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Home My WebLink About190-0371. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,821 feet N/A feet true vertical 7,418 feet 11,730 feet Effective Depth measured 11,730 feet N/A feet true vertical 7,327 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 / EUE 11,151' 6,941' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: Hilcorp Alaska LLC 3,520psi 7,240psi11,777' 7,360' Burst 3,730psi Collapse 1,130psi 2,020psi 5,410psi Casing Conductor 11,777' 6,850'Surface Production 13-3/8" 9-5/8" 7" 105' 6,850' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-037 50-029-22028-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509 & ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT L-07 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 100 Gas-Mcf MD 105' 1,220 Size 105' 4,645' 2,047 400328 0 3290 332 324-152 & 324-191 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 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 3:40 pm, May 28, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.05.28 13:55:10 - 08'00' Taylor Wellman (2143) RBDMS JSB 053024 DSR-5/29/24WCB 8-28-2024 _____________________________________________________________________________________ Revised By: TDF 5/22/2024 SCHEMATIC Milne Point Unit Well: MP L-07 Last Completed: 5/1/2024 PTD: 190-037 TD =11,821’ (MD) / TD = 7,418’(TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.= 53’ 7” 3 5 7 & 8 9 9 10 11 Casing Patch in 9-5/8” from 1,910’ to 1,930’ – Installed 2/18/1991 9-5/8” 1 2 KUP A Sands PBTD =11,732’(MD) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 12 6 Fish @Approx 11,625’ MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 9-5/8" Surface 36 / K-55 / Btrc 8.765 Surface 6,850’ 7" Production 26 / L-80 / Btrc 6.151 Surface 11,777’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE R2 2.441 Surface 11,151’ JEWELRY DETAIL No Depth Item 1 232’ Sta #2: 2-7/8" x 1" GLM #6530-15 W/ .25 OV 2 10,932’ Sta #1: 2-7/8" GLM W/ 1" Dummy Valve # 6315-17 3 11,023’ XN-Nipple, ID = 2.313” / 2.205” No-Go 4 11,076’ Discharge Sub & Discharge Bolt On 5 11,077’ Pump: 538/SJ4200/90S/INC/15/1:1AR/HTEM 6 11,101’ Intake Gas Sep.: GS/538/TDM/H2X/SS/INC/D15 7 11,108’ Upper Tandem Seal: 8 11,117’ Lower Tandem Seal: 9 11,126’ Motor: 562/ KMS2// 300HP/ 3255V/57A 10 11,147’ Guage @ Centralizer: Btm @ 11,151’ 11 11,734’ 7” Float Collar 12 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’ 11,331’ 7,076’ 7,081’ 8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’ 11,377’ 7,096’ 7,111’ 22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’ 11,403’ 7,116’ 7,128’ 18 2/24/1991 4.5” / 12spf/ Open Kup. A3 Sands 11,495’ 11,515’ 7,190’ 7,204’ 20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’ 11,557’ 7,208’ 7,233’ 36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,570’ 11,619’ 7,214’ 7,248’ 49 4/27/2024 3.375” / 6spf / Open Kup. A1 Sands 11,579’ 11,583’ 7,249’ 7,251’ 4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of Permafrost C in 30” Hole 9-5/8" Cmt w/ 1,090 sx Permafrost Class “E” & 330 sx Class “G”in 12-1/4” Hole 7” Cmt w/ 550 sx Premium Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DETAIL 2/26/1991 – Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E – 2/20/1991 SP RWO w/ Nabors 4ES - 5/2/1994 ESP RWO w/ Nabors 4ES - 6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 – 5/20/2011 ESP RWO w/ Nordic #3 – 2/24/2015 ESP RWO w/ ASR – 4/5/2021 ESP Swap & Perf Add w/ ASR#1 5/1/2024 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR#1 50-029-22028-00-00 190-037 4/19/2024 5/1/2024 Continue POOH w/ 3-1/2" workstring F/ 3,786' pumping double pipe displacement. OOH w/ BHA, recovered aprox. 10' of MLE, 1 flat guard, and multiple bands. P/U M/U Burn shoe BHA as per fishing hand. RIH w/ 3-1/2" workstring - tag fish at11,478'. PUH establish parameters. Begin burining over ESP. Continue POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/ 10,726' T/956' MD while maintaining 2x displacement. 4/20/2024 - Saturday Continue RIH w/ 3-1/2",10.37#,G-105, 2-7/8" IF DP, Scru Grab BHA# 1 while maintaining 1x displacement F/ 6,508' T/ 11,000' MD. Swivel up. Get parameters.PUW 93K SOW 43K RTW 62K. Free TQ 3000. Tag up @ 11,187' with 4K down. Swivel up and rotate. PUW 98K SOW 43K Set down, fish moving down hole. Push fish down to 11,478' TOF. Torque stall out @ 5,000 f/lb. set 10K down. POOH w/ 3-1/2" workstring F/ 11,478' T/ 3,186' pumping double pipe displacement. 4/23/2024 - Tuesday 4/21/2024 - Sunday Continue POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/956' MD while maintaining 2x displacement. ESP parted between Gas separator and intake. Gas release when opening Blinds. Test Blind Rams 250/2500psi (good) RIH w/ 3-1/2",10.37#,G-105, 2- 7/8" IF DP, Scru Grab BHA# 1 while maintaining 1x displacement T/ 6,508' MD. 4/22/2024 - Monday 4/19/2024 - Friday RIG ACCEPTED 00:00. Replace Mud Seal and Blind Ram elements. Test BOPE 250/2500psi - witnessed by AOGCC. Ensure well is static, Pull CTS & BPV. Install Landing Joint w/ TIW, Kelly up. Pull Hanger to floor - off seat at 98k, PUW = 90k. Pump 20bbls down IA. POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/ 11,159' T/ 10,726' MD 4/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/18/2024 - Thursday No operations to report. Continue POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/956' MD Test BOPE 250/2500psi - witnessed by AOGCC. POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/ 11,159' T/ 10,726' MD ESP parted between Gas separator and intake Req'd by Sundry 324-152. -WCB Push fish down to 11,478' TOF. Torque stall out @ 5,000 f/lb. set 10K down. POOH w/ 3-1/2" workstring F/ 11,478' T/ 3,186 Continue POOH w/ 2-7/8",6.5#,L,EUE ESP Completion F/ 10,726' T/956' MD Continue POOH w/ 3-1/2" workstring F/ 3,786' pumping double pipe displacement. OOH w/ BHA, recovered aprox. 10' of MLE, 1 flat guard, and multiple bands. P/U M/U Burn shoe BHA as per fishing hand. RIH w/ 3-1/2" workstring - tag fish at11,478'. PUH establish parameters. Begin burining over ESP Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR#1 & SL 50-029-22028-00-00 190-037 4/19/2024 5/1/2024 4/26/2024 - Friday Cont. to POOH w/ Burn shoe BHA F/ 7,987' S/O wt = 38K P/U wt = 58K Pumping double displacement. T/ 59'. pumping double displacement. Lay down Burn shoe BHA as per fishing rep. Rig up slick line P/U M/U 3.85" GR and 3.85" centralizer. RIH w/ slickline to 11,670' SLM tag TOF. POOH w/ SL. R/D SL. Pull wear ring. Set test hanger. P/U M/U test tools. Flood stack with fresh water. Test BOPE as per approved sundry. AOGCC waived witness. Test w/ 2-7/8" & 3-1/2" test joints to 250 low 2500 high f/ 5/5 charted mins. Perform accumulator drawdown test. L/D test tools. B/D lines. Line up for well operations. P/U dutch riser, space out & shut upper rams & lock in. Shut in annular as well. R/U wireline p/u PCE equip. Fill & prep to test. Test dutch riser & E-line PCE to 250 psi low & 2500 psi high f/ 5/5/ charted mins. (good test). Disconnect at quick test sub, P/U tee bar. Need extension for TWC. Wellhead rep. mobilizing to location. Clean & clear rig floor. 4/24/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. burning over fish at 2.3 bpm w/ 390 psi w/ 80 RPM 3.2 k free TQ. Observe psi increase indicating over fish to 460 psi. Burn over 5' to 11,483'. Make multiple passes to clean up fishing neck while rotating. Shut down rotation. Set dw 10K & 15K 2x on fish. Gain 15K overpull. Fish not moving past 11,483'. Shut dw pumps - 21bbl loss during burn over. With pumps off able to travel / chase fish down to 11,598', setting dw 10K. Break circ. at 2.5 bpm w/ 450 psi slight pressure increase indicating over fish to 610 psi. SD on fish w/ 5K at 11,610' rotate over / chase fish to 11,616'. P/U off bottom w/ 24K overpull and then 3-4K drag. Begin POOH F/ 11,616' at a depth of 11,570' observe 20K overpull while pulling through perfs. Cont. POOH w/ burn shoe BHA ( 5" ID) laying down singles to pipeshed. Pump double displacement for pipe tripped out of hole T/ BHA at 54' Change handling equipment. L/D burn shoe & wash pipe retrieve 3.18' of gas sep. shaft / inducer, one flat guard & discernible pieces of cable. Clean & clear rig floor. Remove fishing handling equip. Spot in slickline unit. R/U slick line for JB & GR (6.1") run. PJSM w/ crew. Hang sheave p/u slick line tools. Hang & zero depth at ASR rig floor. 4/25/2024 - Thursday RIH w/ JB & 6.1" GR on slick line At 11,486' SLM set dw multiply times. P/U w/ 1,300 lbs overpull, Jar free, POOH. Possible obstruction / perf debris at 11,486' SLM. Decision made to RIH w/ burnshoe & tag fish, ensuring on bottom. RIH w/ burn shoe. Work through tight spot in perfs at 11,480' - 11,490'. Tag fish on previous depth at 11,618' Set 7K down. POOH. Seeing slight drag in perfs ~ 5K. Run back to bottom ensure fish on depth. Tag at same mark. POOH. Drag in perfs from 11,480' -11,490' minimal. 2-3k. Cont. POOH. Pull TWC w/ tee bar. Montior IA (static). L/D tee bar, M/U guns as per AK E-line. P/U 48.6' of 3.375" 6 SPF 60 deg. phasing 22.7 gram .42 entrance w/ 46" pen. guns. M/U to Head/CCL-GR/BRT/49' 3-3/8" HSD & Test CCL (good) RIH w/ e-line guns. On bottom Make correlation pass. Discuss & correlate w/ GEO. Depth correct minus 24'. On depth with tie in gamma. TOF tag = 11,625' (gamma corrected) Set on bottom P/U to 11559.8', placing top shot at 11570' bottom shot = 11,618.6'. While in tension shoot guns, Guns fired. POOH. Slight drag pulling through new perfs. Out of hole. L/D guns. All shots fired. R/D E-line. L/D dutch riser. Pull test hanger. Install wear ring. P/U & M/U AS1X Test pack. RIH w/ 3-1/2" 9.5# G-105 workstring and test packer T/ 11,179''. M/U kelly hose, Swivel up P/U to place 7" test packer at 11,150' (ORKB corrected 11,166'). Set test PKR. Fill backside w/ 2.5 bbls. Pressure up back side testing 7" casing to 2000 psi. Hold for 30 charted mins (good test). 4/27/2024 - Saturday RIH w/ JB & 6.1" GR on slick line At 11,486' SLM set dw multiply times. P/U w/ 1,300 lbs overpull, Jar free, POOH. Possible obstruction / perf debris at 11,486' SLM. Decision made to RIH w/ burnshoe & tag fish, ensuring on bottom. RIH w/ burn shoe. Work through tight spot in perfs at 11,480' - 11,490'. Fish not moving past 11,483'. Test BOPE as per approved sundry. AOGCC waived witness placing top shot at 11570' bottom shot = 11,618.6'. While in tension shoot guns, Guns fired. POOH /D burn shoe & wash pipe retrieve 3.18' of gas sep. shaft / inducer, one flat guard & discernible pieces of cable. Cont. to POOH w/ Burn shoe BHA F/ 7,987' S/O wt = 38K P/U wt = 58K Pumping double displacement. T/ 59'. pumping double displacement. Lay down Burn shoe BHA as per fishing rep. Rig up slick line P/U M/U 3.85" GR and 3.85" centralizer. RIH w/ slickline to 11,670' SLM tag TOF. R/U slick lin Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR#1 & SL 50-029-22028-00-00 190-037 4/19/2024 5/1/2024 Hilcorp Alaska, LLC Weekly Operations Summary Cont. reel to reel splice of ESP cable. Completed splice. RIH w/ ESP. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE tubing T/ 11,114'. Pump continuous hole fill. Losing 4 BPH. checking cable every 1,000' P/U = 65K S/O = 40K P/U M/U Hlanding joint and hanger. Perform hanger splice. Drain stack. blow out fluid lines. Land hanger. S/O = 40K. RILDS. Pull landing joint. Set BPV. Begin RDMO. Rig released 12:00 4/30/2024. Cont. to service seals as per ESP reps. M/U intake, pump, Discharge head xo to 2-7/8" 6.5# L-80 EUE tubing. Completed M/U of ESP Assy. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE tubing f/ 85' T/ 7,820' Pump continuous hole fill. Losing 6.5 BPH. checking cable every 1,000' P/U = 42K S/O = 32K. Begin reel to reel splice. Perform reel to reel splice of ESP cable. Transfer source water to pits. Clean out sumps in pipe shed. Inspect equip. Swivel proxies, camera system. Clean rig. 4/30/2024 - Tuesday 4/28/2024 - Sunday Release 7" Test PKR. Ensure free travel up & dw. P/U = 82K S/O = 50K Pump a workstring volume = 96 bbls at 2.5 bpm w/ 220 psi. Final circ pressure = 200 psi. Shut down monitor well (static) B/D lines & remove kelly hose. POOH w/ 7" ASX1 test PKR. F/ 11,100' T/ 6,490 ' Pump double displacement for pipe pulled. Rig service. Regen rig 30 min downtime. VMS clear codes from rig. Fix small hyd. leak on carriage. POOH w/ 7" ASX1 test PKR. F/ 3,420'. OOH w/ test packer inspect & L/D. Clear floor of all fishing equipment. Pull wear ring. Swap over handling equipment for picking up ESP equipment. Load pipe shed with ESP equipment and 2-7/8" EUE pipe. Hang ESP sheave & cable. P/U ESP tools & handling equip. P/U motor & service. Service seals. Connect MLE & test (good) Cont. to P/U ESP assy. 4/29/2024 - Monday Drain stack. blow out fluid lines. Land hanger. S/O = 40K. RILDS RIH w/ ESP. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE tubing T/ 11,114'. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE tubing f/ 85' T/ 7,820' Pump continuous hole fill. Losing 6.5 BPH. checking cable every 1,000' P/U = 42K S/O = 32K. Begin reel to reel splice. Perform reel to reel splice of ESP cable. Transfer source water to pits. Clean out sumps in pipe shed. Inspect equip. Swivel proxies, camera system. Clean rig Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 Wellhead 50-029-22028-00-00 190-037 4/19/2024 5/1/2024 No operations to report. No operations to report. 5/4/2024 - Saturday No operations to report. 5/7/2024 - Tuesday 5/5/2024 - Sunday No operations to report. 5/6/2024 - Monday 5/3/2024 - Friday No operations to report. 5/1/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD: MU tbg hgr to 2 7/8 EUE LJ.PU and MU to completion string, Line up hgr to alignment pin, land into profile RKB 18.41 RILDS, BO alignment pin 11 turns, pull landing joint and set BPV. ASR RD BOP pulled clean void NU tree/adaptor. Test tbg hgr void to 500/5000 5/10 mins good test. Pulled 2.5 BPV with S10 Lubriacator. T/10 PSI IA/40 PSI and Sectured well. 5/2/2024 - 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: 5/10/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240510-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 242-04 50283201640000 212041 3/11/2024 AK E-LINE Perf LRU C-01RD 50283200610100 201168 4/26/2024 AK E-LINE Perf LRU C-02 50283201900000 223057 4/28/2024 AK E-LINE Perf MPU F-65 50029227526000 223121 5/3/2024 AK E-LINE HoistCut MPU L-07 50029220280000 190037 4/26/2024 AK E-LINE Perf NCIU A-17 50883201880000 223031 4/28/2024 AK E-LINE GPT/Perf NCIU B-02 50883200900100 197210 4/29/2024 AK E-LINE PPROF NCIU B-02 50883200900100 197210 5/4/2024 AK E-LINE PPROF PAXTON 6 50133207070000 222054 4/13/2024 AK E-LINE GPT/CIBP/Perf PAXTON 6 50133207070000 222054 4/16/2024 AK E-LINE GPT/CIBP/Perf SRU 14B-27 50133206040000 212089 4/23/2024 AK E-LINE Caliper SRU 32C-15 50133206130000 213070 4/24/2024 AK E-LINE Caliper TBU M-15 50733204220000 190109 4/18/2024 AK E-LINE GPT/Puncher TBU M-23 50733207190000 224018 5/1/2024 AK E-LINE CBL Please include current contact information if different from above. T38780 T38781 T38782 T38783 T38784 T38785 T38786 T38786 T38787 T38787 T38788 T38789 T38790 T38791 MPU L-07 50029220280000 190037 4/26/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 15:31:19 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Russell Gallen - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:MP L-07 weekly BOPE test. Date:Monday, April 29, 2024 4:25:57 AM Attachments:L-07 BOPE test report (weekly ) 2024.xlsx You don't often get email from russell.gallen@hilcorp.com. Learn why this is important Thank you. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 4/26/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #1900370 Sundry #324-191 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1985 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2 1/16"P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)17 P BOP Misc 0 NA Full Pressure Attained (sec)72 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 2412 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 14 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/25/24 06:20 Waived By Test Start Date/Time:4/26/2024 12:45 (date) (time)Witness Test Finish Date/Time:4/26/2024 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Tested with 2-7/8" & 3-1/2" test joints Precharge bottle psi = 1,012 psi C. Pace / M. Boord Hilcorp Alaska LLC A. Haberthur / R. Gallen MPU L-07 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0426_BOP_Hilcorp_ASR1_MPU_L-07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT L-07 JBR 06/07/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2 7/8" and 3.5" test joints used for testing. Test Results TEST DATA Rig Rep:C. Pace/ J. WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:A. Habethur/M. Heinz-Brow Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1900370 DATE:4/19/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC240417201225 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1985 Sundry No: 324-191 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11" 5000 P #1 Rams 1 2 7/8"x5" VB P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 1 2 1/16" 5000 P Kill Line Valves 3 2 1/16" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1900 200 PSI Attained P16 Full Pressure Attained P56 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2450 ACC Misc NA NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P11 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0      Hilcorp ASR1 - BOPE Test MPU L-07 (PTD 1900370) BOPE Test - Hilcorp ASR1 MPU L-07 AOGCC Insp # bopgdc240417201225 4/19/2024 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Change of Program 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,821'11,730' Casing Collapse Conductor 1,130psi Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 105' 13-3/8" 9-5/8" 7" 6,850' 11,777' MD 2,730psi 3,520psi 7,240psi 4,645' 7,360' 6,850' 11,777' Length Size Proposed Pools: 105' 105' 6.5# / L-80 / EUE 8rd TVD Burst 11,159' MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 190-037 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22028-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5/1/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-07 KUPARUK RIVER OIL N/A 7,418' 11,731' 7,327' 1,985 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:01 pm, Apr 01, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.01 11:14:09 - 08'00' Taylor Wellman (2143) 324-191 DSR-4/12/24 1,985 SFD 4/10/2024 * BOPE test to 2500 psi. * 30 minute charted MIT of inner casing to 1900 psi. 10-404 Perforate MGR16APR24JLC 4/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.16 16:21:13 -04'00'04/16/24 RBDMS JSB 041724 Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 Well Name:MPL-07 API Number:50-029-22028-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:5/1/24 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:190-037 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,710 psi at 7,249’ TVD SBHP 2/08/2021| 7.2 ppg, 7.4 KWF Max Potential Surface Pressure: 1,985 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 52° to 60° between 2,500’ -11,000’ MD Max Dogleg:4.99°/100’ at 6,789’ TVD Brief Well Summary: MPU L-07 well was drilled by Nabors 27E as a Kuparuk development well in February 2002. The well was perforated, Frac’d in the Kuparuk A, B & C sands and initially completed with an ESP. The well has had 11 ESPs failures to date. The current ESP failed 3/02/2024. Objectives: Pull failed ESP completion, test casing, run new ESP completion. Notes Regarding Wellbore Condition: x 7” Casing MIT at 11,126’ MD to 1,500 psi passed on 2/24/2015 x Offset Injector Support o C-19 – SI. o L-16 – Injecting 1,500 BPD water at 750 psi. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from 11,083’ to surface. 4. Run SBHPS with 10 min stops at 11,000’MD (6,849’ TVD) and 10,600’ MD (6,627’ TVD). 5. Attempt to pull dummy valve from GLM at 10,970’ MD and leave open. 6. Pull GLV and set dummy valve in upper GLM at 236’ MD. 7. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE to 250 psi low / 2,500 psi high. 2. PU 1.75” jet nozzle. 3. Jet down to discharge head at 11,083’ MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 10. Freeze protect tubing as POOH. 11. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. 6. RU spoolers to handle ESP cable and 3/8” capillary string. a. Use extreme care in spooling the capillary string to promote reuse of the string. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an WKM 11” x 2-7/8” 5M, with 2-7/8” EUE thread top and bottom. b. 2021 tubing PU weight on ASR #1 recorded as 85 kip. Slack off weight recorded as 33 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use tubing based on Caliper results. Confirm with engineer. b. Keep ported discharge head and centralizer for future use. Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 188 ii. SS Bands: 15 iii. Splice clamp: 1 iv. Seal Clamp: 4 v. Flat guards: 5 vi. Motor Bands: 4 Clamps on every joint for first 15 joints and then every other joint to surface 10. Lay Down ESP. 11. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 12. PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 11,670’ MD. 13. POOH and make 2 passes to scrape casing interval from 11,100’ to 11,200’ MD. 14. Circulate well clean. 15. POOH while filling hole with 2x displacement. 16. RU Eline, pressure test lube to 250 psi low and 2500 psi high. 17. RIH to perforate 11,570’-11,640’ MD. 18. Tie-in with the GR/CCL and send to Geologist & OE for correlation: Graham Emerson, graham.emerson@hilcorp.com, 907-793-0315 and Ryan Lewis 303-906-5178. 19. Perforate and POOH. Eline RDMO. 20. PU and RIH with 7” test packer to 11,150’ MD. 21. MIT the 7” casing charted to 1,900 psi for 30 minutes. 22. POOH with test packer. 23. RIH with 2-7/8” 6.5# L-80 ESP completion to +/- 11,145’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Summit, and cross coupling clamps every other joint. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 3 Intake Sensor 30 5.62 17 Motor - 300HP 80 5.2 9 Lower Tandem Seal 38 5.2 9 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 22 SGNPSH 45 5.38 24 Pump – SJ2800 45 5.38 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 perforate 11,570’-11,640’ MD Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 10,700 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 24. Land tubing hanger. Use extra caution to not damage cable. 25. Lay down landing joint. 26. Set BPV. 27. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic _____________________________________________________________________________________ Revised By: DH 4/27/2021 SCHEMATIC Milne Point Unit Well: MP L-07 Last Completed: 4/5/2021 PTD: 190-037 TD = 11,821’ (MD) / TD = 7,418’(TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.=53’ 7” 3 7 8 10 11 9 12 13 Casing Patch in 9-5/8” from 1,910’ to 1,930’– Installed 2/18/1991 9-5/8” 1 2 3/8”SS Capstring KUP A Sands PBTD =BB 11,732’(MD) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 14 5, 6 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 54.5 /K-55 / N/A 12.459 Surface 105' 9-5/8"Surface 36 / K-55 / Btrc 8.765 Surface 6,850’ 7"Production 26 / L-80 /Btrc 6.151 Surface 11,777’ TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 2.441 Surface 11,159’ 3/8” Capstring Stainless Steel N/A N/A 11,159’ JEWELRY DETAIL No Depth Item 1 236’2-7/8”GLM,ID = 2.390” 2 10,970’2-7/8”GLM, ID = 2.398” 3 11,028’XN-Nipple, ID = 2.313” 4 11,083’Discharge Head 5 11,083’Pump 2 6 11,099 Pump 1 7 11,115’Gas Separator GRSFTX AR HS 8 11,120’Upper Tandem Seal 9 11,129’Lower Tandem Seal 10 11,138’Motor, 562 series, KMS2, 240 HP, 2890 V, 51A 11 11,154’Motor Gauge 12 11,157’Centralizer –Bottom @ 11,159’ 13 11,734’ 7” Float Collar 14 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’11,331’7,076’7,081’8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’11,377’7,096’7,111’22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’11,403’7,116’7,128’18 2/24/1991 4.5” / 12spf/ Open Kup.A3 Sands 11,495’11,515’7,190’7,204’20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’11,557’ 7,208’7,233’36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,579’11,583’ 7,249’7,251’4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/500 sx of Permafrost C in 30” Hole 9-5/8" Cmt w/1,090 sx Permafrost Class “E”& 330 sx Class “G”in 12-1/4” Hole 7”Cmt w/550 sx PremiumClass “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DATA 2/26/1991 –Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E –2/20/1991 SP RWO w/ Nabors 4ES -5/2/1994 ESP RWO w/ Nabors 4ES -6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 –5/20/2011 ESP RWO w/ Nordic #3 –2/24/2015 ESP RWO w/ ASR –4/5/2021 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile _____________________________________________________________________________________ Revised By: TDF 3/7/2024 PROPOSED Milne Point Unit Well: MP L-07 Last Completed: 4/5/2021 PTD: 190-037 TD = 11,821’ (MD) / TD = 7,418’(TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.= 53’ 7” 3 5 8 10 11 9 12 13 Casing Patch in 9-5/8” from 1,910’ to 1,930’ – Installed 2/18/1991 9-5/8” 1 2 KUP A Sands PBTD =11,732’(MD) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 14 6 &7 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 9-5/8" Surface 36 / K-55 / Btrc 8.765 Surface 6,850’ 7" Production 26 / L-80 / Btrc 6.151 Surface 11,777’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface ±11,150’ JEWELRY DETAIL No Depth Item 1 XXX’ Sta #2: 2-7/8” GLM, ¼” OV 2 XX,XXX’ Sta #1: 2-7/8” GLM, DV Installed 3 XX,XXX’ XN-Nipple, ID = 2.313” / 2.205” No-Go 4 XX,XXX’ Ported Discharge Head: 5 XX,XXX’ Pump: 6 XX,XXX’ SGNPSH: 7 XX,XXX’ Gas Separator: 8 XX,XXX’ Upper Tandem Seal: 9 XX,XXX’ Lower Tandem Seal: 10 XX,XXX’ Motor: 300HP 11 XX,XXX’ Intake Sensor: 12 XX,XXX’ Centralizer – Bottom @ ±11,150’ 13 11,734’ 7” Float Collar 14 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’ 11,331’ 7,076’ 7,081’ 8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’ 11,377’ 7,096’ 7,111’ 22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’ 11,403’ 7,116’ 7,128’ 18 2/24/1991 4.5” / 12spf/ Open Kup. A3 Sands 11,495’ 11,515’ 7,190’ 7,204’ 20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’ 11,557’ 7,208’ 7,233’ 36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,579’ 11,583’ 7,249’ 7,251’ 4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of Permafrost C in 30” Hole 9-5/8" Cmt w/ 1,090 sx Permafrost Class “E” & 330 sx Class “G”in 12-1/4” Hole 7” Cmt w/ 550 sx Premium Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DETAIL 2/26/1991 – Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E – 2/20/1991 SP RWO w/ Nabors 4ES - 5/2/1994 ESP RWO w/ Nabors 4ES - 6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 – 5/20/2011 ESP RWO w/ Nordic #3 – 2/24/2015 ESP RWO w/ ASR – 4/5/2021 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile New perfs 11,570' - 11,640' MD. - mgr Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Nolan Vlahovich Hilcorp Alaska, LLC 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: 4/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240412 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU G-18 50029231940000 204020 3/21/2024 READ CaliperSurvey MPU L-07 50029220280000 190037 3/30/2024 READ CaliperSurvey PBU 01-19C 50029208000300 213171 2/22/2024 BAKER MRPM PBU 01-28B 50029215970200 223089 1/21/2024 BAKER MRPM PBU 11-42 50029237750000 223117 3/5/2024 HALLIBURTON RBT PBU N-11D 50029213750300 223083 2/14/2024 BAKER MRPM PBU N-21A 50029213420100 196196 3/28/2024 BAKER SPN PBU S-201A 50029229870100 219092 4/8/2024 READ LeakPointSurvey Please include current contact information if different from above T38705 T38706 T38707 T38708 T38709 T38710 T38711 T38712 T38713 MPU L-07 50029220280000 190037 3/30/2024 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 11:46:27 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,821' 11,730' Casing Collapse Conductor 1,130psi Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 105' 13-3/8" 9-5/8" 7" 6,850' 11,777' MD 2,730psi 3,520psi 7,240psi 4,645' 7,360' 6,850' 11,777' Length Size Proposed Pools: 105' 105' 6.5# / L-80 / EUE 8rd TVD Burst 11,159' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 190-037 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22028-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5/1/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-07 MILNE POINT KUPARUK RIVER OIL N/A 7,418' 11,731' 7,327' 1,985 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 12:32 pm, Mar 08, 2024 324-152 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.08 12:17:11 - 09'00' Taylor Wellman (2143) 10-404 SFD 3/20/2024MGR12MAR24 * BOPE test to 2500 psi. * 30 minute charted MIT of inner casing to 1900 psi. DSR-3/11/24 1,985 JLC 3/20/2024 Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 Well Name:MPL-07 API Number:50-029-22028-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:5/1/24 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:190-037 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,710 psi at 7,249 TVD SBHP 2/08/2021| 7.2 ppg, 7.4 KWF Max Potential Surface Pressure: 1,985 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 52° to 60° between 2,500 -11,000 MD Max Dogleg:4.99°/100 at 6,789 TVD Brief Well Summary: MPU L-07 well was drilled by Nabors 27E as a Kuparuk development well in February 2002. The well was perforated, Fracd in the Kuparuk A, B & C sands and initially completed with an ESP. The well has had 11 ESPs failures to date. The current ESP failed 3/02/2024. Objectives: Pull failed ESP completion, test casing, run new ESP completion. Notes Regarding Wellbore Condition: 7 Casing MIT at 11,126 MD to 1,500 psi passed on 2/24/2015 Offset Injector Support o C-19 SI. o L-16 Injecting 1,500 BPD water at 750 psi. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from 11,083 to surface. 4. Run SBHPS with 10 min stops at 11,000MD (6,849 TVD) and 10,600 MD (6,627 TVD). 5. Attempt to pull dummy valve from GLM at 10,970 MD and leave open. 6. Pull GLV and set dummy valve in upper GLM at 236 MD. 7. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE to 250 psi low / 2,500 psi high. 2. PU 1.75 jet nozzle. 3. Jet down to discharge head at 11,083 MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 10. Freeze protect tubing as POOH. 11. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8 and 3-1/2 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. 6. RU spoolers to handle ESP cable and 3/8 capillary string. a. Use extreme care in spooling the capillary string to promote reuse of the string. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an WKM 11 x 2-7/8 5M, with 2-7/8 EUE thread top and bottom. b. 2021 tubing PU weight on ASR #1 recorded as 85 kip. Slack off weight recorded as 33 kip. c. 2-7/8 L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8 tubing. a. Re-use tubing based on Caliper results. Confirm with engineer. b. Keep ported discharge head and centralizer for future use. Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 188 ii. SS Bands: 15 iii. Splice clamp: 1 iv. Seal Clamp: 4 v. Flat guards: 5 vi. Motor Bands: 4 Clamps on every joint for first 15 joints and then every other joint to surface 10. Lay Down ESP. 11. Pressure test pulled 3/8 capillary tubing to 3500 psi. If PT passes, plan to save for future work. 12. If scale or debris is reported during the pull, then PU a scraper otherwise proceed to RIH with 7 packer. 13. PU 3-1/2 workstring, 7 casing scraper, and muleshoe. RIH to 11,200 MD. 14. Circulate well clean. 15. Scrape casing interval from 11,100 to 11,200 MD. 16. POOH while filling hole with 2x displacement. 17. PU and RIH with 7 test packer to 11,150 MD. 18. Test 7 casing to 1,800 psi for 30 minutes. 19. POOH with test packer. 20. RIH with 2-7/8 6.5# L-80 ESP completion to +/- 11,150 and obtain string weights. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. c. Install ESP clamps per Summit, and cross coupling clamps every other joint. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 3 Intake Sensor 30 5.62 17 Motor - 300HP 80 5.2 9 Lower Tandem Seal 38 5.2 9 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 22 SGNPSH 45 5.38 24 Pump SJ2800 45 5.38 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 1900 . 25 * 7327 = 1831 psi or 1900 psi. Chart the same. - mgr Well: MPL-07 PTD: 190-037 API: 50-029-22028-00-00 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 10,700 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 21. Land tubing hanger. Use extra caution to not damage cable. 22. Lay down landing joint. 23. Set BPV. 24. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic _____________________________________________________________________________________ Revised By: DH 4/27/2021 SCHEMATIC Milne Point Unit Well: MP L-07 Last Completed: 4/5/2021 PTD: 190-037 TD =11,821 (MD) / TD = 7,418(TVD) 13-3/8 Fish @Approx 11,730 MD KB Elev.=53 7 3 7 8 10 11 9 12 13 Casing Patch in 9-5/8 from 1,910 to 1,930 Installed 2/18/1991 9-5/8 1 2 3/8SS Capstring KUP A Sands PBTD =BB 11,732(MD) / PBTD = 7,355(TVD) 4 RA Tag @ 11,137.5 14 5, 6 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 54.5 /K-55 / N/A 12.459 Surface 105' 9-5/8"Surface 36 / K-55 / Btrc 8.765 Surface 6,850 7"Production 26 / L-80 /Btrc 6.151 Surface 11,777 TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 2.441 Surface 11,159 3/8 Capstring Stainless Steel N/A N/A 11,159 JEWELRY DETAIL No Depth Item 1 2362-7/8GLM,ID = 2.390 2 10,9702-7/8GLM, ID = 2.398 3 11,028XN-Nipple, ID = 2.313 4 11,083Discharge Head 5 11,083Pump 2 6 11,099 Pump 1 7 11,115Gas Separator GRSFTX AR HS 8 11,120Upper Tandem Seal 9 11,129Lower Tandem Seal 10 11,138Motor, 562 series, KMS2, 240 HP, 2890 V, 51A 11 11,154Motor Gauge 12 11,157Centralizer Bottom @ 11,159 13 11,734 7 Float Collar 14 11,779 7 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,32311,3317,0767,0818 2/24/1991 4.5 / 12spf/ Open Kup. B Sands 11,35511,3777,0967,11122 2/24/1991 4.5 / 12spf/ Open Kup. B Sands 11,38511,4037,1167,12818 2/24/1991 4.5 / 12spf/ Open Kup.A3 Sands 11,49511,5157,1907,20420 2/24/1991 4.5 / 12spf/ Open Kup. A2 Sands 11,52111,557 7,2087,23336 2/24/1991 4.5 / 12spf/ Open Kup. A1 Sands 11,57911,583 7,2497,2514 2/24/1991 4.5 / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/500 sx of Permafrost C in 30 Hole 9-5/8"Cmt w/1,090 sx Permafrost Class E& 330 sx Class Gin 12-1/4 Hole 7Cmt w/550 sx Premium Class Gin 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 Max Hole Angle = 52 to 60 deg. From 2,500 to 11,000 Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600, 2,000, 2,500, 7,700, 9,400 & 10,900 FRAC DATA 2/26/1991 Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E 2/20/1991 SP RWO w/ Nabors 4ES -5/2/1994 ESP RWO w/ Nabors 4ES -6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 5/20/2011 ESP RWO w/ Nordic #3 2/24/2015 ESP RWO w/ ASR 4/5/2021 TREE & WELLHEAD Tree 2-9/16 5M WKM Wellhead 11 x 11 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5 CIW-H BPV profile _____________________________________________________________________________________ Revised By: TDF 3/7/2024 PROPOSED Milne Point Unit Well: MP L-07 Last Completed: 4/5/2021 PTD: 190-037 TD =11,821 (MD) / TD = 7,418(TVD) 13-3/8 Fish @Approx 11,730 MD KB Elev.= 53 7 3 5 8 10 11 9 12 13 Casing Patch in 9-5/8 from 1,910 to 1,930 Installed 2/18/1991 9-5/8 1 2 KUP A Sands PBTD =11,732(MD) / PBTD = 7,355(TVD) 4 RA Tag @ 11,137.5 14 6 &7 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 9-5/8" Surface 36 / K-55 / Btrc 8.765 Surface 6,850 7" Production 26 / L-80 / Btrc 6.151 Surface 11,777 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface ±11,150 JEWELRY DETAIL No Depth Item 1 XXX Sta #2: 2-7/8 GLM, ¼ OV 2 XX,XXX Sta #1: 2-7/8 GLM, DV Installed 3 XX,XXX XN-Nipple, ID = 2.313 / 2.205 No-Go 4 XX,XXX Ported Discharge Head: 5 XX,XXX Pump: 6 XX,XXX SGNPSH: 7 XX,XXX Gas Separator: 8 XX,XXX Upper Tandem Seal: 9 XX,XXX Lower Tandem Seal: 10 XX,XXX Motor: 300HP 11 XX,XXX Intake Sensor: 12 XX,XXX Centralizer Bottom @ ±11,150 13 11,734 7 Float Collar 14 11,779 7 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323 11,331 7,076 7,081 8 2/24/1991 4.5 / 12spf/ Open Kup. B Sands 11,355 11,377 7,096 7,111 22 2/24/1991 4.5 / 12spf/ Open Kup. B Sands 11,385 11,403 7,116 7,128 18 2/24/1991 4.5 / 12spf/ Open Kup. A3 Sands 11,495 11,515 7,190 7,204 20 2/24/1991 4.5 / 12spf/ Open Kup. A2 Sands 11,521 11,557 7,208 7,233 36 2/24/1991 4.5 / 12spf/ Open Kup. A1 Sands 11,579 11,583 7,249 7,251 4 2/24/1991 4.5 / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 500 sx of Permafrost C in 30 Hole 9-5/8" Cmt w/ 1,090 sx Permafrost Class E & 330 sx Class Gin 12-1/4 Hole 7 Cmt w/ 550 sx Premium Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 500 Max Hole Angle = 52 to 60 deg. From 2,500 to 11,000 Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600, 2,000, 2,500, 7,700, 9,400 & 10,900 FRAC DETAIL 2/26/1991 Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E 2/20/1991 SP RWO w/ Nabors 4ES - 5/2/1994 ESP RWO w/ Nabors 4ES - 6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 5/20/2011 ESP RWO w/ Nordic #3 2/24/2015 ESP RWO w/ ASR 4/5/2021 TREE & WELLHEAD Tree 2-9/16 5M WKM Wellhead 11 x 11 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5 CIW-H BPV profile Milne Point ASR Rig 1 BOPE 2023 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8 x 5 VBR 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,821'11,730' Casing Collapse Conductor 1,130psi Surface 2,020psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Ian Toomey Operations Manager Contact Email: Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng itoomey@hilcorp.com COMMISSION USE ONLY Authorized Name: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 190-037 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22028-00-00 Hilcorp Alaska LLC Length Size 7,418'11,731'7,327'2,335 N/A MILNE POINT / KUPARUK RIVER OIL 6,850' 6.5# / L-80 / EUE 8rd TVD Burst 11,142' 7,240psi MD Tubing Size:Tubing Grade:Tubing MD (ft): 7" 13-3/8" 9-5/8" 105' 6,850' 2,730psi 3,520psi 105' 4,645' 105' Authorized Signature: 4/10/2021 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): MILNE PT UNIT L-07 C.O. 432D N/A and N/A N/A and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 11,777'11,777' 7,360' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:48 am, Mar 30, 2021 321-153 Chad Helgeson (1517) 2021.03.30 06:28:52 - 08'00' DLB 03/30/2021 BOPE pressure test to 2500 psi. MGR30MAR21 X 10-404 2,335 DSR 3/30/21Comm 3/30/21 dts 3/30/2021 JLC 3/30/2021 RBDMS HEW 3/31/2021 ESP Changeout Well: MP L-07 Date: 3/29/2021 Well Name:MPU L-07 API Number:50-029-22028-00-00 Current Status:SI Producer (Failed ESP)Pad:L-Pad Estimated Start Date:April 10 th , 2021 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:190-037 First Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:Job Type:ESP Changeout Current Bottom Hole Pressure: 2,710 psi at 7,249’ TVD SBHP 2/08/2021|7.2 ppg Maximum Expected BHP:3,060 psi at 7,249’ TVD 30 dayPBU Extrapolation |8.2 ppg MPSP:2,336 psi (0.1 psi/ft gas gradient) Max Inclination:52° to 60° between 2,500’ -11,000’ MD Max Dogleg:4.99°/100’ at 6,789’ TVD Tree:Cameron 2-9/16” 5M Wellhead:WKM, 11” 5M Tubing Hanger Lift threads:2-7/8” EUE 8rd top & bottom BPV Profile:2-1/2” CIW Type H Brief Well Summary: MPU L-07 well was drilled by Nabors 27E as a Kuparuk development well in February 2002. The well was perforated, Frac’d in the Kuparuk A, B & C sands and initially completed with an ESP. The well has had ten ESP failures to date. The current ESP failed 1/30/2021. Notes Regarding the Well & Design x 7” Casing MIT at 11,126’ MD to 1,500 psi passed on 2/24/2015 x Offset Injector Support o C-19 – Injecting 1,300 BPD water at 1,600 psi. o L-16 – Injecting 2,500 BPD water at 1,200 psi. Objective: x Pull failed ESP Completion with 3/8” capillary tubing. x Run new ESP Completion with 3/8” capillary tubing Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU LRS. 4. Obtain updated fluid level shot and IA pressure to update KWF requirement. Contact operation engineer to confirm well kill. 5. Kill the well with seawater (volumes: tubing = 65 bbls & IA = 337 bbls). 6. Confirm well is dead. 7. RD LRS. 8. RU crane. Set 2-1/2” HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. ESP Changeout Well: MP L-07 Date: 3/29/2021 9. NU BOPE. RD Crane. 10. NU BOPE house. Spot mud boat. RWO Procedure: 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 12. Test BOPE to 250/2,500 psi, annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/ BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 13. RU to pull 2-7/8” ESP completion. 14. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with seawater and pull the BPV. 15. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. PU = 120K and SO = 70K when landed in 8.5ppg seawater by Nordic 3 (block weight = 35K) in 2015. 16. Lay down the landing joint and tubing hanger. RU to pull ESP cable over the sheaves to the spooling unit. a. Inspect the tubing hanger and note any damage. If any damage is found, contact well head specialist for redress or replacement. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8” tubing spooling ESP cable and capillary tubing. Lay down ESP and motor. a. Note any corrosion, sand, scale, damage or over torqued connections on the tubing with associated depths and ESP components on the morning report. Equipment Disposition Tubing hanger Visually inspect on site then reuse ESP Changeout Well: MP L-07 Date: 3/29/2021 Tubing & Pup joints Visually inspect on site then reuse Gaslift Mandrels/Nipple Visually inspect on site then reuse ESP equipment/Power Cable Centerlift to take possession for inspection and teardown 3/8” Chemical Injection line Visually inspect on site then reuse (PT to verify integrity) Protectorlizer (4)Visually inspect on site then reuse, restock or junk Cannon clamps (180)Visually inspect on site then reuse, restock or junk Flat Guard (3)Visually inspect on site then reuse, restock or junk SS Bands (1)Junk 18. RD ESP pulling equipment. 19. RU to run ESP completion. 20. PU and MU new Summit ESP assembly. Set base of ESP assembly at ±11,140’ MD. Check electrical integrity test every 1,000’. Install clamps on the first 15 joints then every other joint to surface. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Gas separator g. Pump #1 h. Pump #2 i. Ported discharge head j. Bolt on discharge head with pup joint, 2-7/8”, 6.5#, L-80, EUE 8rd box up k. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing l. Nipple, 2.313” XN (2.205” no-go) with 10’ handling pups above and below m. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing n. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below o. XXX joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing p. GLM, 2-7/8” x 1”, DSOV installed with 10’ handling pups above and below (setting depth ±136’ MD) q. X joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing 21. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator, MU the 3/8” Chemical injection line to the tubing hanger and dummy off any additional control line ports if present. 22. Land tubing hanger with extreme caution to avoid damaging the ESP cable, penetrator or 3/8” chemical injection line. RILDS. Record PU and SO weights on tally and WellEZ. 23. Set 2-1/2” HP BPV. Post-Rig Procedure: 24. RD mud boat. RD BOPE house. Move to next well location. 25. RU crane. ND BOPE. Install the plug off tool. 26. NU the tubing head adapter and NU 2-9/16” 5M tree. 27. PT the tubing hanger void to 500/ 5,000 psi. PT the tree to 250/ 5,000 psi. ESP Changeout Well: MP L-07 Date: 3/29/2021 28. Pull the plug off tool and BPV. 29. RD crane. Move returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production via handover form. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Stack Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: JRM 2/16/2021 SCHEMATIC Milne Point Unit Well: MP L-07 Last Completed: 2/24/2015 PTD: 190-037 TD = 11,821’ (MD ) / TD = 7,418’88 (TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.= 53’ 7” 3 6 7 9 10 9 11 12 Casing Patch in 9-5/8” from 1,910’ to 1,930’– Installed 2/18/1991 9-5/8”88 1 2 3/8” SS Capstring KUP A Sands PBTD =BB 11,732’(MD ) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 13 5 8 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 54.5 /K-55 / N/A 12.459 Surf 105' 9-5/8"Surface 36 / K-55 / Btrc 8.765 Surf 6,850’ 7"Production 26 / L-80 /Btrc 6.151 Surf 11,777’ TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 2.441 Surf 11,142’ 3/8” Capstring Stainless Steel N/A N/A 11,142’ JEWELRY DETAIL No Depth Item 1 136’GLM (Dummied 2/12/21) 2 10,894’GLM (Open pocket 2/12/21) 3 11,037’XN-Nipple 4 11,079.95’Discharge Head 5 11,080’SXD Pump 100P31 6 11,099’ Gas Separator GRSFTX AR HS 7 11,104 Upper Tandem Seal GSB3DBUT SB/SB PFSA 8 11,111’Lower Tandem Seal GSB3DBLT SB/SB FSA CL5 9 11,118’MotorCL5 MSP-3: 252hp, 2,275 Volts, 67 Amps 10 11,138’Pumpmate Sensor 11 11,140’Centralizer –Bottom @ 11,142’ 12 11,734’ 7” Float Collar 13 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’11,331’7,076’7,081’8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’11,377’7,096’7,111’22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’11,403’7,116’7,128’18 2/24/1991 4.5” / 12spf/ Open Kup. A3 Sands 11,495’11,515’7,190’7,204’20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’11,557’ 7,208’7,233’36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,579’11,583’ 7,249’7,251’4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/500 sx of Permafrost C in 30” Hole 9-5/8"Cmt w/1,090 sx Permafrost Class “E” & 330 sx Class “G”in 12-1/4” Hole 7”Cmt w/550 sx PremiumClass “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DATA 2/26/1991 –Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E –2/20/1991 SP RWO w/ Nabors 4ES -5/2/1994 ESP RWO w/ Nabors 4ES -6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 –5/20/2011 ESP RWO w/ Nordic #3 – 2/24/2015 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile _____________________________________________________________________________________ Revised By: TDF 2/12/2021 PROPOSED Milne Point Unit Well: MP L-07 Last Completed: 2/24/2015 PTD: 190-037 TD = 11,821’ (MD ) / TD = 7,418’88 (TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.= 53’ 7” 3 6 7 9 10 9 11 12 Casing Patch in 9-5/8” from 1,910’ to 1,930’– Installed 2/18/1991 9-5/8”88 1 2 3/8” SS Capstring KUP A Sands PBTD =BB 11,732’(MD ) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 13 5 8 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 54.5 /K-55 / N/A 12.459 Surface 105' 9-5/8"Surface 36 / K-55 / Btrc 8.765 Surface 6,850’ 7"Production 26 / L-80 /Btrc 6.151 Surface 11,777’ TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 2.441 Surface ±11,142’ 3/8” Capstring Stainless Steel N/A N/A ±11,142’ JEWELRY DETAIL No Depth Item 1 ±136’GLM 2 ±10,894’GLM 3 ±11,037’XN-Nipple 4 ±11,078’Discharge Head 5 ±11,080’Pump 6 ±11,099’ Gas Separator GRSFTX AR HS 7 ±11,104 Upper Tandem Seal 8 ±11,111’Lower Tandem Seal 9 ±11,118’Motor 10 ±11,138’Sensor 11 ±11,140’ Centralizer –Bottom @ ±11,142’ 12 11,734’ 7” Float Collar 13 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’11,331’7,076’7,081’8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’11,377’7,096’7,111’22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’11,403’7,116’7,128’18 2/24/1991 4.5” / 12spf/ Open Kup. A3 Sands 11,495’11,515’7,190’7,204’20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’11,557’ 7,208’7,233’36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,579’11,583’ 7,249’7,251’4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/500 sx of Permafrost C in 30” Hole 9-5/8"Cmt w/1,090 sx Permafrost Class “E” & 330 sx Class “G”in 12-1/4” Hole 7”Cmt w/550 sx PremiumClass “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DATA 2/26/1991 –Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E –2/20/1991 SP RWO w/ Nabors 4ES -5/2/1994 ESP RWO w/ Nabors 4ES -6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 –5/20/2011 ESP RWO w/ Nordic #3 – 2/24/2015 TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile 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 Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 29th, 2021Subject: Changes to Approved Sundry Procedure for Well MP L-07Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,821 feet N/A feet true vertical 7,418 feet 11,730 feet Effective Depth measured 11,730 feet N/A feet true vertical 7,327 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 11,159' 6,946' Packers & SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 777-8520 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 1,130psi 2,020psi 5,410psi Burst 3,730psi 3,520psi 7,240psi 4,645' 7,360' 6,850' 11,777' Surface Production 13-3/8" 9-5/8" 7" measured N/A Casing Conductor Length 400 MILNE PT UNIT L-07 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 127 Gas-Mcf 400 Casing Pressure Tubing Pressure 92 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-153 359 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-037 50-029-22028-00-00 Plugs ADL0025509 & ADL0047434 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3340 Oil-Bbl measured true vertical Packer Size 105' WINJ WAG 0 Water-Bbl MD 105' 6,850' 11,777' TVD 105' 2,101 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations NBy Meredith Guhl at 11:11 am, May 06, 2021 Chad Helgeson (1517) 2021.05.03 16:07:07 - 08'00' MGR30JUL2021 RBDMS HEW 5/6/2021 SFD 5/6/2021DSR-5/6/21 _____________________________________________________________________________________ Revised By: DH 4/27/2021 SCHEMATIC Milne Point Unit Well: MP L-07 Last Completed: 4/5/2021 PTD: 190-037 TD = 11,821’ (MD) / TD = 7,418’(TVD) 13-3/8” Fish @Approx 11,730’ MD KB Elev.=53’ 7” 3 7 8 10 11 9 12 13 Casing Patch in 9-5/8” from 1,910’ to 1,930’ – Installed 2/18/1991 9-5/8” 1 2 3/8”SS Capstring KUP A Sands PBTD =BB 11,732’(MD ) / PBTD = 7,355’(TVD) 4 RA Tag @ 11,137.5’ 14 5, 6 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 54.5 /K-55 / N/A 12.459 Surface 105' 9-5/8"Surface 36 / K-55 / Btrc 8.765 Surface 6,850’ 7"Production 26 / L-80 /Btrc 6.151 Surface 11,777’ TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 2.441 Surface 11,159’ 3/8” Capstring Stainless Steel N/A N/A 11,159’ JEWELRY DETAIL No Depth Item 1 236’2-7/8”GLM,ID = 2.390” 2 10,970’2-7/8”GLM, ID = 2.398” 3 11,028’XN-Nipple, ID = 2.313” 4 11,083’Discharge Head 5 11,083’Pump 2 6 11,099 Pump 1 7 11,115’Gas Separator GRSFTX AR HS 8 11,120’Upper Tandem Seal 9 11,129’Lower Tandem Seal 10 11,138’Motor, 562 series, KMS2, 240 HP, 2890 V, 51A 11 11,154’Motor Gauge 12 11,157’Centralizer –Bottom @ 11,159’ 13 11,734’ 7” Float Collar 14 11,779’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size /SPF/Status Kup. C Sands 11,323’11,331’7,076’7,081’8 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,355’11,377’7,096’7,111’22 2/24/1991 4.5” / 12spf/ Open Kup. B Sands 11,385’11,403’7,116’7,128’18 2/24/1991 4.5” / 12spf/ Open Kup.A3 Sands 11,495’11,515’7,190’7,204’20 2/24/1991 4.5” / 12spf/ Open Kup. A2 Sands 11,521’11,557’ 7,208’7,233’36 2/24/1991 4.5” / 12spf/ Open Kup. A1 Sands 11,579’11,583’ 7,249’7,251’4 2/24/1991 4.5” / 12spf/ Open OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/500 sx of Permafrost C in 30” Hole 9-5/8"Cmt w/1,090 sx Permafrost Class “E” & 330 sx Class “G”in 12-1/4” Hole 7”Cmt w/550 sx Premium Class “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 52 to 60 deg. From 2,500’ to 11,000’ Hole Angle through perforations = 47 deg. DLS > 4 deg./ 100 @ 1,600’, 2,000’, 2,500’, 7,700’, 9,400’ & 10,900’ FRAC DATA 2/26/1991 –Frac w/ 159,595lbs of 16-20 Carbolite behind pipe with all zones open. Screened out with 12.9 ppg at the perfs GENERAL WELL INFO API: 50-029-22028-00-00 Drilled and Cased by Nabors 27E –2/20/1991 SP RWO w/ Nabors 4ES -5/2/1994 ESP RWO w/ Nabors 4ES -6/12/1996, 8/2/1997, 6/24/2000, 10/7/2000, 5/25/2001, 3/3/2002 and 8/8/2005 ESP RWO w/ Doyon 16 –5/20/2011 ESP RWO w/ Nordic #3 – 2/24/2015 ESP RWO w/ ASR – 4/5/2021 Tree 2-9/16” 5M WKM Wellhead 11” x 11” 5M WKM tubing hanger 8rd EUE thread top & bottom, 2.5” CIW-H BPV profile Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR 50-029-22028-00-00 190-037 4/3/2021 4/7/2021 Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM, Discussed plan forward, Pre-Rig Pad Inspection walk thru with Pad Op-all good. Crew finished moving equipment and cleaning up around I-40. Mobe equipment from I-Pad to L-Pad. L-07 Set VR Plug and removed OA Valve. Cleared snow around the well cellar to spot well house and jet heaters. Spot mud boat. Began crane ops. Fly on well house. ND the tree, inspected and tested void. Could not spot pits due to the angle of the location. Called well support to disconnect and remove adjacent well house. Spot pusher shack and camps. Spotted crane and fly off L-49 well house. Spotted pits. NU the 11" BOP Stack. Fly on rig floor and laid out accumulator control lines. RDMO crane. Mobe ASR from A- pad to L-pad. Crew continued with ground work. Spotted ASR, raised mast and secured rack pins. Organized rig floor. Set stairs and hooked up kill/choke Lines. Spotted in rig Pump and conex's. Hooked up circulating lines. Spotted in glycol unit and began winterizing lines and equipment. Final torque up on stack. Install pipe rack containment and spot catwalk. Connect Koomey lines. Load pits with 50 bbls of fresh water. Spot and rig up flow back tank. Begin testing BOPE per AOGCC and well plan requirements as following: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi. Test Fire&Gas and preformed the Koomey drawdown test. No failures were recorded. 2-7/8" Test joint used. Witness was waived by Adam Earl on April 3, 2021 at 05:48. 4/3/2021 4/4/2021 PJSM, sundry review with Day Crew,L/D BOPE testing equipment, P/U 2-7/8" handling equipment and hung cable sheave. Loaded pits with 200bbls of 8.3 source water. Pulled the test plug, PU dry rod and check for pressure under BPV, tbg on a vacuum. Pulled BPV. Monitored well T/IA = 0/0. PU/MU 2-7/8" Landing joint w/TIW Install, IA open and BOLDS. Unseat tbg hanger and pulled to rig floor. PUW 85k. Cut cable and de-completed hanger. L/D hanger andlanding Joint. Hanger in good condition, wellhead group to inspect hanger closer in shop for reuse. Took 15bbls to fill the hole, continues fill monitor well losing 20bph. RU the elephant truck. L/D 3 jts and pulled cable and cap string over sheave to spoolers. POOH w/ 2-7/8” 6.5#, L-80 EUE tubing, spooling ESP cable and 3/8" cap-string. Tubing, cap-string, GLMs and clamps being inspected for reuse. Filling hole 5bbls every 15jts out. L/D 22jts. Rig operator wobbled the pipe 1/4 turn to line up the ESP cable with the slips and could get the wobble back in position to L/D pipe. Troubleshooting with ProStar why wobble will turn. Disconnected the hydraulics and manually turned the wobble. Will troubleshot after the well is completed. Cont POH w/ 2- 7/8” 6.5#, L-80 EUE tubing, spooling ESP cable and 3/8" cap-string and removing clamps. Tubing, cap-string, GLMs and clamps being inspected for reuse. Completion pulling clean. Filling hole 5bbls every 15jts out. Total of 77 jts LD, averaging 600' fph. Kicked out Jt #69, #70, #73 due to bad joints. Cont POH w/ 2-7/8” 6.5#, L-80 EUE tubing, spooling ESP cable and 3/8" cap-string and removing clamps. Tubing, cap-string, GLMs and clamps being inspected for reuse. Over pull @ jts 130 - 132. with 6k - 10k over. Suspect DLS at ESP depth. Continue OOH. Filling hole 5bbls every 15jts out. Total of 188 jts LD, kicked out Jts 92,153,154,157,176, 177 due to bad joints. Pull out ESP spooler and swap ESP reels. Continue POH w/ 2-7/8” 6.5#, L-80 EUE tubing, spooling ESP cable and 3/8" cap-string and removing clamps. Tubing, cap-string, GLMs and clamps being inspected for reuse. Completion pulling clean. Filling hole with 5bbls 8.33 ppg source water every 15 jts out. Total of 320 jts LD. Kicked Out 34 jts, bad threads. Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR 50-029-22028-00-00 190-037 4/3/2021 4/7/2021 Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM, checked fliuds and serviced ris as needed. Cont RIH w/ Summit ESP completion on 2-7/8” EUE tubing f/4,600' t/6,430'spooling cable and 3/8" cap string. Clamping every other joint and testing every 1000'. Clean trip in hole without set downs, SOW 22k,Swapped cable spools and Summit Rep Make Reel Splice, Cable Test Good. Filling hole 5bph, Cont RIH w/ Summit ESP completion on 2-7/8” EUE tubing, f/6,430 t/9,455' spooling Cable and 3/8" Cap String. Cable Splice fell 8' in on Joint 206, clamping every other Joint and testing every 1000'. Clean trip in hole without set downs, SOW 22k. Cont RIH w/ Summit ESP completion on 2-7/8” EUE tubing spooling cable and 3/8" cap string. Clamping every other joint andtesting every 1000'. Clean trip in hole without set downs, SOW 24k. Pinhole/crack in cap string. Secure cap string and beed off pressure. Secure and repair broken capillary line. Pressure up and test coupling. Begin to RIH and have another cap string failure on the rig floor. Shut down and secure cap string. Clean rig floor and prep to spool back to spooler. Move spooler and install new reel of cap string. Troubleshoot new reel of 3/8" cap string. Cap string appears to have internal plug or blockage. Able to pressure up on spooler end to 3000psi but no fluid movement on rig floor. Check with Baker to see if they have another reel available. In the meantime, continue to heat spooler trailer to thaw any potential ice. Move spooler and swap reels of 3/8" cap string to new 3000' reel. Establish circulation to rig floor. M/U cap string connection on floor. Pressure test entire string and new reel to 2500 psi. Test good. RIH w/Summit ESP completion on 2-7/8" EUE tubing, ESP cable and 3/8" cap string. Clamping every other joint and testing ESP cable every 1000'. Filling hole every hour with 8.33 ppg source water. Clean trip in hole without set downs. SOW 28k. PU Tbg Hanger at report time. Held PJSM, checked fluids and serviced rig as needed. Cont POH w/ 2-7/8” 6.5#, L-80 EUE tubing, Spooling ESP cable and 3/8" Cap-string and removing clamps. Tubing, Cap-string, GLMs and Clamps being inspected for reuse. Filling hole 5bbls every 15jts out. Total of 348 jts L/D, Kicked out 33 joints due galled threads. All clamps accounted for from previous RWO in 2015.,LD ESP assembly. The Pump would not turn, Seals full of well bore fluids. No corrosion, solids or visual damage on the ESP components. 3/8" cap-string was parted and wadded up around the centralizer. One bent fin on the centralizer. Cleaned and cleared rig floor. Staged Summit tools to service ESP on rig floor. RD the elephant trunk. Swapped ESP Spools. Offloaded and staged Summit ESP Equipment on the pipe racks. Tested 3/8" cap-string 3,000psi-good test. Pulled cap- string and cable over sheave to rig floor. HAL loaded DSOV in GLM. Filling Hole 5bph. PU/MU and serviced New Summit ESP assembly. Summit did not have the right motor and pump clamps. Discussed options with Town and decided to was 3/4" SS bands and flatguards. Continued servicing new Summit ESP assembly. RIH w/ Summit ESP completion on 2-7/8” tubing spooling cable and 3/8" cap string. Installing clamps on first 15 joints and every other joint thereafter. Mix 1/2 drum of Baro-Lube with 40 bbls source water. Fill hole with 10 bbls source water and 1.6% Baro-Lube. Cont RIH w/ Summit ESP completion on 2-7.8" tubing. Filled hole with 14 bbls source water with 1.6% Baro-Lube. RIH w/jt 42 and noted fluid at top of tubing. Stab and shut TIW. Prepare to install low pressure gauge and find tubing on vacuum. Pump 2 x tubing vol. and monitor well. Returns noted at surface @ 5bbls away. Monitor well and tubing for 15 minutes and note both stable. RIH w/ Summit ESP completion on 2-7/8” tubing spooling cable and 3/8" cap string. Total of 144 jts ran at report time. Clean trip in hole without set downs 4/6/2021 4/5/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP L-07 ASR 50-029-22028-00-00 190-037 4/3/2021 4/7/2021 Hilcorp Alaska, LLC Weekly Operations Summary 4/7/2021 PJSM, PU landing joint and tbg hanger with BPV installed. Cut cable make cable splice to the penetrator, MU 3/8" chemical line to hanger. Made final cable checks. Landed completion with 33k down on hanger. RILDS. BO/LD thelandingjt. EOT @ 11,160'. End of well work. Blow lines dry. Cleaned and cleared rig floor. RD cable sheave. Moved out pipe racks and catwalk. Cleared snow from the containment. Removed winterization and disconnected lines. Moved out rig pump, C-cans and Glycol Unit. Disconnect fire and gas. RDMO ASR and Pits. Moved rig to A-pad Tent for service checks. Roads and pads assisting the rig move to F-96. RDMO ASR and pits. Moved rig to A-pad tent for service checks. Began crane work. Fly off rig floor well house. ND BOP's/NU the Tree. RDMO crane. Tested void 500/5,000psi-good test. Pulled BPV. Secured well. Turn over to Ops. See F-96 Report. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 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 : 02/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-07 (PTD 190 -037) Multi Finger Caliper Log 02/12/2021 Please include current contact information if different from above. PTD: 1900370 E-Set: 34750 Received by the AOGCC 03/08/2021 03/09/2021 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM__.JN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ESP Changeout Performed: Alter Casing ❑ Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number Name: Hilcorp Alaska,LLC Development Q Exploratory 0 190-037 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22028-00-00 7.Property Designation(Lease Number): -8.Well Name and Number: ADL0047434 Milne Pt Unit KR L-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): U N/A Milne Point Field/Ic *aruk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,821 feet Plugs measured N/A flet`E C E I ^v E D true vertical 7,418 feet Junk measured 11,730 feet MAR 2 3 2015 Effective Depth measured 11,731 feet Packer measured N/A feet �"L��V1.A true vertical 7,327 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 2,730psi 1,130psi Surface 6,850' 9-5/8" 6,850' 4,645' 3,520psi 2,020psi Intermediate Production 11,777' 7" 11,777' 7,360' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic SriM� NE0 r,`'- 4 �' True Vertical depth See Attached Schematic �• Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 11,142'(MD) 6,936'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 119 34 1,066 260 202 Subsequent to operation: 195 233 1,755 240 205 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑� Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-092 Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name G Chris Kanyer Title Operations Engineer Signature z,.. Phone 907-777-8377 Date 3/23/2015 41-21- b� , RBDMS APR - 6 1015 Form 10-404 Revised 10/2012 � I //� Submit Original Only Milne Point Unit - Well: MPL-07 SCHEMATIC Last Completed: 2/24/2015 Hilcorp Alaska,LLC PTD: 190-037 CSING DETAIL 4 , KB EIev.53' Size Type Wt/Gade/Conn Drift ID Top Btm `` 13-3/8" Conductor 54.5 inAoKry K-55/N/A12.459Surf105'9-5/8" Surface36/ -55/Btrc8.765191 Surf6,850133/8" 7" Production 26/ -80/Btrc 6.151 Surf 11,777' 1rTBINGDETAIL�, �..� 2-7/8" Tubing6,5/L-80/EUE2.441Surf11,142'�" 3/8" CapstringStailessSteelN/AN/A11,142'• tCJEELRYDETAILihNo Depth Item 35/g .' 1 136' GLM Casing Patch r 9&8' 2 10,894' GLM from 1,910'to 1,930'- 3 11,037' XN-Nipple Irtstalled2/1819914 11,079.95' Discharge Head 5 11,080' SXD Pump 100P31 6 11,099' Gas Separator GRSFTX AR HS 7 11,104 Upper Tandem Seal GSB3DBUT SB/SB PFSA 8 11,111' Lower Tandem Seal GSB3DBLT SB/SB FSA CL5 3/8 � 9 11,118' Motor CL5 MSP-3:252hp,2,275 Volts,67 Amps 10 11,138' Pumpmate Sensor 11 11,140' Centralizer-Bottom @ 11,142' 12 11,734' 7"Float Collar �� 13 11,779' 7"Float Shoe 0, PERFORATION DETAIL '' Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Size/SPF/Status z 7.y4 0 Kup.C Sands 11,323' 11,331' 7,076' 7,081' 8 2/24/1991 4.5"/12spf/Open .4 Kup.B Sands 11,355' 11,377' 7,096' 7,111' 22 2/24/1991 4.5"/12spf/Open i.; >?' Kup.B Sands 11,385' 11,403' 7,116' 7,128' 18 2/24/1991 4.5"/12spf/Open L2 4 Kup.A3 Sands 11,495' 11,515' 7,190' 7,204' 20 2/24/1991 4.5"/12spf/Open Kup.A2 Sands 11,521' 11,557' 7,208' 7,233' 36 2/24/1991 4.5"/12spf/Open J: Kup.Al Sands 11,579' 11,583' 7,249' 7,251' 4 2/24/1991 4.5"/12spf/Open wWELL INCLINATION DETAIL 3 t KOP@500'' Max Hole Angle=52 to 60 deg. From 2,500 to 11,000Hole Angle through perforations=47 deg. '•4 DIS>4 deg./100 @ 1,600',2,000',2,500',7,700',9,400'&10,900' RA Tag @ _ 211,137.5 xi s OPEN HLE/CEMENT DETAIL 9 .6 13 3/8" Cmt w/500 sx of Permafrost C in 30"Hole 4 1Ai7 9-5/8" Cmt w/1,090 sx Permafrost Class"E"&330 sx Class"G"in 12-1/4"Hole l 8 7" Cmt w/550 sx Premium Class"G"in 8-1/2"Hole-TOC Calc.@ 10,300' P� _NOTE: Need cementing report to establish tops for 13-3/8"&9-5/8" FRAC DATA In2/26/1991-Frac w/159,595lbs of 16-20 Carbolite behind pipe with all zones k j•'t0 open. Screened out with 12.9ppg at the perfs til A TREE&WELLHEAD i 11 L�} Tree 2-9/16"SM WKM 't, 'il Wellhead 11"x 11"5M WKM tubing hanger 8rd EUE thread top&bottom, 14 2.5"CIW-H BPV profile Fshlincox .KUPASands GENERAL WELL INFO 11,730 MD API:50-029-22028-00-00 Drilled and Cased by Nabors 27E-2/20/1991 7,4117„' ds 12 13 SP RWO w/Nabors 4ES-5/2/1994 ESP RWO w/Nabors 4ES-6/12/1996, 8/2/1997,6/24/2000,10/7/2000,5/25/2001, 1D=11,821'(MD)/ID=7,418'(TVD) 3/3/2002 and 8/8/2005 PBTD=11,732'(MD)/PBTD=7,355'(TVD) ESP RWO w/Doyon 16-5/20/2011 ESP RWO w/Nordic#3-2/24/2015 Created By:TDF 3/9/2015 Hilcorp Alaska, C Weekly Operations S ummary H." ",Alay.kat'mw: Well Name API Number Well Permit Number Start Date End Date MPL-07 50-029-22028-00-00 _190-037 2/20/2015 'Z/24/ZOzS ta , `��"' '�� ' �v� �� 11.4 2/18/15-Wednesday No operations to report. 2/19/15-Thursday No operations to report. 2/20/15-Friday Rig accepted, rig up. Run hardline rig up cellar hoses, Berm cellar 2/21/15-Saturday Purge hardline/test/Z50psilow/Z'5OVpsihigh.Open upwell S|TP3ZOpsi'8CP59Opsi. Blow down well tokill tank mostly gasblowdov,n�b�5Vpg csgOOpsi RU�opumpdowntubin�pump|CP55Opdw/zO0psionchoke 8.5 ppg ' � . � seawater @ 140F.Catch circ @ 35 bbls,8.6 return warm seawater after 330 bbl(60 bbl early.)Continue circ hole volume,plentiful gas, pump 404 bbl total. Recovery 277 bbl mix oil/water. Lost 127 bbl. Fluid level was 1,250'48 hours prior to circ. Monitor well 30 minutesequalized after 15 mm .SET BPV. RD pump lines ND tree. NU BOPE,remove BPV, install TWC. Begin shell test:250psi low/3,000psi high.3 packing glands on hold downs leaking.Tighten same. Continue with test.All good. Kick and fire drill response time 23 sec.Test and chart BOP[Z5Opsi|ow/3'OOOpghigh. Test annular 250psi low/2,500psi high.Draw down test accumulator.Annulus open Pull 2 way check. Install landing jt and TIS. Back out lockdowns. PU pipe moving @ 112k 10-12K drag. Pull to hanger. Decomplete Hanger,fill hole 22 bbls. Cut ESP cable POOH with 3 stands thread cable to spooler. POOH SW 115K, LD jt 232 badly pitted.Continue to POOH. 2/22/15-Sunday PJSM.POOH LD 7 jts bent and crossthreaded. LD three 10'pup joints will not replace. Recover 181 LaSalle clamps,3 flat bars,5 protectolizers.Appears to be a miscount on the previous tally. BO/LD ESP assy.PU MU 7"scraper with 3.5'' mu|eshoeand x'overtnZ'7/O'' EUsproduction string to11'3O8' Crushed 1 jt in tongs LD same probably peviously damaged from RIH previous completion.Fill hole w/14 bbls. Pump tubing 68 bbls,attempt to achieve circulation in reverse circ.No circ. Lost 44 bbl.Monitor well losing 9 bbls every 30 minutes.POOH for casing test,packer run.LD 2 more jts bent pipe. PU MU 7"champ packer and RIH. 2/23/15-Monday PJSM.RIH w/champ packer.Space out champ packer to seal depth 11,126'and set with 20K down.350 jts.Fill hole 22 w^/\ bbl.Close pipe rams. Pressure test casing to 1,500 PSI and chart for 30 minutes. Bleed off pressure,open bypass, C'`^� release packer.POOH and BO/LD champ packer. PU/MU ESP BHA and service motor and seals.Install cap line and ESP line and test check valve cycle @4,JOOpsi.P]SN1.K|Hwith Z'7/8'' L80EUEh.5#tubing,3/8''S3cap string ESP cable and | Cannon clamps.Test ESP cable and capillary cycled @ 4,300 psi. RIH with ESP completion.All cap checks good 3,100- 3,400 psi. 2/24/15-Tuesday PJSM. RIH with completion 7,908'+/-,splicing cable.Splice and test cable.Good.Continue to run the ESP completion on 2'7/8''out ofthe derrick F/7,90D'T/11'115' P/U last GLM,M/U hanger&landing joint. 120k up/70k dn. Blocks&TD weight 40K. Make final cut on ESP cable and splice on penetrator.Terminate capillary string&install in hanger.Test cable&capulary string. Final clamp count. 185 Canon clamps, 1 Steel band,4 protectrolizers,3 flat guard. Land hanger. Verify&RILD.Back out and L/D landing joint. Install BPV.PJSM, N/D BOPS,slip&cut drilling line.Service hanger,orient hanger for penetrator&bolt hole alignment. N/U Tree.Test void to 250psi low/5,000psi high. Pull BPV,install IWC. Test tree 250psi low/5,000psi high. Prep for rig move. Release rig from MPL-07.Total|osaestoweU564bbiN1overig from MPL-07 To MPL-12. N, OF T�� ,vw\&\\��j,�sv THE STATE Alaska Oil and Gas �w '—s�� '� of Conservation Commission - - ALAS A et#__,_ 333 West Seventh Avenue OF ^QTR„ if GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS/CP' Fax• 907.276.7542 6' 'Li"' www.aogcc.alaska.gov N j Chris Kanyer Operations Engineer 0 37 Hilcorp Alaska, LLC I 1© 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR L-07 Sundry Number: 315-092 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P Sle Cathy P. oerster Chair DATED this 1/ day of February, 2015 Encl. RECEIVED STATE OF ALASKA FEB 18 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 2Q AAC 25.280 111.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well P/C/1'9-- Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 ' Time Extension❑ Operations Shutdown Cl Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Remove and Replace ESP 0 ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development 0 • 190-037 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22028-00-00 . 7.If perforating: l'I3C. (14 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.]73 Will planned perforations require a spacing exception? Yes ❑ No 0 Milne Pt Unit KR L-07• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0047434, Milne Point Field/Kkparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,821 7,418• 11,731 • 7,327 ' N/A 11,730 Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 2,730psi 1,130psi Surface 6,850' 9-5/8" 6,850' 4,645' 3,520psi 2,020psi Intermediate Production 11,777' 7" 11,777' 7,360' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic' See Attached Schematic 2-7/8" 6.5#/L-80/8rd EUE 11,188' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/23/2015 Oil 0 - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanverhilcorp.com Printed Name Chris Kanyer Title Title Operations Engineer Signature `/ •. C— Phone 777-8377 Date 2/17/2015 TYt+R 444tM471/ 4g. 6,4ets 1 OY6�ISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witnes3 Sundry Number: _ , U Plug Integrity ❑ BOP Test Lg' Mechanical Integrity Test ❑ Location Clearance ❑ Other: e 3000 ca 54 , i) C�.)4- ( /1/1 As( '31-Cc-X.) I''''` ' l_ Spacing Exception Required? Yes ❑ No EX Subsequent Form Required: i'D—''1 0'. APPROVED BY _, Approved by: COMMISSIONER THE COMMISSION Date: Z -/9 �- /s / j i).15–* — I W LN A Submit Form and Form 10-403(Revised 10/2012) pRIa li O I v I r 12 months fro the date of approval. Attachments in Duplicate RBDMS FEB 2 3 2015 , . • . 14 Well Prognosis Well: MPL-07 llileorp,Un,ka.Ll; Date: 2/17/2015 Well Name: MPL-07 API Number: 50-029-22028-00-00 Current Status: SI Producer Pad: L Pad Estimated Start Date: February 23, 2015 Rig: Nordic 3 Reg.Approval Req'd? February 23, 2015 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-037 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1454020 Current Bottom Hole Pressure: _2,723 psi @ 7,000' TVD (Last BHP measured 7/24/2012) Maximum Expected BHP: —2,723 psi @ 7,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 87% (0.426psi/ft) with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point L-07 well was drilled as a Kuparuk development well that TD'd at a depth of 11,821' and ran and cemented 7" production casing in February 2002. The well was perforated and Frac'd in the Kuparuk A, B, & C sands and initially completed with an ESP. The well has had nine ESPs failures to date. There is no recent casing pressure test performed and one will be completed during this workover. The most recent pump had a broken shaft is only able to produce at a reduced fluid rate. The well has been shut in preparation of an elective pull and replacement of the ESP. It will remain shut in until replaced. A downhole chemical injection line will be run as part of the new completion, but no scaling issues suspected in this well. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: it t\ ' Pull ESP, perform fill cleanout, pressure test casing,. & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg brine. Monitor well. 3. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3.000psihigh,.annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 11,188'to surface and lay down same. 5. RIH with 7" cleanout BHA to +/-11,583'. POOH with same. 6. RIH and set test packer at+/-10,850' (within 500ft of open perforations). k,� #I 7. Perform a charted casin&pressur_e_les.t tp.L5QOpsi for 3Omin. Weed off pressure and POOH with same. 9 ' Well Prognosis Well: MPL-07 Date: 2/17/2015 8. MU and RIH with ESP with gas separator and 3/8" chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-11,188'. Land tubing hanger. 9. ND BOP, NU and tree. 10. RDMO workover rig and equipment. 11. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit , ll Well: MPL-07 SCHEMATIC Last Completed: 5/20/2011 'Warp Alaska,LLC c PTD: 190-037 CASING DETAIL 4 c. KB Elev.:3' Size Type Wt/Grade/Conn Drift ID Top Btm k13-3/8" Conductor 5634.65. 4,5/K-55/N/A 12.459 Surf 105' �t 9-5/8" Surface 36/K-55/Btrc 8.765 Surf 6,850' 13-3/8" 7" Production 26/L-80/Btrc 6.151 Surf 11,777' , TUBING DETAIL 2-7/8" Tubing 6.5/L-8o/EUE 2.347 Surf 11,188' ,. '� JEWELRY DETAIL r i� No Depth Item p 1 137' Camco 2-7/8"x 1"Sidepocket KBMM GLM 9-5/g' 2 10,962' Camco 2-7/8"x 1"Sidepocket KBMM GLM Casing Patch in9 S8"• 3 11,100' 2-7/8"XN-Nipple(2.205"No-go ID) .uii 1412/01:11499310- 4 11,121' ESP Pump PMSXD 100-P31 VIretal5 11,140' Tandem Gas Separator Model-GSTHV -Intake(TVD=6,935') o' y. 6 11,143' Tandem Seal Section GSB3DB UT/LT SB/SB PFSA/FSA CLS l 'i 7 11,157' Centrilift MSP1 Motor 240hp/2,445 volt/59 amp O. 8 11,183' Centrilift PumpMate XTO W/6 Fin Centralizer(TVD=6,961') 4` 5' k'. 9 11,188' Bottom of Centralizer '' �� 10 11,734' 7"Float Collar 4 4ili. tzI 11 11,779' 7"Float Shoe ? ' CP PERFORATION DETAIL 'i Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Size/SPF/Status IKup.C Sands 11,323' 11,331' 7,076' 7,081' 8 2/24/1991 4.5"/12spf/Open Kup.B Sands 11,355' 11,377' 7,096' 7,111' 22 2/24/1991 4.5"/12spf/Open il Kup.B Sands 11,385' 11,403' 7,116' 7,128' 18 2/24/1991 4.5"/12spf/Open v 4: Kup.A3 Sands 11,495' 11,515' 7,190' 7,204' 20 2/24/1991 4.5"/12spf/Open '. 5i Kup.A2 Sands 11,521' 11,557' 7,208' 7,233' 36 2/24/1991 4.5"/12spf/Open �4 4 + L.' 2 Kup.Al Sands 11,579' 11,583' 7,249' 7,251' 4 2/24/1991 4.5"/12spf/Open WELL INCLINATION DETAIL '' 0 4. KOP @ 500' Max Hole Angle=52 to 60 deg. From 2,500'to 11,000' silo s Hole Angle through perforations=47 deg. 3 01 DLS>4 deg./100 @ 1,600',2,000',2,500',7,700',9,400'&10,900' OPEN HOLE/CEMENT DETAIL RATag© 71 }i 4 13-3/8" Cmt w/500 sx of Permafrost C in 30"Hole 11,137.5 9-5/8" Cmt w/1,090 sx Permafrost Class"E"&330 sx Class"G"in 12-1/4"Hole '$5 7" Cmt w/550 sx Premium Class"G"in 8-1/2"Hole-TOC Calc.@ 10,300' NOTE:Need cementing report to establish tops for 13-3/8"&9-5/8" 6 FRAC DATA 2/26/1991-Frac w/159,5951bs of 16-20 Carbolite behind pipe with all zones «r open. Screened out with 12.9ppg at the perfs 'a 4,7 w TREE&WELLHEAD i 8 , Tree 2-9/16"5M WKM alk 9 11"x 11"SM WKM tubing hanger 8rd EUE thread top&bottom, if Wellhead 2.5"CIW-H BPV profile m GENERAL WELL INFO ,1 lA API:50-029-22028-00-00 Saxls Fsh®°r°x is Drilled and Cased by Nabors 27E-2/20/1991 11,730 ND ,i SP RWO w/Nabors 4ES-5/2/1994 w ESP RWO w/Nabors 4ES-6/12/1996 ).?T at 10 11 ESP RWO w/Nabors 4ES-8/2/1997 ESP RWO w/Nabors 4ES-6/24/2000 1D=11,821'(MD)/TD=7,418'(TVD) ESP RWO w/Nabors 4ES- 10/7/2000 PBTD=11,732'(MD)/PBTD=7,355'(1VD) ESP RWO w/Nabors 4ES-5/25/2001 ESP RWO w/Nabors 4E5- 3/3/2002 ESP RWO w/Nabors 4E5- 8/8/2005 ESP RWO w/Doyon 16-5/20/2011 Created By:TDF 2/17/2014 Milne Point Unit • Well: MPL-07 PROPOSED Last Completed: 5/20/2011 Hilcorp Alaska,LLC PTD: 190-037 CASING DETAIL KB Elev.=53' Size Type Wt/Grade/Conn Drift ID Top Btm L 13-3/8"9-5/8" Conductor 54.5/K-55/N/A 12.459 Surf 105' Surface 36/K-55/Btrc 8.765 Surf 6,850' 13-3/8" 7" Production 26/L-80/Btrc 6.151 Surf 11,777' I( 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf ±11,190' 3/8" Capstring Stainless Steel N/A N/A ±11,190' JEWELRY DETAIL :;$ .1\ No Depth Item 9-5/3"'a & 1 ±140' GLM Casing Patch in 9-58" 2 ±10,960' GLM from 1,910'to 1,930'- 3 ±11,100' XN-Nipple ' Installed 2/18/1991 4 ±11,121' ESP Pump 5 ±11,140' Tandem Gas Separator 6 ±11,145' Tandem Seal Section 7 ±11,160' Motor 3/8"SSCapstring` 8 ±11,185' PumpMate XTO W/6 Fin Centralizer \y 9 ±11,190' Bottom of Centralizer 10 11,734' 7"Float Collar 11 11,779' i 7"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Size/SPF/Status Kup.C Sands 11,323' 11,331' 7,076' 7,081' 8 2/24/1991 4.5"/12spf/Open Kup.B Sands 11,355' 11,377' 7,096' 7,111' 22 2/24/1991 4.5"/12spf/Open Kup.B Sands 11,385' 11,403' 7,116' 7,128' 18 2/24/1991 4.5"/12spf/Open Kup.A3 Sands 11,495' 11,515' 7,190' 7,204' 20 2/24/1991 4.5"/12spf/Open 2 Kup.A2 Sands 11,521' 11,557' 7,208' 7,233' 36 _ 2/24/1991 4.5"/12spf/Open Kup.Al Sands 11,579' 11,583' 7,249' 7,251' 4 2/24/1991 4.5"/12spf/Open WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=52 to 60 deg. From 2,500'to 11,000' 3 Hole Angle through perforations=47 deg. DLS>4 deg./100 @ 1,600',2,000',2,500',7,700',9,400'&10,900' f - 4 OPEN HOLE/CEMENT DETAIL 1ag 11 1375@ ----SA 13-3/8" Cmt w/500 sx of Permafrost C in 30"Hole 9-5/8" Cmt w/1,090 sx Permafrost Class"E"&330 sx Class"G"in 12-1/4"Hole 5 7" Cmt w/550 sx Premium Class"G"in 8-1/2"Hole-FOC Calc.@ 10,300' [.. 6 NOTE: Need cementing report to establish tops for 13-3/8" &9-5/8" FRAC DATA 2/26/1991-Frac w/159,5951bs of 16-20 Carbolite behind pipe with all zones 7 open. Screened out with 12.9ppg at the perfs , 0 8 TREE &WELLHEAD Tree 2-9/16"SM WKM 9 11"x 11"5M WKM tubing hanger 8rd EUE thread top&bottom, Wellhead 2.5"CIW-H BPV profile GENERAL WELL INFO s KIP Drilled API:50-029-22028-00-00 Fsf @4ppr°x _} Drilled and Cased by Nabors 27E-2/20/1991 11,730 ND SP RWO w/Nabors 4ES-5/2/1994 ESP RWO w/Nabors 4ES-6/12/1996 7., A i 10 11 ESP RWO w/Nabors 4ES-8/2/1997 ESP RWO w/Nabors 4ES-6/24/2000 TD=11,821'(MD)/TD=7,418'(TVD) ESP RWO w/Nabors 4ES- 10/7/2000 PBTD=11,732'(MD)/PBTD=7,355'(TVD) ESP RWO w/Nabors 4ES-5/25/2001 ESP RWO w/Nabors 4E5- 3/3/2002 ESP RWO w/Nabors 4E5- 8/8/2005 ESP RWO w/Doyon 16-5/20/2011 Created By:TDF 2/10/2015 MPU BOP Stack • r O ,ft rrn rft al1tm1 art (fel t( i Hydril 13 5/8 5M , rt-ti rffi rffiiflutt ' (- 13(,5/88 5M 111)=$ 2 7/8"-5-%z" variables L-T_Lutptirw 14) Spacer spool 135/8 SM lEft rf1 iI 13 5/8 5M I. Blinds 0 ,_.5E rte- LLWUHUMUMIT ' ' 46 ilii.i11.liMILiii lux-tuAtp Lix qii- Spacer spool 13 5/8 5M ,dt_ rfT 11t ff i f 13 5/8" 5MX11" 5M DSA ! ill [ II _ III III Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~ O "' O~3t7' File Number of Well I History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~ Bren Vincent Nathan Lowell Date~,:Q,0~)--Is/ f~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd STATE OF ALASKA • ALAS L AND GAS CONSERVATION COMMISaN REPOR OF SUNDRY WELL OPERAMNS 1. Operations Performed: ❑ Abandon ∎_ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ∎ i Pull Tubing ❑ Perforate New Pool ❑ Waiver ■I Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory ' 190 - 037 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 4- 50 - 029 - 22028 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 047434 & 025509 MPL -07 9. Field / Pool(s): a Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 11821' feet Plugs (measured) None feet true vertical 7391' feet Junk (measured) —11730' feet Effective depth: measured 11730' feet Packer: (measured) None feet true vertical 7327' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 13 -3/8" 105' 105' 2730 1130 Surface 6815' 9-5/8" 6850' 4645' 3520 2020 Intermediate Production 11742' 7" 11777' 6958' 7240 5410 Liner Perforation Depth: Measured Depth: 11323' - 11583 `..u., AWNED JUN 1 6 2011 True Vertical Depth: 7050' - 7223' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 11188' 6964' Packers and SSSV (type, measured and true vertical depth): None None 11. Stimulation or cement squeeze summary: " E Intervals treated (measured): ($ ,F01r JUN Treatment description including volumes used and final pressure: Mika Oil & Gaii COrts. Commission Antcrm"rago 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 214 100 2,595 340 256 Subsequent to operation: 206 99 3,090 310 262 13. Attachments: 14. Well Class after work: ❑ Copies of Logs and Surveys run ❑ Exploratory a® Development ❑Service ❑Stratigraphic ® Daily Report of Well Operations Well Schematic Diagram 15. Well Status after work: ❑ GINJ # -4 Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Charles Reynolds, 564 -5480 N/A Printed Name Terrie Hubble Title Drilling Technologist � No Prepared By Name/Number: Signature " Ib/ 4 4A-65-et Phone 564 -4628 Date IT ( 11 Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 RBDMS JUN 1 ' 7 `�S Submit Original Only 6 i • 0 North America - ALASKA - BP'". Page 1 of 5 Operation Summary Report' Common Well Name: MPL -07 _____� AFE No _ ___ v— �� Event Type: WORKOVER (WO) ! Start Date: 5/3/2011 1 End Date: X4- 00TQK -E: (900,000.00 ) Project: Milne Point I Site: M Pt L Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 1/24/1991 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292202800 Active Datum: 11 : 07 1/19/1991 00:00 @56.00ft (above Mean Sea Level) Date 1 From - To 1 Hrs Task 1 Code 1 NPT NPT Depth Phase I Description of Operations (hr) 5/15/2011 •06:00 - 14:30 . 8.50 MOB P PRE MOB RIG. -PJSM AND MOB RIG OFF OF MPE -28. -L/D DERRICK, REMOVE BOPE EQUIPMENT, ATTACH BOOSTER WHEEL. 1 14:30 15:30 1 1.00 MOB P PRE 'CLEAN AROUND WELL MPE -28. -SPILL RESPONSE AROUND L -PAD. 1 1.5 GAL HYDRAULIC SPIL FROM PUMP 10 -RING FAILURE ON CAT LOADER. CHANGE OUT CABLE ON SKATE. 1 15:30 - 00:00 8.50 MOB P PRE !MOB RIG FROM MPE -28 DOWN MILNE POINT 1 ROAD TO L -PAD ACCESS. 17:15 HRS - LEFT MESSAGE WITH AOGCC 1 OF UPCOMING BOPE TEST. 24 HOUR NOTICE. -RIG ARRIVED ON L -PAD AT 22:00 HRS. -SPOT RIG ON FRONT OF PAD. 1- r - REMOVE BOOSTER WHEELS. 5/16/2011 00:00 - 03:00 3.00 1 MOB P PRE ' BRING IN AND INSTALL ROPE STACK INTO CELLAR. 1 I -LAY RIG MATS AROUND WELL. -RAISE DERRICK. 03:00 - 06:00 ' 3.00 MOB P ! PRE MOR RIG CA/FR WFI 1 MPI - f17 - [-EXTREMELY TIGHT LOCATION WITH 1 UTILIDOOR AND EDGE OF THE PAD ON BACKSIDE OF L PAD. -OVER THE WELL AT 04:30. CENTER AND SHIM RIG. 1-SPOT TANKS AND EQUIPMENT. 1 I- RIG EVAC DRILL, WITH AAR. RIG ACCEPTED AT 0600. 06:00 - 11:30 5.50 KILLW P r DECOMP RIGGING UP SURFACE LINES. - RIG PERFORMING MP2 MAINTENANCE WAITING ON WELLSUPPORT JOHN CRISP WITH AOGCC CALLED & 1 ASKED FOR AN UPDATE AT 18:00 11:30 14:30 3.00 KILLW P DECOMP 1 , FLUIDS ON LOCATION , 4 TRUCKS. 1 1 TAKING ON KWF, 11.9 PPG SODIUM BROMIDE ' WELLS SUPPORT SPOTTING THE SLOP TANK AND THE FLOW BACK TANK, RIGGING UP THE HARD LINE TO THE FLOW BACK ! 1- BUILDING THE CONTAINMENT BERM I AROUND THE SLOP TANK. 14:30 - 15:00 0.50 KILLW P 1 DECOMP RIG EVACUATION DRILL ! ' - RIG H2S DRILL. I AAR: ALL PERSONAL EVACUATED IN A TIMELY MANNER. THERE WAS A SLIGHT GAP IN THE DRILLERS ANNOUNCEMENT FOR WHERE THE ALARM 1 WAS BEING SEEN, SO THAT THE PEOPLE IN ! 1 'THE DOG HOUSE COULD EVACUATE THE 1 1 I CORRECT WAY. Printed 5/25/2011 4:04:28PM orth America - ALASKA - BP Page 2 of 5 n Summary Re perat�o ry ort p Common Well Name: MPL -07 1 AFE No Event Type: WORKOVER (WO) Start Date: 5/3/2011 I End Date: X4- 00TQK -E: (900,000.00 ) Project: Milne Point I Site: M Pt L Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 1/24/1991 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. LUWI: 500292202800 Active Datum: 11 : 07 1/19/1991 00:00 @56.00ft (above Mean Sea Level) Date 1 From - To Hrs 1 Task Code I NPT NPT Depth 1 Phase 1 Description of Operations (hr) I ft 15:00 17:30 2.50 KILLW P O DECOMP 1TESTING SURFACE LINES & EQUIPMENT 1 - RU PRESSURE TESTING EQPT. - PRESSURE TESTING TO 250 PSI LOW AND 1 14000 PSI HIGH FOR 5 CHARTED MIN. BOTH .TESTS GOOD. I -BLOW DOWN HARD LINE TO TANK. -CHANGE OUT TREE BONNET. 17:30 18:30 1.00 KILLW P DECOMP ! MU WELL SUPPORT LUBRICATOR - PRESSURE TEST TO 250 PSI LOW AND 4000 1 18:30 - 19:00 0.50 KILLW P ' I DECOMP ' PUI HIGH. GOOD TEST. HIGH. ;PULL BPV WITH DSM LUBRICATOR. -PSI ON TUBING OF 1100, PSI ON ANN. OF 1080. 19:00 - 20:00 1.00 KILLW P DECOMP INSPECT EQUIPMENT TO FLOW BACK TANK AND ALL HARD LINE. 1 - DOUBLE CHECK VALVE ALIGNMENT. I -PJSM WITH ALL HANDS. NOTIFY MP SECURITY AND PAD OP ON I VENTING GAS OPERATIONS. 1 -CLOSE AND CLEAR PAD OF ALL NON ESSENTIAL PERSONAL AND EQUIPMENT. 20:00 - 23:00 3.00 KILLW P DECOMP BLEED GAS CAP OFF OF WELL THROUGH I MANUAL CHOKE. -MAINTAIN 75 PSI ON LINE TO FLOW BACK 1 ! TANK. I - INITIAL PRESSURE OF 1100 PSI DROPPED 1 TO 630 PSI. -BLEED BACK 220 BBLS OF CRUDE WITH GAS. '- RECOVERED CRUDE SENT MILNE PLANT. 1 00 - 23:30 0.50 KILLW 23. � - � -'- - � - -- - - -- - - -- - - - -- P DECOMP , R/U TO PUMP DOWN TUBING AND TAKE RETURNS FROM ANN THROUGH SUPER 1 CHOKE. 1 1 -PUMP 75 BBLS OF 11.9 PPG BRINE DOWN TUBING. -PUMP AT 3 BPM AT 860 PSI. 1 23:30 - 00:00 0.50 KILLW P DECOMP I CLOSE ANN. VALVE. -BULL HEAD 76 BBLS AT 5 BPM AND 1900 PSI. 5/17/2011 00:00 - 03:30 1 3.50 KILLW P DECOMP CIRCULATE SURFACE TO SURFACE 385 BBLS I 1 AT 3 BPM 800 PSI TUBING PRESSURE -TOTAL LOSSES DURING CIRCULATION 52 1 1 IBBLS KILLW P 03:30 04:00 0.50 DECOMP MONITOR WELL - TUBING AND IA ON VAC - LOSSES -20 BPH 04:00 - 06:00 2.00 WHSUR P I DECOMP 1 RIG UP AND TEST DSM LUBRICATOR -250 PSI LOW, 4000 PSI HIGH FOR 5 1 I CHARTED MIN, GOOD TEST ! -SET AND TEST TWC -250 PSI LOW, 4000 PSI HIGH FOR 5 , CHARTED MIN, TEST GOOD 06:00 07:30 1 1.50 WHSUR P DECOMP ND TREE AND ADAPTER I FUNCTION LDS W/ 3 -3/4" IN AND 3 -1/2" OUT I TEST MU 2 -7/8" TO TUBING HANGER FOR 11 TURNS TO MU 1 07:30 09:30 2.00 BOPSUR 1 P 7 DECOMP NU BOPS AND INSTALL LOWER 2 -7/8" RAMS Printed 5/25/2011 4:04:28PM orth America - ALASKA BP Page 3 of 5 ion Summary Report perm rY P ort Common Well Name: MPL -07 I AFE No Event Type: WORKOVER (WO) I Start Date: 5/3/2011 End Date: 1 X4- 00TQK -E: (900,000.00 ) Project: Milne Point Site: M Pt L Pad - Rig Name /No.: DOYON 16 Spud Date/Time: 1/24/1991 12:00:OOAM Rig Release: Rig Contractor DOYON DRILLING INC. I UWI: 500292202800 Active Datum: 11 : 07 1/19/1991 00:00 @56.00ft (above Mean Sea Level) Date I From - To Hrs Task I Code NPT NPT Depth I Phase Description of Operations 09:30 16:30 7 0 BOPSUR P (ft) DECOMP - TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. TEST WITNESS WAIVED BY MATT HERRERA OF AOGCC. n I I I -RAMS TESTED TO 250 PSI LOW AND 4,000 1 PSI HIGH. j - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL & DDI TP. -ALL TEST FOLLOW TESTING CRITERIA I DOCUMENTED IN CRT - AK -10 -45 I,- MAINTAINING 20 BPH CONTINUOUS HOLE FILL IN THE IA DURING TESTING. KOOMEY DRAW DOWN TEST: -2850 PSI DRAWN DOWN TO 1750 PSI. I ' -200 PSI INCREASE IN 18 SECONDS. I -FULL PRESSURE IN 80 SECONDS. -5 N2 BOTTLES @ 1900 PSI. 16:30 - 18:00 1.50 BOPSUR P fi DECOMP RD TEST EQUIPMENT AND SUCK OUT STACK CLEAN OFF TOP OF TWC PROFILE 18:00 19:00 1.00 WHSUR P DECOMP RU TO PULL TWC WITH OPSO -LOPSO AND ' DSM HYDRAULIC LUBRICATOR 19:00 20:00 1.00 WHSUR N DECOMP OPSO = LOPSO TOO TALL AT RIG FLOOR, TRIED TO BACK IT OUT OF TUBING HANGER I AND PUP JOINT IN OPSO -LOPSO BACKED I OFF. -- TWC IS STILL SECURE IN WELL HEAD AND HAS NOT BEEN ENGAGED - -- ATTEMPT TO MU AND PULL ONCE MORE BUT I IUNABLE OPEN LOWER RAM DOOR AND BACK OUT I2 -7/8" x 4" XO AND POOH 20:00 - 21:00 1.00 BOPSUR N DECOMP MU TEST EQUIPMENT AND TEST LOWER RAM DOORS AT 250 PSI LOW AND 4,000 PSI I HIGH FOR 5 CHARTED MIN. RD FROM I PRESSURE TESTING. r 21:00 - 22:30 1.50 WHSUR N DECOMP RECONFIGURE OPSO -LOPSO WITH ONE LESS PUP JOINT AND TORQUE UP ALL CONNECTIONS RE -STAB OPSO -LOPSO INTO WELL HEAD I AND MU TO HANGER 22:30 00:00 1.50 WHSUR P DECOMP MU PUMP IN SUB AND HYDRAULIC LUBRICATOR TO OPSO -LOPSO AND TRY TO TEST TO 250/4,000 PSI , TOTAL LOSSES FOR THE DAY ARE = 457 I BBLS 5/18/2011 00:00 - 01:30 ' 1.50 -- WHSUR 1 P DECOMP PT D- - - - - SM HYDRAULIC LUBRICATOR TO 250 PSI I LOW AND 4,000 PSI HIGH FOR 5 MIN ' PULL TWC AND WELL IS STILL ON A VAC RD DSM AND SEND OUT 01:30 - 02:00 0.50 PULL P DECOMP MU CIRCULATING HEAD TO LANDING JOINT , MU LANDING JOINT TO TUBING HANGER I BACK OUT LDS PULL TUBING HANGER WITH -70 K UP WEIGHT Printed 5/25/2011 4:04:28PM North America - ALASKA - BP Page 4 of 5 • • 7 e r Lion Summary Report' ' ffp a �f P Common Well Name: MPL -07 LL�___.-------------------- �__------------ _- _...--------- - - ---- I AFE No Event Type: WORKOVER (WO) Start Date: 5/3/2011 I End Date: 1 X4- 00TQK -E: (900,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 1/24/1991 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. I UWI: 500292202800 Active Datum: 11 : 07 1/19/1991 00:00 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth I Phase I Description of Operations ( PULL P (ft) I DECOMP CBU THROUGH CHOKE AND GAS BUSTER 02:00 04:00 2.00 I STAGE UP TO 5 BPM @ 1960 PSI I 1 'BACK OFF TO 1900 PSI AND 4.75 BPM I I CAUGHT RETURNS AT 34 BBLS AWAY I LOSSES WERE 108 BPH AT 4.75 BPM ! CBU OF 457 BBLS WITH LOSSES / 5420 STKS WELL IS STILL ON A VAC WITH 24 BPH LOSS RATE 04:00 - 05:00� 1.00 PULL P DECOMP RD CIRCULATING LINE AND LD TUBING I (HANGER — ! - FEEDING WELL AT 20 BPH 1 05:00 06:00 1.00 PULL P DECOMP ' SECURE ESP CABLE AND RIH TO TAG FILL 1 ON ADDITIONAL 2-7/8" TUBING -RIH TO 11,645 FT ON 15 JOINTS OF 2 -7/8" !TUBING ! I- STOP WITH NO TAG OF FILL, BUT WERE 70 ' FT BELOW THE LOWEST PERFS 06:00 - 08:00 2.00 I PULL P I DECOMP rRU AND PREP TO PULL 2 -7/8" ESP COMPLETION ! - TOH , LD 15 SINGLES TO THE PIPE SHED. ! 1- FILL THE HOLE & ESTABLISH STATIC LOSS RATE, - 48 BPH LOSS RATE. - FILLING HOLE AT 20 BPH. I - ESTABLISH SPR'S 20 SPM @ 280 PSI AND 30 SPM @ 550 PSI - MONITOR FOR FLOW, NO FLOW 08:00 - 18:00 10.00 PULL P 1 DECOMP ' PULL OUT OF THE HOLE WITH FAILED ESP COMPLETION ON 2 -7/8" 8 RD EUE TBG . -TOH FROM 11,204' RACKING BACK IN THE DERRICK - VISUALLY INSPECTING, FLAGGING ANY BAD I I 1 JTS. I - PULL OUT WITH TWO STANDS AND MAKE UP ESP CABLE TO SPOOLING UNIT. I- MAINTAIN CONT HOLE FILL DURING TRIP @ ' 20 BPH. 18:00 - 19:00 , 1.00 PULL P DECOMP RU AND LD ESP ASSEMBLY RECOVERED 6 PROTECTOLIZERS, 3 FLAT 1 P GUARDS, 181 LESALLE CLAMPS 19:00 - 22:30 3.50 PULL DECOMP CLEAN AND CLEAR RIG FLOOR RD OLD ESP CABLE SECURE AND WRAP OLD ESP SPOOLS AND ! I ! REMOVE FROM SPOOLER LOAD NEW SPOOLS FOR NEW COMPLETION ' REMOVE ESP FROM PIPE SHED BREAK OUT XN NIPPLE AND DRESS XN NIPPLE WITH XXN PLUG 22:30 RUNCOM 00:00 1.50 P RUNCMP I p•ISM / MU NEW ESP ASSEMBLY ' MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH I DAILY LOSSES = 607 BBLS 5/19/2011 00:00 - 02:00 2.00 I RUNCOM P RUNCMP CONTINUE TO MU ESP TIE IN ESP CABLE AND TEST FEED HOLE AT 20 BPH Ii i 1 - -- - - - Printed 5/25/2011 4:04:28PM North America - ALASKA - BP Page 5 of 5 eration Summary Report Ai ler P rll Common Well Name: MPL -07 AFE No Event Type: WORKOVER (WO) I Start Date: 5/3/2011 ! End Date: X4- 00TQK -E: (900,000.00 ) Project: Milne Point Site: M Pt L Pad ! Rig Name /No.: DOYON 16 1 Spud Date/Time: 1/24/1991 12:00:OOAM 1Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292202800 Active Datum: 11 : 07 1/19/1991 00:00 @56.00ft (above Mean Sea Level) Date From - To 1 Hrs 1 Task I Code 1 NPT NPT Depth ''1 Phase � Description of Operations (hr) L 02:00 06:00 4.00 RUNCOM P RUNCMP RUN NEW ESP COMPLETION ON PREVIOUS ' 2 -7/8" 6.5#, L -80, EUE 8 RD TUBING INSTALLED 5 PROTECTOLIZERS AND 3 FLAT (GUARDS RE RUN XN NIPPLE WITH INSTALLED XXN PLUG WITH FILL TUBE 1 ! RE RUN BOTH GLM'S WITH BOTTOM GLM OPEN FOR CIRCULATION ! 1INSTALL CANNON CLAMPS ON THE FIRST 4 JTS, 2 PUPS, AND GLM ASSEMBLY PUPS, ' AND THEN ON EVERY OTHER JOINT CONTINUE TO MAINTAIN 20 BPH HOLE FEED 24 STANDS OF 116 IN THE HOLE AT 06:00 AND CONTINUING - r I 106:00 - 17:00 11.00 1 , RUNCOM ' P RUNCMP TIH WITH NEW ESP COMPLETION ON 2 -7/8" 8RD EUE TBG. - TIH WITH COMPLETION TO — 7,700' FEET ON 1243 OF 350 JNTS ! - FILLING EVERY 2000' AND CENTERLIFT CHECKING CONNECTIVITY, USING CANNON CLAMPS EVERY OTHER JOINT. - USING BEST 0 LIFE PIPE DOPE ON 1 CONNECTIONS - HAVING TO CHANGE OUT BAD JOINTS THAT WERE DAMAGED ON THE TRIP OU T O F THE HOLE. 20 JOINTS C/O SO FAR. - MAINTAINING CONTINUOUS HOLE FILL AT 1 20 BPH WITH 11.7 PPG NABR. 1- REEL TO REEL SPLICE , CENTRILIFT REPS PERFORMING SPLICE. MEETING WITH FIELD ENGINEER ABOUT THE CONDITION OF F -80 1 17:00 - 20:00 I 3.00 RUNCOM P RUNCMP PERFORMM REEL TO REEL SPLICE AND 20:00 22:30 2.50 RUNCOM TEST I - . P RUNCMP TO RUN COMPLETION, STILL ! I FINDING BAD JOINTS TO BE CHANGED OUT AFTER HAVING TO REPLACE ALL 3 JOINTS ! OF STAND 82, ESP CABLE WAS STARTING TO 1 I WAD UP 22 :30 00:00 1.50 RUNCOM N HMAN RUNCMP I STAND BACK TO STAND 79 TO GET KINKED ! I ESP CABLE BACK INTO SPOOLING UNIT 1 I 1 - SECURE TUBING WITH FLOOR SAFETY ,VALVE 1 -CUT OUT KINKED AREA FROM STAND 81/82 1 BACK TO PREVIOUS REEL TO REEL SPLICE -MAKE NEW REEL TO REEL SPLICE CONTINUE TO FEED HOLE 20 BPH ' LOSSES FOR THE DAY = Printed 5/25/2011 4:04:28PM Tree: 2 9/16" - 5M WKM M P L -07 Orig. KB EIe4)56.0' (N 27E) Wellhead: 11" x 11" 5M WKIW Orig. GL EIe 21.0' w/ 11" x 2 7/8" WKM tbg. hgr, 8rd KB To 7" csg. hng. = 34' (N 27E) EUE threads top & bottom, 2.5" CIW H BPV profile 13 3/8 ", 54.5 ppf, K -55 csg. 1 105' I 1 Camco 2 7/8" x 1" KOP @ 500' , 137` Max. hole angle = 52 to 60 deg. f/ sidepocket KBMM GLM 2500' to 11,100' Hole angle thru' perfs = 47 deg. DLS > 4 deg. /100' @ 1600', 2000', 2500', 7700', 9400', &10,900' 1 11 9 5/8 ", 36 ppf, K -55 Btrc 6850' and Camco 2 7/8" x 1" 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. sidepocket KBMM GLM I 10962' I ( drift ID = 2.347 ', cap. = 0.00592 bpf) ,,,, 7" 26 ppf, L -80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) HES "XN" Nipple 1 11100` _ v_ d a_ (2.205" No -go ID) ESP Pump PMSXD I 11121' 100 -P31 Radioactive Marker at 11,132' wlm w , • _; Tandem Gas Separator 11140` GSTHV Intake TVD 1 6935' p' Tandem Seal Section Stimulation Summary GSB3 DB UT /LT SB /SB PFSA/FSA CL5 I 11143 02/25/91 - Fraced w/ 150.4 M# ► Centrilift MSP1 Motor ( 11157` I 16 -20 Carbolite behind pipe with 240 hp / 2455 volt / 59 amp all zones open. Screened out w/ MIK 12.6 ppg at the perfs. Centrilift PumpMate XTO 1 11183` I 1 w/ 6 Fin Centralizer Perforation Summary PumpMate TVD 1 6961' Ref log: 02/14/91 DIL / SFL Size SPF Interval (TVD) 4.5" 12 11,323'- 11,331' (7076- 7081') 4.5" 12 11,355- 11,377' (7096- 7111') 4.5" 12 11,385- 11,403' (7116- 7128') — 4.5" 12 11,495- 11,516' (7190'- 7204') — 4.5" 12 11,521'- 11,557' (7206- 7233') 4.5" 12 11,579'- 11,583' (7246- 7251') Fish* Last Drift: 5/20/11 RWO to 11645' MD 60 deg. phasing — No fill tagged. 7345' TVD 1 Mid -Pert TVD = 7163' Mid -Perf MD = 11453' • 7" float collar (PBTD) 11 1,734' * Fish: 12 cable bands and one 7" float shoe I 11,779' I flat guard DATE REV. BY COMMENTS MILNE POINT UNIT 03/03/92 JBF Drilled and Cased by Nabors 27E 6/24/00 MDO ESP RWO Nabors 4 - es WELL MPL -07 10/7/00 GMH ESP RWO Nabors 4ES 05/25/01 BMH ESP RWO Nabors 4ES API NO: 50- 029 -22028 03/03/02 M. Linder ESP RWO Nabors 4 -es 08/08/05 Lee Hulme ESP RWO Nabors 4ES 05/20/11 Lee Hulme ESP RWO Doyon 16 BP EXPLORATION (AK) OPERABLE -MPL-07 (PTD #1370) Online ESP completion • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer (NSUADWWeIllntegrityEngineer@BP.com] .~ Sent: Wednesday, March 12, 2008 3:19 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R Cc: Roschinger, Torin T.; Hassanali, Hamid Subject: OPERABLE -MPL-07 (PTD #1900370) Online ESP completion i all, Milne Point Well MPL-07 is back online as of 03110I08. on 03112108 the wellhead pressures were tubingllAlOA equal to 276138012fl. The well has been reclassified as Operable. From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 20, 2008 9:40 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Hassanali, Hamid Subject: UNDER EVALUATION -MPL-07 High IAP due to ESP completion Hi all, Milne Point Well MPL-07 is a packerless ESP completion. Due to the IA being open to formation and the well being shut- in, the well has confirmed high IA pressure. The wellhead pressures were tubing/IA/OA were shut-in/2360/0 on 02/19/08. The well has been reclassified as Under Evaluation on a 28 day clock starting 02/16/08. The plan forward includes: 1. MP: Eval for bleeding the IA pressure and pumping fluid down the IA to knock down the pressure 3/14/2008 RE: UNDER EVALUATION - Nom,-07 (PTD #1900370) High IAP due to ESP completion Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, February 20, 2008 11:37 PM ~ ~~ 3~ 1 ~'~~°v- To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION -MPL-07 (PTD #1900370) High IAP due to ESP completion ,~ Attachments: MPL-07 90-day TIO plot.BMP; MPL-07.pdf I apologize I forgot the PTD number, schematic, and TIO plat for refierence. «MPL-07 90-day TIO plot.BMP» «MPL-07.pdf» From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 20,.2008 9:40 PM ~"' To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Hassanali, Hamid Subject: UNDER EVALUATION -MPL-07 High IAP due to ESP completion ~~~~~ ~I~~ ~ ~, 200 Hi all, Milne Point Well MPL-07 (PTD #1900370) is a packerless ESP completion. Due to the lA being open to formation and the well being shut-in, the well has confirmed high IA pressure. The wellhead pressures were tubing/IA/OA were shut- in/2360/0 on 02/19/08. The well has been reclassified as Under Evaluation on a 28 day clock starting 02/16/08. The plan forward includes: 1. MP: Eval for bleeding the IA pressure and pumping fluid down the IA to knock down the pressure 3/13/2008 a,aoo ~ 3,000 2,000 I,a, MAASP C:~,~', r~I~.~.SP 1,000 # Tbg f -~- IA -~ 0~, OOR 0 - - 000• 11 ~20~2007 1215007 12~20~2007 1 Pa~2008 1 ~0l2008 2I412008 2~0~008 3J6l2008 __ _ _ _ _ ............T41'P'L~T'T1LYPr8Y .............. j I Tree: 2 9/16" - 5M W Wellhead: 11" x 11" KM w/ 11" x 2 7/8" WKM tbg, hgr, $rd ' EUE threads top & bottom, 2.5" CIW H BPV profile 13 3/8", 54.5 ppf, K-55 csg. 105' KOP @ 500' Max. hale angle = 52 to 60 deg. f/ 2500' to 11,100' Hole angle thru' perfs = 47 deg. DLS > 4 deg./100' @ 1600', 2000', 2500', 7700', 9400', &10,900' 9 5/8", 36 ppf, K-55 Btrc 6850' and 2 718" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, B#rc. production casing (drift ID = 6.151", cap. = 0.0383 bpf ) Radioactive Marker at 11,132' wlm Stimulation Summary 02!25191 - Fraced w/ 150.4 M# 16-20 Carbolite behind pipe with all zones open. Screened out w/ 12.6 ppg at the perfs. Perforation Summary Ref log: 02/14(91 DIL ! SFL Size SPF Interval (TVD) 4.5" 12 11,323'-11,331' (7076'-7081') 4.5" 12 11,355'-11,377 (7096'-7111') 4.5" 12 11;385'-11,403' (7116'-7128') 4,5" 12 11.495'-11,516' (7190'-7204') 4.5" 12 11,521'-11,557' (7208'-7233') 4.5" 12 11;579'-11,583' (7249'-7251') 60 deg. phasing Mid-Perf TVD = 7163' Mid-Perf MD = 11453' Fish: 12 cable bands and one flat gaurd Orig. ~lev. = 56.0' (N 27E) Orig. fev. = 21.0' KB To 7" csg. hng. = 34' (N 27E} Camco 2 7/8" x 1" 167` sidepocket KBMM GLM Camco 2 7/8" x 1" 10966` sidepocket KBMM GLM HES "XN" Nipple (2.205" ID} 11105` w/ collar Tandem Pump 11127` 52/74GC3500 GMPTAR 1:1 Intake TVD 6926' Tandem Gas Separator 11154` GRSTXARH6 Tandem Seal Section 11160` GS63 DB UT/LT AB/HSN PFSA/FSA CL5 Centrilift KMH 562 series, 11173` 304 hp, 2290 volt! 81 amp Centrilift PumpMate 11199` w/ 6 Fin Centralizer PumpMate TVD 6971' 7345' TVD 7" float collar (PBTD) 11,734' 7" float shoe 11,779' DATE REV. BY COMMENTS 03/03/92 JBF Drilled and Cased by Nabors 27E 6124/00 MDO ESP RWO Nabors 4 - es 1017/00 GMH ESP RWO Nabors 4ES 05(25/01 BMH ESP RWO Nabors 4ES 03/03/02 M.Linder ESP RWO Nabors 4-es 08/08/05 Lee Hulme ESP RWO Nabors 4ES MILNE POINT UNIT WELL MPL-07 API NO: 50-029-22028 BP EXPLORATION nnP~-a7 'I STATE OF ALASKA '\ ALASKA )L AND GAS CONSERVATION CO.",.V1ISSION REPORT OF SUNDRY WELL OPE RATIO Nc:§:::, S'E:P 1 (F~ 20 nr: " .., u:] 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Change out ESP o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 190-037 6. API Number: 50-029-22028-00-00 99519-6612 56' 9. Well Name and Number: MPL-07 8. Property Designation: ADL 047434 11. Present well condition summary Total depth: measured 11777 feet true vertical 7360 feet Effective depth: measured 11732 feet true vertical 7328 feet 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands Plugs (measured) Junk (measured) approx. 11730' Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 70' 6815' 13-3/8" 9-5/8" 105' 6850' 105' 4645' 2730 3520 1130 2020 11742' 7" 11777' 7360' 7240 5410 ii.," ø-' i' I¡Ü Iil.Ut.:: r:) (; F P t;;.~~^ß~ßl¡J~';;"._, \" - C" ,(~~ ~ Perforation Depth MD (ft): Perforation Depth TVD (ft): 11323'-11583' 7050' - 7223' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# L-80 11203' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFL SEP 1 9 2005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman ..A Title Technical Assistant ignature Form 10-404 Revised 04ì2004 CO: ~'..~~o?:. ¡ í\ '5~1750 \_ I, '\ ~ r,,,) ~ \ \J 1-\ L i \ Prepared By Name/Number: Date ffi - \ I. - OS3ondra Stewman, 564-4750 Submit Original Only Tree: 2 9/16" - 5M WKM Wellhead: 11" x 11" 5 )KM w/ 11" x 2 7/8" WKM tb8. ngr, 8rd EUE threads top & bottom, 2.5" CIW H BPV profile 13 3/8", 54.5 ppf, K-55 csg. I 105' I · KOP @ 500' Max. hole angle = 52 to 60 deg. fl 2500' to 11,100' Hole angle thru' perfs = 47 deg. DLS > 4 deg./1 00' @ 1600', 2000', 2500',7700', 9400', &10,900' 95/8", 36 ppf, K-55 Btrcl6850' mdl ~ 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6,151 ", cap. = 0.0383 bpf ) MPL-07 Or~g. V'"''{:lev.: 56.0: (N 27E) Ong. Elev. - 21.0 KB To 7" csg. hng. = 34' (N 27E) .. Cameo 2 7/8" x 1" sidepocket KBMM GLM 167' , Cameo 27/8" x 1 II side pocket KBMM GLM I 10966' I HES "XN" Nipple (2.205" ID) I 11105' I wi collar Tandem Pump I 11127' I 52/74GC3500 GMPTAR 1:1 Radioactive Marker at 11,132' wlm v Intake TVD I 6926' 1 A. Tandem Gas Separator I 11154' I GRSTXARH6 Tandem Seal Section I 11160' I Stimulation Summary GSB3 DB UT/L T AB/HSN PFSA/FSA CL5 02/25/91 - Fraced wi 150.4 M# Centrilift KMH 562 series, 11173'1 16-20 Carbolite behind pipe with 304 hp, 2290 volt/ 81 amp all zones open. Screened out wi 12.6 ppg at the perfs. Centrilift PumpMate 11199' I wi 6 Fin Centralizer Perforation Summary PumpMate TVD I 6971' I Ref log: 02/14/91 DIL / SFL Size SPF Interval (TVD) 4,5" 12 11,323'-11,331' (7076'-7081 ') 4.5" 12 11,355'-11,377' (7096'-7111 ') 4.5" 12 11,385'-11,403' (7116'-7128') ] 4.5" 12 11,495'-11,516' (7190'-7204') 4,5" 12 11,521'-11.557' (7208'-7233') 4,5" 12 11,579'-11,583' (7249'-7251 ') 60 deg. phasing 7345' TVD Mid-Perf TVD = 7163' Fish* 111,734' I Mid-Perf MD = 11453' 7" float collar (PBTD) ~ ~ I 11 ,779' I * Fish: 12 cable bands and one 7" float shoe flat gaurd DATE REV,BY 03/03/96 6/24/00 10/7/00 OS/25/01 03/03/02 08/08/05 JBF MOO GMH BMH M.Linder Lee Hulme COMMENTS Drilled and Cased by Nabors 27E ESP RWO Nabors 4 - es ESP RWO Nabors 4ES ESP RWO Nabors 4ES ESP RWO Nabors 4-es ESP RWO Nabors 4ES MILNE POINT UNIT WELL MPL-07 API NO: 50-029-22028 BP EXPLORATION (AK) ) ) BP EXPLÖRATION OperationsSlImrnary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPL-07 MPL-07 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Päge10f 2 Start: 8/5/2005 Rig Release: 8/8/2005 Rig Number: 4ES Spud Date: 1/24/1991 End: 8/8/2005 Description of Operations 8/5/2005 From - To Hours Task· Code 00:00 - 02:00 2.00 MOB P 02:00 - 09:00 7.00 MOB P 09:00 - 12:00 3.00 MOB P 12:00 - 18:00 6.00 MOB P 18:00 - 22:00 4.00 MOB P 22:00 - 00:00 2.00 RIGU P 00:00 - 01 :00 1.00 RIGU P 01 :00 - 03:00 2.00 RIGU P 03:00 - 04:00 1.00 RIGU P 04:00 - 04:30 0.50 RIGU P 04:30 - 06:00 1.50 KILL P 06:00 - 07:00 1.00 KILL P 07:00 - 08:00 1.00 KILL P 08:00 - 13:00 5.00 KILL P 13:00 - 18:00 5.00 KILL P 18:00 - 21 :30 3.50 KILL P DECOMP PRE PRE PRE PRE PRE PRE 8/6/2005 PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECaMP 21 :30 - 22:30 1.00 KILL P 22:30 - 00:00 1.50 KILL P 8/7/2005 00:00 - 00:30 0.50 KILL P 00:30 - 01 :00 0.50 KILL P 01 :00 - 01 :30 0.50 KILL P 01 :30 - 03:00 1.50 KILL P 03:00 - 08:00 5.00 KILL P 08:00 - 11 :30 3.50 BOPSUR P 11 :30 - 13:00 1.50 PULL P 13:00 - 18:00 5.00 PULL P 18:00 - 18:30 0.50 PULL P 18:30 - 21 :00 2.50 PULL P 21 :00 - 23:00 2.00 PULL P 23:00 - 00:00 1.00 PULL P 8/8/2005 00:00 - 00:30 0.50 RUNCOtvP 00:30 - 03:00 2.50 RUNCOtvP 03:00 - 06:00 3.00 RUNCOtvP 06:00 - 06:30 0.50 RUNCOtvP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP Moving Rig from GPB to Milne Point. Stop to change flat tire. Continue with Rig move. Stop at Milne Point Spine turn-off. Park Rig and wait on MPU change-out to and from Kuparuk Airport. (authorized by J.C.). Continue with Rig move to MPU "Y". Park to allow for Pad Operators to change-out. Continue with Rig move to L-Pad. Load BOP Stack in Sub. Spot Sub Base over MPL-07 Wellhead. Raise and scope Derrick. Spot Pits, Pipe Shed, and Camp. Take on Hot Sea Water in Pits. Spot Tiger Tank. Lay Lines. Rig-up to Production Tree. Accept Rig at 01 :00 hrs. Test Lines to 3,500 psi. Pick-up Lubricator and pull BPV. Lay down same. Hold Safety and Pre-Operations meeting with all personell. Begin to circulate Well with Hot Sea Water. Continue circulating Well with Hot Sea Water at 4.0 BPM at 1400 psi. Monitor pressures to calculate kill weight Brine. Ordered 600 bbls. 9.9 ppg Brine. Monitor Well while waiting on kill weight Brine. Swap well over to kill weight Brine at 3.0 BPM at 1000 psi and monitor for stability. Monitor Well for stability. Tubing flowing 4 bbls/hr. Shut in Well and order used 11.3 ppg. Brine recovered from previous Milne Point Well Workover. Weight up kill weight Brine with 11.3 ppg Brine increasing 9.9 ppg brine to 10.2 ppg. Brine. Circulate 10.2 ppg kill weight Brine at 3.0 bpm at 1175 psi. to kill well. Continue Circulate 10.2 ppg Brine at 4.0 bpm at 1225 psi. Montitor Well for stability. Set Two-Way check. Tested to 500 psi. Good test. Nipple down Production Tree. Nipple up BOPE. Change out Pipe Rams to 2-7/8" x 5" VB Pipe Rams and NU HCR Valves. Installed scaffolding and connected Koomey lines. Test BOPE per BP/AOGCC requirements at 350/3500 psi. States right to witness test waived by J. Jones. String ESP Cable over Cable Sheave. Unland and lay down Tubing Hanger. POH with ESP Completion. Swap Cable Reels POH with 2-7/8" ESP Completion Lay Down ESP pump Clean Rig Flooor, Load New Reels, Load New Completion Assemblys, R/U to Run 2-7/8" ESP Completion Conduct Pre-Job Safety Meeting P/U ESP Pump Assembly, Assemble and check conductivity, Install ESP Cable. RIH w/ESP Assembly on 2 7/8" Tubing. Test Cable and Pump through Cable every 2000 ft. Service rig. Printed: 8/15/2005 1 :07:41 PM ') ) BPËXPLGRATION ()perationsSu rn rnaryReport . PafJe 201 2· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-07 MPL-07 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/5/2005 Rig Release: 8/8/2005 Rig Number: 4ES Spud Date: 1/24/1991 End: 8/8/2005 Date From';To Hours· Task Code NPT Phase Description ofOpëra.tiöns 8/8/2005 06:30 - 08:30 2.00 RUNCOMP RUNCMP RIH with ESP assembly, ESP Cable and 2 7/8" Tubing. Test Cable and Pump through Cable every 2000 ft. 08:30 - 12:00 3.50 RUNCOMP RUNCMP Fabricate Reel to Reel ESP Cable splice. Rig floor housekeeping. 12:00 - 15:00 3.00 RUNCOMP RUNCMP TIH with ESP Assembly Cable and 2-7/8" Tbg. 15:00 - 17:30 2.50 RUNCOMP RUNCMP M/U Hanger w/Landing Jt I Make cable connection and test 17:30 - 18:00 0.50 RUNCOMP RUNCMP Check P/U Wt. 68K SIO Wt. 38K Land Tbg. Hanger 18:00 - 19:00 1.00 RUNCOMP RUNCMP UD Landing Jt. Set TWC 19:00 - 20:00 1.00 BOPSUPP RUNCMP Nipple Down BOPE 20:00 - 23:00 3.00 WHSUR P RUNCMP Nipple Up Tree Test, Test Cable connection, Pick-up Lubricator pull TWC, Install BPV. Secure Well and Cellar.. 23:00 - 00:00 1.00 RIGD P RUNCMP Release Rig. RDMO. Printed: 8/15/2005 1 :07:41 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] 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 3424' NSL, 4705' WEL, SEC. 8, T13N, R10E, UM MPL-07 At top of productive interval ,9. Permit Number / Approval No. 190-037 4113' NSL, 976' EWL, SEC. 4, T13N, R10E, UM 10. APl Number At effective depth 50-029-22028-00 4267' NSL, 1234' EWL, SEC. 4, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4283' NSL, 1261' EWL, SEC. 4, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 11777 feet Plugs (measured) true vertical 7360 feet Effective depth: measured 11732 feet Junk (measured) Fish: 12 Cable bands and a flat guard below parrs. true vertical 7328 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 13-3/8" 500 sx Permafrost 'C' 105' 105' Surface 6815' 9-5/8" 1090 sx PF 'E', 330 sx Class 'G' 6850' 4645' Intermediate Production 11742' 7" 550 sx Class 'G' 11777' 7360' Liner Perforation depth: measured 11323'- 11331', 11355'- 11377', 11385 - 11403', 11495'- 11515', 11521'- 11557', 11579'- 11583' true vertical 7050' - 7055', 7071' - 7085', 7090'- 7102', 7163' - 7177', 7181' - 7206', 7221' - 7223' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80, 8rd EUE to 11211' Packers and SSSV (type and measured depth) N/A ......... ' .... 13. Stimulation orcement squeeze summary i~[/J~,i~ {) < /'i ,' Intervals treated (measured) Alaska 0il & G~ Treatment description including volumes used and final pressure &tu, 14. ' ' ' Representative D~ily Average Production or Injection 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: I-'1 Copies of Logs and Surveys run [] Oil r-! Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that~tb__e .~r~going is true and correct to the best of my knowledge Signed s~ra._~~~ * Title Technical Assistant Date Prepared By Name/Number Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ,,~ Legal Well Name: MPL-07 Common Well Name: MPL-07 Spud Date: 1/24/1991 Event Name: WORKOVER Start: 3/1/2002 End: Contractor Name: NABORS Rig Release: 5/23/2001 Rig Name: NABORS 4ES Rig Number: 4ES ~ ~i~ity ~o:~ ~ Description of Operations ....... 3/1/2002 08:00 - 10:00 2.00 MOB P PRE MOVE RIG FROM MPH-07 TO MPL-07. 10:00 - 12:00 2.00 RIGU P PRE BERM AND SPOT RIG. 12:00 - 13:00 1.00i RIGU P PRE RAISE AND SCOPE DERRICK. 13:00 - 13:30 0.50 RIGU P DECOMP RIG UP HARD LINE TO GREEN TANK. 13:30 - 14:30 1.00 RIGU P DECOMP RIG HCR VALVE AND HARD LINES TO TREE. 14:30 - 15:00 0.50 RIGU P DECOMP PRESSURE TEST LINES TO 3,500 PSI. GOOD. 15:00 - 16:00 1.00 WHSUR P DECOMP PU LUBRICATOR. PULL TWC. LD LUBRICATOR. 16:00 - 17:30 1.50 KILL P DECOMP TAKE ON 11.6 LB/GAL BRINE IN PITS. 17:30 - 18:00 0.50 PULL , P DECOMP RIG UP ESP CABLE SHEAVE. CREW CHANGE. I 18:00 - 23:30 5.50 KILL !P DECOMP PJSM. CIRCULATE WELL BORE TO 11.6 LB/GAL MONITOR...DPP = 110 PSI. PREPARE TO WEIGHT UP. 23:30 - 00:00 0.50 KILL P DECOMP BEGIN TO BRING BRINE WEIGHT UP TO 12.0 LB/GAL. 3/2/2002 00:00 - 04:00 4.00 KILL P DECOMP CIRCULATED WELL OVER TO 12.0 LB/GAL. 04:00- 04:30 0.50 KILL ~ DECOMP MONITOR WELL. WELL DEAD. INSTALL TWC. TEST. 04:30-06:00 1.50 WHSUR ~ DECOMP BLOW DOWN LINES. PJSM. REMOVE PRODUCETION TREE. CREW CHANGE. 06:00 - 07:30 1.50 BOPSUF = DECOMP INSTALL DOPE. 07:30 - 08:30 1.00 BOPSUF~ = DECOMP PERFORM BOP BODY TEST AT 250/3,500 PSI AS PER BP AND AOGCC REQUIREMENTS. STATE RIGHT TO WITNESS TEST WAIVED BY C. SHELVE. 08:30 - 09:30 1.00 WHSUR P DECOMP PICK UP LUBRICATOR. PULL TWC. LAY DOWN SAME. 09:30 - 10:00 0.50 PULL P DECOMP PICK UP LANDING JT. BOLDS. PULL TBG HANGER TO FLOOR...80K. LAY DOWN SAME. 10:00 - 10:30 0.50 PULL P DECOMP RIG UP FLOOR TO PULL TBG AND ESP ASSY. 10:30 - 13:30 3.00 PULL P DECOMP START POH WITH 2 7/8" TBG AND ESP ASSY. STOP AT 6,200-FT. 13:30 - 14:00 0.50 PULL P DECOMP ;CHANGE ESP CABLE SPOOL. 14:00 - 17:00 3.00 PULL P DECOMP CONTINUE POH WITH TBG AND ESP ASSY. 17:00 - 18:00 1.00 PULL = DECOMP ESP ASSY TO SURFACE. START TO INSPECT AND LD. CREW CHANGE. 18:00-20:00 2.00 PULL = DECOMP FINISH LD ESPASSY. 20:00 - 20:30 0.50 PULL = DECOMP CLEAR AND CLEAN FLOOR. 20:30 - 23:30 3.00 RUNCOI~P COMP PICK-UP AND SERVICE NEW ESP ASSY. 23:30 - 00:00 0.50 RUNCOkP COMP START RIH WITH ESP ASSY AND 2 7/8" TBG. 3/3/2002 00:00 - 04:00 4.00 RUNCOI~P COMP CONTINUE RIH WITH ESP ASSY AND TBG. STOP. 04:00 - 07:00 3.00 RUNCOkP COMP CHANGE OUT ESP CABLE SPOOLS. MAKE REEL TO REEL SPLICE AT 7,900-FT (+/-). 07:00 - 09:00 2.00 RUNCOr~ COMP CONTINUE RIH WITH ESP ASSY AND TBG. 09:00 - 11:30 2.50 RUNCO~ COMP i PU HANGER. MAKE PIGTAIL SPLICE. 11:30 - 12:00 0.50 WHSUR P COMP LAND TBG HANGER. INSTALL AND TEST TWC. 12:00 - 14:30 2.50 BOPSUF.P COMP PJSM. NIPPLE DOWN DOPE. 14:30 - 16:30 2.00 WHSUR ~ COMP NIPPLE UP ADAPTOR FLANGE. INSTALL PRODUCTION TREE. TEST TO 5,000 PSI. GOOD. 16:30 - 18:00 1.50 WHSUR ~ COMP FINAL ESP CABLE CHECK. GOOD. PULL TWC. INSTALL BPV. SECURE WELL. RELEASE RIG AT 18:00 HRS. 18:00 - 20:00 2.00 RIGD P POST LOWER AND SCOPE DERRICK. 20:00 - 22:00 2.00 DEMOB P POST PREPARE REMAINING EQUIPMENT RDMO. Printed: 3/4/2002 10:27:46AM ---. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMN, 51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] 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 3424' NSL, 4705' WEL, SEC. 8, T13N, R10E, UM MPL-07 At top of productive interval 9. Permit Number / Approval No. 190-037 4113' NSL, 976' EWL, SEC. 4, T13N, R10E, UM 10. APl Number At effective depth 50-029-22028-00 4267' NSL, 1234' EWL, SEC. 4, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4283' NSL, 1261' EWL, SEC. 4, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 11777 feet Plugs (measured) true vertical 7360 feet Effective depth: measured 11732 feet Junk (measured) true vertical 7328 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 13-3/8" 500 sx Permafrost 'C' 105' 105' Surface 6815' 9-5/8" 1090 sx PF 'E', 330 sx Class 'G' 6850' 4645' Intermediate Production 11742' 7" 550 sx Class 'G' 11777' 7360' Liner Perforation depth: measured 11323'- 11331', 11355'- 11377', 11385 - 11403', 11495'- 11515', 11521'- 11557', 11579'- 11583' true vertical 7050'- 7055', 7071'- 7085', 7090'- 7102', 7163'- 7177', 7181'- 7206', 7221'- 7223' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80, 8rd EUE to 11226' Packers and SSSV (type and measured depth) N/A REC E IVE D 13. Stimulation or cement squeeze summary J U N ,1_ 9 2 0 01 Intervals treated (measured) Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17.1 hereby certify that the fo~..egoing is true and correct to the best of my knowledge Signed so~d'ra ........ Stewm.~,w_r?~ ,~ · _ Title Technical Assistant Date ~,~- /O I- ~\ Prepared By Name/Nurnber: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ~ r'~ ! f-~ ! I~ ! /~ I Submit In Duplicate. ORIGINAL Legal Well Name: MPL-07 Common Well Name: MPL-07 Spud Date: 1/24/1991 Event Name: WORKOVER Start: 6/24/2000 End: 6/26/2000 Contractor Name: NABORS Rig Release: 6/26/2000 Rig Name: NABORS 4ES Rig Number: · . D~te:::i:::::~;.. ?:.:,.:FrO~.:~:To. :::Hours... :~tiVi~ ¢Od~:i: NPT phase Description of Operations 6~24~2000 01:30 - 06:00 4.50 RIGU P DEGOMP Accept rig at 01:30 6~24~00. RU HGR and hard lines, test. Load pits w/kill fluid 06:00 - 07:00 1.00 KILL P DEOOMP RU lubricator, pull BPV 07:00 - 08:00 1.00 KILL P DEOOMP RU to kill well, test lines to 3000 psi 08:00 - 16:30 8.50 KILL P DECOMP Kill well, monitor pressures, circulate kill weight fluid 16:30 - 18:00 1.50. WHSUR P DECOMP ND X-mas tree and HCR valve 18:00 - 20:30 2.50 BOPSUIq P DECOMP NU BOP 20:30 - 21:30 1.00 BOPSUIq P DECOMP Function test, and full body pressure test BOP. Witness waived by Lew Grimaldi - AOGCC 21:30 - 22:30 1.00 PULL P DECOMP RU lubricator, pull TWC 22:30 - 00:00 1.50 PULL P DEGOMP MU Landing jt., pull Tubing Hanger, check ESP Cable 6~25~2000 00:00 - 03:00 3.00 PULL P DECOMP Pull 2 7/8" ESP completion 03:00 - 03:30 0.50 PULL P DECOMP Change reel in ESP Spooling unit 03:30 - 09:30 6.00 PULL P DEGOMP Pull2 7~8" ESP Completion 09:30 - 10:30 1.00 PULL P DEGOMP Service and LD pump 10:30 - 11:30 1.00 PULL P DECOMP Clear floor, prep to run completion 11:30 - 14:00 2.50 RUNCO~/P COMP PU and service pump, check ESP connection 14:00 - 18:00 4.00 RUNCOI~ COMP Run 2 7/8" ESP Completion 18:00 - 22:30 4.50 RUNCOI~' COMP Change reels, splice ESP cable 22:30 - 00:00 1.50 RUNCOI~ COMP Run 2 7~8" ESP Completion 6~26~2000 00:00 - 02:00 2.00 RUNCOI~ COMP Run 2 7~8" ESP Completion 02:00 - 04:00 2.00 RUNCOI~ COMP PU Tubing Hanger, install Penetrator, splice connector, Test ESP cable 04:00 - 05:00 1.00 RUNCOI~ COMP Land Tubing Hanger, install TWC 05:00 - 07:30 2.50 BOPSUI; P COMP ND BOP 07:30 - 09:00 1.50 WHSUR ~ COMP NU X-mas tree, test to 3000 psi, final check ESP cable 09:00 - 10:00 1.00 WHSUR 3 COMP RU lubricator, Set BPV. Release rig 10:00 hrs. Printed: 5/29/2001 1:34:20 PM / ?oo MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julia Heusser, ~\~ Commissioner Tom Maunder, P. I. Supervisor DATE: December 22, 2000 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments: SVS MPU L pad 12-22-00jc cc; NON-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc AlaSka Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ ! Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060 140 100 '"90 P P " OIL L-03 1900070 ,, L-04 1900380 140 100 105 P P OIL L-05 1900390 140 100 100 P P OIL , L-06 1900100 140 100 100 P P OIL L-07 1900370 140 100 100 P P OIL L-08 1901000 4000 2000 1950 P P WAG L-09 1901010 ,, L-II 1930130 140 100 115 P P OIL L-12 1930110 140 100 100 P P OIL L-13 1930120 140 100 100 P P OIL L-14 1940680 140 100 95 P P OIL L-15 1940620 L-16A 1990900 L-17. 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800 140 1001 105 P P OIL L-28A 1982470 140 100 110 P P OIL L-29 1950090 140 100 95 P P OIL L-32 1970650 140 100! 100 P P OIL , L-33 1971050 L-35 1970920 140 100 1051 P P OIL L-36 1971480 140 100 105 P P OIL L-37A 1980560 L-40 1980100 140 100 100 P P g-x2,~ ~ Xo .x¢,~ ~6 OIL L-45 1981690! 140 100 105 P P ~5' OIL L-34 1970800 4000 2000 1900 e 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% El90 var Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE I II 12/26/00 Page 2 of 2 SVS MPU L Pad 12-22-OOjc.xls STATE OF ALASKA ALASK,~'~''''''_ AND GAS CONSERVATION COMI~ "~'-'~ION RETORT OF SUNDRY WELL OPERATION,., 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] 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 3424' NSL, 4705' WEL, SEC. 8, T13N, R10E, UM MPL-07 At top of productive intervalRECEIVED 9. Permit190.037Number/ Approval No. 4113' NSL, 976' EWL, SEC. 4, T13N, R10E, UM 10. APl Number At effective depth 50-029-22028-00 4267' NSL, 1234' EWL, SEC. 4, T13N, R10E, UM i! .~.: \! 0 2 ""'"'~ c'~.lj 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4283' NSL, 1261' EWL, SEC. 4, T13N, R10E, UM ?~i~ska0il &G~s Cons~ C0r~issi0n Sands 12. Present well condition summary Total depth: measured 11777 feet Plugs(measured) ORIGINAL true vertical 7360 feet Effective depth: measured 11732 feet Junk (measured) true vertical 7328 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" To su dace 80' 80' Surface 6850' 9-5/8" 1090 sx PF 'E', 330 sx Class 'G' 6850' 4645' Intermediate Production 11777' 7" 550 sx Class 'G' 11777' 7360' Liner Perforation depth: measured 11323'- 11331', 11355' - 11377', 11385- 11403', 11495'- 11515', 11521'- 11557', 11579'- 11583' true vertical 7050' - 7055', 7071' - 7085', 7090' - 7102', 7163' - 7177', 7181' - 7206', 7221' - 7223' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80, 8rd EUE to 11205' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~'~ ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Du Bp AMOco , ..... ,, ,, Page l of 2 ~:.' ':i:: :'.i:::i:::" i:::': : : :~ : :: ,~:~a~ka 0il & Gas Cons. Com~/s,~in~. Legal Well Name: MPL-07 Common Well Name: MPL-07 Spud Date: 6/24/2000 Event Name: WORKOVER Start: q 0/3/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES :: D~i;'::i':,::;; i::Fr°~i;i~°. :: ;iH~fi~ :: ::: :Task .:: i ~ .~fiase :~::' Description of Operations 10/4/2000 00:00 - 04:00 4.00 MOB PRE ARRIVE ON LOCATION FROM M-29. SPOT IN EQUIP R/U RIG 4ES. RAISE & SCOPE DERRICK. PJU ANNULUS VALVE & HARD LINES IN CELLAR. ACCEPT RIG @ 0400 HRS 10-4-00. 04:00 - 06:00 2.00 MOB DECOMP SET TIGER TANK. R//U & TEST HARD LINES BERM AROUND SAME. 06:00 - 07':00 1.00: WHSUR DECOMP M/U LUBRICATOR & PULL BPV. 07:00 - 07:30 0.50~ PULL DEOOMP HANG SHEAVE & SERVICE RIG. 07:30 - 08:00 0.50 REST DECOMP SPOT IN SPOOLING UNIT. 08:00 - 09:30 1.50 KILL DECOMP TAKE ON 9.2 PPG KILL FLUID. 09:30 - 12:30 3.00 KILL DECOMP HEAT UP 200 BBL OF KILL FLUID TO 140 DEG. 12:30 - 13:00 0.50 KILL DECOMP HOLD PRE-SPUD MTG & RISK ACGESSMENT, REVIEW W/O OBJECTIVES. 13:00 - 16:30 3.50 KILL DECOMP SITP 1050 PSI, SlGP 1050 PSI. KILL WELL @ 3 BPM. BUMP 465 BBLS 9.2 BRINE WTR. CIRC OUT 495 BBL OIL. SIP 200 PSI. STILL GETTING OIL RETURNS. 16:30 - 18:00 1.50 KILL DEGOMP S/D. CIRCULATED OUT 490 BBLS OIL IN TIGER TANK, WAIT ON TRUCKS & KILL FLUID. 18:00 - 20:00 2.00 KILL DEOOMP TRANSFER OUT 475 BBLS CRUDE. LOAD 300 BBLS OF 9.2 PPG KILL FLUID. TP 270 PSI, CP 450 PSI. 20:00 - 22:00 2.00 KILL DECOMP KILL WELL @ 3 BPM 850 PSI. GETTING KILL FLUID RETURNS. (9.1 PPG) RETURNS 99% BRINE. SI WELL TP 250 PSI, CP 300 PSI. WT UP TO 9.5 PPG. 22:00 - 00:00 2.00 KILL DEOOMP PUMP 9.5 PPG FLUID & CIRCULATE WELL. 10/5/2000 00:00 - 01:00 1.00 KILL DECOMP PUMP 9.4 KILL WT FLUID ROUND WELLBORE. SlW. WELL NO DEAD. TP 150 PSI, CP 200 PSI. 01:00 - 04:00 3.00 KILL DECOMP WT UP TO 9.8 PPG. CIRCULATE AROUND WELLBORE. 04:00 - 05:00 1.00 KILL DEOOMP SIW. TP 70 PSI, CP 50 PSI, BLED OFF 2 BBLS. TP & CP 25 PSI. OBSERVE WELL. 05:00 - 06:00 1.00 KILL DECOMP WELL APPEARS OUT OF BALANCE. CIRC 15 MIN & PREPARE TO PULL BPV, WELL STARTED FLOWING. 06:00 - 11:00 5.00 KILL DECOMP WT UP TO 10 PPG. CIRCULATE AROUND WELLBORE & KILL WELL. OBSERVE WELL. WELL DEAD. 11:00 - 11:30 0.50 WHSUR DECOMP PULL BPV & INSTALL TWC. 11:30- 12:30 1.00 WHSUR DEGOMP N/DX-MAS TREE. 12:30- 16:00 3.50 BOPSUI; DECOMP N/U BOPE. 16:00 - 23:00 7.00 BOPSUF DEGOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI. ANNULAR PREVENTER WOULD NOT TEST. TEST WITNESSED BY JEFF JONES W/AOGCC. 23:00 - 00:00 1.00 BOPSUR DECOMP REPLACE RUBBER IN ANNULAR. 10/6/2000 00:00 - 03:00 3.00 BOPSUR DECOMP REPLACE RUBBER IN ANNULAR PREVENTER. 03:00 - 04:00 1.00i BOPSUR DECOMP PRESSURE TEST ANNULAR PREVENTER TO 2500 PSI, OK. 04:00 - 05:00 1.00 WHSUR DECOMP PULL BPV & INSTALL TWC. 05:00 - 06:00 1.00 PULL DEOOMP M/U LANDING JT & PULL HANGER THRU FLOOR. P/U WT 85K. 06:00 - 07:30 1.50 PULL DECOMP INSPECT ESP PENETRATOR, CUT ESP CABLE & CHECK SAME. 07:30 - 11:00 3.50 KILL DECOMP CIRCULATE GAS & OIL OUT OF WELL 11:00 - 13:30 2.50 PULL DEOOMP SPLICE PIGTAIL ON ESP CABLE. 13:30 - 15:30 2.00 PULL DECOMP PULL OUT OF HOLE 60' & CHECK 1st CABLE CLAMP. BLOW OUT IN CABLE. RECOMMEND PULLING & REPLACING CABLE. TBG FLOWING SLIGHTLY. 15:30 - 18:00 2.50 KILL DECOMP CIRCULATE WELL 4 BPM @ 1000 PSI. WELL FLOWING. 18:00 - 20:30 2.50 KILL DECOMP REVERSE CIRCULATE 54 BBLS. MONITOR WELL TBG DEAD, ANNULUS FLOWING. 20:30 - 23:30 3.00 KILL DEGOMP PUMP 65 BBLS DOWN TBG. CLOSE IN ANNULAR & BULLHEAD 45 Printed: 11/1/2000 1:00:23 PM BP AMOco Page 2 of 2 OPeratiOns SUmma~ Report Legal Well Name: MPL-07 Common Well Name: MPL-07 Spud Date: 6~24~2000 Event Name: WORKOVER Start: 10~3~2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES · Dat~ 'From. To: H°Ur:s Ta~k ~ PhaSe Description of Operations 10/6/2000 20:30 - 23:30 3.00 KILL DECOMP BBLS DOWN IN LINER BELOW GLM. OPEN WELL UP & CIRCULATE 400 BBLS. 23:30 - 00:00 0.50 KILL DECOMP OBSERVE WELL WELL FLOWING, DECREASING OVER TIME. 10/7/2000 00:00 - 02:00 2.00 KILL DECOMP MONITOR WELL. FLOW STOPPED. 02:00 - 04:00 2.00 KILL DECOMP WAIT ON KILL FLUID. MONITOR WELL WELL DEAD. 04:00 - 07:00 3.00 KILL DECOMP WEIGHT UP TO 10.2 PPG. CIRCULATE WELL W/BRINE & KILL WELL. MONITOR WELL. WELL DEAD. 07:00 - 07:30 0.50 PULL DECOMP PREPARE TO PULL COMPLETION. STRING ESP CABLE TO SPOOLER. 07:30 - 16:30 9.00 PULL DECOMP PULL OUT OF HOLE W/COMPLETION STRING. 16:30 - 19:30 3.00 PULL DECOMP FLUSH PUMP & WASH OUT SALT. CHECK & L/D ESP. 19:30 - 20:30 1.00 RUNCOI~ COMP CLEAR FLOOR & R/U TO RUN NEW PUMP. 20:30 - 22:00 1.50 RUNCOI~ COMP MAKE UP NEW PUMP ASSY. 22:00 - 23:00 1.00 RUNCOIt COMP SPLICE ESP CABLE TO PUMP. 23:00 - 00:00 1.00 RUNCO~ COMP P/U COMPLETION EQUIP & 2 7/8" TBG & RIH. 10/8/2000 00:00 - 02:00 2.00 RUNCOk COMP TRIP IN HOLE W/COMPLETION TOOLS & 2 7/8" TBG TO 3910'. 02:00 - 02:30 0.501 RUNCOIt COMP CHECK CIRCULATION & CABLE 02:30 - 04:00 1.50 RUNCOr COMP TRIP IN HOLE W/COMPLETION STRING TO 6170'. 04:00 - 07:00 3.00 RUNCOr COMP CHECK CIRCULATION & MAKE REEL TO REEL SPLICE ON ESP CABLE. 07:00 - 10:00 3.00 RUNCOr COMP RUN IN HOLE W/COMPLETIO STRING TO 9000'. 10:00 - 15:00 5.00 RUNCOt COMP CIRCULATE THRU TBG. CUT OFF BAD SPLICE IN CABLE & RESPLICE SAME. 15:00 - 17:00 2.00 RUNCO~I COMP RUN IN HOLE W/COMPLETION STRING. P/U 1 JT & GLM ASSY RUN 1 STAND & CHECK ESP CABLE. 17:00 - 18:00 1.00 RUNCO~I COMP M.U HANGER & SPACE OUT FOR TOP SPLICE. 18:00 - 21:30 3.50 RUNCOI~ COMP SPLICE & TEST ESP CABLE. 21:30 - 22:00 0.50 RUNCOI~ COMP CONNECT ESP CABLE TO HANGER & LAND HANGER. SET COMPLETION @ 11205' (SEE TBG SET SHEET) P/U WT 74K, SIC WT 40K. 22:00 - 23:00 1.00 RUNCOI~ COMP SET & TEST 'rwc TO 1000 PSI, OK. 23:00 - 00:00 1.00 RUNCOI~ COMP FLUSH BOPE & BID HARD LINES..N/D BOPE. RECEIVE3 Printed: 11/1/2000 1:00:23 PM THE MATE~AL UNDER THIS COVER HAS BEEN MICROFI'LMED ON OR BEFORE ,OCTOBER 27, 2000 E E C:LORBMFILM.IX)C PL E W M A TE R IA L U N D ER TH IS M A.R K ER MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner DATE: October 5, 2000 Blair Wondzell THRU: P.I. Supervisor ~ ~ c,~',~-_.) FROM: Jeff Jone'e~s Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 4ES BPX/L Pad L-7 190-037 KRF/MPU Operator Rep.: Tom Abbott Contractor Rep.' Gene Sweat Op. phone: 659-4154 Rig phone: 659-4563 Op. e-mail: Rig e-mail: Test Pressures Rams: 3500 MISC. INSPECTIONS: P/F Location Gen.: Housekeeping: PTD On Location Standing Order: P Sign: P Rig cond: ~ P Hazard: P BOP STACK: Annular: 2500 Choke: 3500 TEST DATA FLOOR VALVES: P/F Quantity P/F P Upper Kelly 1 N/T P Lower Kelly 1 N/T P Ball Type 1 P Inside BOP 1 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 F CHOKE MANIFOLD: Time/Psi P/F Pipe Rams N/A Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 2 7/8x5 P No. Valves 11 P After Closure 1700 P Blind Rams 1 blind/shea P Man. Chokes 1 P 200 psi Attained 33 sec. P Choke Ln. Valves 1 3 1/8 P Hyd. Chokes 1 P Full Pressure 2 min. 10 P HCR Valves 2 3 1/8 P Blind Covers (All Stations): P Kill Line Valves 1 3 1/8 P N2 Bottles (avg.): 4(~ 1400 P Check Valve N/A Test's Details Thursda% October 5, 2000.'. I traveled to BPX's MPU L-Pad to witness an initial BOPE test, where Nabors Rig 4ES personnel were preparing to perform a submersible pump change on well L-7. The testing lasted 5.5 hours with one failure. The annular pre.v..ente_r failed the pressure te__,st and the element was replaced with a new one and passed a retest. The extended test time was due in part to the repair of pressure sensing equipment that was not functioning properly. The gas detection alarm system was tested and operated properly. The kelly valves were not tested at this time because the kelly will not be used for this operation, but they will be tested and documented before their next use. The rig appeared clean and in good condition and the location well organized. Summary: I witnessed the initial BOPE test on Nabors 4ES, perfomaing a pump change on BPX's MPU well L-7. The annular preventer failed the pressure test, and a new element was installed and passed a retest. Total Test Time: $. 1,/.2 Number of failures: cc: MPU Drilling Engineer 1 Attachments: 0 BOP Nabors 4ES 10-5-00 JJ.xls STATE OF ALASKA ALASKA .AND GAS CONSERVATION COMIV "ION RE',, URT OF SUNDRY WELL OPERATION~ 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] 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 MPL-07 3424' NSL, 4705' WEL, SEC. 8, T13N, R10E, UM ~?--~.~ ~ .... .~.;'~ ~ .... ~ ~ :';~ ..... "' ~1%~' :~ ..... :'~ ,:~ ~ ....... !ii ~::.? !'?-~'.i'~ !i~,.:.,~ 9. Permit Number / Approval No. At top of productive interval 190-037 4113' NSL, 976' EWL, SEC. 4, T13N, R10E, UM 10. APl Number L ~ !.'"' ¢'.~ -'? "' .., ~.. 50- 029-22028-00 At effective depth ~-~,~.,~ '.,~ 4267' NSL, 1234' EWL, SEC. 4, T13N, R10E, UM 11. Field and Pool At total depth ,~"~-~ Milne Point Unit / Kuparuk River 4283' NSL, 1261' EWL, SEC. 4, T13N, RIOE, UM ':?:~:!'~":'";~ Sands 12. Present well condition summary Total depth: measured 11777 feet Plugs (measured) true vertical 7360 feetORIi INAL Effective depth: measured 11732 feet Junk (measured) true vertical 7328 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" To surface 80' 80' Surface 6850' 9-5/8" 1090 sx PF 'E', 330 sx Class 'G' 6850' 4645' Intermediate Production 11777' 7" 550 sx Class 'G' 11777' 7360' Liner Perforation depth: measured 11323'- 11331', 11355'- 11377', 11385- 11403', 11495'- 11515', 11521'- 11557', 11579'- 11583' true vertical 7050' - 7055', 7071' - 7085', 7090' - 7102', 7163' - 7177', 7181' - 7206', 7221' - 7223' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80, 8rd EUE to 11237 Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-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 I'"1 Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si.qned TerrieHubble ~ ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate Form 10-404 Rev. 06/15/88 ePort Legal Well Name: Milne Point L-07 Common Well Name: MP L-07 Spud Date: 6/24/2000 !Event Name: WORKOVER Start: 6/24/2000 End: 6/26/2000 Contractor Name: NABORS Rig Release: 6/26/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: ~haSe ~ ,,,,: Description,, of Operations 6/24/2000 01:30 - 06:00 4.50 RIGU DECOMP Accept rig at 01:30 6/24/00. RU HCR and hard lines, test. Load pits w/kill fluid 06:00 - 07:00 1.00 KILL DECOMP RU lubricator, pull BPV 07:00 - 08:00 1.00 KILL DECOMP RU to kill well, test lines to 3000 psi 08:00 - 16:30 8.50 KILL DECOMP Kill well, monitor pressures, circulate kill weight fluid 16:30 - 18:00 1.50 WHSUR DECOMP ND X-mas tree and HCR valve 18:00- 20:30 2.50 BOPSUF DECOMP NU BOP 20:30 - 21:30 1.00 BOPSUF DECOMP Function test, and full body pressure test BOP. Witness waived by Lew Grimaldi- AOGCC 21:30 - 22:30 1.00 PULL DECOMP RU lubricator, pull TWC 22:30 - 00:00 1.50 PULL DECOMP MU Landing it., pull Tubing Hanger, check ESP Cable 6/25/2000 00:00 - 03:00 3.00 PULL DECOMP Pull 2 7/8" ESP completion 03:00 - 03:30 0.50 PULL DECOMP Change reel in ESP Spooling unit 03:30 - 09:30 6.00 PULL DECOMP Pull2 7/8" ESP Completion 09:30 - 10:30 1.00 PULL DECOMP Service and LD pump 10:30 - 11:30 1.00 PULL DECOMP Clear floor, prep to run completion 11:30 - 14:00 2.50 RUNCOI~ , COMP PU and service pump, check ESP connection 14:00 - 18:00 4.00 RUNCOk COMP Run 2 7/8" ESP Completion 18:00 - 22:30 4.50' RUNCO~ COMP Change reels, splice ESP cable 22:30 - 00:00 1.50 RUNCO~ COMP Run 2 7/8" ESP Completion 6/26/2000 00:00 - 02:00 2.00 RUNCO~ COMP Run 2 7/8" ESP Completion 02:00 - 04:00 2.00 RUNCO~ COMP PU Tubing Hanger, install Penetrator, splice connector, Test ESP cable 04:00 - 05:00 1.00 RUNCO~I COMP Land Tubing Hanger, install TWC 05:00 - 07:30 2.50 BOPSUF COMP ND BOP 07:30 - 09:00 1.50 WHSUR COMP NU X-mas tree, test to 3000 psi, final check ESP cable !09:00 - 10:00 1.00 WHSUR COMP RU lubricator, Set BPV. Release rig 10:00 hrs. f.~;.~i.~ ,.,, . ., ,,.., Printed: 7/20/2000 10:30:04AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3424' NSL, 4705' WEL, Sec. 8, T13N, R10E, UM At top of productive interval 4116' NSL, 955' EWL, Sec. 4, T13N, R10E, UM At effective depth 4267' NSL, 1206' EWL, Sec. 4, T13N, R10E, UM At total depth 4284' NSL, 1235' EWL, Sec. 4, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 53' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-07 9. Permit Number / Approval No. 90-37 94-059 10. APl Number 50-029-22028 11. Field and Pool Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11779' feet Plugs (measured) 7361' feet 11732' feet Junk (measured) 7362' feet Length Size Cemented 80' 13 3/8" To surface 6850' 9 5/8" 1090 sx 'E'/330 sx 'G' MD ~;' ~.ii////!1/~~ 80' 80' 6850' 4600' 11777' 7" 550 sx Class 'G' 11777' 7372' Perforation depth: measured 11323'-11331', 11355'-11377', 11385-11403', 11495'-11515', 11521'-11557', 11579'-11583' true vertical 7076'-7081',7096'-7111',7116'-7128',7190'-7204',7208'-7233',7249'-7251' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 11190' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. 14. Prior to well operation: Subsequent to operation: ReDresentative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~.~¢~_. ~./' ~ .... Title Form 10-404 Rev. 06/15/88 Engineerin,g, Supervisor,,,.,,........... Date .,~t~{-0,~ ......... Youngers 564-5242 Prepared By Name/Number: Mary Submit In Duplicate~N¥ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-07 Rig Name: N-4ES AFE# 339053 Accept Date: 07/30/97 Spud Date: - Release Date: 08/01/97 JULY 31, 1997 ACCEPT RIG @ 09:00 HRS. SPOT RIG @ L-07, RAISE & SCOPE DERRICK. RIG UP FLOWLINES & MUD LINE. FILL RIG PITS WITH SEA WATER. SPOT TIGER TANK. RIG UP HARD LINES FOR WELL KILL. TEST LINES TO 2000 PSI. OK. PULL BPV W/LUB. TP 550 PSI. BLEED GAS. KILL WELL W/FILTERED SEA WATER @ 3BPM/1600 PSI. MONITOR WELL-DEAD INSTALL TWC. ND TREE START TO NU BOPE. PROBLEM W/BRIDGE CRANE - UNABLE TO PU BOP STACK. MAKE REPAIRS. FINISH NU BOPE. PERFORM BOPE TEST PER BP/AOGCC REQUIREMENTS. AOGCC PRESENT FOR TEST. (JS) LD TEST JT. FINISH RU FOR 2 7/8" TUBING. PULL TWC FILL & MONITOR WELL MU LANDING JT. PULL HANGER. LD HANGER & LANDING JT. START POOH W/ESP COMP. AUGUST 01, 1997 POOH W/2 7/8" TBG & ESP ASSY. LD ESP ASSY. RU HOWCO WL RIH W/5.9750" GR/JB. TAG BTM @ 11670' WLM. POOH RD HOWCO. PU & SERVICE ESP ASSY. RIH W/ESP & 2 7/8" TUBING. CHANGE SPOOL - MAKE SPOOL TO SPOOL SPLICE. CUT & SLIP DRILLING LINE. CHECK CABLE CONTINUE RIH W/ESP ASSY & TBG. AUGUST 02, 1997 CONTINUE RIH W/ESP COMP. PU LANDING JT. & HANGER. MU PIG TAIL SPLICE. CHECK CABLE - OK. LAND HANGER. LD LANDING JT. RILDS SET TWC. ND BOP'S NU TREE TEST TUBING HANGER & TREE TO 5000 PSI. OK. PULL TWC. SET BPV. FREEZE PROTECT WELL W/DIESEL. RD LINES. SECURE WELL. RIG RELEASED @ 1600 HRS. Page 1 of 1 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-07 Rig Name: N-4ES AFE# 339013 Accept Date: 5/29/96 Spud Date: - Release Date: 6/11/96 JUNE 03, 1996 RIG ACCEPTED @ 1000 HRS. SCOPE & LOWER DERRICK, MOVE RIG F/MPU C-23 TO MPU L-07 LAY HERCULITE & SPOT RIG ON L-07. JUNE O4, 1996 TAKE SOURCE WATER, HOOK LINES INTO TREE. SET & BERM TIGER TANK. PULL BPV, SITP 240 PSI SICP=0, TEST LINES TO 2500 PSI. MULL HEAD 75 BBLS 8.8 PPG BRINE DOWN TUBING. 2 BPM @ 2500 PSI. FINAL PRESS=0 RU CAMCO. TEST LUBRICATOR TO 1000 PSI. RIH & RETRIEVE SHEAR VALVE IN GLM @ 11036' RIH TO SET DUMMY VALVE IN GLM @ 11036' PIH TO SET DUMMY VALVE IN GLM @ 11036'. RIH TO SET DUMMY VALVE IN GLM @ 11036' POH VALVE DID NOT SET, RERUN 1" DUMMY VALVE & SET @ 11036' POH. RIH TO PULL DUMMY VALVE @ 632' PRESSURE TUBING TO 500 PSI. PULL DUMMY PRESSURE BLED TO 370 PSI POH W/DUMMY VALVE. BULL HEAD ANNULUS W/42 PILL FOLLOWED W/340 BBLS OF 8.8 PPG BRINE @ 3.5 BPM @ 2500 PSI. MONITOR WELL, WELL DEAD. COMCO PIH W/I" DUMMY VALVE & SET @ 632' POH RIH & PULL DUMMY VALVE FROM GLM @ 11036' RIG DOWN CAMCO INSTALL TWC ND COMPLETION TREE NU BOPE. CHANGE OUT SPOOL IN SPOOLING UNIT & TEST ESP LINE. CONTINUED POOH W/ESP COMPLETION. JUNE 05, 1996 FINISHED NU BOPE. TEST ALL RAMS & VALVES 250 PSI/5000 PSI. TESTED ANNULAR 250 PSI/3000 PSI WITNESS OF BOP TEST WAIVED BY LOU GRAMALDI. REBUILD KILL LINE HCR VALVE. FINISHED TESTING BOPE. RIGGED UP LUBRICATOR & PULLED TWC RD LUBRICATOR. MU LANDING JOINT BACK OUT LDS RELEASE PACKER W/50K OVERPULL. CIRCULATE THROUGH CHOKE & ALLOW ELEMENTS TO RELAX. CIRCULATED @ 4BPM @ 1300 PSI. LOST 12 BBLS/HR ATTEMPTING TO CIRCULATE PAST PACKER. PULL HANGER TO FLOOR & LAID OUT SINGLES TO TOP GLM. LAID OUT SSSV, DHR PACKER & TOP GLM. CIRCULATE BU AND MONITOR WELL. POOH W/EST COMPLETION DRIFT & SLM. CUT 84' & SLIP 42' OF DRILL LINE. CONTINUED POOH W/ESP COMPLETION. JUNE 06, 1996 INSPECT & LD ESP. CLEAR FLOOR. RD TUBING HANDLING TOOLS. RU TO RUN DRILL PIPE. CHANGE RAS TO 3 1/2" TEST DOOR SEALS & RAMS TO 5000 PSI. LD LANDING JT AND SET WR. MU BURNING SHOE ASSEMBLY & PU 3 1/2" DRILL PIPE FROM SHED. TAGGED TOP OF PACKER @ 11281' MILLED BAKER MODEL "D" PACKER F/11287'-11281'. CHASE PACKER TO 11296'. CIRCULATED BU DID NOT HAVE ANY GAS RETURN F/UNDER PACKER MONITOR WELL. POOH W/BURNING SHOE ASSEMBLY. RECOVERED 697 PREFORMED BANDS, 34 FLAT BANDS & 8 2/3" FLAT BANDS. Page 1 of :3 SUMMARY OF DALLY OPERATIONS JUNE O7, 1996 RIG SERVICE. FINISHED POOH W/MILL. EMPTIED JUNK BASKETS. RECOVERED APPROXIMATED 2 ~/~ GALLON METAL CUTTINGS. BREAK OUT MILL & MU OVERSHOT W/4 1/8" GRAPPLE. TIH TO TOP OF FISH @ 11296'. CIRCULATED BU NO GAS TO SURFACE. LATCHED ONTO FISH @ 11296'. FISH STUCK. ATTEMPTED TO JAR FISH FREE. MAXIMUM PULL 250K WOULD NOT COME FREE. ROTATED OFF FISH. BLOW DOWN KELLY & POOH. SLIP 42' DRILL LINE. FINISHED POOH. CLEAN OUT BOOT BASKETS - NO JUNK RECOVERED. MU MILL. TIH W/MILLING ASSEMBLY. MILL ON PACKER F/11296'-11300' APPEARED TO BE MILLING JUNK HELD D-1 DRILL 75 SECS & SPILL DRILL 90 SECS. JUNE 08, 1996 CIRCULATED AROUND HIGH VIS SWEEP 5 ~,'~ BPM @ 1300 PSI. MONITOR WELL, POOH. CLEAN JUNK BASKETS. RECOVERED 1 GALLON OF SMALL CUTTINGS. BROKE OFF BURNING SHOE & MU OVERSHOT W/4 1/8" GRAPPLE. TIH TO TOP OF FISH @ 12296'. REVERSE CIRCULATED ON TOP OF FISH. NO JUNK RECOVERY. LATCHED ONTO FISH W/OVERSHOT. FISH STUCK. JARRED ON FISH. MAXIMUM PULL 260K. ROTATE OFF FISH. TOOH W/3 Y2" DRILL PIPE. LD OVERSHOT & MU WASH PIPE & BURNING SHOEL CHANGE OUT OIL JARS. TIH W/5 :~A" WASH OVER ASSEMBLY. JUNE O9, 1996 LUB RIG. FINISHED RIH W/WO SHOE & WASHPIPE. TAG TOP OF FISH @ 11300'. MILL OVER FISH FROM 11300'-11305'. PUMPED SWEEPS TO CLEAN HOLE. UNABLE TO MAKE ANY MORE HOLE. WASHED OVER 8' OF FISH TOTAL. CIRCULATED OUT SWEEP @ 5BPM @ 1150' PSI. POOH. INSPECT SHOE, MISSING 7" APPEARS TO BE BROUND OFF EMPTY JUNK BASKETS & RECOVERED 2 GALS OF SMALL CUTTINGS. LD WASH PIPE & MU OVERSHOT W/4 1/8" GRAPPLE. DLIP DRILL LINE. TIH W/OVERSHOT. TAG TOP OF FISH @ 11296'. LATCH FISH & JARRED FISH UPHOLE. TOOH WORKING THROUGH TIGHT SPOTS. JUNE 10, 1996 LUBE RIG. FINISHED POOH W/FISH. RECOVERED AND LD FISH. LAID OUT FISHING ASSEMBLY. MU CLEAN OUT ASSEMBLY. TIH TO 11436'. BEGAN TAKING WEIGHT. REVERSE CIRCULATE & WASH F/11436'-11665' PBTD. (DP MEASUREMENT). NO SAND OR FILL. PUMPED 5 SWEEPS DURING REVERSE & WASHING. SWEPT HOLE W/ZANVIS PILL FROM 11665' PBTD. 5.5 BPM @ 1300 PSI. SPOT 25 BBL CLEAN BRINE ZANVIS PILL THROUGH PERF AREA. LD 18 JTS DRILL PIPE TO 11122'. CLEAN PITS & MIX CLEAN 8.8 BRINE IN PITS. DISPLACED HOLE W/CLEAN 8.8 PPG BRINE. PUMPED 40 BBLS. 140 DEG. DIESEL, 25 BBL ZANVIS SWEEP FOLLOWED W/CLEAN BRINE. MIX 150 ADDITIONAL BBLS OF CLEAN 8.8 PPG BRINE RU MI FILTER UNIT CIRC. & FILTER BRINE W/MI FILTER UNIT. Page 2 of :3 SUMMARY OF DALLY OPERATIONS JUNE 11, 1996 FINISHED CIRCULATING THROUGH M-I FILTER UNIT @ 4.5 BPM. CIRCULATED 2 WELL VOLUMES. 45 NTU READING OUT OF WELL. TOOH LD DRILL PIPE. CUT & SLIP DRILL LINE. FINISHED TOOH, LD DRILL PIPE & BHA. PULL WR SET TEST PLUG. CHANGE PIPE RAMS TO 2 7/8" TEST RAM TO 5000 PSI NO TEST REBUILD RAM RIG UP TO RUN ESP COMPLETION. TEST RAM TO 5000 PSI - OK FLUSH STACK W/PORTED SUB, SERVICE AND MU ESP. TIH W/ESP COMPLETION ASSEMBLY. JUNE 12, 1996 LUBE RIG. CONTINUED TIH W/2 7/8" ESP COMPLETION TO 8100' MAKE INLINE SPOOL TO SPOOL SPLICE. FINISHED RIH W/ESP COMPLETION ASSEMBLY. RAN A TOTAL OF 351 JTS OF 2 7/8" 6.5# L-80 EUE 8RD TUBING. MU HANGER & LANDING JOINT AND TWC. MADE PIGTAIL SPLICE @ HANGER. LAND TUBING RILDS. TEST PRIMARY HANGER SEALS TO 5000 PSI. CLEAR FLOOR & ND BOP STACK. NU TREE. TEST HANGER & TREE TO 5000 PSI. PULL TWC. SET BPV. FREEZE PROTECT ANNULUS W/67 BBLS DIELSEL & TUBING W/13 BBLS OF DIESEL. SECURE WELL & CELLAR. RIG RELEASED @ 2400 HRS 6/11. Page 3 of 3 STATE OF ALASKA ALA~,,~A OIL AND GAS CONSERVATION COMMIS$,,.,,~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1853' SNL, 4700' WEL, SEC. 8, T13N, RIOE At top of productive interval 1140' SNL, 921' EWL, SEC. 4, T13N, RIOE At effective depth 1140' SNL, 921' EWL, SEC. 4, T13N, RIOE At total depth 990' SNL, 1163' EWL, SEC. 4, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 53' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPL-7 9. Permit number/approval number 90-37/94-O59 10. APl number 50- 029-22028 11. Field/Pool Kuparuk River Pool 11821 feet Plugs (measured) 7418 feet Effective depth: measured true vertical 11732 feet Junk (measured) 7362 feet Casing Length Structural Conductor 80' Surface 6850' Intermediate Production 11777' Liner Perforation depth: Size Cemented Measured depth True vertical depth 13-3/8" To Surface 80' 80' 9-5/8" 1090 sx "E"/330 sx "G" 6850' 4600' 7" 550 sx C/ass "G" 11777' 7372' measured 11323'-11331', 11355'-11377', 11385'-11403', 11495'-11515', 11521'-11557', 11579'-11583' true vertical 7076'-7081', 7096'-7111', 7116'-7128', 7190'-7204', 7208'-7233', 7249'-7251' Tubing (size, grade, and measured depth) 2-7/8", L-80, 6.5tt, tubing to 11227' MD Packers and SSSV (type and measured depth) Model "D" packer @11287' MD; Otis DHR Packer ~_'~_,~.i w~l~=.. ,.,,~'C~V @ 560' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MAY 2 4 1994 Alaska 0il & Gas Cons. Commission Anchorage 14. Reoresentative 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 classification as: Copies of Logs and Surveys run Daily Report of Well/~)perations _z_ ~.~ Oil x Gas Suspended 17. I hereby certify<~h.~~ru_~d ~rrect to the best of my knowledge. FS~mneld0.4O4 Rev/06,~5/87 ~...~~ L. Title Drilling En~ineerSupervisor Service Date -~Z~/~ SUBMIT IN DUPLIdATE' ' .M PL-07, 04/26/94 MOVE RIG FROM L-11 TO L-07. 04/27/94 11,732' RU AND CHECKED PRESSURE. CLOSED SCSSV AND BLED OFF PRESSURE FROM TBG. ND XMAS TREE. NU BOPE, TESTED BOPE. BLED PRESSURE BELOW BACK PRESSURE VALVE, RU ANNULUS TO CHOKE, PUMPED DOWN TUBING AND KILLED WELL TAKING RETURNS FROM ANNULUS, OBSERVED WELL, ANNULUS BUILD TO 25 PSI. BACKED OUT LOCK DOWN SCREWS, PULLED PACKER FREE. RAISED WT ON BRINE TO 8.9, PUMPED PILL AND CIRCULATED. 04/28/94 11,732' CIRC OUT PILL AND OBSERVED WELL. PULLED AND LAID DOWN ESP. PACKER CAME LOOSE AT 40 K OVERPULL. CLEARED DRILL FLOOR, RU ATLAS, RAN GR/CCL TO 11667', TOP OF FILL. RAN GR JUNK BASKET TO 11270', RECOVERED 11 BANDS AND OTHER DEBRIS. RERAN GR JUNK BASKET. 04/29/94 11,732' RAN GAUGE RING - JUNK BASKET 11270' FT. RECOVERED 1 PIECE RUBBER. RAN AND SET BAKER MOD. D PACKER WITH SCREENS AT 11287'. RD ATLAS. RU AND RAN ESP ASSEMBLY. 04/30/94 11,732' RAN ESP ASSEMBLY. LANDED STRING AND PUMPED FREEZE PROTECTION. DROPPED BALL AND PRESSURED UP TO SET PACKER, NO INDICATION WAS SEEN THAT PACKER SET. BROUGHT PRESSURE TO 3000 FOR 30 MIN., BLED OFF TUBING AND TESTED ANNULUS, NO GOOD, ATTEMPTED TO BRING TBG PRESSURE TO 3500 PSI, BALL SHEARED OUT AT 3400 PSI. TESTED ANNULUS TO 500 PSI, WOULD NOT HOLD, PRESSURE EQUALIZED WITH TUBING. WAITED ON SLICK LINE UNIT, RU CAMCO. RETRIEVED RHC PLUG, RIH AND SET XX PLUG IN X NIPPLE BELOW PACKER. PRESSURED UP ON TBG TO 4000 PSI NO INDICATION OF PACKER SET, TEST ON ANNULUS WAS NO GOOD, RETRIEVED XX PLUG AND RD CAMEO. RU TO PULL COMPLETION AND CHANGE PACKER. 05/01/94 11,732' POH ESP TO PACKER. CLEARED DRILL FLOOR AND CHANGED OUT MAY 2 4 1994 Alaska Oil & Gas Cons. Commission Anchorage DETECTED, WOO FROM PRODUCTION. RU TO PULL PUMP AND POH. FOUND BROKEN POT HEAD PROTECTOR, DAMAGED POT HEAD, 2 PINCHED SPOTS IN CABLE, ALL CABLE FLAT GUARDS WERE PILED UP, 1 WAS MISSING, REPAIRED DAMAGE AND RESPLICED FLAT CABLE. 05/02/94 1 1,732' FINISHED SPLICE AT MOTOR. RIH W/ESP, DID NOT ENTER WELLHEAD CLEANLY, PULLED OUT, REPLACED 2 BANDS, RAN GRAPPLE TO 105 FT. NO OBSTRUCTION. RIH W/ESP COMP. 05/03/94 11,732' RIH, LANDED TBG ESP, TESTED TBG HNG. RU TO DISPLACE ANNULUS. DISPLACED ANNULUS WITH 60/40 METH/H20 TO 2383', DISPLACED TBG WITH DIESEL TO 2383' FOR FREEZE PROTECTION. DROPPED BALL AND PRESSURED UP TO SET PACKER. PACKER STILL NOT SET, HELD PRESSURE 1/2 HR., PRESSURE UP TO 3500 OSI PACKER SET, TESTED PACKER. PACKER WAS ONLY PINNED 2 SCREWS AND SHOULD HAVE SET AT 1500 PSI. BACKED OUT LANDING JOINT, INSTALLED 2 WAY CHECK, ND BOP, CHANGED RAM TO 5", NU TREE. TESTED TREE, TESTED ALL FLANGES AND ESP CABLE. PULLED CHECK AND INSTALLED BPV, SECURED WELL AND PUMPED CELLAR. RELEASED RIG @ 1830 HR'S ON 05/02/94. RECEIVED MAY 2 4 1994 Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 25, 1994 David W. Johnston AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Dear Mr. Johnston: BP Exploration requests approval (Form 403 attached) to pull the failed ESP and rerun new ESP equipment in Milne Point Unit well L-7 to restore production of approximately 1,400 BOPD. Based on the current rig schedule, this work will commence on April 15, 1994 and finish on April 21, 1994. If you have questions regarding this proposal, please contact Steve Rossberg, Lead Production Engineer, at 564-7637. Yours Truly, Bruce J. Policky Exploitation Manager cc: RSR, DW, FWG, L-7 Well File RECEIVED MAR -2 1994 Alaska 0ii & Gas Cons. Commission Anchorage 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS,,..,N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program__ Pull tubing x Variance Perforate Other 5. Type of Well: 6. Datum elevation (DF or KB) Development X 5 3'KB feet\ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1853'FNL, 4700'FEL, SECTION 8, T13N, RIOE, UM At top of productive interval 1140'FNL, 921' FWL, SECTION 4, T13N, RIOE, UM At effective depth 1140' FNL ,921' FWL, SECTION 4, T13N, RIOE, UM At total depth 990' FNL, 1163' FWL, SECTION 4, T13N, RIOE, UM Exploratory __ Stratig raphic Service RECEIVED MAR -2 1994 Alaska 0il & Gas Cons. Commission Anchorage 7. Unit or Property name Milne Point Unit 8. Well number L-7 9. Permit number 90-37 10. APl number 50-029-22028 11. Field/Pool Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11821' feet Plugs (measured) 7418' feet 11732 feet Junk (measured) 7362 feet Casing Length Structural Conductor 80' Surface 6850' Intermediate Production 11777' Liner Perforation depth: Size Cemented Measured d/~D~ True vertical depth BKB 13-3/8" To Surface 80' 80' 9-5/8" 1090 SKSE/330SKSG 6850' 4600' 7" 550 SKSClass G 11777' 7372' measured 11323-11331~ 11355'-11377~ 11385-11403~ 11495-11515~ 11521-11557~11579-11583' true vertical 7076-7081~7096-7111~ 7116-7128~ 7190-7204~7208-7233~7249-7251' Tubing (size, grade, and measured depth) 2-7/8", L-80, at 11,249', Bottom of ESP at 11,299' Packers and SSSV (type and measured depth) Otis ,RDH ,ESP Packer at 533. Otis, Series 10, FMX TRSV at 514'. 13. Attachments Description summary of proposal x Detailed operations program __ Pull failed ESPand rerun new pumping equipment to restore production. BOP sketch 14. Estimated date for commencing operation April 15, 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas~ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' /~'~,.... Title FOR COMMISSION USE ONLY Date 2/24/94 Conditions of approval: Notify Commission so rep/r, esentative may witness Plug integrity BOP Test // Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission Original Signed By David W. Johnston J Approval No -"-~ ...... · ,&p?FOV~U. ',-'~'F'Y r ---RetuFF~ed .. Commissioner Date-~ / z%/'¢, ,/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT WELL L-7 ESP REPLACEMENT PROCEDURE February 24, 1993 1. Install BPV. MIRU drilling rig. 2. Shear open annular vent valve by pressuring up on the 2-7/8" tubing by 7" casing annulus to 3500 psig with the valve closed. 3. Kill well by circulating hole full with 10.2 ppg NaBr/NaCI brine. Spot salt- based LCM pills, if necessary. 4. ND tree. NU BOPs. Pull BPV. Install two-way check. Pressure test BOP equipment. 5. MU landing joint to tubing hanger. PU 20,000 to 30,000 lbs. above pipe weight to release Otis RDH packer located at 533'. 6. POOH with 2-7/8" tubing and ESP. Lay down ESP. 7. TIH with bit and casing scraper to PBTD to confirm perf interval is clear of fill. POOH. 8. MU ESP assembly and TIH on 2-7/8" production tubing. 9. MU Otis DHR packer with a mandrel and valve located below the packer to allow gas back into the tubing. Install an Otis X nipple between the packer and mandrel. Install a 2-7/8" tubing retrievable SCSSV in the production tubing above the packer and space out to place the SCSSV at least 500' below ground level. 10. Land production tubing in tubing hanger and freeze protect annulus. 11. RU wireline and set a plug in the X nipple located below the production packer. Pressure up against the plug to approximately 3,000 psig to set the packer. POOH with plug and rig down wireline. 12. Pressure test packer by pressuring up on the annulus to 500 psig. 13. Freeze protect tubing. Install BPV. Close SCSSV. ND BOPs. NU tree. Pull BPV. Install two-way check and test tree. Pull two-way check. Install BPV. 14. RDMO workover rig. RU and test flow line. Pull BPV. Return to production. RECEIVED MAR -2 1994 Alaska 0ii & Gas Cons. Commission Anchorage ~,onoco Inc. Anchorage Division h=cord of Shipment of Confidential Information Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 {907) 279-1433 [] Under Separate Cover Enclosed .D. ate From Steve Davies Conoco Inc. 3201 C Street, Suite 200 Mav 5. 1993 Anchorage~ AlaSka 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Well Log Magnetic Tapes I-2, I-3~ I-4~ I-4A~ J-l, J-3~ J-4, L-7~ L-8~ L-9 Quantity Contents 1 each I-2 Magnetic Tape. ~EDIT, APl #50-029-22066, Log Date: 03-NOV-90, Ref #74175. I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203. I-4 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-90, Ref #74208. 1-48/Magnetic Tape. J-1 Magnetic Tape. J-3 Magnetic Tape. J-4 Magnetic Tape. L-7 Magnetic Tape. L-8 Magnetic Tape. L-9 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 29-Nov-90, Ref #74229. Open Hole,APl #50-029-22070, Log Date: .13-Dec-90, Atlas Wireline & US listing. O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & US listing. O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting.¢~,.¢~ O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350.,;~1),,~"/ Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS Iisting. C~o~ll3O O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467. RECEIVED MAY 0 5 1993 ~Jaska 0il & Gas Cons, Commission Anchorage **LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver granted via phone conversation May 5, 1993. [~..~~ Signed By Transmittal Approved By ~ Date Instructions: Please ackno~-I~ge~omptly by signing and returning second copy. Received By Date May 5, 1993 Remarks Transmittal Copy Only To ---. ORIGIN4L · ' ' STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION WiLL ¢OM~L~?ION OR P.F. COM~LIETIO# RE~ORT AND LOG ~ 1. Status of Well GAS [] SUSPENDED [] ABANDONED [] SERVICE I~] Classification of Service Well 2. Name of Operator Conoco Inc. 3. Address 't201 'C' .qtr~t.. S,-it~ 200 Anehorago_.- A1 a.qka 00503 7. Permit Number 90-37 8. APl Number 50-- 029-22028 4. Location of well at surface /' ',,,';';:; ;:: :: ..... ::. .....................9. Unit or Lease Name At Top Producing Interval : : : ~' 1140' ~, 921' ~ SECTION 4 TI3N RIOE :~ - At Total Deoth .... ~= ........ ;. ? 3. F~eld and Pool 990~ ~ 1163' ~ SECTION 4~ T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.)6. Lease Designation and Serial No. Kuparuk River Field 53~ ~ ~L 47434 '11 ' '1 14' [ ./. ,.e, ~.To,a,a~,,h(UO+T~) [~S.~,u~ac~e,,,(~Wa~ ~9. Oirectio.~,Surve, [ 20. O.,,,~.eSSS~,e, ~l. Th,o*.e.o,*er~*ro,~ 11,821 (7418) [ 11,732 (7355) YES ~ NO D 514 feet MD · 1800 22. Type Electric or Other Logs Run CBT, CET, CL, GR, GCT, lqI..D 23. CASING, LINER ANDCEMENTING RECORD CASINGSIZE WT. PER FT. GRADE HOLESIZE CEMENTING RECORD AMOUNTPULLED 54.5 K55 30 500 sx Permafrost C .N/A 13-3/8" 9-5/8" 36 7!1 26 K55 L80 SETTING DEPTH MD TOP BOTTOM 35 105 35 6850 35 11777 24. Perforations open to Production (MD+TVD of Top and Bottom and 12-1/4" 8-1/2" 1090 sx Permafrost E & 330 sx Permafrost 550 sx Premium G N/A N/A 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) interval, size and number) LK 1, 12 SPF/24 GM 11,323-11,331 MD 11,355-11,377 MD 11,385-11,403 MD 11,495-11,515 MD 11,521-11,557 MD 11,579-11,583 MD 7076-7081TVD 7096-7111TVD 7116-7128 TVD 7190-7204 TVD 7208-7233 TVD 7249-7251TVD 2-7/8" 11.249' 26. ACID, FRACTURE, CEMENTSQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 3-22-91 Date of Test Hours Tested 2-8-92 6 Flow Tubing Press. 422 Casing Pressure 422 IMethod of Operation (Flowing, gas lift, etc.) Submersible P,,mp TEST PERIOD * { 335 { 62 24-HOUR RATE { 1340 { 247 ! WATER-DEL ICHOKESIZE GAS-OIL RATIO 1 I 209 184 WATER-DEL lOlL GRAVITY-APl (corr) 5 { 23.0 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED FEB 2 0 1992 Alaska Oil & Gas Cons. OommisSio[~ ~nohorage Form 10407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate MILNE PC .~ L-7 FINAL DRILLING REPOi~_ Milne Point L No. 7- Drill & Equip. API No.: 50-029-22028 Location: Milne Point Field - Kuparuk River Pool AFE Number: 10-61-1195 Approved: 07/20/90, NOC 01/11/91 Operator: Conoco 0.7214934 Water Depth: Not Applicable Chevron 0.1737352 KB: 35' OXY 0.1047714 Objectives: Kuparuk Reservoir Spud Date: Rig Release Date: Rig: Planned Depth: Current Depth: Progress: Planned Days: Actual Days: 01/19/91 Nabors 27E 11,905' MD 11,821' MD 0' 23 44 AFE Reserves: 2,487 MBO N/A MMCF 1,251 IP (BOPD) AFE Amount: $2,637,000 gross Cost to Date: $4,506,698 gross Current Cost Est: $4,180,000 gross Test Summary: Type Interval Shows Operations: 03/04/91: COMPLETING Splice cable and hookup to hanger. Land tubing. Drop plug to set packer and tested to 500 psig. Retreived plug. Bleed off tubing, back out landing joint and install BPV. Nipple down BOP. Install tree and test. Released rig at 2000 hours. 03/03/91: Continue RIH with 2-7/8" tubing and ESP. Splice cable at packer. Make up SSSV and test control line. Shut-in well. Weight up brine and circulate 40 bbls. oil and gas through the choke. Splice cable at the hanger. 03/02/91: Service ESP assembly and hookup elecrical cable. RIH with 2-7/8" tubing and electrical cable test cable every 40 joints. Conduct BOP drills with both crews. 03/01/91: Continue bailing sand 11,470'- 11,555', no fill. Bailed sand 11,720'- 11,732', no fill. POOH laid down bailer. Pull wear ring and change rams to 2-7/8". Prepare to run ESP. 02/28/91: Bail sand from 11,283'- 11,397'. POOH and service bailer. Bail sand from 11,334'- 11,502'. POOH and service bailer. 02/27/91: Wait on gels to break. RU WL. RIH. Tag sand at 11,190'. POOH. RD WL. Release PKR. POOH. RIH w/ Bailer on DP. Bail f/ 11,224' to 11,283'. 02/26/91: Fin POOH. Test BOP's. RIH w/ PKR on DP. RU to FRAC well. Press annulus to 2000 psi. Test lines to 10,000 psi. Frac well. tatal PROP 159,595#. Toatal fluid 2018 BBL. Avg Press 8700 psi. ISIP 2396 psi. AVg rate 21 BPM. Open bypass. Rev out sand. Wait for frac gel to break. 02/25/91: Weight up brine to 12.3 PPG. Circ. Release pkr. Well flowing. Circ out gas and oil. Weight up to 12.4 PPG. POOH. 02/24/91: Correlate depth of guns w/ WL. Reposition guns 6' deeper. Verify depth w/ WL. Perforated 6 intervals between 11,323' to 11,583'. RD W/L. Reverse out 30 BBL oil. Release pkr. Had 260 psi DPP & CP. $~_ . Pkr. Rev out gas & oil. ~._11 pits w/ 12.0 PPG Brine. (Fluid in hole is 11.5 PPG). 02/23/91: LD BHA. RU E/L. Run Gyro. Run CBT-CET-CL-GR. MU perforating guns & PKR on DP and RIH. RU E/L to correlate depth of guns. 02/22/91: Fin RIH, picking up 3 1/2" DP. Tag cmt at 11,723'. Wash to 11,730'. Reverse circ dirt magnet around. Filter brine. POOH. 02/21/91: Test packoff to 5000 psi. Change pipe rams to 3 1/2". Clean mud pits & inject mud. Replace and repair damaged valves to mud system. MU BHA (Bit & csg scrapers). RIH, picking up 3 1/2" DP. 02/20/91: Run 274 jts 7", 26 PPF, L-80, BUTT csg. FS @ 11,777'. FC @ 11,733' Circ. Cement w/ 114 BBL G cmt + add's at 15.8 PPG. Recip pipe throughout job. Partial mud returns throughout job (22%). Bump plug. Floats held. Set csg hgr packoff. 02/19/91: RIH w/ bit. C & C. POOH. LD DP, HW, & BHA. RIH w/ RTTS. Set @ 1945'. Test 9 5/8" csg patch to 2000 psi. POOH w/ RTTS. LD DP. RU to run 7" csg. 02/18/91: Drill f/ 11,790' to 11,821'. Circ. Short trip 10 stds. Circ. POOH. Test BOP's. Run 9 5/8" csg patch. Set patch f/ 1910' to 1930'(Leak @ 1920'). POOH w/ rng tool. 02/17/91: Finished logging and POOH with TLC equipment. RD logging company and PU RTTS packer and RIH to pressure test casing. Leak at 1920' which is at the HOS cementer, POOH and LD RTTS RIH to C&C tight spot at 11,059' packing off. Reamed to bottom and freed packed off BHA. Drilling from 11,758' - 11,790'. NOTE: The well lost 220 bbls. of mud while freeing packed BHA. 02/16/91: RIH with logging tools (AMS,NGT,DIL) could not get below 10,540'. POOH with wireline tools. Rig up to run drill pipe conveyed tools (TLC). Continue RIH with CNL, LDT, DIL, NGT, AMS. Hole in good shape. Continue logging with TLC. 02-15-91: Drill f/ 11,680' to 11,758'. C&C. Short trip to shoe. C&C. POOH. RU E/L. RIH w/ triple combo. Could not get below 10,540'. Made three attempts changing tool length and centralization. Unable to get below 10,540'. 02-14-91: Circ 11.4 PPG mud thru choke (2 circ). SIDPP 0 psi. SICP 0 psi. Open annular. C & C mud to 11.6 PPG. Short trip 20 stds. Circ. Mud cut to 10.6 PPG at btms up. Drill f/ 11,552' to 11,680'. Increase MW to 11.8 PPG while drlg. 02-13-91: Drill f/ 11,524' to 11,552'. Observed increase in flow. Shut pumps down. Well flowing. Shut well in. No pressure observed. Circ. Observed increase in flow. Shut in w/ 0 SIDPP and 80 psi SICP. Circ thru choke w/ 10.8 PPG mud (was 10.5 PPG). SIDPP 175 psi & SICP 300 psi. Circ 11.0 PPG mud around. Got back 8.3 PPG gas cut mud. SIDPP 65 psi. SICP 170 psi. Weight up mud to 11.4 PPG. Working pipe while circ (Pipe free). 02-12-91: Drill f/ 10,990' to 11,220'. Short trip 10 stds. Drill to 11,524'. 02-11-91: Drill f/ 10,722' to 10,940' (TOF @ 10,878'). Circ. POOH. MU BHA (Packed ASSY). RIH. Ream 10,884' to 10,940'. Drill f/ 10,940' to 10,990'. 02-10-91: Drill f/ 10,661' to 10,718'. Trip for BHA change. LD motor. Test BOP's. MU BHA (30' pendulum assy). RIH. Ream 10,612' to 10,718'. Drill 10,718' to 10,722'. 02-08-91: Fin RIH w/ bit. Wash f/ 10,096 to 10,185. Circ. Wash to 10,248. Soft cmt @ 10,200'. Circ. Pull into shoe. WOC. RIH. Dress cmt f/ 10,248 to 10,355. C & C. POOH. MU bit and steerable BHA. 02-07-91: Ream 10575 to 10878. Circ. POOH. RIH w/ cmt sub. C & C. Set 50 BB1 cmt plug f/ 10873 to 10,200. POOH. RIH w/ bit. 02-06-91: Fin POOH. RIH w/ jars & screw in sub to 10848'. Circ and work 02-05-91: Stuck Pipe Fin .... IH w/ sinker bars to MWD. oOOH. RIH w/ free point. Unable to get past 10470'. POOH. RIH w/ String shot. Attempt backoff @ 11,014' (above MWD). No backoff. Backoff @ 10,848' (above jars). Circ hole clean. POOH. 02-04-91: Jar on stuck pipe. Move pipe f/ 11,110' to 11,105'. Circ & work pipe. RU E/L. RIH w/ free point. Could not get below top of HWDP @ 9778'. RIH w/ sinker bars. 02/03/91: Drill 11,089 to 11,151'. POOH. Test BOP's. Change bit & MWD. RIH w/ Steerable BHA. Break circ @ 11,140'. Hole tight. Work pipe up to 11,110'. Stuck pipe @ 11,110'. Work pipe. 02-01-91: Drill 9103 to 9221. Short trip 10 stds. Drill to 10,076. Short trip 10 stds. Drill to 10,234. 01/31/91: Drill 7998 to 8654. Short trip to 9 5/8" shoe. Drill to 9103. 01/30/91: Drill 7104 to 7737. Lost 700 psi pump pressure. POOH. Found washout in HWDP. Change out motor to high speed. RIH. Drill 7737 to 7998. 01-29-91: RIH w/ junk basket. Washover junk. POOH. Recovered more metal. RIH w/ rock bit. Drill f/ 6879 to 6888. POOH. RIH w/ PDC bit. Drill to 7104. 01-28-91: Drill out DV collar @ 1913. RIH to 6775. Test csg to 1500 psi. Drill out float equip & cmt. Drill f/ 6870 to 6877. Bit quit. Run leakoff test to 13.5 PPG EMW. POOH. Bit badly damaged f/junk (DV). RIH w/ junk basket. Cut 2' f/6877 to 6879. POOH. Recovered 17 pcs of junk f/ DV. 01-27-91: Circ & recip csg. Cmt first stage w/ 383 BBL Permafrost E @ 12.3 PPG & 68 BB1 G @ 15.8 PPG. Disp w/ mud. Bump plug. Open DV collar. Circ. Had 60 BBL cmt returns. Cmt second stage w/ 372 BBL Permafrost E @ 12.3 PPG & 10 BBL G @ 15.8 PPG. Disp & bump plug. Had 150 BBL cmt returns. ND diverter. MU speed head. NU BOP. Test same. MU 8 1/2" bit & steerable BHA. 01-26-91: Circ. POOH. LD BHA. RU E/L. RIH w/ 4 arm caliper. Could not get below 750'. POOH. RIH w/ 12 1/4" bit to 2021. C & C. POOH. LD BHA. RU E/L. Run 4 arm caliper f/ 2604 to surface. RU and run 157 jts, 9 5/8", 36#, K-55, Butt. FS @ 6850. FC @ 6768. DV @ 1906. 01-25-91: Fin POOH. Change out motor & bit. Lost one cone in hole. RIH. Work past cone. Drill f/ 6493 to 6870. C & C. Short trip to 500'. C & C. 01-24-91: Drill 5904 to 6408. Short trip 10 stds. Drill to 6493. POOH. LD 13 jts G DP. 01-23-91: Drill 4730 to 4763. Start short trip. BHA balled up. POOH. Clean BHA. RIH. Drill to 5841. Short trip 10 stds. Drill to 5904. 01-22-91: Drill f/ 2547 to 2832. Short trip 12 stds. Drill to 3877. Short trip 11 stds. Drill to 4730. 01-21-91: Drill f/ 872 to 992. Run w/1 survey. Drill to 1474. Ream out dogleg. Drill to 1770. Short trip 10 stds. Drill to 2547. 01-20-91: Accepted rig at 0001 hrs 01-19-91. RU. Mix mud. Function test diverter. MU 12 1/4" steerable assy. Drill f/ 105 to 872. 01-19-91: Move rig from J-4 to L pad. ORIGINal. SUB. SURFACE DIRECTIONAL SURVEY ~[]UIDANCE ~]ONTINUOUS ~JOOL Company C0~0C0 Well Name __MPu L-7 (1853' F,,NL, ,4700'_ FI4L,SEC 8]T13N]R1,0E) Fleld/Locatlorl_M[LN[, POZNT, NORTH SLOP.E, _ Job Reference No. _ 74388 Long ,ed .ay: FRITZKE C OFILMED Oate 22-FEB-91 Com~ute ,ct a~ KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA SURVEY DATE: 22-FEB-1991 ENGINEER: A. FRITZKE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 43 DEG 55 MIN EAST COMPUTATION DATE: 4-MAR-91 PAGE 1 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FE8-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 3OO O0 400 O0 500 O0 600 O0 700 oo 800 O0 900 O0 0 O0 99 95 199 95 299 94 399 94 499 91 599 74 699 20 798 25 896 80 -56.00 0 0 N 0 0 E 43.95 0 23 N 16 31 E 143.95 0 27 N 33 27 E 243.94 0 33 N 34 8 E 343.94 0 50 N 29 37 E 443.91 1 59 N 24 17 E 543.74 4 35 N 28 37 E 643.20 7 8 N 31 21 E 742.25 8 50 N 33 3 E 840.80 10 52 N 35 47 E 0 O0 0 20 0 90 1 71 2 95 4 98 10 32 20 35 33 84 50 53 0 O0 0 O8 0 O0 0 40 021 3 76 3 07 1 78 2 O5 2 60 0 O0 N 0 22 N O 89 N 1 58 N 2 67 N 4 53 N g 69 N 18 52 N 30 17 N 44 14 N 0.00 E 0.05 E 0.37 E 0 83 E 1 48 E 2 48 E 481 E 10 11 E 17 46 E 27 02 E 0 O0 N 0 0 E 0 0 1 3 5 10 21 34 51 23 N 13 3 E 96 N 22 35 E 78 N 27 33 E 05 N 29 7 E 16 N 28 45 E 82 N 26 24 E 10 N 28 38 E 85 N 30 4 E 75 N 31 28 E 1000.00 1100.00 1091 1200.00 1186 1300.00 1280 1400 O0 1372 1500 O0 1464 1600 O0 1555 1700 O0 1644 1800 O0 1730 1900 O0 1814 994 47 02 1035 40 1130 38 1224 67 1316 44 1408 68 1499 50 1588 61 1674 90 1758 938 47 13 42 N 37 42 E 02 16 15 N 38 36 E 40 18 24 N 38 42 E 38 21 39 N 38 24 E 67 23 9 N 39 38 E 44 23 34 N 39 44 E 68 25 39 N 38 55 E 50 28 39 N 39 31 E 61 31 43 N 39 40 E 90 33 21 N 40 9 E 71.77 97.66 127.56 161.53 199.89 239.5O 280.29 326.06 376.73 430.40 1 91 1 92 2 34 3 50 051 0 6 2 1 0 35 94 87 47 86 61.18 N 81.62 N 105.06 N 74 131 78 N 96 161 68 N 120 192 21N 145 223 85 N 171 259 37 N 200 298 53 N 233 339 80 N 267 56 04 E 99 80 E 128 03 E 163 27 E 201 67 E 241 62 E 282 73 E 327 11 E 378 62 E 432 39.94 E 73 06 N 33 8 E O0 N 34 28 E 97 N 35 27 E 06 N 36 5 E 51 N 36 39 E 18 N 37 9 E 07 N 37 29 E 97 N 37 44 E 77 N 37 59 E 53 N 38 13 E 2000 O0 1897 40 1841 40 36 21 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1975 O0 2049 O0 2120 O0 2187 O0 2251 O0 2311 O0 2368 O0 2425 O0 2481 38 1919 31 1993 03 2064 53 2131 74 2195 42 2255 74 2312 58 2369 80 2425 N 40 2 E 38 40 42 N 40 32 E 31 43 36 N 40 44 E 03 46 19 N 41 0 E 53 48 48 N 41 55 E 74 51 47 N 43 10 E 42 54 31 N 43 36 E 74 55 17 N 43 18 E 58 55 37 N 43 14 E 1081 80 56 0 N 43 3 E 1164 486.76 549.19 616.39 686.97 760 67 837 28 917 51 999 44 71 4O 6 54 3 59 2 48 1 9O 2 08 4 99 1 69 0 52 0.74 0.33 383 05 N 303 97 E 489 O0 N 38 26 E 430 481 535 590 647 705 764 824 885 72 N 344 82 N 388 27 N 434 63 N 483 07 N 535 28 N 590 74 N 646 69 N 703 04 N 759 46 E 551 28 E 618 52 E 689 29 E 763 12 E 839 33 E 919 71E 1001 06 E 1083 60 E 1166 52 N 38 39 E 79 N 38 52 E 44 N 39 4 E 16 N 39 18 E 68 N 39 35 E 73 N 39 56 E 53 N 40 13 E 70 N 40 27 E 32 N 40 38 E 3000 O0 2537.75 2481 75 56 7 3100 3200 3300 340O 3500 3600 3700 3800 3900 O0 2593.19 2537 O0 2648.00 2592 O0 2702.97 2646 O0 2757 57 2701 O0 2811 94 2755 O0 2866 14 2810 O0 2920 18 2864 O0 2973 72 2917 O0 3026 85 2970 19 56 36 O0 56 47 97 56 45 57 56 56 94 57 12 14 57 17 18 57 30 72 57 51 85 58 2 N 43 19 E 1247 28 N 43 26 E 1330 N 43 21 E 1414 N 43 6 E 1497 N 43 3 E 1581 N 42 41E 1665 N 43 9 E 1749 N 43 12 E 1833 N 42 44 E 1917 N 42 35 E 2002 50 14 67 43 35 37 51 95 65 1.14 0.62 0.13 0.42 0 42 0 O0 0 80 0 94 1 O1 0 34 945 46 N 816 33 E 1249 12 N 40 48 E 1005 1066 1127 1188 1250 1311 1373 1435 1497 98 N 873 73 N 930 66 N 988 79 N 1045 33 N 1102 90 N 1159 21N 1217 03 N 1274 34 N 1332 46 E 1332 96 E 1415 11 E 1499 39 E 1583 46 E 1666 66 E 1750 28 E 1835 83 E 1919 22 E 2004 27 N 40 58 E 84 N 41 7 E 32 N 41 14 E 05 N 41 20 E 96 N 41 24 E 97 N 41 29 E 07 N 41 33 E 50 N 41 37 E 21 N 41 40 E COMPUTATION DATE: 4-MAR-91 PAGE 2 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3080 08 3024 08 57 22 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3134 29 3078 O0 3188 88 3132 O0 3243 58 3187 O0 3297 57 3241 O0 3350 45 3294 O0 3402 79 3346 O0 3455 07 3399 O0 3507.61 3451 O0 3561.07 3505 29 57 16 88 56 44 58 56 55 57 57 46 45 58 18 79 58 33 07 58 27 61 57 40 07 57 51 N 42 20 E 2087 28 N 42 5 E 2171 N 41 59 E 2255 N 41 47 E 2338 N 41 11 E 2422 N 40 43 E 2507 N 4O 15 E 2592 N 39 52 E 2677 N 42 10 E 2762 N 42 35 E 2847 27 01 67 77 54 58 63 56 05 0.24 0.68 1 .17 1 .20 0.95 1 .33 0.78 0.58 1 .80 0.57 1559 75 N 1389 42 E 2088 85 N 41 42 E 1622 1684 1746 1809 1873 1~38 2003 2068 2130 05 N 1445 28 N 1501 59 N 1557 63 N 1613 67 N 1669 53 N 1724 78 N 1779 44 N 1834 69 N 1891 82 E 2172 92 E 2256 82 E 234O 60 E 2424 29 E 2509 55 E 2594 41 E 2679 70 E 2764 85 E 2849 89 N 41 43 E 67 N 41 43 E 38 N 41 44 E 55 N 41 43 E 42 N 41 42 E 61 N 41 39 E 82 N 41 36 E 88 N 41 34 E 38 N 41 36 E 5000 O0 3613.87 3557.87 58 22 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3665.94 3609.94 58 59 O0 3717 59 3661.59 58 28 O0 3770 11 3714.11 58 23 O0 3822 47 3766.47 58 34 O0 3874 63 3818.63 58 52 O0 3926 82 3870.82 58 20 O0 3979 57 3923.57 57 23 O0 4033 44 3977.44 57 19 O0 4087 81 4031.81 57 8 N 42 16 E 2931 94 N 41 39 E 3017 N 44 10 E 3102 N 44 9 E 3187 N 44 2 E 3273 N 43 55 E 3358 N 43 39 E 3443 N 43 53 E 3528 N 44 1E 3612 N 44 6 E 3696 27 87 96 16 48 78 73 98 90 0.40 0.22 0.86 0.74 0.33 0.44 0.35 0.87 0.78 0.00 2193.35 N 1949 17 E 2934 29 N 41 38 E 2256.81N 2006 2319.71 N 2064 2380.70 N 2123 2441.89 N 2182 2503.30 N 2242 2564.83 N 2301 2626.31 N 2359 2686.98 N 2418 2747.32 N 2476 28 E 3019 37 E 3105 72 E 3190 99 E 3275 23 E 3360 30 E 3445 93 E 3530 39 E 3615 71E 3698 66 N 41 38 E 27 N 41 40 E 28 N 41 44 E 41 N 41 48 E 67 N 41 51 E 92 N 41 54 E 83 N 41 57 E 03 N 41 59 E 90 N 42 2 E 6000 O0 4142.57 4086.57 56 31 6100 62OO 6300 6400 6500 6600 6700 6800 6900 O0 4198.26 4142 26 55 42 O0 4254.83 4198 O0 4312.50 4256 O0 4372.26 4316 O0 4431.48 4375 O0 4491.45 4435 O0 4552.19 4496 O0 4613.23 4557 O0 4674.04 4618 83 55 9 5O 53 53 26 53 4 48 53 47 45 52 5O 19 52 27 23 52 24 04 53 33 N 44 17 E 3780.58 N 44 32 E 3863.63 N 44 41 E 3946.09 N 44 38 E 4027.77 N 44 37 E 4107.95 N 44 18 E 4188.52 N 44 32 E 4268.54 N 45 45 E 4347.96 N 46 27 E 4427.11 N 48 1 E 4506.37 1 O6 0 6O 1 46 2 26 1 51 031 1 65 1 04 0 93 3 78 2807.30 N 2535 06 E 3782 52 N 42 5 E 2866 70 N 2593 2925 2983 3040 3097 3155 3211 3266 3320 33 N 2651 40 N 2708 42 N 2764 95 N 2821 15 N 2877 20 N 2933 08 N 2990 11N 3048 12 E 3865 09 E 3947 56 E 4029 94 E 4109 35 E 4190 31 E 4270 60 E 4349 72 E 4428 87 E 4507 52 N 42 8 E 90 N 42 11 E 51 N 42 14 E 62 N 42 17 E 14 N 42 19 E 12 N 42 22 E 46 N 42 25 E 51 N 42 29 E 63 N 42 34 E 7000 O0 4730 45 4674 45 57 18 7100 72O0 7300 7400 7500 7600 7700 7800 7900 O0 4784 O0 4836 O0 4889 O0 4941 O0 4993 O0 5O43 O0 5094 O0 5148 O0 5202 18 4728 73 4780 65 4833 98 4885 52 4937 84 4987 40 5038 52 5092 36 5146 18 58 10 73 58 5 65 58 13 98 58 47 52 59 12 84 6O 14 40 58 6 52 57 6 36 57 43 N 48 9 E 4588 68 N 47 49 E 4672 N 47 35 E 4757 N 47 20 E 4842 N 44 6 E 4927 N 42 47 E 5013 N 42 38 E 5099 N 42 6 E 5185 N 42 5 E 5269 N 41 34 E 5354 81 71 39 54 22 61 85 90 12 0.42 1 .48 2.96 0.90 3.40 0.58 0.47 4.02 0.75 2.01 3375 18 N 3110 36 E 4589 79 N 42 40 E 3431 3488 3546 3605 3668 3731 3795 3857 3920 68 N 3172 96 N 3235 24 N 3298 42 N 3359 03 N 3418 53 N 3476 15 N 3535 52 N 3591 31N 3647 97 E 4673 88 E 4758 47 E 4843 78 E 4928 29 E 5013 90 E 5100 15 E 5186 55 E 5270 76 E 5354 77 N 42 45 E 54 N 42 51 E 11 N 42 56 E 20 N 42 59 E 89 N 42 59 E 30 N 42 59 E 57 N 42 58 E 65 N 42 57 E 90 N 42 56 E COMPUTATION DATE: 4-MAR-91 PAGE 3 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 5255.56 5199.56 58 2 8100 8200 8300 84O0 8500 8600 8700 8800 8900 O0 5308.31 5252.31 58 16 O0 5360.39 5304.39 58 55 O0 5411.67 5355.67 59 24 O0 5462.63 5406.63 59 22 O0 5513.97 5457.97 59 15 O0 5564.71 5508.71 59 49 O0 5615.11 5559.11 59 7 O0 5667,36 5611.36 58 30 O0 5719.14 5663.14 59 16 N 41 1E 5438 70 N 40 25 E 5523 N 40 8 E 5608 N 39 45 E 5694 N 41 9 E 5780 N 42 50 E 5865 N 42 40 E 5952 N 42 19 E 6038 N 42 7 E 6123 N 41 34 E 6209 52 72 36 22 99 14 49 71 21 0 36 0 35 1 48 0 18 1 85 0 15 0 79 1 96 0 83 0 58 3983.91 N 3703 66 E 5439 54 N 42 55 E 4048.30 N 3759 08 E 5524 4113.42 N 3814 27 E 5609 4179.28 N 3869 34 E 5695 4245.01 N 3924 86 E 5781 4308.41 N 3982 69 E 5867 4371.70 N 4041 17 E 5953 4435.37 N 4099 53 E 6039 4498.50 N 4156.83 E 6125 4562.22 N 4213.92 E 6210 44 N 42 53 E 71 N 42 50 E 45 N 42 48 E 41 N 42 45 E 22 N 42 45 E 38 N 42 45 E 75 N 42 45 E 01 N 42 44 E 55 N 42 44 E 9000 O0 5769 70 5713.70 60 3 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 5818 O0 5867 O0 5917 O0 5967 O0 6021 O0 6077 O0 6131 O0 6184 O0 6241 63 5762.63 61 16 06 5811.06 60 15 15 5861 15 60 22 O0 5911 O0 58 39 45 5965 45 55 47 29 6021 29 56 35 65 6075 65 57 46 92 6128 92 56 29 38 6185 38 55 50 N 40 50 E 6295.38 N 40 26 E 6382.45 N 40 27 E 6469.77 N 40 27 E 6556.16 N 40 25 E 6642.69 N 40 54 E 6726.39 N 44 5 E 6809.31 N 44 23 E 6893.24 N 46 19 E 6977.83 N 45 58 E 7060.31 0 44 1 07 1 76 0 34 4 26 2 43 0 37 212 3 93 0.80 4627 17 N 4270.70 E 6296 79 N 42 42 E 4693 4759 4825 4891 4955 5016 5076 5136 5193 34 N 4327.51 E 6383 96 N 4384.21 E 6471 82 N 4440.36 E 6557 81 N 4496.58 E 6644 70 N 4550.91 E 6728 65 N 4607.15 E 6811 81 N 4665.68 E 6895 29 N 4725.87 E 6979 53 N 4785.33 E 7062 95 N 42 41 E 36 N 42 39 E 85 N 42 37 E 47 N 42 35 E 27 N 42 34 E 21 N 42 34 E 11 N 42 35 E 64 N 42 37 E 02 N 42 39 E 10000.00 6296.96 6240.96 56 36 10100.00 6351,20 6295.20 57 43 10200.00 6403.85 6347.85 58 9 10300 O0 6459.11 6403.11 54 51 10400 O0 6516.51 6460.51 55 45 10500 O0 6572.07 6516.07 56 56 10600 O0 6625.61 6569.61 57 51 10700 O0 6677.87 6621.87 59 6 10800 O0 6730.82 6674.82 56 46 10900 O0 6787,62 6731.62 53 49 N 46 1 E 7143.39 N 45 43 E 7227 35 N 45 41 E 7312 N 44 41E 7395 N 44 3O E 7477 N 44 17 E 7560 N 44 7 E 7645 N 44 3 E 7730 N 45 28 E 7815 N 50 22 E 7897 33 63 5O 65 10 36 17 27 1 24 1 27 2 52 3 63 1 O8 1 74 0 68 0 83 4 O8 6 43 5251 26 N 4845.15 E 7145 01 N 42 42 E 5309 5369 5427 5486 5545 5605 5667 5728 5783 79 N 4905.41 E 7228 18 N 4966.26 E 7313 78 N 5025.49 E 7397 11 N 5082.96 E 7478 56 N 5141.08 E 7562 99 N 5200.09 E 7646 20 N 5259.42 E 7731 03 N 5318.54 E 7816 41 N 5379.38 E 7898 90 N 42 44 E 81 N 42 46 E 05 N 42 48 E 89 N 42 49 E 01 N 42 50 E 44 N 42 51 E 67 N 42 52 E 47 N 42 53 E 45 N 42 56 E 11000.00 6847.75 6791.75 52 49 11100.00 6908.74 6852.74 52 6 11200.00 6970.78 6914.78 51 10 11300.00 7034.28 6978.28 50 12 11400.00 7098.96 7042.96 48 55 11500.00 7165.77 7109.77 47 29 11600.00 7234.14 7178.14 46 20 11700.00 7304.87 7248,87 44 34 11777.00 7359.75 7303.75 44 34 N 53 44 E 7976.23 N 56 19 E 8053.99 N 57 50 E 8130.34 N 59 13 E 8205 10 N 59 12 E 8278 55 N 59 5 E 8350 36 N 58 43 E 8420 84 N 59 4 E 8489 35 N 59 4 E 8541 49 1 .65 1 .71 1 .O8 1.14 1 .74 0.37 1 .34 0.00 0.00 5831 88 N 5442.88 E 7977.20 N 43 1 E 5877 5919 596O 5998 6037 6074 6111 6139 34 N 5507.78 E 8054.74 N 43 8 E 90 N 5573.66 E 8130.86 N 43 16 E 24 N 5639 54 E 8205.41 N 43 25 E 94 N 5705 24 E 8278.71 N 43 34 E 17 N 5769 08 E 8350.43 N 43 42 E 84 N 5831 56 E 8420.85 N 43 50 E 53 N 5892 22 E 8489.35 N 43 57 E 30 N 5938 55 E 8541.51 N 44 3 E COMPUTATION DATE: 4-MAR-91 PAGE 4 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN -56 O0 47 938 40 1841 75 2481 08 3024 87 3557 57 4086 45 4674 56 5199 70 5713 0 0 47 13 42 40 36 21 75 56 7 08 57 22 87 58 22 57 56 31 45 57 18 56 58 2 70 60 3 ENGINEER: A. FRITZKE 0 O0 O0 994 O0 1897 O0 2537 oo 3080 oo 3613 O0 4142 oo 4730 O0 5255 O0 5769 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 N 0 0 E 0.00 N 37 42 E 71.77 N 40 2 E 486.76 N 43 19 E 1247.28 N 42 20 E 2087.28 N 42 16 E 2931.94 N 44 17 E 3780.58 N 48 9 E 4588.68 N 41 1 E 5438.70 N 40 50 E 6295.38 10000.00 6296.96 6240.96 56 36 11000.00 6847.75 6791.75 52 49 11777.00 7359.75 7303.75 44 34 N 46 1E 7143.39 N 53 44 E 7976.23 N 59 4 E 8541.49 0 O0 1 91 6 54 1 14 0 24 0 40 1 06 0 42 0 36 0 44 0 O0 N 61 383 945 1559 2193 2807 3375 3983 4627 18 N 39 05 N 303 46 N 816 75 N 1389 35 N 1949 3O N 2535 18 N 3110 91 N 3703 17 N 4270 94 E 73 97 E 489 33 E 1249 42 E 2088 17 E 2934 06 E 3782 36 E 4589 66 E 5439 70 E 6296 0 O0 E 0 O0 N 0 0 E 06 N 33 8 E O0 N 38 26 E 12 N 40 48 E 85 N 41 42 E 29 N 41 38 E 52 N 42 5 E 79 N 42 40 E 54 N 42 55 E 79 N 42 42 E 1 .24 1 .65 0.00 5251.26 N 4845.15 E 7145.01 N 42 42 E 5831.88 N 5442.88 E 7977.20 N 43 1 E 6139.30 N 5938.55 E 8541.51 N 44 3 E COMPUTATION DATE: 4-MAR-91 PAGE 5 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 0 O0 56 05 156 05 256 06 356 06 456 07 556 15 656 50 757 3o 858 52 0 O0 56 O0 156 O0 256 O0 356 O0 456 O0 556 O0 656 O0 756 O0 856 oo -56 O0 0 O0 100 O0 200 O0 300 O0 400 O0 50O O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 9 N 9 24 E 0 26 N 26 32 E 029 N 32 3 E 045 N 31 4 E 1 12 N 29 33 E 3 19 N 22 36 E 6 4 N 31 26 E 7 58 N 32 31 E 9 52 N 34 36 E 0 O0 0 O0 0 57 1 33 2 36 3 89 7 50 15 42 27 72 43 15 0 O0 0 O0 0 09 0 04 0 06 081 1 45 2 77 1 46 2 44 0 O0 N 0 O0 N 0 60 N 1 26 N 2 14 N 3 50 N 7 01 N 14 21 N 24 92 N 38 03 N 0 O0 E 0 O0 E 0 20 E 0 62 E 1 18 E 1 97 E 3 52 E 7 48 E 14 09 E 22 71 E 0 O0 N 0 0 E 0 0 1 2 4 7 16 28 44 O0 N 13 31 E 63 N 18 27 E 40 N 26 6 E 44 N 28 48 E 02 N 29 24 E 85 N 26 41 E 06 N 27 46 E 63 N 29 28 E 30 N 30 51 E 960.47 956.00 900.00 12 43 1063.59 1056.00 1000.00 15 34 1168.02 1156.00 1100.00 17 55 1273.86 1256.00 1200,00 20 43 1381 88 1356.00 1300.00 23 3 1490 79 1456.00 1400.00 23 33 1600 35 1556.00 1500.00 25 40 1713 17 1656.00 1600.00 29 13 1829 93 1756.00 1700.00 32 12 1949 39 1856.00 1800.00 34 2 N 37 34 E N 38 28 E N 38 44 E N 38 2O E N 39 27 E N 39 46 E N 38 55 E N 39 32 E N 39 48 E N 40 1 E 62,75 87.71 117.65 152.14 192 80 235 83 280 44 332 47 392 54 457 72 3.88 54.00 N 2.66 73.80 N 49 1.16 97.29 N 68 3.51 124.37 N 90 0.77 156.20 N 115 0.22 1'89.38 N 143 6.82 223.97 N 171 4.38 264.33 N 204 1.86 310.72 N 243 2.39 360.75 N 285 34 39 E 81 E 89 58 E 119 18 E 153 74 E 194 32 E 237 72 E 282 82 E 334 24 E 394 26 E 459 64 02 N 32 29 E 04 N 34 1 E 03 N 35 11 E 63 N 35 57 E 41 N 36 32 E 50 N 37 7 E 22 N 37 29 E 39 N 37 46 E 60 N 38 3 E 91 N 38 20 E 2074 66 1956.00 1900.00 39 54 2209 23 2056.00 2000.00 43 49 2352 71 2156.00 2100.00 47 37 2506 92 2256.00 2200.00 52 6 2677 63 2356.00 2300.00 55 13 2854 03 2456.00 2400.00 55 48 3032 71 2556.00 2500.00 56 8 3214 60 2656.00 2600.00 56 43 3397 11 2756.00 2700.00 56 56 3581.26 2856.00 2800.00 57 13 N 40 29 E N 4O 45 E 622 N 41 21E 725 N 43 15 E 842 N 43 23 E 981 N 43 8 E 1126 N 43 18 E 1274 N 43 17 E 1426 N 43 4 E 1579 N 43 8 E 1733 532 89 73 46 73 05 35 42 35 01 61 3 08 2 89 3 02 4 55 041 0 26 0 76 0 73 0 43 0 79 418 30 N 333 86 E 535 20 N 38 36 E 486 564 651 751 857 965 1075 1187 1300 64 N 392 28 N 459 04 N 538 36 N 634 24 N 733 21 N 834 61 N 939 02 N 1043 40 N 1148 42 E 625 88 E 727 85 E 845 09 E 983 61 E 1128 95 E 1276 34 E 1428 74 E 1580 88 E 1735 15 N 38 53 E 94 N 39 11 E 11 N 39 37 E 17 N 40 10 E 30 N 40 33 E 24 N 40 52 E 04 N 41 8 E 63 N 41 19 E 21 N 41 28 E 3766.81 2956.00 2900 O0 57 39 3955.10 3056.00 3000 4140 O0 3156.00 3100 4322 76 3256.00 3200 4510 58 3356.00 3300 4701 77 3456.00 3400 4890 47 3556.00 3500 5080 74 3656.00 3600 5273 15 3756.00 3700 5464 13 3856.00 3800 O0 57 58 O0 56 55 O0 57 0 O0 58 22 O0 58 28 O0 57 47 O0 58 50 O0 58 11 O0 58 32 N 42 54 E 1889.90 N 42 35 E 2049.40 N 42 2 E 2204.85 N 41 38 E 2357.73 N 40 38 E 2516.52 N 39 51 E 2679.14 N 42 35 E 2838.98 N 41 44 E 3000.78 N 44 10 E 3165.12 N 43 55 E 3327.82 0.57 1 .53 1.11 1 .32 0.41 0.46 0.60 1 .56 1 .09 1 .35 1414 44 N 1255.76 E 1891 45 N 41 36 E 1531 1646 1760 1880 2004 2124 2244 2364 2481 78 N 1363.86 E 2050 99 N 1468.32 E 2206 83 N 1570.50 E 2359 50 N 1675.16 E 2518 94 N 1780.38 E 2681 75 N 1886.39 E 2841 49 N 1995.31 E 3003 31 N 2107.80 E 3167 21 N 2220.96 E 3330 96 N 41 41 E 48 N 41 43 E 45 N 41 44 E 42 N 41 42 E 33 N 41 36 E 31 N 41 36 E 17 N 41 38 E 46 N 41 43 E 03 N 41 50 E COMPUTATION DATE: 4-MAR-91 PAGE 6 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5655 73 3956 O0 3900.00 58 25 5841 6024 6202 6373 6541 6706 687O 7047 7236 68 4056 O0 4000.00 56 58 26 4156 O0 4100.00 56 17 04 4256 O0 4200.00 55 6 02 4356 O0 4300.00 52 54 18 4456 O0 4400.00 53 3 26 4556 O0 4500.00 52 29 O0 4656 O0 4600.00 52 36 32 4756.00 4700.00 57 13 34 4856.00 4800.00 57 57 N 43 34 E 3491 25 N 44 1 E 3648 N 44 18 E 3800 N 44 41 E 3947 N 44 44 E 4086 N 44 19 E 4221 N 45 49 E 4352 N 47 35 E 4482 N 47 55 E 4628 N 47 37 E 4788 O2 79 76 42 6O 92 45 41 46 1 86 1 O2 0 6O 1 61 0 39 1 31 0 84 3 O6 0 78 1 26 2599 22 N 2334 03 E 3493 37 N 41 55 E 2712 2821 2926 3025 3121 3214 3304 3401 3509 17 N 2442 77 N 2549 53 N 2652 11 N 2749 63 N 2844 66 N 2937 02 N 3031 82 N 3139 75 N 3258 75 E 3650 17 E 3802 27 E 3949 80 E 4088 45 E 4223 16 E 4354 10 E 4483 97 E 4629 62 E 4789 05 N 42 0 E 71 N 42 6 E 57 N 42 11 E 11 N 42 16 E 21 N 42 20 E 41 N 42 25 E 76 N 42 32 E 45 N 42 42 E 25 N 42 53 E 7427.09 4956.00 4900 O0 58 54 N 43 13 E 4950 71 7624.51 5056.00 5000 O0 60 12 N 42 38 E 5120 7813.80 5156.00 5100 O0 57 16 N 42 0 E 5281 8000.83 5256.00 5200 O0 58 2 N 41 1 E 5439 8191.51 5356.00 5300 O0 58 49 N 40 8 E 5601 8386.98 5456,00 5400 O0 59 26 N 40 53 E 5769 8582.71 5556.00 5500 O0 59 40 N 42 41 E 5937 8778.28 5656,00 5600 O0 58 29 N 42 10 E 6105 8972.59 5756.00 5700.00 59 52 N 40 59 E 6271 9177.60 5856.00 5800.00 60 34 89 49 4O 46 O2 21 21 67 N 40 25 E 6450.32 2 29 0 96 1 74 0 29 1 1 0 1 2 1 3622 19 N 3375.77 E 4951 37 N 42 59 E 3747 18 N 3491.31 E 5121 58 N 42 59 E 3866 13 N 3599.32 E 5282 24 N 42 57 E 3984 44 N 3704.12 E 5440 24 N 42 55 E 17 4107 86 N 3809.58 E 5602 45 N 42 51 E 88 4236 56 N 3917.51 E 5770 21 N 42 46 E 71 4360.72 N 4031.04 E 5938 45 N 42 45 E 40 4484.77 N 4144.41 E 6106.50 N 42 44 E 44 4609,23 N 4255.15 E 6273.06 N 42 43 E 17 4745.13 N 4371.58 E 6451.90 N 42 39 E 9378 57 5956.00 5900 O0 59 36 9561 9746 9926 10109 10294 10470 10657 10845 11013 61 6056.00 6000 14 6156.00 6100 07 6256.00 6200 O0 6356.00 6300 58 6456.00 6400 81 6556.00 6500 57 6656.00 6600 12 6756.00 6700 66 6856.00 6800 O0 56 0 O0 58 17 O0 55 59 O0 57 51 O0 55 3 O0 56 20 O0 58 37 O0 55 37 O0 52 50 N 40 26 E 6624.33 N 43 17 E 6777 37 N 45 10 E 693243 N 45 59 E 7081 88 N 45 43 E 7234 96 N 44 47 E 7391 19 N 44 15 E 7536 28 N 44 10 E 7694 O0 N 47 27 E 7852 57 N 54 1 E 7986.95 5 15 3 11 2 78 0 74 1 54 3 78 0 58 2 54 4 50 201 4877.81 N 4484.65 E 6626.10 N 42 36 E 4993.59 N 4585.05 E 6779.28 N 42 33 E 5104.68 N 4693.24 E 6934.28 N 42 36 E 5208.53 N 4800,84 E 7083,56 N 42 40 E 5315.11 N 4910.86 E 7236.50 N 42 44 E 5424.63 N 5022.37 E 7392.61 N 42 48 E 5528.11 N 5124.07 E 7537.64 N 42 50 E 5641.10 N 5234.11 E 7695.32 N 42 51 E 5753.82 N 5345.66 E 7853.83 N 42 54 E 5838.30 N 5451.67 E 7987.89 N 43 2 E 11176.38 6956.00 6900.00 51 20 11333.93 7056~00 700~.00 50 11485.54 7156.00 7100.00 47 33 11631.47 7256.00 7200.00 45 39 11771.74 7356.00 7300.00 44 34 11777.00 7359.75 7303.75 44 34 N 57 35 E 8112.45 N 59 35 E 8230.21 N 59 7 E 8340.07 N 58 41 E 8442.74 N 59 4 E 8537.93 N 59 4 E 8541.49 1 36 1 84 0 3O 2 78 0 O0 0 O0 5910.05 N 5558 08 E 8113.01 N 43 15 E 5973.50 N 5661 97 E 8230.47 N 43 28 E 6031.69 N 5759 92 E 8340.14 N 43 41 E 6086.59 N 5850 92 E 8442.74 N 43 52 E 6137.40 N 5935 39 E 8537.95 N 44 2 E 6139.30 N 5938 55 E 8541.51 N 44 3 E CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA MARKER LAST READING GCT TD COMPUTATION DATE: 4-MAR-91 PAGE 7 DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 1853' FNL ~ 4700' FEL, SEC8 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11672.20 72B5.06 7229.06 6101,51 N 5875.50 E 11777.00 7359.75 7303.75 6139.30 N 5938.55 E COMPUTATION DATE: 4-MAR-91 PAGE 8 CONOCO INC. MILNE POINT UNIT L-7 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 22-FEB-1991 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: A. FRITZKE ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1853' FNL & 4700' FEL, SECB T13N RIOE MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST READING GCT TD 11672.20 7285.06 7229.06 6101.51 N 5875.50 E 11777.00 7359.75 7303.75 6139.30 N 5938.55 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 11777.00 7359.75 7303.75 8541.51 N 44 3 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY CONOCO INC. NELL MILNE POINT UNIT L-7 FIELO MILNE POINT COUNTRY USA RUN ONE DATE LOOOEO 22 - FEB - REFERENCE ~EL,L' ' HILNE POINT UNIT l-7 (1853, ~FNL, 4700' FEL, sEc 8, .~3N, RIOE) HORIZONTAL PROJECTION 'NORTH 12000 REF 74388 5CI:ILE = ~ / 2000 I N/FT lO000 · 400O 20OO -2000 ~OUTH -4000 -6000 WEST -2000 0 2000 4000 GO00 8000 10000 · , WEL-. ' i.IILNE' POINT UNIT L-7 ,....,.-% (1853' 'FNL, 4700' FEL., SEC .8, T7 ~ RIOE) VERTICAL ?i",UdLU~ tur~ -4000 -2000 0 0 2000 4000 6000 8000 10000 ~ I i ~ = '~ ..'~ i' !; {' .~ ..~ l'~J~"! ~-- ;~ ~ ~; ~ ~ ~ ' ~ ~: :~'~ ~' .~~.' ~-- ..~-.~...4..- -~-~..~-.-~: ~ ....... ..... ~..~-.* ...... * ....... ~...~ ........... *..-*-.~ ..... 4..~...~..-, ~ ~ ~ ~ ~ ~ ~ ~ ~ "~ ~ i ~1 I~ i i i ~ ~ ~ ~ ~ ; ' i i ~ ~-~-'~* t"~'~"t-""~-'+ ...... t'"t'~-'~ ...... V'~'~ ..... t"~-~ '~, '*'~ i ~ ~ ~ ~ * , ~ ~ ~-' ~ i' ~ '" ~ ~ , ~ ~ , ~',~ .... '-~-~,-?'*'+--"-*~'"?"* ..... ?"',--'?",'"r--?-~',-I ~.~--4-~4,~---..4---~.4..4-4-.-4-.4.-,4.-.4 ...... ~.4,-.4...~.+.4--44.~.-.~-~4~. ~ ~ ~M.~-~-&4.--.~-4.4-~44..~..~ ...... &~.-L.-4..4..4,..4...4...+ ...... ~'?-~-'f-fS- 5'ff"i"i-+'t'?"f"~ ..... hnWN'i"t' 5eT-t. }H-fi ...... '~-~"~'W--TT'?TTT'TTT" "'?"~'"7"]'"~"]'"T']]T""g'W'~ ~ ~ ~ ~"-T'T~TTU ~ ~W-TT'~'7'7"7"-~"TT'I ..... ~"T"7'7'"'~T'7~-'FT"7"T" i ~:= } ~-~,-q-?..-,-~-~ ....... r.~-?-?..-'?'-~-?'?'m'-??~-~ ~ : ]~ i 5 i5 ~ ~ 5:5 %: -?W~--,7]-?-m-m--* .... ~'~', , ~"t ....... *"'~"%-% ...... *'"?'"?'"?- ~, J ~ l i, J~?:%w??-?r"'Tm~h~"~--~ J~ ?~ii{ ~ i"-i ?- 7% i:t-~'~t~T%T"~TT]~-.'~Z?'"'"T'T"]"'T"J"T":'T ,-0~i::4 :~ ~"+-~---*-~-'f-'+"-7'+'"~"?'5-t"+-'?~'" ..+4...?f- -~-~-'-+N-~.~..~tW...{~O.++.l-,.5..~...i ...... 7~-~-.4.-~-?T-.~-..~ ....... ~"'?"?"~'"?' ~ ?-7'-?" ~ ....................... ~ ............................... ¢ ................................................ 4 ........................... ~.4.., ............. , ....... ,...~ .~ ......... ~ .... --~m ..... ~- ~--W?.+.-..-.+ ...... +---r ....... ?--,---?., }--?-.,--.,-?~-.~-.?-.,-,--...~-~ ~-,.-?- 5 ~ ~+...~-.?..?,...f..?m--m'.~-' '--'~'-m"*"? ..... *'"*'"?~ r":-', 7' ~ ..... ~ 7'" ~:~: } 5 iff-f ? t-t-%-m?-?.'~ -.-?-~--?.?--t...t~UT~'-'W-%t~ ,m~; i } j ~ ~m" q-T-?"?'t"Y-r'~"'t ...... ?'T"?"~ '"t"'?"T"? ...... t"7 ....... 7"T"r ....... :-'7 ' i i ~ , ~ ; i ~ i ~ ~z ~ ; ; ~ ~ ' ~ ~ i i : ! i t i t i ~ ~ .~ ~-~- ~ ~14-~.;.~-&.:4...~ L.4...;...i -..~..i...;,..&...4 ........... ; .................. ;... .4~4,, ~ .............. .... } F:f ~: -O-~b~..-~---O--..--+].'~ ~ , ~: ' i-b--h4. } ................................... { i ~ } i i ~ ¢ ': ':4--~-d-f+ff-{-~-4..4..+--?~+-'f ..... {"+"f"f ...... 1"+"?'+"t'""' ......... ~ ' ' ~ ' ' ' : ' ' ' ' : '. '-'-'.--4~.-*..~---¢.~..*...~ ..... ,.-+...*...;...L.;...~ .; ....... f..~...? ._,_ .,,, , ,,,, ,,,, i,/¢ ::;:::::;:::: ::::::: :::::::::::::::::::::::: [!J ! J i.i ~ J ~ ~ ~ ~ ~ . L..: ~ ~ i,i ~ i ~ ~ i ~ I i ~ i ~ ! ~ ~ J.~ L~ ~ ~ ~ ~.~; ': T : ~ ~ ...;4...; ........ ;-4 ......... ~ .................. '~ ~ :~ ~ } ~ } T'~ ?+~'~"-'~'f"'f"~ }' fur ~ i r f ' ~ r i ; i } } ~-r~~7-~"~-~"'t'T-f"7"7'"7'" "W-'*'"*'"~'"T .......... : ....... .~ ~ ; , ~ f ~:~-~.*~-..-..t ? - ..... ~ ~ ; ~ ; ~-~.~ ~-~-~.'-""~'"4'"+'"'"1'"?'+","'~ ...................... ~ ....... ~'7 ..... tq ~ ~ ~ ~ ~ ~ r ~ ~ ~-T'7"T"T""T?'7-TT'~ ~ ~ ~ ~ ~ i i ~ ~ ~ ~ ~ ~ : T~ :TI ~'7 Tq : ' : : : · ] : : , : ~ . .~ :: '"~ ~: ff i:: i~ ~ -'t'~-? '"?'m":'"?'T'T'I"~' ~ ~- r~ 'I"'?': !- '~'T'T'T'T'T'T'7"%';' "",' : '7 I I ~ I ~ : ' ; t , i ~ ~ i : i_ L L_ i_~ 1~ -~--$ ~ ~ ~ ~ ~ ~ I : ~ L ~ -4 ~-4~ ' .4-.-~-4--~-.~.~.-~ ..... 4.~.-4...4 ...... · ....... ;...; ....... ;-..~..4...i ...... ,...~ ........ f ?" tiii ~{ ~,~ ~ =,,~t,,,~ ,,,~ {}~. ,.,.~.,,~6_,.i. u.,_,..~..I..u..u_~...u.:...:...u.~..:....t...~...:...~..: ..... ;...: ...... ~ ..... 1 " , ~ 2::i :? ~'~:=t .... ~:'~"'"[T"'T T"¢"T'~"T"W' '~% ] i T [ '~Y ~ '~ % T ~ i 7 ? T · J T ~ : T : : ' . i : ~ : ~ --~ :~: ~ ~ ~ e ~ ::f: ~+~ ...... N':~:~'~-e~" "~' ~' "+'~"" ~-'+"+'~ ...... ~'"+"~ ....... }'"+'"'~ ...... ~ ...... : ~ = .......... ~': 1' ~ ........ 12OO0 44. PROJECTION ON VERTICAl. PLANE 44. - 224. 6CALED IN VERTICRL DEPTHS HORIZ SCF~LE = 1/2000 IN/FT ^OOCC GEOLOGICAL MAIEI:aJALS INVENIOP, Y LiST --~-'~ .... :: __ : _~ L~ i i1,11 i i i , - form received received date Commeni~ ......... ~-~o-~ .............. ~-i.~: ........ ~,~ ......... ;i-~i--;~ .................................. ........... '~'~""~"~'~"~ "'~'~' ...................... , 403 yea no sund~ application 4~4 yes " no ..... repod of sund~ application ...... ,,, , , il i,, , ,,,, i dLJ i, , ,,,1 i i Open required received Cased required received :-~roductior required received ,,hole.,,,,109, ,, hole log log ....... MUD, OCT ~ ~ IEMP '-:Di~s FL_ /.....~ ~ CNL ...................... ~0D ....... .... OL~.- ...... "CB'I BHC~SL' gET ...... E~ OHtER DA~A ........... :__ , , , !_~ PERF nEC _ ......... _ __ . ..... "'SSS '- PACKER ~ / Digital Data r~C- W~li I CNI_ ~ ~ / Tests FDC RWD reqU'i-~-"~i~ ..... s~p~S'rcquhe-d' received MWD .... ,, , ,, LDTICNL ~ ~ d~ ditch ML core CYBER ......................... core " Analysis ........... .__~~ ~ ..... ~ ................... ,.,,,..,, ,,, III AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST PERMIT# cl~ -~_'~"7 COMPLETION DATE ~. . / c~,~ i c~l CO. CONTACT Co~oc..~ cl~eck off or list data as it i~' received.*list received de. re for 407. if 407 ! *a...~,O -ct?-- ariliin~ history,* ! v'l' survey! v'[ well tests cored intervals , core analysis ,~ dr~t ditch inte~als ~0~' m ~ not r~j,u, ired list as NR digital data i LOG -,'~n=, ,r',_ RUN INTERVALS SCALE ..... NO. [to the neares,t foot! [inchl100'] ...... . . 12! i,~ ~, ,,~ , , ,,, , ,, ~ ~H., ...... SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS ?7251-2 175 FEB 2 ? 1991 ~..SE .EPL¥ TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention' Van Lineberser Gentlemen: Enclosed ore 2 BLprintsof the Company CONOC0, Inc. / / / GCT, CET, CBT. Run 1 2/22/91 TCP 'Gun/Packe/r Posit~nni-_g Rec~ [,an !, 2/23f~1 Well_ Milne Point Unit L-7 Field Milne Point Additional prints ore being sent to: 1 BL nrints CONOC6, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope State 1BL prints, 1RF Sepia CONOCO, Inc. 1000 South Pine Alaska Ponca City, OK 74603 Attn: Glenn Welch 7360RDW 1BL prints, I RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A. 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) ~sk~ Oil & Gas Go~serva~ion /Commission ' , / t.~ooz Porcup~n~ ~v~ / ~chora.e. AK 99501 / prints The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. Received bv: . A. . - Al_ . Date: I Very truly yours, SCHLUMBERGER WELL SERVICES SwS-- t 327.F Raymond N. Dickes DISTRICT MANAGER CONOCO, Inc. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 PLE&'E REPLY TO FEB ! 8 1991 SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley , 3201 "C" Street, Suite 200 Anchorage, AK 99503 Gentlemen: DI E, Raw Da , Poro y, NGT, Cyberlook, Enclosed are. 2. BLprints of the. Run Company CONOCO, Inc. Attention: Van Lineberser .on: Well Milne Point Unit L-7 Field Milne Point Additionol prints ore being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope Stote Alaska 1BL prints, I RF Sepia CONOCO, Inc. 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch ?360RDW I BL nrints, 1 RF Sepia OXY U'S.A., Inc. 6 Desta Drive Midland, TX 797i0 Attn: John Carrol *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A. 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLero¥ *(713/561-365_~2~) I ,I~kL/ prints, 1RF Sepia ~aska 0il & Gas Conservation ~ .... /Commission / 3001 Porcupine D~ive [ Anchorage, AK 99501 ~ohn Boyl~../~ The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints prints prints Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SW,~-- 132T-F July 25, 1990 Telecopy~ (907)276-7542 David L. MountJoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. L-7 Revised Conoco Inc. Permit No. 90-37 Sur. Loc. 1853'FNL, 4700'FEL, Sec. 8, T13N, R10E, UM. Btmhole Loc. 780'FIqL, 1269'FWL, Sec. 4, T13N, R10E, UM. Dear Mr. Mountjoy: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated March 8, 1990, accompanying the original approved permit are in effect for this revision. Very truly yours, David W. johns~°n Commissioner. of! Alaska Oil and Gas Conservation Commission BY ORDER OF I~{E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ALASKA C AND GAS CONSERVATION CO IISSION PERMIT TO DRILL 20 AAC 25.005 DrillX~ Redrill ~_I lb. Type of welI. Exploratory F~ Stratigraphic Test ,.~_ OevelopmentOil~.~, Re-Entry - Deepen Service - Developement Gas - Single Zone '- Multiple Zone la. Type of work 2. Name of Operator CONOCO INC. 3. Address Pouch 340045, Prudhoe Bay, AK 99734 4. Location of well at surface 1853'FNL, 4700'FEL, SEC,8, T13N, R10E At top of productive interval 1120'FNL, 950'FWL, SEC.4, T13N, RIOE At total depth 780'FNL, 1269'FWL, SEC.4, T13N, RIOE 12. Distance to nearest property line 780'FNL feet 13. Distance to nearest well 60' {~,500 F/L-10 feet 5. Datum Elevation (DF or KB) KB ,53 MSL feet 6. Property Designation ADL-47434 7. Unit or property Name MILNI:' POINT UNTT 8. Well number L-7 9. Approximate spud date DECEMBER 1, 1990 14. Number of acres in property 2560 ACRES I 10. Field and Pool KUPARUK RIVER F_~ELn 11. Type Bond (see 20 AAC 25.025) BLANKET Number 8086-15- 54 Amount $20o:000 15. Proposed depth ~MD and TVD) tgos'HD: 736()'TVD* feet 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 57 0 18. Casing program size Hole Casing 30 !2 1/4 L3 3/8 9 5/8 ARC1 ST~ 8.b Specifications Weight I Grade 1 Coupling I Length 54# H-40 I.£LD I RO' 36# ~3-55 I BTRS,. TC GRA@E | | ~E 2 +~16 SqS PERMAp'R0S,T [ -IL-80/BTRS 1l[870 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)l Maximum surface 3200 psig At total depth ¢TVD) Setting Depth Top Bottom ~' I~R' IllR, I 11~,~ + SKS CLASS IG 35' 13535' 11190517360' Quantity of cement (include stage data) ..K~ CFC DDDMA~DA¢~ ?52 $K$ PERMAFROST ~Rn~ ~ CLASS G -,328 SKS CLASS G _ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) DOWNSQUEEZE trUe vertical feet 4- 403 SKS PERMAFROST C 4- 60 BBLS DEAD CRUDE Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth REEEIVED 'JUL 2 4 measured true vertical PIT SKETCH x '~ ~ '~ 20. Attachments Filing fee ~E] Property plat ~ BOP Sketch ~ Diverter Sketch X~ Drilling program X-' Drilling fluid program ~Ei Time vs depth plot [ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~~../~ Title SR. D RZLLING FOREMAN -- ' - / ~'Commission Use Only Permit Number APl number [ Appr~v¢~/~}~ See cover letter m ~O -- ~~ 50-- ©~' ~'-- Z' ~---- O ~ t~I - -9 0 for other requirements "Condit'ions of approval Samples required ,~ Yes ~No Mud log requLred .2 Yes .~ No Hydrogen sulfide.measures ~ Yes ~ No Directional survey required ~ Yes ~ No Required working pressure for BOPE ~2M' ~ 3M; .~ SM; [] 10M; L3 15M Other:~ ~~/~~"~ .~.__.~.----~ . ~¢_~~~~~_ ..... by order of Approved Commissioner the commission Form 10-401 Rev. 12-1-85 ~'"~ Date ,-./ . 7/2'//¢0 . . Submit' in t'r[p SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-7 Conoc" I. Casing and Cementing Program ao Be The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with ±500 sacks Permafrost type "C". The 9-5/8" surfaCe casing will be cemented in 2 stages with the first stage using ±752 sacks of Permafrost "E" cement followed by ±805 sacks of Class "G" cement. A DV tool will be placed at ±1900 MD. The second stage will contain ±416 sacks of Permafrost "E" cement followed'by ±90 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±328 sacks of Class "G" cement pumped- around the casing sh0e' The secondary cement job will consist of ±403 sacks of Permafrost type "C" cement followed by ±60 barrels of'Dead' Crude and/or Diesel pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program ! A. 0-500' 9.0 ppg freshwater spud mud. B. 500'-6900' 9.0 ppg-9.4 ppg freshwater spud mud. C. 6900'-10900' 9.4 ppg-10.2 ppg dispersed. D. 10900'-TD 10.2 ppg-10.4 ppg dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.5 ppg. Mud weight at TD will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8" 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is L-10 with 60' of closure at 500'. Dead Crude and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. Am Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to +4650' TVD (6897' MD) and set 9-5/8" casing. em Drill an 8-1/2" production hole t° +7360 ' TVD (11,905 ' MD) and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL 0' 0' 500' 500' 3625' 5005' 3725' 5190' 3975' 5652' 4150' 5975' 6625' 10551' 6850' 10967' 7060' 11351' 7360' 11905' Gravel 1-1-4 9.0 32 20 90 15 Sand/Clay 1-1-4 9.0 25 20 '65 15 "K" Sands 1-1-4 9.2 25 15 65 14 "M" sands 1-1-4 9.4 25 15 65 13 "N" Sands 1-1-4 9.4 25 t5 65 12 "O" Sands 1-1-4 9.4 25 15 65 12 Sea Bee 1-1-6 · 9.4 8 ' ' 12 40 10 Kup Top 1-1-6 10.4 8 12 35 5 LK1 1-1-6 10.4 8 12 35 5 'TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the.actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. T13NR9E ~RON + 2,,1 24 AOL-25514 2:560 AC CJ'~VRON ~ · CONOCO F.T Al. (~ , 10 T 13N RIOE T 13NR 11E CONOCO ET AL (~) 2 ~' 6 XOL-3'~;'~ 12es ,~c CONOCO' ET AL 11 . , 7 8 ADL-47433 2 AC L.~743 68 CONO4 CONOCO ET 13 18 - 23 24 19 2 ADL-4T437 2560 AC ADL-47438 2544 ¢0 N Oc o, 11, ell 15 2544 AC tzeo AC ADL-47434 2560 AC CHEVRON 22 ADL-25516 1280 AC MILNE POINT UNIT 4~ Denolel Itec! numbefe TO(el Area In Unit 35.744 ACfl Unit Boundary Lee,84 ~ 6/84 CONOCO ET ,AL E).. @ 21 7439 1280 AC 22 ADL.-315846 · 1280 AC 'T · EXHIBIT A MILNE POINT UNIT AREA Baled on Umlel Metldlln,Aleeke Mille 0 I 2 I Scale ~--'11 II NOTE,S: ~ I Il Il I Ill III - I 1. STATE PLANE COORDINATES ARE ZONE 4. 2, ALL GEODETIC POSITIONS ARE BA~ED ON N,A,D, 1927, OI:i::SET8 TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUE8 OF: TIlE SECTION CORNER POSTIONS. 6,10' L PAD -- ;$TA_T_E .PLANE OOORDINATE$-ZONE 4 ¥' I ..... / X _ WELL L-5 'L-7 6,© $1,343. r J 844,970:?' 6,031,41~.4' [ 548,021.3 6,031,447.6 1848,07L9' 31o' l GEODETIC POSITIONS NAD 1927 ~I ~ = WELL.... NORTH LATITUDE J WE,'J' LON~iTL~DE' '111 J 1 r-~...'..'; L-5 70' 29'48,096" J 149' $7'84.6~I" ~- ~,,. :- c.','~'; ;-;,~':' ','. ..... '" ' J 149' ~ ~:~ L-7 70'29'48.410' TYPICAL SECTION .,, ,-/~ r I ~.~ ~,. J'~ I ,SURVEYED. i::OR:C"C~O'~ PROPOSED DATE: ~et), 20, 1990 DRAWN: JSP CHE~CKED: [IELD BOOK: 'JUL :~ z, ~o WELL LOCATION8 SCALE r;2oo' JOB NO, 89009 eS ."':49~ '.. ~,~ ee e · · leee Ieee el· el,lei, l· ROBERT BELL NO. 3252-3 TIME ESTIMATE k. Be Ce Do E . F. Ge He J . K. Description Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L.D. Run Production Casing Cement Production Casing Clean Pits, N/D BOP, N/U Tree Move Rig. Hours 80 36 101 36 20 16 10 12 24 Cum Days 0.33 3.66 5.16 5.49 9.69 11.19 12.02 12.69 13.11 13.61 14.61 TOTAL 14.61 -1 -2 -3 -4 -5 -6 -7 -8 -9 10 11 MILNE POINT'-~JNIT WELL - /_.- ~x Rate vs. Depth. 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 . -- RIG DAYS CONOCO, [no. Ped L, Well Not 7 Revised Proposal HIIne Point Unl~, North Slope, Aleske 0 _ RIC~ ELEVATION, I'1'1 1000_ 2000 _ ~o0o _ 4000 _ sooo _ 6000 _ 7000 _ 8000 KOP TVD-500 TMD=500 DEP'=O $ I0 BUILD 2.5 DEO 20 PER ! O0 FT 25 30 SS EOB TVD-2427 TMD-2790 DEP=1052 9 5/8' CSG PT TVD-4650 TMD=6897 DEP=4506 AVERAGE ANGLE 57 DEG 14 HI N TARGET / LKI TVD=7060 THD=I1551 DEP=8251 TD / 7= LINER TVD-7360 THD=IIg05 DEP=8717 i 1 000 I 2000 I i I I i 1 3000 4000 5000 6000 7000 8000 VERTICAL SECT[ON i 9000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET CONOCO. Inc. Pad L. Well No, Z Revised Proposal MIIne Point Unit. NoPth Slope. Alaska 7000 6000 _ 5000 4000 - 3000 - 2000 _ 1000 0 1000 J WEST-EAST 000 0 1 000 2000 3000 4000 5000 6000 I I I I I I I TD LI:X~ATI ON t Z80' FNL, 1269' FW1. SEC. 4, 'rl3N, RIOE · · TAROET / LKI TVD=7~O / TMD-! 1351 DEP=0251 · NORTH 6013 /' E^s, ~5o TARG'ET LOCATION~ · 1120' FNL..950' FWL . · ' / ' . . · SEC. x/ N 4,3DE(~ 1,3HI NE SURFACE SEC. 8. TI3N, RIOE 1400 _ 15OO 1800 _ 1700 1800 1900 2000 21 O0 2200 100 0 100 200 300 400 500 600 ?00 800 21 O0 1900 17'00 ~1 O0 SOO 2300 \ \ \ *1 O0 2'~R~7oo ® 1 go0 1700 500 I t ~ I / / \ / ~ 31 o0 ~ 3700 \ / \ / \ / \ / ~ 2900 / \ 7' 3500 \ / \ / "",~ ,500 1 2700 / x \ ~' 3300 / / %1 313,0 / / 1 500 ". ~,~oo \ ,/ 1,2300 / 31oo ~' 1300 t $00 / 7" 2900 / 1 lOO 21oo · ~ 900 300 O0 1300 0 0 J 5300 I / 630° soo9°° I /' 87~ / / / / il700 900 1700 0 500 0 I I I I 100 0 100 200 300 400 500 600 700 800 900 I, I 2300 I I 900 _ 1400 .1500 .1600 1700 1800 1900 2000 _ 21 O0 2200 CONOCO INC,--NABORS RIO 27E, 13-5/8" 58888 Fill Line Ali 13--5e~3' 5~ AFl 13-~v~ 51~ AFl 13-~v~ ~E F low Llne Annular'Preventer R~m Ram API 13-5/8" 5~1 x il' ~l Tubing Spool w/ 2"-5000~t Side APl 11' 5M Casing Spool w/ 3"-5000~ Side T~ed Co~cf~n 9-5/8" SurFace C'hoke Ltne~ 3" 5000~ Manual -' & 3" HOR VALVE KILL Line: Two 3" 5000~ Manual VaLves" Outlets Outlets Casing 13-3/8" ConductOr- Casing BOP Gate SYSTEH Vatve Oate l, BOP STACK SIZE RATING MEETS APl RP53 & SPEC 6A FOR CLASS 5.M 2, DOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL MANIFOLD LOCATED REMOTE WITH 160 OALLON ACCUMULATOR, RESERVOIR UNIT, & AUXILIARY ENERO¥ SOURCE FOR SYSTEM ACTIVATION, ~r, MINIMUM ONE SET BLIND RAMS & TWO SETS APPROPRIATE PIPE RAMS, 5, CHOKE & KILL MANIFOLDS SHOWN SEPARATELY TO MEET APl R.P 53 CLASS 5M REOU]REMENTS, ~ FRSU PIJ~P KILL B/I'glFOLD FROU REUOTE HIGH ~ I~~ ~, R&~OTE PRr~°''~ PRESSURE PU~P ~ ~j ~ .oou.[ v~uc NOTE: ~ ~JS[I~LIC CONTROLLED ~NT~L TO BE ~[D ON RiG fLOOR. . CHOKE ADJU~AB~ ~ ~ ~ ~ ~ ~ ~ AD~U~AB~ UANIFOLD . BLeD LI~E TO ATMOSPHERIC TO PIT ~UD/GAS SEPARATOR . - CHOKE 8 KILL MANIFOLDS FOR ~s/Se 8 7" OD CASING BOP STACK 80P L{ANIFOLD LAYOUT- CONO~, INC. ..... : - ~ m -,_ .... CONOCO, INC. IdlLN[ POINT UNIT DIVERTER STACK FOR 13 318' CONDUCTOR STARTIkO ~q[JLD 1. The hydraulic control syste~ will b~ in accordance wi'th PPI specifications and ~ ~equi~e~en%s. e. The HCR valve will open ~hen the pp~ventep closes. A single . IO" relief line ~ill run off of the drilling spool HCR valve and ~ill have a ta~-qeted do~rnstream tee fop downwind dive.ion. Valves on ~th sides of the t~ ~tll ~ full opening a~ linked togethep to enable one to al~ays be o~n a~ the othep to ~ closed. FJiOM $~t 4~dA~C[~ IdUO Tdl~# NOel I~LL · P~ I March 8, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco Inc Pouch 340045 Prudhoe Bay, AK 99734 Re: Milne Pt Unit L-7 Conoco Inc Permit ~ 90-37 Surf Loc 470'FWL, 2023'FNL, Sec 8, T13N, R10E, UM Btmhole Loc 1276'FWL, 770'FNL, Sec 4, T13N, R10E, UM Dear Mr Rainwater~ 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ru%y~ye-urs,~ C~VChatterton Chai~n Alaska Oil and Gas Conservagion Commission BY ORDER OF THE COMMISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA'-'"L AND GAS CONSERVATION C'-"IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill :RI Redrill d of well. Exploratory [] Stratigraphic Test [] Development Oil-~"'~.~ Re-Entry [] Deepen~1 ServicerS, Developement Gas [] Single Zone"~ Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Conoco ]:nc. 56' MSL feet , 31 Address 6. Property Designation Kuparuk River ~-ie-lxt- P.O. Box 340045, Prudhoe Bay, AK 99734 ADL-47434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 470'FWL,2023'FNL,Sec 8,T13N,R10E, UM Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 950'FWL, ll20'FNL,Sec 4,T13N,R10E, UM L-7 8086-15-54 At total depth 9. Approximate spud date Amount 1276'FWL,770'FNL,Sec 4,T13N,R10E, UM April 11, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 12 084'MD, *7360'TVD 700 feet 60' @ Surface feet 2560 ac ' feet 16. To be completed for deviated wells 17. Anticipated pressure (se,~ 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 58 0 Maximum surface 3200 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size .Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 13-3/8" 48#/F~ H-40 Weld 80' 35' 35' 115' 115' 485sks Permafrost C 12-1/4" 9-5/8" 36#/Ft J-55 BTRS 6942' 35' 35' 6977' 4650' First Stage: 886sks I~¢~-~ Perm~frost E and 5,' D ski Class G, Second StagE: 564~ks Permafrost E & 84sks Class 8-1/2" 7" 26#/Fi 1,-80 BTRS 12049' 35' 35' 12084 73607 First Stage: 346sk.s C1 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~15 Second Stab;e: 18Oaks Permafrost C and Present well condition summary bbls Dead 0il/Diesel 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 (~t~; tu%rta~, RECEIVED Surface Intermediate - 5 !990 Production Alaska Oil & Gas Cons. CommiSsiOB Liner Anchorage Perforation depth: measured true vertical Pit Sketch X 20. Attachments Filing fee .~ Property plat [] BOp Sketch [] Diverter Sketch [] Drilling program ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report f~ 20 AAC 25.050 requirements [] 21. I hereby certify that~b.e foregoing is true and correct to the best oi my knowledge Signed ~/~/. ~ /C~>;~..,.~;, C --~ Title Senior Production Foreman Date~. Commission Use Only Permit Number I APl number I Approval date ! See cover letter ~'~-,.~7 ] 50--o-~9- 2202.¢ 103/08/90 /for°therrequirements Condition' 's'of approval Saml~les reqq. ired [] Yes ~R'No Mud log required Lq Yes ~ No HIT required/,~/ Hydrogen sulfide measures [] Yes ~No Directiona, I survey required "~ Yes [] No Call for' rep - Required working pr~e for B~PE' J~M; [] 3M; ~ 5M; [] 10M; [] 15M Other: ~ /"~//U--J~-,~ to wi tness. ~ - by order of ~// Approved by L___/~ _~ L ~'~ Commissioner the commission Date ~/~?...~,~7 Form 10-401 Rev. 12-1-85 'iplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-7 Conoco Inc. P.O. Box 340045 Prudhoe Bay, AK 99734 I. Casing and Cementing Program A. The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +480 sacks Permafrost type "C". Be The 9-5/8" surface casing will be cemented in 2 stages with the first stage using +886 sacks of Permafrost "E" cement followed by +_520 sacks of Class "G" cement. A DV tool will be placed at +1883'MD. The second stage will contain +564 sacks of Permafrost "E" cement followed by +84 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of +346 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of+--- sacks of Permafrost type "C" cement followed by +60 barrels of Dead Crude and/or Diesel pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program A. Be Ce 0-500' 9.0 ppg freshwater spud mud. R~CEIVE~) 500'-'6980 9.0 ppg-9.8 ppg freshwater spud mud. 6980'-10,563' 9.0 ppg-9.5 ppg dispersed, t~iaskaO#&,-,, o- ]0,563'-TD 10.2 ppg-lO.4 ppg dispersed. Anchorage III. Drilling Program ~ Conoco Inc. proposes drilling the subject well as a~'~~vell in the KuparukRiverField. The mud system will be low solid~ispersedwith a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.2 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. Maximumdownhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is L-5 with 60' of closure at surface. Dead Crude and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drill ing rig. A. Drill a 30" conductor hole to +80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to +4650' TVD (6977' MD) and set 9-5/8" casing. C. Drill an 8-1/2" production hole to 7360'TVD (12,084' MD) and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' O' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3632' 4936' "K" Sands 1-1-4 9.2 25 15 65 14 3721' 5104' "M" Sands 1-1-4 9.4 25 15 65 13 3977' 5587' "N" Sands 1-1-4 9.4 25 15 65 12 4149' 5912' "0" Sands 1-1-4 9.4 25 15 65 12 6614' 10563' Sea Bee 1-1-4 10.2 8 12 40 10 6836' 10982' Kup Top 1-1-6 10.2 8 12 35 5 7060' 11405' L K (1) 1-1-6 10.2 8 12 35 5 7079' 11441' L K (2) 1-1-6 10.2 8 12 35 5 7260' 11782' B L K 1-1-6 10.4 6 12 35 5 7360' 11971' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. RECEIVED MAR - 5 !gq0 Alaska Oil & Gas Cons. Coremissi°~'~ Anchorage CONOCO, Ino. Ped L, Well Not 7 Revised Proposel HIIne Point Unit, North Slope. 0 - RKB ELEVATIONt 29' rtl 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000 _ KOP 10 TVD=500 TMD=500 DEP=O 25 30 35 40 45 50 55 EOB BUILD 2.5 OEO PER 100 FT TVD=2442 TMD=2818 DEP=1076 9 5/8' CSG PT TVD=4650 TMD=6977 DEP=4601 AVERAGE ANGLE 57 DEG 57 HI N RECEIVED MAR - 5 l~n .OJJ & Gas Cons. C;ommlssio~ Anchorage TARGET / LK-1 TVD=7060 TMD=ll518 DEP=8450 TD / 7" LINER TVD=7360 THD'-12084 DEP-8929 ! 1000 2000 I I I I I ! 3000 4000 5000 6000 7000 8000 VERTICAL SECTION i 9000 ,ORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET CONOCO, Inc. Ped L. Well Not T Revleed Propoeel MIIne Poln~ Unit, North Slope. AleeEa z 0 --I I o 7000 6000 _ 5000 _ 4000 _ 3000 _ 2000 1000 _ O _ 1000 1000 0 1000 2000 SURFACE I I ! WEST-EAST 3000 I 4000 5000 6000 I I I TARGET / LK-I TVD=?O60 THD=ll$18 DEP-8450 NORTH 6183 EAST 5759 TARGET LOCATION~ 1120' FNL, 950' FWL SEC. 4. T13N. RIOE TD LOCATION, 769' FNL0 1277' FWL SEC. 4. TI3N. RIOE N 42 DEG 58 HIN E 8450' (TO TARGET) SURFACE LOCATION, 2023' FHL. 471' FWL SEC. 8. T13N. RIOE RECEIVED MAR - 5 ]990 AJaska Oil & Gas Cons. CommissioP Anchorage, 70O0 I 1 50 200 250 :~00 550 !400 .J. 450 _.Z500 550 ~ __ 1650 J,~oo""L_ ........... , 1850 j ~ 1 900 Jj ~oo 1050 ~ ~~ ,oo ~~ soo s°° co 5 ~ /~ , ~ Jj .~ o 200 Jl / I 13oo/ / ooo X,,oo X o 5500 ,_ ~ / / ~n ~o~o ~[-..~:~:: %00. ~oo ~ j ~~oo .. 5oo 2 1 O0 ~ ~ ~ 1 co MAR - ~ ]9gO ' I I 2100 4 /6300 /~00 --' ~ · · ~ J J j / · soo A~aska 0~1 & Sas Cons. Commissio~ 2150 -- ~- /' 450 500 550 150 200 250 500 550 400 NOTES: STATE PLANE COORDINATES ARE ZONE 4. 2, ALL GEODETIC POSITIONS ARE BASED ON 'N.A.D. 1927, OI::FSET$ TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALU~S OF TIlE SECTION CORNER POSTtON& I 6~O' VVV ' ,,i I Pit · , L PAD MILN~ POINT UNIT ~OW'YDY~ BAY J M ILNE PT. VICINITY MAP MILEB LOCATION IN SEC, 8, T13N, R1OE, UMIAT MERIDIAN ~ · J WELL J r~OM NO,TH L,NE mOM WEST UNE_ L~4' J~oS~'- .... ~' " L-5 J20$6' 420' L--? J2023' 470,~' STATE PLANE COORDINATES-ZONE 4 l .... x L-4 l ~,,-6~,~e~:r 544,970.7' L-5 6,O31,41§,4' 548,O21,3 L-7 0,0~1,44~.~, ~4~,O7~,9' GEODETIC POSITION8 NAD 1927 ~.J...,.._..-_.._ WELL L-7 NORTH LATITUD&: 70' 29'47,782' 70' 29'48,O96" 70* 29'48.410' WEST LONGITUDE 149' 37'~S& 147' 149' 87'~4.~1' TYPICAL _~ECTION NO SCALE -- ~AR -5 1990 Alas~a_0il &~Gas Cons. 8U~EYED I:~R:r~~O) '- - ..... : ' "~ PROPOSED WE~ g~AWN: CHECKED: FIELD BOOK: ......... ~- , ~ ~CALB 1',200' JOB NO, 8900~ T 13NR 9 E T 13 N R 10 E T 13 NR 11 E MILNE POIN' II ~ Ill .~ ~ II III I II I I CHEVRON~ CONOCO ET AL ~) CONOCO ET AL ~) CONOCO ET AL ~ (~ Denote. t,act n ADL-31971Z ,~ 265..AC. coNoc~ ET AL ~-255~ 25~C ADL'47434 2560 AC ADL'47433 ~60 AC~.~D~743~68 A~ X r [ I"' ' I ,, , ,, ==o c.=v.o. + + _,- 23 24 le 20 21 22 23 24 21 22 ~oL-31584e ADL-25516 ADL-47439 ADL-3158d ~-25574 25e0 &C ADL-25515 2~4 AC 12eo AC 1280 AC ADL-47431 256O AC ADL-47438_.~ 1280 AC 12 II I I ' '"' " iii I ~"°" ~ ~~xo" ~ ~ c,Ev.o. A.c°-~xxo. ~ ,, ~ 30 2g 2a 27 2e 2S 30 2g E Ex~ ~ c~ Mllel 0 ~ ~ ~ 2235AC 2 :ADL-25~ 25~OAC ADL-25510 2560 AC ADL-26231 2555 AC ~ ~ , · ~ - II ~11 I II IIII I ~1' I III I II numbefa 35,744 Acrel 8/84 SOHIO BP&flCO CHE¥. 'UNIT ,IBIT A UNIT AREA t Merldlan,Alalks 1 2 Scala WELL L-7 TIME ESTIMATE. Hours Days Cum. Days A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 110 4.50 4.91 C. Run Surface Casing and Cement 36 1.50 6.41 D. Drill Out and Test 8 0.33 6.74 E. Drill Production Hole 141 5.88 12.62 F. Log Open Hole 36 1.50 14.12 G. Condition, POOH, L.D. 20 0.83 14.95 H. Run ProductioN Casing I. Cement Production Casing J. Run Cased Hole Logs & Perf 16 0.67 15.62 · . 10 0.42 16.04 36 1.50 17.54 K. Run Completion EQ 12 0.50 18.04 L. Move Rig 8 0.33 18.37 TOTALS 416 18.37 18.37 RECEIVED ~liaska 0il & Sas Coas. Commission' Anchorage W~ QO -1 MILNE POINT UNIT WELL L-7 Rate v$.depth -2 -5 -5 -6 -7 -8 0.00 2.00 4.00 6.00 ,'~ 8'00 10.00 12.00 14.00 16.00 18.00 · .RIO DAYS CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318' CONDUCTOR OIYERTER OUICK CONN£CT &SS[MILT RECEIVED I. The hydraulic control syste~ will be in accordance with API specifications and ADGCC requirements. 2. The HCR valve will open when the preventer closes. A single ' ~0" ~'e]~e~ ]~ne Nil! pun o~ of the drilling spoo! HCR and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening arx~ linked together to enable one to always be open and the other to be closed. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING APl $000 B.O.P. stack size rating meets APl RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. .-. t~ ...... ,,- mow ' (2) BOP£ to be ~ operated on each ~; trip & pressure ~- ~ ,~' ~P, ~ooo~ tested weekly e . . ~ .: .~ (3) Mydraultc control ~7~t~ for BOPE to include (5) ~ ~ ~ .... ~ ~%' IP~ ~ooo~ station control _ ~ _ ~antfold located remote with 160 ~. mo~ gallon accumulator and reservo{r un{t ,~%' aP~ ~ooo~ . '.' ~ }ooo and auxtltar7 ~ y '=:-~ energy source for · ,, ~ooo'I~',~'..~. '~:~il~' ~mG ~ system activation. OUTLETS u ~~~ ~ (~) Ram type ~0~ to '/Ir ~, ,' Ie, ~ooo' include a mtntmu~ ~ ~ of one set of ~ ~1 blind rams and two ~OOO~ OUTL(TS ~ ~ [SPOOL SR[S of appropriate pipe ' a · ~ ' · ~S. Threaded :'~ ' ~' ." (5) Choke and kill Connection ~ - ' ~ ~ .'' * .' manifolds ~ho~ ~ I I ~' : t~separatel7 to meet 9_~/8"c~o~- . . I i Il.., L/ ='. '' ~ ; ' . '". ,'-" '.,..' "Ii ~ , . . t~A~ -51S~O ; ;. '. .~."" ,.. .' .' ;.. ~. II -~ / ' alaska Oil & aas cons. Commissior~ .-Anchorage TROUGH HOLE luuOwx PuU~ NABORS DI~iLLC'~ L~,/'3TEF.., AL~E&TA 'l 0 R T H I PAD L SECTION Ii, TI3N, RIOE, AS-BUILT UMIAT tAEI~IDIAN CE~TtFICflTE VIC_ h_NITX. _~AP -- RECEIVED LOCATION IN SECTION : FROM NORTH LINE : FROM WESTLINE WELL .;. m i ~STO' .: I se' · STATE PLANE .COORDINATES · .......... :~, .... ?.......,...,,...o,,,....,~.,..,,.,...,.....o..., ..... WELL i NORTHiNGS ,I EASTING$ I : 6,031 .499.2 :. ·, 544, 758.7 : : . · : : z ONE · GEODETIC POSITIONS REGISTERED AND LICENSED TO PRACTIC - -URVEYING IN THE STATE OF ~L~S~ ~-- - ~ ~ a '~ ~ ED FOR: CONOC '~ ' ~ ~ D~TE 7-24-84 .................... )1 3340 4,c~/c Bou/eva,d, Su,'te 201, Anchorage, AlasAa ~9503 S~LE I" : 200' DEC~6 ............ ; ............................... ~ ............................. .. I .; 70° 29' 49' : 149° 38' 02" ,, ~aska 011 & Gas Corm. Oommlsslo, i , .~ch0rage i : i ! ; ; I CHECK LIST FOR NEW WELL PER, fITS Company . ~)z ~.~ ~-~. ........ Lease & Well No. //z~ IT~ 32PROVE DATE YES NO _ (1) Fe__~e .M~/°~ 7/¢~/~ 1. Is the perm.it fee attached .......................................... ~ . -- (2 ~hru 8) 2, (8) (3) Admin/__~ ~ 9. (9 thru 13)' 10. (10 and 13) 12. 13. (~ ~ t~ru z~_) (23 thru 28) '(29 thru 32) (6) Add: Z- ¥-Fo Geoiogy: Engineering: DWJ ~ LCS BEW rev: 01/30/89 6.011. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 30. 31. 32. Is well to' be located in a defined pool ............................. Is well located proper distance from proper=y line .................. Is wel! located proper distance from other wells ........ ~ ........... Is sufficient undedicated acreage available in this pool ............ Is we!! to be deviated and is we!lbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is admimistrative approval needed ................................... ~ Is the lease number appropriate .................................... ~_ Does the well have a unique name an~ number Is cdnductor string provided ........................................ Wi!l surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... ,.~ Will cement tie in surface and intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ezisting wel!bore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate ~, Are necessary diagrsms and descriptions of dive:tar and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ~'d~O psig .. .~ . Does the choke maaifold comply w/API RP-53 (May 84) .................. ~ Is the presence of H2S gas probable ............................. ~... ,~ exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO. SHORE ¢o o,cg Additional Remarks: CHECK LIST FOR NEW WELL PERMITS ITEM (1) Fee (2) Loc APPROVE DATE (8) (10 and 13)- (4) Casg'~~,~, ,~--~--~'~ (14 thru 22) Company 1. Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... (5) BOPE (23 thru 28) e 10. 11. 12. 13. 14. 15. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease & Well YES NO Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~"~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29- thri, 31') (6) Add: Geology: DWJ ~ Engi,neerin$: ..... rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE