 10!,3.5 -3,!2 4,72 O,,B3 i OO, ,:':,/, -3 6,13 0,58 i2~,,42 - '-.:, ""'": .2 .... rr. " f'~.97 i, '""' Z,_,v I ,.9.B 3,35 143,~3 0~42 3+0! z~,34 135,96 0,24 ~,~z 5, "":", 125,?~, A .--, : ~, ,:. __ v+'/¢' =' '-'¢' A,55 124,67 0,35 2,¢7 . i!00~00 i300,00 1400,00 15CX).O0 100~0 !097,% I~>~,0 .~oo ,-,, i00,© !?P?,% iC<~O !399~95 .. ~,t,~/ 7,75 0,57 E5-,43 -3,77 7,05 7,99 i18,15 0.24 ~,~Oz O,.2L ~o,~ ~,~,v' !~./Z ~.,44 a.~,~ .... 8,73 0,27 .._,..,~':-;~ -3,27 ~,~ '~ 8,~! iN,?~_ . 0,25 !600+00 !7:E>,O0 2000~00 iOO,O !599+63 lOO,O !499.05 IQ?+O i796131 !00,0 !897+07 !00,0 i8,88 5~) !04,45 %+97 !7,97 !8,94 108,36 7v,:4~ .... 6,73 t07 "= -9,0~_ ~7 ,%'.o .... -' 41 1c)7.98 ~.44 .... .7~ /7. .. 4i,68 7,52 ilh..~, A~.,~ -~,!9 __ qo,A2.=, ... 4!,Al~. 108,39 0.86 -15,oc; /~,~0 13,3~ I00+63 -z~,J: /J,~: //,~ 108,24 3,72 2400,C4 25C~3,00 100,0 20'9i~80 .. !¢<).0 2378,47 !00,71 .... -' ~ -33.14 ' 1, .~ 157.v4 7 ~ ,, -36,79 ,70,w :~.18 97,40 ~:~,~,., 23.40 9~,97 98,30 102.47 !06,41 2,05 ~:,0, kY,Jo 104,85 1,l~ 153,60 157,94 103,47 1.50 i85,62 190,08 102,44 2,68 ~,35 227.1i 10i,75 3+27 2700 28<×) uYJ 2900.00 i¢<;,0_ 25S!.M ,. 269,20 !00~0 ~-~' ~' I~2'.0 ~r,~ ,~ 477.72 _ 26.79 .. 98.88 _-52,84 264,24 ..269,47 29,25 79,73 -60,45 310,59 316,42 31,~ I02,94 ~. o ............... 33,9A. .~,~ ~n~ ~ -8i,47 4i2,48 . 490,As 26,40 10t,19 -92,50 4A9,:o 4,8,~ 10t,31 10!,01 101,06 10!,17 101,15 2,49 2,57 2.93 2,45 3100,00 I00,0 , ..... = =o:, , 2.',oi.%, · .. ,_v:, ,,.,v 1 CC..:, 0 , .i..~ z.,q-:, vi 3",.n,,.~. n,,,) I00.0 3130,60 672,11 · 3400, ~) I(~-~, 0 32<0,53 743,56 35C0.C0 i00,0 3267,28 818,CQ ~?.08 Im',!5,,,_ -104,90 41,~4 i03,!6 -i!9,13 "" -135,70 1'-..I , 4:.~,~, '* !~,60 -154,47 49,42 I02,5! -172,51 52-5',16 5~',46 101,21 2.74 592.48 604.33 :.,.,~,'nl <72,g~- 658,79 672.62 101.64 2,79 727.75 743,96 101,98 2.50 777,97 818,~6 102,17 3,46 4000,00 !C~%0 3~0,58 895.40 100,0 33%.09 9~.70 !00,0 2.445,91 1058,61 ltr., A 3497,69 i144.11 100,0 3545,8'2; 123!,75 52.05 105.82 -191,47 54,90 105,96 -213.50 ~,~ 105.60 -2~.0S 44),39 105,55 -259,02 62.~? 1¢,q.58 -281,80 87S,00 875,71 102,34 3,67 952.28 975,~ 102,64 2,85 1032,12 1058,77 102,88 2,3S 1!14,51 1144,22 103,~, 3,16 1!99.16 1231,83 !03,22 1 '"" .7rd M~A£L~D !HTE;,'VA£ V?.RTiC-AL D~TH ft ft ft ~. ~ ~., ~. ~. . ~J'/:J ~ 7~ 42~h~<> 1~,0 ~.24,0i 43~0~00 104,0 3677,76 447X~00 100~0 3722,i4 =,,n ,-~ ~CO~n 3765,96 T~RG~ STATION AZIMdTH ft deg ~ i320.% 64,Z7 !02,3'? 1411+1~ M.69 101,89 i5Ol ~06 6~,42 102~69 .... . 1 ,)4 ,~ deg 10~ 103.17 103, Ii 103,!4 DLS Oeo/ lOOft 2.93 0,62 1.46 1,47 0.62 · ,,v.,: 6n,66 ~n, tF~':.O 3652,60 ~:~r, ~n ~,3.87 "' i00.0 3~97,21 I~50.16 63.15 i04,55 i00,0 3943,24 2036.89 62,C~ i06,61 i00.0 3987,00 2i28.~ ~6.05 107 -406.56 1723.50 1770.30 103~27 -43~,~) !809.91 1860.76 !03,42 -455,90 !~96.t6 i~50.20 103~52 -479,73 !98!,67 2036.9! 103.61 -506.!7 2067,5? 2i28,64 103,76 2.56 0.79 1,82 2.14 4,10 5200,00 5300,00 5400,00 ~.~ 0 ..... 4C45.66 231!.96 A7.~7 109.49 t00+0 4i0R.69 2404.!5 A7,~A ,.~? =z __ . ~zzv.v_, 103,92 -563,83 2242,!8 231i,98 1C4,12 -620.33 2417.33. 2495,65 lrM,?? -~,!4 244.3,39 :J:!,8~ lo4,4~ 0.7E' 1.7& 2,46 1.36 5460,00 5580.00 30.0 4i~4,37 26~4.26 64,.54 107,3i 30.0 4220~09 2~8.37 ~4.82 107,4B %35,79 *-,,. ~ o~q~ ~ ltM,44 Z4,.,?,5: ~aav~v_, ~. . _ _ ~4.~.~¢ ~,26 104,46 -65i.60 ~o~,,J?~="* =.-. 2^n4.42.= 104.49. -&~7,56 2>-7.3,~ 2654,57 1~,54 0.84 2.33 2.54 2.09 56!0 5640,00 30.0 4232,82 2685,50 30,0 4245,41 27i2,7i 65,47 165,72 ~.O 4257,D 2739,99 65,73 106.59 30,0 4270,!0 Z767,[~ 65,86 104,~. 503,0 4282,39 2794.70 65.W 1(4.05 -6/~: 2599.36 zo~.7~ 104,57 ~ ~5 2A29,~9 2712,92 104.59 -67i,15 2651.(J 2740.~ 104,61 -698,57 2677,96 2767,58 104~62 -7C5,87 2704.34 2794,94 104,63 2,68 1,~ 0.96 3,57 57%,00 54D.00 5650,~ S<.~,0 4~7.20 2M9,31 30,0 4319,6~. o~l =? e-,-~ L*J¢; 4~2,42 2903,72 30,0 ~"~- ~ 29~30,8:) 65,%~ 65,56 M,51 64,47 - I05,66 105,94 104,26 i03,33 - ~713.20 -720,43 -727,~. -7~,94 -741 Z730.~.6.. 2-322+27 2756,99 2849.57 2783.24 28.76.M · /~9, .6 2904.~Fo 2~ ~' 2931,07 _ 104.M 104,64 104.66 104,66 I04,65 3,17 1,92 1,30 5,64 2,80 5910.00 '~ *' 5940.00 30.0 4371 5970.6~ 30,0 60v0,0o ~,0 4:~7,47 6113,49 1t3.5 ~3.10 ~,6 : 4528.~ ~,63 96,5 A~1,47 ,0.~.,0 97.8 2957,90 Dll,88 N~38,85 3141.28 ~26.Z7 :~12,12 S~59,08 35_,46,62 64,~ :*J,q. VO 63.96 64,t4 63'45 64.,13 63,I9 103,20 103,95 102,48- 103'07 102,16 101,20 101,49 i01.26 -747,6i 2862,13 2958,16 104,64 -753.54 2888.52 2965.!? 104.62 -~9,Q7 2x~14,91 5~12,13 104,60 -765,02 2941,~ 3039,08 104,58 -78~,44 3040,~ 3141.50 104,54 -D7,23 3i23,85 ~26,46 104,49 -826,01 3207,64 3312,29 104,44 -843.53 3292,28 !r3%,62 1~.37 -8~,46 3~1,74 ~59,I? !04,32 -&72.74 3437,64 ~_'-546.70 104,25 0.69 1,71 7,22 1,34 0,71 1,~ 0,93 0,80 0,91 7i36,0/? / ,:Z ..-- 7325,84 75i6. 76!0.8,.5 7707,94 8i82,77 8469,07 9043,08 9232,03 932B,~4 9423.~ %19,72 76,15,39 9711.65 9~7,51 "10188,15 102~,68 TA~E? S?ATiC~ Ali~4~fi LATITUDE S£CTiON IN~LH. N/-S ft deg ~eg ft 3630~83 62,% !0i,63 -8~9,46 3714.76 62.75 102.i9 ~e, ou. ~4 ~3 ~o i02,93 -925,$~ .... ~- ~,.,~ . . - 3806,10 65,71 103,42 -944,95 94~9 4692,~'~ 93,4 4930,29 96,4 4969,&~ 95,7 5008~40 55.3 5047,~ 4146,15 65,74 I04,37 -1007,40 4234.~A 66.11 103.61 -~n~ ~ 4321.69 ~4.07 104.36 -i049.81 4,~=.o~ 66.03 103.i0 -~070.49 97.1 5125,44 94,7 5164.02 95~4 5202.79 ~,J 5ZqO.Z/ ...... ~:. 4583,02 ,.,_ .8: 102.&5 -!ii0.37 4669,52 ES,06 !02,35 -i!29,i! /=--'~ ' "-, L L f'i;3 · -':/oo, e.? ..,o · ..-. i04~21 -ii4v.14 484!,r.'~ M,17.. !03,4! '1169,31 OL Q ~ '-*-~ :" ' ; *.., ~ ~., _.'Al 7,5'4.' ..,: 53!~,,54 '.:-'5..t 5356.27 95,9 5??4,03 . _ .a-'tO i, 7 ~ 4929.!3 65.48 104.34 -11%~39 $016.W 66~35 103.47 -12!i.46 5i04,09 ~L/¥,o£ 66.41 t02.2A -1270,26 94,9 96.7 97,5 94.6 95,0 5470,0i 5546.36 56~,00 5366.52 ~.,~4 .~ .... -ko=,~o N54.95 66,18 101.79 -1308.77 ~4,I2 ~,.22 I01.87 -1327,06 562<~,57 66.t4 t02.05 -!34AI~97 ~!7.AO ~..10 102,50 ri2~3.46 7w~ 91,6 97.3 96,8 94,7 570!,~ 5741,07 57~0.70 5~04,.~ 588B,04 5976,83 6C65,11 6151.32 65.,~. 65.84 65.94 65,47 96,2 '.'..5.7 96.3 95,9 94.4 95,3 195.5 5~,0,13 59~9,59 5979,11 4015.~5 6238.65 6412.81 6500.51 6587,40 6052,~ 6676,53 60~.0~ 6764.76 6123.52 6852,25 ~-~ 6940.96 6!94.05 7030.53 64.99 65,87 66.75 67.46 68,49 68,65 uior LHU~'ir, M i B.t ft ft 3520 .~ 26 3~3<~, ~,9 ~'.'-02,43 37!4,80 3i46,47 3500,~,7 3769.48 38~.6.12 3:::54:76 3'?73 AZI~TH deq. 104.18- 104.13 lCq 104,07 104:07 3)99,i3 4060,~.5 !04,06 402!,55 4!46.20 104.06 4107.33 4234,i~ 104.06 41'~2,26 432!,7! 104,06 4276,~9 4406,82 104,05 42~v3,28 44?4.52 1~,04 44%,49 4563. vo"~ 10~,02, .... 4~.,v,.~ 103,99 46i5,8! 4756,70 i03.90 4697,89 4Mi,2~ !03,98 deg/ !(Oft 0,73 0,55 1,14 2,25 0,63 0,97 0,82 0,72 1,21 0,65 0,91 0.36 1,79 0,82 4783,24 4929,14 103,98 1,02 4~$5,31 5016.78 103.97 1,07 495.3,20 5104,D 103,97 0,63 5124,~ 5279.6~ 103,92 .~ .... ,.z 103.90 =.~=,62 54..54,95 103,8~ ~5~4.12 5~2,95 r ~ 103,B5 5467,s7_, ~.30 ,.,~v 103,82 ~.45 5717.41 103.D in2,18 -1382.04 = '~ - ~ o~,,SJ 580~,49 · . t02,3I -1355',81 5719,24 4~ 4~ ..... 102,54 -.. r~ 55?2 55 60As.i~ i02.38 -f4~.15 5976.77 6151,36 103,~ I,-%,03 106,® ,106,~ :107.01 103,77 . 103.75 103,73 103.70 103.68 -1475,06 606.1,80 627~..69 103,~, -1497,51 6145,53 6325,35 !03.69 -1521.67 6299.68 6412,.~ 103.73 -1546.12 6313.98 6500.53 103.76 -1571,09 6397,31 6587.40 103,BO 6482,80 6676,53 103.84 6567.31 6764.76 103.B8 6651,24 6~52,Z5 103.91 6736,90 6940.97 103,~ 6823,42 7030,54 103,94 106.31 -1596.68 :107~2 '10'5.61 4647.50 104,67 -1670,6B 105.38 -16~.9i 1,03 1,47 0,19 0,44 0,40 0,14 0,76 0,31 1,60 1,94 0.91 0.98 0,99 0.92 1,29 1.98 1.03 0,71 i095~.34 96,~ 6417,96 I!C~7~0~; 95,7 6457.08 11141,76 94,8 6495,$~ L!Z27,53 ?5,8 6535,23 11358.35 95.8 657,'4.46 ii42a ~ 6613,i? ,oo ?5,0 115~.45 94,i 665!,36 11616 ~'' 6~.89,37 ,~ 94:4 1296,76 96,2 7¢~00,29 12562,?! 94.6 7079.!6 ~=~ =~ 94,5 7158,A-4 -,Z=~o,?o. 96,Z 7!98,85 i2943,M3- 96,9 7~8.76 L~gT 9LMg~¥ t3 F$~O.~D TO T~ TARGET ~..,..: A-.'.P¢JiH LATiTLD: SEC'TI£~'~ iNC',..N. N/-S ft deg deo ft 71i8:16 A7. ho. ~ .-':~ A7 _~vlv 7207,03 67,59 !04,29 -1740,34 -,..- 72'~i,r~ 67.81 ~"= ~'-' ': ~'- ~ , , , .,. IgJ,oO 7552 ~"~ ...... ~'" '"' -i7S4, ~, ,,'¢.-$ Ivo,O: 29 f -,.:;_= . - . 74A,o, ~o z=, 0.,-, !03,63 .... , .._:~ ~..,.~ M~T ~.,...-.. , . _..- ~, ~,TL~,~ [)IF;P: ~'"EMvi-Yf,' E/-W ft ft 6?07:89 7!I&.17 69'~'> vi 7207,04 '. lull f ~,.~. ~ __ . 7247,20 7468,40 ~i~ ~^ A5,87 103.40 -~-~ A~ //~, 103,28 78!7,t6 ^5.81 105_-...cK~ '~= ~ AZIMUTH DLS deg/ deg lOOft lO~ o~ 1..A7 _._~1.., ~ ._: 103,97 1,42 i03,96 1,04 103,95' 2,°~ 103,98 0,53 8077,34 &6,!O 103,9& -i95i,35 ._,~£ ~'?50,7~ ~.6.26 103,67 -i994,51 8333,65 AA.~' ~'" .. ,:= 104 -2014,96 7~)i,57 7729.33 103.96 .--.. ~. ~ ~ J L 75AA?A 78i7,17 ~O~ 96 ~,,.,4 7670,69 7904.57 103,97 0,06 8~"::"" '~' /'.=:,,79 104,57 ",r,'-,~ ,--,- P-"-.~I,',:-O 65,9! !:',..4. -?~'""="' "-.' 8597,12 65,99 i05 =' -708!,69 ~-s-.~_~,,i~ ~'" '""'" l(~JJl - i'-;~;,51 876?,66 65,35 !05,!3 -2i26,86 78~$,!0 8077,35 103,98 0,16 7921,7~ 8!63.78 103.99 80?,6,0? 8250,79 lC)3,99 1,26 8085,4! 8333,67 i03,99 1,24 ........ o ._ I05,06 -2t49,62 8939,98 64,84 !04,9& -217i.15 9025,~ 64.87 IC~,88_', -2!~,92 9ii0,03 64,90 104,60 -2216,14 OlOS.L7 A~ ~o 1 ..... v --223~-,09 ..... ,.. .¢,,, 8i74,10 8424 '~' 1oz,EK} 0,42 6341,31 8597,i5 104,0i 1,28 ~24 *~ 8683 '~ i04,03 F,,AA 8537,8.5 876?,69 104,04 0,27 %~71 oc;,'.uz 0.17 &672,36 8940,03 104,(~, 0,40 8754,90 ~::~,60 104,07 0,87 883.6,43 9!I0,09 1(~,08 1,24 &919,2~ 9195,73 104,09 0,57 92e~,14 . i04,10 1,05.: 9371,45 104,!2 0,97 65,42 ~n~ 19 =22Ai,A7 9F~3,42 65.96 t05.~ -~85,67 9088,44 9457,37 104,13 0,04 RECEIVED JUL 1 2 1996 Alaska 0il & Gas Cons. Commission Anohorage MPU E-23i TREE: 3.1/8"-5M FMC WELLHEAD: 11' 5M FMC, Gen. 5 ORIG. DF ELEV = 54.1' (N 22E) w/ 11 ' FMC Tubing Hanger, 3.5' NSCT ORIG. GL. ELEV = 24.9' (N 22E) lift threads, 3' CIW 'H' BPV profile RT To 7" csg. hng. = 28.5' KOP @ 1400' , Max. hole angle 63 ~ 68 deg. f/4050' o TD , L-80 Btrc. (} Halliburton "ES" Cementer 6566' md 3.5 9.3 ppf, N-80, mod. 8rd.. (capacity = 0.0087 bpi) ~ Y Radioactive Marker @ 12,352' wlm 22.5' Short Joint (12,366' - 12,388' md) "~ Baker S-3 Packer 1i2,275' mdl Stimulation Summary HES 3.5" "XN" Landing Npl. 11~,3o2' md None to date (w/2.813" ID w/2.75" No-go)l Perforation .~ummary ~ EOT Ref log:. Q8/22/95 ,$BL/CCL l i~,315'.., m~ SIZE SPF ,NTER~/~L (TVD) 2.0" 4 12,706'-12766' (7140'-7165' - Alpha Jet charges @ 0 deg. phasing - decenl~alized, EHD = 0.28", TTP = 12.2" ' ~ ORIG. PBTD 112.,9.32' m. dl ~~k, 7' 26#, L-80, OTRS ,D, ATE REV. BY ,, CO, MMENTS MILN.E POINT uN.rr 09 / 13 / 95 jBF Completion by N 4ES WELL E - 23i ...... APl NO: 50-029-22570 BP EXPLORATION (AK) TO: Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) November 17, 1995 BP Exploration (Alaska) InC. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth shifted CDR/CDN.CDR/CDN TVD'S for well Job # 95271 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each I Film each ............. 1- Dept. h. shift display · .. .. state of Alaska _ .~. ..... Alaska Oil & Gas Conservation Comm. . ( Attn: Larry Grant ...... 3001 Porcupine Drive -~- .... Anchorage, Alaska 99501 1 OH LIS Tape I Blueline each 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 349 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 · Schlumberger Couri SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Received ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 11 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION _ MPE-15 ' 1 PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF 1 TEMP LOG FINAL BL+RF Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 ECC No. 6434.02 Please sign and return to: Attn. Rodney D.-Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, ~ 99518 Or F~ to (907) 563-7803 · Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, please-find the data as described below: Date: 1 September 1995 . _. RE: Trm'~smittal of Data ._ ' r.-----. - .;' :.~ .-. .... . ..... . .: ~ :. · ' S - --"- ...... ~- ..... ~'" -~ .....................~ ..... '--'~-~ .... ~:___- .:_:._ ._ _ _ Atlas Wireline Service -' --,:.'--;:/-'-.:~7-~'-,:-~_.::,:~:'~',". ,.'....:.,~-'..' .:~'.'.;:.-~.~.:-.:~:~.~.~- ....... :- .':'~,-:~ ~j~'r.:~- ::.j-:':.~.jj%:-: .. :: ~--.. ..... %. ~..-._~.~.:-...~:~ Suite 201 - ,horage, ~ 99518 Or F~ to (907) 563-7803 -' . . :.-~.~.:.:-~3~.~_ Date: SEP 1 1995 Alaska Oil & Gas Co,re. uummismon Anchorage - LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION I GR/CCL FINAL BL+RF i GR/CC~. FINAL 1 SBT/GR FINAL BL+RF .. ECC No. ~- . Run ~ I 6469.01 : ~:i :~,"~-~.:' - Run ~ I ' 6472.00 Run # 1 6473.00 .... :,~; · . · '. · Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services . 5600 B Street Suite 201 Anchorage, AK 99518 . Qr FAX to (907) 563-7803 \ , RECEIVr.0 SEP 3 ~ ;995 -. '.4]aska Oil & Gas ~,,. Anchorage ......... ~slon' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: 'David' J o~~,' Chairma~ Blair Wondzell, P. I. Supervisor FROM: John Spauiding~,~ SUBJECT: Petroleum DATE: FILE NO: August 19, 1995 AW9LHSCD.doc BOPE Test Nabors 4ES Milne Point Unit / BPX Well E 23i P~D 95-94 Saturday August 19, 1995: I witnessed the BOPE Test on Nabors 4ES at BPX's Miine Point Unit, well E-23i. The AOGCC BOPE Test report is attached for reference. Nabors 4ES was recently down for summer maintenance, I found the rig to be in excellent shape with many new upgrades. Although the area around the rig is being shared with construction crews, I found good access to the rig and excess materials were in an orderly fashion. During the test the test pump was having some problems resulting in a rather long test time. Summary: ! witnessed the BOPE Test on Nabors 4ES, 5.5 test time. Attachments' AW9LHSCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nabors Rig No. 4ES PTD # BPX Rep.: MPE-23i Rig Rep.: 7" Set @ 13,024' Location: Sec. Weekly Other DATE :- 8/119/95 95-94 Rig Ph.# 659-6476 Wayne Helms Dan Hebert 25 T. 13N R. 110E Meridian U>M> TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 11 500/5, 000 P 11 500/5, 000 P 11 500/5, 000 P 1 500/5, 000 P Quan. Test Press. P/F Test 11 300/3, 000 P Pressure P/F 110 500/5,000 P '1 500/5,000 P NA 500/5,000 P 11 500/5,000 P 'I 500/5,000 P 2 500/5,000 P ~ 500/5,000 P NA CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 24 500/5,000 P 11 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3, 000 P Pressure After Closure 11,900 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 37 Trip Tank OK OK System Pressure Attained 2 minutes 20 Pit Level Indicators OK OK Blind Switch Covers: Master: YES Remote: Flow Indicator OK OK Nitgn. Btl's: 4 ~ 2000 AVG. Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK sec. sec. YES TEST RESULTS Number of Failures: 0 ,Test Time: 5.5 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) AW9LHSCD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing__ Variance__ Perforate__ Other X __ Run Completion w/4ES 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development x KBE = 55' feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 3735' NSL, 1830' WEL, SEC 25, T13N, RIOE At top of productive interval N/A At effective depth N/A At total depth N/A MPE-23 9. Permit number 95-94 10. APl number 50- 029-2257O 11. Field/Pool Milne Point / Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 4209' Intermediate 13003' Production Liner Perforation depth: measured N/A 13040 N/A Size 9-5/8" 7' true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 850 sx 'E', 250 sx 'E', 150 sx 'E' 310 sx Class 'G' True vertical depth 4240' 13033' AUG 0 7 1995 Naska OiL & Gas Cong. Commission Anchorage 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch 14. Estimated date for commencing operation August 15, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby c~at the foreg?ing is tru~j ~nd correct to the best of my knowledge. Signed ~ ~~~,~ '~,~U Ti t I e .~er~ior Dri//ir~,.q ~'r~,..qin e or FOR COMMISSION USE ONLY Commission so representative may witness Conditions of approval: Noti~ ~' ' ' Plug integrity__ BOP Test ~ Location clearance __ Mechanical~nte~ri~ Test ~ Subsequent form required 10-. H~ Urigmal Signed ~pproved Copy D ~d W J~h Re~rne~ a nsto Approved by order of the U~Is~i0H ~ Form 10-403 Rev 06/15/88 Date ~-- 7- C~ ~, I Approva, NO. ?~-_./,.~ ~ Commissioner Date '~ -~/'/~~ 5~ SUBMIT IN TRIPLICATE ,..~ E-23i SUNDRY INFORMATIO,_~ Objective: The objective of this workover is to complete E-23i as WAG (Water Alternate Gas) injector 'in the Kuparuk C and B sands, with 3-1/2" 9.2# L-80 NSCT tubing and a 7" latch type packer. A cement bond/GR/CCL logs will be run on this well prior to the completion, however, perforating will be done with wireline after the workover rig moves off the well. Scope' 1. Pre- rig: none for this new drilled well. 2. MIRU Nabors 4ES workover rig. ND tree, NU and test BOP. 3. Clean out wellbore with 6" mill and 7" casing scraper using source water. 4. Run cement bond logs and GR/CCL as for future tie-in logs. . RIH with 7" latch type packer on new 3-1/2" 9.2# L-80 NSCT tubing and 3-1/2" tailpipe with one 3.5" XN nipple. Space out the packer @ +/-12,300'MD and land the tubing hanger. . Freeze protect the well with diesel to 2,000'TVD before setting the tubing packer. ND BOP and NU tree. RDMO Nabors 4ES. Tlmincj: Nabors 4ES will be making a well to well move from E-20 to E-23i on approximately 8/15/95. This workover should take approximately 3 days rig time. MIRU / ND_NU Cleanout wellbore w/casing scraper Run cement bond logs and GR/CCL Complete well w/3-1/2" new tubing 0.5 day 1.0 day 0.5 day 1.0 days Total' 3.0 days DH, July 30, 1995, 2:44 AM /~U6 07 ~995 , Git & Gas Cons. Commission ~chorage TREE: 3 1/8'-5M WKM MPU E- 23i COmpletion WELLHEAD: 11' 5M WKM i. ' ACTOATOR: · KB-__54~ ' GL 24 20' Conductor Casing!~ , Surfaco Casing , 3-1/2' NS CT Tubing i ~2,300.~I' , ; : KOP @ 15oo' Max@ 5161'H°l°MDAngl°:-~7-~ i , , NO GAS LIFT MANDRELS ! I .. ; I AUG 0 7 1995 ~:~ ~ Nasl~ Oil &. Gas Cons. Commission ,, -' Anchorage 3 1/2' XN Nipple NSCT 3 1/2" L-80 NSCT WLEG - 12,300' md i .PERFORATION SUMMARY REF: LOG: Anaddll CDN/CDR ' SIZE SPF INTERVAL OPEN/SQZ'D 2 1/2 4 12532to 12534' Open 2 1/2 4 12720to'12780' Open I 7',26#/ft, L-80 Butt l i3,0331~ DATE REV. BY COMMENTS .MILNE POJNT UNIT ABC COMPLETION DATE .WELL E-23i RBF WORKOVER DATE .APl NO; 50-029-22570 1! BP EXPLORATION (AK) ,AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP E-23 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API:' 50- PERMIT: APPROVAL: ACCEPT: 06/30/95 05:00 SPUD: 07/01/95 03:00 RELEASE: 07/13/95 11:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: 07/01/95 ( 1) TD: 270' ( 270) 07/02/95 ( 2) TD: 2782' (2512) 07/03/95 (3) TD: 4260' (1478) 07/04/95 ( 4) TD: 4260' ( 0) 07/05/95 (5) TD: 4872' ( 612) 07/06/95 ( 6) TD: 6488' (1616) DRILLING MW: 0.0 VIS: 0 LEVEL RIG/ACCEPT RiG @ 1700 HRS. NU DIVERTER. FUNCTION TEST. BOBBY FOSTER W/AOGCC WAIVED WITNESSING. SPUD & DRILL F/l12 T/270. DRILLING MW: 0.0 VIS.:. 0 DRILL T/1926. CBU. DRILL T/2261. CBU INCREASE THE MUD WT T/ll.4PPG. DRILL T/2782. SHORT TRIP MW: 0.0 VIS: 0 DRILL T/3069. CBU. DRILL T/3934. COULDN'T SLIDE. CBU & MIX PILL. POOH MOTOR LOCKED UP. MU NEW MOTOR. SERVICE THE TOP DRIVE. TIH & DRILL T/4260. CBU. SHORT TRIP T/CHK HOLE. NU BOPE MW: 0.0 VIS: 0 CIR & COND MUD. POOH LD BHA. RU CASG EQUIP. RUN 9-5/8" 40# L-80 BTC CASG T/SHOE @4240. CIRC & COND. MUD @ 15 BPM W/1000PSI & NO LOSSES. TEST LINES T/3500PSI. PUMP 70 BBLS SPACER. MIX & PUMP 850 SXS "E" @ 12. PPG. TAIL W/250 SXS "E" @ 15.8 PPG. PUMP 10 BBLS WATER & DISPLACE W/RIG PUMPS @ 15 BPM W/1000PSI. BUMP PLUG T/3000. FLTS HELD. CIP @ 2100 HRS. LD LND JT. ND DVRTR. RU & PUMP 150 SXS TOP JOB. INSTALL CSG HEAD & TEST PACKOFF. NU BOPE. DRILLING MW: 0.0 VIS: 0 RU & TEST BOPE 250/5000. NO INSPECTOR WAS ON THE SLOPE. UPPER & LOWER IBOP VALVE FAILED. CHANGE OUT. RU & RE-TEST. OK. MU BHA #3. TIH TAG FC @4152. CIRC & TEST CSG T/3000/30 MIN. DRILL FC, FS & 10' NEW HOLE T/4270. POOH MW: 0.0 VIS: 0 DRILL T/5349. SHORT TRIP T/SHOE. OK. DRILL T/6488. CBU. RU & RUN GYRO. CBU. POOH * DOWNLOAD CDR & LD MOTOR. AUG 0 7 1995 D~ & Gas Cons. Commission : ~P E-23 OPERATION: RIG : NABORS 22E PAGE: 2 07/07/95 ( 7) TD: 8055' (1567) 07/08/95 ( 8) TD: 9650'(1595) 07/09/95 ( 9) TD: 9778' ( 128) 07/10/95 (10) TD:l1830' (2052) 07/11/95 (11) TD:13040' (1210) 07/12/95 (12) TD:13040' ( 0) 07/13/95 (13) TD:13040' ( 0) 07/14/95 (14) TD:13040' ( 0) DRILLING MW: 0.0 ViS: 0 MU BHA#3, TEST ORIENT & RIH T/4183. CUT/SLIP DL & SERVICE THE TOP DRIVE. BENCHMARK SURVEY @5644 TIE-IN W/GYRO. DRILL T/8055. DRILLING MW: 0.0 ViS: 0 DRILL T/9236. CBU. DRILL T/9650. TRIP IN HOLE MW: 0.0 ViS: 0 DRIL T/9778. POOH T/cASG SHOE. NO HOLE PROBLEMS. REPAIR SCR PROBLEM. POOH & DOWNLOAD & INSPECT BIT. MU BHA. TEST MWD TIH. TAKE BENCHMARK SURVEY TIE-IN @ 5644. DRILLING MW: 0.0 VIS: 0 DRILL T/11830 DRILLING MW: 0.0 ViS: 0 DRILL T/11903. CBU. DRILL T/13040. TD. REACHED. RUN CASING MW: 0.0 ViS: 0 CBU. POOH LD DP.DOWNLOAD LWD. RU CASG EQUIP & RUN 7" 26# L-80 BTC. CBU MW: 0.0 VIS: 0 CIRC & CONDITION MUD F/2ND STAGE CMT. LOST 10 BBLS OF FLUID T/FORMATION. RELEASED RIG MW: 0.0 VIS: 0 ClRC AND CONDITION MUD FOR 2ND STAGE CEMENT JOE. PUMP 20 BBLS H20, 70 BBLS 11.6 SPACER, 310 SX CEMENT. DISPLACED W/ 75 BBLS DIESEL AND H20. BUMP PLUG. PRESS CSG TO 2500 PSI TO CLOSE ES CEMENTER. BLEED OFF PRESSURE. RD HALLIBURTON CEMENT HEAD. LD LANDING JT. INSTALL HANGER PACKOFF. WOULD NOT TEST. PULL PACKOFF. RELEASE. SET SCREWS ON JUNK RING. REINSTALL AND TEST. MU HANGER W/ 2 WAY CHECK. INSTALL SAME. TEST. ND BOPE. NU ADAPTER FLANGE AND TREE. HANGER NOT COMPATABLE WITH ADAPTER. PORTS DO NOT LINE UP. HANGER IS BORED WRONG. TEST. HANGER WILL BE REPLACED DURING COMPLETION. TEST ADAPTER AND TREE. FINISH PIT CLENAING. FREEZE PROTECT E-23 ANNULUS W/ 75 BBLS DIESEL. FREEZE PROTECT E-20 ANNULUS W/ 120 BBLS DIESEL. SECURE WELLS. RELEASE RIG 2300 HRS ON 07/13/95. &,Gas Cons. Comnds~. : MP E-23 JPERATION: RIG : PAGE: SIGNATURE: (drilling superintendent) DATE: AUG 0 7 199,5 Di~ & Gas Cons. ~ CONSERVATION COMMISSION ALASKA OIL AND GAS / TONY KNOWLE$, GOVEBNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE'. (907) 279-1433 FAX: (907) 276-7542 June 22, 1995 Adrian Clark Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: MPE-23i BP Exploration (Alaska), Inc. Permit No.' 95-94 Sur. Loc 3735'NSL, 1830'WEL, Sec 25, T13N, R10E, UM Btmhole Loc. 1463'NSL, 3185'WEL, Sec. 29, T13N, RllE, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Tuckerman Babcock Co~issioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 .a. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 55 fe et Milne Point / Kuparuk River 3. Address 6. Property Designation Sands P. 0. Box 196612, Anchorage. Alaska 99519-6612 ADL 028231 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3735' NSL, 1830' WEL, SEC 25, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 1561' NSL, 3577' WEL, SEC 29, T13N, R11E MPE-23i 2S100302630-277 At total depth 9. Approximate spud d~tte Amount 1463' NSL, 3185' WEL, SEC29, T13N, R11E 06/25/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property 15. Proposed depth (MD and mVD) property line , ADL 028232 3185 feet No Close Approach feet 2560 13033' MD / 7278' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 Kickoff depth ~ooo feet Maximum hole angle 65.5 o Maximum surface 2810 psig At total depth (TVD) 7278'/3510 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 12-1/4" 9-5/8" 40# L-80 Btrc 4194' 31' 31' 4225' 3586' 828 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 13003' 30' 30' 13033' 7278' 5375x Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production ,JUN 1 9 19°~ Liner A.i~ska 0il & 6as Cons. Commission Perforation depth: measured Anch0r~- true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~I~['1,,- ~ ~C..~ff~,J,~.., Title Senior Orillin~ Engineer Date Commission Use Only Permit LNumber IAPI number IApproval date ISee cover letter ,.?~Z"~ /¢~' 150-O~ ~-' ~- ~-~7~ I (¢ -~ ~ ~ -'~..~for other requirements L;onaklons- ct approval Samples req?~ed [] Yes ~ No Mud Icg requi_red [] YesJ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; D3M; 'i~5M; []10M; []15M; Other: :Original Signed By by order of Approved by TIJckerman R2hrmr, l,, Commissioner tne commission Date Form 10-401 Rev. 12-1-85 Submit cate Well Name: I MPE-23i Well Plan Summary I Type of Well (producer or injector): I Kuparuk Injector I Surface Location: Target Location: Bottom Hole Location: I AFE Number:~ 1330131 ] Estimated Start Date: I 6/25/95 I I 3735 NSL 1830 WEL Sec 25 T13N R10E UM., AK. 1561 NSL 3577 WEL Sec 29 T13N R11E UM., AK. 1463 NSL 3185 WEL Sec 29 T13N RllE UM., AK. I ] TVD: I Well Design (conventional, slimhole, etc.): I Rig: IN, abors 22-E Operating days to complete: I 19 I 727S' bkb~I I KBE: ] Milne Point Ultra Slimhole 7LS 154' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1815 1814 NA 5915 4329 Top of Schrader Bluff Sands (8.3 ppg) OB 6385 4524 (8.3 ppg) Seabee Shale 6470 4559 Base of Schrader Bluff Sands (8.3 ppg) HRZ 10959 6419 High Resistivity Streak Top Kup 11997 6849 Kuparuk Cap Rock Top C1 Sand--Target 12588 7094 Target Sand 1 (9.7 ppg) Top B7 Sand 12733 7154 Target Sand 1 (9.7 ppg) Total Depth 13033 7278 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDflWD MDfrVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 4194 31/31 4225/3586 8 1/2" 7" 26# L-80 btrc 13003 30/30 13033/7278 Internal yield pressure of the 7" 264/casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3510 psi is 2810 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional Only Intermediate N/A Final 1. Insert Bit to Seabee Top w/w/MWD Dir and LWD (GR/CDR/CDN). 2. PDC Bit f/Seabee to TI) w/MWD Dir and LWD (GR/CDR/CDN). "Cased Hole Logs: CBL required for injector.. GR/CCL will be mn in 7" casing to locate the TCP Guns. D r' t~ I~ ! ~ ! E2 f I\LLLI V LL JUN 1 ~a. ska Uil & Gas Cons. Commission Anchor-:' ::~ Mud Logging is not required. Mud Program: I Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 10.5 150 35 15 30 10 15 'intermediate Mud Properties: N/A [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to - to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: ]KOP: [ 1000' Maximum Hole Angle: [65.5 degrees I (No Shut Ins) Close Approach Well: Disposal: Cuffings Handling: Central Reserve Pit while the Kuparuk Bridge is out; otherwise CC2A. Fluid Handling: All drilling and completion fluids can be annular injected. Annular Injection: The MPE-23 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPE-23 0 35,000 1/1/95- 1 2/31/95 Milne Point MPE-10 9000 35,000 1/1/95- 1 2/31/95 Milne Point MPE-09 5000 35,000 1/1/95-12/31/95 F ECE VED JUN q 9 'i995 Alaska Oil & Gas Cons. Commission Anchor; :- FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. RECEIVED Ai~.ska (.)ii & Gas Cons. Corr~mission Anchor:: :, MPE~'23 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT (Do not exceed 12.5 ppg). 8. Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale, CBU, Wiper Trip to the BHA, POOH. LD the Insert Bit and Motor. Send Schrader Bluff Logs to town -- ASAP. 9. MU a Hughes R417G PDC bit on a turbine, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH. 10. Drill 8.5" hole to TD and Run and Cement 7" casing (2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). 11. RIH while PU 3-1/2" drill pipe with 7" 26# bit and scraper. Drill out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with 10.2 ppg brine, while performing a casing wash, filter brine water to 2 micron absolute. 12. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Packer. Perforate the well underbalance. Kill well while circulating 10.2 ppg kill weight brine. 13. POOH laying down 3-1/2" Drill Pipe. 14. Change Rams and run straddle packer completion on 3-1/2" 9.3# L80 Modified 8rd EUE tubing. 15. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 16. Install Surface Lines and Wellhouse and put the well on injection. Drilling Hazards and Risks: 1. There was evidence of shallow gas/hydrates in the E-Pad area (E-7,8, 9, 10, 11, and MPE-22 wells). Be prepared to control drill and be weighted up to 10.5 ppg by the base of the permafrost. 2. While drilling MPE-09, 11.6 ppg pore pressure was encountered while drilling into the Kuparuk reservoir (9.8 ppg was prognosed). SSD policy now requires the rig team to conduct a pre drilling reservoir meeting on the rig prior to drilling into any known hydro carbon bearing reservoir. [~ ~ C E IV 3.No other drilling hazzards or risks have been identified for this welL Anchor~ ~ MPE-23 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" SPACER: 75 bbls fresh water. CIRC. TEMP 50 deg F at 2500' TVDSS. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 828 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Gre~ter than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER:0 TOP JOB CEMENT TYPE= Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 250 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing required). 2. Place all centralizers in middle of joints using stop collars. (15 OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to ¢~,.¢~)'C~ i V E D with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. JUN 0il & Gas Cons, Commission Anchor. MPE-23 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg ab~ current mud weight. ...* CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 34~ WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 228 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60° F BHST 80 deg F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg ab~ current mud weight. .LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 309 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle.R E C E tV ~ P A!ss~a Oil & Gas Cons. Commission Anchor: '. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 tol This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6550' - 5700' to cover the Schrader BI~ Sands (20Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" CaSing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ens compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requiremE Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base-to the to 1000' above the NA Top with 30% excess. I. · SH/('RED. SERVICES ORILLIN6 ND BKB SECI~ INCLN 0 ..... 0 . .0 0.~0 .. 'i5oo ~5oo ~ ~.oo 3500 3256 8i§ 50.00 4121 3586 1342 65,52 t2588 7094 9049 55.52 13833 7278 9453 §5.52 --13033 ...... 7'2'7'8 .... 9453--65;52 ............................... ~nadr~ ]] Schlumberger ii --- iii i ill _ Iii Ill lllll [ ......... B...P. E-23 (P6). VERTICAL SECTION' VIEW ! Section ~t: 103,87 TVD Scale'.' 1 inch = 1600 leet .............................. Dep--Scal'e ;': .... 1-'tnch"=-"'lC00-f~et: .......................... Ora~n ..... "05/24/95 ... i i · hill !~ J I · · . ! ! · ' R-- ~ > ...... --... '" - '~ 3F_ ~1~6'~, f - TeT4" [2~' ~ ............ ............... ~-. .......................... - ~ --' ~1 J ,._: , ...... = .... ~._ ~ ~ ,_,,_.__1 i , ,.:...:. , I;EAS ~ " ~ ' ~ · ' ip~ ~i~ ~,.....:~::;::::: ~ ~:;~' NOT i,k OVED~ FLaK ' , .. ~.. ...., : ~ ..., ' ' ~ ~ PL, NN '*/?-'- ~;'~ .... ,, , ~ .'. ' ~ ' I i -.-- _. _ ..... _,_. ...... ~ ~ _~ ......... J ~ ~ 'T~ -edfl ......... ~--' ......... ~ .... ~ - . ~:j~==:::~::=== --::=---:::=:=== ==:=:= ==~':=::~==== =:=. ',m jr -~ ~ ] ....... , '~ ' r " ' - -' i-il~l:'i-i-lJJi-i'l - iiiii ..... ] ~i....~,i.:, .,.,~'~mlJ~'[=,=-~,,...,....., ~, '" I ' ' ' r · - ' -' I ..... 1' ' '" ." " ~ "" 200 1000 t800 2riO0 3400 4~0 ~00 5800 ~00 7400 8200 9000 9800 10600 11400 12~0 13000 l~80O ........... ........ Section De mture Z I ao I ITl Z Z ITl ITl _ i i ~nadril ]. Sc#lu~berger.. '1 · i ii MPE:2.3 (P6.) PLAN. ¥IE~ i ii i i _ SHARED SER'V. ICES DRILLIN · ii · i i ~ i _ _ JI II · i i _ ii ii i i ii LO UFIE ' 9453 feet at Azimuth ~03,87 OECL SCALE DFIAWN Mact, er AIL. KB .... 181 KOP, I¢~ 9-5~ :Ol END FI 1" G) ]O .... ...: i-inch'.=-d200 I-eet'. - · "'[ .......... ~ .... i, ' ................... ~ 1 Ident i t icat ion I~ It/S E/K " ..... "' f"":-':.--.- .................... 0 ......... 0 ........ D ................................................ [ -- ,. - ..... '8'~BIJILD ~.5/i00 i500 0 0 --"------ ---"---~ '-'~9 _~PC_ ' CAS]NB P01U'I 3500 t§6 7~J ~" f, IADR I[~-,, ,-m ~.5/100 BUILD 4121 322 i303 , ' ........ _____.-- i';~,~ ~, n--A,I I -- :ASIN6 FOINT 130332266 9t78 I .~o~ ,_~,,..,. },IOTiAPP ~,OV ~D F'DR I ~!xE'(: ,UTI j~N " ' PI.AN ~._~_: ,, ................ , ).,_ . .. ~. .>r~ ..,, ..· , :o o O ---- : ' tO0 F1 TARGET ~AOIUS ! ~ o ~ i .., ,I / ~ , .~ - , ' ~.,., · i ~' ~ N ..... o ~ rtl , , ~ ..........i .................. , ..... I ........................ · " · 0 ' 600 0 600 1200 !800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 go00 9600 10200 .'. .......................... .......... <- WESl · EAST -> (Ano~lt fciC3 N~Z3~6 8J.SZ 4: Il PI~ t) L Z I 6;) I m 7 I-ri m _.__.- I-'ERMIT CHECKLIST ~"~'~s~o~ PROGRAM: exp [] dev [] redrll [] serv~ ENGINEERING 1. 2. 3. 4. 5. 6. ~ 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located proper distance from drlg unit boundary. Well located proper distance from ~ther wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ...... '.. 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ..... · ..... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~(i~ psig.~ 27. Choke manifold complies w/API aP-53 (May'84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ........... .~ N~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis 9f shallow gas zones .......... ~/ N 33. Seabed condition survey (if off-shore) ........ /Y/ N 34. Contact name/phone for weekly progress reports . . . / . Y N [exploratory only] GEOLOGY._ ENGINEERING: COMMISSION: DWJ HOW/jo - A:'tFORMSAcheklist rev 03/94 Comments/Instructions: Z 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. * ALASKA COHPUTING CENTER *= * ....... SCHLUMBERGER ....... * COMPANY NAME : BP EXPLORATION WELL NAME : MPE-23 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22570-00 REFERENCE NO : 95271 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 **** REEL HEADER ~*** SERVICE NAME : EDIT DATE : 95/il/13 ORIGIN : FLIC REEL NAME : 95271 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT MPE-23, API #50-029-22570-00 **** TAPE HEADER ~*** SERVICE NAME : EDIT DATE : 95/11/13 ORIGIN : FLIC TAPE NAME : 95271 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPE-23, API #50-029-22570-00 TAPE HEADER MILNE POINT MWD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95271 ST. AMOUR 1ST STRING 2ND STRING MPE-23 500292257000 BP EXPLORATION SCHLUMBERGER WELL SERVICES 13-NOV-95 BIT RUN 2 BIT RUN 3 95271 95271 ST. AMOUR ST. AMOUR 25 13N iOE 3735 1830 54.10 54.10 24.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 4240.0 PAGE: LIS Tape Verification Listing Schlumoerger Alaska Computing Center 13-NOV-1995 15:56 3RD STRING PRODUCTION STRING REMARKS: MPE-23 OPENHOLE EDIT LIBRARY TAPE CONTAINING LOGGING WHILE DRILLING CDR RESISTIVITY (3 BIT RUNS) AND CDN DENSITY/NEUTRON (2 BIT RUNS). $ $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves~ all bit runs merged. DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 4188.5 CDN 6330.0 BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 88875.0 12863.0 12850.0 12849.0 12837.0 12827.0 12814.0 12805.5 12793.5 12776.0 12763.5 12771.0 12759.0 12762.0 12750.0 12755.0 12742.5 12728.0 12715.5 12698.5 12687.5 12691.0 12678.5 12682.0 12668.0 12671.5 12658.5 12667.5 12655.5 12643.0 12629.5 12630.5 12618.5 STOP DEPTH 13024.5 13024.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... CDR/CDN LIS Tape Verification Listing Schlumberger Alaska Computing Center 12614.5 12602.5 12600.0 12588.0 12585.5 12573.0 12577.5 12565.5 12567.5 12555.5 12553.5 12542.0 12515.5 12503.5 12503.5 12492.5 12481.5 12469.5 12472.5 12460.0 12459.5 12448.0 12426.5 12414.5 12413.0 12401.5 12378.5 12367.0 12335.5 12325.0 12310.5 12299.0 12305.0 12294.5 12277.5 12266.5 12257.5 12246.5 12231.0 12220.0 12216.5 12205.5 12187.0 12176.0 12172.5 12161.5 12160.5 12149.5 12150.5 12140.0 12144.5 12133.5 12123.0 12112.5 12101.0 12089.5 12078.5 12067.0 12068.0 12057.0 12037.0 12025.5 12027.0 12016.0 12001.5 11990.5 11978.5 11968.0 11961.0 11949.5 11943.0 11932.0 11927.5 11916.0 11893.5 11882.0 11881.0 11869.5 11863.0 11852.0 11832.0 11822.0 11815.5 11804.5 11767.5 11756.5 11730.0 11719.0 11718.5 11708.0 11697.0 11686.5 11693.5 11682.0 11665.0 11653.5 · 11643.0 11631.5 11636.0 11625.0 11610.0 11600.0 11588.0 11579.0 11578.5 11568.0 11557.0 11544.0 11553.5 11540.5 13-NOV-1995 15:56 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11537.5 11526.0 11518.5 11507.0 11514.0 11503.5 11461.0 11450.5 11414.5 11403.5 11408.0 11396.0 11377.5 11367.5 11357.5 11346.5 11337.5 11325.0 11329.5 11318.5 11328.5 11317.5 11313.0 11301.5 11308.5 11297.0 11298.0 11287.0 11292.0 11280.5 11286.5 11275.5 11275.0 11264.0 11270.5 11258.5 11260.5 11250.0 11250.5 11239.0 11245.0 11233.5 11234.5 11223.5 11222.0 11211.0 11210.5 11198.5 11206.5 11195.5 11199.0 11188.0 11195.0 11183.5 11190.5 11179.0 11182.5 11171.5 11176.0 11164.5 11164.0 11153.5 11160.0 11148.5 11148.0 11137~0 11140.5 11128.5 11133.0 11121.5 11126.0 11114.5 11122.0 11110.5 11117.0 11105.5 11112.5 11101.5 11105.0 11095.0 11092.5 11081.0 11087.5 11076.0 11085.5 11074.0 11080.0 11070.0 11054.5 11042.0 11049.0 11038.0 11025.5 11014.5 11012.5 11002.5 10978.5 10967.5 10974.0 10962.0 10967.0 10956.5 10954.0 10943.0 10945.0 10933.0 10938.5 10926.5 10936.5 10925.0 13-NOV-1995 15:56 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 10928.5 10917.0 10890.0 10878.5 10864.5 10854.0 10861.0 10849.5 10844.5 10831.5 10840.0 10825.5 10833.5 10819.5 10828.0 10816.0 10820.0 10808.5 10785.0 10772.5 10774.5 10762.5 10751.0 10739.0 10741.5 10729.0 10733.5 10721.0 10723.5 10710.5 10714.0 10702.5 10697.0 10685.0 10682.5 10671.0 10673.5 10660.5 100.0 87.0 $ MERGED DATA SOURCE LDWG TOOL CODE CDR CDR CDR CDN CDN $ REMARKS: BIT RUN NO. MERGE TOP MERGE BASE 1 4188.5 6476.0 2 6476.0 9766.0 3 9766.0 13024.5 2 6330.0 9766.0 3 9766.0 13024.5 THIS FILE CONTAINS THE EDITED/CLIPPED, DEPTH CORRECTED CDR RESISTIVITY (3 BIT RUNS OF DRILLING DATA) AND CDN DENSITY/NEUTRON (2 BIT RUNS OF DRILLING DATA). THE BASE CASED HOLE GAMMA RAY USED TO DEPTH CORRECT THE CDR AND CDN DATA WAS ONLY ACQUIRED OVER THE INTERVAL FROM 10655.5' TO 12875.5'. TIlE CDR AND CDN DATA HAVE A -13' BLOCKSHIFT APPLIED FROM 12863' TO TD, AND A -t3' BLOCKSHIFT FROM THE TOP OF RUN #1 TO 10673.5'. LIS FORMAT DATA PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API AP!-,~i-F]'LE ~--~l~-'~i~--'~---~~-'- ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) OE~ ~ ~0~0~ O0 000 O0 0~ ~ ~ ~ ~ -~$~~- RA MWO OHMM 630301 O0 000 O0 01 1 1 4 680000000000 ~ MWO0"~ 6~0~0~ O0 000 O0 0~ ~ ~ ~ 6~0000000000 VRA MWD OHMM 6BOBO1 O0 000 O0 01 i 1 4 680000000000 YRP MWD OHMM 630301 O0 000 O0 01 1 1 4 680000000000 O~R ~wo o,~ 6~o~o~ oo ooo oo o~ ~ ~ ~ 6~oooooooooo ROP MWD FPHR 630901 O0 000 O0 0t I 1 4 680000000000 FET MWD HR 630901 O0 000 O0 01 1 1 4 680000000000 GR MWD GAPI 630301 O0 000 O0 01 1 1 4 680000000000 RHOB MWD G/CB 690301 O0 000 O0 01 1 1 4 680000000000 DRHO MWD G/CB 630301 O0 000 O0 01 1 1 4 680000000000 PEF MWD BN/E 690301 O0 000 O0 01 1 1 4 680000000000 CALN MWD IN 630301 O0 000 O0 01 1 1 4 680000000000 NPHI MWD PU-S 630301 O0 000 O0 01 1 1 4 680000000000 GRCH GR GAPI 630301 O0 000 O0 01 1 1 4 680000000000 ** DATA ** DEPT. 13024.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 141.730 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.GR -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: DEPT. 4188.500 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 33.342 RHOB.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RP.HWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GR -999.250 -999.250 -999.250 -999.250 VRA.MWD FET.MWD PEF.MWD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE ; FLIC VERSION : 001C01 DATE : 95/1t/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUHBER 2 RAW MWD Curves and tog header data for each bit run in separate files. BIT RUN NUHBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUHMARY VENDOR TOOL CODE START DEPTH CDR 4201.0 $ 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): STOP DEPTH 6488.5 12-JUL-95 FAST 2.5-005B V4.0C MEMORY 13038.0 4201.0 13038.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 BIT ROTATING SPEED (RPM): NOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN DENSITY/NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS 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 CiRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF · REMARKS: RESISTIVITY TO BIT: 48.95 ft. DRILLED INTERVAL: 4260' TO 6488'. TOOL LOGGED ON THIS BIT RUN. $ LIS FORMAT DATA 70 68.6 TOOL NUMBER RGS055 NDS022 8.500 4240.0 10.50 2.630 75.0 1.640 65.0 20000 GR TO BIT: 59.37 ft. CDR WAS ONLY PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: --. TYPE REPR CODE VALUE --~ .......... ~ .......... ~--- 1 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 0.5 FT 36 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAHP ELEM CODE (HEX) ATR LW1 OHMM 630301 O0 000 O0 0 21 1 4 680000000000 PSR LW1 OHHH 630301 O0 000 O0 0 2I I 4 680000000000 DER LW1 OHMM 630301 O0 000 O0 0 21 1 4 680000000000 ROPE LW1 F/HR 630301 O0 000 O0 0 2I 1 4 680000000000 TABR LW1 HR 630301 O0 OOO O0 0 21 1 4 680000000000 GR LW1 GAPI 630301 O0 000 O0 0 21 1 4 680000000000 ** DATA DEPT. ROPE.LW1 DEPT. ROPE.LW1 6488. 500 ATR. LW1 -999. 250 PSR. LW1 -999. 250 DER. LW1 124.994 TABR. LW1 -999.250 GR. LW1 -999.250 4201.000 ATR. LW1 -999. 250 PSR. LW1 -999. 250 DER. LW1 -999.250 TABR. LW1 -999.250 GR. LW1 33.477 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 13-NOV-1995 15:56 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001¢01 DATE : 95/1!/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE CDR CDN $ LOG HEADER DATA DATE LOGGED: FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. 2 O.50O0 START DEPTH STOP DEPTH 6405.5 9778.0 6339.5 9778.0 SOFTWARE: SURFACE SOFTWARE VERS'ION: 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: MAXIMUH ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN DENSITY/NEUTRON 12-JUL-95 FAST 2.5-005B V4.0C MEMORY 13038.0 4201.0 13038.0 70 68.6 TOOL NUMBER RGS055 NDS022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH(FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/~): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): . . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX ¢IRCULATIONG TEHPERATURE : HUD FILTRATE AT (MT): MUD CAKE AT (MT): 8.500 4240.0 10.50 2.630 1.640 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF t~/' 1.0 EWR FREQUENCY 20000 REMARKS: RESISTIVITY TO BIT: 54.88 ft. GR TO BIT 65.3 ft. DENSITY TO BIT: 124.8 ft. NEUTRON TO BIT: 131.78 DRILLED INTERVAL: 6488 ft. TO 9778 ft. $ LIS FORMAT DATA 75.0 65.0 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: 12 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 i ** SET TYPE - CHAN ** SERV UU T SERVICE F LE NUMB NUMB S ZE R PR PROCESS"' ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630301 O0 000 O0 0 3 1 i 4 68 0000000000 ATR LW2 OHMM 630301 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OHMM 630301 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OHMM 630301 O0 000 O0 0 3 1 I 4 68 0000000000 ROPE LW2 F/HR 630301 O0 000 O0 0 3 I i 4 68 0000000000 TABR LW2 HR 630301 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 630301 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 630301 O0 000 O0 0 3 1 i 4 68 0000000000 DRHO LW2 G/C3 630301 O0 000 O0 0 3 1 i 4 68 0000000000 PEF LW2 BN/E 630301 O0 000 O0 0 3 I I 4 68 0000000000 CALN LW2 IN 630301 O0 000 O0 0 3 I 1 4 68 0000000000 TNPH LW2 PU 630301 O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 HR 630301 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LW2 PU 630301 O0 000 O0 0 3 I i 4 68 0000000000 DCAL LW2 IN 630301 O0 000 O0 0 3 I 1 4 68 0000000000 ** DATA ** DEPT. 9778.000 ATR.LW2 -999.250 PSR.LW2 -999.250 DER.LW2 ROPE.LW2 93.754 TABR.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF.LW2 -999.250 CALN.LW2 -999.250 TNPH.LW2 TABD.LW2 -999.250 DPHI.LW2 -999.250 DCAL.LW2 -999.250 DEPT. 6339.500 ATR.LW2 -999.250 PSR.LW2 -999.250 DER. LW2 ROPE.LW2 -999.250 TABR.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF. LW2 -999.250 CALN.LW2 -999.250 TNPH.LW2 TABD.LW2 -999.250 DPHI.LW2 -999.250 DCAL. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 34.800 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/1!/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001¢01 DATE : 95/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 13-NOV-1995 15:56 PAGE: 13 FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 9713.5 CDN 9648.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNNOLE 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: HAXIHUH ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN DENSITY/NEUTRON STOP DEPTH 13037.5 13037.5 12-JUL-95 FAST 2.5-005B V4.0C MEMORY 13038.0 4201.0 13038.0 70 68.6 TOOL NUMBER RCS055 NDS022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 4240.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 2.630 75.0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.640 65.0 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN)' 1.0 EWR FREQUENCY(HZ) 20000 REMARKS: RESISTIVITY TO BIT: 54.88 ft. GR TO BIT 65.3 ft. DENSITY TO BIT: 124.8 ft. NEUTRON TO BIT: 131.78 DRILLED INTERVAL: 9778 ft. TO 13038 ft. CONTROLLED DRILLED AT 60-75 FT/HR FROM 12500' TO 12850'. $ LIS FORMAT DATA PAGE: 14 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** I 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: 15 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS "OD NU"B SA"P EIE" CODE (HEX) DEPT FT 630301 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OHMM 630301 O0 000 O0 0 4 1 I 4 68 0000000000 PSR LW3 OHMM 630301 O0 000 O0 0 4 1 I 4 68 0000000000 DER LW3 OHMM 630301 O0 000 O0 0 4 1 I 4 68 0000000000 ROPE LW3 F/HR 630301 O0 000 O0 0 4 1 I 4 68 0000000000 TABR LW3 HR 630301 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 630301 O0 000 O0 0 4 1 i 4 68 0000000000 RHOB LW3 G/C3 630301 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LW3 G/C3 630301 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LW3 BN/E 630301 O0 000 O0 0 4 I 1 4 68 0000000000 CALN LW3 IN 630301 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU 630301 O0 000 O0 0 4 1 1 4 68 0000000000 TABD LW3 630301 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LW3 PU 630301 O0 000 O0 0 4 1 i 4 68 0000000000 DCAL LW3 IN 630301 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13037.500 ATR.LW3 -999.250 PSR.LW3 -999.250 DER.LW3 ROPE.LW3 141.730 TABR.LW3 -999.250 GR. LW3 -999.250 RHOB.LW3 DRHO.LW3 -999.250 PEF.LW3 -999.250 CALN.LW3 -999.250 TNPH.LW3 TABD.LW3 -999.250 DPHI.LW3 -999.250 DCAL. LW3 -999.250 DEPT. 9648.500 ATR. LW3 -999.250 PSR.LW3 -999.250 DER. LW3 ROPE.LW3 -999.250 TABR.LW3 -999.250 GR.LW3 -999.250 RHOB.LW3 DRHO.LW3 -999.250 PEF.LW3 -999.250 CALN.LW3 -999.250 TNPH.LW3 TABD.LW3 -999.250 DPHI.LW3 -999.250 DCAL. LW3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 34.300 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1995 15:56 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001¢01 DATE : 95/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/11/13 ORIGIN : FLIC TAPE NAME : 95271 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPE-23, API #50-029-22570-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/11/13 ORIGIN : FLIC REEL NAME : 95271 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT MPE-23, API #50-029-22570-00 MPE - 23 MILNE POINT~~:' -~ ? ?'~ · c Run 1' 22 - August - 1995 Marked Line GR Cased Hole 10655 2876 WESTERN ATLAS Logging Services Tape Subfile 2 is type: IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPE - 23 500292257000 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 30-AUG-95 6473.00 K. RICHARDS W. HELMS 25 13N 10E 3735 1830 .00 54.10 24.90 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 3RD STRING 9.625 4240.0 47.00 PRODUCTION STRING 7.000 13033.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ SBT GRCH 1 1 22-AUG-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH ......... REMARKS: Marked Line GR/SBT. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10655.0 12876.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT BP EXPLORATION (ALASKA) MPE - 23 MILNE POINT/KUPARUK NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 310 01 1 4 4 30 635 99 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 56 Tape File Start Depth = 12970.000000 Tape File End Depth = 10641.000000 Tape File Level Spacing = 0.500000 Tape File Depth U1 ,s = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13978 datums Tape Subfile: 2 146 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 .is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 12630.0 12876.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 12638.0 12637.5 12643.0 12643.5 12650.0 12650.5 12659.0 12659.0 12678.5 12679.0 12685.0 12685.0 12715.5 12715.5 12742.5 12742.5 12750.5 12750.5 12758.5 12758.5 12794.0 12794.0 12814.0 12814.0 12836.5 12836.0 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH ......... PASS 2 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. CN WN FN COUN STAT / ? ?MATCH. OUT $ : BP EXPLORATION (ALASKA) : MPE - 23 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: API API API API Log Crv Crv Name Tool Cod~ 3amples Units Size Leng~.~. Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 12947.000000 Tape File End Depth = 12618.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1978 datums Tape Subfile: 3 53 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4.is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10655.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12931.0 22-AUG-95 FSYS JlV2.0 UPDATE1 622 22-AUG-95 12927.0 12914.0 10700.0 12876.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330NA 1309XA 1633EA 1424XA 1424PA 4324LA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 13033.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SOURCE WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT PJ. ~' NORMALIZATION IN OIL ZONn TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 23 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 1 1 F/MN 1 LB 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 222 Tape File Start Depth = 12970.000000 Tape File End Depth = 10641.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 69881 datums Tape Subfile: 4 298 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE GR $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): START DEPTH 12628.0 STOP DEPTH 12908.0 22-AUG-95 FSYS JlV2.0 UPDATE1 421 22-AUG-95 12927.0 12914.0 10700.0 12876.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330NA 1309XA 1633EA 1424XA 1424PA 4324LA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 13033.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SOURCE WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RA NORMALIZATION IN OIL ZON. TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS) . $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 23 : MILNE POINT/KUPARUK : NORTH SLOPE · o ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 1 1 F/MN 1 LB 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 32 Tape File Start Depth = 12947.000000 Tape File End Depth = 12618.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9881 datums Tape Subfile: 5 108 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 ~is t~pe: LIS 95/ 8/30 01 **** REEL TRAILER **** 95/ 8/31 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 31 AUG 95 ll:17a Elapsed execution time = 1.76 seconds. SYSTEM RETURN CODE = 0