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Home My WebLink About222-080STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS By AnPrysunka of 11:59 am, Nov S0, 10Y4 1. 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 Set Packers ■ 2. Operator Name: Hilcorp North Slope, LLC 14. Well Class Before Work: S. Permit to Drill Number: 222-080 Development ❑ Stratigraphic ❑ Exploratory ❑ Service ■ 3. Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 6. API Number: 50-029-23720-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. PBU Z-223 ADL 0028262, 0047450 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, SCHRADER BLUFF OIL, ORION Dev Area 11. Present Well Condition Summary: Total Depth measured 16855 feet Plugs measured 15300 feet true vertical 4876 feet Junk measured None feet Effective Depth measured 15300 feet Packer measured 4058 feet true vertical 4826 feet true vertical 3491 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" X 34" 27 - 107 27 - 107 2280 770 Surface 2238 9-5/8" 26 - 6220 26 - 4700 6870 4760 Tieback 3924 7" 24 - 3948 24 - 3389 7240 5410 Production Liner 11453 7" x 4-1/2" 3938 -15391 3380 - 4830 7240 / 8430 5410 / 7500 Perforation depth Measured depth 4898 -15253 feet True Vertical depth 4228-4824 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 22 - 4204 22 - 3626 Packers and SSSV 4-1/2" HES TNT Perm Packer- 4058, 3491 No SSSV Installed (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New Well 0 0 Subsequent to operation: 2734 750 1342 13b. Pools active after work: SCHRADER BLUFF OIL, ORION Dev Area 14. Attachments (required per 20 AAC 25.07Q 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: OIL ❑ GAS ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ Suspended ❑ 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: Stan Go JiS [AgUlNsgnea by Stan cons N/A 00 : c—n -,. leao), -uses Authorized Name and (880) ogre: zozz.n.as io:acranaron' Contact Name: Wyatt Rivard Digital Signature with Date: Stan Golis Contact Email: wrivard@hilcorp.c rn Authorized Title: Sr. Area Operations Manager Contact Phone: 907.777.8547 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Daily Report of Well Operations PBU Z-223 ACTIVITY DATE SUMMARY ***WELL S/I ON ARRIVAL*** SET CATCHER ON BALL & ROD @ 4,134' MD PULL 1" BEK-SHEAR VALVE FROM STA #1 @ 2,668' MD SET 1" BK-DMY GLV IN STA #1 @ 2,668' MD PULL CATCHER FROM TOP OF BALL & ROD @ 4,134' MD PULL BALL & ROD FROM 4-1/2" RHC @ 4,134' MD 9/23/2022 ***CONT WSR ON 09/24/2022*** ***CONT WSR FROM 09/23/2022*** PULL 4-1/2" RHC FROM X-NIPPLE @ 4,134' MD 9/24/2022 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** CTU 9 2.0" CT Job Objective: Set Packers & Shift Open NCS Sleeves MIRU. Pump drift ball. Test BOPS. 9/24/2022 ***Job in Progress*** CTU 9 2.0" CT Job Objective: Set Packers & Shift Open NCS Sleeves Continue to test BOPS. MU & RIH w/ 3.80" drift BHA. Tag at 4203'. MIT -IA to 870psi fail. POH. FP well. MU & RIH w/ 3.70" drift BHA. Tag at 4203'. POH. Rig off well. RU slickline. Tag at 4203' with 3.80" LIB. Tag at 4364' with 3.55" GR. Tag at 4089' with 3.6" GR. Drift to deviation - 5689' with 3.25" centralizer. Drift to deviation - 5689' with caliper drift. 9/25/2022 ***Job in Progress*** ***WELL S/I ON ARRIVAL*** (assist coil) TAGGED OBSTRUCTION @ 4187' SLM w/ 3.80" LIB TAGGED OBSTRUCTION @ 4364' SLM w/ 3.55" GAUGE RING TAGGED OBSTRUCTION @ 4189' SLM w/ 3.60" GAUGE RING DRIFTED TO DEVIATION @ 5689' SLM w/ 3.25" CENTRALIZER DRIFTED TO DEVIATION @ 5697' SLM w/ 2.35" SWAGE & 20'x1.75" BAILER 9/25/2022 ***JOB IN PROGRESS, CONTINUED ON 9/26/22*** T/I/O=SSV/0/0, Temp=Sl. PPPOT-IC (PASS), eval IAxOA com. PPPOT-IC: Stung into test port (0 psi), Pumped through void, good returns. Pressured void to 3000 psi for 30 min test, lost 25 psi in 15 min, Iost25 psi in second 15 min (PASS). Bled void to 0 psi. 9/25/2022 CTU 9 2.0" CT Job Objective: Set Packers & Shift Open NCS Sleeves Caliper well from 5689' to surface. RD slickline. RIH w/2.5"DJN tag float collar @15348' set down 14k attempt to set packers. Unable to pressure well up to set packers. POOH. FP well. RDMO. 9/26/2022 ***Incomplete*** ***CONTINUED FROM 9/25/22*** (Assist coil) LOGGED w/ READ 40 ARM CALIPER FROM 5800'SLM TO SURFACE (Good data) ***CTU IN CONTROL OF WELL*** 9/26/2022 T/I/O = 290/0/0. Temp = SI. T FL (OE). No wellhouse, drill scafold installed around well head. T FL @ surface. 9/30/2022 SV, WV, SSV = C. MV = O. IA, CA = OTG. 10:45 Daily Report of Well Operations PBU Z-223 T/I/O= 240/0/0 Temp = SI (AOGCC MIT -IA) **PASSED** to 3570 psi. Witnessed by Kam St John. Pumped down IA, 2.9 bbls ambient diesel to reach max applied 3756 psi. 1st 15 minute IA loss = 162 psi, 2 nd 15 minute IA loss = 24 psi. Bled back 1.5 10/13/2022 bbls. Tag hung, DSO notified, FWHP's = 190/0/0 ***WELL S/I ON ARRIVAL*** (Profile modification) STAND BY FOR WELL TESTERS BLOCKING ACCESS RU POLLARD SLU # 60 10/26/2022 ***JOB IN PROGRESS, CONTINUED ON 10/27/22 WSR*** ***CONTINUED FROM 10/26/22 WSR*** (Profile modification) OPEN UP OVERTORQUED COLLARS @ 4,380' & 4,534' MD w/ 3.56" SWAGE. DRIFT TBG TO DEVIATION STALL @ 5786' SLM w/ 41' x 3.50" PIPE DRIFT (300# overpull to pass back through restrictions @ 4192' , 4366' & 4517' slm) 10/27/2022 ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** TWO = 340/100/VAC. Temp = SI. T FL (Ops). T FL @ 100' (2 bbls). 10/28/2022 SV, WV, SSV = C. MV = 0. IA, CA = OTG. 14:00 ***WELL SHUT IN ON ARRIVAL*** OBJECTIVE: DRIFT / SET CBP / SET PKR'S / SHIFT SLV'S RIG UP YJ ELINE & WELLTECH TRACTOR. PT PCE 300 PSI LOW /3500 PSI HIGH. RIH W/ WELLTEC 3-1/8" TRACTOR & 3.50" CENTRALIZER DRIFT. TAG PBTD AT 15343.5', CCL LOG CORRELATED TO LINER TALLY DATED 8/24/22, LAY DOWN FOR THE NIGHT 11/3/2022 ***CONTINUE JOB ON 11/04/22*** ***CONTINUED JOB FROM 11/03/22*** ( SET BAKER EXTENDED REACH CBP) PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/ WELLTEC 3-1/8" TRACTOR/SHORTY SETTING TOOUBAKER EXTENDED REACH CBP (MAX OD 3.19") MAX OAL 40.8'. SET BAKER EXTENDED REACH CBP (3.19" OD, 10 RATED, CLUTCH TOP & BOTTOM) @ 15300' MD CCL TO MID ELEM 12.4' CCL STOP DEPTH 15287.6' WELL READY FOR LINER PRESSURE TEST LAY DOWN FOR THE NIGHT 11/4/2022 ***CONTINUE JOB ON 11/05/22*** T/1/0= 73/1465/VAC TEMP= S/I (LRS UNIT 42) **SWELL PACKER SET W/ WELL TECH** PUMPED 1.5 BBS 60/40 METH DOWN IA TO MAINTAIN POSITIVE DIFFERENTIAL PRESSURE. PUMPED 27 BBLS 60/40 DOWN TBG TO ASSIST IN 11/4/2022 SETTING THE SWELL PACKER. BLED TBG TO 140 PSI. BLEED IA TO 250 PSI ***JOB CONTINUED FROM 11/04/2022*** OBJECTIVE: SHIFT SLV'S WAIT ON WELLTEC TO GET SHIFTING TOOL READY TO RIH. DURING THE SHIFTING TOOL FUNCTION TEST AT SURFACE, SHIFTING GRIPPER KEYS WERE OVER EXTENDED AND SHEARED OUT OF THE TOOL. *** JOB CONTINUE ON 11/06/22*** 11 /5/2022 Daily Report of Well Operations PBU Z-223 ***JOB CONTINUED FROM 11/05/2022*** OBJECTIVE: SHIFT SLV'S PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/ WELLTEC 3-1/8" TRACTOR/STROKER/SHIFTING TOOL 55' OAL. ATTEMPT TO OPEN NCS SLV #1 @ 15253' MD. WELLTEC STROKER TOOL NOT RESPONDING. ABLE TO TRACTOR & EXPAND KEY PADS BUT NOT STROKE. WELLTEC TROUBLESHOOT & DETERMINES IS A DOWNHOLE TOOL ISSUE. POOH. LAY DOWN FOR THE NIGHT ***JOB CONTINUE ON 11/07/2022*** 11 /6/2022 T/I/O= 250/250/0 TEMP=SI (Assist Eline w/ Injectivity test RU Standby for eline Rig 11/6/2022 down. FWHP's=250/250/0 ***CONTINUED JOB FROM 11/06/22*** OBJECTIVE: SHIFT SLV'S PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/ WELLTEC 3-1/8" TRACTOR/STROCKER/SHIFTING TOOL 55" MAX OAL OPEN SLV #1. GOOD WELLTEC & CCL INDICATION. NO PRESSURE CHANGE. INJECTIVITY 0.4 BPM @ 2500psi & SLOWLY CLIMBING. 11 bbls away. OPEN SLV#2. GOOD WELLTEC & NO CCL INDICATION. NO PRESSURE CHANGE. INJECTIVITY SAME AS SLV #1. OPEN SLV#3. GOOD WELLTEC & NO CCL INDICATION. NO PRESSURE CHANGE. INJECTIVITY SAME AS SLV #1. OPEN SLV#4. GOOD WELLTEC & CCL INDICATION. NO PRESSURE CHANGE. INJECTIVITY SAME AS SLV #1 OPEN SLV#6. GOOD WELLTEC & CCL INDICATION. NO PRESSURE CHANGE. INJECTIVITY SAME AS SLV #1 OPEN SLV#7. IN PROGRESS ***JOB CONTINE ON 11/08/2022*** 11/7/2022 T/I/O= 351/317/0. LRS 72 Assist E/L (PROFILE MODIFICATION). E/L shifted sleeve #1. Pumped 11 bbls to establish injection of 0.4 bpm at 2450 psi. Pumped 20 bbls total down tbg to assist E-line 11/7/2022 *** job continued to 11-08-22*** Daily Report of Well Operations PBU Z-223 ***CONTINUED JOB FROM 11/07/22*** OBJECTIVE: SHIFT SLV'S ATTEMPT TO OPEN SLV #7 WITH NO SUCCESS. APPEARS WELLTEC GRIPPER PADS ARE SLIDING. ATTEMPT TO OPEN SLV #10 WITH NO SUCCESS. APPEARS WELLTEC GRIPPER PADS ARE SLIDING. DECISION TO POOH & CHECK WELLTEC GRIPPER PADS. AT SURFACE BOTH PADS ARE WORN DOWN. INSTALL NEW GRIPPER PADS & RE -RUN WELLTEC TRACTOR, STROKER & SHIFTING TOOL. ATTEMPT TO OPEN SLEEVE #7 MULTIPLE TIMES WITH NO SUCCES. MOVE UP TO SLV #10. ATTEMP TO OPEN SLEEVE #10 MULTIPLE TIMES WITH NO SUCCES. MOVE UP TO SLV #12. OPEN SLV#12. GOOD WELLTEC INDICATION. INJECTIVITY 2 BPM @ 860 psi 9 bbls away, AFTER OPEN THE SLEEVE #12 TRIED TO TRACTOR BACK DOWN TO SLEEVE #10 BUT WE COULDN'T PASS THROUGH SLEEVE #12. MOVE UP TO SLEEVE#14. ATTEMPT TO OPEN SLEEVE #14 MULTIPLE TIMES WITH NO SUCCESS. MOVE UP TO SLEEVE #16. ATTEMPT TO OPEN SLEEVE#16 WITH NO SUCCESS. GRIPPER PADS ARE SLIDING. DECISION TO POOH & CHECK WELLTEC GRIPPER PADS ***JOB CONTINED ON 11/09/2022*** 11/8/2022 ***job continued from 11-07-22*** Assist E/L with Sliding Sleeves. Call off to freeze 11/8/2022 protect while they RIH. T/I/O= 497/328/0 LRS 72 Assist E-Line (PROFILE MODIFICATION). Continued from 11/8/2022 earlier today. Pumped 19 bbls DSL to assist E-line ***job continued to 11-09-22*** ***JOB CONTINUED FROM 11/08/22*** OBJECTIVE: SHIFT SLV'S CONTINUED POOH. WELLTEC GRIPPER PADS SHOW WEAR ON THEM. DECISION TO RIG DOWN. ***JOB NOT COMPLETE / TURN WELL OVER FOR INJECTION*** 11 /9/2022 11/9/2022 ***job continued from 11-08-22*** RDMO T/I/0 = 1130/920/640. Temp = 1180. IA FL (pre AOGCC MIT). No AL. IA FL @ surface. 11/13/2022 SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:30 T/I/O/=1188/1011/760 (MIT -IA AGOCC) Witnessed by (Sully Sullivan) Pumped .5 bbls to get to1900 Psi.. Loss 41 Psi in 15 min. Loss 4Psi in 30 min. Bleed back .5 11/15/2022 lbbls Final T/1/0=1191/500/757 WELLHEAD = ACTUATOR = OKB. ELEV = REF ELEV = 82.66' BF. ELEV = -58.66' KOP = Max Angle = 97" @ 12028' Dahim MD = 4797' Datum TVD = '4400' COND, 19-58' CSG. 47#. TXP BTC. ID = 8.681' 1 Minimum ID=3.813"@2699' 4-1/2" HES X NIPPLE 7' TIEBACK, 260, L-80 BTC, .0383 bpf, ID = 6276' 4-12' TBG, 12.6#, L-80 VT, .0152 bpf, ID = 3.958' 4204' 7- LNR, 26#, L-80 H563, .0383' bpf, ID = 6.276' 4208' 9-5/8• CSG, 40#, L-80 TXP BTC, ID = 8.835' 6220' 4-12" WELLTEC SWELL PACKERS NO DEPTH O/C DATE 8 6227 S 082422 7 7733 S 082422 6 8265 S 082422 5 10175 S 082422 4 10762 S 082422 3 11840 S 082422 2 12699 S 082422 1 M17 S 082422 O=OPEN C=CLOSED BKR EXT RANGE CBP(11/0422) I— 15300' PBTD 15349' 4-12' LNR, 12.6#, L-80 JFE BEAR, 1639V .0152 bpf, I D = 3.958' Z-223 SAFETY NOTES: WELL ANGLE > 70" 0 6654'. 2282' —i93/8' HES CEMENTER 2599' 4-12' HES X NIP, ID = 3.813' GAS LIFT MANDRELS ST I MD I TVD I DEVI TYPE IVLVILATCHIPORTI DATE 3938' �9-5/8' X 7' SLZXP UP W/TIEBACK SLEEVE, ID=6.180' 3g8g 4-12' HES X NIP, ID = 3.813' 4058' 7- X 4-12' TNT PKR, ID = 3.856' 4134' 4-12' HES X NIP, ID = 3.813' 4204' 4-12- MULESHOE, ID = 3.958- A9� 7•XA-1/9•Xn In=R97R- 4-1/2" NCS FRAC SLV. ID = 3.958" NO DEPTH O/C DATE 23 4898 C 0824/22 22 5390 C 0824/22 21 5885 C 0824/22 20 6406 C 0824/22 19 6901 C 0824/22 18 7393 C 0824/22 17 8409 C 082422 16 8902 C 0824/22 15 9393 C 0824/22 14 9992 C 0824/22 13 10436 C 0824/22 12 10540 O 11/08/22 11 10944 C 0824/22 10 11359 C 0824/22 9 11771 C 0824/22 8 12139 C 0824/22 7 12243 C 0824/22 6 12845 C 0824/22 5 13298 C 0824/22 4 13775 C 0824/22 3 14307 C 0824/22 2 14761 C 0824/22 1 15253 O 11/07/22 O=OPEN C=CLOSED DATE REV BY COMMENTS DATE REV BY COMMENTS 08/30/22 IRIG INITIAL WELLBORE 09/0622 JMD UPDATED WBS 0911222 WR/JMD FINAL ODE APPROVAL 102022 TFA/JMD GLV C/O 092322 1111622 TFA/JMD SET CBP & SHIFTED SLV ORION UNIT WELL: Z-223 PERMIT No: 222-080 API No: 50-029-23720-00 T11 N, R12E, 4294' FS L & 272 Hileolp North Slope, LLC DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : RO P , A G R , D G R , A B G , E W R , A D R M D & T V D No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 10 / 5 / 2 0 2 2 62 1 1 1 6 8 1 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U Z - 2 2 3 A D R Qu a d r a n t s A l l C u r v e s . l a s 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 10 6 1 6 8 5 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U Z - 2 2 3 L W D Fi n a l . l a s 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 G e o s t e e r i n g E O W Lo g . e m f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 G e o s t e e r i n g E O W Lo g . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 C u s t o m e r S u r v e y . x l s x 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 G e o s t e e r i n g E n d o f W e l l R e p o r t . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 P o s t - W e l l Ge o s t e e r i n g X - S e c t i o n S u m m a r y . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 P o s t - W e l l Ge o s t e e r i n g X - S e c t i o n S u m m a r y . p p t x 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 G e o s t e e r i n g E O W Lo g _ 1 5 0 . t i f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 G e o s t e e r i n g E O W Lo g _ 3 0 0 . t i f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l M D . c g m 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l T V D . c g m 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ D e f i n i t i v e S u r v e y Re p o r t . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ d e f i n i t i v e s u r v e y r e p o r t . t x t 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ G I S . t x t 37 1 0 2 ED Di g i t a l D a t a Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 1 o f 6 PB U Z - 2 2 3 L W D Fi n al. l as DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ P l a n . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ S u r v e y s . x l s x 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : Z - 2 2 3 _ V S e c . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l M D . e m f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l T V D . e m f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ A D R _ I m a g e . d l i s 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ A D R _ I m a g e . v e r 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l M D . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l T V D . p d f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l M D . t i f 37 1 0 2 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : P B U Z - 2 2 3 L W D F I n a l T V D . t i f 37 1 0 2 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 89 8 1 9 4 3 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : L - 1 1 2 _ 0 6 - J a n - 23 _ M a i n U p P a s s _ 3 0 f p m . l a s 37 4 3 9 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 89 7 9 9 4 3 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : L - 1 1 2 _ 0 6 - J a n - 23 _ R e p e a t U p P a s s _ 3 0 f p m . l a s 37 4 3 9 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ L - 1 1 2 _ 0 6 - J a n - 23 _ M e m o r y R a d i a l C e m e n t B o n d L o g . p d f 37 4 3 9 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ L - 1 1 2 _ 0 6 - J a n - 23 _ M e m o r y R a d i a l C e m e n t B o n d L o g . t i f 37 4 3 9 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 89 8 1 9 4 3 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : L - 1 1 2 _ 0 6 - J a n - 23 _ M a i n U p P a s s _ 3 0 f p m . l a s 37 4 4 0 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 89 7 9 9 4 3 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : L - 1 1 2 _ 0 6 - J a n - 23 _ R e p e a t U p P a s s _ 3 0 f p m . l a s 37 4 4 0 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ L - 1 1 2 _ 0 6 - J a n - 23 _ M e m o r y R a d i a l C e m e n t B o n d L o g . p d f 37 4 4 0 ED Di g i t a l D a t a DF 1/ 1 1 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ L - 1 1 2 _ 0 6 - J a n - 23 _ M e m o r y R a d i a l C e m e n t B o n d L o g . t i f 37 4 4 0 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 32 6 0 3 5 2 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 4 0 - d n . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 35 2 3 3 2 8 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 4 0 - u p . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 32 8 6 3 5 4 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 6 0 - d n . l a s 37 5 4 4 ED Di g i t a l D a t a Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 2 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s DF 3/ 8 / 2 0 2 3 35 4 6 3 2 8 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 6 0 - u p . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 32 8 0 3 5 3 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 8 0 - d n . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 35 3 8 3 2 9 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 8 0 - u p . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 15 2 9 3 5 7 7 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 8 0 - u p 2 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 15 2 7 0 5 8 0 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ 0 8 0 - u p 3 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 4 2 5 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ R I H 0 1 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 25 9 3 2 6 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ R I H 0 2 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 32 9 0 5 4 4 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ R I H 0 3 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 57 5 0 1 5 2 7 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ T r a c t o r - d n . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 57 7 6 1 5 2 7 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ T r a c t o r - d n 2 . l a s 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ I P R O F _ 2 8 F E B 2 3 . p d f 37 5 4 4 ED Di g i t a l D a t a DF 3/ 8 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ i m g . t i f f 37 5 4 4 ED Di g i t a l D a t a DF 6/ 1 3 / 2 0 2 3 E l e c t r o n i c F i l e : P B U _ Z - 22 3 _ I P R O F _ 2 8 F E B 2 3 _ R e p o r t - V 1 . p d f 37 7 4 2 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 48 5 8 1 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ B a s e l i n e . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 0 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 2 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 4 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 6 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 3 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s DF 1/ 7 / 2 0 2 5 0 8 4 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 8 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 0 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 2 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 4 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 6 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 0 8 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 8 0 0 . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 58 4 1 3 7 8 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ W a r m B a c k - 0 1 H r . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 58 3 2 3 7 8 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ W a r m B a c k - 0 3 H r s . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 58 3 2 3 8 8 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ W a r m B a c k - 0 6 H r s . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 58 4 2 3 7 9 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ W a r m B a c k - I m m e d i a t e . l a s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 . p d f 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ i m g . t i f f 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ R e p o r t . p d f 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 0 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 2 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 4 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 6 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 4 8 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 4 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 8 / 2 9 / 2 0 2 2 Re l e a s e D a t e : 6 / 2 3 / 2 0 2 2 DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 0 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 2 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 4 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 6 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a DF 1/ 7 / 2 0 2 5 E l e c t r o n i c F i l e : P B U _ Z - 2 2 3 _ W F L - RM T 3 D _ 1 5 D E C 2 4 _ s t o p - 5 8 0 0 . d l i s 39 9 2 6 ED Di g i t a l D a t a Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 5 o f 6 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 3 7 2 0 - 0 0 - 0 0 We l l N a m e / N o . PR U D H O E B A Y U N O R I N Z - 2 2 3 Co m p l e t i o n S t a t u s WA G I N Co m p l e t i o n D a t e 8/ 2 9 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 8 0 0 Op e r a t o r Hi l c o r p N o r t h S l o p e , L L C MD 16 8 5 5 TV D 48 7 6 Cu r r e n t S t a t u s WA G I N 5/ 1 / 2 0 2 5 UI C Ye s Co m p l i a n c e R e v i e w e d B y : Da t e : Th u r s d a y , M a y 1 , 2 0 2 5 AO G C C P a g e 6 o f 6 M. G u h l 5/ 1 / 2 0 2 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-223 PRUDHOE BAY UN ORIN Z-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 Z-223 50-029-23720-00-00 222-080-0 G SPT 3491 2220800 3000 1930 1936 1940 1932 0 0 6 6 REQVAR P Sully Sullivan 10/6/2024 test to MAIP (3000psi) psi per AIO 26B.008 every 2 years 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN Z-223 Inspection Date: Tubing OA Packer Depth 7 3264 3102 3076IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009100450 BBL Pumped:1.6 BBL Returned:1.3 Friday, January 10, 2025 Page 1 of 1 MEU 5(9,6(' 7\SH,QMHFWLRQFKDQJHGWR**DV 9 9 9 9 9 9 9 99 999 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 13:04:44 -09'00' 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: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-223 PRUDHOE BAY UN ORIN Z-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 Z-223 50-029-23720-00-00 222-080-0 W SPT 3491 2220800 3000 1930 1936 1940 1932 0 0 6 6 REQVAR P Sully Sullivan 10/6/2024 test to MAIP (3000psi) psi per AIO 26B.008 every 2 years 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN Z-223 Inspection Date: Tubing OA Packer Depth 7 3264 3102 3076IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009100450 BBL Pumped:1.6 BBL Returned:1.3 Friday, December 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 999 9 9 9 9 9 AIO 26B.008 James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 11:07:00 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/08/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230308 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 09-09A 50029202320100 222157 2/19/2023 HALLIBURTON COILFLAG-RBT PBU 09-43A 50029220780100 222156 3/4/2023 HALLIBURTON RBT PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON IPROF PBU 11-40 50029235530000 215122 2/20/2023 READ MULTIPLEARRAYPRODUCTION PROFILE Please include current contact information if different from above. PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON IPROF Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230111 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 05-30 50029222130000 191115 1/2/2023 HALLIBURTON RMT3D PBU 15-07D 50029211660400 215158 12/29/2022 HALLIBURTON RMT3D PBU K-20C 50029225550300 208049 1/2/2023 HALLIBURTON RBT PBU L1-13 50029235630000 216003 1/4/2023 HALLIBURTON RMT3D PBU Z-223 50029237200000 222080 12/22/2022 HALLIBURTON WFL-TMD3D-RMT3D PBU L-112 50029231290000 202229 1/6/2023 READ MemoryRadialCementBondLog Please include current contact information if different from above. By Meredith Guhl at 3:24 pm, Jan 11, 2023 T37435 T37436 T37437 T37438 T37439 T37440 PBU Z-223 50029237200000 222080 12/22/2022 HALLIBURTON WFL-TMD3D-RMT3D Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.11 15:32:54 -09'00' From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Date:Thursday, December 22, 2022 9:55:30 AM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, December 21, 2022 2:56 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Oliver, Your request to continue water injection while evaluating the log and processing the administrative approval is approved. Regards Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, December 21, 2022, 2:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Chris, Z-223 was placed on water injection for its 60-day evaluation period on 11/11/22. As discussed we are currently conducting the WFL and temperature warm back log on the well and dependent on favorable results of the WFL we are planning to submit an AA request for WAG injection. In the meantime we request AOGCC permission to keep the well on water injection while the AA request is submitted and processed. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, September 29, 2022 1:09 PM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL] RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Wyatt, Thank you for meeting with us and the good discussion on this well. Plan as detailed below is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, September 22, 2022 3:25 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Hello Chris and Mel, Thank you again for meeting last week to discuss PBU well Z-223 (PTD #222080). Per our discussion Hilcorp would like to request approval to put Z-223 on injection and then obtain a waterflow log for submission with a formal AA request for continued injection. Background Z-223 (PTD#222080) was recently drilled as a Schrader Bluff WAG injector. While running the 4.5” injection liner to bottom, rig encountered issues getting liner down. After washing and reaming and rotating liner, liner shoe was eventually worked from ~ 9500’ down to 15391’ MD at which point no further progress could be made and liner was set short of the 17,549’ MD target. Current wellbore schematic is attached for reference. This placed the liner top packer and subsequently the injection packer high with injection packer set at 4058’ MD roughly 1432’ MD /1087’ TVD above the planned and permitted set depth of 5490’ MD. A packer depth of 4058’ MD places the bottom of the monitorable annulus above the top of the Schrader Bluff injection zone at ~ 5430’ MD/4544’TVD and into the Ugnu formation. The top of the Ugnu formation is at ~3670’ MD. Request Hilcorp requests to place Z-223 on water injection for a period of two months for internal mechanical integrity testing and stabilized external mechanical integrity logging at and above the top of injection zone. After confirmation of internal and external mechanical integrity, Hilcorp would make a formal request for an administrative approval to continue injection with additional cyclical logging in place to confirm long term isolation of injection fluids to the Schrader Bluff formation. 2 month request is for water only injection, additional data regarding WAG cycling and the relative frequency of potential gas vs water injection would be included with AA request. Mitigations 9-5/8” casing tested good to 2500 psi on 8/14/22 confirming integrity of the casing below liner top packer, ensuring current isolation of injected fluids to below the 9-5/8” casing shoe. Upper three sliding sleeves will be left closed. Uppermost injection from the liner will occur at 6406’ MD injection sleeve within the lower OBC sand in Schrader Bluff formation, ~ 970’ MD past the top of the Schrader Bluff. Daily pressure and injection rate monitoring to identify any unexplained drop in pressure or increase in injection rate indicating possible out of zone injection to shallower zones. An open hole metal expandable packer set at 6227’ MD below the 9-5/8” casing shoe providing additional isolation of injection fluids to the open hole section of the OBC sand within the Schrader Bluff formation. Initial and subsequent two year cyclical water flow logging with temperature warmbacks will be proposed from lowermost wireline accessible depth of ~5550’ MD (below the top of the Schrader Bluff at ~5430’ MD) to above the tubing packer at ~4058’ MD. Stop counts would be taken at least every ~200’ confirming no upward flow of water behind the 4.5” injection liner or behind the 9-5/8” casing. Following stopcounts and dynamic temperature pass, well would be SI and warmback temperature trends will be taken to further confirm consistent temperature gradient/trend with no “bulbs” indicating injection through 9-5/8” casing. Hilcorp would include an interpretive report highlighting WFL/Temp logging results, confirmation of integrity and addressing any anomalies observed. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 theonward 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, January 3, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-223 PRUDHOE BAY UN ORIN Z-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/03/2023 Z-223 50-029-23720-00-00 222-080-0 W SPT 3491 2220800 1500 1192 1192 1190 1192 757 851 844 842 INITAL P Sully Sullivan 11/15/2022 90 degrees Diesel was used for test. Well was online for 6 days prior to MIT 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UN ORIN Z-223 Inspection Date: Tubing OA Packer Depth 1002 1897 1856 1852IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS221114162447 BBL Pumped:0.5 BBL Returned:0.5 Tuesday, January 3, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-223 PRUDHOE BAY UN ORIN Z-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 Z-223 50-029-23720-00-00 222-080-0 N SPT 3491 2220800 1500 241 325 323 322 0 0 0 0 OTHER P Kam StJohn 10/13/2022 MIT-I/A required as Per PTD# 2220800 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UN ORIN Z-223 Inspection Date: Tubing OA Packer Depth 0 3756 3594 3570IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221013182753 BBL Pumped:2.9 BBL Returned:1.5 Tuesday, December 13, 2022 Page 1 of 1 MIT-I/A required as Per PTD# 2220800 7. 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 Z-223 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 222-080 50-029-23720-00-00 16855 Conductor Surface Tieback Production Liner 4876 80 2238 3924 11453 15300 20" X 34" 9-5/8" 7" 7" x 4-1/2" 4826 27 - 107 26 - 6220 24 - 3948 3938 - 15391 27 - 107 26 - 4700 24 - 3389 3380 - 4830 None 770 4760 5410 5410 / 7500 15300 2280 6870 7240 7240 / 8430 4898 - 15253 4-1/2" 12.6# L-80 22 - 4204 4228 - 4824 Structural 4-1/2" HES TNT Perm Packer 4058, 3491 4058 3491 Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, SCHRADER BLUFF OIL, ORION Dev Area 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 0028262, 0047450 22 - 3626 N/A N/A 2734 3642 750 150 1342 1395 N/A 13b. Pools active after work:SCHRADER BLUFF OIL, ORION Dev Area No SSSV Installed 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 Anne Prysunka at 4:04 pm, Dec 22, 2022 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2022.12.21 16:40:33 -09'00' Stan Golis (880) DSR-1/3/23 RBDMS JSB 122922 WCB 11-26-2024 ACTIVITY DATE SUMMARY 12/5/2022 ** FREEZE PROTECT for E-LIne ** Freeze protected FL with 6 bbls 60/40 methonal and freeze protected TBG with 38 bbls 60/40. E-Line on well at time of departure. 12/5/2022 ***WELL INJECTING ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP MU & CHECK TRACTOR/GR/CCL/SWITCH TOOLSTRING TO BE READY FOR MORNING ***WELL LEFT SHUT IN*** JOB CONTINUED 12/6/2022 12/6/2022 JOB CONTINUED FROM 12/5/2022 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1 7/16" CHD (1" FN), ALTUS SWIVEL, RELEASE DEVISE, 2.5" TRACTOR, GR/CCL, 2" SWITCH GUN STRING (49' OAL) SHOT 2" 0 DEG PHASE GUNS LOADED 5 SPF W/ 6.5 GRAM RAZOR CHARGES PERF DEPTHS=14,680'-14,682.8', 14,230'-14,231.8', 13,630'-13,631.8', 13,027'- 13,030' CORRELATED TO LNR TALLY DATED 8/24/2022 ***WELL LEFT SHUT IN*** JOB CONTINUED ON 12/7/2022 12/7/2022 ***CONTINUED FROM 12/6/2022 WSR*** TRACTOR FROM 5750' MD - 11150' MD, CORRELATE TO TUBING TALLY 8/26/22. 8' DISCREPENANCY IN JT # 128 PERF W/ 3' X 2" GEO RAZORS SWITCH GUNS AT 11430'-11433', 10980'-10983', 10070'-10073' & 9080'-9083' MD. BOTTOM GUN DID NOT FIRE, WILL PERFORATE FROM 11430'-11433' WITH 4 REMAINING INTERVALS TOMMORROW. ***CONTINUED ON 12/8/22 WSR*** 12/8/2022 ***CONTINUED FROM 12/7/2022 WSR*** REBUILD AND RECONFIGURE SWITCH GUN TO COVER LOWEST INTERVAL AND UPPER FOUR INTERVALS. ***CONTINUED ON 12/9/2022 12/9/2022 ***CONTINUED FROM 12/8/2022 WSR*** PT PCE 250LP-3500HP TRACTOR FROM 5750' TO 11950' MD. CORRELATE TO TUBING TALLY DATED:8/26/22 GUN#1 PERF FROM 11430' - 11433' MD, CCL TO TS=20.2', CCL STOP DEPTH=11409.8' MD. 6 SPF, 0 PHASED GUN#2 PERF FROM 8330' - 8332.8' MD, CCL TO TS=15.9', CCL STOP DEPTH=8314.1' MD. 5 SPF, 0 PHASED GUN#3 PERF FROM 7652' - 7654.8' MD, CCL TO TS=11.6', CCL STOP DEPTH=7640.4' MD. 5 SPF, 0 PHASED GUN#4 PERF FROM 7080' - 7082.8' MD, CCL TO TS=7.4', CCL STOP DEPTH=7072.6' MD. 5 SPF, 0 PHASED GUN#5 PERF FROM 6468' - 6470.8' MD, CCL TO TS=3.1', CCL STOP DEPTH=6464.9' MD. 5 SPF, 0 PHASED. GEO DYNAMICS RAZOR 6.5 GRAM CHARGES RUN. ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU Z-223 PERF FROM 8330' - 8332.8' MD PERF FROM 11430' - 11433' MD PERF FROM 7080' - 7082.8' MD PERF FROM 7652' - 7654.8' MD All perfed intervals are correctly shown on the WBS below. -WCB PERF FROM 6468' - 6470.8' MD 10980'-10983', 10070'-10073' & 9080'-9083' MD PERF DEPTHS=14,680'-14,682.8', 14,230'-14,231.8', 13,630'-13,631.8', 13,027'- 13,030' 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Thursday, October 13, 2022 1:29 PM To:PB Wells Integrity Cc:Regg, James B (OGC) Subject:RE: Hilcorp (PBU) September 2022 MIT Forms Attachments:MIT PBU P-24 09-16-22.xlsx; MIT PBU Z-223 09-16-22 Revised.xlsx; MIT PBU S-106 09-18-22 Revised.xlsx Andy, Attached are revised reports as follows: MIT PBU P 24 09 16 22 Added the trailing zero to PTD #1970540 MIT PBU Z 223 09 16 22 moved the Waived remarks to the Notes and changed the test result to I MIT PBU S 106 09 18 22 changed the test psi to the required pressure of 4000 and moved the extended time to the Notes Please update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907 793 1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Saturday, October 1, 2022 2:10 PM To:Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc:Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject:Hilcorp (PBU) September 2022 MIT Forms All, Attached are the completed AOGCC MIT forms for the test performed by Hilcorp in September 2022. Well: PTD: Notes NK 13 1961340 4 year MIT IA 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. revised reports MIT PBU Z 223 09 16 22 2 P 24 1970540 4 year MIT IA S 106 2010120 CMIT TxIA per Sundry 322 477 W 30 1881360 2 year MIT T & CMIT TxIA per CO 736 WGI 09 2061460 4 year MIT IA Z 223 2220800 CMIT TxIA to satisfy witnessed rig MIT IA per PTD 222 080. Test pressure did not meet pressure criteria o Please reply with questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659 5102 M: (307)399 3816 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. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220800 Type Inj N Tubing 0 3500 3386 3346 Type Test P Packer TVD 3490 BBL Pump 2.7 IA 0 3510 3397 3355 Interval O Test psi 3500 BBL Return 2.7 OA 0 0 0 0 Result I Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / Z Pad Ryan Holt 09/16/22 Notes:AOGCC CMIT-TxIA to satisfy witnessed rig MIT-IA per PTD 222-080. Test pressure did not meet pressure criteria outlined in PTD and will be re-done before well is made Operable. Waived Austin McLeod. Notes: Notes: Notes: Z-223 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0916_MIT_PBU_Z-223 CMIT-TxIA Test pressure did not meet pressure criteria outlined in PTD 3397 3355 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov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essie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.05 13:06:12 -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:Monty Myers To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC);Joseph Engel;Denali Kemppel;Aras Worthington Subject:PTD( 222-0800) PBU Z-223 Docket Number OTH-22-029 Date:Tuesday, September 27, 2022 2:42:20 PM Attachments:Diverter Hilcorp Innovation 08-04-22 (incorrect).pdf 8-5-22 PBW Z-223 Drilling #2 Trouble shoot MWD.pdf Diverter Hilcorp Innovation 08-04-22 (corrected).pdf Jim, This email is in response to the NOV Hilcorp received on September 14th, 2022. Docket Number OTH-22-029 In review of the AOGCC report submitted and the actual data from the Drilling report dated August 5th 2022, for the diverter function test, it appears that the numbers were transposed between the 2 reports. (I have attached both reports for reference with highlights). On the 8.5.2022 drilling report, it states that the Annular closed in 13 seconds and the Knife valve opened in 10 seconds, which would actually be a passing test and we would be in compliance with 20 AAC 25.035(c)(2)(B). On the AOGCC Diverter Systems Inspection Report the numbers were transposed into the incorrect boxes. I apologize for the confusion on this report and will communicate to the field the importance of double checking that the correct numbers are in place for future reports. I have also attached a corrected AOGCC report for your records if you would like to replace the incorrect one with it. Sincerely, Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) 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. Date: 8/4/2022 Development: X Exploratory: Drlg Contractor: Rig No. Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220800 Rig Phone: Rig Email: MISCELLANEOUS:DIVERTER SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P ACCUMULATOR SYSTEM:Diverter Size: 13 5/8 in. Systems Pressure: 3,100 psig P Hole Size: 12 1/4 in. Pressure After Closure: 2,000 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 16 Seconds P Vent Line(s) Length: 173 ft. P Full Recharge Time:48 Seconds P Closest Ignition Source: 81 ft. P Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 155 ft. P Avg. Pressure: 2325 psig P Accumulator Misc: NA Vent Line(s) Anchored: P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time:13 sec P Mud System Misc: 0 NA Knife Valve Open Time:10 sec P Diverter Misc: NA GAS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 0.5 hrs Non-Compliance Items: 0 Remarks: Submit to: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report GENERAL INFORMATION WaivedHilcorp *All Diverter reports are due to the agency within 5 days of testing* jlott@hilcorp.com TEST DATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Tested with 5" DP. 0 James Lott 0 670-3094 TEST DETAILS jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU Z-223 Form 10-425 (Revised 04/2018)Diverter Hilcorp Innovation 08-04-22 AFE DAYS 2 ENGINEERPPG 17300 LAST SHOE TEST DAYS SINCE SPUD FIELD SUPERVISOR Joe EngelJ Lott / O Amend ROTATIONAL 221 STROKES MUD CLEAN DERRICK #1 SHAKER #2 SHAKER #1 120/120/12 120/120/12 RP TOT CUM HR SLACK OFF JAR HOURS MUD MOTOR HRS TORQUE PICK UP DRILL STRING CAPACITY SPM for PSI 1/2/3 96 DEPTH Pump # 1 962 SLOW PUMP DATA @ PSI 1 PSI 2 PSI 3 Eff % www.wellez.com WellEz Information Management LLC ver_011821rw Partly Cloudy TOTAL $40,678 M/V TEMP DIESEL FUNC. DUE TOTAL 50 M/V PRES COND23M/V SEAS 47BOATS WIND 8 MPH MUD $40,678 $40,678 8/18/2022 SERVICE DAILY CUM 25 Misc 8/4/2022 HEC 2 %Pb NEXT TEST DUE RIG 560 GAL BOP TESTED PERSONNEL ON BOARD IMP FORCE WEATHER JET VEL 144.752 HRS H.S.I. FT/SEC HEAVY H2O DRKS GAL CENT HRS SKS 1.57364 HP/IN² FUEL USED 443 GAL BRDT HRS HHP BIT 185.373 HP BARITE GAL DRK 2 d Pb 166.779 PSI TUG FUEL GAL SOLIDS EQUIPMENT NOZ.AREA .8399 IN² POT. WATER TOT WEIGHT (LBS)51010 DEPTH 221 FT CREW BOAT FUEL ES LIQ MUD TOTAL LENGTH (FT) HYDRAULICS INNER DULL CHAR. FUEL 11775 GAL ADD (DIESELGAL) CUM HR BHA OUTER LOCATION 30.69 %LGS 1.5 LIME 5" D.P. GAUGE 5 4.276 6.5 2.75 74 AV DP CSG Cal 1500 Clwtr 53 AV DC 341.35 30 8.06 3.25 29.21 AV DP OP HLE 6.5" SLB Jars X/O 7.85 3.25 3.52 11 ea 5" HWDPClmud1500 8" NM FC 8.06 3.25 31.05 3 186.51 pH 0/0PF/MF 9.7 9.56 ROT. RPM 97.5 ANN VEL6 ea 5" HWDP 5 4000 DEPTH OUT Pm 0.15 8" EWR-M5 Collar 8.06 2.375 32.29 8" NM FC 31.91 HOURS 0.8399 221 DEPTH IN 107 TOTAL FT. MBT 25 SD %0.2 WOB AVG ROP 114 3X14 3X13 TFA POM 8" GWD Collar 7.84 3.5 WTR %96 3.5 8" TerraForce 1.5? 8 5 8" DM Collar 7.94 8" TM Collar 7.83 3.25 DESCRIPTION OD ID 12.25" K5M633 Hybrid 12.25 2.75 FEET OIL %1 HTHP 13.73 8.95 1.35 ADJSOL 3.0 SERIAL NO.5326698 SOLIDS 2.7 BHA# 1 NOZZLES CAKE 3 TYPE K5M633 Hybrid MFG.HughesAPI WL 7.6 SUR .PSI 425 425 GELS 74 / 110 / 160 SIZE 12.25 GAL/STK 1.96 1.96 YP 67 BIT NO.1 PV 32.0 TOP OF LINER @ SPM 5.00 5.00LINER SZ 97 97VISC350.0 88 WEIGHT 8.85 STROKE Quatro-1300LW Quatro-1300LW TEMP 71 MODEL White Star White Star DEPTH 221 18.25 MAKE 12 TIME 21:00 20 Insulated 129.5 Weld 107 ID NUMBER GPM SIZE GRADE WT CONN DEPTH DV TYPE Spud Mud DATA 380 MUD RECORD CASING RECORD PUMP 9.05 BPM SPILLS Zero Drill 12.25" Surface as per WP02. TRIP GAS SAFETY None ENVIRONMENTAL None Plan Next 24 Hr TOTAL 24.00 LITHOLOGY: MAX GAS B.G. GAS CON GAS 05:00 06:00 1.0 23:00 00:00 1.0 00:00 05:00 5.0 19:30 23:00 3.5 18:00 18:30 0.5 18:30 19:30 1.0 15:30 17:00 1.5 17:00 18:00 1.0 12:00 14:30 2.5 14:30 15:30 1.0 06:00 08:00 2.0 08:00 12:00 4.0 TIME LOG ELAPSED FROM TO TIME MD ANGLE AZIMUTH TVD DOG LEG Slide/ Drill ahead F/ 221' MD. DEPTH: MD/TVD ACTIVITY SUMMARY AT:6:00 HRS SURVEY: 221 PROGRESS / HRS $95,695 $314,548 $4,988 Slide Drill 8/5/2022 221 221 1 PROP. TD 26.46 83 STATE 907-670-3094 RIG PHONE DRLG Drilling SlideDrl COUNTY / PARISH WELL Hilcorp Energy Company DAILY DRILLING REPORT REPORT NO. LEASE WELL NO.DATE Cum Drill Cost AFE BUDGET $5,067,804 Cum Cmpl Cost PBW Z-223 ACTIVITY TYPE: RIG RKB to GL RKB to MSL Innovation Total D&C CostCum Job Cost $314,548 Alaska2 ADL0028262 PBW Z-223 Daily Job Cost AFE NO. 221-00062 ELEV GL 56.2 CloudyFORECAST SECTION N / S E / W $319,536 Continue N/U Diverter System. Install Trip nipple with spare air boot. Continue to work on Rig Acceptance Check list. Accept Rig at 08:00 Hrs. Install mouse hole in rotary table, lower Annular Pressure to 250 psi. Start P/U and Rack Back 5"DP Continue to P/U and Rack Back 5" DP. (99 Stds Total) Drift size = 3.125". P/U HWDP and Jars (9 stds). Open annular and L/D Mouse Hole. "Perform Diverter test. Test 5"" D.P. Start Press Acc 3,100 psi, after 2,000 psi. Annular close, 13 sec, Knife valve open, 10 sec. 200 psi recharge 16 sec, full charge 48 sec. 6 bottle average N2 average 2,325 psi, Witnessed waived by AOGCC Rep Austin Mcleod. Screw into Jt, Perform Drill Line inspection, hang blocks. Ton Miles 1,017, cut 13 wraps (81'). 2646' left on spool. 16561 ACC/TM. Calibrate blocks. PJSM Perform monthly sheave wobble EAM for blocks and crown sheaves. Inspect top drive carriage, good. Prep rig floor for BHA. Hold pre spud meeting with all personnel. Discussed anticipated gas hydrates, conductor broaching, rig evacuation, H2S, muster area, IP and fire safety. Roles and responsibilities during divert and desert. PJSM M/U 12.25" K5M633 Hybrid (0.8399 TFA) Bit and 8" TerraForce (Lobe 4/5-5.3stg) 1.5° Motor W/ X/O. Make first stand 5" 49.5# S-135 NC50 HWDP. Flood lines and check for leaks, good. PT mud line to 3,000 psi, good. PJSM Wash down and tag ice at 38' MD. Cont to wash down 300 gpm 230 psi 30 rpm Trq 800 ft/lb to 116' MD W/ 1-2k. Cont drilling 12.25" surface F/ 116' to 221' MD. Encountered dynamic losses at 118' MD (~160 BPH Dynamic) seeing heavy gravel, sand and wood at shakers. Lost 160 bbls while drilling. 350 gpm 280 psi on, 300-400 off, F/O 55%, 30 rpm, Trq 800-1.2k, WOB 1-4k, ROP 80-120 fph. P/U 46k SLK 50k ROT 49k. Jetting flow line as needed and at connection. PJSM BROOH F/ 221' to 38' MD CBU during first stand out of hole. No issues pulling into conductor. 350 gpm, 255 psi, 30 rpm, Trq 1k, P/U 42k SLK 44k ROT 43k. Bit had 2 minor outer chipped buttons. (RR) Hold pre spud meeting W/ new crew. PJSM M/U BHA to 12.25" Bit & 1.5° Motor, P/U 8" GWD, 8" DM, 8" EWR-M5 & 8" TM. RFO 1.5/8.09=66.75°. Download MWD. Cont P/U 8" NM FC to 158' MD. Wash down to 221' MD. Tagged fill at 213' MD (9'). 350 gpm 415 psi 30 rpm Trq 900 ft/lb. Kelly up and adjusted flow rates F/ 350 to 400 gpm attempting to get detection. Cleaned out beaver strainers and adjusting flow rates F/ 325 to 400 gpm seeing pulses W/ MWD but no detection. Rack back stand and carry scribe up string. M/U stand at 221’ MD. Check MP #1 at 315 gpm 345 psi and started to see detection. Shut and check MP #2 315 GPM 345 PSI and was able to get detection. Cycle MWD to get survey at 221’ MD. Daily disposal to G&I: 0 bbls, total= 0 bbls Daily H2O from Lake 2: 470 bbls, total= 470 bbls Daily Metal: 0# Total 0# Daily losses 160 bbls, total 160 bbls NU/ND BOPE Trips Trips Test BOP/WH/LOT/Csg Rig Service/Slip & Cut Rig Service/Slip & Cut Safety Meeting Trips Drilling Drilling Wash & Ream Trips ACTIVITY COMMENTS Circ & Cond Circ & Cond Miscellaneous . Annular close, 13 sec, Knife valve open, 10 sec. 200 Date: 8/4/2022 Development: X Exploratory: Drlg Contractor: Rig No. Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220800 Rig Phone: Rig Email: MISCELLANEOUS:DIVERTER SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P ACCUMULATOR SYSTEM:Diverter Size: 13 5/8 in. Systems Pressure: 3,100 psig P Hole Size: 12 1/4 in. Pressure After Closure: 2,000 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 16 Seconds P Vent Line(s) Length: 173 ft. P Full Recharge Time:48 Seconds P Closest Ignition Source: 81 ft. P Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 155 ft. P Avg. Pressure: 2325 psig P Accumulator Misc: NA Vent Line(s) Anchored: P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time:10 sec P Mud System Misc: 0 NA Knife Valve Open Time:13 sec P Diverter Misc: NA GAS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 0.5 hrs Non-Compliance Items: 0 Remarks: Submit to: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report GENERAL INFORMATION WaivedHilcorp *All Diverter reports are due to the agency within 5 days of testing* jlott@hilcorp.com TEST DATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Tested with 5" DP. 0 James Lott 0 670-3094 TEST DETAILS jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU Z-223 Form 10-425 (Revised 04/2018)Diverter Hilcorp Innovation 08-04-22 me:10 me:13 Prudhoe Bay Field / Schrader Bluff Oil Pool, Orion Dev Area By James Brooks at 2:12 pm, Sep 22, 2022 Completed 8/29/22 JSB RBDMS JSB 101322 2080' / 1853' G MDG DSR-10/14/22MGR05JUNE2023 for Monty Myers Joseph Engel (2493) 2022.09.22 13:26:28 -08'00' Joseph Engel (2493) NOTE: emails for variance to shallow liner top packer setting depth approved. - mgr CASING AND LEAK-OFF FRACTURE TESTS Well Name:PBU Z-223 Date:8/15/2022 Csg Size/Wt/Grade: Supervisor:Barber/Amend Csg Setting Depth:6220 TMD 4700 TVD Mud Weight:9.3 ppg LOT / FIT Press =660 psi LOT / FIT =12.00 ppg Hole Depth =6250 md Fluid Pumped=1.8 Bbls Volume Back =1.4 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->0 ->0 ->259 ->6134 ->4139 ->12 358 ->6216 ->18 584 ->8298 ->24 778 ->10 381 ->30 983 ->12 462 ->36 1199 ->14 531 ->44 1496 ->16 596 ->50 1735 ->18 665 ->56 1966 ->20 705 ->62 2199 ->22 ->68 2433 ->24 ->74 2688 ->26 -> Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0705 ->0 2688 ->1560 ->1 2683 ->2479 ->2 2681 ->3449 ->3 2680 ->4433 ->4 2679 ->5420 ->5 2677 ->6408 ->6 2676 ->7395 ->7 2675 ->8385 ->8 2674 ->9376 ->9 2674 ->10 367 ->10 2673 ->12 ->15 2670 ->14 ->20 2668 ->15 ->30 2663 9 5/8" 47#/40# L-80 2 4 6 8 10 12 14 16 18 20 6 12 18 24 30 0 100 200 300 400 500 600 700 800 900 1000 0 1020304050 Pr e s s u r e ( p s i ) Strokes (# of) LOT / FIT DATA CASING TEST DATA 705 560 479449433420408395385376367 26882683268126802679267726762675267426742673 2670 2668 2663 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 0 5 10 15 20 25 30 Pr e s s u r e ( p s i ) Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 8/3/2022 Rotate sub on stompers and walk over Z-223. Set down sub and retract stompers. Set outriggers and rig matts. Spot catwalk, shim and set down. Scope out cattle chute and set stairs. Spot pipe shed, mud and gen mod. NES released 18:00. Safe out stairs and landing. Hook up interconnects. Spot break shack & envirovac. Lay Herculite and cutting box. Swap to gen power @ 19:20. Work on rig acceptance check list. Prep and scope up derrick. Bridle down. Run steam and H2O around rig and check for leaks. Install cellar grating. Install MPD Pull off MPD head and L/D. N/U Tee and stack to speed head. Install knife valve. Install 16" diverter line. SIMOPS Work on rig acceptance checklist. Dress shakers. take on Spud Mud to pits. 8/4/2022 Continue N/U Diverter System. Install Trip nipple with spare air boot. Continue to work on Rig Acceptance Check list. Accept Rig at 08:00 Hrs. Install mouse hole in rotary table, lower Annular Pressure to 250 psi. Start P/U and Rack Back 5"DP Continue to P/U and Rack Back 5" DP. (99 Stds Total) Drift size = 3.125". P/U HWDP and Jars (9 stds). Open annular and L/D Mouse Hole. "Perform Diverter test. Test 5"" D.P. Start Press Acc 3,100 psi, after 2,000 psi. Annular close, 13 sec, Knife valve open, 10 sec. 200 psi recharge 16 sec, full charge 48 sec. 6 bottle average N2 average 2,325 psi, Witnessed waived by AOGCC Rep Austin Mcleod. Screw into Jt, Perform Drill Line inspection, hang blocks. Ton Miles 1,017, cut 13 wraps (81'). 2646' left on spool. 16561 ACC/TM. Calibrate blocks. PJSM Perform monthly sheave wobble EAM for blocks and crown sheaves. Inspect top drive carriage, good. Prep rig floor for BHA. Hold pre spud meeting with all personnel. Discussed anticipated gas hydrates, conductor broaching, rig evacuation, H2S, muster area, IP and fire safety. Roles and responsibilities during divert and desert. PJSM M/U 12.25" K5M633 Hybrid (0.8399 TFA) Bit and 8" TerraForce (Lobe 4/5-5.3stg) 1.5° Motor W/ X/O. Make first stand 5" 49.5# S-135 NC50 HWDP. Flood lines and check for leaks, good. PT mud line to 3,000 psi, good. PJSM Wash down and tag ice at 38' MD. Cont to wash down 300 gpm 230 psi 30 rpm Trq 800 ft/lb to 116' MD W/ 1-2k. Cont drilling 12.25" surface F/ 116' to 221' MD. Encountered dynamic losses at 118' MD (~160 BPH Dynamic) seeing heavy gravel, sand and wood at shakers. Lost 160 bbls while drilling. 350 gpm 280 psi on, 300-400 off, F/O 55%, 30 rpm, Trq 800-1.2k, WOB 1-4k, ROP 80-120 fph. P/U 46k SLK 50k ROT 49k. Jetting flow line as needed and at connection. PJSM BROOH F/ 221' to 38' MD CBU during first stand out of hole. No issues pulling into conductor. 350 gpm, 255 psi, 30 rpm, Trq 1k, P/U 42k SLK 44k ROT 43k. Bit had 2 minor outer chipped buttons. (RR) Hold pre spud meeting W/ new crew. PJSM M/U BHA to 12.25" Bit & 1.5° Motor, P/U 8" GWD, 8" DM, 8" EWR-M5 & 8" TM. RFO 1.5/8.09=66.75°. Download MWD. Cont P/U 8" NM FC to 158' MD. Wash down to 221' MD. Tagged fill at 213' MD (9'). 350 gpm 415 psi 30 rpm Trq 900 ft/lb. Kelly up and adjusted flow rates F/ 350 to 400 gpm attempting to get detection. Cleaned out beaver strainers and adjusting flow rates F/ 325 to 400 gpm seeing pulses W/ MWD but no detection. Rack back stand and carry scribe up string. M/U stand at 221’ MD. Check MP #1 at 315 gpm 345 psi and started to see detection. Shut and check MP #2 315 GPM 345 PSI and was able to get detection. Cycle MWD to get survey at 221’ MD. Daily disposal to G&I: 0 bbls, total= 0 bbls. Daily H2O from Lake 2: 470 bbls, total= 470 bbls. Daily Metal: 0# Total 0#. Daily losses 160 bbls, total 160 bbls. 8/5/2022 Slide/ Drill 12.25" Hole F/ 221' to 408' MD (407' TVD) Total 187' (AROP 31.2') 400 gpm, psi on 675, psi off 590, 0 rpm, TRQ on na, TRQ off na, wob 6-18k. ECD 9.68, MW in/out 8.9, Max Gas 15u. P/U 67k, SLK 59k, Jet flowline as needed. MWD pulsar cleaning up and able to read surveys. KOP 221' MD. Start build 3°/100. Still seeing heavy gravel, sand and slight wood at shakers. Lost 144 bbls dynamic losses slowing to zero at ~400' MD. Slide/ Drill 12.25" Hole F/ 408' to 1,045' MD (1014' TVD) Total 637' (AROP 106.2') 400 gpm, psi on 920, psi off 780, 40 rpm, TRQ on 3-5k, TRQ off 1.6k, wob 6-10k. ECD 10.7, MW in/out 9.15, Max Gas 15u. P/U 77k, SLK 74k, ROT 75k. Jet flowline as needed. Seeing heavy clay at shakers. Back ream 30'. End 3°/100 build at 781' MD Sliding ~35' a stand average DLS 3° inc. Last Gyro survey at 742' MD and MWD survey at 792' MD. Start 4.5°/100 build/turn at 781' MD. Slide/ Drill 12.25" Hole F/ 1,045' to 1,673' MD (1499' TVD) Total 628' (AROP 104.7') 400 gpm, psi on 1210, psi off 910, 40 rpm, TRQ on 6.5k, TRQ off 3.5k, wob 11-13k. ECD 10.73, MW in/out 9.4/9.45, Max Gas 15u. P/U 85k, SLK 71k, ROT 80k. Jet flowline as needed. Heavy clay at shakers. Back ream 30 Cont 4.5°/100 build/turn to 1,276' MD sliding 45-55' per stand average DLS 4° inc. Start tangent at 1,276' MD 36° inc 187° Azi. Perform maintenance slide as needed. Start increase MW F/ 9.25 to 9.35 at 1,300' MD. Slide/ Drill 12.25" Hole F/ 1,673' to 2,054' MD (1,821' TVD) Total 381' (AROP 63.5') 450 gpm, psi on 1290, psi off 1108, 50 rpm, TRQ on 6-8k, TRQ off 3.5k, wob 7-11k. ECD 10.32, MW in/out 9.5/9.55, Max Gas 15u. P/U 99k, SLK 73k, ROT 82k. Jet flowline as needed. Back ream 60'. At ~1,771' MD encountered heavy flocculated mud W/ heavy clay unloading at shakers reduce ROP and perform 4 clean up cycles (4 BU) for ECD's Initial 10.85 reduced to 10.29. Adding pretreat for hydrates. Distance to WP02: 0.54’, 0.47’ Low 0.26’ Left Daily disposal to G&I: 798 bbls, total= 798 bbls. Daily H2O from Lake 2: 720 bbls, total= 1190 bbls. Daily Metal: 0# Total 0#. Daily losses 144 bbls, total 304 bbls. 8/6/2022 Slide/ Drill 12.25" Hole F/ 2,054' to 2,687' MD (2,305' TVD) Total 633' (AROP 105') 500 gpm, psi on 1270, psi off 1150, 50 rpm, TRQ on 5-7k, TRQ off 6k, WOB 3- 8k. ECD 10.66, MW in/out 9.5+/9.6, Max Gas 569u. P/U 112k, SLK 78k, ROT 89k. Jet flowline as needed. Back ream 60'. Logged the base of permafrost at 2140’ md (1912’ TVD). Slide/ Drill 12.25" Hole F/ 2,687' to 3,449' MD (2,907' TVD) Total 762' (AROP 127') 475 gpm, psi on 1500, psi off 1400, 80 rpm, TRQ on 7-8k, TRQ off 7-10k, WOB 3-7k. ECD 10.91, MW in/out 9.7/9.75, Max Gas 2129u. P/U 125k, SLK 86k, ROT 102k. Jet flowline as needed. Back ream 60'. Sliding as needed to maintain tangent 36° in 187° azi Slide/ Drill 12.25" Hole F/ 3,449' to 3,766' MD (3,188' TVD) Total 317' (AROP 52.8') 450 gpm, psi on 1475, psi off 1380, 80 rpm, TRQ on 7-10k, TRQ off 6-9k, WOB 8-12k. ECD 10.55, F/O 58%, MW in/out 9.65, Max Gas 2935u BGG 620u. P/U 132k, SLK 89k, ROT 108k. Jet flowline as needed. Back ream 60'. End tangent @ 3,573’ MD, start drop/turn 5°/100. At 3,456' MD encountered +2400u gas, reduced rate F/ 475 gpm to 400 gpm to control gas breaking out and shakers running over. Reduced ROP to 120-150 fph and continue drilling ahead. Encountered 2935u max gas W/ 1600u BGG F/ 3,456' to 3,595' MD. Slide/ Drill 12.25" Hole F/ 3,766' to 3,950' MD (3,395' TVD) Total 184' (AROP 30.7') 500 gpm, psi on 1555, psi off 1480, 80 rpm, TRQ on 7- 8k, TRQ off 7-10k, WOB 5-12k. ECD 10.38, F/O 62%, MW in/out 9.6/9.7, Max Gas 606u BGG 260u P/U 140k, SLK 92k, ROT 110k. Jet flowline as needed. Back ream 60'. Cont drop/turn 5°/100 sliding 40' per stand. Distance to WP02: 18.77’, 5.97’ Low 17.70’ Left. ROT Hrs: 9.27. SLD Hrs: 3.99 Daily disposal to G&I: 1197 bbls, total= 1995 bbls. Daily H2O from Lake 2: 840 bbls, total= 2030 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls, total 304 bbls. 50-029-23720-00-00API #: Well Name: Field: County/State: PBW Z-223 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 8/4/2022Spud Date: 8/7/2022 Slide/ Drill 12.25" Hole F/ 3,950' to 4,272' MD (3,688' TVD) Total 322' (AROP 53.6') 500 gpm, psi on 1701, psi off 1558, 80 rpm, TRQ on 7-10k, TRQ off 6-9k, WOB 8-12k. ECD 10.55, F/O 58%, MW in/out 9.7, Max Gas 412u. P/U 156k, SLK 94k, ROT 112k. Jet flowline as needed. Back ream 60'. See erratic Tq and slight Pack Offs Back Reaming stand from 3950'-3901'. Reduced ROP ,Flow Rate and Pulling Speed. Cont drop/turn 5°/100. Slide/ Drill 12.25" Hole F/ 4272' to 4589' MD (3960' TVD) Total 317' (AROP 52.8') 500 gpm, psi on 1740, psi off 1570, 80 rpm, TRQ on 12-14k, TRQ off 12-15k, WOB 9-11k. ECD 10.4, F/O 58%, MW in/out 9.6+, Max Gas 742u. P/U 171k, SLK 98k, ROT 128k. Jet flowline as needed. Back ream 60'. Cont drop/turn 5°/100. Slide/ Drill 12.25" Hole F/ 4,589' to 4,974' MD (4,251' TVD) Total 385' (AROP 64.2') 500 gpm, psi on 1750, psi off 1600, 80 rpm, TRQ on 13-15k, TRQ off 12-15k, WOB 10-15k. ECD 10.38, F/O 58%, MW in/out 9.6+/9.7, Max Gas 510u. P/U 174k, SLK 100k, ROT 128k. Jet flowline as needed. Back ream 60'. Cont drop/turn 5°/100. Slide/ Drill 12.25" Hole F/ 4,974' to 5,160' MD (4,405' TVD) Total 186' (AROP 31') 500 gpm, psi on 1760, psi off 1680, 80 rpm, TRQ on 13-17k, TRQ off 10-15k, WOB 4-12k. ECD 10.32, F/O 59%, MW in/out 9.7, Max Gas 376u. P/U 186k, SLK 102k, ROT 129k. Jet flowline as needed. Back ream 60'. Cont drop/turn 5°/100. Distance to WP02: 21.32’, 17.03’ High 12.82’ Right. ROT Hrs: 1.97. SLD Hrs: 11.04 Daily disposal to G&I: 912 bbls, total= 2907 bbls. Daily H2O from Lake 2: 960 bbls, total= 2990 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls, total 304 bbls. 8/8/2022 Slide/ Drill 12.25" Hole F/ 5,160' to 5,416' MD (4,541' TVD) Total 256' (AROP 42.6') 500 gpm, psi on 1850, psi off 1740, 80 rpm, TRQ on 13-18k, TRQ off 11-14k, WOB 7-13k. ECD 10.4, F/O 59%, MW in/out 9.7/9.7+, Max Gas 471u. P/U 187k, SLK 94k, ROT 129k. Jet flowline as needed. Back ream 60' Cont drop/turn 5°/100 as per plan. Sliding 50-60' per stand. Slide/ Drill 12.25" Hole F/ 5,416' to 5,799' MD (4,650' TVD) Total 383' (AROP 6.8') 500 gpm, psi on 1930, psi off 1730, 80 rpm, TRQ on 15.5k, TRQ off 14-19k, WOB 6-10k. ECD 10.42, F/O 56%, MW in/out 9.75, Max Gas 675u. P/U 183k, SLK 92k, ROT 126k. Jet flowline as needed. Back ream 60' Cont drop/turn 5°/100 as per plan. Sliding 50-60' per stand. Crossed Fault 1 at 5430' md / 4550' tvd throw 158' DTSW into OA sand. Slide/ Drill 12.25" Hole F/ 5,799' to 6,178' MD (4,692' TVD) Total 379' (AROP 63.2') 500 gpm, psi on 1930, psi off 1730, 80 rpm, TRQ on 16k, TRQ off 13-18k, WOB 9k. ECD 10.24, F/O 55%, MW in/out 9.7/9.7+, Max Gas 737u. P/U 173k, SLK 90k, ROT 122k. Jet flowline as needed. Back ream 60' End drop/turn 5°/100 at 5,945' MD Build turn as per Geo to 86° at TD. Slide/ Drill 12.25" Hole F/ 6,178' to 6,230' MD (4,701' TVD) Total 52' (AROP 26') 500 gpm, psi on 1825, psi off 1770, 80 rpm, TRQ on 15-16k, TRQ off 16-17k, WOB 5-7k. ECD 10.23, F/O 56%, MW in/out 9.7/9.7+, Max Gas 664u. P/U 174k, SLK 91k, ROT 122k. Jet flowline as needed. Back ream 60' Build turn as per Geo to 86° at TD 6,230' MD. Shot final survey: 6,178' MD 4,696' TVD 84°° Inc 42.35° Azi. Shut down and monitor well 10 min, static. BROOH F/ 6,230' to 5,926' MD. Circulate 0.5 BU per stand for 3 stands for 1.5 BU. 500 gpm, psi 1650, 80 rpm, TRQ 13-19k, ECD 10.2, F/O 57%, Max Gas 541u. P/U 188k, SLK 91k, ROT 123k. Rot/Rec F/ 5,983' to 5,918' MD. Pump 40 bbl 275 qt/sec HiVis 9.55 ppg Nut Plug sweep. Returned 33 bbls late W/ zero increase in cuttings. Circulated 1.5 BU for a total of 3X BU. 500 gpm, psi 1650, 80 rpm, TRQ 15-17k, ECD 10.25, F/O 56%, Max Gas 372u. P/U 188k, SLK 91k, ROT 123k. Distance to WP02: 7.13’, 4.71’ High 5.36’ Right. Crossed Fault 1 at 5430' md / 4550' tvd throw 158' DTSW. ROT Hrs: 5.15. SLD Hrs: 8.17 Daily disposal to G&I: 107 bbls, total= 4114 bbls. Daily H2O from Lake 2: 845 bbls, total= 3835 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls, total 304 bbls. 8/9/2022 PJSM RIH on elevators F/ 5,962' to 6,320' MD. Wash down last stand, no fill. 500 gpm, 1,630 psi, P/U177k SLK SLK 91k. PJSM BROOH 6,230' to 4,328' MD 500 gpm 1,610 psi, 80 rpm, Trq 13-16k, ECD 10.2, F/O 57% Max Gas 342u. Pulling speed 20-30 ft/min as hole dictates. P/U 169k SLK 91k ROT 118k. Lost 24 bbls to hole. PJSM BROOH 4,328' to 1,673' MD 500 gpm 1,275 psi, 80 rpm, Trq 6-10k, ECD 10.5, F/O 60% Max Gas 621u. Pulling speed 15-30 ft/min as hole dictates. CBU prior to BPF at 2,300' MD. P/U 102k SLK 70k ROT 82k. Lost 66 bls to hole. BROOH 1,673' to 440' MD 500 gpm 1,175 psi, 80 rpm, Trq 5-9k, ECD 10.37, F/O 55% Max Gas 466u. Pulling speed 5-20 ft/min as hole dictates. P/U 86k SLK 62k ROT 72k. Jetting flowline as needed. Lost 90 bbls to hole At 1,702’ MD ECD climb F/ 10.5 to 11.06 ECD CBU over 1 stand heavy flocculated mud at shakers and hole unloading heavy sand and clay. ECD’s falling back to 10.5 ECD Max Gas 466u. Reduced RPM to 40 rpm at 1,300’ MD to more vertical hole at <35° inc. Hole started unloading at 1,022’ MD ECD increased to 11.13 ECD reduced pump rate to 450 gpm seeing extreme sand and wood at shakers, CBU 2X over 1 stand hole cleaning up and ECD coming down to 10.3 ECD. Hole cont unloading adjust pull speed as needed to 711' MD. PJSM Cont BROOH 440' to 171' MD 325-350 gpm 310-410 psi, 25 rpm, Trq 2-5k, ECD 10.55, F/O 45% Max Gas 86u. Pulling speed 2-10 ft/min as hole dictates. P/U 60k SLK 57k ROT 59k. Was able to pull jars on elevators but unable to continue after that pulling over 13k. Lost 2 bbls to hole POOH on elevators F/ 171' to surface. Rack back 3 stands HWDP. L/D X/O 2 ea NM FC. Read MWD tools. Continue L/D TM, DM, EWR, motor and 12.25" bit. PDC 1-3-RO-T-X-I-BT-TD Bit Grade 2-2-WT-A-2-I-JD-TD. No static losses. Clean and clear rig floor. L/D remaining BHA components. Daily disposal to G&I: 570 bbls, total= 4684 bbls. Daily H2O from Lake 2: 725 bbls, total= 4560 bbls. Daily Metal: 0# Total 0#. Daily losses 156 bbls, total 460 bbls. 8/10/2022 Service rig Grease crown, blocks, top drive, PH8 and inspect drawworks. PJSM R/U Parker Csg 9.625" Csg Equip. R/U CRT, bail Ext and bring up 9.625" handling Equip. Stage 66 9.625" bow spring centralizers. PJSM P/U M/U 9,625" 40# L-80 TXP BTC Shoe track as per tally. Drop bypass valve and check floats, good. Baker Loc shoe track. RIH to 444' MD. 20-25 ft/min filling every 5 jnts. Trq 40# TXP BTC 20,960 ft/lb. P/U 49k SLK 49k. PJSM Cont RIH W/ 9.625" 40# L-80 TXP BTC F/ 444' to 2,220' MD as per tally. Work string down 444' to 1,260' MD W/ 6 bpm 63 psi 10 rpm Trq 605-10k (Stall set 10K) W/ 10-15k down. At 1,260' Circ string volume at 7.5 bpm 190 psi. Run speed 10-80 fpm. P/U 119k SLK 72k. Trq 40# TCP BTC 20,960 ft/lb. Fill every 5 jnts and top off every 10. Lost 80 bbls during running. Cont RIH W/ 9.625" 40/47# L-80 TXP BTC F/ 2,220' to 5,222' MD as per tally. P/U 268k SLK 90k. Rot/ Rec at 2,383' to 2,424' MD circ string volume 7.5 bpm 185 psi 5 rpm Trq 8-10k (stall 10k) Max Gas 133u. P/U M/U ES at 3,939' MD as per HES on sight. (Baker Loc) Cont W/ 47# Csg. Trq 40# TCP BTC 20,960 ft/lb. Trq 47# TXP BTC 23,820 ft/lb. Run speed 30-50 fpm. Fill every 5 jnts top off every 10. Lost 89 bbls during running. Cont RIH W/ 9.625" 47# L-80 TXP BTC F/ 5,222' to 5,833' MD as per tally. P/U 240k SLK 90k. Trq 47# TXP BTC 23,820 ft/lb. Run speed 30-50 fpm. Fill every 5 jnts top off every 10. Lost 15 bbls during running. Circ casing volume at end of tangent. Reciprocate F/ 5,833’ to 5,797’ MD. Work string to gain Circ breaking string over at 296k to P/U 240k SLK 90k. Circ at 2 bpm W/ 790 psi to 6 bpm ICP 680 psi dropping FCP 419 psi, staging up to 7 bpm FCP 300 psi. Jetting flow line and managing flocculated mud. At BU hole unloaded heavy sand, clay and wood. Circ 700 strokes past a string volume to clean up hole. P/U 262k SLK 131k. Lost 7 bbls while circulating. Cont RIH W/ 9.625" 40# L-80 TXP BTC F/ 5,833' to 6,220' MD as per tally. Wash down last jnt (159) 4 bpm 340 psi to 6,220' MD. P/U Jnt 160 and was down 10' tag on depth at 6,230' MD W/ 10k. L/D Jnt 160. Check jnts in shed 17 remaining and 1 centralizer on rig floor. P/U 280k SLK 128k. Trq 47# TXP BTC 23,820 ft/lb. Run speed 30-50 fpm. Fill every 5 jnts top off every 10. Circ & Cond mud. Reciprocate F/ 6,220' to 6,180' MD Circ 6.5 bpm 337 psi stage up to 7 bpm 385 psi. P/U 255k SLK 123k. L/D Bail Ext, stage elevators on rig floor. R/D power tongs. Condition mud to <25 YP W/ H2O and centrifuges on. R/U cement lines and 1502’s. Daily disposal to G&I: 171 bbls, total= 4855 bbls. Daily H2O from Lake 2: 145 bbls, total= 4705 bbls. Daily Metal: 0# Total 0#. Daily losses 169 bbls, total 629 bbls. 8/11/2022 Shut down, blow down Top Drive. Shut LWR/UPR IBOP. R/U Cement line to VOLANT Swivel. Cont circulate through cement line staging pump to 7 BPM/ 215 PSI, 42% flow. PJSM, Wet lines w/ 5 bbls H2O (HES), P/T low kick out 1000 low/ 4800 high (ok). Pump 1st stage cement job - 5 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls) 3.5 bpm, 320 psi. Drop bypass plug. (HES) Pump 213 bbls (512 sx) 12 ppg EconoCem Type I II Lead cmt, 2.347 yld, 4.5 bpm,600 psi. 82 bbls (400 sx) 15.8 ppg HalCem Type I II Tail cmt, 1.156 yld, 3.5 bpm, 600 PSI. Release F/ Volant, drop shutoff plug. Displace w/ 20 bbls H2O f/CMT Unit 4 bpm, 550 psi. Turn over to rig. Rig disp (MP #2) w/ 260 bbls 9.7 ppg spud mud, 7 bpm, ICP 400 psi, FCP 528 psi. HES pump 80 bbls 9.4 ppg spacer, 4 bpm, 525 ICP, 600 FCP, 38% flow. Rig displace w/ 99.7 bbls 5.5 bpm, FCP 1150 psi reducing rate last 10 bbls to 3 bpm, 1050 FCP. Bumped @ 459.7 bbls total pumped / Calc 456.2 bbls. Psi up and hold 1560 psi (3 min). Bleed off psi, Check floats (good). Psi up, open stage tool 6 bpm, shift @ 3620 psi. CIP @ 12:23 hrs. Rotate/Recip pipe to 4186 stks (114 bbls cmt OH), park in tension 239k up. 10 bbl loss during job. Circulate out excess cmt and mud. Dumped 64 bbl green cmt, 130 bbls spacer and 276 bbls contaminated mud. Total dumped 470 bbls. Circulate and condition mud via stage tool (2281' MD) 5.5. bpm, 290 ICP, 47% flow. Drain stack and flush with black water, function annular. Continue circulating and surge to 9.4 bpm, 795 psi (3 min) on the hour to help mitigate channeling. PJSM, Wet lines w/ 5 bbls H2O (HES) Pump 2nd stage cement job as follows: 60 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls). Lead ArcticCem 359 bbls 10.7 ppg Lead cmt, 2.883 yld, (697 sx) 4.0 bpm, ICP 308/ 3 bpm FCP 261 psi. 218 bbls into cement saw poly flak at shaker. At 228 bbls (Calc 253.7 bbl) into cement saw 10.0 ppg spacer/cement at shakers. Started dumping overboard at 305 bbls into cement job. Swapped to tail at 359 bbls away 10.7 ppg cement at shakers. Pump Tail Type I / II cement 56 bbls 15.8 ppg Tail cmt, 1.17 yld, (270 sx) 3.0 bpm, 311 psi. Release from CRT & drop closing plug. Displace w/ 20 bbls H2O (HES) 4.7 bpm 218 psi then turn over to rig. Rig attempted displacing at 7 bpm 9.7 ppg Spud Mud then MP #1 stated decavitating. Changed up rates and was unable to pump. Attempted pumping W/ MP #2 and same results. Pumped a total of ~44 bbls of Spud Mud. Cleaned suction screens and found heavy flocculated mud in strainers. Suction pit mud was clabbered up and attempted to thin back W/ H2O. Decision was made to use HES to finish cement job W/ H2O. HES pumped at 4 bpm ICP 418 psi , reduce rate 3 bpm 80 bbls away ICP 646 FCP 738 psi. Closing plug landed at 105 bbls (Calc 103.4 bbls). ES Cementer shifted shut at 1,900 PSI. Held 2,187 psi for 3 minutes, check plug - good. CIP 23:54 hrs. No losses. Dumped 269 bbls of green cement. PJSM Flush surface equip with black water. Blow down cement lines to HES. R/D cement manifold. Fill stack W/ black water and work bad 4X flushing flow line. Install bridge cranes and R/D chains and binders. Four bolt speed head and Diverter Tee flanges. SIMOPS Offload mud from pits. PJSM Remove mouse hole and sections of 16 diverter in cellar. Remove 4" conductor valves and install caps. Vault rep removed bolts from speed head. Lift stack and set ES slips (56k) as per Vault rep. Set down stack and break speed head F/ Diverter Tee. R/D Volant tool. Clear mud out of 9.625" Csg for cut. Lift stack and make 9.625" Csg cut. Daily disposal to G&I: 1358 bbls, total= 6213 bbls. Daily H2O from Lake 2: 1330 bbls, total= 6035 bbls. Daily Metal: 0# Total 0#. Daily losses 113 bbls, total 742 bbls. 8/12/2022 Cut 9.625" Csg as per Vault rep onsite. L/D 9.625" cut jnt (28.10') Set down stack and johnny whack W/ black H2O. Drain stack, R/D knife valve and spilt stack F/ diverter tee. SIMOPS Open and inspect MP's. Clear debris from valve and seats. Cont cleaning pits. PJSM Cont N/D BOPE. Pull riser, rack back stack and secure. L/D diverter tee. Pull speed speed as per Vault Rep onsite. Remove Tee F/ cellar. Remove bell nipple F/ stack. Install MPD RCD on stack as per Beyond rep onsite. Dress 9.625" Csg stump as per Vault rep. Install multi bowl well head. Test seals to 360/ 3800 psi for 10 min, good. SIMOPS Open up UPR, verify 4.5" X 7" rams and clean cavity. Install test plug. Set 11" X 13.635" DSA. Set stack on DSA and Trq bolts (11" 3,332 ft/lb 13.625" 2,146 ft/lb) Install drip pan and 4" MPD lines. Flood stack & test MPD lines 250/2500 psi, good. Obtain RKB. SIMOPS Stage split bushings and MPD riser on rig floor. L/D master bushing & riser. P/U M/U 4.5" test jnt, 5" Dart vlave, 5" TIW (1) and pump in sub. M/U test sub to top drive. Flood lines and purge air from system. Test Upper IBOP, 5" Dart, Mezz Kill, Annular and CMV 11-15. 250/ 3,000 psi 5 min ea. Witnessed waived by AOGCC Rep Bob Noble. Cont 4.5" BOPE test. Reflood and purge air from system due test 2 failing. Appears Lower IBOP failing. Test 4 found leaking gauge on test pump line, plugged. Found leaking Y strainer and retightened. Retighten fittings behind test pump and purge test pump line. Found both 6000 psi Nutron test valves leaking back to the test pump and replacing valves at report time. Tested UPR (4.5" X 7" VBR's) Lower IBOP (Failed) 5" TIW (1), CMV'S 4-10, Manual HCR, Kill, HCR. Having issues trouble shooting leaks. Test 250/ 3000 psi 5 min each. Witnessed waived by AOGCC rep Bob Noble. Daily disposal to G&I: 1574 bbls, total= 7787 bbls. Daily H2O from Lake 2: 599 bbls, total= 6634 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls, total 742 bbls. 8/13/2022 Complete changing out both 6,000 psi Nutron valves on test pump. Cont testing 4.5" test jnt, Lower VBR (2.875” X 5.5”), Super Choke and manual 1,600 psi. Perform Koomey draw drown initial System 3,000 PSI, Manifold 1,500 PSI, Annular 1,500 PSI, after System 1,500 PSI, Man 1,500 PSI, Ann 1,500 pis 200 PSI increase 24 Sec, full charge 90 sec. Nitrogen 6 bottle average 2,183 PSI. Closing times Ann 15 sec, UPR & Blinds 8/9 sec, LPR 5 sec, HCR Choke & Kill 1/1 sec. Test 7" jnt W/ 5" TIW (2), HCR & Manual Choke & UPR (4.5" X 7" VBR's), Blind Rams and CMV's 1-3. Installed new lower IBOP & NC50 Saver Sub. P/U 5" test jnt. test LPR's (2.875" X 5.5" VBR's) & IBOP. C/O lower IBOP due to failure. Tested LPR's (2.875" X 5.5" VBR's). Test Press 250/ 3,000 psi 5 min ea. L/D 5" test jnt. Test fluid H2O. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Checked PVT sensors and return Install rebuilt lower IBOP. Test lower IBOP, fail. Greased 4X and retest, fail. C/O lower IBOP. and replace W/ rebuild. Attempted to test and found leak on Choke line collar from HP line to flange on BOP side. Blow down line. Remove choke line at flange. Attempt to back out set screws to attempt to tighten. Was unable to remove last 3 set screws. Decision was made to change out choke line. SIMOPS: Retrieve choke line F/ D Pad. Install fetter ring on upper and lower IBOP connection. Break down TIW'S, Dart and pump in sub. Clean and L/D NC50 saver sub & bad IBOP. L/D MPD test head. PJSM Remove choke line F/ choke manifold and replace W/ new choke line. Flood lines and check for leaks. Test Lower IBOP, new choke line and Upper IBOP connection to 250/ 3,000 psi 5 min ea passed. Daily disposal to G&I: 57 bbls, total= 7844 bbls. Daily H2O from Lake 2: 155 bbls, total= 6789 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls. Total Surface loss: 742 bbls. 8/14/2022 PJSM, R/D test equipment. Pull test plug, Install 9" ID wear bushing. B/D all surface equipment choke, kill and TDS. Mobilize BHA components to rig floor. Prep handling equipment on rig floor. M/U 8.5" Milltooth (Smith XR+CPS) w/ 6-3/4" 1.5° StrataForce mtr. 6x 5" NC50 49.3# HWDP, 6-1/2" Hydra Jar, 11x 5" NC50 49.3# HWDP. Total BHA length 590.7' MD. Continue Single in F/ 590' - T/ 2212' MD picking up 5" NC50, S-135, 19.5# DP (Drift 3.125"). Wash down F/ 2212' - T/ tag depth 2277' MD. 350 gpm, 550 psi, 30 rpm, 4.5k tq. P/U 94k, S/O 76k, ROT 80k. Drill cmt and stage tool F/ 2277' - T/ 2285' MD (2281' tally). 350 gpm, 515 psi, 30 rpm, 4.5k tq, 2-8k WOB, P/U 94k, S/O 76k, ROT 80k. Tripped thru stage tool clean 2x without issue. Worked past debris F/ 2285' - T/ 2371' MD then tripped clean. Continue TIH picking up 5" out of shed F/ 2371' - T/ 6027' MD. Wash down F/ 6027' - T/ 6,054' MD 375 gpm 740 psi 30 rpm 14-16k tq. P/U 190k S/O 85k ROT 119k. CBU 375 gpm 680 psi 30 rpm Trq 151k F/O 42% P/U 190k SLK 85k ROT 119k. PJSM R/U test Equip. Pump purge aire out of system. Perform 9.625" Csg test Shut press 2,688 psi bled to 2,663 psi (lost 25 psi) after 30 min, good. Pumped 4 bbls and bled back 4 bbls. Drill shoe Track F/ 6,054' to 6,094' MD Tag TOC 6,089' MD Drill BFA 6,094' MD & FC6,138' MD on depth. Ream FC 2X no issue. 400 gpm 875 psi 30 rpm Trq 14-15k. WOB 3-4k F/O 39%. P/U 201k SLK 89k ROT 122k. P/U single (31.95') and drill to 6,213' MD. Went to make connection and galled saver sub. C/O Saver sub. R/D saver sub and replace with new NC50 saver sub. L/D galled 5" D.P. from stand 89. Drill shoe track F/ 6,213' to shoe on depth at 6,220' MD. Drill rat hole and 20' of new F/ 6,220' to 6,250' MD (4,702' TVD) Reamed shoe 3X W/ ROT/ Pumps and 1X without, pulled clean W/ pumps off P/U 201k SLK 89k. 450 gpm, 1,032 psi, 30 rpm, Trq 10- 15k WOB 4-10k P/U 174k SLK 92 ROT 122. PJSM Displace well F/ 9.55 Spud Mud to 9.3 ppg BaraDril N. Pump 40 bbl 300+ HiVis sweep chase W/ 9.3 ppg BaraDril N dumping return overboard. ROT/ REC F/ 6,250' to 6,203' MD 400 gpm 806 psi 30 RPM Trq 15-16k P/U 174k SLK 92k ROT 124k. Circ till 9.3 ppg in/out. Monitor well 10 min, static. Rack back 1 stand. R/U Test lines, TIW and head pin, Flush through stack and choke manifold. Perform FIT to 12 EMW W/ 9.3 ppg BraDril N to 660 psi on chart. Pumped 1.8 bbls, bled back 1.4 bbls. Daily disposal to G&I: 627 bbls, total= 8471 bbls. Daily H2O from Lake 2: 420 bbls, total= 7209 bbls. Daily Metal: 0# Total 0#. Daily losses 0 bbls. Total Surface loss: 742 bbls. 8/15/2022 B/D choke and kill lines. B/D MPD lines. Obtain SPR. Monitor well (static). Pump dry job and B/D TDS. Install stripping rubber. POOH F/ 6190' - T/ BHA (590'). Pulled clean thru stage tool. Hole took proper displacement. P/U 52k, S/O 52k. POOH F/ 590' - T/ surface. Rack back 3x stds HWDP w/ jars. Lay down excess 5" HWDP. Drain mtr, B/O bit and L/D same. Bit graded 1,1,WT,A,E,NO,BHA. No damage to BHA noted. Calculated hole fill for BHA. Clan and clear rig floor. Stage BHA components on rig floor. Prep pipeshed for picking up DP. PJSM, M/U 8.5" Hycalog PDC, Geo Pilot and MWD/LWD tools. Download MWD. M/U ILS, NM FS, NM Flex DC, NM FS, NM Flex DC, 4x 5" HWDP, Jars, 3x 5" HWDP - Total length 403.74' MD. P/U 59k, S/O 57k. Calculated displacement. Single in hole 8.5" RSS BHA W/ 5" 19.5# S-135 NC50 D.P. F/ pipe shed F/ 404' to 2,629' MD P/U 97k SLK 71k. Observed Calc Disp. (Rabbit OD 3.125") Break in GeoPilot seals at 5, 10, 20, 40 & 60 rpm for 1 min ea 450 gpm 875 psi. Perform shallow pulse test. GeoPiolt not responding. Perform Mod reset and was able to send and receive commands to GeoPilot. Cont single in hole 5" 19.5# S-135 NC 50 D.P. F/ pipe shed F/ 2,629' to 5,171' MD. Filled pip and checked GeoPilot not responding. Performed quick reset and still no communication. Decision was made to POOH to C/O GeoPilot. 450 gpm 1,085 psi P/U 155k SLK 105k. Monitor well 10 min, static. Pump 20 bbl 10.4 ppg dry job. Blow down top drive. Kick out warn hard band 5" HWDP and galled 5" D.P. from pipe shed. Prep for laying down 5" D.P. due to minimal room on the rig floor for L/D BHA. PJSM POOH L/D 5" D.P. to pipe shed F/ 5,171' to 403' MD. Calc Disp. Daily disposal to G&I: 694 bbls, total= 9165 bbls. Daily H2O from Lake 2: 160 bbls, total= 7369 bbls. Daily Metal: 21# Total 21#. Daily losses 0 bbls. Total Surface loss: 742 bbls. 8/16/2022 PJSM - L/D BHA F/403' MD - T/ Surface. Rack back 3 stds HWDP, Jars. L/D NM Flex Collars, float subs and Stabilizer. Rack Back MWD and swap out GEO-Pilot for New. Re-Run Bit. PJSM. P/U BHA Per DD and MWD. BHA #4: TK66 NOV Bit, NRP Sleeve, GEO-Pilot and perform integrity test - Good. P/U MWD, NM Flex Collars, Floats, Stabilizers, Jar and HWDP and RIH T/403.79'. Shallow Pulse tested at 218' 450 GPM - Good. P/U 58k,. S/O 56k. P/U 5" S-135 19.5# DP F/Shed F/403.79' - T/1230' MD. 3.15" Rabbit. PJSM. P/U 5" DP F/1230' - T/6124' MD. Fill Pipe at 2760' and shallow pulse tested at 450 GPM - Good. Break in seals on GEO-Pilot. 5, 10, 20, 40, 60 RPM for 1 minute each. Fill Pipe at 5171' P/U 141k, S/O 81k, GPM 140=450psi, F/O 20%. Pull Flow riser and install RCD Bearing, Install Boot Saver. Circulate through MPD Lines checking for Leaks - Good. Cut and Slip drilling Line: 884 ton miles 69' of drill line removed. SIMOPS: Circulate over the hole to shear out Mud at 350 GPM = 750psi. PJSM. Rig Service: Grease TD, wash pipe, FH-80, Upper Pipe Spinners. Do Monthly Sheave Wobble EAM on blocks. Wash Down F/6124' - T/6250' MD, no fill. GPM 400 = 975 psi. P/U 151k, S/O 97k, ROT 115k at 50 RPM. Drill 8.5" Injection Lateral F/6250' - T/6502' MD. GPM 500 = 1515psi, WOB 3-15k, RPM 80 = 13-15k TQ, P/U 158k, S/O81k, ROT 112k. Max Gas 683 units on bottoms up, BGG 325 units. MW 9.3ppg, ECD 10.16ppg. Drill 8.5" Injection Lateral F/6502' - T/7202' MD. GPM 500 = 1670psi. WOB 5-14k, RPM 80 = 12-16k TQ. Max Gas 1691 units, MW 9.3 ppg = 10.67 ECD. P/U 167k, S/O86k, ROT 112k. Pump 20bbl Hi-Vis Sweep @ 6817' observed minimal increase in cuttings. 9-5/8" Shoe = 6220' MD. Distance to WP02 26.11', 25.96' High, 2.80' Left. 7 concretions for a total thickness of 20’ (2.3% of the lateral). Total Footage in OBc Sands = 952'. Total Footage out of OBc Sand = 0'. Total Footage in Lateral = 952' Daily disposal to G&I: 57 bbls, total= 9222 bbls. Daily H2O from Lake 2: 70 bbls, total= 7439 bbls. Daily Metal: 21# Total 21#. Daily losses 0 bbls. Total Surface loss: 742 bbls. 8/17/2022 Drill 8.5" Injection Lateral F/7202' - T/8030' MD (4759' TVD), (828' total = 138' AROP). GPM 500 = 1715 psi. WOB 7-16k, RPM 100-120, 16-18k TQ on, 14-16k tq off. Max Gas 2206u, ~950u BGG, 10.6 ECD w/ 9.3 MW. P/U 143k, S/O 92k, ROT 108k. Increase lubes F/ 2% - T/ ~3% @ 7580' MD. Drill 8.5" Injection Lateral F/8030' - T/8960' MD (4767' TVD), (930' total = 155' AROP). GPM 500 = 1875 psi. WOB 10k, RPM 100-120, 16k TQ on, 14k tq off. Max Gas 1758u, ~1150u BGG, 10.96 ECD w/ 9.4 MW. P/U 143k, S/O 92k, ROT 108k. Drill 8.5" Injection Lateral F/8960' - T/9682' MD (4817' TVD), (722' total = 121' AROP). GPM 500 = 1975 psi. WOB 8-18k, RPM 80-120, 7-11k TQ on, 7-9k tq off. Max Gas 1881u, ~890u BGG, 11.07 ECD w/ 9.4 MW. P/U 145k, S/O 87k, ROT 106k. Fault #1 observed at 9298'MD, 60' Throw DTN into the OBb Sand. Drill 8.5" Injection Lateral F/9682' - T/10385' MD (4822' TVD), (703' total = 118' AROP). GPM 500 = 2201 psi. WOB 8-16k, RPM 80-120, 11-14k TQ on, 9-14k tq off. Max Gas 2028u, ~981u BGG, 11.57 ECD w/ 9.4 MW. P/U 147k, S/O 84k, ROT 108k. Drilled back into OBc Sands at 9723' MD. Pumped a 25 bbl Hi-Vis Sweep at 10255' MD observed a 25% increase in cuttings. Backreaming Full length stands to help reduce ECD's. 9-5/8" Shoe = 6220' MD. Distance to WP02 29.45', 11.31' Low, 27.19' Right. 22 concretions for a total thickness of 71’ (1.7% of the lateral). Total Footage in OBc Sands = 3675'. Total Footage out of OBc Sand = 425'. Total Footage in Lateral = 4100' Daily disposal to G&I: 798 bbls, total= 10020 bbls. Daily H2O from Lake 2: 960 bbls, total= 8399 bbls. Daily Metal: 10# Total 31#. Daily losses 0 bbls. Total Surface loss: 742 bbls. 8/18/2022 Drill 8.5" Injection Lateral F/10385' - T/11018' MD (4822' TVD), (633' total = 106' AROP). GPM 500 = 2260 psi. WOB 8-16k, RPM 100-120, 11-14k TQ on, 9-14k TQ off. Max Gas 2233u, ~1017u BGG, 11.77 ECD w/ 9.4 MW. P/U 151k, S/O 74k, ROT 109k. Pumped Tandem sweep @10898' (30 bbl Lo-Vis/8.7ppg, 20 bbl Hi- Vis/9.4ppg) observed a 25% increase in cuttings at shakers - No reduction in ECD's. Reduce ROP to max 250 FPH. Drill 8.5" Injection Lateral F/11018' - T/11655' MD (4862' TVD), (637' total = 106' AROP). GPM 480 = 2315 psi. WOB 5-18k, RPM 120, 12-16k TQ on, 12-14k TQ off. Max Gas 2193u, ~713u BGG, 11.8 ECD w/ 9.4 MW. P/U 158k, S/O 63k, ROT 104k. Drill 8.5" Injection Lateral F/11655' - T/12225' MD (4825' TVD), (570' total = 95' AROP). GPM 480 = 2340 psi. WOB 5- 12k, RPM 120, 13-16k TQ on, 11-12k TQ off. Max Gas 2759u, ~407u BGG, 11.79 ECD w/ 9.4 MW. P/U 152k, S/O 67k, ROT 104k. Losses 20-27bph Drilled T/11690' MD and lost detection with MWD. Cleaned out suction pods and fluctuated flow rates and troubleshooted. MP#2, #1 dampener over pressured, bled down to 500psi - Interference reduced, better detection. Drill through Fault #2 @11703, 85' DTS Throw. Drilled out of OBc into OBd sands. Re-entered OBc Sands at 12300' MD. Drill 8.5" Injection Lateral F/12225' - T/12915' MD (4833' TVD), (641' total = 107' AROP). GPM 480 = 2185 psi. WOB 5-12k, RPM 120, 12-18k TQ on, 16-17k TQ off. Max Gas 2208u, ~296u BGG, 11.3 ECD w/ 9.4 MW. P/U 165k, S/O 35k, ROT 104k. Losses 15-20bph. Lost all down weight at 12480' MD. Performed a 290 bbl Dilution with 9.3 ppg BARADRIL-N at 12732' MD. ECD's reduced F/11.76 ppg - T/11.48 ppg TQ reduced F/21-22k - T/19-20k. H2O @ 40bph. 9-5/8" Shoe = 6220' MD. Distance to WP02 31.62', 30.22' Low, 9.29' Right. 37 concretions for a total thickness of 122’ (1.9% of the lateral). Total Footage in OBc Sands = 5362'. Total Footage out of OBc Sand = 1215'. Total Footage in Lateral = 6577' Daily disposal to G&I: 806 bbls, total= 10826 bbls. Daily H2O from Lake 2: 855 bbls, total= 9254 bbls. Daily Metal: 10# Total 31#. Daily losses 101 bbls. Total Surface loss: 843 bbls. 8/19/2022 Drill 8.5" Injection Lateral F/12975' - T/13305' MD (4845' TVD), (330' total = 83' AROP). GPM 480 In / 462 out, 2185 psi on, WOB 5-12k, RPM 120, 17k TQ on, 16k TQ off. Max Gas 1999u, ~296u BGG, 11.4 ECD w/ 9.4 MW. P/U 165k, S/O 60k, ROT 106k. Losses ~3 bph. Res issues on MWD (missing data). Service rig. Grease traveling equipment, wash pipe. Sim Ops - C/O bladder on MP#2 dampner #1. Charge and put back online. Drill 8.5" Injection Lateral F/13305' - T/13391' MD (4845' TVD), (90' total = 60' AROP). GPM 480 In / 462 Out, 2270 psi on, WOB 10-18k, RPM 120, 17k TQ on, 16k TQ off. Max Gas 1999u, ~296u BGG, 11.4 ECD w/ 9.4 MW. P/U 160k, S/O 60k, ROT 106k. Losses ~3 bph. MWD failure. BROOH F/ 13391' - T/ 13107' MD @ 5 fpm while circulating Btm's up at max rate. 500 gpm, 2420 psi, 120 rpm, 14.5k tq. P/U 160k, S/O 63k, Rot 107k. 260u BGG. Replace failed die retainer plate on die block (TDS) for grabbers. Finish replacing retainer plate on die block for grabbers. Continue BROOH F/ 13107' - T/ 11535' MD @ 45-60 fpm, 500 gpm, 2320 psi, 120 rpm, 13.5k tq. P/U 160k, S/O N/A, Rot 106k. Continue BROOH F/11535' - T/7714' MD @ 40-60 fpm, 500 gpm, 1850 psi, 120 rpm, 7k tq. P/U 153k, S/O 87k, Rot 112k. Continue BROOH F/7714' - T/6113' MD @ 40-60 fpm, 500 gpm, 1800 psi, 120 rpm, 6k tq. P/U 150k, S/O 87k, Rot 107k. No issues pulling BHA up through shoe @ 6220' MD, observed 2-3k overpull due to Stabilizers and GEO-Pilot coming through. Pumped a 25 bbl Hi-Vis sweep at 6113' MD. 500 GPM = 1585psi observed no increase in cuttings at shakers. SIMOPS: Rig Service and prep for L/D RCD bearing Shut down and monitored flow for 15 mins through MPD - No Flow. Rig Service, Grease Roughneck, Crown, Blocks, TD, RLA linkage, Check Rotary oil and TD Gear oil. PJSM - Drain Stack, Shut in MPD and remove MPD head Clamp - bring RCD to surface. Remove airboot and install trip nipple. PJSM - TOOH racking back 5" DP stands in Derrick. Pull 5 stands F/6113' -T/5730' MD. Monitor well for flow - No flow. Pump a 20 bbl dry-job and begin TOOH T/Surface. P/U135k, S/O 116k. 9-5/8" Shoe = 6220' MD. Distance to WP02 47.68', 42.71' Low, 21.18' Right. 44 concretions for a total thickness of 140’ (2.0% of the lateral). Total Footage in OBc Sands = 5362'. Total Footage out of OBc Sand = 1215'. Total Footage in Lateral = 6577' Daily disposal to G&I: 688 bbls, total= 11514 bbls. Daily H2O from Lake 2: 865 bbls, total= 10119 bbls. Daily Metal: 10# Total 31#. Daily losses 197 bbls. Total Surface loss: 1040 bbls. 8/20/2022 Continue POOH L/D DP F/5362' - T/402' MD. P/U 53k, S/O 52k. 18 bbl loss for trip. POOH F/402' - T/surface with BHA. Rack back HWDP w/ jars. Rack back NM Flex DC's with float subs (inspected floats / good). L/D IBS, TM, DM, ADR collars. Monitor well during MWD read w/ 0 BPH static loss rate. Inspect GeoPilot (good), Bit grade 2,1,CT,N,X,I,NO,DTF Mobilize new BHA components to rig floor. Re-run bit and GeoPilot. M/U new MWD tools and download same. M/U NM flex DCs, HWDP w/ Jars - 403.91' total length. Trip in with 5" NC50 singles from shed w/ 8.5" RSS lateral assy F/ 404' - T/ 3645' MD. Drift 3.125". PJSM - Continue P/U 5" DP out of Shed F/3899' - T/5299' MD. P/U 134k, S/O 106k. RIH on 5" DP F/5299' - T/6124' MD out of Derrick and fill pipe. P/U 137k, S/O 118k. PJSM for removing trip nipple and installing RCD Bearing. Monitor well for 15 mins - No movement. Perform a pulse test at 6124' before going into open hole, 450 GPM = 1350psi, F/O 443 GPM, P/U145k, S/O 78k. RIH F/6124' - T/10575' MD. Observed no issues with BHA coming out of shoe track, RIH at 75-100 FPM. PJSM - Continue RIH with 5" drill pipe F/10575' - T/12837' MD, P/U 155K, S/O 77K, Lost 21 bbls DH on trip overall. RIH T/11225' and 12130' MD and set down respectively 20K/30K, Line up and pump 235 GPM = 695psi at 60 RPM working tight spots 9-10k TQ. RIH on Elevators F/12178' - T/12837' MD MAD-Passing down F/12837' - T/13391' MD (Bottom). 250 FPH, 475 GPM = 1880psi, F/O 462 GPM, RPM 100 = 12k TQ. ECD 10.5ppg with 9.4 MW. 9-5/8" Shoe = 6220' MD. Distance to WP02 47.68', 42.71' Low, 21.18' Right. 44 concretions for a total thickness of 140’ (2.0% of the lateral). Total Footage in OBc Sands = 5897'. Total Footage out of OBc Sand = 1276'. Total Footage in Lateral = 7173' Daily disposal to G&I: 388 bbls, total= 11902 bbls. Daily H2O from Lake 2: 390 bbls, total= 10509 bbls. Daily Metal: 10# Total 31#. Daily losses 26 bbls. Total Surface loss: 1066 bbls. 8/21/2022 Drill 8.5" Injection Lateral F/13391' - T/13748' MD (4825' TVD), (357' total = 60' AROP). GPM 500 In / 482 Out, 2250 psi on, WOB 8-15k, RPM 120, 17.5k TQ on, 16k TQ off. Max Gas 1873u, ~300u BGG, 11.2 ECD w/ 9.4 MW. P/U 172k, S/O 55k, ROT 102k. Drilled fault #3 @ 13392' w/ 84' DTS throw. Drilled up in section and reaquired OBc sand base @ 14206' MD. Drill 8.5" Injection Lateral F/13748' - T/14405' MD (4809' TVD), (657' total = 110' AROP). GPM 500 In / 484 Out, 2250 psi on, WOB 6-17k, RPM 120, 17.5k TQ on, 15k TQ off. Max Gas 1808u, ~300u BGG, 11.5 ECD w/ 9.4 MW. P/U 122k, S/O N/A, ROT 104k. Lost dn wt @ 14004' MD. Completed a 290 bbl dilution at 14405' MD. ECD's went from 11.83ppg down to 11.21ppg - no change in Torque. Drill 8.5' Injection Lateral F/14405' - T/14795' MD (4815' TVD), (390' total = 98' AROP). GPM 500 = 2250psi, F/O 480 GPM. WOB 8-10k, RPM 120, 17.5k TQ on, 15k TQ off. Max Gas 1936u, ~700u BGG, 11.19 ECD w/ 9.4 MW. P/U 170k, S/O N/A, ROT 106k. Change out Drawworks / Top drive cooling fan as it had faulted out on the DSU. Reduced Pump rate to 250 GPM while issue was addressed. SIMOPS: Grease Crown, blocks, FH-80, Check Drawworks Oil. Drill 8.5' Injection Lateral F/14795' - T/14891' MD (4813' TVD), (95' total = 65' AROP). GPM 500 = 2330psi, F/O 484 GPM. WOB 10-13k, RPM 120, 18k TQ on, 16k TQ off. Max Gas 1937u, ~450u BGG, 11.4 ECD w/ 9.4 MW. P/U 171k, S/O N/A, ROT 109k. Drill 8.5' Injection Lateral F/14891' - T/15350' MD (4828' TVD), (459' total = 77' AROP). GPM 500 = 2415psi, F/O 483 GPM. WOB 12-15k, RPM 120, 18-19k TQ on, 17k TQ off. Max Gas 1625u, ~350u BGG, 11.4 ECD w/ 9.4 MW. P/U 168k, S/O N/A, ROT 106k. 9-5/8" Shoe = 6220' MD. Distance to WP02 3.31', 1.94' High, 2.68' Left. 58 concretions for a total thickness of 233’ (2.6% of the lateral). Total Footage in OBc Sands = 6961'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 9050' Daily disposal to G&I: 746 bbls, total= 12648 bbls. Daily H2O from Lake 2: 635 bbls, total= 11144 bbls. Daily Metal: 0# Total 31#. Daily losses 84 bbls. Total Surface loss: 1150 bbls. 8/22/2022 Drill 8.5' Injection Lateral F/15350' - T/16069' MD (4855' TVD), (719' total = 120' AROP). GPM 485 = 2485psi, F/O 472 GPM. WOB 10-12k, RPM 120, 19k TQ on, 18k TQ off. Max Gas 1698u, ~600u BGG, 11.7 ECD w/ 9.4 MW. P/U 170k, S/O N/A, ROT 105k. Drill 8.5' Injection Lateral F/16069' - T/16069' MD (4855' TVD), (719' total = 120' AROP). GPM 485 = 2485psi, F/O 472 GPM. WOB 10-12k, RPM 120, 19k TQ on, 18k TQ off. Max Gas 1698u, ~600u BGG, 11.7 ECD w/ 9.4 MW. P/U 170k, S/O N/A, ROT 105k. Drill 8.5' Injection Lateral F/16700' - T/16855' MD (4876' TVD), (155' total = 78' AROP). GPM 475 = 2590psi, F/O 454 GPM. WOB 8-12k, RPM 120, 20-24k TQ on, 18k TQ off. Max Gas 1285u, ~450u BGG, 11.87 ECD w/ 9.4 MW. P/U 169k, S/O 35k, ROT 104k. FTD was called by GEO at 16855.00' MD Pump 40 bbl Hi-Vis Sweep (9.45 ppg 203 FV) sweep was observed on time with a minimal increase in cuttings. Pump two additional bottoms up (racking back 1 stand per BU) while R&R at 120 RPM, 500 GPM = 2675psi, F/O 488. Dynamic Losses at ~20bph. P/U 171k, S/O N/A, ROT 107k. Finished pumping in total four bottoms up (racking back 1 stand per BU) F/16855' - 16609' MD. GPM 500 = 2675psi, F/O 488. ECD 11.64 w/9.4ppg MW. RPM 120, 20k TQ, P/U 171k, S/O N/A, ROT 107k. Max Gas 345u, 163 BGG. Hold PJSM Wash back to bottom F/16609' - T/16855'. GPM 450 = 2200psi, F/O 450, ECD 11.65 ppg w/9.4ppg MW. PJSM - Pump SAPP Train and displace well with 9.3 ppg QUIKDRIL. Pump three 40 bbl SAPP pills with 20 bbls of QUIKDRIL in between each pill, followed by QUIKDRILL - pumped 1105 bbls 9.3 ppg Quikdrill before we had good mud returns. Dynamic losses at 35bph. Monitored well 15 minutes for flow via MPD - No flow. Dropped 2.38" x 20" Metal drift and began back-reaming operations. Dynamic Losses ~35bph. BROOH F/16799' - 16400' MD. GPM 500 = 1800psi, F/O 470. RPM 120, 17-18k TQ, Max gas 20u, P/U 181k, S/O N/A, ROT 110k. BROOH at 15-25 ft/min. 9-5/8" Shoe = 6220' MD, FTD 16855' MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635' Daily disposal to PBU G&I: 713 bbls, total= 13361 bbls. Daily Disposal to MPU G&I: 265 bbls, total = 265 bbls. Daily H2O from Lake 2: 960 bbls, total= 12104 bbls. Daily Metal: 0# Total 31#. Daily losses 79 bbls. Total Surface loss: 1229 bbls. 8/23/2022 PJSM. BROOH F/16400' - T/13520' MD, GPM 500 = 1740 psi, F/O 460. RPM 120, 14-16k TQ, ECD 10.6ppg with 9.3ppg MW, Max gas 221u. P/U 165k, S/O N/A, ROT 102k. Dynamic losses at 15 BPH, Pulling Speed = 15-30 ft/min as hole dictates. PJSM. BROOH F/13520' - T/10000' MD, GPM 500 = 1650 psi, F/O 460. RPM 120, 10-16k TQ, ECD 10.2ppg with 9.3ppg MW, Max gas 980u. P/U 155k, S/O 86k, ROT 113k. Dynamic losses at 9 BPH, Pulling Speed = 30-45 ft/min as hole dictates. PJSM. BROOH F/10000' - T/6569' MD, GPM 500 = 1550 psi, F/O 460. RPM 120, 6k TQ, ECD 10.1ppg with 9.3ppg MW, Max gas 818u. P/U 138k, S/O 95k, ROT 113k. Dynamic losses at 7 BPH, Pulling Speed = 30-45 ft/min as hole dictates. PJSM. BROOH F/6569' - T/6124' MD, GPM 500 = 1550 psi, F/O 460. RPM 120, 6-7k TQ, ECD 10.1ppg with 9.3ppg MW, Max gas 818u. P/U 133k, S/O 100k, ROT 111k. Dynamic losses at 7 BPH, Pulling Speed = 30-45 ft/min as hole dictates. Rotate and Reciprocrate F/6124' - T/6061' MD. Pumped a 30 bbl Hi-Vis (200FV) sweep no increase in cuttings. Pumped an additional two bottoms up and flow checked (15 mins) the well with MPD - No Flow. PJSM. R/D Beyond RCD Bearing. Drain Stack and shut in Orbit valve. Loosen clamp and bring element to floor. Install trip nipple and air boots flood lines and check for leaks - Good. PJSM. L/D 5" DP to Shed. Flow checked well for 5 mins visually - good. TOOH 5 stands to check for swabbing - no swabbing. Pump 20 bbl corrosion inhibited dry job (10.3ppg) and began TOOH F/6061' - T/4150' MD, trip Losses 2 bbls. SIMOPS: Separating out pipe for CATIV Inspection. 9-5/8" Shoe = 6220' MD, FTD 16855' MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635' Daily disposal to PBU G&I: 1130 bbls, total= 14491 bbls. Daily Disposal to MPU G&I: 528 bbls, total = 793 bbls. Daily H2O from Lake 2: 510 bbls, total= 12614 bbls. Daily Metal: 0# Total 34#. Daily losses 80 bbls. Total Surface loss: 1309 bbls. 8/24/2022 L/D 5" DP F/4150' - T/403' MD (BHA), separating out pipe for CATIV Inspections. P/U 55k, S/O 52k. Trip Losses = 13.5 bbls. Trip in the hole with DP from the derrick F/403' - T/5538' MD. P/U 116k, S/O 87k. Losses = 18 bbls on trip in. L/D 5" DP F/5538' - T/3996' MD. P/U 105k, S/O 86k. No Losses on trip out. Finish L/D 5" DP to the Shed F/3996' - T/403' MD. P/U 55k, S/O 52k. Trip out losses at 9 bbls. Sent in 35 joints for CATIV Inspections. PJSM. L/D HWDP, Jars, Flex Collars, float subs and MWD tools. Bit Graded 2-4-CT-A-X-I-BT-TD. Rig Service - Grease Crown, Blocks, Top Drive, Spinner and FH-80. PJSM. R/U Parker Wellbore Tubular. P/U Power tongs and setup TQ Turn system, P/U Airslips, slip lock elevators, checked slips and elevators with a mandrel - Good. Load rig floor with 264 Solid Body Centralizers, 16 Clam shell Centralizers and 16 stop rings. Verify Pipe on Location. PJSM. Perform a dump test with TQ Turn system - Good. M/U Shoe, Float Collar and a blank using Baker-Lok checked floats prior. RIH F/Surface - T/1300' with 4.5" 12.6# L-80 JFE Bear Liner installing NCS Frac Sleeves and WellTec Expandable Packers (Per Rep). P/U 42k, S/O 40k, Loss of 13 bbls on trip. Torque Turning 4.5" 12.6# L-80 API-Modified JFE Bear Connections to 5400 Ft/Lbs. RIH with 4.5" Liner F/1300' - T/6118' MD Installing NCS Frac sleeves and Welltec Expandable Packers (per Rep). 1 Solid Body 7.5" Centralizer (free floating) on each joint and 2 Clam-Shell 7.5" Centralizers with Stop rings on Welltec Expandable Packer joints. P/U 62k, S/O 52k, Loss of 9 bbls on trip. 9-5/8" Shoe = 6220' MD, FTD 16855' MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635' Daily disposal to PBU G&I: 57 bbls, total= 14548 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 120 bbls, total= 12734 bbls. Daily Metal: 0# Total 34#. Daily losses 22 bbls. Total Surface loss: 1331 bbls. 8/25/2022 RIH with 4.5" Liner F/6118' - T/10,204'. At /9830' MD and no longer able to float liner due. Begin to work 4.5" Lower Completion liner to bottom. P/U 73k, S/O 40k, Loss of 17.8 bbls on trip. Torque Turning Connections to 5400 ft/Lbs, 4.5" JFE Bear 12.6# L-80 API-Modified. Installing NCS Frac sleeves and Welltec Expandable Packers (per Rep). 1 Solid Body 7.5" Centralizer (free floating) on each joint and 2 Clam-Shell 7.5" Centralizers with Stop rings on Welltec Packer joints. RIH working down 4.5" Liner F/10204' - T/10520' MD. Fill pipe and begin to Wash and Ream 4 1/2" Liner F/10520' - T/11182' MD at 1-3.5BPM = 140-190psi. 15 RPM = 5150TQ stall. P/U 120k, S/O 45k, Running speed set at 70 ft/min. Loss of 27 bbls on trip. Due to prior washing and reaming operations the Airlock and pups were removed from the tally - M/U two blank pup joints in the Airlock's place. R/D 4.5" Handling Equipment, R/U 7" Handling equipment and M/U 7" H563 x 4.5" JFE Bear XO. M/U 6 joints of 7" H563 F/11182' - T/11427' MD followed by Baker SLZXP packer per Baker Rep. R/D 7" Handling Equipment and R/U for 5" Drill Pipe. RIH w/4.5" Lower Completion conveyed on 5" drill pipe for one stand. Begin washing and reaming at 2-3BPM, 10-15 RPM = 5150 TQ, P/U 123k, S/O 45k - unable to work down second stand. Decision was made to Rack back second 5" DP stand and continue on with 5" HWDP. Wash and Ream on HWDP F/11557' - T/11681' MD. 1-3BPM = 250-315psi P/U 130k, S/O 55k, 15 RPM = 5150 TQ. Pumped a 40 bbl Concentrated Lube Pill at 11460' and 11589' MD. Loss of 4 bbls downhole. Torque Limiter set to 5150 ft/lbs. Continue Washing and Reaming on HWDP F/11681' - 12112' MD and Pumped another 40 bbl Concentrated Lube pill. Continue to Wash and Ream F/12112' - T/12851' MD 2-3 BPM, 20 RPM = 5150 TQ Stall. P/U 155, S/O 70k. Increased overall Lube Concentration to 3%. 9-5/8" Shoe = 6220' MD, FTD 16855' MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635' Daily disposal to PBU G&I: 57 bbls, total= 14605 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 0 bbls, total= 12734 bbls. Daily Metal: 1.5# Total 35.5#. Daily losses 49 bbls. Total Surface loss: 1380 bbls. 8/26/2022 Wash and Ream F/12851' - T/13774' MD. Conveying 4.5" Lower Completions on 5" HWDP. Washing down at 2-3 BPM = 200-250psi, losses at 2 BPH pumping down 40 bbl Lube Pills as necessary. 10-20 RPM = 5150 TQ Stalls. P/U 185k, S/O 85k ROT 100-110k before setting down. When setting down we are not seeing overpulls on the way back up and we are not having issues with packing off. Washed and Ream F/13774 - T/14607' MD with HWDP from Shed. Continue Washing and reaming with 5" DP from Derrick F/14607' - T/14670' MD. Washing down at 3 BPM = 450psi, loss rate of 6.5bph. 10-20 RPM = 5150 TQ stalls. P/U 205k, S/O 95k. Washed and Ream F/14670 - T/15416' MD with DP from Derrick. Washing down at 3 BPM = 450psi, loss rate of 6.5bph. 10-20 RPM = 5150 TQ stalls. P/U 205k, S/O 95k. Unable to work past 15416' MD - Decision was made to set Packer at 15,390' DP MD. PJSM. L/D single and P/U to 15,390' MD and drop 1" Phenolic ball per Baker Rep. Chased ball down with 3 BPM, Ball engaged seat at 495 strokes (1825psi), setdown to 130k and P/U to 205k - Packer not setting and pressure bleeding off. Pressured back up to 2341 psi setting packer and neutralizer. Held Pressure with Rig pumps ensuring good set. P/U 157k S/O 120k verify packer set - Good. Pressure up to 3800psi at 1 BPM to shear out ball seat - ball seat not fully sheared and bleeding off pressure slowly test pump unable to keep up. Decision was made to test 9-5/8" CSG against SLZXP. Liner Shoe set at 15390.67' DP MD. SLZXP Liner top at 3937.67' DP MD PJSM. Flood Kill and Choke Lines. Shut Annular and purge air from choke manifold. Test 9-5/8" SLZXP Packer T/1500 psi for 10 mins on Chart - Good test. Pumped 1.1 bbls, bled back 1.0 bbls. R/D Test Equipment. 2nd Attempt to Shear Ball Seat: Pressured up again with Mud Pumps at 2 BPM to 3900 psi holding pressure with Mud Pumps (slowly stroking). Bled off pressure and pressure dumped slowly - still not shearing. P/U Packoff out of SLZXP F/3937' - T/3905' MD and brought on the pumps at 3 BPM = 3657psi. pressure dumping quicker. Indications seem to be a partially sheared ball seat and or obstructed flow path around the ports. Decision was made to pick up 29' further and bring the pumps on at 5bpm to try and push ball seat further down or clear flow path. Pressured up to 2400psi at 5BPM and slowly trended down to 900psi. PJSM - Slip and Cut Drill line at 3904' MD. Pump BU during this rig service at 5BPM = ICP 900psi FCP 500psi over this period, full returns, Max gas of 853 units. Ton Miles = 1610. Hang Blocks, cut 20 wraps (125'). Check Drawworks breaks, perform crown sheave EAM. PJSM. Finish up checking the drawworks brakes. Calibrate the second wrap on the drum. Check the crown and floor saver. Grease Top Drive, Crown and Blocks. Complete block wobble EAM. Check Top Drive gear oil, Rotary table oil and grease Spinners. PJSM. TOOH on Elevators F/3904' - T/600' MD laying down 5" HWDP. Loss of 19 bbls on trip. TOL @ 3937.67' DP MD 4.5" Shoe @ 15390.67' DP MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635' Daily disposal to PBU G&I: 0 bbls, total= 14605 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 0 bbls, total= 12734 bbls. Daily Metal: 1.5# Total 35.5# Daily losses 184 bbls. Total Surface loss: 1564 bbls. Activity Date Ops Summary 8/27/2022 Trip out of the Hole on elevators L/D 5" Drill Pipe and HWDP F/600' - T/Surface. Loss of 1 bbl on Trip,Trip in the Hole with 5" Drill Pipe stands from Derrick. M/U 3.5" Stinger on bottom of 5" Drill Pipe. Trip F/Surface - T/3369' MD. P/U 91k, S/O 82k. Loss of 5 bbls on trip.,Pull out of the hole Laying down 5" Drill Pipe F/3369' - T/650' MD. P/U 91k, S/O 82k. Loss of 7 bbls on trip,PJSM. Finish Laying down 5" Drill Pipe F/650' - T/Surface. P/U 42k, S/O 44k. Loss of 2 bbls on trip,Trip in the Hole with 5" Drill Pipe stands from Derrick. M/U 3.5" Stinger on bottom of 5" Drill Pipe. Trip F/Surface - T/2469' MD. P/U 69k, S/O 64k. Loss of 3 bbls on trip.,Pull out of the hole Laying down 5" Drill Pipe F/2469' - T/Surface. P/U 52k, S/O 55k. Loss of 5 bbls on Trip.,PJSM. Lay down 3.5" stinger and M/U wear ring puller, engage Wear Ring and Back out lockdown screws - Pull Wear Ring and lay down running tool.,M/U 4.5" Test plug, side entry sub, TIW, Dart and make up test sub to Top Drive. Flood Lines and Purge air from system. Perform a shell test T/3000psi - Good.,PJSM Witness waived by AOGCC Lou Laubenstein. Perform BOPE test W/ 4.5" & 7" to 250/3,000psai for 5/5 Min. Tested Choke Manifold 1-15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, Super Choke and manual to 2,000 PSI, Upper VBR (4.5" x 7") and lower VBR (2.875" X 5.5"), Blind Rams & Annular. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms.,Checked PVT sensors and return flow. Koomey draw drown Initial System 3,050 PSI, Manifold 1,450 PSI, Annular 1,250 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,350 PSI. 200 PSI increase 25 Sec, full charge 93 sec. Nitrogen 6 bottle average 2,241 PSI.,Bleed off and open Rams. R/D Test Equipment. Break apart TIW and side entry sub. Pull test plug and lay down 7" test joint. Blow down Choke Manifold and Kill Line. Line up Choke for Hard Shut in.,R/D 5" Hydraulic Elevators and R/U Manual 7" Elevators. P/U 7" Landing joint and complete a dry run on the 7" Hanger per onsite Vault Rep - Good Run. L/D 7" Hanger.,PJSM with Rig Crews and PWB Casing hands. Bring to floor PWB power tongs and function test - Good. P/U 7" BTC Drive sub and make up FOSV.,Rig Service - Grease and Inspect crown sheaves, blocks and inspect Top Drive.,PJSM. Finish Rigging up to run 7" BTC casing. P/U Baker Seal assembly per Baker Rep. Run in the hole F/Surface - T/3600' MD, torqueing up to 9300 ft/lbs.,TOL @ 3937.67' DP MD 4.5", Shoe @ 15390.67' DP MD. Distance to WP02 12.68', 5.15' Low, 11.58' Left. 72 concretions for a total thickness of 318’ (3% of the lateral). Total Footage in OBc Sands = 8546'. Total Footage out of OBc Sand = 2089'. Total Footage in Lateral = 10635',Daily disposal to PBU G&I: 57 bbls, total= 14662 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 0 bbls, total= 12734 bbls. Daily Metal: 0# Total 35.5#. Daily losses 35 bbls. Total Surface loss: 1599 bbls. 8/28/2022 PJSM. Run 7' Tieback Seal Assembly F/3600' - T/3948' MD. Space out accordingly, Mule shoe 1.8' off of No-Go. Land Hanger. P/U 116k, S/O 95k.,Closed Annular and pressure up T/300psi to ensure Seals engaged in TOL. Strip up exposing the seal assembly ports and observe the pressure to dump. LRS Pressure test Lines to 2000 psi - Good. LRS Reverse circulate 104 bbls of diesel at 3BPM = ICP 165psi, FCP 500psi. Strip back down and land out Casing Hanger.,L/D Landing joint and P/U Packoff running tool and Packoff. RIH with packoff setting 10k down with Top drive, RILDS. Wellhead Rep Tested packoff to 500/5000 - Good.,PJSM. LRS remained lined up to IA and tied into Rig test chart. LRS pressure tested IA to 1500 psi for 30 min on chart - Good. R/D LRS.,PJSM. R/D 7" Handling equipment and R/U 4.5" Handling Equipment for 4.5" VamTop 12.6# L-80 Tubing.,PJSM New Crews. Finish R/U 4.5" Handling Equipment and Torque Turn Components. Torque Turning 4.5" VamTop 12.6# L-80 Tubing to 4440 ft/lbs, PWB TRS performed Pressure Dump - Good.,P/U 4.5" VamTop Tubing and Jewelry per Approved Tally. RIH F/Surface - T/4208' tagging up 5' early. Pull back up and L/D 9.67' pup from tally, Mule shoe at 4203.56' MD. M/U Landing Joint and Land Hanger, RILDS and L/D Landing Joint. Loss of 10 bbls on trip.,PJSM for PMIT. Flood Kill Line, Shut Annular and PT the hanger to 500 psi for 5 mins - Good. Bleed down Pressure and R/U High pressure hose with Sensator to IA for reverse circulating. Pressure test Manifold and High pressure hose on IA to 1500 psi - Good.,Line up Vac-Truck with 9.3 ppg Corrosion Inhibited Brine on MP #1. Reverse circulate 78 bbls of CI Brine down IA (7" x 4-1/2") taking returns up thru tubing hanger down the choke line at 2BPM, ICP = 140 bbls, FCP = 80 psi no losses during the circulation.,M/U Hanger Landing Joint, Drop 1-7/8" Ball and Rod (8'9" rod with 5 Rollers). Back out Landing Joint.,PJSM. Shut Blinds, Flood Lines and Purge air out of Kill and Choke Lines. Pressure up on Tubing thru the Kill Line. Walked pressure up at 1/2 BPM, observed Packer set at 783psi due to pressure trends. Continued pressuring up Tubing to 3500psi for PMIT for 30 mins on chart - Good.,Bleed down tubing to 2000psi and hold. Pressure up on IA from Mud Manifold to 3500 psi for PMIT for 30 mins on Chart - Good. Bleed off Tubing to zero psi allowing the GLM to shear out from IA side - Good Communication across GLM. R/D equipment and blowdown lines. Install TWC per Wellhead (Vault) Rep.,PJSM. Pump Soapy water through Kill, Choke and Gas Buster. Blow down Top drive, Choke, Kill, Hole Fill and Mud Pumps.,PJSM. R/D Trip Nipple, Drip Pan, Beyond MPD Hard line manifold. R/D Choke, Kill and Hole fill line. Swap out Split Bushing for solid body. Start breaking the stack, installing bridge cranes, and take off chain binders.,Daily disposal to PBU G&I: 57 bbls, total= 14719 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 0 bbls, total= 12734 bbls. Daily Metal: 0# Total 35.5#. Daily losses 35 bbls. Total Surface loss: 1599 bbls. 8/29/2022 PJSM. NIpple down BOPE. Rack back stack and secure. Pull DSA and clean ring grooves. Install MPD Test Cap.,N/U tree. Install SBMS Seal on top of Tubing Hanger. P/U Clean and install tree torqueing to spec per Wellhead Rep. Pressure test the void 500/5000psi and hold for 10/10mins - Good. Test Tree to 5000psi and hold for 10 mins - Good. R/D Test Equipment and pull TWC per Wellhead Rep.,PJSM. Rig up test manifold and pressure test Lines to 1500psi with LRS. Reverse circulate down the IA 91 bbls of FP diesel at 2BPM, ICP = 715psi, FCP = 600psi. R/D LRS and allow well to U-tube.,Finish U-Tube on IA and Tubing, Install Gauge on U-Tube - 0psi. R/D U-Tube Manifold and release LRS. Go into RDMO mode. Clean pits. Take apart fluid ends of MP #1 for Inspection. Bridle up. Scope down Derrick and Blow down steam and water lines. Rig Released at 18:00. Daily disposal to PBU G&I: 652 bbls, total= 15371 bbls. Daily Disposal to MPU G&I: 0 bbls, total = 793 bbls. Daily H2O from Lake 2: 0 bbls, total= 12734 bbls. Daily Metal: 0# Total 35.5#. Daily losses 35 bbls. Total Surface loss: 1599 bbls. 50-029-23720-00-00API #: Well Name: Field: County/State: PBW Z-223 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 8/4/2022Spud Date: TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 3 94 55 Yes X No X Yes No 6 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Float Shoe RKB 10 3/4 378 4366 SE C O N D S T A G E HES 23:54 Cement returns to Surface Rotate Csg Recip Csg Ft. Min. PPG9.55 Shoe @ 6220 FC @ Top of Liner6,135.25 Floats Held 366 711 333 378 Multiple (H20, Mud, Spacer, Mud) CASING RECORD County State Alaska Supv.J Lott / O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.PBW Z-223 Date Run 11-Aug-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top TCP BTC Innovex 1.75 6,220.00 6,218.25 26.50 Csg Wt. On Hook:255,000 Type Float Collar:Conventional No. Hrs to Run:19.5 9.7 7 1900 10 10.7 359 4 100 1050 Bump Plug? FI R S T S T A G E 10Tuned Spacer 5# Poly Flake/ red dye 60 15.8 738 3 8.33 4 169/167.4 459.7/459.7 1560 64 MP1 15.8 82 Bump press ES Cementer Bump Plug? 12:23 8/11/2022 2,282 2281.65 6,220.006,230.00 CEMENTING REPORT Csg Wt. On Slips:56,000 Spud Mud Tuned Spacer 5# Poly Flake/ red dye 697 2.88 Stage Collar @ 60 Bump press 100 269 ES Closure OK 56 12 214 26.46 RKB to CHF Type of Shoe:Conventional Casing Crew:Parker Casing No. Jts. Delivered 169 No. Jts. Run 152 17 Length Measurements W/O Threads Ftg. Delivered 6,929.00 Ftg. Run 6,232.00 Ftg. Returned 697.00 Ftg. Cut Jt.28.10 Ftg. Balance www.wellez.net WellEz Information Management LLC ver_04818br 2.7 ArcticCem Type 2 ea BS & 4 ea SR on shoe jnt, 1 ea BS & 2 ea SE Blan Jnt and FC jnt. 1 ea BS to jnt 26. Every other Jnt to Jnt 56. 5 ea BS before ES, 1 ea BS ES Pups, 5 ea BS after ES. Every third jnt to jnt 154. Total 6 stop rings and 69 Bow Spring Centralizers. 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 81.55 6,218.25 6,136.70 Float Collar 10 3/4 TCP BTC Innovex 1.45 6,136.70 6,135.25 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 39.93 6,135.25 6,095.32 Baffle Adapter 10 3/4 TCP BTC Halliburton 1.40 6,095.32 6,093.92 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 3,791.37 6,093.92 2,302.55 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 18.08 2,302.55 2,284.47 ES Cementer 11 3/4 TCP BTC Halliburton 2.82 2,284.47 2,281.65 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 17.57 2,281.65 2,264.08 9.625 CSG 9 5/8 47.0 L-80 TCP BTC Tenaris 2,237.58 2,264.08 EconoCem Type I II 512 2.35 HalCem Type I II 400 1.16 4.6 Type I/II 270 1.17 8/11/2022 Surface H2O/Mud/H20 TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 3 94 55 Yes X No X Yes No 6 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Float Shoe RKB 10 3/4 378 4366 SE C O N D S T A G E HES Rotate Csg Recip Csg Ft. Min. PPG9.55 Shoe @ 6220 FC @ Top of Liner6,135.25 Floats Held 366 711 333 378 H2O CASING RECORD County State Alaska Supv.J Lott / O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.PBW Z-223 Date Run 11-Aug-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top TCP BTC Innovex 1.75 6,220.00 6,218.25 26.50 Csg Wt. On Hook:255,000 Type Float Collar:Conventional No. Hrs to Run:19.5 8.33 4 0 10 10.7 359 4 100 550 Bump Plug? FI R S T S T A G E 10Tuned Spacer 5# Poly Flake/ red dye 60 15.8 218 3 8.33 4.7 20/20 20/20 0 HES 15.8 82 Bump pressBump Plug? 0 2281.65 6,220.006,230.00 CEMENTING REPORT Csg Wt. On Slips:56,000 Spud Mud Tuned Spacer 5# Poly Flake/ red dye 697 2.88 Stage Collar @ 60 Bump press 100 0 ES Closure OK 56 12 214 26.46 RKB to CHF Type of Shoe:Conventional Casing Crew:Parker Casing No. Jts. Delivered 169 No. Jts. Run 152 17 Length Measurements W/O Threads Ftg. Delivered 6,929.00 Ftg. Run 6,232.00 Ftg. Returned 697.00 Ftg. Cut Jt.28.10 Ftg. Balance www.wellez.net WellEz Information Management LLC ver_04818br 2.7 ArcticCem Type 2 ea BS & 4 ea SR on shoe jnt, 1 ea BS & 2 ea SE Blan Jnt and FC jnt. 1 ea BS to jnt 26. Every other Jnt to Jnt 56. 5 ea BS before ES, 1 ea BS ES Pups, 5 ea BS after ES. Every third jnt to jnt 154. Total 6 stop rings and 69 Bow Spring Centralizers. 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 81.55 6,218.25 6,136.70 Float Collar 10 3/4 TCP BTC Innovex 1.45 6,136.70 6,135.25 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 39.93 6,135.25 6,095.32 Baffle Adapter 10 3/4 TCP BTC Halliburton 1.40 6,095.32 6,093.92 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 3,791.37 6,093.92 2,302.55 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 18.08 2,302.55 2,284.47 ES Cementer 11 3/4 TCP BTC Halliburton 2.82 2,284.47 2,281.65 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 17.57 2,281.65 2,264.08 9.625 CSG 9 5/8 47.0 L-80 TCP BTC Tenaris 2,237.58 2,264.08 EconoCem Type I II 512 2.35 HalCem Type I II 400 1.16 4.6 Type I/II 270 1.17 0 H2O SUPERSEDED 'HILQLWLYH6XUYH\5HSRUW $XJXVW +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ = = 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 79'5HIHUHQFH 6LWH +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ = 'HILQLWLYH6XUYH\5HSRUW :HOO :HOOERUH = =6XUYH\&DOFXODWLRQ0HWKRG0LQLPXP&XUYDWXUH =$FWXDO5.%#XVIW 'HVLJQ='DWDEDVH1257+86&$1$'$ 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=6XUYH\&DOFXODWLRQ0HWKRG0LQLPXP&XUYDWXUH =$FWXDO5.%#XVIW 'HVLJQ='DWDEDVH1257+86&$1$'$ 0'5HIHUHQFH=$FWXDO5.%#XVIW 1RUWK5HIHUHQFH :HOO= 7UXH 0' XVIW ,QF $]L (: XVIW 16 XVIW 6XUYH\ 79' XVIW 79'66 XVIW 0DS 1RUWKLQJ IW 0DS (DVWLQJ IW 9HUWLFDO 6HFWLRQ IW '/6 6XUYH\7RRO1DPH B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ 352-(&7('WR7' $SSURYHG%\&KHFNHG%\'DWH $0 &203$66%XLOG(3DJH Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.08.23 08:38:25 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.08.24 08:02:09 -08'00' 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Sunday, September 4, 2022 6:22 PM To:Brooks, Phoebe L (OGC) Cc:Regg, James B (OGC) Subject:Hilcorp (PBU) August 2022 MIT Forms Attachments:MIT PBU 13-31A 08-02-22.xlsx; MIT PBU 17-15A 08-02-22.xlsx; MIT PBU GC-2E 08-22-22.xlsx; MIT PBU L-105 08-14-22.xlsx; MIT PBU NGI-06 08-02-22.xlsx; MIT PBU X-28 08-14-22.xlsx; MIT PBU G-21 08-30-22.xlsx; Z-223i PMIT TBG AOGCC Form 10-426 8-29-22.xlsx Mrs. Brooks, Attached are the completed AOGCC MIT forms for the tests performed by Hilcorp in August 2022 Well: PTD: Notes: 13 31A 2051600 2 year MIT IA per AA AIO 4G.003 17 15A 1991310 2 year MIT IA per AA AIO 4E.020 G 21 195154 2 year MIT T & CMIT TxIA per CO 736 GC 2E 1970180 2 year MIT IA per AA AIO 3.022 L 105 2020580 Under Evaluation for possible TxIA NGI 06 1760290 4 year MIT IA X 28 1931140 4 year MIT IA Z 223 222 080 Initial Test Please reply with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659 5102 M: (907) 232 1005 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. 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. Z 223 222 080 Initial Test Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 222-080 Type Inj N Tubing 1500 3710 3674 3644 Type Test P Packer TVD 3522 BBL Pump 1.0 IA 1500 0 12 12 Interval I Test psi 3700 BBL Return 1.2 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: HILCORP NORTH SLOPE LLC PRUDHOE BAY / WEST SIDE / Z-223I WITNESS WAIVED by Bob Noble STEVE CARTER 08/29/22 Notes: Notes: Notes: Notes: Z-223i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0829_MIT_PBU_Z-223 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 6HSWHPEHU &(57,),('0$,/± 5(78515(&(,375(48(67(' 0U0RQW\0\HUV 'ULOOLQJ0DQDJHU +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$. 5H 'RFNHW1XPEHU27+ 1RWLFHRI9LRODWLRQ 3UXGKRH%D\8QLW= 37' 'HDU0U 0\HUV 2Q $XJXVWWKH$ODVND2LODQG*DV&RQVHUYDWLRQ&RPPLVVLRQ$2*&&UHFHLYHGDUHSRUW IRUDGLYHUWHUV\VWHPWHVWFRPSOHWHGRQ$XJXVW7KHWHVWZDVSHUIRUPHGRQ+LOFRUS ,QQRYDWLRQ ZKLOHSUHSDULQJWRGULOO3UXGKRH%D\8QLW =±$2*&&ZLWQHVVZDVZDLYHG7KH UHSRUW VKRZHG WKHFORVHWLPHRIWKHDQQXODUSDFNLQJHOHPHQWZDVVHFRQGVDQGWKHYHQWOLQH YDOYHNQLIHYDOYHZDVVHFRQGVLGHQWLI\LQJERWKDVSDVVLQJWHVWV %\HPDLOGDWHG6HSWHPEHU $2*&&VHQW+LOFRUS1RUWK6ORSH//&+LOFRUSWKHIROORZLQJFRUUHFWLRQ Knife valve is required to open before the annular packing element fully closes; refer to 20 AAC 25.035(c)(2)(B). Knife valve test is a failure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³the actuating mechanism for the vent line valve must be integrated with the actuating mechanism for the annular pack-off device in a fail-safe manner so that the vent line valve automatically opens before full closure of the annular pack-off´ 'RFNHW1XPEHU27+ 6HSWHPEHU 3DJH RI 7KH$2*&&UHVHUYHVWKHULJKWWRSXUVXHDGGLWLRQDOHQIRUFHPHQWDFWLRQLQFRQQHFWLRQZLWKWKLV 1RWLFHRI9LRODWLRQ4XHVWLRQVUHJDUGLQJWKLVOHWWHUVKRXOGEHGLUHFWHGWR-LP5HJJDW MLPUHJJ#DODVNDJRY 6LQFHUHO\ -HUHP\03ULFH &RPPLVVLRQHU&KDLU FF $2*&&,QVSHFWRUVHPDLO 3KRHEH%URRNV$2*&& Jeremy Price Digitally signed by Jeremy Price Date: 2022.09.14 11:38:30 -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:Regg, James B (OGC) To:James Lott - (C);Oliver Amend - (C);Joseph Engel Cc:Rixse, Melvin G (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Subject:RE: Diverter Hilcorp Innovation 08-04-22 Date:Thursday, September 8, 2022 11:40:00 AM Attachments:2022-0804_Diverter_Hilcorp_Innovation_PBU_Z-223.xlsx Knife valve is required to open before the annular packing element fully closes; refer to 20 AAC 25.035(c)(2)(B). Knife valve test is a failure. Revised report attached. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: James Lott - (C) <jlott@hilcorp.com> Sent: Saturday, August 6, 2022 7:47 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Oliver Amend - (C) <oamend@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: Diverter Hilcorp Innovation 08-04-22 James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig PBU, North Slope Alaska 907-670-3094 (Office) 907-398-9069 (Cell) Harmony 1006 jlott@hilcorp.com jameslott352@yahoo.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. 'DWH 'HYHORSPHQW ; ([SORUDWRU\ 'UOJ&RQWUDFWRU 5LJ1R ,QQRYDWLRQ $2*&&5HS 2SHUDWRU2SHU5HS )LHOG8QLW:HOO1R5LJ5HS 37'1R 5LJ3KRQH 5LJ(PDLO 0,6&(//$1(286',9(57(56<67(0 /RFDWLRQ*HQ 3 :HOO6LJQ 3 'HVLJQHGWR$YRLG)UHH]HXS" 3 +RXVHNHHSLQJ 3 'UOJ5LJ 3 5HPRWH2SHUDWHG'LYHUWHU" 3 :DUQLQJ6LJQ 3 0LVF 1$ 1R7KUHDGHG&RQQHFWLRQV" 3 KU1RWLFH 3 9HQWOLQH%HORZ'LYHUWHU" 3 $&&808/$7256<67(0'LYHUWHU6L]H LQ 6\VWHPV3UHVVXUH SVLJ 3 +ROH6L]H LQ 3UHVVXUH$IWHU&ORVXUH SVLJ 3 9HQW/LQHV6L]H LQ 3 SVL5HFKDUJH7LPH 6HFRQGV 3 9HQW/LQHV/HQJWK IW 3 )XOO5HFKDUJH7LPH6HFRQGV 3 &ORVHVW,JQLWLRQ6RXUFH IW 3 1LWURJHQ%RWWOHV1XPEHURI 2XWOHWIURP5LJ6XEVWUXFWXUH IW 3 $YJ3UHVVXUH SVLJ 3 $FFXPXODWRU0LVF 1$ 9HQW/LQHV$QFKRUHG 3 08'6<67(09LVXDO $ODUP 7XUQV7DUJHWHG/RQJ5DGLXV 1$ 7ULS7DQN 3 3 'LYHUW9DOYHV)XOO2SHQLQJ 3 0XG3LWV 3 3 9DOYHV$XWR 6LPXOWDQHRXV )ORZ0RQLWRU 3 3 $QQXODU&ORVHG7LPHVHF 3 0XG6\VWHP0LVF 1$ .QLIH9DOYH2SHQ7LPHVHF ) 'LYHUWHU0LVF 1$ *$6'(7(&72569LVXDO $ODUP 0HWKDQH 3 3 +\GURJHQ6XOILGH 3 3 *DV'HWHFWRUV0LVF 1$ 7RWDO7HVW7LPH KUV 1RQ&RPSOLDQFH,WHPV 5HPDUNV 6XEPLWWR MORWW#KLOFRUSFRP 7(67'$7$ -RHO6WXUH SKRHEHEURRNV#DODVNDJRY +LOFRUS 7HVWHGZLWK'3.QLIH9DOYHFKDQJHGWR)$$&F%UHTXLUHVLWWRRSHQEHIRUHDQQXODUSDFNLQJHOHPHQWFORVHV-5HJJ -DPHV/RWW 7(67'(7$,/6 MLPUHJJ#DODVNDJRY $2*&&,QVSHFWRUV#DODVNDJRY 3%8= 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 'LYHUWHU6\VWHPV,QVSHFWLRQ5HSRUW *(1(5$/,1)250$7,21 :DLYHG+LOFRUS $OO'LYHUWHUUHSRUWVDUHGXHWRWKHDJHQF\ZLWKLQGD\VRIWHVWLQJ )RUP5HYLVHGB'LYHUWHUB+LOFRUSB,QQRYDWLRQB3%8B= David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 10/05/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU Z-223 PTD: 222-080 API: 50-029-23720-00-00 FINAL LWD FORMATION EVALUATION LOGS (08/04/2022 to 08/22/2022) x AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Geosteering and EOW Report SFTP Transfer – Main Folders: FINAL LWD Folder: FINAL GEOSTEERING + EOW Folder: Please include current contact information if different from above. PTD:222-080 T37102 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 10:17:00 -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:Wallace, Chris D (OGC) To:Wyatt Rivard Cc:Rixse, Melvin G (OGC); Oliver Sternicki; AOGCC Records (CED sponsored) Subject:RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Date:Thursday, September 29, 2022 1:09:31 PM Wyatt, Thank you for meeting with us and the good discussion on this well. Plan as detailed below is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, September 22, 2022 3:25 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: Z-223 (PTD#222080) Request to Place Well on Water Injection for Internal and External Mechanical Integrity Verification Hello Chris and Mel, Thank you again for meeting last week to discuss PBU well Z-223 (PTD #222080). Per our discussion Hilcorp would like to request approval to put Z-223 on injection and then obtain a waterflow log for submission with a formal AA request for continued injection. Background Z-223 (PTD#222080) was recently drilled as a Schrader Bluff WAG injector. While running the 4.5” injection liner to bottom, rig encountered issues getting liner down. After washing and reaming and rotating liner, liner shoe was eventually worked from ~ 9500’ down to 15391’ MD at which point no further progress could be made and liner was set short of the 17,549’ MD target. Current wellbore schematic is attached for reference. This placed the liner top packer and subsequently the injection packer high with injection packer set at 4058’ MD roughly 1432’ MD /1087’ TVD above the planned and permitted set depth of 5490’ MD. A packer depth of 4058’ MD places the bottom of the monitorable annulus above the top of the Schrader Bluff injection zone at ~ 5430’ MD/4544’TVD and into the Ugnu formation. The top of the Ugnu formation is at ~3670’ MD. Request Hilcorp requests to place Z-223 on water injection for a period of two months for internal mechanical integrity testing and stabilized external mechanical integrity logging at and above the top of injection zone. After confirmation of internal and external mechanical integrity, Hilcorp would make a formal request for an administrative approval to continue injection with additional cyclical logging in place to confirm long term isolation of injection fluids to the Schrader Bluff formation. 2 month request is for water only injection, additional data regarding WAG cycling and the relative frequency of potential gas vs water injection would be included with AA request. Mitigations 9-5/8” casing tested good to 2500 psi on 8/14/22 confirming integrity of the casing below liner top packer, ensuring current isolation of injected fluids to below the 9-5/8” casing shoe. Upper three sliding sleeves will be left closed. Uppermost injection from the liner will occur at 6406’ MD injection sleeve within the lower OBC sand in Schrader Bluff formation, ~ 970’ MD past the top of the Schrader Bluff. Daily pressure and injection rate monitoring to identify any unexplained drop in pressure or increase in injection rate indicating possible out of zone injection to shallower zones. An open hole metal expandable packer set at 6227’ MD below the 9-5/8” casing shoe providing additional isolation of injection fluids to the open hole section of the OBC sand within the Schrader Bluff formation. Initial and subsequent two year cyclical water flow logging with temperature warmbacks will be proposed from lowermost wireline accessible depth of ~5550’ MD (below the top of the Schrader Bluff at ~5430’ MD) to above the tubing packer at ~4058’ MD. Stop counts would be taken at least every ~200’ confirming no upward flow of water behind the 4.5” injection liner or behind the 9-5/8” casing. Following stopcounts and dynamic temperature pass, well would be SI and warmback temperature trends will be taken to further confirm consistent temperature gradient/trend with no “bulbs” indicating injection through 9-5/8” casing. Hilcorp would include an interpretive report highlighting WFL/Temp logging results, confirmation of integrity and addressing any anomalies observed. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Z-223 (PTD#222080) New Drill Injector Highset Liner & Packer Date:Tuesday, September 20, 2022 9:12:02 AM Attachments:image001.png From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, September 12, 2022 11:28 AM To: Wyatt Rivard <wrivard@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: Z-223 (PTD#222080) New Drill Injector Highset Liner & Packer Wyatt, I think that should work. We will need to meet in the Public Hearing Room, as the conference room is in use all week. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 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). Mel From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, September 12, 2022 9:58 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: Z-223 (PTD#222080) New Drill Injector Highset Liner & Packer Mel/Chris, Would 2PM on Thursday work for us to come by? Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.com 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Hilcorp Alaska, LLC | Anchorage, AK 99503 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, September 9, 2022 4:55 PM To: Wyatt Rivard <wrivard@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: Z-223 (PTD#222080) New Drill Injector Highset Liner & Packer I am around. Mid to late next week might be better as I need to pass a covid test to make it into the office. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 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: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, September 9, 2022 4:22 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Z-223 (PTD#222080) New Drill Injector Highset Liner & Packer Hello Mel and Chris, The Innovation Rig recently experienced issues with getting liner to bottom on new drill injector Z- 223 (PTD#222080). The rig worked liner down to 15391’ MD but were unable to get down to target depth of ~17500’ MD, having to set liner high. This resulted in the injection packer being set at 4058’MD putting the packer 1432’ MD / 1087’ TVD higher than the planned set depth. This high-set packer depth extends the monitorable annulus only into the Ugnu formation with the top of the Schrader Bluff at ~5420’MD/4544’TVD. Injection on this well would remain confined to the Schrader Bluff by the tested and cemented 9-5/8” casing run to 6220’MD. An open hole metal expandable packer set at 6227’ MD would provide additional isolation of the 4.5”x9-5/8” annulus from injection, with uppermost injection sleeves required to be left closed. Would you be available for a phone call or meeting early next week? We’d like to discuss our potential options for diagnostics or remediation to address the high set packer and confirm long term confinement of injection to Schrader Bluff formation. Thank You, Wyatt Z-223 Current Wellbore Schematic Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are 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. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Z-223 (PTD# 222080) Pre injection MIT-IA Date:Tuesday, September 20, 2022 9:17:51 AM From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, September 8, 2022 3:50 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Z-223 (PTD# 222080) Pre injection MIT-IA Chris, Mel, After dropping the ball and rod on Z-223 (PTD# 222080) a waived witness MIT-T and MIT-IA were conducted on 8/29/2022. The MIT-T was a good test and the 10-426 was submitted with the August MIT forms. The MIT-IA, upon review was considered an inconclusive test and was not extended or repeated at the time. We are currently scheduling Slickline and Fullbore to repeat the AOGCC witnessed MIT-IA before the ball and rod and RHC are pulled. Let me know if you have any questions or concerns. 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 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. 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW7KXUVGD\6HSWHPEHU$0 7R-DPHV/RWW&2OLYHU$PHQG&-RVHSK(QJHO &F5L[VH0HOYLQ*2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& 6XEMHFW5('LYHUWHU+LOFRUS,QQRYDWLRQ $WWDFKPHQWVB'LYHUWHUB+LOFRUSB,QQRYDWLRQB3%8B=[OV[ <ŶŝĨĞǀĂůǀĞŝƐƌĞƋƵŝƌĞĚƚŽŽƉĞŶďĞĨŽƌĞƚŚĞĂŶŶƵůĂƌƉĂĐŬŝŶŐĞůĞŵĞŶƚĨƵůůǇĐůŽƐĞƐ͖ƌĞĨĞƌƚŽϮϬϮϱ͘Ϭϯϱ;ĐͿ;ϮͿ;Ϳ͘<ŶŝĨĞ ǀĂůǀĞƚĞƐƚŝƐĂĨĂŝůƵƌĞ͘ZĞǀŝƐĞĚƌĞƉŽƌƚĂƚƚĂĐŚĞĚ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗:ĂŵĞƐ>ŽƚƚͲ;ͿфũůŽƚƚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕ƵŐƵƐƚϲ͕ϮϬϮϮϳ͗ϰϳD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗KůŝǀĞƌŵĞŶĚͲ;ͿфŽĂŵĞŶĚΛŚŝůĐŽƌƉ͘ĐŽŵх͖:ŽƐĞƉŚŶŐĞůфũĞŶŐĞůΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗ŝǀĞƌƚĞƌ,ŝůĐŽƌƉ/ŶŶŽǀĂƚŝŽŶϬϴͲϬϰͲϮϮ :ĂŵĞƐ>Žƚƚ ,/>KZWƌŝůůŝŶŐ&ŽƌĞŵĂŶ ,/>KZW/EEKsd/KEZŝŐ Wh͕EŽƌƚŚ^ůŽƉĞůĂƐŬĂ ϵϬϳͲϲϳϬͲϯϬϵϰ;KĨĨŝĐĞͿ ϵϬϳͲϯϵϴͲϵϬϲϵ;ĞůůͿ ,ĂƌŵŽŶǇϭϬϬϲ ũůŽƚƚΛŚŝůĐŽƌƉ͘ĐŽŵ ũĂŵĞƐůŽƚƚϯϱϮΛǇĂŚŽŽ͘ĐŽŵ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ǀĂůǀĞƚĞƐƚŝƐĂĨĂŝůƵƌĞ͘ <ŶŝĨĞ Date: 8/4/2022 Development: X Exploratory: Drlg Contractor: Rig No. Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220800 Rig Phone: Rig Email: MMISCELLANEOUS:DIVERTERR SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P AACCUMULATORR SYSTEM:Diverter Size: 13 5/8 in. Systems Pressure: 3,100 psig P Hole Size: 12 1/4 in. Pressure After Closure: 2,000 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 16 Seconds P Vent Line(s) Length: 173 ft. P Full Recharge Time:48 Seconds P Closest Ignition Source: 81 ft. P Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 155 ft. P Avg. Pressure: 2325 psig P Accumulator Misc: NA Vent Line(s) Anchored: P MMUDD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time: 10 sec P Mud System Misc: 0 NA Knife Valve Open Time: 13 sec F Diverter Misc: NA GGASS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 0.5 hrs Non-Compliance Items: 0 Remarks: Submit to: jlott@hilcorp.com TTESTT DATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Tested with 5" DP. Knife Valve changed to "F" - 20 AAC 25.035(c)(2(B) requires it to open before annular packing element closes (J. Regg) 0 James Lott 0 670-3094 TTESTT DETAILS jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU Z-223 SSTATEE OFF AL ASK A AAL ASK AA OILL ANDD GASS CONSERVATIONN COMMISSION DDi v er t err Sys t em ss In s p ec t i o nn Rep o r t GGENERALL INFORMATION WaivedHilcorp **Al ll Di ver t err r epor t ss ar ee duee t oo t h ee ag enc yy w i t h i nn 55 dayss off t est i n g * Form 10-425 (Revised 04/2018)2022-0804_Diverter_Hilcorp_Innovation_PBU_Z-223 +LOFRUS1RUWK6ORSH//& 9 9 9 -5HJJ F Knife Valve changed to "F" - 20 AAC 25.035(c)(2(B) requires it to open before annular packing element closes (J. Regg) 1#6; 15% 5HJJ-DPHV%2*& )URP-DPHV/RWW&MORWW#KLOFRUSFRP! 6HQW0RQGD\$XJXVW$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F6WHYH&DUWHU& 6XEMHFW+LOFRUS,QQRYDWLRQ $WWDFKPHQWV+LOFRUS,QQRYDWLRQ[OV[ :ĂŵĞƐ>Žƚƚ ,/>KZWƌŝůůŝŶŐ&ŽƌĞŵĂŶ ,/>KZW/EEKsd/KEZŝŐ Wh͕EŽƌƚŚ^ůŽƉĞůĂƐŬĂ ϵϬϳͲϲϳϬͲϯϬϵϰ;KĨĨŝĐĞͿ ϵϬϳͲϯϵϴͲϵϬϲϵ;ĞůůͿ ,ĂƌŵŽŶǇϭϬϬϲ ũůŽƚƚΛŚŝůĐŽƌƉ͘ĐŽŵ ũĂŵĞƐůŽƚƚϯϱϮΛǇĂŚŽŽ͘ĐŽŵ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Innovation DATE: 8/27/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2220800 Sundry # Operation: Drilling: x Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: x Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1592 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8", 5K P Pit Level Indicators PP #1 Rams 1 4-1/2"x7"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"x5-1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8", 5K P Time/Pressure Test Result HCR Valves 1 3-1/8", 5K P System Pressure (psi)3050 P Kill Line Valves 1 3-1/8", 5K P Pressure After Closure (psi)1500 P Check Valve 0NA200 psi Attained (sec)25 P BOP Misc 0NAFull Pressure Attained (sec)93 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2241 psi P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 10 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/27, 06:00 Waived By Test Start Date/Time:8/27/2022 17:00 (date) (time)Witness Test Finish Date/Time:8/27/2022 22:00 nnovationtoolpusher@hilcorp.com BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Joel Sture Hilcorp James Lott Test Pressure (psi): jlott@hilcorp.com Hilcorp PBU Z-223 Form 10-424 (Revised 08/2022) 2022-0827_BOP_Hilcorp_Innovation_PBU_Z-223 9 9 9 9 9999 9 9 9 -5HJJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Innovation DATE: 8/14/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22220800 Sundry # Operation: Drilling: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1592 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1FP Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8", 5K P Pit Level Indicators PP #1 Rams 1 4-1/2"x7"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"x5-1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8", 5K P Time/Pressure Test Result HCR Valves 1 3-1/8", 5K P System Pressure (psi)3000 P Kill Line Valves 1 3-1/8", 5K P Pressure After Closure (psi)1500 P Check Valve 0NA200 psi Attained (sec)24 P BOP Misc 1 choke hose leak FP Full Pressure Attained (sec)90 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2183 psi P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 15 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 9 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:31.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/11/22 16:49 Waived By Test Start Date/Time:8/12/2022 23:00 (date) (time)Witness Test Finish Date/Time:8/14/2022 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Tested with 4-1/2", 5", and 7" test joints. Failed lower IBOP, Failed spare IBOP. Rebuilt and retested with passing test. Observed slight leak on choke hose connection. Replaced choke hose and retested (pass). Tested all components with water. Matt Vanhoose Hilcorp Shane Barber PBU Z-223 Test Pressure (psi): nnovationtoolpusher@hilcorp.com sbarber@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0814_BOP_Hilcorp_Innovation_PBU_Z-223 9 +LOFRUS1RUWK6ORSH//& 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 -5HJJ FP FP Failed lower IBOP,Failed spare IBOP.j leak on choke hose connection. 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU Z-223 Hilcorp North Slope, LLC Permit to Drill Number: 222-080 Surface Location: 4294' FSL, 2727' FEL, Sec. 19, T11N, R12E, UM, AK Bottomhole Location: 2094' FNL, 788' FWL, Sec. 08, T11N, R12E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of June, 2022. 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Drilling Procedure ´+ROH6HFWLRQ0$63 '/% 3DJH Prudhoe Bay West Z-223 SB Injector Drilling Procedure 6SLGHU3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH Prudhoe Bay West Z-223 SB Injector Drilling Procedure 6XUIDFH3ODW$V%XLOW1$' 6WDQGDUG3URSRVDO5HSRUW 0D\ 3ODQ=ZS +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ = 3ODQ= = 0750150022503000375045005250True Vertical Depth (1500 usft/in)-3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250Vertical Section at 20.20° (1500 usft/in)Z-223 wp02 HeelZ-223 wp02 CP1Z-223 wp02 CP3Z-223 wp02 CP5Z-223 wp02 CP6Z-223 wp02 Toe9 5/8" x 12 1/4"4 1/2" x 8 1/2"5001000150020002500300035004000450050005500600065007000750080008500900095001000010500110001150012000125001300013500140001450015000155001600016500170001750017549Z-223 wp02Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4.5º/100' : 750' MD, 744.31'TVDEnd Dir : 1241.73' MD, 1184.81' TVDStart Dir 5º/100' : 3589' MD, 3070.57'TVDFault A (20' DTSW throw)Fault B (205' DTSW throw)End Dir : 5887.18' MD, 4669.63' TVDStart Dir 2º/100' : 6037.18' MD, 4682.7'TVDEnd Dir : 6353.27' MD, 4697.35' TVDStart Dir 2º/100' : 7770.27' MD, 4705.06'TVDStart Dir 2.5º/100' : 9077.7' MD, 4737.7'TVDEnd Dir : 9483.47' MD, 4770.34' TVDStart Dir 2.5º/100' : 9638.38' MD, 4788.45'TVDEnd Dir : 9985.41' MD, 4811.5' TVDStart Dir 2º/100' : 11335.41' MD, 4832.7'TVDEnd Dir : 11688.09' MD, 4817.48' TVDStart Dir 2º/100' : 11858.92' MD, 4800.07'TVDEnd Dir : 12219.91' MD, 4785.91' TVDStart Dir 2º/100' : 13144.91' MD, 4807.7'TVDEnd Dir : 13354.52' MD, 4804.97' TVDStart Dir 2º/100' : 13733.06' MD, 4786.22'TVDEnd Dir : 13962.31' MD, 4784.02' TVDTotal Depth : 17549.21' MD, 4892.7' TVDBPRFSV3SV1Ugnu 4AUG3Ugnu MBObaOBcHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: Z-22356.20+N/-S+E/-WNorthingEastingLatitudeLongitude0.000.005959100.14599950.89 70° 17' 51.620 N 149° 11' 26.097 WSURVEY PROGRAMDate: 2022-03-29T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 800.00 Z-223 wp02 (Z-223) GYD_Quest GWD800.00 6038.00 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+Sag6038.00 17549.21 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1909.70 1827.00 2144.02 BPRF2321.70 2239.00 2656.85 SV32830.70 2748.00 3290.42 SV13190.70 3108.00 3733.58 Ugnu 4A3501.70 3419.00 4080.02 UG34351.70 4269.00 5079.05 Ugnu MB4608.70 4526.00 5590.56 Oba4690.70 4608.00 6146.71 OBcREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Z-223, True NorthVertical (TVD) Reference:z-223 as built rkb @ 82.70usft (Original Well Elev)Measured Depth Reference:z-223 as built rkb @ 82.70usft (Original Well Elev)Calculation Method:Minimum CurvatureProject:Prudhoe BaySite:ZWell:Plan: Z-223Wellbore:Z-223Design:Z-223 wp02CASING DETAILSTVD TVDSS MD SizeName4682.77 4600.07 6038.00 9-5/8 9 5/8" x 12 1/4"4892.70 4810.00 17549.21 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 750.00 15.00 175.00 744.31 -64.83 5.67 3.00 175.00 -58.88 Start Dir 4.5º/100' : 750' MD, 744.31'TVD4 1241.73 36.55 187.72 1184.81 -275.93 -8.63 4.50 20.37 -261.93 End Dir : 1241.73' MD, 1184.81' TVD5 3589.00 36.55 187.72 3070.57 -1660.95 -196.41 0.00 0.00 -1626.59 Start Dir 5º/100' : 3589' MD, 3070.57'TVD6 5887.18 85.00 41.82 4669.63 -1387.39 852.67 5.00 -141.99 -1007.55 End Dir : 5887.18' MD, 4669.63' TVD7 6037.18 85.00 41.82 4682.70 -1276.03 952.31 0.00 0.00 -868.63 Z-223 wp02 Heel Start Dir 2º/100' : 6037.18' MD, 4682.7'TVD8 6353.27 89.69 46.07 4697.35 -1048.82 1171.32 2.00 42.26 -579.76 End Dir : 6353.27' MD, 4697.35' TVD9 7770.27 89.69 46.07 4705.06 -65.68 2191.75 0.00 0.00 695.29 Start Dir 2º/100' : 7770.27' MD, 4705.06'TVD10 9077.70 87.50 20.00 4737.70 1020.50 2898.19 2.00 -95.04 1958.62 Z-223 wp02 CP1 Start Dir 2.5º/100' : 9077.7' MD, 4737.7'TVD11 9483.47 83.29 10.74 4770.34 1409.95 3005.35 2.50 -114.84 2361.12 End Dir : 9483.47' MD, 4770.34' TVD12 9638.38 83.29 10.74 4788.45 1561.11 3034.01 0.00 0.00 2512.87 Start Dir 2.5º/100' : 9638.38' MD, 4788.45'TVD13 9985.41 89.10 4.28 4811.50 1904.08 3079.16 2.50 -48.22 2850.33 End Dir : 9985.41' MD, 4811.5' TVD14 11335.41 89.10 4.28 4832.70 3250.15 3179.90 0.00 0.00 4148.37 Z-223 wp02 CP3 Start Dir 2º/100' : 11335.41' MD, 4832.7'TVD15 11688.09 95.85 2.23 4817.48 3601.71 3199.90 2.00 -16.86 4485.21 End Dir : 11688.09' MD, 4817.48' TVD16 11858.92 95.85 2.23 4800.07 3771.52 3206.51 0.00 0.00 4646.85 Start Dir 2º/100' : 11858.92' MD, 4800.07'TVD17 12219.91 88.65 2.77 4785.91 4131.65 3222.23 2.00 175.68 4990.25 End Dir : 12219.91' MD, 4785.91' TVD18 13144.91 88.65 2.77 4807.70 5055.31 3266.92 0.00 0.00 5872.52 Z-223 wp02 CP5 Start Dir 2º/100' : 13144.91' MD, 4807.7'TVD19 13354.52 92.84 2.90 4804.97 5264.60 3277.29 2.00 1.81 6072.51 End Dir : 13354.52' MD, 4804.97' TVD20 13733.06 92.84 2.90 4786.22 5642.18 3296.43 0.00 0.00 6433.47 Start Dir 2º/100' : 13733.06' MD, 4786.22'TVD21 13875.06 90.00 2.90 4782.70 5783.95 3303.61 2.00 -179.95 6569.00 Z-223 wp02 CP622 13962.31 88.26 2.73 4784.02 5871.08 3307.90 2.00 -174.29 6652.24 End Dir : 13962.31' MD, 4784.02' TVD23 17549.21 88.26 2.73 4892.70 9452.28 3478.43 0.00 0.00 10071.99 Z-223 wp02 Toe Total Depth : 17549.21' MD, 4892.7' TVD -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 South(-)/North(+) (1500 usft/in)-3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 West(-)/East(+) (1500 usft/in) Z-223 wp02 Toe Z-223 wp02 CP6 Z-223 wp02 CP5 Z-223 wp02 CP3 Z-223 wp02 CP1 Z-223 wp02 Heel 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 1250 2500 375042504 5 0 0 4750 4893 Z-223 wp02 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4.5º/100' : 750' MD, 744.31'TVD End Dir : 1241.73' MD, 1184.81' TVD Start Dir 5º/100' : 3589' MD, 3070.57'TVD Fault A (20' DTSW throw) Fault B (205' DTSW throw) End Dir : 5887.18' MD, 4669.63' TVD End Dir : 6353.27' MD, 4697.35' TVD Start Dir 2º/100' : 7770.27' MD, 4705.06'TVD Start Dir 2.5º/100' : 9077.7' MD, 4737.7'TVD End Dir : 9483.47' MD, 4770.34' TVD Start Dir 2.5º/100' : 9638.38' MD, 4788.45'TVD End Dir : 9985.41' MD, 4811.5' TVD Start Dir 2º/100' : 11335.41' MD, 4832.7'TVD End Dir : 11688.09' MD, 4817.48' TVD Start Dir 2º/100' : 11858.92' MD, 4800.07'TVD End Dir : 12219.91' MD, 4785.91' TVD Start Dir 2º/100' : 13144.91' MD, 4807.7'TVD End Dir : 13354.52' MD, 4804.97' TVD Start Dir 2º/100' : 13733.06' MD, 4786.22'TVD End Dir : 13962.31' MD, 4784.02' TVD Total Depth : 17549.21' MD, 4892.7' TVD CASING DETAILS TVD TVDSS MD Size Name 4682.77 4600.07 6038.00 9-5/8 9 5/8" x 12 1/4" 4892.70 4810.00 17549.21 4-1/2 4 1/2" x 8 1/2" Project: Prudhoe Bay Site: Z Well: Plan: Z-223 Wellbore: Z-223 Plan: Z-223 wp02 WELL DETAILS: Plan: Z-223 56.20 +N/-S +E/-W 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975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)Z-16Z-46AZ-46Z-222 wp03Z-221Z-40No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: Z-223 NAD 1927 (NADCON CONUS)Alaska Zone 0456.20+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005959100.14599950.8970° 17' 51.620 N 149° 11' 26.097 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Z-223, True NorthVertical (TVD) Reference: z-223 as built rkb @ 82.70usft (Original Well Elev)Measured Depth Reference:z-223 as built rkb @ 82.70usft (Original Well Elev)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-03-29T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 Z-223 wp02 (Z-223) GYD_Quest GWD800.00 6038.00 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+Sag6038.00 17549.21 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)Z-20Z-229 wp02Z-222 wp03Z-34Z-50Z-61Z-70Z-113Z-115Z-66Z-220Z-221Z-221Z-65Z-40Z-69NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17549.21Project: Prudhoe BaySite: ZWell: Plan: Z-223Wellbore: Z-223Plan: Z-223 wp02Ladder / S.F. 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Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: Z-223 NAD 1927 (NADCON CONUS)Alaska Zone 0456.20+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005959100.14599950.8970° 17' 51.620 N149° 11' 26.097 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Z-223, True NorthVertical (TVD) Reference: z-223 as built rkb @ 82.70usft (Original Well Elev)Measured Depth Reference:z-223 as built rkb @ 82.70usft (Original Well Elev)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-03-29T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 Z-223 wp02 (Z-223) GYD_Quest GWD800.00 6038.00 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+Sag6038.00 17549.21 Z-223 wp02 (Z-223) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200 16800 17400Measured Depth (1200 usft/in)Z-221NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17549.21Project: Prudhoe BaySite: ZWell: Plan: Z-223Wellbore: Z-223Plan: Z-223 wp02Ladder / S.F. 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