The URL can be used to link to this page

Home My WebLink About213-151STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Oil -Bbl Gas-Mcf Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Atter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 43-2686 5. Permit to Drill Number. 213-151 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory [1 9-5/8" 1365-4888 AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20412-01-00 7. Property Designation (Lease Number): ADL 028313 & 028312 8. Well Name and Number PBU %-04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 5410 Liner 3308 4-1/2" 11318 - 14626 10. Field/Pools' 7500 PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 14628 feel Plugs measured None feet true vertical 8648 feet Junk measured None feet JUN 2 6 2019 Effective Depth: measured 14626 feet Packer measured 11195 feet true vertical 8548 feet Packer true vertical 8454 feet A®G C C Casing: Length: Size: MD: ND: Buret: Collapse: Structural Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Prior to well operation: Conductor 80 20" x 30" 44-124 44-124 Subsequent to operation: Surface 2643 13-3/8" 43-2686 43-2686 5380 2670 Intermediate 3523 9-5/8" 1365-4888 1365-4717 6870 4760 Intermediate 11420 7" 41-11461 41-8660 7240 5410 Liner 3308 4-1/2" 11318 - 14626 8549-8648 8430 7500 Perforation Depth: Measured depth: 13062 -14586 feet True vertical depth: 8675-8649 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 39-11318 39-8549 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 11195 8454 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Pumped the following down the OA taking returns to formation: 10 BBLS 60/40, 50 BBLS surfactant, 10 BBLS 13.5 PPG Mudpush, 20 BBLS neat 15.8 PPG Class G CMT, 50 BBLS 15.8 PPG Class G CMT w/ 15 PPB AGG, 198 BBLS neat 15.8 PPG Class G CMT. Intervals treated (measured): 43' - 2686' (Surface to Surface Casing Shoe) Treatment descriptions including volumes used and final pressure: 10 BBLS 13.5 PPG Mudpush, 218 BBLS Neat 15.8 PPG Class G Cement, 50 BBLS 15.8 PPG Class G Cement with 15 PPB Aggregate Final Pressures: OA = psi, IA = 1583 psi, TBG = 1647 psi 13. Representative Daily Average Production or Injection Data Tubing Pressure 1622 1647 14. Attachments: (requred Per 2o awc 25.07025.071, &25 283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-062 Authorized Name: Worthington, Area J Contact Name: Worthington Area J Authorized Title: IntervenVns & Integrity Engineee4 Contact Email: Aras.Worthinglonabp.com Authorized Signature: �— Date: 6�� JJ C(' Contact Phone: +1 907 564 4102 i Form 10-404 Revised 04/2017/�� µ`(j,i RBD MS 'JUN 2 81019 Submit Original Only Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Prior to well operation: 229 13885 1116 1097 Subsequent to operation: 212 14411 1204 1583 Tubing Pressure 1622 1647 14. Attachments: (requred Per 2o awc 25.07025.071, &25 283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-062 Authorized Name: Worthington, Area J Contact Name: Worthington Area J Authorized Title: IntervenVns & Integrity Engineee4 Contact Email: Aras.Worthinglonabp.com Authorized Signature: �— Date: 6�� JJ C(' Contact Phone: +1 907 564 4102 i Form 10-404 Revised 04/2017/�� µ`(j,i RBD MS 'JUN 2 81019 Submit Original Only Daily Report of Well Operations PBU X -04A n rrlviTvnnT� CI IAAMARV T/1/0=1900/1280/470 (LRS Unit 76 - OA Injectivity Test) Establish OA injectivity of 1430 psi @ 5 BPM w/ 100 bbls crude. RU to TC. Freeze protect FL w/ 5 bbis 60/40, 75 bbls Crude. SV,WV,SSV shut. MV,IA,OA Open. 4/25/2019 FWHP=1780/1300/550 Initial T/I/O = 1586/1635/529 (SLB Cementing Unit 28803 - OA DOWNSQUEEZE) Pumped the following down the OA taking returns to formation: 10 BBLS 60/40, 50 BBLS surfactant, 10 BBLS 13.5 PPG Mudpush, 20 BBLS neat 15.8 PPG Class G CMT, 50 BBLS 15.8 PPG Class G CMT w/ 15 PPB AGG, 198 BELS neat 15.8 PPG Class G CMT. FHPWS = 1613/1653Nac MV = 0 SV,SSV,WV = C IA CSG = OTG OA CSG = C TOC in OA (13-3/8" x 7") = Surface BOC in OA (13-3/8" x 7") = 1365' MD / 1365' TVD 5/16/2019 BOC in OA 9-5/8" x 7" = 4888' MD/ 4717' TVD TWO = 1610/1770NAC. Temp = 1360. Bleed IAP to 300 psi (Eva] Tx IA). ALP = 690 psi, SI @ CV. Initial IA FL @ 2976', 554' above Sta 6- Dome, 69 bbls). Bled IAP to OT from 1770 psi to 280 psi in 34 minutes. Monitor for 1 hr. IAP increased 130 psi & IA FL @ 2566' ( 964' above Sta 6- Dome, 45 bbls) after monitor. IA FL rose 410' during bleed & monitor. Final WHPs = 1610/410NAC. 5/31/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 23:00 T/I/O = 1630/470NAC. Temp = 139°. WHPs (post bleed). ALP = 510 psi, SI @ CV. TP increased 20 psi, IAP increased 60 psi, OAP unchanged overnight. 6/2/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 01:50 T/I/O = 1600/1260NAC. Temp = 130°. Warm TIFL (eval T x IA). ALP = 1950 psi, SI @ CV. Initial IA FL @ 3530' (Sta 6- Dome, 189 bbls). Open GLT to depress fluid to SO. Monitor IA FLs & pressures. WHPs = 1600/1950NAC. SV = 0. WV, SSV, MV = 0. IA, OA = OTG. 23:59 6/2/2019 "" Job in progress. Continued on 6/3/19 AWGRS*" Job contined from 6/2/19 AWGRS"" TWO = 1600/1950NAC. Temp = 130°. Warm TIFL (eval Tx IA). ALP = 1950 psi, online. IA FL @ 3830' ( 300' below Ste 6- Dome, 205 bbls). Monitor IAP & IA FL while depressing fluid down to SO. IA FL unchanged. Final WHPs = 1760/1950NAC. 6/3/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 04:35 T/I/O = 1750/1910Nac. Temp = 136'. TIFL PASSED. (Eval T x IA Communication). ALP = 1910 psi & SI @ IA casing valve. IA FL @ 3530' (sta# 6, Dome valve, (62 bbl). SI Wing valve & stacked out TP to 2040 psi in 30 minutes. Grease crew Serviced & grease locked the AL casing valve, Bled ALP from casing valve to AL lateral valve to 0 psi in 5 minutes. IAP decreased 50 psi during TP stack out after AL casing valve was grease locked. Bled IAP from 1860 psi to 290 psi in 40 minutes, no change in IA FL, TP decreased 40 psi during IA bleed, Rig down & monitor. TP decreased 10 psi, no change in IAP, IA FL or OAP. OPS POP well, now online. Final WHP's. 1790/290Nac. 6/7/2019 SV = C. WV, MV, SSV = O. IA, OA = OTG. 16:05 7RPF= � 41/16" CNV ILLI-EAD= MCEVOY ACTUNTOR= BAKBRC OKB. ELEV = 74.65' BF. ELEV = 40.66 KOP= 3000' Max Angle = 106° @ 12105 Datum MD = NA Datum ND= 6805 SS 13-3/8' X 7' L-80 BTRS, D =12.347' D=8.681' Minimum 10=3.726"@ 11301' 4-1/2" HES XN NIPPLE 1 11318' 1 D = 3.958' 7- CSG, 26#, L-80 VAM TOP HC, D = 6.276" - 11461' J 1 I I I I JI 4-12' LP42, 12.60,13CR-85 HYD 521, 14626' J .0152 bpf, D = 3.958' F / w 1 2MM' H3518"DJPKRI ST PERFORATION SUNIMRY 1TVDIDEVITYPE REF LOG. 7 ANGLE AT TOP PERF: NA' Note: Pefer to Production OB for historical pert data SRE SPF NfERVAL �SHOT 3516 SQZ 4-12" J—SLOJ 13062 - 13297 O 03/06/14 5 4-12" I-SLOI 13462 - 14142 O 03/06/14 BK 4-12' I*SLOII 14303 -14586 O 03/06114 61 1 I I I I JI 4-12' LP42, 12.60,13CR-85 HYD 521, 14626' J .0152 bpf, D = 3.958' F / w 1 2MM' H3518"DJPKRI ST MD 1TVDIDEVITYPE I MND 7 VLV LATCH I PORT DATE 6 3530 3516 17 KBG-2 DOW BBC 16 03/22114 5 5929 5510 53 KBG2 SO BK 20 0322/14 4 7955 6505 61 KBG-2 DMI' BK 0 03/10/14 3 9568 7302 57 KBG-2 OM1' BK 0 03/10/14 2 10350 7793 42 KBG-2 MY BK 0 03/10/14 1 11008 8306 38 KBG-2 OM1' BK 0 03/10/14 35/6" MLLOIIT WINDOW (X -04A) 4888'-4904' 11167' HBS X NP. D= LTP w/IV EUMD TT NOT LOGGED 11841' 7' X 5' BKR DG FLIX LOC 11360' 5' X 4-12" XO, H6 WATER SWELL PACKERS NO SIZE I TOP DEPTH I MND 7 4-12" 11477 3.958' 6 4-1/2" 12834 3.958" 5 4-12" 13002 3.958" 4 4-12' 13297 3.958" 3 4-12' 13417 3.958" 2 4-12" 14142 3.958" 1 4-12" 14263 3.956' DATE REI/ BY OOM.9JI5 CATE REV BY COMaEIM 0128180 N1 ES INTIAL COMPLETION 03128/14 JCV PJC FINAL CDEAPPROVAL 03111114 D-25 SIDETRACK (X -04A) 06/10/19 JL/J AD CA DOMSOZ 8 C9AMM 0321/14 PJC ORLG HO OORRECIIOPS 0325114 JMJ CORRECTED 7" LNR TO CSG 0325/14 PJC GLVS / PERFS DAF UPDATES 0326114 SWU PJC GLV 40(0222/14) PR DHOE BAY UNIT WELL: X -04A PEFUT No: 1131510 AR No: 50-02320412-01 SEC 8, T10N, M4E, 341' FN- & 168' FAL BP EKpbration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras J. Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X -04A Permit to Drill Number: 213-151 Sundry Number: 319-062 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Se4nount, Jr. Commissioner DATED this day of March, 2019. '�;gpN1S�tj 0� 71©19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 J1EAVED 1. Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Strip Well ❑ Alter Casing ❑ Other OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development p• 5. Permit to Drill Number 213-151 ' 3. Address: P.O. Box 196612 Anchorage, AK 8. 99519-6612 Stretigraphic ❑ Service El API Number: 50-029.20412-01 00 7. If perforating: B. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No El POU X -04A - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028313 & 028312 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14628 ' 8648 14626 8648 None None Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" x 30" 44-124 44-124 Surface 2642 13-3/'8" 43-2686 43-2686 5380 2670 Intermediate 3523 9-5/8" 1365-4888 1365-4717 1 6870 4760 Intermediate 1 11420 7" 41-11461 41-8660 1 7240 5410 Liner 1 3308 4-1/2" 11318-14626 8549-8648 1 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13062- 14586 Be75 - 8649 4-1/2" 12.6# 13Cr85 39-11318 Packers and SSSV Type: 4-1/2" HES TNT Penn Packer Packers and SSSV MD (ft) and TVD (ft): 11195/8454 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic R1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Sl2tigraphic ❑ Development m Service ❑ 14. Estimated Date for Commencing Operations: March 1, 2019 15. Well Status after proposed work: Oil ® WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Area J be deviated from without prior written approval. Contact Email: Aras.Worthingtonabp.com Authorized Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authorized Title: Interventions Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �"t '2 s1 CA _ ^J v L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Past Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Fii Subsequent Form Required: 'O—#*,,LI APPROVED BVTHE Approved by: COMMISSIONER COMMISSION Date ` 317 / (jn nn 10-403 Revised 04/2017 ORIGINAL RBDMS_iLFv MAR 0 7 2019 M(y�'7m��1 Submit Form and Approved application is valid for 12 months from me date of approval. y gAtffachm is in Duplicate by 2 X-04 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Wade Boman (907) 564-4674 Estimated Start Date: 3/1/2019 History X -04A is a horizontal Sag well drilled in March 2014 and completed with 1200' slots (3 sets) and swell packers. i X-04A's OA is suspected to be in communication with the Cretaceous disposal water via the sidetrack window from 4888' MD (4716' TVD) to 4905' MD (4731' TVD). On 7/26/18, an OA no - flow -test failed. OA repress urization appears to occur without thermal influence. Current Status The well is currently classified as "Operable". Objective 11 Perform an OA down -squeeze to fully cement the OA and seal off communication between the OA and the Cretaceous interval. Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel or crude oil down the OA and into formation. Max OA pressure 2500 psi. 2. Pump —250 bbls of 15.8 ppg Class G cement down the OA to fully cement the OA from surface to the Surface Casing Shoe. Pump the following schedule at maximum rate below 2500 psi treating pressure: ^r 10-bbls of 60/40 or 10 bbls neat MEOH ➢ 50 bbls hot (180 deg) freshwater + surfactant; 2 gal/bbl F103 and 2 gal/bbl UO67 ➢ 10 bbls of 13.5 ppg MUDPUSH II Spacer ➢ 20 bbls of neat cement ➢ 50 bbls of cement with 15 -ppb aggregate ➢ 180 bbls of neat cement Volumes: top bot volume MD MD Size ID bbls/ft. Ft. bbls Ppg: 15.8 ppg Class G Unislurry — Mix on the fly Slurry Temperature: 13-3/8" 72# x 12.347" 40 - 200 cc (20-100cc/30min) Thickening Time: Minimum 4 hours 13-3/8" x 7" annulus 0 1365' 7" 26# x 7.0" 0.100 1365' 137 9-5/8" 47# x 8.681" 9-5/8" x 7" annulus 1365' 4888' 7" 26# x 7.0" 0.024 3523' 90 Ppg: 15.8 ppg Class G Unislurry — Mix on the fly Slurry Temperature: between 800 and 110°F API fluid loss: 40 - 200 cc (20-100cc/30min) Thickening Time: Minimum 4 hours Compressive Strength: 2000 psi in 24 — 48 hours Cement thickening time: Mix on the fly Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 DHD/Operations 1. POP well Under-Evalution and monitor OA for re -pressurization. Special Projects (contingent step if OA re -pressurizes) 1. Strap the TOC in the OA. 2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product. Squeeze to 2500 psi. TRI£= 4-1/16'CIW WELLHEAD= RCEVOY ACTUATOR= BAKER CKB. BEV = 74.66 BF. EiEV = 40.65' KOPL 3_000' Max Angle = 1 OF @ 12106' Datum MD = WA Datum TVD= 8800'SS 133/8• CSG. 72N. L-80 BTRS. D= Minimum ID = 3.725" @ 11301' 4-1/2" HES XN NIPPLE .0152 0of. D = 3.958' D = 6.276' Pff FORATDN SL*AAARY FEF LOG. ANGLEATTOPPBTF: NA' Note: Refer to Roduction DB for tustorcal pert data SAFETY NOTE: WILL ANGLE>70'@11737'^•41/2- CHROME TBG d SOLID LNR—SEE PG. FOR X-04 Current PREVKHIS Wl3LBORE••• i i I I 412' LPR 12.6X, 13CR-86 HYD 521, 14628• .0152 DP9, D = 3.956' I$X MP. D=3.813• GAS LFT MANDRELS ST LRD TVD DEV TYPE VLV LATCH PORT DATE 6 3530 3516 17 KBG2 DOW BW 16 03122/1 5 5929 5510 53 K8G2 SO BK 20 03/22/1 4 7955 6505 61 KBG2 DMI BK 0 03/1011 3 95M 7302 57 K8Cr2 DMI BK 0 0311011 2 10350 7793 42 TBG -2 DMI BK 0 03/10/1 1 11008 6306 38 KBG2 DMI BK 0 03/1011 9-5/8• MLLODT WNDOW (X -04A) 4888' -4904 - FES X 888'-4909' FESX NR D=3.813• 1119W 1-47'X4-i2•FESTNTPKRD=3.856• I i 11318' HE X 5•BKR FRD-E ZXP UP w l I VTlEBK, 4..3! 11318' 4-12' WLEG, D = 3.958• f3J.0 TT NOT LOGE® 11341- Hr X 5• BKR DG FLIX LOCK HGR D= 4.34• 11360' 5' X 4-12• XO, D = 3.90• HES WATER SWE3.L PACKERS NO SIZE TOP DOTH MND 7 41/2' 11477 3.958• 6 412' 12834 3.956' 5 412' 13002 3.958• 4 4112' 13297 3.958' 3 412' 13417 3.958• 2 412• 14142 3.958' 1 412' 14263 3.958' DATE REV BY COMMENTS DATE REV BY CONAINT5 01128/80 NIE4 INITIAL COMPLETION 03128/14 JG/PJC FNALODEAPPROVAL 03111114 625 SIDETRACK(X-MA) 03/21/14 PJC DI3G ED OORRE3CTDIS 03126114 JAD CORFECTED 7' LN2 TO CSG ON26114 PJC GLVS / PERS DYF OPDATES 03126/14 SWC/ PJC GLV CIO (02=14) PRWFDE BAY UNT WELL: X -04A PHMITKb "1131510 AH No: 50029-20412-01 SEC 8, TION, R14F 341' 81 8 168' FWL 13P E§piwalkm (Alaska) X-04 Proposed H EV = Fully Cemented OA Minimum ID = 3.725" @ 11301' 4-1l2" HES XN NIPPLE 4-12' TBG, 12.60,13CR-86 VAM TOP, 11318' .0152 bp1, D = 3.958' SG. 284, L-80 VAM TOP HG D = 6.276' 1146 PERFORATION SL&WRY REF LOG. ANGLEATTOPPE7F: WA' Note* Refer to Production DB for historical cert data 412' 4112• I I 1 I 14-'12'L 12.69, 13CR-86 H1'D 521, 74628' .0152 bPf, D= 3.958' SAFETY NOTES: WELL ANGLE>70'@11737""4.112" CHROME TBG 8 SOLID LNR — SEE PG. 2 FOR PREVIOUS WELLBORE"'• 1 1366' 35/8' Cl7f CSG (02/08114) —[. .14 -IQ- FES X FP, D= 3.813' 2580' 3s/e• w FNR GAS LFT MANDRELS ST h0 TVD DEV TYPE VLV LATCH PORT DATE 6 3530 3516 17 KBG-2 DOW BBC 16 032211 5 5929 5510 53 KBG-2 SO BK 20 032211 4 7955 6505 61 KBG-2 DMI BK 0 0311011 3 9568 7302 57 KBG-2 DMI BK 0 03110/1 2 10350 7793 42 KBG-2 DMI BK 0 03/10/1 1 11008 8306 38 KBG-2 DMI BK 0 0311(/1 35/8' MLLOUff WNDOW (X-041) 4888' - 4904' 12' FES X NP, D = 3813- X 4-12' FES TNT FKIR. D = 3.856' 11318' H7• X 5• BKR HR3 E ZXP LTPw I I I'TIEBK, 4..3! 11318' 4-12- V11EG, ID = 3.958' aMD TT NOT LOGG® 11341' r X 5• BKR DG FLEXLOCK HGP D = 4.34' 5" X 4-12' XO. D= 3.90' UES WATER SWELL PACKERS NO SIZE TOP DEPTH I MND 7 4-12' 11477 8" 6 41/2' 12834 0321114 4112' 13002 8" 4 41/2" 13297 [3.958" 8' 3 4-1/r' 13417 8' 2 41/2' 14142 8' 1 412' 14263 DATE REV BY ODM.BJTS DATE REV BY COL48415 01128180 MES INTLILCOMPLEION 03128114 JDPJC PNALOOEAPPROVAL 03111/14 M25 9DETRACK(X-04A) 0321114 PJC DRLG HO CORRECTIONS OYM14 JMD CORRECTED 7' LNR TO CSG 03Y28114 PJC GLV S / PEFS DVW LFDATES 03126114 SW0 PJC GLV C/O (02/22/14) PRUDHOE BAY UNIT VVELL: X -04A PUMT No: `2131510 AR No: 50.OM20412-01 SEC 8, T10N R14E, 341' RAL 8 168' FW - SIP Exploration (Alaska) 4