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Home My WebLink About209-0377. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-28B Tbg Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-037 50-029-21770-02-00 13782 Surface Intermediate Liner Liner Liner 9020 3257 10532 714 1501 2279 12445 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8994 26 - 3283 23 - 10555 9847 - 10561 10395 - 11896 11500 - 13779 26 - 2989 23 - 8376 7932 - 8379 8300 - 8994 8823 - 9019 none 1950 4760 5410 7500 13890 12445 3450 6870 7240 8430 13450 10570 - 13540 4-1/2" 12.6# L-80 21 - 10294 8383 - 8995 Conductor 80 20" 27 - 107 27 - 107 1490 470 4-1/2" HAL TNT , 9736 , 7845 8273 9736 7845 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 , 028306 21 - 8243 477 285 32133 13147 11 21 0 0 1095 798 323-134 13b. Pools active after work:PRUDHOE OIL No SSSV 10346 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations / By Grace Christianson at 9:24 am, Aug 26, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.08.23 19:53:08 - 08'00' Bo York (1248) WCB 11-6-2024 DSR-8/26/24 ACTIVITYDATE SUMMARY 7/12/2024 ***WELL S/I ON ARRIVAL*** TAGGED WRP w/ 3.80" BARBELL & 3.70" LIB @ 10,367' MD (good impression of shear stud) PULLED WRP FROM 10,367' MD (COVERED IN PARAFIN). RAN 4 1/2" BRUSH, AND 3.78" GAUGE RING TO 10,372' MD. ***WSR CONTINUED ON 7-13-24*** 7/13/2024 T/I/O = 137/30/3, LRS Unit 70, Assist Slickline with CMIT(RWO EXPENSE) Perform CMIT-TxIA ***Job Continued to 7-14-24*** CMIT-TxIA - Pumped 17.3 bbls into TBG to achieve MAP of 3000 psi. 3002/2985/4 7/13/2024 ***WSR CONTINUED FROM 7-12-24*** SET 4 1/2" EVOTRIEVE PLUG @ 10,367' MD SET 4 1/2" WHIDDON ON EVO-TRIEVE. PULLED RK-DGLV FROM ST#3 @ 9,743' MD MADE 2 ATTEMPTS TO SET RK-DGLV IN ST#2 @ 7,408' MD (dropped valve) PULLED RK-DGLV FROM CATCHER w/ 2-1/2" GUTTED JD MADE 2 MORE FAILED ATTEMPTS @ SETTING ST#2 SET RK-DGLV IN ST#2 @ 7,408' MD. LOGGED W/ 40 ARM CALIPER FROM 10,340' SLM TO SURFACE. ***CONTINUED ON 7-14-24*** 7/14/2024 ***WSR CONTINUED FROM 7-13-24*** LRS TO CMIT 3000 PSI (PASSED). ***WELL S/I ON DEPARTURE*** 7/14/2024 ***Continue Job from 7-13-24*** LRS Unit 70, Assist Slickline with CMIT (RWO EXPENSE) SL in control of well and DSO notified upon LRS departure. CMIT-TxIA - Pumped 17.3 bbls into TBG to achieve MAP of 3000 psi. 3002/2985/4. TBG/IA lost 86/88 psi 1st 15 min, lost 38/38 2nd 15 min. 2878/2859/6. CMIT-TxIA = PASSED. Bled back12.94 bbls. 160/139/4 7/19/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE WELLTEC TBG CUT RIG UP YJ ELINE. RIH W/ WELLTEC 3 1/8" MECHANICAL CUTTER CUT 4 1/2" TBG @ 10300' MID OF THE FULL JOINT ABOVE PKR PRE CUT T/I/O/200/200/0PSI, POST CUT T/I/O/= 200/200/0 PT PCE 300 PSI LOW / 3000 PSI HIGH RIH CH/ 3 1/8" WELLTEC CUTTER TO 10300' AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 4.7" RDMO YELLOWJACKET ELINE JOB COMPLETE ***WELL S/I ON DEPARTURE**** 7/21/2024 Circ Out (RWO EXPENSE) Pumped 50 bbls deep clean followed by 120 bbls 1% KCL down Tbg, Up IA taking returns down 07-29 FL. Soak for 1 hour. Pumped an additional 1300 bbls 1% KCL and 140 bbls DSL down Tbg, up IA taking returns to FL of 07-29. U-Tube DSL into IA for 1 hour. Bled Tbg/IA to 0 psi. Pad op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG Daily Report of Well Operations PBU 07-28B CUT 4 1/2" TBG @ 10300' MID OF THE FULL JOINT ABOVE PKR RIH CH/ 3 1/8" WELLTEC CUTTER TO 10300' AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 4.7" RDMO YELLOW JACKET ELINE Daily Report of Well Operations PBU 07-28B 7/22/2024 T/I/O = VAC/VAC/20. Temp = SI. Bleed WHPs to 0 (pre-RWO) Bleed C & B lines to 0. No AL. OA FL near surface. Bled OAP to BT to 0 psi in < 5 min (gas). Monitored for 30 min. OAP unchanged. Bled (burp) Control Line from 100 psi to 0 psi (gas & fluid) in 1 hr. Monitored for 30 min. CLP unchanged. Bled (burp) Balance line from 400 psi to 0 psi (gas/fluid) in 1hr 30 min. Monitor for 30 min. BLP unchanged. Final WHPs = VAC/VAC/0 SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 13:00 8/2/2024 PJSM w/ Well Support. Check for pressure on (2) control lines, at 0. N/D control line termination flanges and disconnect. Pump open SSV and check for pressure on tree, on vac. RIH w/ dry rod and set 4" ISA plug. Close swab valve. Check for pressure on THA void, at 0. Break flange loose. R/U and pull tree. Clean void, inspect TBG HGR neck and lift threads. SBMS stayed in THA. Terminate (2) 1/4" control lines. Remove seal from TBG HGR landing sub and dry run (5 1/2 left hand turns to M/U) Remove landing sub, remove seal from blanking sub and dry run (5 1/2 left hand turns to M/U) pull blanking sub, install seal and reinstall on TBG HGR. Install new R54. N/U BOP oriented as per ASR tool pusher. Top of FLG to top of TBG HGR neck: 10" Top of FLG to top of blanking plug: 15" LDS out: 4 1/2" 8/2/2024 T/I/O=BPV/0/0. Per ASR request, installed 2" FMC VR Plug. Removed Comp IA. Installed Blind with Alemite fitting. ***Job Complete*** FWP = BPV/0/0 8/4/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. Continue RDMO from MPS-17: Move ASR to tent for servicing. Load catwalk, pipe sheds on truck and transport to DS07. Lift spools, spacers, etc from rig floor. Lift floor from cellar. Lift cellar. Load mudboat on truck and secure. ND BOP, NU production tree. Test void - good. Pull BPV. Disassemble BOP for service in DH. Load Cellar and Rig Floor on trucks and secure, send to DS07. Loadout Pits to DS07. Mobilize rig crews and ASR-1 from MPU to DS07. Set rig mats. Spot in mudboat, pits. Level and secure pits. Spot in Koomey hose coffin. Lift cellar and level. Lift rig floor, riser spools, slips, and elevators. Install Koomey hoses, communications, and electrical lines. Spot ASR-1 in on mudboat. Layout all equipment to raise mast. ***CONT WSR ON 08/05/2024*** 8/5/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. Continue RU ASR-1. Test ESD - good. Accept rig 10:00 8/5/2024. Test Blind and Pipe Rams 250/5000psi F/ 5/5min (good) Test all other equipment 250/3000psi F/ 5/5min. AOGCC witness waived. 2hrs downtime for rig coolant hose rupture replacement. RU sheave and handling equipment. Ops. check MP#2. ***CONT WSR ON 08/06/2024*** 8/6/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. Pull blanking plug and BPV. BOLDS. Unseat Hanger at 117.76K, pull free 111.1K. PUH below Annular and close. Reverse circulate 1% KCl taking returns to Tiger Tank, 122bbls total. FWD circulate 1% KCl taking returns to Tiger Tank, 227bbls total. POOH w/ 4-1/2",12.6#,L, IBT-M completion w/ dual control lines maintaining 1x displacement T/ 8,113' - PUW 93k. Dual C/L wrapped around and under SVLN. Cut free and dispose of. All C/L recovered (not parted) Missing 7 of 55 SS Bands. Continue POOH T/ 4,396' - PUW 51k. ***CONT WSR ON 08/07/2024*** Test Blind andgg Pipe Rams 250/5000psi F/ 5/5min (good) Test all other equipment 250/3000psi F/ 5/5min. AOGCC witness waived. g Pull blanking plug and BPV. BOLDS. Unseat Hanger at 117.76K, pull free 111.1K.gg g PUH below Annular and close. Reverse circulate 1% KCl taking returns to Tigergg Tank, 122bbls total. FWD circulate 1% KCl taking returns to Tiger Tank, 227bbls total. POOH w/ 4-1/2",12.6#,L, IBT-M completion w/ dual control lines maintaining 1x displacement Daily Report of Well Operations PBU 07-28B 8/6/2024 M/U Blanking plug R/R tool, RIH, pull blanking plug RIH w/ T-bar, off seat poppet in ISA plug...no pressure RIH w/ T-bar, pull ISA plug M/U TBG HGR landing sub, RIH, make up to TBG HGR. BOLDS Off seat TBG HGR S/B for rig to circulate 8/7/2024 ***ASR RIG ASSISST*** MADE 2 RUNS w/ 5.5" JUNK BASKET W/ 8.525" RING TO 9-5/8" x7" XO @ 9,847' MD, RECOVERED 4 CONTROL LINE BANDS MADE 2 RUNS w/ 5.5" JUNK BASKET w/ 5.98" RING TO TBG CUT @ 10,300' MD. RECOVERED 3 LAST MISSING BANDS. *** JOB COMPLETE*** 8/7/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. Continue POOH w/ 4-1/2",12.6#,L, IBT-M completion maintaining 1x displacement F/ 4,396' to clean TBG cut (4.93' OAL). Slickline recovered 7 SS Bands w/ 9-5/8" and 7" Junk Baskets. Recovered scale from 7" Liner - 3 cups. RU GB&R Torque-turn equipment. Drift Overshot w/ TBG cut - good. Re-Level rig. RIH w/ 4-1/2",12.6#,13Cr-80, VamTop R3 completion as per approved tally T/ 817' - SOW 8.5k. ***CONT WSR ON 08/08/2024*** 8/8/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. Continue RIH w/ 4-1/2",12.6#,13Cr-80, VamTop R3 completion as per approved tally F/ 817' to TBG stub at 10,300'. Shear Overshot, install space-out pups, and hanger. Close Annular, reverse circulate 550 BBLS - 1% KCl w/ CI. FWD circulate 5 BBLS to clean RHC-M seat. Vac out BOP stack. Final PUW - 120k, SOW - 72k. Land hanger placing Overshot 10,308' MD or 5.52' off no-go. RILDS. RD fluid lines. Drop B&R (1- 3/8" F.Neck, 2.00" WHLS, 1-7/8" Ball, 9' OAL) and shut Bilnd Rams. Bring TBG pressure up to ~2,000psi and Packer set, continue up to 3,500psi. MIT-T - Pass. ***CONT WSR ON 08/09/2024*** 8/9/2024 RWO Scope: Pull existing 4-1/2" L-80 TBG. Run new 4-1/2" 13Cr Completion. MIT-T Passed, see WSR from 08/08/2024. Bleed TBG to 2,000psi. MIT-IA - Pass. (see data tab) Bleed TBG pressure and shear valve in upper GLM. LRS reverse circulate 140 BBLS DSL taking returns to Tiger Tank. Install BPV. RD ASR-1. ***Release rig 06:00 8/9/2024 - END WSR*** 8/9/2024 Make up tubing hanger to tubing string, RIH, land on RKB, run in lock down screws, stand by for set packer, test tubing & IA, etc., set CIW 4" H TWC, stand by for rig move, nipple down BOP/nipple up tree. 8/9/2024 BOP removed, clean void, ring groove, hanger neck, & BPV profile, install new SBMS in hanger neck, install new RX-54 ,fill void w/ hydraulic fluid, make up THA to tubing head, stand by for well support to torque, test tubing hanger void 500 psi/5 min., 0 psi loss, test 5000 psi./30 min., lost 175 psi first half, lost 0 psi second half, bleed off test psi, monitor SBMS while well support tests tree, no leak, pull TWC w/ T-bar, RDMO Make up tubing hanger to tubing string, RIH, land on RKB, run in lock down screws, Bleed TBG pressure and shear valve in upper GLM g Continue POOH w/ 4-1/2",12.6#,L, IBT-M completion maintaining 1x displacement F/g 4,396' to clean TBG cut (4.93' OAL). Slickline recovered 7 SS Bands w/ 9-5/8" and 7"() Junk Baskets. Recovered scale from 7" Liner - 3 cups. RU GB&R Torque-turn equipment. Drift Overshot w/ TBG cut - good. g Continue RIH w/ 4-1/2",12.6#,13Cr-80, VamTop R3 completion as per approved tallyy F/ 817' to TBG stub at 10,300'. Shear Overshot, install space-out pups, and hanger.g Close Annular, reverse circulate 550 BBLS - 1% KCl w/ CI. FWD circulate 5 BBLS to clean RHC-M seat. Vac out BOP stack. Final PUW - 120k, SOW - 72k. Land hangerg placing Overshot 10,308' MD or 5.52' off no-go. RILDS. RD fluid lines. Drop B&R (1-gg 3/8" F.Neck, 2.00" WHLS, 1-7/8" Ball, 9' OAL) and shut Bilnd Rams. Bring TBG)g pressure up to ~2,000psi and Packer set, continue up to 3,500psi. MIT-T - Pass. Bleed TBG to 2,000psi. MIT-IA - Pass Daily Report of Well Operations PBU 07-28B 8/10/2024 ***WELL S/I ON ARRIVAL*** PULLL B&R FROM 9746' SLM. PULLED RK-DGLV FROM STA# 3 @ 6708' MD. PULLED RK-SOV FROM STA# 4 @ 3826' MD. SET RK-LGLV IN STA# 4 @ 3826' MD. SET RK-OGLV IN STA# 3 @ 6708' MD. 8/11/2024 ***CONTINUED FROM 8-10-24*** RAN 2.5" PUMP BAILER TO CATCHER @ 10,343' SLM PULLED 4-1/2" WHIDDON FROM EVO EQUALIZE AND PULL EVO FROM 10,367' MD DRIFT w/ 3.802" CENT TO 45 KB PKR @ 10,372' MD DRIFT w/ 2.20" CENT, 1-3/4" SAMPLE BAILER TO DEVIATION @ 11,862' SLM ***WELL S/I ON DEPARTURE*** 8/11/2024 T/I/O=TWC/174/0. POST ASR RIG ,TREE TORQED TO SPEC PT TO 5000 PSI. PASS PULL 4" TWC @125", TWC LTT Passed. PT tree cap to 500 psi. Pass. ***Job Complete*** See Log. Final WHP's V/174/0 8/13/2024 Passed witnessed State Test. PULLL B&R FROM 9746' SLM EQUALIZE AND PULL EVO FROM 10,367' MD New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 PBU 07-28B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-037 50-029-21770-02-00 ADL 0028309 , 028306 13782 9020 3257 10532 714 1501 2279 10367 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8285 26 - 3283 23 - 10555 9847 - 10561 10395 - 11896 11500 - 13779 2447 26 - 2989 23 - 8376 7932 - 8379 8300 - 8994 8823 - 9019 none10367 , 12445 3450 6870 7240 8430 13450 10570 - 13540 4-1/2" 12.6# L-80 21 - 104018383 - 8995 80 20" 27 - 107 27 - 107 1490 4-1/2" Baker SB3 No SSSV 10346 8273 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 PRUDHOE BAY 7/21/2024 PRUDHOE OIL PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.10 16:28:02 - 08'00' Bo York (1248) By Grace Christianson at 10:36 am, Jul 12, 2024 324-398 * BOPE test to 3000 psi. Annular to 2500 psi. 2447 10-404 MGR15JULY24 SFD 7/15/2024 DSR-7/15/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.15 15:40:35 -08'00'07/15/24 RBDMS JSB 071624 RWO Procedure 07-28B PTD:2090370 Well Name:07-28B API Number:50029217700200 Current Status:Shut-In, Secured with TTP Rig:ASR#1 Estimated Start Date:07/21/2024 Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:2090370 First Call Engineer:Jerry Lau 907-564-5280 907-360-6233 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.3 PPGE I Average of surrounding wells Max. Anticipated Surface Pressure:2,447psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1550 psi (Taken pre TTP 05/22/22) Min ID:2.30”ID Milled out bushing @ 11513’ MD Max Angle:96 Deg @ 12028’ MD Brief Well Summary: 07-28B is a Z1A lateral producer originally drilled in ’88, rotary sidetracked in ’97, then CTD sidetracked in 02’ and most recently in ’09. The well was competitive producing 375 bopd at 60 IOR until TxIA communication developed in April ’21. A subsequent LDL log found 15 TBG holes from 5900-7300’ in addition to another previously patched hole at 8246’. Sag add perfs were added and the well was flowed under eval from May to July ’22 to help justify the economics of a RWO – the last well test was 500 bopd at 114 IOR. Now we will pursue a RWO to replace the L-80 TBG with 13 Cr TBG. There is potential to mill out a CIBP set in 2017 to recover more production from the toe perfs. Notes Regarding Wellbore Condition: x The 9-5/8” production casing and 7” liner above production packer passed a CMIT-TxIA to 2500 psi on 5/14/2022. x Ivishak and sag perfs will remain hydraulically isolated throughout RWO by tested 4-1/2” Evo-Trieve plug at 10,367’ MD. We plan to pull WRP and reset EVO-Trieve prior to RWO. x PPPOT-T/IC passed on 1/7/23 x 15+ holes in TBG from 5900’-8250’ MD. Objective: Pull the existing 4-1/2” L80 tubing out of the well and replace with 4-1/2” 13Cr tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO DHD– Cycle LDS (DONE 12/15/23) PPPOT-T to 5000 psi (DONE 03/23/23) PPPOT-IC to 3500 psi (DONE 03/23/23) SL - Pull ST#3 DGLV, Set ST#2 DGLV. Pull 4-1/2” WRP Set 4-1/2” EVO-Trieve Plug w/ Junk Basket @ 10367’ MD, CMIT to 3000 psi Run Caliper, rush data to Jerry.Lau@hilcorp.com RWO Procedure 07-28B PTD:2090370 All subsequent work pending sundry approval EL – Cut tubing using welltech mech cutter @ ~10,297’ MD (2’ below top of 1 st full joint above PKR). Contingent TBG punch @ ~10,260’ MD in case slickline was unable to pull lower station. Circ out well to 8.5ppg 1%KCl w/ diesel FP on T & IA DHD– Bleed WHP’s to 0 Valve Shop – Set and test ISA BPV Nipple Down Tree and tubing head adapter. Inspect lift threads. Install ISA blanking plug. NU 11” BOPE Stack configured top down, Annular, 2-7/8” x 5” VBRs, Blinds and flow cross. RWO 1. NU BOP house and spot mud boat. MIRU ASR #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi 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 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5” VBR’s with 4-1/2” test joint. Test the Annular preventer with 4-1/2” test joint. We will not proactively test with a workstring test joint. If needed, we will test accordingly. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull Blanking Plug and ISA BPV. Use a dry rod to pull the back pressure valve unless pressure is expected, then rig up lubricator. 4. RU Control line spooler. There are dual control lines to the safety valve landing nipple. It was reported to have 55 stainless steel bands. 5. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~113 K. The lift threads are expected to be 4-1/2” BTC-MOD. Circulate bottoms up. 6. Pull 4-1/2” tubing. The tubing will not be salvaged. While rigging down control line spooler circulate at max rate. Note if any bands or line are missing. 7. Drift the production overshot with the cut joint. 8. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on the proposed schematic. a. The packer depth is estimated to have 93’ of stand-off above the top of 7” LTP. 9. Land tubing hanger and reverse in corrosion inhibited 1% KCl (or seawater) into the IA. 10. Drop ball and rod and set packer with 3,500-psi pump pressure. 11. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 12. Shear valve in upper GLM. 13. Set TWC 14. Rig down ASR #1 Post RWO - ValveShop 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. If any risk of pressure, lubricate BPV. - mgr RWO Procedure 07-28B PTD:2090370 Post RWO – Slickline 1. Pull Ball and rod and RHC profile 2. Pull Junk basket and EVO-Trieve from 10,367’ MD. 3. Set GLV’s per GL Engineer. 4. RDMO Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Existing Tally 5. Proposed Tally 6. 4-1/2” VamTop Tech Sheet 7. Sundry Revision Change Form. RWO Procedure 07-28B PTD:2090370 Current Wellbore Schematic RWO Procedure 07-28B PTD:2090370 Proposed Wellbore Schematic 4-1/2" EVO-Trieve RWO Procedure 07-28B PTD:2090370 RWO BOP Stack RWO Procedure 07-28B PTD:2090370 Existing Tally RWO Procedure 07-28B PTD:2090370 Proposed Tally RWO Procedure 07-28B PTD:2090370 4-1/2” VamTop Spec Sheet RWO Procedure 07-28B PTD:2090370 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 07-28B Tbg Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-037 50-029-21770-02-00 ADL 0028309 , 028306 13782 Surface Intermediate Liner Liner Liner 9020 3257 10532 714 1501 2279 10367 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8285 26 - 3283 23 - 10555 9847 - 10561 10395 - 11896 11500 - 13779 2447 26 - 2989 23 - 8376 7932 - 8379 8300 - 8994 8823 - 9019 none 1950 4760 5410 7500 13890 10367 , 12445 3450 6870 7240 8430 13450 10570 - 13540 4-1/2" 12.6# L-80 21 - 104018383 - 8995 Conductor 80 20" 27 - 107 27 - 107 1490 470 4-1/2" Baker SB3 Packer No SSSV 10346 8273 Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 PRUDHOE BAY 7/1/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:12 am, Mar 07, 2023 323-134 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.03.06 11:38:41 -09'00' 2447 * BOPE test to 3000 psi. Annular to 2500 psi. 10-404 DSR-3/7/23SFD 3/8/2023MGR08MAR23GCW 03/09/23JLC 3/9/2023 3/9/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.09 13:59:39 -09'00' RBDMS JSB 030923 RWO Procedure 07-28B PTD:209-037 326Well Name:07-28B API Number:50029217700200 Current Status:Shut-In, Secured with TTP Rig:Thunderbird #1 Estimated Start Date:07/01/2023 Duration/Cost:6.5 days / $1.100MM Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:209 0370 First Call Engineer:Jerry Lau 907-564-5280 907-360-6233 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 AFE Number:IOR 160 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.3 PPGE I Average of surrounding wells Max. Anticipated Surface Pressure:2,447psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1550 psi (Taken pre TTP 05/22/22) Min ID:2.30”ID Milled out bushing @ 11513’ MD Max Angle:96 Deg @ 12028’ MD Brief Well Summary: 07-28B is a Z1A later producer originally drilled in ’88, rotary sidetracked in ’97, then CTD sidetracked in 02’ and most recently in ’09. The well was competitive producing 375 bopd at 60 IOR until TxIA communication developed in April ’21. A subsequent LDL log found 15 TBG holes from 5900-7300’ in addition to another previously patched hole at 8246’. Sag add perfs were added and the well was flowed under eval from May to July ’22 to help justify the economics of a RWO – the last well test was 500 bopd at 114 IOR. Now we will pursue a RWO to replace the L-80 TBG with 13 Cr TBG. There is potential to mill out a CIBP set in 2017 to recover more production from the toe perfs Notes Regarding Wellbore Condition: x The 9-5/8” production casing and 7” liner above production packer passed a CMIT-TxIA to 2500 psi on 5/14/2022. Need to retest to 3000 psi. x Ivishak and sag perfs will remain hydraulically isolated throughout RWO by tested 4-1/2” WRP plug at 10,367’ MD. x PPPOT-T/IC passed on 1/7/23 x 15+ holes in TBG from 5900’-8250’ MD. Objective: Pull the existing 4-1/2” L80 tubing out of the well and replace with 4-1/2” 13Cr tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD – CMIT-TxIA to 3,000-psi. Cycle LDS’s SL - Set 4-1/2” Junk Basket on top of WRP at 10,367’ MD. Run Caliper EL – Cut tubing using welltech mech cutter @ 10,297’ MD (2’ below top of 1 st full joint above PKR) Circ out well to 8.5ppg 1%KCl w/ diesel FP on T & IA Need to retest to 3000 psi. Set 4-1/2” Junk Basket on top of WRP at 10,367’ MD. 209-037 CMIT-TxIA to 3,000-psi. SFD RWO Procedure 07-28B PTD:209-037 DHD - Bleed WHP’s to 0 Valve Shop – Set and test ISA BPV Nipple Down Tree and tubing head adapter. Inspect lift threads. Install ISA blanking plug. NU BOPE configured top down, Annular, 2-7/8” x 5” VBRs, Blinds and integral flow cross. 13-5/8” x 11” Adapter. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5” VBR’s with 4-1/2” test joint. Test the Annular preventer with 4-1/2” test joint. We will not proactively test with a workstring test joint. If needed, we will change rams and test accordingly. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull Blanking Plug and ISA BPV. Use a dry rod to pull the back pressure valve unless pressure is expected, then rig up lubricator. 4. RU Control line spooler. There are dual control lines to the safety valve landing nipple. It was reported to have 55 stainless steel bands. 5. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~113 K. The lift threads are expected to be 4-1/2” BTC-MOD. Circulate bottoms up. 6. Pull 4-1/2” tubing. The tubing will not be salvaged. While rigging down control line spooler circulate at max rate. Note if any bands or line are missing. 7. Drift the production overshot with the cut joint. 8. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on the proposed schematic. a. The packer depth is estimated to have 93’ of stand-off above the top of 7” LNR with overshot stung in. 9. Land tubing hanger and reverse in corrosion inhibited 1% KCl (or seawater) into the IA. 10. Drop ball and rod and set packer with 3,500-psi pump pressure. 11. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 12. Shear valve in upper GLM. 13. Set TWC 14. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Post rig Slickline Work RWO Procedure 07-28B PTD:209-037 1. Pull Ball and rod and RHC profile 2. Pull Junk basket and WRP from 10,367’ MD. 3. Set GLV’s per GL Engineer. 4. RDMO & pop well Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Existing Tally 5. Proposed Tally 6. 4-1/2” VamTop Tech Sheet 7. Sundry Revision Change Form. RWO Procedure 07-28B PTD:209-037 Current Wellbore Schematic RWO Procedure 07-28B PTD:209-037 Proposed Wellbore Schematic RWO Procedure 07-28B PTD:209-037 RWO BOPs RWO Procedure 07-28B PTD:209-037 Existing Tally RWO Procedure 07-28B PTD:209-037 Proposed Tally RWO Procedure 07-28B PTD:209-037 4-1/2” VamTop Spec Sheet RWO Procedure 07-28B PTD:209-037 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 2022-0517-1530 APPROVAL to flow under evaluation PBU 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Date:Tuesday, May 17, 2022 3:37:04 PM Attachments:image002.png image003.png To: Oliver Sternicki <oliver.sternicki@hilcorp.com> Subject: 2022-0517-1530 APPROVAL to flow under evaluation PBU 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Oliver, Hilcorp North Slope, LLC is approved to flow well PBU 07-28 (PTD209-037) ‘under evaluation’ for 60 days. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, May 17, 2022 3:28 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Proposed perforations in the program are: Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, May 17, 2022 3:16 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Oliver, What are the proposed depths for the Sag perforations? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, May 16, 2022 4:40 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> 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. Subject: RE: [EXTERNAL] RE: 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Mel, These will be new perfs. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, May 16, 2022 3:08 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Oliver, Is this a ‘reperforate’ Sag? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, May 16, 2022 1:27 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 07-28(PTD# 209037) Request to flow under evaluation for up to 60 days Mel, Producer 07-28 (PTD# 209037) was made not operable on 4/29/2021 after the IA exceeded NOL of 2100 psi and subsequent leak detection logging found multiple holes in the tubing between 5907’-7272’ MD. TxIA liquid leak rate= 0.52 bpm @ 1700 psi. On 5/13/2022 a WRP was set at 10364’ MD and the well passed a non-witnessed CMIT-TxIA to 2490 psi. This passing CMIT-TxIA proves the integrity of the secondary barrier. Plans for the well are to add Sag perforations to increase productivity, but economics are needed based on these new perfs to justify repair of the tubing. Hilcorp request permission to flow 07- 28 under evaluation for up to 60 days to confirm production rates post Sag perforations. Gas lift may be needed to flow the well during the under evaluation period. Let me know if you have any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@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 havereceived 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 ortelephone 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 notadversely 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. By Anne Prysunka at 3:55 pm, Aug 02, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAR 7 1 mmo 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shputdlp�lnl�1� l/�, l/�, Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change AppfoJE3�rd;inQ `iJ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 209-037 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service ❑ 1 6. API Number: 50-029-21770-02-00 7. Property Designation (Lease Number): ADL 028309 & ADL 028306 8. Well Name and Number: PBU 07-28B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13782 feet Plugs measured 12445 feet true vertical 9020 feet Junk measured None feet Effective Depth: measured 12445 feet Packer measured 10346 feet true vertical 8994 feet Packer true vertical 8274 feet Casing: Length. Size: MD: TVD: Burst: Collapse: Conductor 80 20" 27-107 27-107 1490 470 Surface 3257 13-3/8" 26-3283 26-2989 3450 / 5380 1950/2670 Intermediate 10532 9-5/8" 23-10555 23-8376 6870 4760 Liner 714 7" 9847-10561 7932-8379 7240 5410 Liner 1501 4-1/2' 10395 - 11896 8300-8994 8430 7500 Liner 2279 3-1/2" x 3-3/16" x 2-7/8" 11500 - 13779 8823-9019 13450 13890 Perforation Depth: Measured depth: 11387 -13540 feet True vertical depth: 8764-8995 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 21-10401 21-8340 Packers and SSSV (type, measured and 4-1/2' Baker SB3 Packer 10346 8274 true vertical depth) NO SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 13 303 3 0 210 Subsequent to operation: 1726 19138 55 0 398 14. Attachments: treauiretl per 20 nnc 25.07025.071, a 252M) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Vohra, Prachi Contact Name: Vohra, Prachi Authorized Title: Production Engr Contact Email: Prachi .Volftri,corn Authorized Signature: 0Yr9"`s--" Date. 612 -* 111 Contact Phone: +1 9075644677 Form 10.404 Revised 042077 DMS.kA MAR 211019 Submit Original Only Daily Report of Well Operations PBI 07-28B nrTiViTvnnTG 01 IRAAAA MV 2/26/2019 ***WELL S/I ON ARRIVAL*** (Adperf) RIG UP HES RELAY UNIT #46 ***JOB CONTINUED ON 27 -FEB -2019*** ***JOB CONTINUED FROM 26 -FEB -2019*** (Adperf) HES RELAY UNIT #46 RUN 1: PERFORM GR/CCL JEWELRY LOG 11,940'- 11220'. RUN 2: PERFORATE 11,797' - 11,820'W/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. 2/27/2019 ***JOB CONTINUED ON 28 -FEB -2019*** ***JOB CONTINUED FROM 27 -FEB -2019*** (Adperf) HES RELAY UNIT #46 RUN 3: PERFORATE 11,387'- 11,392' W/2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. ALL LOGS CORRELATED TO PDCL DA 29 -OCT -2018. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/1/0 = 1200/1240/0. 2/28/2019 ***JOB COMPLETE ON 28 -FEB -2018*** WELLHEAD= FMC ACTUATOR= BAKERC OKB. B -EV = 62.0' REF ala/ = 53.217 BF. ELEV = 29.99 KOP(A)= 1488' Max Angk: = 96' @ 12028' Datum MD= 11559 Datum TVD= 8800'SS 20" CONDUCTOR,110' 91.5#, H-40, D =19.124" IL 13-3/8" CSG, 68#, K-55 (1 JOINT), D = 12.415' 1-3/8" CSG, 72#, L-80, D = 12.347" 15KB BKR FLOGAURD PATCH, D = 2.45" (07/03/18) r➢ 18233' - 8253' 1 Minimum ID =2.30" @ 11513' MILLED OUT SEBLRT BUSHING 4-V2" LNR 12.6#, L-80 BTGM-ERW, .0152 bpf, ID= 3.958' —11896 4-1/2" TBG, 12.6#, L-80 BTGM, 10401' REF LOG: GR/CCL on 06/30/09 .0152 bpf, D = 3.958" ANGLE AT TOP PERF: 57" @ 11387' Note: Refer to Production DB for historical pert data SIZEI SPFI1 7" TBG, 26#, L-80 BTC -10561' 2-6 i 11387 - 11392 0 102/28/19 .0383 bpf, D= 6276" 2" 6 19-5/8"WHIPSTOCK � 10564' RK 2" 6 11830 - 11840 O 07/17/17 11558' 111847 - 11894 O 07/17117 3-1/2' LNR 8.81#, L-80 STL, 112520 - 12870 C 07/01/09 .0087 bpf, D = 2.990' 12920 - 133101 C 07/01/09 4-1/2 WH� 11896' 4-V2" LNR 12.6#, L-80 BTGM-ERW, .0152 bpf, ID= 3.958' —11896 E IO US WW EL BORES NOT SHONOTES: W ELL ANGLE > 70WN BELOW 118 e•` 07-28B PR WHIPSTOCK*** = 3.813" GAS LFT MANDRELS ST PERFORATION SLAWAARY TVD REF LOG: GR/CCL on 06/30/09 TYPE ANGLE AT TOP PERF: 57" @ 11387' Note: Refer to Production DB for historical pert data SIZEI SPFI1 INTERVAL Opn/Sgz SHOT SOZ 2-6 i 11387 - 11392 0 102/28/19 3413 2" 6 111797 - 118201 O 02/27/19 RK 2" 6 11830 - 11840 O 07/17/17 2" 6 111847 - 11894 O 07/17117 2" 6 112520 - 12870 C 07/01/09 2" 6 12920 - 133101 C 07/01/09 2" 6 13460-135401 C 07/01/09 E IO US WW EL BORES NOT SHONOTES: W ELL ANGLE > 70WN BELOW 118 e•` 07-28B PR WHIPSTOCK*** = 3.813" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3840 3413 39 Hfu1(' DONE RK 16 07/09/18 2 7408 6099 42 MMG SO RK 22 07/09118 3 9743 7850 38 kT1C' DMY RK 0 04/01/08 X 8-1/4" BKR ZXP PKR, D = BKR HMC HGR, D = 6.250' X7 -XO D=6 184- 10�--17" X 4-1/2' BKR SB -3 PKR D = 3.875" 10372' 45 KB PKR w /2-7/8' NP REDUCER 4-1/2' WLEG, D = 3.958" D = 2.31' (3/30/18) -MAX DIFF PRESSURE ELMD TT NOT LOGGED ACROSS NP REDUCER IS 2500 PSS 10379' 4-1/2" HES XN NP MILLED TO 3.80' 10395' —1 7" X 5-3/4" BKR ZXP PKR 10414' 5'X4-1/2'XO,D=3.937' 11�60� 4-1/2' KB PKR w/SEAL STEM. D = 11606 1370' DEPLOYMENT SLV, D = 3.00' 11613' MILLED OUT BUSHING, MLLOUT WINDOW (07-28B) 11896'-11901' 11668' 3-1/2" X 3-3/16' XO, D = 2.786' lam\ 1/2161' 3-3/16' X 2-7/8" XO, D = 2.387' \ v 12445' WFD C13P(07/16/17) .0076 bpf, D = 2.80" 12-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, D = 2.441' I DATE w / 7.11" TIERAM D = 4.40' 10401' DATE 4-1/2' WLEG, D = 3.958" 06/20/68 ELMD TT NOT LOGGED 10408'7" X 5' HMC HGR, D = 4.40' 10414' 5'X4-1/2'XO,D=3.937' 11�60� 4-1/2' KB PKR w/SEAL STEM. D = 11606 1370' DEPLOYMENT SLV, D = 3.00' 11613' MILLED OUT BUSHING, MLLOUT WINDOW (07-28B) 11896'-11901' 11668' 3-1/2" X 3-3/16' XO, D = 2.786' lam\ 1/2161' 3-3/16' X 2-7/8" XO, D = 2.387' \ v 12445' WFD C13P(07/16/17) .0076 bpf, D = 2.80" 12-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, D = 2.441' I DATE REV BY COMMENTS DATE REV BY CONVENTS 06/20/68 ROWAN 41 INITIAL COMPLETION 07/10/18 N WJMO SET FLOGUARD PATCH 08/19/97 0141 SIDETRACK(07-28A) 07/12/18 CJFYJMO GLV 00(07/09/18) 07131/02 NORDIC 1 CTD SIDETRACK (07-28AL1 07/12/18 RCB/JM) R LLED2-7/8" XX PLUG (07/10/18) 07102109 NORDIC 1 CTD SIDETRACK (07-28B) 03/04/19 MS/JM) ADPERFS 04/02/18 BSFJJMO SET PKR w /PP RED & PLUG 03/20/19 DD'JMD ADDED OKB, REF, & BF ELEV 04/24/18 JMGIJMO GLV CJO(04/11/18) PRUDHDE BAY UNT WB_L: 07-28B PB2MT No '2090370 API No: 50-029-21770-02-00 SEC 33, T11 N, R14E, 394' FNL & 339' FB_ BP Exploration (Alaska) STATE OF ALASKA EC E'` sE �ASKA OIL AND GAS CONSERVATION COMMIS RV ED OF SUNDRY WELL OPERATIO 1. Operations Performed AA'' ,,II ((�� CC 2017 Abandon ❑ Plug Perforations El Fracture Stimulate 0 Pull Tubing 0 OperatiorNO (ddNr6 ❑ Suspend 0 Perforate IZI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for RedriII 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: SeeeCG❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 209-037 3. Address: P.O.Box 196612 Anchorage, Development Il Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21770-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-28B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13782 feet Plugs measured 12445 feet true vertical 9020 feet Junk measured None feet Effective Depth: measured 12445 feet Packer measured 10345 feet true vertical 8994 feet Packer true vertical 8273 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 79 20" 27-106 27-106 1490 470 Surface 3252 13-3/8" 26-3278 26-2985 3450/4930 1950/2670 Intermediate 9999 9-5/8" 23-10022 23-8064 6870 4760 Liner 714 7" 9846-10560 7931-8378 7240 5410 Liner 1503 4-1/2" 10393-11896 8299-8994 8430 7500 Liner 2279 3-1/2"x 3-3/16"x 2-7/8" 11500-13779 8823-9019 Perforation Depth: Measured depth: 11830-13540 feet NE True vertical depth: 8973-8995 feet SCAN D JAN 0 3 2M Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 21 -10400 21 -8303 Packers and SSSV(type,measured and 4-1/2"Baker SB-3 Packer 10345 8273 true vertical depth) - 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 243 24111 16 600 434 Subsequent to operation: 675 1559 96 1800 238 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory ❑ Development IZI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: N/A Authorized Name: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: PProducctionnEngr Contact Email: Prachi.Vohra(�bp.com Authorized Signature: 099,9c9— _ Date: op/')2.0 it Contact Phone: +1 9075644677 Form 10-404 Revised 04/2017 rT-- 1 7,/71 i - ;1/ Submit Original Only ,A /z7,/7 REZ:i7 i3 u,/ Cis:', -. 7 2r,..117 t.11 • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 31, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for 07-28B PTD #209-037, plug perforations and perforate. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Daily Report of Well Operations 07-28B ACTIVITYDATE SUMMARY CTU #8 - 1.50" CT. Job Scope: Set CIBP,Adperf Arrive on location begin rig up 7/15/2017 ***Job in progress*** ***Continue from WSR 7/15/17*** CTU #8 - 1.50" CT. Job Scope - Set CIBP,Adperf RIH w/ HES Memory GR/CCL in carrier. Tag @ 13259', log up @ 50 fpm to 10,300'. Painted WHITE & ORANGE flag @ 12400'. 7/16/2017 T/I/O = 1370/100/0. Temp = SI. IA FL (SLB Coil request). No AL. IA FL @ 480' (26 7/16/2017 bbls). ***Continue from WSR 7/15/17*** CTU #8 - 1.50" CT. Job Scope - Set CIBP,Adperf RIH w/ HES Memory GR/CCL in carrier. Tag @ 13259', log up @ 50 fpm to 10,200'. Painted WHITE & ORANGE flag @ 12400'. Kill well. RIH &set Weatherford CIBP at 12,500' ME/ 11429.7' Top of Plug. Test Tubing to 2000psi -fail. Freeze Protect well. LRS loaded IA w/27 bbls diesel, PT tubing; Starting T/I/O = 2081/298/49. Five minutes 1001/287/481. Bump up w/ pressure w/ 1.3 bbls 50/50. Starting T/I/O = 2206/292/48, Five minutes 1626/287/48, Ten minutes 1263/283/48. Determine 4.2 GPM LLR with no communication in IA, LLR acceptable. Make up & RIH w/ 32'x 2.00" HES Millenium guns. ***Job in progress*** 7/16/2017 T/I/0=120/0/0 Temp= S/I Assist CTU (PROFILE MODIFICATION) Pumped 27 bbls, 80*F, crude down IA to load while coil tubing pressure tested TBG string. CTU in control of well 7/16/2017 upon LRS departure. FWHP's coil/300/50 ***Continue from WSR 7/15/17*** CTU #8 - 1.50" CT. Job Scope - Set CIBP,Adperf RIH w/ HES Memory GR/CCL in carrier. Tag @ 13259', log up @ 50 fpm to 10,200'. Painted WHITE &ORANGE flag © 12400'. Kill well. RIH &set Weatherford CIBP at 12,500ft. Test Tubing to 2000psi -fail. Freeze Protect well. 7/16/2017 ***Continue from WSR 7/16/17*** CTU #8 - 1.50" CT. Job Scope - Set CIBP,Adperf Perforated interval #1; 11864' - 11894'w/2" HES Millenium guns, 6 SPF 60* phasing, tied into Schlumberger Memory Gamma Ray/CCL log dated 30-June-2009 Perforated interval#2; 11847' - 11864'w/2" HES Millenium guns, 6 SPF 60* phasing, tied into Schlumberger Memory Gamma Ray/CCL log dated 30-June-2009 Perforated interval#3; 11830' - 11840'w/2" HES Millenium guns, 6 SPF 60* phasing, tied into Schlumberger Memory Gamma Ray/CCL log dated 30-June-2009 Freeze protect wellbore 7/17/2017 ***Job Complete*** Fluids Summary Volume Type 505 Bbls Slick 1% KCL 102 Bbls 50/50 Meth 27 Bbls Crude TREE= 41!16"CNV FLS WELLHEAD= FMC • 07-28 B P IOUS W EL BORES NOT SHOWN BELOW••" C ACTUATOR= BAKER IAL KB.El 53.25' WHIPSTOCK*** MAL BF.ELEV= ) X 1 KOP(A)= 1488' 20"CONDUCTOR —1 110' kix Angle - 96 @ 12028' 2173' —4-112"CAMCO SSSV Nom,D=3.813" Datum A/3= 11559' 91.5#,1440, Datum NQ_ 8800.ss D=19.124" GAS UFT MANDRELS 113-3/8"CSG,68#,K-55(1 JOINT),ID=12.415" 1— 80' MD TVD DEV TYPE VLV LATCH PORT DTE 17. 3840 3413 39 NAG DOME RK 16 03/21/16 7408 6099 42 MNG DOME RK 16 03/21/16 13-316"CSG,72#,L-80,D=12.347' 1 - 3292' 9743 7850 38 M43 DMY RK 0 04/01/08 TOP OF 7"LNR — 9847' 1---,I ---1 9847' —19-5/8'x B-1/4'BKR ZXP PKR D=7.500" 9881' H 8.313"BKR HMC HGR,D=6.250" 986T -18.313'X 7"X0,10=6.184" X X 10346' —17"X4-1/2'BKR SB-3PKR,0=3.875' Minimum ID = 2.30" @ 11513' MILLED OUT SEBLRT BUSHING I I 10379' H4-1/2"HES XN NP MLLED TO 3.80" 10395' —7'X 5-3/4"BKR ZXP PKR WI 7.11"TIEBACK,D=4.40' 4-1/2'TBG,12.6#,L-80 BTC-M H 10401' / 10401' —14-1/2"WLEG,D=3.958" .0152 bpf,ID=3.958" ✓ H ELM)TT NOT LOGGED 10408' R D 7"X 5"MAC HG =4.40" T TBG,26#,L-80 BTGM —1 10561' .0383 bpf,D=6.276" 10414' 5"X 41/2"X0,113=3.937" 9-5/B'WHPSTOCK — 10023' : r/ 11500' —14-1/2"KB F1(R w/SEAL STEM D=2.377" 9-5/8'CSG,47#,L-80,D=8.681' — —10023 11506' -13.70'DEPLOY KENT SLV,D=3.00" 1 1 11513' HULLED OUT BUSF1NG,D=2.30' 3-1/2"LNC,8.81#,L-80 STL, —1 11558' / .0087 bpf,ID=2.990" ' 1 1 MLLOUT WINDOW(07-28B) 11896'- 11901' 4-1/2"WHPSTOCK —1 11896' ! 1 4-1/2"LNR,12.6#,L-80 BTC-M-ERW, H —11896 �" 11558' —3-1/7 X 3-3/16"XO,D=2.786" .0152 bpf,D=3.958" `v4'��4 `ftlw 12161' —13-3/16“X 2-7/8"XO,ID=2.387" FEW-ORATION SUMMARY V IVq: REF LOG:GR/CCL on 06/30/09 x.1...4 12445' WFD CSP(07/16/17) 44441 _ ANGLE AT TOP PERF:71°@ 11830' A l Note:Refer to Production DB for historical perf data , SIZE SPF INTERVAL OpnlSgz SI-OT SOZ 33/16"LNR 6.2#,L-80 TCI, H 12161' /i��'�/ 2" 6 11830-11840 0 07/17/17 .0076 bpf,D=2.80" 2' 6 11847-11894 0 07/17/17 2" 6 12520-12870 C 07/01/09 FBTD —1 13739' 2" 6 12920-13310 C 07/01/09 2' 6 13460- 13540 C 07/01/09 2-7/8'LNR,6.16#,L-80 SR,_0058 bpf,ID=2.441" —1 13779' DATE REV BY (X1M&NTS DTE REV BY COMMENTS PRIDHOE BAY MT 06/20/88 ROWAN 41 INITIAL COMPLETION 07/18/17 MR/JMD SET CSPB ADPERFS WELL 07-28B 08/19/97 D141 SIDETRACK(07-28A) PERMIT No: 2090370 07/31102 NORDIC 1 CTD SIDETRACK(07-28AL1) AR No: 50-029-21770-02-00 07/02/09 NORDIC 1 CTD SIDETRACK(07-28B) SEL 33,T11 N,R14E,394'FM_8 339'FEL 12/16/10 CSR/PJC MICR CORRECTIONS 03/23/16 RJK/JM) GLV C/O(03/21/16) BP Exploration(Alaska) 2.001,0-67 R EC ElVeD RUM APR 12 2U16 PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 07-28B 900 E. Benson Blvd. it/01/201t. M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE March 21,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE April 11,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIMLOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX LOGS - CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #01--'FiIN I S #OF COPIES #OF COPIES #OF COPIES ' 4 4 4 4 4 4 U 1 BP North Slope. 0 0 0 I 0 I 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 I 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 SCppHED JUN 1 7 2G it' 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 1 1 0 0 I Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 I _ I I 0 .1 0 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 I 1 I 0 I 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 I 0 I 0 I 0 I 0 I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0