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181-027
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 16-13 PRUDHOE BAY UNIT 16-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 16-13 50-029-20566-00-00 181-027-0 N SPT 6730 1810270 1683 407 2595 2537 2517 0 0 0 0 OTHER P Brian Bixby 11/17/2023 This is a producer. CMIT TxIA as per Sundry 319-472 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 UNIT 16-13 Inspection Date: Tubing OA Packer Depth 409 2596 2543 2524IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB231117162646 BBL Pumped:22 BBL Returned:9 Friday, January 12, 2024 Page 1 of 1 1-Oil Producer; excessive fluid pumped for test indicative of well not being fluid packed prior to test. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed IAN 0 8 2020 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operationsphutdew, Suspend ❑ Perforate 11 OtherStimulate ❑ Alter Casing 1:1Change ApprbSedf�� Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 21 Re-enter Susp Well ❑ Other: OA WeIlLock Squeeze 2 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development RI Exploratory ❑ 5. Permit to Drill Number: 181-027 3. Address: P.O. Box 196612, AK 99519-6612 Stratigrephic ❑ S 1 6API Number: 50-029-20566-00-00 7 Property Designation (Lease Number): ADL 028332 B. Well Name and Number: PBU 16-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: Total Depth: measured 12690 feet Plugs measured 12103, 12141 feet true vertical 9307 feet Junk measured -10000, 12401, 12625, feet 126 58 Effective Depth: measured 12103 feet Packer measured 9669,9, 109 10953 feet true vertical 8982 feet Packer true vertical 7326. 8217 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2621 13-3/8" 33-2654 33-2654 5380 2670 Intermediate 11741 9-5/8" 31-11772 31 -8773 6870 / 8150 4760 / 5080 Production Liner 1576 7" 11109 - 12685 8321 -9305 8160 7020 Perforation Depth: Measured depth: 11900 - 12298 feet True vertical depth: 8855-9096 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 29 - 9769 /10000 -111582 29 - 7394 17556 - 8649 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 9669 7326 true vertical depth) 4-1/2" TIW Liner Top Packer 10953 8217 12. Stimulation or cement squeeze summary: Intervals treated (measured): Strapped OA TOC 25" @ the 12 o'clock position & 24" @ the 6 o'clock position. Treatment descriptions including volumes used and final pressure: Monitor OAP for 1 hr for no observable flow. Installed sweeping 90 & 1' standing pipe. Used funnel to fill OA w/ 8 gals WeIlLock using companion side for clear WeIlLock returns Squeeze 0.86 gals (8.86 gals total) WeIlLock into OA @ 2500 psi. WeIlLock sample is setup hard. Final Pressures: OA = 0 psi, IA = 1762 psi, TBG = 276 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 192 730 7791 1762 1 287 Subsequent to operation: 165 758 7744 1773 302 14. Attachments: (requlreE per 20 Arc 25.070.25071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development R1 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: 319472 Authorized Name: Worthington, Aras J Contact Name: Worthington, Area J Authorized Title: Interventions & Integrity Engineer Contact Email: Aras.Worthington@bp.com Authorized Signature: Date: I I� �� Contact Phone: +1 907 564 4102 Form 10404 Revised 04/2017 4e0f115ozo O iBDMS.W JAN 102020 Submit Original Only Daily Report of Well Operations PBU 16-13 ACTI V ITV nATF m IRARA w 0v ***WELL S/I ON ARRIVAL` LRS LOADED IA W/ 365 BBL'S OF CRUDE, TBG W/ 185 BBL'S OF CRUDE. DRIFT W/ 3.80" G.RING & 4-1/2" BLB. BRUSH TO XN @ 9,725' SLM / 9,756' MD. SET 4-1/2" XXN PLUG @ 9,756' MD. ***JOB CONTINUED ON 13-NOV-2019*** 11/12/2019 LRS REMAINED ON LOCATION TO PERFORM CMIT-T x IA. ***WSR Continued from 11/12/2019***(LRS Unit 70 - Assist Slickline: Load & Test) CMIT-TxIA to 2567/2647 psi ***PASSED*** Target Pressure= 2500 psi Max Applied= 2750 psi Pumped an additional 13.8 bbls of Crude for a total of 71.8 bbls of Crude down TxIA to achieve a test pressure of 2599/2678 psi. 1st 15 minute loss of 20/20 psi, 2nd 15 minute loss of 12/11 psi, for a total loss of 32/31 psi in 30 minutes. Bled TxIA to 930/930 psi. Bled back —41.5 bbls Valve Positions - SV, WV, SSV, AL= Closed - MV= Open - CVs OTG / Tags hung on CV/WV / AFE Sign hung on well / ***FLUID PACKED WELL*** 11/13/2019 Final WHP= 930/930/710 ***CONT WSR FROM 11-12-19*** PULL 4-1/2" XX PLUG IN XN @ 9,756' MD 11/13/2019 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED ON WELL STATUS*** RD OA, RU Intergal and block valve w/ high temp gaskets. RD Comp OA flange and VR Plug, RU 11/14/2019 Inter al and block valve w/ high temp gaskets. RDMO. ***Job Com Tete*** T/I/O = SSV/740/0. Temp = SI. Strap TOC in OA (pre Wellock). ALP = 1950 psi, SI @ CV. Strapped OA TOC 25" @ the 12 o'clock position & 24" @ the 6 o'clock position. 11/14/2019 Valve crew in control of valves upon departure. 21:40 T/I/O = SSV/720/410. Temp = Sl. Bleed IAP & OA to 0 psi (pre welllock). ALP = 1900 psi, SI @ CV. IA FL @ 1060' (57 bbls). OA cemented to surface. Started bleeding IAP. Bled OAP from 410 to 0 psi in <5 minutes and held open bleed. 11/16/2019 *** WSR Continued on 11/17/19.*** ***WSR Continued from 11/16/19 TWO = SSV/180/410. Temp = SI. Bleed IAP & OA to 0 psi (pre welllock). ALP = 1900 psi, SI @ CV. IA FL @ near surface. OA cemented to surface. Continued bleeding IAP from 180 psi to 16 psi (gas/fluid) for a total of 6 hours.. Continued holding an open bleed on OAP for a total of 6 hours. Monitored for 30 minutes. During monitor IAP increased 40 psi & OAP increased 50 psi. Final WHPs = SSV/200/50. SV, WV, SSV = C. MV = 0. IA, OA = OTG. 05:30 11/17/2019 T/I/O = SSV/280/0. Temp = SI. OA WeIlLock Squeeze. ALP = 1940 psi, SI @ CV & LV. OA cemented to surface. Monitor OAP for 1 hr for no observable flow. Installed sweeping 90 & 1' standing pipe. Used funnel to fill OA w/ 8 gals WeIlLock using companion side for clear WeIlLock returns. Squeeze 0.86 gals (8.86 gals total) WeIlLock into OA @ 2500 psi. Monitor OAP & SH temp for 24 hrs. 11/17/2019 ***WSR continued on 11/18/19*** ***WSR continued from 11/17/19*** TWO = SSV/280/0. Temp = SI. Monitor OA WeIlLock Squeeze. ALP = 1960 psi, SI @ CV & LV. Continued monitoring OAP & SH temp post OA WeIlLock pumping operation. Two heater trunks in wellhouse. All doors closed. Treecap bled to 0 psi. WH temp = 88° Final WHPs = SSV/280/1860. 11/18/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:00 TWO = SSV/280/1410. Temp = SI. WHPs (post WeIlLock). ALP = 1960 psi, SI @ CV & LV. OA cemented to surface. WH Temp = 75°, adjust heater trunks and close vent on 1 heater. WeIlLock sample has consistency of warm honey. OAP decreased 450 psi in 11 hrs. Increased OAP w/ AL from 1410 psi to 1860 psi. Monitored for 30 min. OAP decreased 20 psi. WH temp = 82*, Final WHPs = SSV/280/1840. 11/19/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 01:30 Daily Report of Well Operations PBU 16-13 T/I/O = SSV/280/1340. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1960 psi). WH temp = 72*. Closed vents on all heaters and adjusted trunks. Wellock sample has not begun to set up. The OAP decreased 500 psi since 0130. Re -Pressured accumulator hose to 1640 psi. 11/20/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:30 TWO = SSV 300/1420. Temp = SI. WHPs (post WeIlLock). ALP = 1960 psi, SI @ CV & LV. WH Temp = 120°. Adjusted heater trunks and opened 2nd outlets on both heaters. WeIlLock sample has not began to set. Both heaters working properly. OAP decreased 180 psi from 01:20 this morning. Increased OAP and accumulator hose to 1600 psi with AL gas. 11/21/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 17:45. TWO = SSV/300/1500. Temp = SI. WHPs (post WeIlLock). ALP = 1960 psi, SI @ CV & LV. OA cemented to surface. WH temp = 77°. Both heaters working properly, both heater vents open. Heater trunk adjusted slightly. OAP decreased 100 psi in 11 hrs. WeIlLock sample has consistency of molasses. 11/22/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 04:45 TWO = SSV/290/1520. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1820 psi). WH temp = 62*. Adjusted both heater trunks. Both heaters working properly. 1 heater vent left open. The IAP remained unchanged and the OAP decreased 30 psi overnight. Wellock sample has the consistency of cold molasses (will no longer move if sample bottle is turned on its side). 11/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:10 TWO = SSV/290/1500. Temp = SI. WHPs (post WeIlLock). ALP = 1820 psi, SI @ CV & LV. OA cemented to surface. WH temp = 58°. Both heaters working properly, 1 heater vent open. Adjust heater trunk. OAP decreased 20 psi in 8.5 hrs. WeIlLock sample is setting up, firm but able to be indented. 11/24/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 00:30 T/I/O = SSV/290/1600. Temp = SI. WHPs (Post WeIlLock). ALP = 1870 psi, SI @ CV & LV. OA cemented to surface. WH temp = 83*. Both heaters working properly, 1 heater vent open. OAP increased 100 psi over night. WeIlLock sample is firm, but able to be indented. 11/25/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 04:00 T/I/O = SSV/290/1320. Temp = SI. WHPs (Post Wellock). ALP = 1870 psi, SI @ CV & LV. OA cemented to surface. WH temp = 84°. Upon arrival both heaters working properly, both heater vents open. OAP decreased 170 psi in 12 hrs. Increased OAP to 1800 psi with AL and monitored for 30 min. Repositioned heater trunks. Wellock sample is firm. Final WH temp = 86° and OAP = 1520 psi. 11/26/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:30 TWO = SSV/290/1500. Temp = SI. WHPs (Post WeIlLock). ALP = 1870 psi, SI @ CV & LV. OA cemented to surface. WH temp = 80*. Both heaters working properly, both heater vents open. OAP decreased 20 psi in 12 hrs. WeIlLock sample is firm but pliable. 11/27/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 04:15 TWO = SSW100/1630. Temp = SI. WHPs (past WeIlLock). ALP = 1830 psi, SI @ CV. WH Temp = 65F. Both heaters working properly. Adjusted trunks slightly. IAP decreased 190 psi, OAP decreased 70 psi in 10 hours. WeIlLock sample is hard. 11/28/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:45 T/I/O = SSV/290/1500. Temp = SI. WHPs (Post WeIlLock). ALP = 1830 psi, SI @ CV & LV. OA cemented to surface. WH temp = 40°. Both heaters working properly, closed 1 heater vent and side door on well house. OAP decreased 130 psi in 9.5 hrs. WeIlLock sample is set up. 11/29/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 01:15 TWO = SSV/290/1700. Temp = SI. WHPs (post Wellock). ALP @ 1860 psi, SI @ CV. WH temp = 92*. OAP decreased 120 psi in 10 hrs. No adjustment needed on heater trunks. 11/30/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 03:30 T/I/O = SSV/290/1760. Temp = SI. WHPs (post Wellock). ALP @ 1860 psi, SI @ CV. WH temp = 102°. OAP increased 100 psi. Adjustmented heater trunks. 12/1/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:30 Daily Report of Well Operations PBU 16-13 TWO = SSV/270/1500. Temp = SI. WHPs (post Wellock). ALP @ 1860 psi, SI @ CV. WH temp = 60°. OAP increased 260 psi. Bled OAP from 1500 psi to 0 psi in <1 min. Rigged down CNG hose. 12/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:45 T/I/O = SI/250/0. Install OA valve. Remove integrals from OA working and companion outlets. Both outlets completely full of well lock. Install existing 3" Gray as working side OA, Torque to API specs. Install tapped blind flange with allemite fitting onto companion side OA flange, Torque to API specs. RDMO ***Job Complete*** SEE LOG FOR DETAILS. Final T/I/O = SI/250/0. MV = O. 12/4/2019 SSV/WV/SV = C. IA/OA = OTG T/I/O = 290/29oNAC. Temp = SI. Assist Ops with PoP (Post WellLock). ALP = 1930 psi, SI @ CV. Monitored WHPs during PoP. OAP unchanged during 5 hours post PoP. Final WHPs 280/1750NAC, Temp = 132F, ALP online. 12/6/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:45 TWO = 280/1750Nac. Temp = 132*. WHPs (Post Wellock). ALP = 1750 psi, open @ CV. WHPs unchanged overnight. 12/7/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 TWO = 280/1750/0. Temp = 130F. WHPs (Post WellLock). ALP online. WHPs unchanged overnight. 12/8/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 17:15 T/l/0 = 270/1740/0. Temp = 140°. WHPs (Post Wellock). ALP = 1740 psi, open @ CV. IAP decreased 10 psi, OAP unchanged since 12/8/19. 12/10/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 22:10 TWO = 270/1750/0. Temp = 140°. WHPs (Post Wellock). ALP = 1750 psi, open @ CV. IAP increased 10 psi & OAP unchanged overnight. 12/11/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 T/I/O = 270/1750/0. Temp = 140°. WHPs (Post Wellock). ALP = 1750 psi, open @ CV. WHPs unchanged overnight. 12/12/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:00 T/I/O = 260/1760/0. Temp = 140°. WHPs (Post Wellock). ALP = 1760 psi, open @ CV. TP & IAP decreased 10 psi overnight. 12/13/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:45. T/I/O = 270/1750/0. Temp = 140°. WHPs (Post Wellock). ALP = 1750 psi, open @ CV. TP & IAP increased 10 psi, & OAP unchanged overnight. 12/14/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 16:30 T/I/O = 220/1770/0. Temp = 139*. WHPs (Post wellock). AL open @ casing valve. The TP decreased 50 psi, IAP increased 20 psi and the OAP remained unchanged since 12-14-19. 12/16/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 09:00 T/l/O = 200/1740/0. Temp = 124*. WHPs (Post Wellock). AL open @ CV. TP decreased 20 psi, IAP decreased 30 psi, & OAP unchanged since 12/16/19. 12/19/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:34 T/1/0 = 210/1750/0. Temp = 136*. WHPs (Post Wellock). AL open @ casing valve. The TP decreased 10 psi, IAP decreased 20 psi and the OAP remained unchanged since 12-16-19. 12/20/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:15 T/I/O = 240/1740/0+. Temp = 142*. WHPs (Post Wellock). AL online. TP increased 30 psi, IAP decreased 10 psi and the OAP remained unchanged since 12/20/19. 12/22/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 04:45 T/I/0 = 250/1750/0+. Temp = 1470. WHPs (Post Wellock). AL online. TP increased 10 psi, IAP & OAP unchanged overnight. 12/23/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 21:45 T/I/O = 240/1750/0+. Temp = 1420. WHPs (Post Wellock). AL online. TP unchanged, IAP increased 10 psi and the OAP remained unchanged overnight. 12/23/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 03:30 T/1/0 = 220/1760/0+. Temp = 142°. WHPs (post Wellock). AL online. TP decreased 30 psi, IAP increased 10 psi, OAP unchanged overnight. 12/24/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 TWO = 280/1740/0+. Temp = 150°. WHPs (post Wellock). AL online. TP increased 50 psi, IAP decreased 20 psi, OAP unchanged overnight. 12/26/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 03:20 Daily Report of Well Operations PBU 16-13 TWO = 280/1750/0+. Temp = 150°. WHPs (post Wellock). AL online. TP unchanged, IAP increased 10 psi, OAP unchanged overnight. 12/27/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 16:30 270/1750/0+. Temp = 150°. WHPs (post Wellock). ALP = 1750 psi, online. TP decreased 10 psi, IAP increased 10 psi, OAP unchanged overnight. 12/28/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 TWO = 260/1750/0+, Temp = 150°. WHPs (post Wellock). ALP = 1750 psi, online. TP decreased 10 psi, IAP & OAP unchanged overnight. 12/29/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 12:30 TWO = 320/1760/0+. Temp = 150°. WHPs (post WellLock). AL online @ 1760 psi. TP increased 60 psi, IAP increased 10 psi, OAP unchanged overnight. 12/30/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 T/1/0 = 290/1750/0. Temp = 151 °. WHPs (Post WellLock). AL online @ 1750 psi. OA cemented to surface. TP decreased 30 psi, IAP decreased 10 psi, OAP decreased to 0 psi. 12/31/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:30 T/I/O = 320/1760/0+. Temp = 1490. WHPs (Post WeIILOCk). AL online @ 1760 psi. OA cemented to surface. TP increased 30 psi, IAP increased 10 psi, OAP increased to 0+ psi overnight. 1/1/2020 ISV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30 TRFF= WELLHEAD= MCEVOYSSH/GRAYGEN2 ACTUATOR= -- - AXELSO OKB. ELEVEV = 7N, _ 70'. BF ELEV ----- 3951" KOP= - - -- --- 3100'1 Max Angle = 59' � 8600" Dafen MD = 11924'1 Datm TVD= _ 8800 -SS, I" CSG, 47", L-80 TCIII3TC, D= 8.681" - 2100' 13-3/8" CSG, 72", L-80, D = 12.347" 2654" - Minimum ID =3.725" @9756' 4-1@" HES XN NIPPLE SAFETY NOTES: "4412" CHROMETBG" S�gION: B SAND D AGED40 -5/8" CSG BELOW Tr 16-13 ORIGINALLY SET @ 12103'. 2088' 9-5/8" HES ES CEAM34TER 2212' 4-12" HES X NP, ID = 3.813" T-1/2" TBG, 12.6", 13CR-80 VAM OP, .0152 bpf, D = 3.958" CAUTION: W NOT WIRELINE BROW THIS POINT - 9-6/8" CSG IS BADLY DAMAGED BELOW TT. ALSO SIZABLE JUNK BEHIND 4-12- TBG STUB (2003 RWO) TOP OF 7" LNR11109' m— 4-1/2' TBG, 12.6", 13 -CR -80,.0152 bpf, ID = 3.958-1 U-0/6" ( U, 4 /9, L-aU/,LKYUo, x] = PEWORATION SUMMARY REF LOG: BHCS ON 06/08/81 ANGLEATTOP PHiF: 50' Q 11900' Note: Infer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8' 4 11900 -11940 O 09/20/81 AM1G 3-3/8' 2 11900 -11940 O 0329/92 4998 50 MUG 11994 -12028 S 03/19/82 08/11/91 3-3/8" 1 12048 - 12060 O 03/29/92 R( 0 04/28/71 2 12054 - 12094 S 03/1982 08/11/91 DW RK 12140 - 12180 S 03/1982 08/11/91 49 Mull' 12196-12216 S 05/1984 08/11/91 3-1/8" 4 11900 -11940 O 06/1885 08/1181 3-1/8" 4 12236 - 12248 S 06/1885 08/1181 3-1/8" 4 12267 - 12274 S 06/1885 08/11/91 3-1/8" 4 12284 - 12298 S 0611885 08/11/91 3-1/8" 4 12284 - 12298 S 05/1984 0811181 7' LAIR 29#, L-80, .0371 bpf, D = 6.184'12685' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3152 3149 11 AM1G DOME RC 16 0329/14 4 5726 4998 50 MUG SO f8C 24 0329/14 3 7509 6102 55 AM1G DAM R( 0 04/28/71 2 9298 7086 52 MNG DW RK 0 04/25/06 1 9577 7264 49 Mull' OMY R( 0 0428/11 9648' 4-1/2" HES X NP, ID= 3.813' 9669' 9-5/8' X 4-1/2" BKR S-3 WR D = 3.875' 9694' 4-12' HES X NP, ID = 3.813" 9756' 4-12' HES XN NP, D = 3.725- 976W 4-12" WLEG, D = 3.958" 04122/03 JBBVTLH RWO (2003) 04/08/14 MBMJMD GLV C/O (0329114) EFMJ TT NOT LOGGED 10000' 4-12" TBG STUB (TAGGED 04/19/06 DIM 10953' 9-5/8' X 4-12" TNV HBBP PKR 11553' 4-12' OTIS X LANDNG NP, 1 = 3.813' 11570' 4-12' OTB XN NP, ID = 3.725" 11582' — 4-12' TUBNG TAIL WLEG 11592' ELMD TT LOGGED 06/06/95 1 12103' 12141' 12401' 1-12" DGLV SEE PRUDHOE BAY UNIT WELL: 16-13 PERMIT No: R 810270 API No: 50-02920566-00 SEC 24, T10N, R15E,1652' FNL 8 548' F WL DATE REV BY COMMENTS DATE REV BY COMMENTS Osmanli ORIGINAL COMPLETION 07/08/06 KSB)PJC JGLV CIO(07MA8) 09/07194 RWO 1994 05/01/11 WEC/ PJC GLV CIO (0428/11) 04122/03 JBBVTLH RWO (2003) 04/08/14 MBMJMD GLV C/O (0329114) 0429/06 N235 RWO (2006) 10/15/19 JNUJMD ADD BF ELEV & MBC CORRECTIONS 05/06/06 DCR/TLH DRLG DRAFT CORRECTION BP Exploration(A=aska) 05/19/06 KSB/TLH GLV C/O(05/it/0fi) THE STATE 01ALASK 1 GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 16-13 Permit to Drill Number: 181-027 Sundry Number: 319-472 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 w .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, WJerem.rice Chair DATED this 7/`day of October, 2019. ABDMS'f--'OCT 111019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 " ..v`r v `v OCT 15 2019 C'M 10/2a_//s� . r � � i. Type of Request: Abandon CI Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 A V I (nown own ❑ Suspend ❑ Perforate ❑ Other -Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ After -Casing ❑ Other OA WellLock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 181-027 r 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20566-00-00 ' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? B. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 r PBU 16-13 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028332 PRUDHOE BAY, PRUDHOE OIL V 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(R): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): -10000, 12690 9307 12103 8982 12103 12141 12401,12625,12650,12658 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 34-114 34 - 114 15: 520 Surface 2621 13-3/8" 33 - 2654 33 - 2654 5380 2670 Intermediate 11741 9-5/8" 31 -11772 31-8773 6870 / 8150 4760/5080 Production Liner 1576 7" 11109 - 12685 8321-9305 1 8160 1 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11900 - 12060 8855-8956 4-1/2" 12.6# 13Cr80 29 - 9669 / 10000 - 11582 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9669/7326 4-1/2" TI W Packer 10953/8217 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: October 22 2019 15. Well Status after proposed work: Oil 0 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, Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.com Authorized Name: Worthington, Ards J Contact Phone: +1 907 564 4102 Authorized Title: Interve*ens B Integrity Engineer Authorized Signature: Date: o-•� p COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ SOP Test ❑ Mec/h�an�ic/al Intvegrity TeGst�❑ Clearance ❑ �/tsLocation Other: Gri �1f� C.- ✓L�/C 7 / !�cvV ? 3BDMS1:P4CT 2 2 2019/ Post Initial Injection MIT Req'tl? Yes ❑ No ❑ Spacing E ption Required? Yes ❑ No 1�7 Subsequent Form Required: /Q .�0 y `Y/�(�/�' COMMISSION Approved by: 1 ' l COMMISSIONER COMMISSION Date: \l7 FWFA IT Form 10-403 Revised 04/2017 tq�,�� ORIGINAL n�a vtz ic�e.��9 Approved application is valid for 12 months from the date of approval. 11011-7 Submit Form and Attachments i.nn„ Dpuuplicate ,/ 16-13 OA WeIlLock Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Meredyth Richards (907) 564-4867 Expected Start Date: October 20, 2019 History: Well: 16-13 16-13 is a gas -lifted producer which exhibits recent OA re -pressurization not manageable by bleeds. The OA was fully cemented during a RWO in 2006. A cold TIFL passed 2/16/2018. A PPPOT-IC passed to 3500 psi on 10/13/19. Current Status The well is currently shut-in and will likely be classified as "Not -Operable" by BP. Objective Squeeze the cemented OA with Well Lock to seal off the OA re -pressurization. Procedure Ia., (fM/T--Tk'r!W fib ZSc�9 Dsi 14 ND OA Gate Valve, NU OA Integral. !!// 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 2500 psi per RPs. 3. After 1 week of cure time, ND Integral and NU Gate Valve. 4. POP Under Evaluation and monitor OA for re -pressurization. 5. Re -squeeze OA with Well Lock if necessary. TRFF = dv1a r W WELLHEAD = MCEVOYSSWGRAYGEN2 ACTUATOR= AXELSON OKB. ELEV = 70' BF. ELEV = 39.51' TOP = 3100' MaxA le= 59' A 8600' Datum MD = 11924' Dakin TVD = 8800' SS CSG, 47#, L-80 TC6'BTC, D 13-3/8" CSG, 72#, L-80, D - Minimum ID = 3.725" @ 9756' 4-1/2" HES XN NIPPLE SAFETYNOTES: "4-1/2"CHRDMETBG"" 16 -13 � AG ND TOP A712214094127103 SG BELOW TT ISP ORIGINALLY SET @ 12103'. 2066' 9-5/8" HES ES � 14-12' TBG , 12.6#, 13CR-80 VAM I 9769' TOP, .0152 bpf, D = 3.958' CAUTION: DO NOT WIRELINE BELOW THIS POINT - 9-5/8" CSG IS BADLY DAMAGED BELOW TT. ALSO SIZABLE JUNK BEHIND 4-12" TBG STUB (2003 RWO) TOP OF 7" LNR 11- 1 412- TSG, 12.69, 13 -CR -80, .0152 bpf, D = 3.958' 1 479, L -80/S00.95, D = 8.681' PERFORATION Sl1NMARY RD= LOG. BRCS ON 06/08/81 ANGLEATTOP FEiF 50"@11900 Note: Refer to Production DB for historical perf data SIZE SPF I INTERVAL Opn1SqzJ SNOT I SQZ 3-3/8" 4 11900 -TI 94-0 O 0920/91 11 3-3/8" 2 11900 -11940 O 0329/92 4 5726 4998 11994 - 12028 S 03/19/82 08/11/91 3-3/8" 1 12048 - 12060 O 0329/92 55 MMG OMY 12054 - 12094 S 03/19/82 08/11/91 9298 7006 12140 - 12180 S 03/19/82 08/11/91 0 0425/06 12196 -12216 S 05/19/84 08/11/91 3-1/8" 4 11900- 11940 O 06/18/85 08/11/91 3-1/8' 4 12236 - 12248 S 06/18/85 08/11/91 3-1/8" 4 12267- 12274 S 06/18/85 08/11/91 3-1/8" 4 12284- 12298 S 06/18/85 08/11/91 3-1/8" 4 12284 - 12298 S 05/19/84 08/11/91 PBTD -1 12656' 7' LNR 299, L-80, .0371 bpf, D = 6.184' 12665' HESX NP, D= AS LFT MALI ST MD ND TDEV TYPEJ VLV I LATCH PORT DATE 5 3152 3149 11 MMG DOME RK 16 0329/14 4 5726 4998 50 MMG SO RK 24 0329/14 3 7509 6102 55 MMG OMY RK 0 04/28/11 2 9298 7006 52 MMG OMY RK 0 0425/06 1 9577 7264 49 MMG DMY RK 0 04/28/11 ( llSilL" �-1412- TUBING TAL WLEG 11597 ELMD TT LOGG® 06/06/95 1 12401' 1 IBP IBP 1-12" DGLV MAGNETIC DECENTRALI ER T 4-12"I$XNP,D=3.813' =J 9-5/8' X4-12' BKR 5-3 PKR, D = 3.875° 9694' 4-12" HESS X NP, D = 3.813" 9756' 4-12' HFS XN NP, D = 3.725' 9768' 4-12' V4LEG, D = 3.958" 04/08/14 MBM/JMD GLV C/O 0329/14) H.MD TT NOT LOGGED 10000' 4-12" TBG STUB (TAGGED 04/19/06 DMB) BP Exploration (Alaska) 10953' 9-518' X 4-7/2' TNV HBBP PKR 11553' 4-1/2° OTS X LANDING NP, 0=3 813 1157W 4-12' OTS XN NP, D = 3.725' ( llSilL" �-1412- TUBING TAL WLEG 11597 ELMD TT LOGG® 06/06/95 1 12401' 1 IBP IBP 1-12" DGLV MAGNETIC DECENTRALI ER T PRUDHOE BAY UNIT WELL: 16-13 PERMIT No: 91810270 API No: 50-029-20566-00 SEC 24, Tl ON. R1 5E, 1652'FNL & 548' FWL DATE REV BY COMMENTS DATE REV BY COMMENTS 06/76/81 ORIGINAL COMPLETION 07/08/08 KSB/PJC GLV C/O 07/02A8) RWO(1994) 05/01/11 WEC/PJC GLV C/00428/11) RWO (2003) 04/08/14 MBM/JMD GLV C/O 0329/14) RWO (2006) §05/06;06EDCRfnLH 10/15/19 JNUJMD ADD BF ELEV & MISC CORRECTIONS DRLGDRAFTCORRECTION BP Exploration (Alaska) GLV C/O (OSE 1/D6) 0 i a c L Y Y O C L O f0 U 3 w o N L c p, a � L ,.. Y O N n Q ci O 3° � O C O 0 M O N -0 m ti 3 0 a O 3 Q ? O to N N N OO y3j L VI UL L O CL 3 .L .o Z E- L L Y O w L C d Q MA E L Y m v Y N � L L Q O J O L — C � C Y O Y C U O O a v W O 3 to 3 w v mc o a f6 n a E v m u m bLO ry N v a — v C L O m O crO u U f0 JO a N L) v r o Q w O o v n O_ C y 1/1 N L N C L O L U r 3 pO vii = L =o � Q a 0 H A O Uo t0 Y N 10 m r 3 W v V w V J N N � CL 3 E A L E Ln O 0 O O m c� O m M � OO C c f6 G r a v O 10 X M C m N > QO O NE a .. v E W m i � v16f v L W Q d U m e O ` C7 C O c O M d Lm cN G C 0 C O L O O 3 X V QI N W Y C W O r-, N 1i F {A 0 i a c L Y Y O C L O f0 U 3 w o N L c p, a � L ,.. Y O N n Q ci O 3° � O C O 0 M O N -0 m ti 3 0 a O 3 Q ? O to N N N OO y3j L VI UL L O CL 3 .L .o Z E- L L Y O w L C d Q MA E L Y m v Y N � L L Q O J O L — C � C Y O Y C U O O a v W O 3 to 3 w v mc o a f6 n a E v m u m bLO ry N v a — v C L O m O crO u U f0 JO a N L) v r o Q w O o v n O_ C y 1/1 N L N C L O L U r 3 pO vii = L =o � Q a 0 H Rixse, Melvin G (CED) Subject: FW: 16-13 OA Gas Sample From: Worthington, Aras J <Aras.Worthington@bp.com> Sent: Monday, October 21, 2019 3:26 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: 16-13 OA Gas Sample Mel and Guy, As discussed for this OA Well Lock squeeze candidate, we took an OA gas sample from the re -pressurizing OA of 16-13 on 10/17/2019 and below are the details. CO2 does not show up at all and is the main fingerprint for either reservoir or lift gas which is usually upward of 10%. Also, the methane content is -10- 20% higher than typical for reservoir or lift gas. So we would conclude that this is not reservoir or lift gas. @ s.maM Deal: API '`�L`'fifi00 Desogen OUTEfl ANNUWS PD62963 Pw OUTERANNULUS Gale 1A'17yals _ TypeGAWMCO POSI110N Dnpagbn Re _ _ UM. 1115 IBTLOF BN GRSDRY REAL _ —. ._-- --_-. 1116.50_ 'BN6F KUGRSSATIDEAL ;. imle — — _--_ _.__.MID F BNGRSSAT REAL BTU NET 1 00110 - —. - _ - C66ipUP-MOL' .__...._ _ —. _. - - ... MOLES; WP -MOL%. _. --__ __. _ ----__—__ _.. _ 02080 MOLE,. C>GRDUP-MOL'- _ 006d0 GRO CBUPJJOL;. 00P0 MLEF. MDLE2 C9GRJUP RgRMPLIZED; I.O.Ol6C MOLEY __MPP ..____._ --- MOLEts COESSIBIUh'FAC. - --- -- D9916 - EMANEMDLE i609R1 18UTANEMOL: _ - _— I D.zfi9B ---___. MDLE% I-0ENTMlEAtOLe. _—___. '.00900 MOLE' UNE PRESSURE yp pgU LINE TEMPEMtUflE DEGF METHaNEMOI: 89.7 — MDLE0. MOLIY or N9UTAMEMOL, :042M1M MOLES. N.PENTANEMOLY _ 'BFvSC - MDLE% 62C6NTNITR�NMOL._ 02CONTAMMO :0 _..__.._._. '.LEX PF,bPANEMOLS _..w__._—_._. _— _._ _.-_2 31M MOLE:', s_EALIDEaL — SPG R_— —_ OM-7 _`0.6301 ----- SPG REAL. 1465 PSlA_. _—�—. _— --_- O.fi301 Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907) 664-4102 Cell: (907) 440-7692 STATE OF ALASKA 1I¿ 5).!/~ ALASKAe.. AND GAS CONSERVATION C&ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Plug Perforations o Perforate New Pool o Perforate o Other o Re-Enter Suspended Well ~ Repair Well ~ Pull Tubing o Operation Shutdown o Stimulate o Waiver o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028332 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner Length 110' 2654' 11772' 1576' 2100' Perforation Depth MD (ft): Perforation Depth TVD (ft): 70' 12690 9307 12141 9005 4. Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 181-027 6. API Number: 50-029-20566-00-00 9. Well Name and Number: PBU 16-13 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 12141 feet Junk (measured) 12401 feet Size MD TVD Burst Collapse 20' 110' 110' 13-3/8" 2654' 2654' 4930 2670 9-5/8" 11772' 8773' 6870 4760 7" 11109' - 12685' 8321' - 9305' 8160 7020 9-5/8" 2100' 2100' 6870 4760 SC!~NN¡::;f! j 3 ZDOe .. ..'J" ~f,· ;v~.. 11900' - 12060' 8855' - 8956' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# 4-1/2", 12.6# 9-5/8" x 4-1/2" Baker 'S-3' packer; 9-5/8" x 4-1/2" TIW 'HBBP' packer; 13Cr80 13Cr80 Surface - 9769' 10000' - 11582' 9669' 10953' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ES Cementer located at 2088'. RBDMS 8Fl MAY 1 6 2006 Treatment description including volumes used and final pressure: Cut and pulled tubing from 9817'. Cut 9-5/8" casing at 2095' and pulled. Run 9-5/8" tieback to surface. Cement w/144,8 Bbls (695 s ) Class 'G'. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure correct to the· 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowledge. Sundry Number or N/A if C.O. Exempt 306-091 o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Title Technical Assistant Phone OSrrdl. Prepared By Name/Number: Date v7/Dfo Terrie Hubble, 564-4628 Submit Original Only 564-4628 TREE = 4-1/16 crw WELLHEAD" MCEVOY SSH/GRA Y GEN2 e ACTUATOR = AXELSON KB. ELEV = 70' BF. ELEV = KOP= 3100' Max Angle - 59 @ 8600' Datum MD = 11924' Datum lVD = 8800' SS 19-5/8" CSG, 47#, L-80 TCIVBTC, ID = 8.681" I 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 3.725" @ 9756' 4-1/2" HES XN NIPPLE 4-1/2" TBG, 12.6#, 13CR-80 V AM TOP, .0152 bpf, ID = 3.958" CAUTION: 00 NOT WIRELINE BELOW THIS POINT - 9-5/S" CSG IS BADLY DAMAGED BELOW TT. ALSO SIZABLE JUNK BEHIND 4-1/2" TBG STUB (2003 RWO) TOPOF 7" LNR I 11109' 14-1/2" TBG, 12.6#, 13-CR-SO, .0152 bpf, ID = 3.958"1 19-5/8" CSG, 47#, L-80/S00-95, ID = 8.681" I PERFORA TION SUMMA RY REF LOG: BHCS ON 06/08/81 ANGLE AT TOP PERF: 50 @ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 11900-11940 0 09/20/91 3-3/8" 2 11900 - 11940 0 03/29/92 11994 - 12028 S 08/11/91 12048 - 12060 0 03/29/92 12054 - 12094 S 08/11/91 12140 -12180 S 08/11/91 12196 - 12216 S 08/11/91 11900-11940 0 06/18/85 12236 - 12248 S 06/18/85 12267 - 12274 S 06/18/85 12284 - 12298 S 06/18/85 12284 - 12298 S 05/19/84 3-3/8" 3-1/8" 3-1/8" 3-1/8" 3-1/8" 3-1/8" 4 4 4 4 4 IPBTD I I 7" LNR, 29#, L-80, .0371 bpf, ID - 6.184" I 12658' 12685' DA TE REV BY COMMENTS 06/16/81 ORIGINAL COMPLETION 09/07/94 RWO (1994) 04/22/03 JBMITL RWO (2003) 04/29/06 N23S RWO (2006) 05/06/06 DCRlTLH DRLG DRAFT CORRECTION 16-13 2088' 2212' ST MD 5 3152 4 5726 3 7509 2 9298 1 9577 9648' 9669' 9694' 9756' 9769' SA FEA:>TES: **4-1/2" CHROMETBG** CAlfTW: BADLY DAMAGED 9-5/8" CSG BELOW TT SL TAGGED SAND TOP @ 121404/27/03. IBP ORIGINALLY SET @ 12103'. H 9-5/8" HES ES CEMENTER -14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS lVD DEV TYPE VLV LATCH 3149 11 MMG OCR 4998 50 MMG DMY RK 6102 55 MMG DMY RK 7086 52 MMG DMY RK 7264 49 MMG DMY RK -14-1/2" HES X NIP, ID = 3.813" I -j 9-5/8" X 4-1/2" BKR 8-3 PKR, ID = 3.875" -j4-1/2" HES X NIP, ID = 3.813" I -j4-1/2" HES XN NIP, ID = 3.725" I -14-1/2" WLEG, ID = 3.958" I H ELMD TT NOT LOGGED I -j4-1/2" TBG STUB (TAGGED 04/19/06 DIMS) -19-5/8" X 4-1/2" Trw HBBP PKR I PORT DATE o 04/25/06 o 04/25/06 o 04/25/06 o 04/25/06 o 04/25/06 11553' H4-1/2"OTISXLANDINGNIP,ID=3.813" I 11570' -14-1/2" OTIS XN NIP, ID = 3.725" I 11582' H4-1/2" TUBING TAIL WLEG I 11592' H ELMD TT LOGGED 06/06/95 I -j4-1/2"IBP(SET07/13/95) - SEE SAFETY NOTE 12141' -jCMTTOP(CTM) I DA TE REV BY COMMENTS -1CA-ROO-ZO-TG I -1 PKR ELEMENT FROM IBP -11-1/2" DGLV I H MAGNETIC DECENTRALIZER 2' PRUDHOE BA Y UNIT WELL: 16-13 PERMIT No: '1810270 API No: 50-029-20566-00 SEC 24, T10N, R15E, 1586.35' FEL & 565.31' FNL BP Exploration (Alaska) e e Well: Field: API: 16-13 Rig Workiver Prudhoe Bay Unit 50-029-20566-00 Accept: Spud: Release: 04/11/06 N/A 04/29/06 PRE-RIG WORK 03/08/06 DRIFTED OUT OF TBG TO 11700' SLM W /3.70" CENT W / SAMPLE BAILER, NO RESTRICTION OR TIGHT SPOTS. 03/11/06 ANN: T/I/O=1750/1740/80. TEMP=SI. OART. (POST PPPOT-IC). IA FL AT 9819' (9-5/8" X 4-1/2" BKR S-3 PKR), OA FL AT 70' (4 BBLS), BLED OAP FROM 80 PSI TO 0 PSI IN 45 MIN. DURING BLEED lAP DECREASED 20 PSI. MONITORED FOR 1 HR, OAP INCREASED 8 PSI. FINAL WHP'S = 1750/1720/8. 03/12/06 TAGGED ABOVE PERFS WITH GAUGES, UNABLE TO GET PAST. PERFORM STATIC AT STOPS, 11,740' MD AND 11,640' MD, DRIFT W/3.25" CENT, AND SAMPLE BAILER TO 12,132' SLM. SET 4.5" XXN PLUG AT 11,566' SLM, BLEED FROM 1800 PSI TO 1550 PSI, GOOD TEST. 03/13/06 ANN: T/I/O= 1640/1710/10. TEMP= SI. MONITOR POST OART, TBG AND IA FL'S (POST PPPOT) DAY 2. TBG FL AT 3658' (55.6 BBLS). IA FL AT 3658' (195.7 BBLS) BETWEEN STA #1 AND #2. TP DECREASED 110 PSI, lAP DECREASED 10 PSI AND OAP UNCHANGED OVERNIGHT. 03/14/06 PTT : T/I/O= 3350/3460/500 MIT T FAILED TO 3500 PSI. CMIT TXIA FAILED TO 3500 PSI. ESTABLISHED LLR .5 BPM AT 3350 ON TBG, 3460 ON IA STEADY FOR 20 BBLS. MIT OA PASSED TO 2000 PSI. PUMPED 6 BBLS CRUDE TO PRESSURE UP TO 2000 PSI. 1ST 15 MIN TEST LOST 50 PSI, 2ND 15 MIN TEST LOST 20 PSI. FINAL WHP'S= 2000/2250/0. 03/25/06 DRIFT W/3.70" CENT, 4.5" BLB, AND SB TO 9850' SLM. UNSUCCESSFUL ATTEMPT TO SET 4.5 PX PLUG BODY. BAND TBG W/4.5" BLB, AND 3.80 GAUGE RING. LRS PUMPED 125 BBLS CRUDE. ATTEMPT TO SET PLUG AGAIN. 03/26/06 SET 4.5 PX PLUG BODY AT 9833' SLM. RUN 4.5 CHECK SET TO 9833' SLM (SHEARED). SET PRONG W/ 1.75 F.N AND 96" OAL. DRAW DOWN TBG. LEFT WELL S/I. 04/04/06 JET CUT TUBING. TUBING CUT AT 9817'. CUTTER HEAD GETTING STUCK IN NIPPLE AT 9808'. 04/05/06 LATCHED E-LlNE TOOL STRING AT 9790' SLM W/3.63" BELL GUIDE AND 2" JUC. RECOVERED ALL OF E- LINE TOOLSTRING AND BOW SPRINGS. JET CUTTER WAS SHOT, TURNED WELL OVER TO DSO. WELL LEFT S/I. e e BP EXPLORATION Page 1 of 10 Oþerations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/10/2006 03:00 - 06:00 3.00 RIGD P POST Rig down,lay down derrick prepare to move to DS16-13 06:00 - 19:00 13.00 RIGD P POST Wait on well / pad preperation on DS16-13. 19:00 - 21 :30 2.50 MOB P PRE Lay matts on DS16-13. Move camp pits and shop. Spot rig on DS16-13 and raise derrick. 21 :30 - 00:00 2.50 RIGU P PRE Spot camp, shop and pits. Rig up floor and hook up pits. 4/11/2006 00:00 - 06:00 6.00 RIGU P PRE Rig up on DS # 16-13. Hook up pits interconnect lines. Level pits & secure flow line. Spot/berm cuttings tank. Bridle down mast. RlU floor. Complete pre-spud check list. 06:00 - 06:30 0.50 RIGU P PRE Hold pre-spud/HSE meeting with Co-man, Tool Pusher and Drill Crew. Rig accepted @ 06:00 hrs, 4/11/2006 06:30 - 07:30 1.00 WHSUR P DECOMP R/U Drill Site Maint lubricator & pull BPV. Tubing on a vacuum. 07:30 - 13:30 6.00 WHSUR P DECOMP Install secondary annulus valve. RlU circ lines. Take on seawater. PJSM. Reverse circ diesel from tubing. Swap lines, pump 45 bbl Safe-Surf-O pill down tubing through choke @ 3 bpm until diesel is displaced. Increase rate to 5 bpm @ 420 psi & displace well to clean seawater +- 754 bbl to tubing cut @ 9833'. 13:30 - 14:00 0.50 WHSUR P DECOMP Using dry rod, install BPV & test from below to 1000 psi, OK. 14:00 - 14:30 0.50 WHSUR P DECOMP Blow down all surface equip. RID circ lines. 14:30 - 16:00 1.50 WHSUR P DECOMP PJSM. N/D tree & adaptor flange. 16:00 - 17:30 1.50 BOPSUF P DECOMP PJSM. N/U 135/8" 5000# BOPE. 17:30 - 22:30 5.00 BOPSUF P DECOMP R/U test equip. Test BOP with 41/2" test joint to 250 psi low test & 3500 high. Test top & bottom rams, blind rams, annular preventor, HCR kill & choke, manual kill & choke, choke manifold & top drive valves. Perform accumulator test. Witness of test waived by AOGCC rep John Spaulding. 22:30 - 23:30 1.00 BOPSUF P DECOMP Dry rod out tree test dart. Pull BPV with DSM lubricator. 23:30 - 00:00 0.50 PULL P DECOMP Install long bails on top drive. Prepare to LID 4.5" 12.6# 13Cr VamAce tubing. 4/12/2006 00:00 - 00:30 0.50 PULL P DECOMP Install long bails on top drive. P/U single of drill pipe and double spear. 00:30 - 02:30 2.00 PULL P DECOMP Engage hanger & pull free @ 200K. Monitor well. Pull hanger to rig floor @ 130K UWT. Break out & LID hanger. 02:30 - 04:00 1.50 PULL P DECOMP PJSM. PIU tubing handling equip. RlU compensator & double stacked tongs. 04:00 - 14:30 10.50 PULL P DECOMP POH LID 4.5" 12.6# 13Cr VamAce tubing from JET cut @ 9817'. 14:30 - 15:00 0.50 PULL N RREP DECOMP Repair pipe skate, trouble shoot & replace joystick control. 15:00 - 19:30 4.50 PULL P DECOMP POH LID 4.5" tubing from 4300'. Layed down 307 joints of 4.5" tubing, 5 ea. GLM & 2 ea. X nipples & 1 cut joint 4.85' long. 19:30 - 21:00 1.50 PULL P DECOMP Rig down tubing handling equip. Clear & clean rig floor. 21 :00 - 22:00 1.00 PULL P DECOMP Remove long bails from top drive. 22:00 - 00:00 2.00 BOPSUF P DECOMP RlU 4" test joint. Install test plug. Test 2 7/8" x 5" variable pipe rams, 3.5" x 6" variable pipe rams & annular preventor to 250 psi low test & 3500 psi high test. OK. Pull test plug & install wear ring. RID test equipment. 4/13/2006 00:00 - 03:30 3.50 EVAL P DECOMP PJSM. RlU SWS & RIH with USIT/GR/CCL logging tools. Log from 3000' to surface. TOC @ 2110'. RID SWS. 03:30 - 04:30 1.00 PULL P DECOMP PJSM. PIU 95/8" casing cutter assy. 04:30 - 07:00 2.50 FISH P DECOMP RIH with 9 5/8" casing cutter picking up 4" HT40 drill pipe. 07:00 - 07:30 0.50 FISH P DECOMP Establish base lines, UWT = 62K, DWT= 62K, RWT = 62K. Printed: 5/1/2006 1 :28:45 PM e e BP . EXPLORATION Page 20f 10 Operations Summary Report Legal Well Name: 16-1 3 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2006 07:00 - 07:30 0.50 FISH P DECOMP Free torque = 2K @ 65 RPM. Pump @ 3 bpm @ 500 psi. Locate casing collar @ 2100', pick up 5' and cut casing @ 2095'. Max torque = 10K. Pick up & confirm cut. 07:30 - 10:00 2.50 CLEAN P DECOMP Open 9 5/8" x 13 3/8" annulus to cuttings tank, close pipe rams & break circ @ 1 bpm @ 1500 psi. Bleed off and surge annulus. Circ arctic pack out @ 3 bpm @ 2000 psi. Circ out 119 bbl. Bleed to 0 psi, shut in annulus & open rams. Monitor well. 10:00 - 11 :00 1.00 CLEAN P DECOMP POH from 2095'. 11 :00 - 11 :30 0.50 FISH P DECOMP LID casing cutter BHA. 11 :30 - 12:30 1.00 BOPSU¡:; P DECOMP M/U wear ring puller & BOLDS. Pull wear ring. 12:30 - 13:30 1.00 BOPSU¡:; P DECOMP Change upper pipe rams to 9 5/8". 13:30 - 14:00 0.50 BOPSU¡:; P DECOMP Install test plug, RIU 4" test equip & test door seals on upper pipe rams to 250/3500 psi. 14:00 - 15:30 1.50 FISH P DECOMP M/U 95/8" spear, engage 9 5/8" casing. BOLDS & pull hanger free with 240K. UWT 130K when free. 15:30 - 18:30 3.00 CLEAN P DECOMP Pump 50 bbl Safe-Surf-O soap pill & 60 bbl120 degree diesel followed by 146 bbl seawater. Spot diesel in arctic pack between 133/8" x 9 5/8" casings. Allow to soak for 30 min. Displace out with 145 bbl seawater @ 5 bpm @ 150 psi. 18:30 - 19:30 1.00 FISH P DECOMP Pull 9 5/8" hanger to rig floor. LID spear. 19:30 - 00:00 4.50 FISH P DECOMP RIU 9 5/8" casing handling equip & POH LID casing from 2095'. 4/14/2006 00:00 - 04:00 4.00 FISH P DECOMP PJSM. POH LID 9 5/8" casing. Recovered 48 joints, 1 cut joint 40'Iong, 12 bow spring centralizers. Lost in hole: 4 springs, half of 3 springs and half of 1 lower clamp ring. RID casing handling equip. Clear & clean rig floor. 04:00 - 06:00 2.00 BOPSUF P DECOMP PJSM. Drain BOP stack. Close blind rams & change upper pipe rams to 3 1/2" x 6" variable rams. 06:00 - 07:00 1.00 BOPSUF P DECOMP M/U test joint, install test plug. Test upper pipe rams & door seals to 250/3500 psi. Install wear ring, LID test joint. 07:00 - 09:30 2.50 FISH P DECOMP P/U packer mill BHA. Change of plan from Anch office. LID BHA. 09:30 - 10:00 0.50 FISH P DECOMP Pull wear ring to accomodate large O.D. polish mill. 10:00 -11:00 1.00 FISH P DECOMP Cut & slip 102' of drill line. Clean & inspect dwks. Inspect brake linkages & dwks traction motor brushes. Service spline on Baylor dynamatic brake. 11 :00 - 11 :30 0.50 FISH P DECOMP Service top drive. 11 :30 - 13:30 2.00 FISH P DECOMP P/U 95/8" wash pipe BHA to 960'. 13:30 - 14:30 1.00 FISH P DECOMP RIH from 960' to 2080'. Install top drive blower hose. Dry tag stump @ 2095'. Torque = 1/2K @ 60 rpm. UWT = 95K, DWT = 95K, RWT = 97K. Pump @ 6 bpm @ 250 psi. 14:30 - 15:00 0.50 FISH P DECOMP Polish 9 5/8" casing stump from 2095' to 2101'. WOB = 5K. Torque = 2K @ 60 rpm. Pump pressure = 300 psi @ 6 bpm. 15:00 - 15:30 0.50 FISH P DECOMP Pump 45 bbl high vis sweep @ 12 bpm @ 870 psi. 15:30 - 16:30 1.00 FISH P DECOMP POH from 2101' to BHA @ 960'. 16:30 - 17:30 1.00 FISH P DECOMP Stand back HWDP & drill collars. LID wash pipe assy. 17:30 - 18:00 0.50 FISH P DECOMP Install wear ring. 18:00 - 19:00 1.00 FISH P DECOMP P/U reverse circ boot basket, jars, bumper sub & HWDP to 957'. 19:00 - 20:00 1.00 FISH P DECOMP RIH to 3012', work through top of 95/8" casing stub @ 2095'. RIH PIU drill pipe from 3012'. 20:00 - 00:00 4.00 FISH P DECOMP RIH P/U 4" HT40 drill pipe from 3012' to 7216'. Printed: 5/1/2006 1 :28:45 PM · BP EXPLORATION Page 30f10 Operations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Dèscription of Operations 4/15/2006 00:00 - 02:30 2.50 FISH P DECOMP RIH P/U HT40 drill pipe to 9789'. 02:30 - 03:30 1.00 FISH P DECOMP Install top drive blower hose. Establish parameters. UWT = 190K, DWT = 145K, RWT = 170K. Torque @ 60 rpm = 6/7K. Pump @ 252 gpm @ 1330 psi. Tag 4 1/2" tubing stub @ 9798'. Work reverse boot basket down to top of 9 5/8" packer @ 9802'. Work boot basket up & down stump rotating & reciprocating. 03:30 - 04:30 1.00 FISH P DECOMP CBU @ 380 gpm @ 3000 psi. 04:30 - 05:00 0.50 FISH P DECOMP Pump dry job, remove top drive blower hose. Blow down top drive & monitor well. 05:00 - 08:00 3.00 FISH P DECOMP POH from 9802' to BHA @ 957'. Monitor well. 08:00 - 09:30 1.50 FISH P DECOMP POH with BHA, clean out reverse circ boot baskets. Recovered : 2 ea 1/2 bow spring centralizers & 1/2 of lower clamp ring. 09:30 - 10:30 1.00 FISH P DECOMP RIH with BHA, rerun reverse circ boot basket assy. 10:30 - 14:30 4.00 FISH P DECOMP RIH. Work BHA through 9 5/8" casing stub @ 2095'. RIH to 9729'. Install top drive blower hose. 14:30 - 16:00 1.50 FISH P DECOMP Wash over 41/2" tubing stub on top of 9 5/8" packer @ 9802'. Rotate & reciprocate. Pump @ 252 gpm @ 1600 psi. UWT = 205K, DWT = 140K, RWT = 170K. Free torque = 7K@ 50 rpm. Increase pump rate to 357 gpm @ 3000 psi & CBU. Remove top drive blower hose & blow down top drive. 16:00 - 19:30 3.50 FISH P DECOMP POH from 9802' to BHA @ 957'. 19:30 - 21 :00 1.50 FISH P DECOMP PJSM. Stand HWDP & drill collars back in derrick. Clean out rev circ boot basket. Recovered: 1 piece (2" x 1 1/2" x 1/4") of bow spring centralizer. LID tools, clear & clean rig floor. 21 :00 - 22:30 1.50 FISH P DECOMP P/U packer mill, boot baskets, pump out sub, jars, acc jars & HWDP. 22:30 - 00:00 1.50 FISH P DECOMP RIH from 975' to 3776'. 4/16/2006 00:00 - 02:00 2.00 FISH P DECOMP RIH with packer mill from 3776' to 9747'. 02:00 - 03:30 1.50 FISH P DECOMP PJSM. Cut & slip 86' of drill line. Service top drive. Install top drive blower hose. 03:30 - 09:30 6.00 FISH P DECOMP Establish parameters. UWT = 200K, DWT = 145K, RTW = 170K. Torque = 6/7K @ 70 rpm. Pump @ 245 gpm @ 700 psi. SPR for both pumps @ 30 spm = 80 psi, @ 45 spm = 160 psi. Wash down to top of 41/2" tubing stub @ 9798'. Mill 4' tubing stub & 9 5/8" packer to 9806'. 09:30 - 11 :30 2.00 FISH P DECOMP Pump high vis sweep, CBU @ 490 gpm @ 2250 psi. Flow increase @ bottoms up. Monitor well, circ out packer gas. Shut down pumps, monitor well. Losing 12 to 15 bph static. Remove top drive blower hose & blow down. 11:30-15:30 4.00 FISH P DECOMP POH from 9806' to BHA @ 975'. Losses to well = 22 bph. 15:30 - 17:30 2.00 FISH P DECOMP Stand back HWDP & drill collars. LID accelerator jars, packer mill, boot baskets & subs. Clean out boot baskets, recovered 4 gallons of iron cuttings & slip segments. Clear & clean rig floor. 17:30 - 19:00 1.50 FISH P DECOMP PIU 95/8" packer spear, XO, pump out sub, jars, acc jars & HWDP to 964'. 19:00 - 22:00 3.00 FISH P DECOMP RIH from 964' to 9736'. Break circ, establish parameters. UWT = 200K, DWT = 145K. Pump @ 160 gpm @ 350 psi. 22:00 - 23:00 1.00 FISH P DECOMP Engage fish @ 9806', work fish & jar free with 275K. UWT = 210K, DWT = 145K. Monitor well, no returns. Well on a vacuum. Pump 70 bbl @ 450 gpm through kill line, no returns. Drop dart & open circ sub. Blow down top drive. 23:00 - 00:00 1.00 FISH P DECOMP POH from 9806' to 8434'. e e Printed: 5/1/2006 1 :28:45 PM e e BP EXPLORATION pagø 4 of1 0 Operations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/17/2006 00:00 - 03:30 3.50 FISH P DECOMP POH from 8434' to BHA @ 965'. Monitor well. Change elevatorslhandling equipment. 03:30 - 07:00 3.50 FISH P DECOMP POH with BHA. Rack back HWDP & collars. LID recovered 9 5/8" packer & tail pipe assy. Punch tail pipe to relieve pressure. LID pups, tail pipe & overshot. Clear rig floor. 07:00 - 09:00 2.00 FISH P DECOMP P/U 8.5" shoe & 9 5/8" casing scraper to 974'. 09:00 - 12:00 3.00 FISH P DECOMP RIH tag obstruction @ 9933'. 12:00 - 14:30 2.50 FISH P DECOMP Install top drive blower hose. Establish parameters. UWT = 215K, DWT = 147K, RWT = 175K. Torque = 7/8K @ 70 rpm. Pump @ 125 gpm @ 50 psi, no returns. Attempt to clean out to 4.5" tubing stub inside of 95/8" casing @ 10000'. Torquing up & stopped @ 9936' with no weight on shoe. 14:30 - 18:00 3.50 FISH P DECOMP POH from 9936' to BHA @ 974'. Top filling hole @ 138 bph. 18:00 - 19:30 1.50 FISH P DECOMP Stand back HWDP & drill collars. LID casing scraper. Drag blocks on scraper damaged, gauge wear on inside & outside of shoe. Clean rig floor. 19:30 - 20:30 1.00 FISH P DECOMP RIH with shoe, drill collars & HWDP to 970'. (no scraper) 20:30 - 23:30 3.00 FISH P DECOMP RIH from 970' to 9929'. 23:30 - 00:00 0.50 FISH P DECOMP Install top drive blower hose, establish parameters. UWT = 215K, DWT = 147K, RWT = 175K. Torque = 10/11K @ 70 rpm. 4/18/2006 00:00 - 01 :30 1.50 FISH P DECOMP Attempt to work down to 4 1/2" tubing stub inside 9 5/8" casing @ 10000', tagged obstruction @ 9936'. Pump down annulus & drill pipe. Rotate down to 9954'. Pump @ 250 gpm @ 40 psi, no returns. UWT = 215K, DWT 145K, RWT = 175K. String torquing up to 15K. Unable to pass 9954'. 01 :30 - 02:30 1.00 FISH P DECOMP POH to 9836'. Blow down top drive. monitor well. Slip & cut 104' drill line. 02:30 - 03:30 1.00 FISH P DECOMP Service top drive & dwks. 03:30 - 08:30 5.00 FISH P DECOMP POH from 9836' to BHA @ 969'. Change elevators & POH with BHA. Stand back HWDP & drill collars. Break shoe, large chunks of cement plugging shoe & wash pipe extension. Clear & clean rig floor. Monitor well, on a vacuum. 08:30 - 09:30 1.00 FISH P DECOMP M/U new flush O.D. shoe & RIH with BHA to 968'. 09:30 - 13:30 4.00 DECOMP RIH to 9927'. Install top drive blower hose. 13:30 - 17:00 3.50 FISH P DECOMP Establish parameters. UWT = 220K, DWT = 145K, RWT = 177K. Torque = 10K @ 60 rpm. Pump @ 125 gpm @ 170 psi. Wash & ream from 9954' to 9972'. No returns. Top filling hole @ 135 bph. 17:00 - 20:30 3.50 FISH P DECOMP POH from 9972' to BHA @ 968'. 20:30 - 23:00 2.50 FISH P DECOMP Stand back HWDP & drill collars. Break shoe, large chunks of cement plugging shoe & wash pipe extension. LID drive sub, XO, boot baskets, jars & bumper sub. Clear & clean rig floor. Line up on 95/8" x 13 3/8" annulus & top fill hole @ 106 bph. 23:00 - 00:00 1.00 FISH P DECOMP Pull wear ring. R/U & test BOPE to 250 psi low test & 3500 psi high test. Tested choke manifold, top & bottom rams, blind rams, annular preventor, HCR valves, kill & choke line valves, floor safety valves & top drive valves. Perform Koomey test. Witness of test waived by AOGCC rep Jeff Jones. Test witnessed by Tool Pusher Ronnie Dalton & WSL James Willingham. 4/19/2006 00:00 - 04:30 4.50 FISH P DECOMP Test BOPE to 250 psi low test, 3500 psi high test. Witness of test waived by AOGCC rep Jeff Jones. Test witnessed by Tool Printed: 5/1/2006 1 :28:45 PM e e BP EXPLORATION Page son 0 Operations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/19/2006 00:00 - 04:30 4.50 FISH P DECOMP Pusher Ronnie Dalton & WSL James Willingham 04:30 - 05:00 0.50 FISH P DECOMP Blow down test lines. Pull test plug & RID test equipment. Install wear ring. 05:00 - 07:00 2.00 FISH P DECOMP PJSM. P/U bladed mill with smooth OD & slightly concave bottom. RIH to clean out to top of 4.5" tubing stub inside 9 5/8" casing. 07:00 - 10:00 3.00 FISH P DECOMP RIH with drill pipe from derrick from 958' to 9917'. 10:00 - 11 :30 1.50 FISH P DECOMP Install blower hose on top drive. Obtain parameters. UWT = 210K, DWT = 145K, RWT = 170K. Torque = 7/9K @ 35 rpm. Pump @ 245 gpm @ 235 psi (no returns). Wash & ream from 9971' to 9975'. Pull up to 9955' and work back down. Tagged up @ 9972". Unable to pass 9972'. 11 :30 - 12:00 0.50 FISH P DECOMP POH to 9917'. Blow down top drive and remove blower hose. Monitor well. 12:00 - 15:00 3.00 FISH P DECOMP POH from 9917' to BHA @ 958'. 15:00 - 17:00 2.00 FISH P DECOMP Stand back HWDP & drill collars. LID junk mill. Clear & clean rig floor. 17:00 - 18:00 1.00 FISH P DECOMP Trouble shoot dwks drum clutch, replace drum clutch quick release. Service rig. 18:00 - 19:00 1.00 FISH P DECOMP P/U junk mill, XOs, string mill, DCs & HWDP. RIH to 972'. 19:00 - 22:00 3.00 FISH P DECOMP RIH from 972' to 9929'. Install top drive blower hose & establish parameters. UWT = 210K, DWT = 145K, RWT = 177K. Torque = 11.5K @ 60 rpm. 22:00 - 00:00 2.00 FISH P DECOMP Attempt to clean out to 41/2" tubing stub @ 10000' inside 9 5/8" casing. Tag up, work through tight spot @ 9960'. Tag again @ 9972'. Ream from 9972' to 9974'. WOB = 5K. Pump @ 190 gpm @ 260 psi (no returns) Rotate @ 60 rpm @ 13K torque. 4/20/2006 00:00 - 01 :00 1.00 FISH P DECOMP Attempt to clean out to 41/2" tubing stub @ 10000' inside of 9 5/8" casing. Mill and work down from 9974' to 9977'. Mill with 5K to 30K WOB. No increase in torque, not making hole. 01 :00 - 03:00 2.00 FISH P DECOMP POH to 9836', monitor well. Blow down top drive & remove blower hose. Cut & slip 96' of drill line. Service top drive, crown & dwks. 03:00 - 06:00 3.00 FISH P DECOMP POH from 9836' to BHA @ 970'. Monitor well. 06:00 - 09:00 3.00 FISH P DECOMP POH with BHA, stand back HWDP, drill collars, jars & bumper sub. LID mills & junk basket. Clear & clean rig floor. Discuss with Anchorage office next course of action. 09:00 - 10:30 1.50 FISH P DECOMP LID jars, bumper sub & subs. Send all fishing tools off rig floor. 10:30 - 11 :30 1.00 FISH P DECOMP Not running drill collars, move collars for drill pipe access. Bring RBP & tools to rig floor. 11 :30 - 17:30 6.00 FISH P DECOMP P/U HOWCO 9 5/8" retrievable bridge plug & RIH to 9700'. 17:30 - 18:30 1.00 FISH P DECOMP M/U top drive and attempt to set RBP @ 9700,9617' & 9430'. No success. 18:30 - 22:30 4.00 FISH P DECOMP POH from 9430'. Observed 3K drag. Attempt to set RBP @ 8965', no success. POH to 7570', attempt to set RBP. No success. POH to BHA. 22:30 - 00:00 1.50 FISH P DECOMP Stand back HWDP. RBP left in hole unset. Clean rig floor. 4/21/2006 00:00 - 01 :00 1.00 FISH P DECOMP LID RBP running tool. Bring Baker fishing tools to the rig floor. 01 :00 - 02:30 1.50 FISH P DECOMP M/U 8 1/8" overshot and grapple. P/U pump out sub, bumper sub & oil jars. RIH with HWDP & drill collars from derrick to 948'. Printed: 5/1/2006 1 :28:45 PM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 16-1 3 Common Well Name: 16-1 3 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/21/2006 02:30 - 07:00 4.50 FISH P DECOMP RIH to fish unset 95/8" RBP. Tag @ 9910', push RBP to 9919'. Engage plug, pull up to 9907'. Set RBP & set down 25K weight to confirm set. 07:00 - 08:30 1.50 FISH P DECOMP Fill hole with seawater (200+ bbls) Close rams & test RBP to 1000 psi for 10 min, OK. Attempt to release from RBP but grapple in overshot disengaged. Hole taking fluid. RIH & engage plug @ 9933'. POH to 9691'. 08:30 - 10:00 1.50 FISH P DECOMP Set RBP @ 9691'. Pick up 10K over to confirm set. Slack off to bumper sub free travel & attempt to release from RBP. Grapple in overshot disengaged and dropped RBP. Pump 400 bbl seawater, no returns. RIH & chase plug to 9943' & engage RBP with overshot. 10:00 - 14:00 4.00 FISH P DECOMP POH from 9943' to BHA @ 948'. Top filling hole @ 140 bph. 14:00 - 15:00 1.00 FISH P DECOMP POH with BHA, rack back HWDP & drill collars. 15:00 - 16:30 1.50 FISH P DECOMP POH, LID RBP, bumper sub & jars. Clear rig floor. 16:30 - 18:00 1.50 FISH P DECOMP PJSM. P/U rebuilt RBP & running tool on HWDP. RIH to 658'. Change elevators & handling equip. 18:00 - 22:30 4.50 FISH P DECOMP RIH to 9704'. UWT = 180K, DWT = 135K. Set RBP @ 9689'. Confirm set. Release from RBP. POH to 9676'. Fill hole with seawater. 22:30 - 23:00 0.50 FISH P DECOMP Test RBP & well bore to 1000 psi for 10 min, OK. Record on chart. 23:00 - 00:00 1.00 FISH P DECOMP Service top drive & dwks. Prepare to cut drill line. 4/22/2006 00:00 - 01 :30 1.50 FISH P DECOMP Cut & slip drill line. Inspect & adjust dwks brakes. 01 :30 - 02:00 0.50 FISH P DECOMP Pump dry job. Blow down top drive. 02:00 - 05:30 3.50 FISH P DECOMP POH with RBP running tool to 658'. Stand back HWDP. 05:30 - 06:30 1.00 FISH P DECOMP PJSM. P/U HOWCO Retrievable bridge plug # 2. RIH to 658'. 06:30 - 08:30 2.00 FISH P DECOMP RIH from 658' to 4019'. UWT = 110K, DWT = 110K. 08:30 - 09:00 0.50 FISH P DECOMP Set RBP @ 4000'. POH 1 stand drill pipe. 09:00 - 11 :30 2.50 FISH P DECOMP Dump 1500# of river sand down drill pipe to RBP. Pump 1 bpm to displace sand. 11:30-12:30 1.00 FISH P DECOMP Pump 30 bbl high vis spacer @ 3917'. Displace well to 9.8 ppg brine @ 12 bpm @ 850 psi. Blow down top drive. 12:30 - 14:30 2.00 FISH P DECOMP POH from 3917' to BHA 658'. Stand back HWDP. LID RBP running tool. 14:30 - 20:00 5.50 FISH P DECOMP Pull wear bushing. P/U 11 3/4" shoe & 1 joint of wash pipe, boot baskets, scraper, bumper sub & oil jar. RIH with drill collars & HWDP to 987'. Slow running speed, brine flowing over the top of the drill pipe. 20:00 - 22:30 2.50 FISH P DECOMP RIH to 2012'. Install top drive blower hose. Wash down to 9 5/8" casing stub @ 2095'. Wash down from 2095' to 2116'. Pump @ 400 gpm @ 500 psi. Torque = 1.6K @ 40 rpm. UWT = 95K, DWT = 92K, RWT = 94K. 22:30 - 23:00 0.50 FISH P DECOMP R/U to reverse circ, pump high vis sweep @ 290 gpm @ 1000 psi. No metal, junk or debris @ bottoms up. 23:00 - 00:00 1.00 FISH P DECOMP POH from 2100' with wash pipe. 4/23/2006 00:00 - 01 :30 1.50 FISH P DECOMP POH with 11 3/4" wash pipe BHA. Stand back HWDP & drill collars. 01 :30 - 03:00 1.50 FISH P DECOMP PJSM. LID shoe, wash pipe, boot basket & 133/8" casing scraper. Clear rig floor. 03:00 - 06:00 3.00 FISH P DECOMP PJSM with drill crew & SWS. R/U lubricator extension & pack-off. RIH with 3 strand string shot to shock 9 5/8" casing connection. Locate 9 5/8" casing collar@ 2100'. Fire shot - e Printed: 5/1/2006 1 :28:45 PM e e BP EXPLORATION Page 7 of 10 Operations Summary Report . Legal Well Name: 16-1 3 Common Well Name: 16-1 3 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/23/2006 03:00 - 06:00 3.00 FISH P DECOMP across collar. POH with wire line. RID SWS. 06:00 - 08:30 2.50 FISH P DECOMP PJSM. RIH with bullnose on drill collars. P/U casing back-off tool. RIH with HWDP to 964'. 08:30 - 10:30 2.00 FISH P DECOMP RIH from 964' to 2405' filling pipe with fresh water. Space out back-off tool power section @ 9 5/8" collar @ 2100'. 10:30 - 12:00 1.50 FISH P DECOMP Pressure up to 1500 psi, set down 22K & set bottom anchor. Pressure up to 4700 psi to set upper anchor. Pressure up to 2100 psi (= 21000 ft Ibs) & break 9 5/8" connection @ 2100'. Cycle tool & back out connection 6 turns total. 12:00 - 13:30 1.50 FISH P DECOMP POH wet with casing back off tool from 2405' to BHA @ 964'. 13:30 - 15:00 1.50 FISH P DECOMP POH with BHA, rack back HWDP. LID casing back-off tools. 15:00 - 16:30 1.50 FISH P DECOMP POH, rack back drill collars. Clear rig floor. 16:30 - 17:30 1.00 FISH P DECOMP P/U 9 5/8" spear & bumper sub. RIH with HWDP to 664'. 17:30 - 18:00 0.50 FISH P DECOMP RIH from 664' to 2095'. Spear 9 5/8" casing stub at 2100'. Rotate to the left to back out casing stub. 18:00 - 20:00 2.00 FISH P DECOMP POH from 2100' to BHA @ 664'. Rack back HWDP, LID bumper sub, spear & 4' long 95/8" casing stub. Clear rig floor. 20:00 - 21 :30 1.50 FISH P DECOMP Set test plug. Change bottom rams to 9 5/8". 21 :30 - 22:00 0.50 FISH P DECOMP Test door seals on bottom rams to 250/3500 psi, OK. 22:00 - 00:00 2.00 FISH P DECOMP RlU to run 95/8" 47# L-80 TCII casing. 4/24/2006 00:00 - 01 :00 1.00 CASE P RUNPRD PJSM. R/U to run 95/8" casing. 01 :00 - 07:00 6.00 CASE P RUNPRD RIH with 95/8" 47# L-80 TCII casing to 2100'. Torque turn all connections. 07:00 - 09:00 2.00 CASE P RUNPRD PJSM. R/U top drive to screw into 9 5/8" casing stub @ 2100'. String weight = 115K. Free torque = 1500 ft Ibs. Screw into casing collar & work torque down. Apply 18000 ft Ibs at surface. Rig down top drive & subs. 09:00 - 09:30 0.50 CASE P RUNPRD Pull test casing to 250K. Pressure test casing to 1500 psi, OK. 09:30 - 13:00 3.50 CEMT N CEMT RUNPRD PJSM with all person ell. R/U cement head, adaptor, manifold & hoses. Pump 5 bbl water, test lines to 4500 psi. Displace water to tee with 9.8 ppg brine. Pressure up to 2700 psi & open Howco ES cementer. Mix & pump 140 bbl of 15.8 ppg class "G" cement. Drop ES cementer closing plug & displace with 120 bbl of 9.8 ppg brine. Close annular preventor, open 133/8" x 9 5/8" annulus. Continue to displace with 154 bbl Plug did not bump. Displace all cement to surface. 13:00 - 13:30 0.50 CEMT N CEMT RUNPRD Check for flow, LID cement head. Closing plug stuck in cement head. Blow down cement lines. M/U top drive to 9 5/8" casing. 13:30 - 16:00 2.50 CEMT N CEMT RUNPRD Circ @ 3 bpm. Take on 9.8 ppg brine to pits. Have new batch of cement delivered to rig. 16:00 - 20:30 4.50 CEMT P RUNPRD M/U HOWCO cement head & circ lines. PJSM with all personell. Pump 5 bbl water, test lines to 4500 psi. Displace water to tee with 9.8 ppg brine. Pump 144 bbl cement. Drop ES cementer closing plug. Displace with 120 bbl 9.8 ppg brine. Close annular preventor, open 133/8" x 95/8" annulus. Continue to displace, cement to surface 136 bbl into displacement. Bump plug 154 bbl into displacement with 1875 psi. Check ES cementer closed, OK. CIP @ 19:00 hrs. Blow down cement lines. RID cementers. Flush BOP stack. 20:30 - 21 :30 1.00 CEMT P RUNPRD Suck fluid out of 9 5/8" casing with super sucker. 21 :30 - 00:00 2.50 BOPSUF P RUNPRD Remove secondary annulus valve. Split BOP stack @ top of tubing spool. Prepare to set emergency slips. 4/25/2006 00:00 - 03:30 3.50 BOPSUF P RUNPRD Set emergency slips on 9 5/8" casing with 200K tension. RlU Printed: 5/1/2006 1 :28:45 PM e e BPEXPLORATION Page 8 of 10 Operations SumrnaryReport Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations . 4/25/2006 00:00 - 03:30 3.50 BOPSUF P RUNPRD WACHS cutter & cut casing. Prep stump & install pack-off. Load shoulder on pack-off to high for lock down screws to engage. Send top ring to machine shop & machine ring down. 03:30 - 04:30 1.00 BOPSUF P RUNPRD PJSM Rig down long bales. Rig up test joint 04:30 - 08:30 4.00 BOPSUF P RUNPRD Install pack off load shoulder ring. Engage lock down screws. Nipple up tubing spool. Pump plastic packing. Test pack off to 3800psi for 30 min. Install secondary Annulus valve. 08:30 - 10:30 2.00 BOPSU¡:; P RUNPRD PJSM Nipple up BOP 10:30 - 11 :30 1.00 BOPSU¡:; P RUNPRD PJSM Change out 9 5/8" rams to 2 7/8" x 5" variables. 11 :30 - 12:00 0.50 BOPSU¡:; P RUNPRD Set test plug 12:00 - 13:00 1.00 BOPSU¡:; P RUNPRD Check Rams door bolts,cellar and gland nuts. Fill BOP stack,choke manifold, and test joint. Check for leaks. 13:00 - 18:00 5.00 BOPSU¡:; P RUNPRD Test BOP 250 low 3500 high, record and chart. IBOP failed Witness waived by AGOCC rep Chuck Sheive, test witnessed by BP rep Howard West. 18:00 - 21 :30 3.50 BOPSU¡:; P RUNPRD Change out lower topdrive hydraulic IBOP valve. Function test valve. Fill lines & stack for testing. 21 :30 - 22:30 1.00 BOPSU¡:; P RUNPRD Resume testing BOP 250psi low 3500psi high,record and chart. Blow down equipment. Test Witnessed by BP rep Blair Neufeld. 22:30 - 20:00 21.50 BOPSU¡:; P RUNPRD Rig down test equipment. Install wear bushing (10 9 1/16") 4/26/2006 00:00 - 01 :30 1.50 BOPSU¡:; P RUNPRD Make up BHA #17 to 34'. RI H with BHA to 956' 01 :30 - 02:30 1.00 BOPSU¡:; P RUNPRD RIH 956' to 1982'. Install blower hose 02:30 - 03:30 1.00 BOPSU¡:; P RUNPRD Tag cement @2032'. Wash/Ream to closing plug @2087'. Drill closing plug and ES cementer@2088'. Up wt. 100K,Down wt. 100K, rotating wt. 100K. 80 RPM @ 3-5K torque, 12 BPM @ 950psi Drill cement to 2093' 03:30 - 04:00 0.50 BOPSU¡:; P RUNPRD Short test casing to 2500psi (good) Blow down surface equipment. 04:00 - 04:30 0.50 BOPSU¡:; P RUNPRD Drill cement from 2093'. Drill baffle plate @ 2096' 04:30 - 05:30 1.00 BOPSU¡:; P RUNPRD Run in hole to top of sand @3969'. Wash down to 3975' and pump sweep. 05:30 - 06:00 0.50 BOPSU¡:; P RUNPRD Test casing to 2500psi. Chart and hold for 30 min. 06:00 - 06:30 0.50 BOPSU¡:; P RUNPRD Pump dry job, Blow down top drive, remove blower hose. 06:30 - 08:00 1.50 BOPSU¡:; P RUNPRD PJSM. POOH from 3975' stand back HWDP and collars to 34'. 08:00 - 09:30 1.50 BOPSU¡:; P RUNPRD PJSM. Lay down and clean out junk baskets. Break off bit.Clean and clear floor. 09:30 - 10:00 0.50 BOPSU¡:; P RUNPRD PJSM. Make up reverse circulating basket to 26' 10:00 - 12:00 2.00 BOPSU¡:; P RUNPRD RIH with drill collars and HWDP to 951'. Run in with drill pipe from 951' to 3939',install blower hose and drop ball. 12:00 - 14:00 2.00 BOPSU¡:; P RUNPRD Displace well to 8.5ppg seawater while washing down from 3939' to 3993'. Circulate and reciprocate. Up wt. 125k, down wt. 11 Ok, rotating wt. 120k. 267 GPM @2500psi. Shut down pumps, monitor well,blow down top drive. Remove blower hose. 14:00 - 17:00 3.00 BOPSU¡:; P RUNPRD POOH 3993' to 951'. Change out handling equipment. Rack back HWDP and drill collars. Lay down and clean out reverse circulating and junk baskets, nothing recovered. Clear floor, bring up tools. 17:00 - 18:00 1.00 BOPSU¡:; P RUNPRD Make up BHA # 19, add wash pipe extentsion to reverse circulating basket. RIH with BHA to 954' 18:00 - 19:30 1.50 BOPSU¡:; P RUNPRD Change out handling equipment. RIH 954' to 3943',install Printed: 5/1/2006 1 :28:45 PM e e BP EXPLORATION Page gof 10 Operations Summary Report Legal Well Name: 16-1 3 Common Well Name: 16-1 3 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2006 18:00 - 19:30 1.50 BOPSUF P RUNPRD blower hose. 19:30 - 20:30 1.00 BOPSUF P RUNPRD Wash down from 3943' to 4003'. Tag RBP @4001' with 2-3k.Up wt. 125k,down wt. 115k, rotating wt. 124k. 20 RPM @ 3k ft/lbs. Attempt to tag RBP a second time, plug dropped downhole. Wash down to 4035', pump high vis sweep and circulate bottoms up. 20:30 - 23:30 3.00 BOPSUF Þ RUNPRD POOH 4035' to 954'. Stand back HWDP and drill collars to 29'. Lay down reverse circulating and junk baskets, no junk recovered. Lay down BHA, clean and clear floor. 23:30 - 00:00 0.50 BOPSUF P RUNPRD Make up Halliburton overshot retrieval tool. 4/27/2006 00:00 - 01 :30 1.50 BOPSUF P RUNPRD Run in hole with overshot and HWDP to 650' 01 :30 - 02:00 0.50 BOPSUF P RUNPRD Run in hole with drill pipe 650' to 3824' 02:00 - 03:30 1.50 BOPSUF P RUNPRD Cut and slip drill line. Inspect and adjust brakes. Grease Elmago coupling. 03:30 - 04:00 0.50 BOPSUF P RUNPRD Service Top drive 04:00 - 06:00 2.00 BOPSUF P RUNPRD Run in hole attempt to locate RBP. Tag@6610, engage and set down 20k. Relax element and pick up with 5k overpull. 06:00 - 09:00 3.00 BOPSUF P RUNPRD POOH 6610' to 650'. Stand back HWDP,lay down RBP. Clear floor. Recovered closing plug ring. 09:00 - 12:00 3.00 BOPSUF P RUNPRD Inspect RBP overshot. RIH with HWDP to 650'. RIH from 650' to 9606' 12:00 - 12:30 0.50 BOPSUF P RUNPRD Make up topdrive and obtain parameters. Up wt. 195k,down wt. 125k, rotating wt. 145k. 3-4k ft/lbs torque. 245 GPM @500psi. 12:30 - 13:00 0.50 BOPSUF P RUNPRD RIH 9606' to 9689' Tag RBPand engage. Verify latch and release RBP. Monitor well. Well on vacuum,fill down annulus @110BPH with no returns. 13:00 - 16:30 3.50 BOPSUF P RUNPRD POOH 9869' to 650' 16:30 - 18:00 1.50 BOPSUF P RUNPRD POOH from 650' stand back HWDP,break out RBP and retrieval tool. Clear and clean floor. 18:00 - 19:30 1.50 BOPSUF P RUNPRD Lay down drill collars from derrick. 19:30 - 20:30 1.00 BOPSUF P RUNPRD Make up RTTS tool and run in with HWDP to 658'. 20:30 - 00:00 3.50 BOPSUF P RUNPRD RIH 658' to 8964' 4/28/2006 00:00 - 00:30 0.50 BOPSUF P RUNPRD RIH 8964' to 9700' 00:30 - 01 :30 1.00 BOPSUF P RUNPRD Set RTTS @ 9700'. 90 BBL to fill annulus. Test casing to 2500psi for 30 min. Release RTTS and blow down surface equipment. 01 :30 - 08:30 7.00 BOPSUF P RUNPRD Lay down drill pipe from 9700' to 958'. Change out handling equipment. 08:30 - 09:30 1.00 BOPSUF P RUNPRD Lay down HWDP and RTTS 09:30 - 11 :30 2.00 RUNCm : RUNCMP Clear and clean floor bring tools to floor. Pull wear bushing. 11 :30 - 14:00 2.50 RUNCm RUNCMP Make up xlo's on landing joint, and floor safety valve.Change out bales, rig up to run 4 1/2" 13CR completion 14:00 - 15:00 1.00 RUNCm p RUNCMP PJSM Pick up packer assembly and Baker Lok all equipment below packer. 15:00 - 00:00 9.00 RUNCm p RUNCMP Pick up and run 4 1/2" 12.6# 13CR80 Yam top tubing to 7461'. Opt. torque 4440 ft/lbs. Jet Lube Seal Guard dope. 4/29/2006 00:00 - 03:00 3.00 RUNCm p RUNCMP Run 4 1/2" 12.6# 13CR80 Yam top tubing from 7461'-9744' Opt. torque 4440 ft/lbs. Jet Lube Seal Guard dope. 03:00 - 04:00 1.00 RUNCm p RUNCMP Rig down compensator. Make up tubing hanger and landing joint. Land @ 9768' and run in lock down screws. 04:00 - 06:00 2.00 RUNCor P RUNCMP Drop ball and rod. Circulate 331 BBL of seawater with corrosion inhibitor down the backside. 3BPM @ 70psi 06:00 - 08:30 2.50 RUNCOr p RUNCMP Test tubing to 3500psi for 30 min. Bleed tubing to 1500psi. Fill Printed: 5/1/2006 1:28:45 PM \ , e e BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 16-1 3 Common Well Name: 16-1 3 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/29/2006 06:00 - 08:30 2.50 RUNcm p RUNCMP annulus (72 BBL) test annulus to 2500psi for 30 min. Bleed off tubing, DCR valve did not shear. Bleed off annulus. Pressure up to 2500psi, DCR sheared, pump to verify 08:30 - 09:00 0.50 BOPSU¡:; P RUNCMP Dry rod TWC - test from below to 1000psi. Blow down all surface equipment and rig down 2nd kill line. 09:00 - 10:30 1.50 BOPSU¡:; P RUNCMP PJSM Nipple down BOP 10:30 - 14:00 3.50 WHSUR P RUNCMP Nipple up tree and adaptor. Test tree and adaptor to 5000psi. 14:00 - 15:00 1.00 WHSUR P RUNCMP Rig up lubricator, pull TWC, rig down lubricator 15:00 - 16:00 1.00 WHSUR P RUNCMP PJSM Rig up hot oil truck to pump freeze protect. Test to 3000psi. 16:00 - 18:00 2.00 WHSUR P RUNCMP Reverse circulate 135BBL 70 degree diesel. U tube. 18:00 - 19:00 1.00 WHSUR P RUNCMP Dry rod BPV Test to 1000psi . Rig down hot oil truck. 19:00 - 20:00 1.00 WHSUR P RUNCMP PJSM Remove secondary annulus valve. Secure tree and cellar. Rig released @ 20:00 4/29/2006 Printed: 5/1/2006 1 :28:45 PM Scblum.erger \'6 \_O?-'1" 05/01/06 NO. 3773 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 u~í\\! ,h,\M\;¡,.\~D WÜ"'ò~ ,ªç~""t~~ t) f\n~, p ~ (,..'vU'-' J U Field: Prudhoe Bay Well Job# Log Description Date BL L-50 40012467 OH LDWG EDIT OF MWD/LWD 10/18/05 2 ~ 16-13 11225959 USIT 04/13/06 0.5. 15-49A 11211378 SCMT 04/07/06 02-09B 11258693 SCMT 04/08/06 P2-11A 11285926 SCMT 04/20/06 PWDW2-1 10563132 TEMPERATURE LOG 02/15/03 J-26 10560274 LDL 06/20/03 W-29 10672333 LDL 10/28/03 W-25 11072872 LDL 07/14/05 R-06A 10572081 LDL 02128/03 N-21A 10703973 LDL 02115/04 PWDW2-1 10560235 LDL 03/01/03 Color CD 1 1 1 1 1 '-' '~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 16-13 RWO Scope Change e e j~t-O'Ll Subject: 16-13 RWO Scope Change From: ''Reem, David C" <ReemDC@BP.com> Date: Thu, 20 Apr 2006 09:06:51 -0800 To: Winton Aubert <winton_aubert@admin.state.ak.us> Winton, as we discussed on the phone, the workover on Prudhoe Bay well 16-13 is in need of a scope change due to deteriorating well bore conditions (specifically suspected damaged 9-5/8" casing at 9933' - 9975' drill pipe measurement). Our plan forward now is to complete the back-off of the cut 9-5/8" casing (was cut at 2095'md, will back-off at the colar at 2100'md), screw back in with 9-5/8" premium connection 40#/ft, L-80 casing and cement to surface. This casing will be landed on 9-5/8" emergency slips in the current casing head. After the shoe-track is drilled up, a casing test against a bridge-plug set at ....4000·md to 3500 psi/30-min will be conducted. This bridge-plug will be retrieved as will a 2nd plug set at -9700'md. We will then run a 4.5", 12.6#/ft, 13Cr-80 gas-lift completion. Please call should further clarification be necessary. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) SCANNEr; ô 1 of 1 4/20/20069:18 AM Re: Nabors Rig 2ES BOPE Test e e j. il- Q 'Ll Subject: Re: Nabors Rig 2ES BORE Test From: Winton Aubert <Winton_aubert@ådmin.state.åk.u$> Date: Mon, 17 Apr 2006 11 :14:05 -0800 To:uNS CC:Ad Nick, AOGCC hereby approves delaying the regularly required BOPE test on well PBU 16-13 (PTD 181-027) until 04/19/2006, as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 NSU, ADW Drlg Rig 2es wrote: Winton, The next BOPE test for Nabors Rig 2ES is scheduled for April 18th, 2006. This is a request for a one day extension. The current well conditions are such as when the packer was retrieved the well started taking fluid in excess of 90 bbllhr. A clean out trip is currently in progress. The next step will be to run a tie-back assembly then run and cement 7" casing to surface. The BOP stack will then be removed to install new casing spool, packott, and hanger. This would allow the BOPE test to be completed with stable well conditions. The AOGCC PI will be contacted on the 18th with a 24 hr notification and the BOPE test started on April 19th, 2006. Thank you for your time on this matter. Nick Scales/Jim Willingham BPX Company Rep Nabors Rig 2ES Tel: 659-4103 Fax: 659-4177 --".-...-....-...- <'..'......'_.-.._.~.P- hg", ~""Wú~r: ~V¿"'t[!~i'·."""" .e; ( f\ 1 of 1 4/17/2006 11: 14 AM "\ ~, lffK\íT~ æJ uLrUL lb e (fiìn, dr Iii ilU:I IJLI' ì e A .,ASIiA. OIL Al'O) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 16-13 Sundry Number: 306-091 \ct\' ÖrÎ ç;'.? , Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval· relating to the above referenced well. Please note the conditions of approval.set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisEday of March, 2006 Encl. " ~ÐV ~~yJ 1) ~ ~,,~"D" 3/:20Lo6 'STATE OF ALASKA ,1'f~ RECELVED ALASKA 0 AND GAS CONSERVATION COMMISSION I) ŒS" ;S [Z{ / Þ APPLICATION FOR SUNDRY APPROVAL MAR 1 7 ¿006 20 AAC 25.280 \ÞJ~ 4- ~ 11./ /2.-0 0 " Alaska Oil & Gas Cons. Commission . 1. Type of Request: o Abandon . 0 Suspend o Operation Shutdown o Perforate o Other .. / III Repair Well ---------~----- o Alter Casing o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program III Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. a Development /0 Exploratory 181-027 ~ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20566-00-00 /" 7. KB Elevation (ft): 70' 9. Well Name and Number: PBU 16-13 / 8. Property Designation: 10. Field / Pool(s): ADL 028332 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12690 9307 12141 9005 12141 12401 Casing Length Size MD / TVD Burst Collapse Structural 110' 20' 110' 110' 2654' 13-3/8" 2654' 2654' 4930 2670 11772' 9-5/8" 11772' 8773' 6870 4760 Liner 1576' 7" 11109' - 12685' 8321' - 9305' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 11900' - 12060' / 8855' - 8956' 4-1/2", 12.6# / 13Cr80 11582' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer; Packers and SSSV MD (ft): 10953' /' 9-5/8" x 4-1/2" Baker 'S-3' packer 9819' 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal o BOP Sketch o Exploratory 1m Development o Service o Detailed Operations Program 14. Estimated Date for APrï0J006 15. Well Status after proposed work: Commencing Operations: 1m Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name ,.pave Wesley Title Senior Drilling Engineer Signature Øt.Pz:... /It.¿t~~''l.1 Q- Date3//6?L(')~ Prepared By Name/Number: Phone 564-5153 Terrie Hubble, 564-4628 / "é Commission Use Only .' Conditions of approval: Notify Commission so that a representative may witness d - I Sundry Number: ::?£y (} _ /)q I o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: Tes t- BorE f-o ~S'o 0 1 PŸ\.· Subsequent Form Required: lO-4oY7} , RBDMS BFL MAR 2 ! 1006'~ .-fff /It1COMMISSIONER APPROVED BY Date a )./ /Db Approved By: THE COMMISSION Form 10-403 Revised 07/2005 \/ ~ , jUbmît In Duplicate ORIGINÄL e e 16-13 Proposed Ria Workover Procedure 1. During the pre-rig work, a plug will be set in the XN nipple in the current 4-1/2" completion at -11,570' MD, the tubing will be cut at -9824' MD and a BPV will be placed in the tubing profile. NOTES: A. On 12/18/05, PPPOT-T passed 5000 psi test & PPPOT-IC passed 3500 psi test. ".- B. On 04/22/03, MITT & MITIA both passed to 3500 psi. ,/ C. On 06/19/05, MITOA passed to 3000 psi. D. MIT-T and MIT-IA to 3500 psi will be performed during the pre-rig work. 2. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. ,/ 3. Pull and LD 4-1/2" tubing string. 4. Mill and retrieve Baker S-3 packer and tailpipe. 5. Mill and retrieve TIW HBBP packer and tailpipe. ~: =~~ :~~ ~~~:~;~P.~6~/f~~;~~~: ~~~~~~D·Z84 Hi s ~ ~i . VJ (,.ft- 8. Cleanout 7" tie-back casing to PBTD. 9. Run 4-1/2" 13Cr80 premium connection completion. Set single packer at -10,901' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. ,/ 12. Set BPV. NO BOPE. NU and test tree. RDMO. 1REE= . GRAY GEN 2 WELLHEAD =¡ GRAY GEN 2 SAFETY_ES: 4-1/2" CHROMETBG. SL TAGGED SANDT~ 12140 4/27/03. IBP ORIGlNALLYSET@ 12103'. e 16-13 ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = AXELSON 70' 3100' 59 @ 8600' 11924' 8800' SS 3' 1-15-1/2" X 4-1/2" XO, ID = 3.958" I -14-1/2" HES X NIP, ID = 3.813" 1 GAS LIFT MANDRELS MD TVD DEV TYÆ VLV LATCH PORT DATE 3041 3040 7 MMG DMY RK 0 04/22/03 3885 3818 34 MMG DOME RK 16 04/27/03 6375 5414 50 MMG DOME RK 16 04/27/03 8077 6416 57 MMG SO RK 28 04/27/03 9189 7021 54 MMG DMY RK 0 04/22/03 -14-1/2" HES X NIP, ID = 3.813" I -19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" -14-1/2" HES X NIP, ID = 3.813" I 1-14-1/2" UNIQUE MACHINE OVERSHOT, ID = 4.65" 10953' -19-5/8" X 4-1/2" TIW HBBP PKR I 113-3/8" CSG, 72#, L-80, 10 = 12347" I Minimum ID = 3.725" @ 11570' 4-1/2" OTIS XN NIPPLE ITOP OF 7" LNR I 11109' 11553' -14-1/2" OTIS X LANDING NIP, ID = 3.813" I 11570' -14-1/2" OTIS XN NIP, ID = 3.725" 1 11582' -14-1/2" TUBING TAIL WLEG I 11592' H ELMO TT LOGGED 06/06/95 1 14-1/2" TBG, 12.6#, 13-CR-SO, .0152 bpf, 10 = 3.958"1 I 9-5/8" CSG, 47#, L-80/S00-95, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/08/81 ANGLEATTOPÆRF: 50@ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11900 - 11940 C 09/20/91 3-3/8" 2 11900 - 11940 C 03/29/92 11994 - 12028 S 08/11/91 12048 - 12060 0 03/29/92 12054-12094 S 08/11/91 12140 - 12180 S 08/11/91 12196-12216 S 08/11/91 11900 - 11940 0 06/18/85 12236 - 12248 S 06/18/85 12267 - 12274 S 06/18/85 12284 - 12298 S 06/18/85 12284 - 12298 S 05/19/84 -14-1/2" IBP (SET 07/13/95) - SEE SAFETY NOTE -iCMTTOP(CTM) I 3-3/8" 12401' 3-1/8" 3-1/8" 3-1/8" 3-1/8" 3-1/8" 4 4 4 4 4 12675' -1 PKR ELEMENT FROM IBP 12680' 12685' -I MAGNETIC DECENTRALIZER 2' IPBTD I 12658' 17" LNR, 29#, L-80, .0371 bpf,ID=6.184" 12685' DA TE REV BY COMMENTS 06/16/81 ORIGINAL COMPLETION 09/07/94 RWO (1994) 04122/03 JBMITL RWO (2003) 10/10/01 CJ/KAK ÆRF CORRECTIONS 02/23/03 DDW/KK SAND DUMP 04/29/03 JCrvvTLH GL V ClO DATE 10/11/03 09/26/05 10/13/05 11/21/05 REV BY COMMENTS KLClTLP REIvtOVE SAND PLUG 04/27/03 EZLlTLH WAIVER SFTY NOTE DELETED RUvVPJC WELLHEAD CORRECTION MORlPJC ELMD CORRECTION PRUDHOE BAY UNrr WELL: 16-13 ÆRMrr No: 1"1810270 API No: 50-029-20566-00 SEC 24, T10N, R15E, 1586.35' FEL & 565.31' FNL BP Exploration (Alaska) TREE::, . GRAY GEN 2 WELLHEAD ~ GRAY GEN 2 ACTUA TOR:: AXELSON KB. ELEV :: 70' BF. ELEV :: KOp:: Max Angle:: Datum MD :: Datum TVD :: [Wf 16-13 Proposed (03/03/2006 - JGR) 3100' 59 @ 8600' 11924' 8800' SS 113-3/8" CSG. 72#, L-80, 10:: 12.347" I 7"Tie-Back Csg, 26#, L-80 Casing / Fully cemented 9-5/8" x 7" Annulus 4-1/2" WLEG -10,999' MD \ TOP OF 7" LNR I 11109' I 9-5/8" CSG, 47#, L-80/S00-95, ID:: 8.681" I PERFORA TION SUMMARY REF LOG: BHCS ON 06/08/81 ANGLE AT TOP PERF: 50 @ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 4 11900 - 11940 C 09/20/91 3-3/8" 2 11900 - 11940 C 03/29/92 11994 - 12028 S 08/11/91 12048 - 12060 0 03/29/92 12054 - 12094 S 08/11/91 12140 -12180 S 08/11/91 12196 - 12216 S 08/11/91 11900 - 11940 0 06/18/85 12236 - 12248 S 06/18/85 12267 - 12274 S 06/18/85 12284 - 12298 S 06/18/85 12284 - 12298 S 05/19/84 3-3/8" 3-1/8" 3-1/8" 3-1/8" 3-1/8" 3-1/8" 4 4 4 4 4 IPBTD I 12685' 12658' 17" LNR, 29#, L-80. .0371 bpf, ID:: 6.184" DA TE REV BY COMMENTS 06/16/81 ORIGINAL COM PLETION 09/07/94 RWO (1994) 04/22/03 JBMITL RWO (2003) 10/10/01 CJ/KAK PERF CORRECTIONS 02/23/03 DDW/KK SAND DUMP 04/29/03 JCM/TLH GL V C/O ÆEJYrÐTE5: 4-112" OfDJETBG SL TAI3EJ WfDTCP@121404/27/03, ISP ælGNALL VSET'@ 12103'. 4-1/2" X-Nipple - -2200' MD, ID = 3.813" Gas Lift Mandrel Placement (MMK (Chrome) - 4-1/2" x 1") #5 - 3153' MD w/DCR Shear Valve #4 - 5729' MD #3 - 7505' MD #2 - 9320' MD .ttl....:....1 0,823' M D 4-1/2" Tubing, 12.6#, 13-CR-80, Yam-Top 4-1/2" X-Nipple -10,890' MD, 10 = 3.813" 7" x 4-112" Baker S-3 Packer -10,901' MD 4-1/2" X-Nipple -10,926' MD, ID = 3.813" 4-1/2" XN-Nipple -10988' MD, ID = 3.725" w/RHC-M Plug 7" Tie-Back Stem into 7" Liner-Top PBR DATE 10/11/03 09/26/05 10/13/05 11/21/05 REV BY COMMENTS KLC/TLP RElv10VE SAND PLUG 04/27/03 EZUTLH WAIVER SFTY NOTE DELETED RUvVPJC WELLHEAD CORRECTION MOR/PJC ELMO CORRECTION -14-1/2" IBP (SET 07/13/95) - SEE SAFETY NOTE -1CMTTOP(CTM) I 12401' 12675' -1 PKR ELEMENT FROM IBP 12680' 12685' -fMAGNETIC DECENTRALIZER2' PRUDHOE BAY UNIT WELL: 16-13 PERMIT No: r.¡810270 API No: 50-029-20566-00 SEC 24, T10N, R15E. 1586.35' FEL & 565.31' FNL BP Exploration (Alaska) STATE OF ALASKA !' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I-I Operation Shutdown ri stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1653' SNL, 548' EWL, SEC. 24, T10N, R15E, UM X = 719331, Y = 5929278 16-13 At top of productive interval 9. Permit Number / Approval No. 181-027 4219' NSL, 3276' EWL, SEC. 13, T10N, R15E, UM X = 721884, Y = 5935228 10. APl Number At effective depth 50-029-20566-00 4357' NSL, 3403' EWL, SEC. 13, T10N, R15E, UM X = 722006, Y = 5935369 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 4713' NSL, 3692' EWL, SEC. 13, T10N, R15E, UM X = 722285, Y = 5935733 Pool 12. Present well condition summary Total depth: measured 12690 feet Plugs (measured) Sand Plug to approximately 12140' (04/03); true vertical 9307 feet IBP set at approximately 12140' (07/95) Effective depth: measured 12040 feet Junk (measured) true vertical 9004 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 300 sx Permafrost 110' 110' Surface 2654' 13-3/8" 3200 sx Fondu, 400 sx Permafrost 2654' 2654' Intermediate 11772' 9-5/8" 333 sx Class 'G', 167 sx Class 'G' 11772' 8773' Production Liner 1576' 7" 700 sx Class 'G' 11109' - 12685' 8321' - 9305' Perforation depth: measured Open: 11900'- 11940', 12048'- 12094'; Squeezed: 11994'- 12028' Squeezed & Below IBP: 12140'- 12298' (five intervals) true vertical Open: 8855' - 8880', 8948' - 8977'; Squeezed: 8914' - 8936' Squeezed & Below IBP: 9004'- 9096' (five Intervals) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 10021 '; 4-1/2", 12.6#, 13Cr80 10009' to 11582' Packers and SSSV (type and measured depth) 4-1/2" TIW 'HBBP' packer at 10953'; 4-1/2" Baker 'S-3' packer at 9812'; 4-1/2" HES 'X' Nipple at 2233' 13. Stimulation or cement squeeze summary ~',". Intervals treated (measured) Treatment description including volumes used and final pressure~'~i~.,~ ~" ~, ~,,~,~, ~,~,,; ,,. ~ ........ ,, , ........ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-~cf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ~ 5. Attachments 16. Status of well classifications as: D Copies of Logs and Su~eys run ~ Daily Repo~ of Well O~ons ~ Oil D Gas ~ Suspended Sewice ~ 7. I hereby ce~ify that the/foregoing is true and correct to the best of my knowledge r'~ I"t I ~t =r~a Submit In Duplicate Well: 16-13 RWO Accept: 04/13/03 Field: Prudhoe Bay Unit Release: 04/22/03 APl: 50-029-20566-00 Permit: 181-027 Rig: Nabors 4ES Date PRE-RIG WORK 02/21/03 MIRU DOWELL PUMP TO TBG. RU LRS TO IA. KILL TUBING, PUMP 15000# 20-40 RIVER SAND, FOLLOWED BY 60 BBLS WTR AND 95 BBLS CRUDE FOR DISPLACEMENT. SIMULATANEOUSLY PUMP WATER AND FREEZE PROTECT DN IA. PUMP SAND PLUG TO PERFS AND SHUT DOWN. DID NOT SEE A PRESSURE INCREASE. SHUT DOWN AND ALLOW SAND TO FALL OUT. CALC'D SAND TOP = 11137', CALC'D TOP OF SLURRY AT S/D = 9000'. LEFT WELL SHUT IN. 02/23/03 T/I/O=540/350/160 BLEED TBG & IA (SECURE WELL) TBG FL NEAR SURFACE IA FL @ 378'. BLED IA FROM 350 PSI TO 250 PSi IN 2 HRS, WOULD NOT BLEED BELOW 250 PSI. BLED ABOUT 14 BBLS OF FLUID. BLEED TRAILER AT 60 % COULD NOT BLEED TBG. MONITORED WHP'S FOR 30 MINS,TBG & IA STAYED THE SAME. FINAL WHP'S 540/250/160. 03/20/03 CHEMICAL CUT TUBING @ 9848' MD IN MIDDLE OF SECOND FULL JOINT ABOVE COLLAPSED TUBING. COLLAPSED TUBING @ 9919' MD. RIH WITH 14' STRINGSHOT. UNABLE TO FALL PAST SSSV. SSSV WAS CLOSED. POOH. BACKFLOW WELL TO OPEN FLAPPER. RBIH AND TAGGED TD @ 9919' MD. FIRED !4' STRINGSHOT FROM 9836'-9850'. RIH WITH 3-3/8" CHC. CUT TUBING @ 9848' MD. POOH. FLOWLINE WILL BE FREEZE PROTECTED WITH CIRC OUT. WELL LEFT SHUT IN. O4/O5/O3 PRE-RWO WELL KILL. PUMP 10 BBLS METH, 790 BBLS INHIBITED 1% KCL, 150 BBLS FLO-PRO,315 BBLS INHIBITED 1% KCL,7 BBLS METH & 130 BBLS DIESEL DOWN IA SPOTTING FLO-PRO PILL ACROSS PERFS WHILE 2ND PUMP PUMPS 10 BBLS METH, 220 BBLS 1% KCL, 53 BBLS FLO-PRO, 110 BBLS 1% KCL, 3 BBL$ METH & 54 BBLS DIESEL DOWN TUBING SPOTTING FLO-PRO PILL ACROSS PERFS TO KILL WELL. SSSV OPEN, NEEDLE VALVE BLOCKED IN @ TREE. FINAL PRESSURES "T/IA/OA" = VAC/VAC/120. 04/11/03 T/I/O = 360/360/0. BLEED TBG AND IA. (PREP FOR BPV, RWO). TBG FL @ 540'. IA FL @ 570'. BLED IA FROM 360 PSI TO 250 PSI IN 1 HOUR. FLUID TO SURFACE. TP INCREASED TO 500 PSI AND FLUID NOW AT SURFACE. BLED TBG FROM 500 PSI TO 60 PSI IN 5 MIN. RIG BACK UP TO IA. BLED IA FOR 1.5 HOURS .WITH NO DECREASE IN PRESSURE. SI BLEED AND MONITORED PRESSURES FOR 30 MIN. lAP INCREASED TO 270 PSI. TP DROPPED TO 10 PSI. BLED TBG FROM 10 PSI TO 0 PSI IN 3 MIN. FINAL WHP'S = 0/270/0. BP EXPLORATION Page 1 of 5 OPerations Summa Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/12/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 4/22/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 4/13/2003 12:00 - 14:00 2.00 MOB P PRE Scope and lower derrick ! 14:00 - 17:00 3.00 MOB P PRE Move rig from DS 16-18 to DS 16-13 !17:00 - 18:00 1.00 MOB P PRE Raise and scope derrick. ***Accept Rig at 1800 hfs *** ~18:00 - 19:30 1.50 RIGU P DECOMP RU tree to circulate. Take on seawater : 19:30 - 20:30 1.00 RIGU P DECOMP RU lubricator and pull BPV. Tbg 0 - IA 600 - OA 0 20:30 - 21:30 1.00 RIGU P DECOMP Finish RU tree and tiger tank to circulate. PT lines to 3500 psi 21:30 - 00:00 2.50 KILL P DECOMP PJSM- NAD / BP. Open choke, start pump with 2 bpm / 100 psi, increase rate to 5 bpm / 500 psi - tbg x ia at 500 psi after 100 bbls pumped, lost returns. SD pumps, total 160 bbls pumped, bleeding gas to tank, !A 750 psi- Tbg 500 psi. 4/14/2003 00:00 - 00:30 0.50 KILL P DECOMP Bull head 1 1/2 tbg vol, 225 bbls seawater down tbg. SD pumps Tbg 0 psi - IA 950 psi. Open choke to bleed IA, gas vented out top of tank resulting in mist escaping tank onto pad and into reserve pit. 00:30 - 03:30 3.00 KILL P DECOMP SRT out to investigate, app 4 gal seawater / diesel mix mist on snow around tiger tank and into reserve pit, Clean up in traffic area, SRT will return later this morning for final clean up. Add demister filter to top of tank. 03:30 - 05:30 2.00 KILL P DECOMP Open well, bleed IA 940 psi to 320 psi / tbg 0. Circulate dn tubing, taking gas returns to tiger tank. Not showing any sign of getting fluid returns up I/A. 05:30 - 07:30 2.00 KILL P DECOMP Shut in tbg. Bullhead 600 bbls down I/A @ 6 bpm / 200-350 psi. 600 bbls pumped. 07:30 - 08:00 0.50 KILL P DECOMP Monitor well, both sides on vacuum. 08:00 - 09:30 1.50 WHSUR P DECOMP Rig up lubricator, set BPV. (2) attempts to set. LID lubricator. 09:30 - 11:00 1.50 WHSUR, P DECOMP N/D existing wellhead. 11:00- 13:00 2.00 BOPSUF P DI=COMP N/U 13 5/8"x 5M BOPE. 13:00 - 16:30 3.50 BOPSUF P DECOMP Conduct full test on BOPE. 24 hour notice given, witnessing of test waived by AOGCC state rep Lou Grimaldi. 16:30-17:30 1.00 BOPSUF P DECOMP Pulltest plug, 10psion I/A, 25 psiontbg. Bullhead 100 bbls down tubing @ 6 bpm / 150 psi, 150 bbls down backside, 6 bpm / 150 psi. Both sides on a vacuum. 17:30 - 18:00 0.50 PULL P DECOMP Make up landing joint & crossovers, BOLDs. 18:00 - 18:30 0.50 PULL :P DECOMP Safety meeting w/crew coming on. Discussed H2S contingency plan, task at hand, stressed awareness with regard to monitoring the hole & fluid management. 18:30 - 19:30 1.00 PULL P DECOMP Pull hanger to floor. Hanging up in bowl area of wellhead. Work to 150K-160K & back down several times..8" of travel. Finally broke free. Pull hanger to floor. Marks on side where it hung up, (1) outer seal missing. 19:30 - 20:00 0.50 PULL P DECOMP Pump 50 bbls SW down tbg at 6 bpm/150 psi, followed by 150 bbls down IA at 6 bpm/200 psi. SD pumps, both Tbg/IA on vac. 20:00 - 21:00 1.00 PULL 3 , DECOMP RU SWS control line spooling unit and NAD casing tongs. 21:00-22:00 1.00 PULL 3 DECOMP Pump50bblsSWdowntbgat6bpm 150psi, 150 bbls down IA at 6 bpm 150 psi before starting out of hole laying down tbg. Both Tbg / IA on vac 22:00 - 00:00 2.00 PULL 3 DECOMP POH laying down 4.5" CR tbg and spooling control line, tight connections on several jts. 3 X pipe displacement,6 bbls every 15 jts of tbg. Pump 50 bbls down tbg every 50 jts tbg. 4/15/2003 00:00 - 01:00 1.00 PULL ~ DECOMP Continue POH laying down 4.5 CR tbg and control line. 3 X ~ ~' pipe displacemnt, 6 bbls, every 15 jts of tbg. Pump 50 bbls down tbg every 50 jts of tbg. Tbg connections continue to be Printed: 4/28/2003 9:16:02 AM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/12/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 4/22/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations ,,, 4/15/2003 00:00 - 01:00 1.00 PULL ~ DECOMP tight. -Recover all of control line and 23 of 26 SS Bands, leaving 3 SS Bands in well. 01:00 - 03:00 2.00 PULL ~ DECOMP LD / SSSV, RD spooling reel, change out 4.5" tbg tongs for 5.5" tbg tongs to help with tight connections. Pump 215 bbls down IA at 6 bpm 200 psi, 50 bbls down tbg at 6 bpm 200 ~si,well on vac. 03:00 - 06:00 3.00 PULL 3 DECOMP Continue POH / Laying down 4.5" CR tbg. Larger tongs did not help with tight connections, connections are still tight. Continous filling IA 1-2 bpm 06:00 - 16:00 10.00 PULL P DECOMP Crew change. PJSM. Continue POH / Laying down 4.5" CR tbg, connections are tight, tbg and threads look good. Filling IA at lbpm. Total 227 jts + 21.70' piece from chemical cut. Cut area had swollen to 4.6"OD from string shot prior to cutting tbg. 16:00 - 17:00 1.00 PULL P DECOMP RD tubing pulling tools, filling hole at 1 bpm 17:00 - 20:30 3.50 BOPSUF:P DECOMP Complete BOPE test, kill line leaking,change out kill line, test Pipe/Blind Rams A¢cumalator as per AOGCC / BP procedures 250 / 3500 psi. Witness of test waived by AOGCC Insp John Chrisp. 20:30 - 23:30 3.00 FISH P DECOMP Pull test plug and set wear ring. MU BHA # l-Wash over shoe, 5 jts WO pipe, boot basket, bump sub,oil jar, xo,9 DC, xo OAL 468.74. filling hole at 1 bpm. 23:30 - 00:00 0.50 FISH !P DECOMP RU 3.5" DP running tools. 4/16/2003 00:00 - 06:00 6.00 FISH P DECOMP Start RIH with BHA #1. PU 3 1/2" DP from pipeshed. Filling hole at 1 bpm. Crew change. 06:00 - 09:00 3.00 FISH P DECOMP PJSM. Continue TIH with BHA #1 and 3 1/2" DP singles. Total 303 jts. PU Kelly. 09:00- 16:30 7.50 FISH P DECOMP PUW = 158K. SOW- 114K. Rotate wt = 135K. Pump rates = 3.5 bpm/100 psi - 4.5 bpm/400 psi. Wt on shoe -- 2K - 10K. RPMs = 60 - 90. Tag top of fish (cut-offjt) @ 9,850-ft 4es RKB Wash down to top of collaspe section @ 9,917-ft 4es RKB. Continue to wash over collasped jt. Made 16-ft. Continue .... (well drinking fluid as fast as we are pumping. Two Vac truck to keep up. Talked to town about a sized salt pill). 16:30 - 18:00 1.50 FISH P DECOMP Mix and pump 30 bbl sized salt pill, spot at 9700', stop pump let pill settle. 18:00 - 19:30 1.50 FISH P DECOMP Crew change. ( Day crew attended Safety Induction Presentation w/Steve Rossberg) Working pipe from 9917" to 9927'.PUW 170k - SOW 110 k Pumps on at 25 spm / 40 psi / 120 rotary / 240 -270 amps. Work tight spot 9927' to 9932', no increase in torque. No returns to surface, hole taking 150 bph. Mix 2nd sized salt pill. 119:30 - 20:30 1.00 FISH P DECOMP Pump 30 bbl sized salt pill to 9700', stop pump, let pill settle for 30 min. 20:30 - 00:00 3.50 FISH P DECOMP Ream from 9932' to 9955',pump at 25 spm / 40 psi / 120 rotary / 240-270 amps, no increase in torque. Fluid loss has decreased from 150 bph to 100 bph, salt pill has helped a little but still have no returns to surface. Reaming is fairly good but slow. 4/17/2003 00:00 - 01:00 1.00 FISH P DECOMP Continue reaming from 9955' to 9963', with same parameters ....:,~..~-~,-'. as above, Unable to see tbg collar at 9957', it appears the next it of tbg could be collapsed or, we are washing the junk ahead of us. Fluid loss continues at 100 bph, still no returns to surface. Work kelly up / down several passes. PUW 200 k -170 Printed: 4/28/2003 9:16:02AM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/12/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 4/22/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 4/17/2003 00:00 - 01:00 1.00 FISH P DECOMP k - SOW 110k, work pipe to PUW 165k- SOW 105k. Cuttings don't appear to be a problem for the most part so far. 01:00 - 01:30 0.50 FISH P DECOMP Confer with An¢ Eng, re; Western Geo surveyors near pad picking up rig milling operations interference. Decided to mix / pump 50 bbl sized salt pill to slow fluid loss and obtain circulation to surface, and let surveyors work pass pad. 01:30 - 04:30 3.00 FISH N WAIT DECOMP Order addition material for and mix salt pill, work pipe while filling hole at 1 bpm. 04:30 - 05:00 0.50 FISH N WAIT DECOMP Pump 30 bbl of 50 bbl sized salt pill when filter on pump suction plugged. 05:00 - 06:00 1.00 FISH N WAIT DECOMP Pull and clean filter, test lines, filter cover leaked, removed and re tighten. Finish pumping pill. Crew change. 06:00 - 08:00 2.00 FISH N WAIT DECOMP PJSM. Continue to let 3rd Salt Pill fall. ( Night crew attended Safety Induction meeting with Steve Rossberg/John Smart ) 08:00 - 08:30 0.50 FISH P DECOMP Resume normal operations. Wash over 4 1/2" tbg from 9,963-ft down to 9,989-ft. Made "fast hole". Push junk from 9,989-ft to 10,017-ft. (end of wash pipe). 08:30 - 12:00 3.50 FISH P DECOMP Set back kelly. TOOH with 102 stds 3 1/2" DP. 12:00 - 12:30 0.50 FISH P DECOMP Stand back 3 stands of Drill Pipe and 1 stand of Wash Pipe. Lay down remaining BHA #1. Shoe 50% life gone. Junk Basket had some fine metal particles and slop. 12:30 - 13:30 1.00 FISH P DECOMP MU BHA #2 as follows: Shoe 6 5~8" ID, Outside Cutter 6 3~4" ID, 5 Jts Washpipe, XO, 9 ea DC, XO. 13:30 - 15:30 2.00 FISH P DECOMP Start TIH with BHA #2 and 3 1/2" DP. Continue hole fill at 60 bph. 15:30 - 16:30 1.00 FISH P DECOMP Stop to cut & slip Drill line (84-ft). 16:30 - 17:00 0.50 FISH P DECOMP !Continue to TIH to 9,923-ft .... encountered tight spot in collasped tbg section. 17:00 - 18:00 1.00 FISH P DECOMP Work pipe in an attempt to get through 9923'. No joy. Crew change 18:00 - 00:00 6.00 FISH P DECOMP PJSM - POH with BHA # 2, filling hole at 1 bpm 4/18/2003 00:00 - 01:00 1.00 FISH P DECOMP LD BHA # 2-Recover 75' of fish, 21' chem cut jt, 43' full jr. 10' of collasped jt leaving a slivered half section of pipe looking up. Lost 4 cutter knives in hole. No junk in junk basket. New TOF at 9925' ( original tag at 9850' + 75' recovered=9925' ), this is the area that BHA # 2 could not go past. filling hole at 1 bpm 01:00 - 02:00 1.00 FISH P DECOMP MU BHA #3 - 8.5x6.625 shoe, 2 jts washpipe, 8.375x6.75 outside cutter, 3 jts washpipe, boot basket, xo, 9 drill collars,xo(OAL 451.21) filling hole at 1 bpm 02:00 - 06:00 4.00 FISH P DECOMP RIH with BHA # 3 filling hole at 1 bpm. Crew change. 06:00 - 13:00 7.00 FISH P DECOMP PJSM. Begin washing over remaining collasped tbg from 9,925-ft down to 9,951-ft. (shoe depth). 13:00 - 14:00 1.00 FISH P DECOMP Work and push junk down to 9,986-ft (shoe depth) 14:00 - 15:30 1.50 FISH P DECOMP Set back Kelly. Work 1 stand down to 10,046-ft (shoe depth. (cutter now at 9,975-ft) 15:30 - 17:00 1.50 FISH P DECOMP PU Kelly and work down to 10,075-ft (shoe). Cutter at 10,003-ft. Engage cutter blades and attempt to cut off tbg. ... ..... - ..... Difficult to tell if a cut was made. 17:00 - 21:30 4.50 FISH P DECOMP POH with BHA #3 -2 stands off bottom, pipe was acting like it was pulling junk up hole, then freed up. Wear on outside of bottom jt of wash pipe. Recovered ~ 1' of balled up piece of sliver of tbg.in cutter, lost 3 1/2 knife blades. LD 2 jts wash Printed: 4~28~2003 9:16:02 AM BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/12/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 4/22/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations ,,, 4/18/2003 17:00 - 21:30 4.50 FISH P DECOMP pipe. Confer with Anc Eng, decision to run 3 jts wash pipe and shoe to clean stub and push junk down hole. 21:30 - 23:00 1.50 FISH P DECOMP MU BHA # 4 -8.5x6.625 shoe, xo, 3 jts washpipe, boot basket, bumper sub, oil jar, xo, 9 drill collars,xo ( OAL 405.49') 23:00 - 00:00 1.00 FISH P DECOMP RIH with BHA # 4 4/19/2003 00:00 - 03:00 3.00 FISH P DECOMP RIH with BHA # 4, filling hole at 1 bpm. 03:00 - 06:00 3.00 FISH P DECOMP PUW 155k - SOW 112k tag at 9937'.40 spm, 120 rpm, 210 amps, wash kelly down to 9952. Pick and run in, tight spot fl 9937' to 9939', make several passes thru this area, with rotary on, tight spot is not there, with rotary off the tight spot is present, some passes with rotary off it is not seen. Crew change. 06:00 - 07:30 1.50 FISH P DECOMP PJSM. Continue to rotate and work down to 9,960-ft. Push junk back down to 10,023-ft. 07:30 - 10:30 3.00 FISH P DECOMP Set back Kelly. TOH with 102 stds + 2 jts + 20-ft Pup Jt. 10:30 - 11:00 0.50 FISH P DECOMP Std back drill collars. LD 6 5/8" Shoe, oil jar, and Bumper Sub. 11:00 - 12:00 1.00 FISH P DECOMP Make up BHA #5 as follows: 6 5~8" Shoe...re-run, Outside Cutter, 3 Jts Washpipe, Junk Basket, XO, 9 ea DC, XO. 12:00 - 13:30 1.50 FISH P DECOMP Start to TIH with BHA #5 and 3 1/2" DP to 7,000-ft. 13:00 - 15:00 2.00 FISH P DECOMP Stop...had to cut Drill Line again. Found several wickered spots. Slip and cut 210-ft off). Lub Rig. 15:00 - 16:30 1.50 FISH P DECOMP Continue to TIH with BHA #5 and 102 std, 2 singles, 10-ft Pup Jr. Made 4 attempts to drop through bad spot again at 9,937-ft. Much joy...continue below collar at 10,000-ft. 16:30 - 17:30 1.00 FISH P DECOMP PU kelly, PUW 150k - SOW 110k, locate collar, space out below collar, make mechanical cut at 10003'. 50 rpm, 210 amps. 17:30 - 18:00 0.50 FISH P DECOMP Set back kelly, lay down 2 singles 1 pup DP 18:00 - 21:00 3.00 FISH P DECOMP Crew change, PJSM. POH with BHA # 5. 21:00 - 22:00 1.00 FISH P Dr:COMP LD BHA # 5 - recovered 68.68' of tbg, the remainig 20.80' of collasped jr, 42.88' full jt, 3.0' cut jr. The mechanical cut was smooth, OD 4.5', slight burrs on inside of tbg. 22:00 - 22:30 0.50 FISH P DECOMP Clean rig floor 22:30 - 00:00 1.50 FISH P DECOMP MU BHA # 6; 8.5x6.625,bushing, extension, boot basket, xo,9 5/8 scraper,xo, bumper sub, oil jar, xo, 9 dc, xo (OAL 324 78') ~4/20/2003 00:00 - 02:00 2.00 FISH P DECOMP RIH with BHA # 6 02:00 - 03:00 1.00 FISH P DECOMP PU kelly, PUW 150k - SOW 110k, wash down with pump at 75 spm, 400 psi. Set down on stub at 10006', pressure increased to 500 psi, with 3k wt on stub.- Scaper at 9998', saw tight spot at 9937'but went right through. (Pkr setting depth ~9946'-RTTS set depth '..9980') Set back kelly, clean floor. 03:00 - 06:30 3.50 FISH P DECOMP POH with BHA # 6 Crew change .PJSM 06:30 - 08:00 1.50 FISH P DECOMP Lay down BHA # 6, clear floor. MU RTTS 08:00 - 10:30 2.50 EVAL P DECOMP RIH with HES - RTTS to 9908' 10:30 - 12:30 2.00 EVAL P DECOMP Set RTTS at 9980', attempt to test csg, was able to inject into well at 2.5 bpm / 2000 psi. Unable to test csg. 12:30 - 14:00 1.50 EVAL 3 DECOMP PUH and set RTTS at 9886', ( above washover operations at 9917'). Load IA with 80 bbls SW, test csg to 3500 psi / 30 min, good test. 14:00 - 15:00 1.00 EVAL ~ DECOMP RBIH and set RTTS at 9970', attempt to test csg, was able to ~nject into the well at 2.75 bpm / 2000 psi. Unable to test csg. Csg appears to have damage, possibly in the area of 9937', this spot gave us trouble during the washover operation. ~ J .................... Printed: 4/28/2003 9:16:02 AM BP EXPLORATION Page 5 of 5 Operations Surnrna Report Legal Well Name: 16-13 Common Well Name: 16-13 Spud Date: 4/6/1981 Event Name: WORKOVER Start: 4/12/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 4/22/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 4/20/2003 15:00 - 18:00 3.00 EVAL P DECOMP Monitor and filling well at 1 bpm, confer with Anc Eng. Decision to revise completion packer setting depth to above the damaged csg area. 18:00 - 21:00 3.00 EVAL P DECOMP Crew change. POH with RTTS and LD / DP 21:00 - 22:00 1.00 EVAL P DECOMP Slip and cut 84' drlg line. 22:00 - 23:00 1.00 EVAL P DECOMP Continue POH LD / DP and RTTS. Lost in hole, 2 drag blocks, 8 springs and 1 block keeper off of RTTS. The drag blocks and springs arel"x8"x 1/2", the block keeper is 1"x1"x1/2". Confer with Anc Eng, the consensus was the blocks / springs fell down hole and in any case was below the perm pkr set depth of 9794', the Unique Overshot (OD 8.23") would act as a guage ring ahead of the pkr. 23:00 - 00:00 1.00 EVAL P DECOMP Pull wear ring and clear floor of DP tools 4/21/2003 00:00 - 01:30 1.50 RUNCOI~I~ COMP RU NAD tbg tongs and load pipe shed with remaining tbg to run 4.5" 13 CR tbg. 01:30 - 02:30 1.00 RUNCOI~ COMP PJSM with NAD, BOT, BP. MU tail pipe and pkr assy. (Note: 5 jt below Pkr in TT Assy have been Baker Lock'd) 02:30 - 06:00 3.50 RUNCOI~ COMP RIH with 4.5" 13 CR tbg, torque Vam Ace connections to 3620 fi/lb. Crew change. 06:00 - 16:00 10.00 RUNCOI~F' COMP PJSM. Continue running 4 1/2" Vam Ace 12.6 lb 13CR completion to 10,000-ft 16:00- 17:30 1.50 RUNCOI~ COMP MU landing jt. Tag stump at 10,009-ft 4es RKB. Slack-off 6-ft and mark tbg. Fill annulus wi90 bbls. Monitor...hole remains full. PUH and off of stump. Hole on vacumn. Run back to mark (same spot). Fill hole...close bag. pressure up to 500 psi. Bleed off...open bag. PU 2-ft. Monitor...hole remains full. PU off of stump. Well on vacumn. 17:30- 19:30 2.00 RUNCOI~ COMP LD landing jt, MU space out pups, hanger. PU landing jr. 19:30 - 23:00 3.50 RUNCOI~F' COMP Pump 530 bbls 140 deg inhibited seawater down IA at 3 bpm - 50 psi 23:00 - 00:00 1.00 RUNCOI~ COMP Land hgr,with Unique overshot 4' over tbg stub at 10009'. RILDS, test pack off to 5000 psi. Good. Load IA with 105 bbls at 3 bpm, pressure increased to 500 psi, verifing over tbg stub. 4/22/2003 00:00 - 02:00 2.00 RUNCOI~ COMP Drop ball/rod, wait 15 min, load tbg- 18 bbls, increase tbg pres to 1500 psi then to 3500 psi. Monior tbg pressure, pressure leveled at 3400 psi for 30 min. Bleed tbg down to 1600 psi. Increase csg to 3500 psi, monitor csg pressure, pressure leveled at 3550 psi for 30 min. Bleed csg pressure to 1500 psi, RP valve did not shear. Bleed Tbg x IA pressures to zero, increase csg pressure to 2800 psi, RP valve sheared. 02:00 - 02:30 0.50 RUNCOI~F' COMP Lay down landing jr. PU lubricator and set Gray BPV / Dart. 02:30 - 04:00 1.50 BOPSUR P COMP ND / BOPE 04:00 - 06:00 2.00 WHSUR P COMP NU Tree, test 5000 psi. Crew change. 06:00 - 06:30 0.50 WHSUR P COMP PJSM. Complete testing tree at 5,000 psi...Good. 06:30 - 08:00 1.50 WHSUR P COMP Pull blanking plug. RU DS Maint and pull BPV. 08:00 - 09:30 1.50 WHSUR P COMP RU HB&R freeze protect well w/190 bbls diesel. 09:30 - 10:30 1.00 WHSUR P COMP Hook-up line to "U-Tube" diesel. Blow down hard lines and begin prep for Rig release. .. 10:30 - 11:30 1.00 WHSUR P COMP Set BPV. LD Lubricator. Instal Blind Flange on wing valve. 11:30 - 12:00 0.50 RIGD P COMP Secure cellar. Release Rig Printed: 4~28~2003 9:16:02 AM Well: 16-13 RWO Accept: 04/13/03 Field: Prudhoe Bay Unit Release: 04/22/03 APl: 50-029-20566-00 Permit: 181-027 Ri~]: Nabors 4ES Date POST RIG WORK 04/27/03 PULL BALL & ROD. PULL DGLV-RK FROM GLM-2 & 3. PULL RP SHEAR VALVE FROM STA-4. SET LGLV @ STA-2,3, SET ORIFICE @ STA-4. 04/28/03 PULL RHC PLUG. DRIFT & TAG TO 12,142' SLM W/3.50 CENT & SB (NO SAMPLE). RUN 3.50" LIB ON "BARBELL ASSEMBLY" TO 12,150' SLM (IMPRESSION OF SAND). WELL LEFT SI. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ SAND PLUG Pull tubing _ Alter casing _ Repair well _ Other_X SAND PLUG 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service_ 4. Location of well at surface 1653' FNL, 4732' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1062' FNL, 2007' FEL, Sec. 13, T10N, R15E, UM At effective depth 945' FNL, 1897' FEL, Sec. 13, T10N, R15E, UM At total depth 567' FNL, 1588' FEL, Sec. 13, T10N, R15E, UM (asp's 719331, 5929278k (asp°s 721881, 5935226) (asp's 721987, 5935346) (asp's 722285, 5935733) 12. Present well condition summary Total depth: measured true vertical 12690 feet Plugs (measured) 9305 feet 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-13 ~,,,~. Permit number / approval number 181-027 10. APl number 50-029-20566-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Effective depth: measured true vertical 12103 feet Junk (measured) 8982 feet Casing Length Conductor 110' Surface 2619' Intermediate 11737' Liner 1576' Size Cemented Measured Depth True Vertical Depth 20" 300 sx Permafrost 145' 145' 13-3/8" 3200 sx Fondu, 400 sx 2654' 2654' Permafrost 9-5/8" 500 sx Class 'G' 11772' 8773' 7" 700 sx Class 'G' 11109' - 12685' 8321' - 9305' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs Covered w/Sand 11900'-11940', 12048'-12060'. Sqzd Perfs 11994'-12028', 12060'-12094', 12140'-12180', 12196'-12216', 12236'-12248', Sqzd Perfs (continued) 12267'-12274', 12284'-12298'. Open Perfs Covered w/Sand 8855'-8880', 8948'-8956'. Sqzd Perfs 8914'-8936', 8956'-8977', 9004'-9028', 9038'-9049', 9061'-9067', Sqzd Perfs (continued) 9078'-9082', 9088'-9096'. 4-1/2", 12.6#, 13-CR-80 TBG @ 11583' MD. 9-5/8" x 4-1/2" TIW HBBP Packer @ 10953'. 4-1/2" Camco TRDP-4A SSSV Nipple @ 2056' MD. ' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SHUT-IN Subsequent to operation SHUT-IN 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true,and correct to the best of my knowledge. D~~~~)~. Title: Technical Assistant Form10-404 Rev 06/15/88 o ORIGINAL ' Date February 28, 2003 Prepared by DeWar/ne R. $chnorr 564-5174~ 'S'UBMIT IN DUPLICATE 16-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/13/2003 RWO EXPENSE: AC-FLUTD LEVEL 02/21/2003 RWO EXPENSE: SAND PLUG 02/21/2003 RWO EXPENSE: SAND PLUG 02/23/2003 RWO EXPENSE: AC-BLEED; AC-FLU;ID LEVEL 02/24/2003 RWO EXPENSE: AC-MONTTOR EVENT SUMMARY 02/13/03 T/I/O=1560/950/220 (SAND BACK) TBG FL @ 216' (4 BBLS), IA FL @ 1170' (62 BBLS), CA FL @ NEAR SURFACE. 02/21/03 PUMPED 5 BBLS METHANOL FOLLOWED BY 400 BBLS INHIBITED WATER DOWN IA. FREEZE PROTECT IA WITH 133 BBLS CRUDE & 7 BBLS DIESEL. 02/21/03 MIRU DOWELL PUMP TO TBG. RU LRS TO IA. (SEE LRS REPORT OF 2/21/03 FOR ADDITIONAL REPORT). KILL TUBING, PUMP 15000# 20-40 RIVER SAND, FOLLOWED BY 60 BBLS WTR AND 95 BBLS CRUDE FOR DISPLACEMENT. SIMULATANEOUSLY PUMP WATER AND FREEZE PROTECT DN IA. PUMP SAND PLUG TO PERFS AND SHUT DOWN. DID NOT SEE A PRESSURE INCREASE. SHUT DOWN AND ALLOW SAND TO FALL OUT. CALC'D SAND TOP = 11137', CALC'D TOP OF SLURRY AT S/D = 9000'. 02/23/03 T/I/O=540/350/160 BLEED TBG & IA (SECURED WELL) TBG FL NEAR SURFACE IA FL @ 378'. BLED IA FROM 350 PSI TO 250 PSI IN 2 HOURS, WOULD NOT BLEED BELOW 250 PSI. BLED ABOUT 14 BBLS OF FLUID. BLEED TRAILER AT 60 % COULD NOT BLEED TBG. MONITORED WHP's FOR MINUTES, TBG & IA STAYED THE SAME. FINAL WHP's 540/250/160. 02/24/03 T/I/O = 580/480/160, MONITOR POST BLEED (SECURE WELL). FLUIDS PUMPED ,, BBLS 20 METHANOL 7 DIESEL 228 CRUDE 440 1% KCL WATER 400 INHIBITED WATER 38 GEL ' 1093 TOTAL Page I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field -D~16 May 1, 2.0,0!: I traveled to BP's Prudhoe Bay Field to witness the semi-annual SVS tests on DS- 16. I witnessed SVS tests on BP's DS-16. Testing went very well. No failures were witnessed. We had more than adequate manpower to test this Pad in a timely manner. Flow 2 Supervisor Roy Wells checked in wi the Pad Operators & Leads on DS-16 that were performing tests to make sure operations were being performed in a safe & efficient manner. Preventive maintena[tce had been performed on SVS for this 'Pad two weeks before State testin~l was conducted. ~ SUMMARY,: ! witnessed SVS tests on BP's PBU DS-16. 20.wells, 40 comoonents tested~ No failures witn..essed;..0%..fai!ure mt.e.., ,,A, .ttachmen~; SVS PBU DS-16 5-01-01jc CC; NON-CONFIDEN,,,TIAL SVS PBU DS-16 5-01-01jc Al~'..a Oil and Gas Conservation Commi['" Safety Valve System Test Report Operator: BPX Operator Rep: W. W~flliams AOGCC Rep: John C.fis, p Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field DS-16 Separator psi: LPS 171 HPS 511/01 Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIN J, Number Number PS! PSI Trip Code Code Code Passed. GAS or CYCLE 16-0i 1801360 16-02 1801500~ 16-03 1810110 16-04A ' 1921510 '17i ' 11o p p OIL 16-05 '18103~0 171 150 125 p ' p, ,' , oIL , 16-06 1810510 , 16-07 1852040 , 16-08A 1991260! 171 150 120 p 'P ~ '' OIL 16-09A 1910380 171 '150 120 p p OIL 16-10A 1991230 , 16-1'1 1801180 , :16-12A 1990190 171 , 150 ,120 'p ,,,p , ' , , . ~oIL,,, 16-13 1810270, '171 150 140' P P 0IL,, 16-14A 1980~60 3000 1800 "'1800 ,'p p , ,, GINJ 16-15 ' 1852640 171 '150 120 p p , ,, OIL 16-16 1801270 , ,, , , t621'7 1852200 171 150 125 p p , ,,. OIL 1'6-18 1852430 ' 171 150 I00 p p OIL 16-19 1852650, '171 150 120 p p OIL :16-20 1852850 171 150 110: p P OIL 16-21 1853120 171 150 , 90 , ,P P , , 'OIL 16-22 1900510 171 150! 120 p p OIL 16-23 1900620 16-24 1860240 , 16-25 'i9205i0 ''171 ' 150 90 p p , OIL 161~6~' 1991270~ 171 150 ' 120 p P OIL! 16-27A 2000040 171 150 1101 p p OIL 16-28 " '1920620 171 150 1'15 p p OIL 16-29A' 1920660 171 150 120 'p p OIL 16'30 1920760 '171 .1501 120 p p , OIL 16-31 1920750 ...... Wells: 20 Components: 40 Failures: 0 Failure Rate: 0.00% 1"190 var Remarks: tLIF 1/16/01 P~ge ! of 2 -- Ii i i II iiill I I __ _ Well Permit Separ Set L/P Test Test Test Date on, WAG, GIN~, Number Number , PSI PSI ,,T, rip Code Code Code ,Passed ,G,AS or ,cY,c3~ RJF 1/16/01 Page 2 of 2 SVS PBU DS-16 5-01-Oljcl GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 9606 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/1/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ~.s. 7-~^ 'I ~ (~- c.~G ~so~ ~ ~ I D.S. 14-34 <~'~ ~ ~ ~2, PROD PROFILE 95071 4 I 1 D.S. 16-13 vS;~ I ~2-") ~' INFLATABLE BRIDGE PLUG !95071 3 I I , " , D.S. 17-7 ~ [ (^ ~ ~ PROD PROFILE 95071 4 1 1 D.S. 17-11 ~ ~ ~.~l-~-i[ PROD PROFILE 950715 ' i "~ t . I' ; ,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. .. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9366 Company: 3/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 t Field: Prudhoe Bay .,~ Floppy Well Job # Log Description i" Date BL RF Sepia DIR MWD Disk ~NDW 2-1 STATIC TEMP-INJ PROF 031795 I 1 O.S. 02-13 POGLM SETI'ING RECORD 031 095 I 1 D.S. 03-09 PERFRECORD 031095 I 1 D.S. 3-29 PERFRECORD 031895 I 1 D.S. 4-12 TUBG PUNCHER RECORD 030395 I 1 i D.S. 4-38 TUBG CUTI'ER RECORD 031695 I 1 D.S. 7-18 PROD PRORLE ' 030495 I 1 D.S. 11-27 BASELINE TEMP 031795i I 1 D.S. 12-14 ST1 PERFRECORD ' 0304951 I 1 D.S. 12-34 ROPE PERF REC/FLD DET 030795 I 1 D.S. 16-13 PROD PROFILE 030695 I 1 D.S. 16-27 PERFRECORD 031895 I 1 'D.S. 1-22A 95049 DUAL BURSTTDT-P 020395 1 D.S. 4-37 95037 CNTD 012095 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: MAi 0 1 1995 . - Alaska 0ii & Gas Cons. C0mmissjon Anchorage '( STATE OF ALASKA ('=' ALASKA OIL AND GAS CONSERVATION COMMISSj0N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing x Stimulate Plugging Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Set, ce Perforate Other 6. Datum elevation (DF or KB) KBE = 70' feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1653'SNL, 548'EWL, SEC. 24, TION, R15E At top of productive interval 1062' SNL, 2007' WEL, SEC. 13, TION, R15E At effective depth At total depth 566' SNL, 1589' WEL, SEC. 13, TION, R15E 12. Present well condition sum.mary Total depth: measured true vertical Effective depth: measured true vertical feet feet Plugs (measured) feet Junk (measured) feet 8. Well number 16-13 9. Permit number/approval number 81-27/Conservation order 258 10. APl number 50- 029-20566 11. Field/Pool Prudhoe Bay Field~Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True vertical depth RECEIVED fVOV 3 0 1994 Alaska Oil & 8as Cons. Cor~ission ~d~ChOl'~r .~j~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR80 Tubing to 11582' MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HBBP' Packer @ 10953' MD; 4-1/2", Camco 'TRDP-4A' SSS V nipple @ 2056' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or In!ection D{~ta OiI-Bbl Gas-Mcf Water. Bbl Casing Pressure Tubing Pressure 15. AttaChments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ /~ Title Drillin~lEn~lineerSupervisor Sicjned ~v~6/15/ Form 10-404 R Date SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIO "N(b PAGE: 1 WELL: DS 16-13 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 08/27/94 10:00 SPUD: RELEASE: 09/06/94 08:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 08/27/94 ( 1) TD:12690 PB:12658 08/28/94 (2) TD:12690 PB:12658 08/29/94 (3) TD:12690 PB:12658 08/30/94 (4) TD:12690 PB:12658 LEVELING RIG MW: 0.0 Seawater MOVE RIG T/DS 16-13. PUT ON BOOSTER WHEELS, LAY PLYWOOD AROUND END OF LOCATION & LOWER DERRICK DUE T/RIG SINKING INTO SOFT PAD. MIRU. SPOT OVER WELL & LEVEL. PULL TBG HNGR MW: 8.5 Seawater PLEVEL & SHIM THE RIG OVER THE WELL. SET IN SEAH20 TANKS, SLOP TANKS & CUTTINGS TANK. BERM AROUND ALL TANKS. LUB UP & PULL BPV. TAKE ON SEAWATER, TIE IN TO WELL & CIRC OUT DIESEL & GAS. SET BPV. RD TREE, RIG UP BOPE. SET TEST PLUG. TEST BOP'S- WITNESS OF TEST WAIVED BY DOUG AMOS OF THE AOGCC. RU LUB & PULL TEST PLUG. RU DOUBLE SPEAR T/PULL 5.5" TBG HNGR & TBG BOLDS. SET SPEAR BELOW CONN. ON HNG. CHANGE OUT 9-5/8" PKOFF MW: 8.5 Seawater PULL & WORK HANGR THRU HYDRILL. LD HNGR. NU CIRC HEAD ON HNGR. CIRC OUT SOME CRUDE & GAS. RD CIRC HEAD. PULL 7 5.5" COMP STRING, SSSV, 10 GLM'S 283 JTS OF 5.5" & 18' OF CUT OFF. NO JHET CUTTER. LD TBG TONGS CLEAN FLOOR. PU TEST PLUG & TEST PIPE RAMS. INSTALL WEAR BUSHING. PU O'SHOT ASSY, 12) 6" DC'S & 5" DP T/797'. MU BACKER 9-5/8" STORM PKR & HANG OFF FISHING STRING @29'. CHANGE OUT CSG PK-OFF. PIN BROKE OFF RETRIEVING TOOL. TAKE OUT TBG SPOOL BOLTS SO SPOOL CAN BE LIFTED OFF OF THE PACKOFF. TOOH W/JET CUTTER MW: 8.5 Seawater CHANGE OUT 9-5/8" PACKOFF. ND BOPE, J-SLOTS PULLED OFF TOP PACK-OFF. PULL TBG SPOOL. REPLACE BTTM PACKOFF. INSTALL NEW SPOOL, TOP PACKOFF. NU BOPE. TEST PCKOFF T/5000/15 MIN. RUN TEST PLUG. TEST BOP BODY/5000. LD TEST PLUG. INSTALL WEAR BUSHING. RETRIEVE STORM PACKER. LD SAME. TRIP IN PU 5" DP. SERV. RIG & HOLD SAFTY MTG. TRIP IN W/OVERSHOT ASSY. PU 5" DP. PU KELLY. BRK CIRC. ENGAGE FISH @10920. PRESS. INCREASED. DROP DART. SHEAR PUMP OUT SUB. TRIP OUT W/ATLAS WL JET CUTTER. RECEIVED Anohom,,~:'.. WELL : DS 16-13 OPERATION: RIG : DOYON 16 PAGE: 2 08/31/94 (5) TD:12690 PB:12658 09/01/94 (6) TD:12690 PB:12658 09/02/94 (7) TD:12690 PB:12658 09/03/94 (8) TD:12690 PB:12658 TIH W/SPEAR ASSY MW: 8.5 Seawater TOOH W/ATLAS WL JET CUTTER. LD. CHANGE O'SHOT ASSY. TIH. SLIP & CUT DL. TIH. PU KELLY. TAG FISH @10934. ENGAGE & PULL 20K OVER ROT WT. ROTATE FREE. CIRC T/CLEAR DP & SET BACK KELLY. TOOH-NO FISH. ADD EXT. CHANGE GRAPPLE. TIH. KELLY UP. TAG FISH @ 10934. ENGAGE, TRY T/ROTATE OUT K ANCHOR, INDICATED PBR SHEARED. SET BACK KELLY. TRIP OUT, RECOVER 18' CUTOFF & SEAL ASSY. LD O'SHOT ASSY. PU SPEAR ASSY. & TRIP IN HOLE. MILLING ON PKR MW: 8.5 Seawater TIH W/SPEAR ASSY. KELLY UP, BREAK CIRC. TAG PBR @10958. ENGAGE & ROTATE OUT. STND BACK KELLY. TOOH W/PBR, NO FISH. CHANGE T/2WAY SPEAR ASSY. TIH . SLIP & CUT DL. TRIP IN PU KELLY. BRK CIRC. ENGAGE PBR. ROTATE 18 TURNS W/20K UP WT. PBR ENGAGED, SET BACK KELLY, TRIP OUT. RECOVERED PBR. LD SPEAR ASSY & PBR. PU MILLING ASSY T/MILL PKR. TIH W/MILLING ASSY. PU KELLY, BRC CIRC. TAG PKR TOP @10972. MILLING ON PKR. TIH W/REV BSKT & SCRPPR MW: 8.5 Seawater MILLING ON PKR F/10974 T/10976. FELL FREE. PUSHED T/11086. ATTEMPTING T/STICK. CBU. TOOH PULL SLOW DUE T/DRAG. NO PKR. LD MILL PRT. EMPTY BOOT BSKTS. PU SPEAR ASSY. TIH W/SPEAR ASSY. ENGAGE FISH @10265. TOOH W/PKR DRAGGING & HANGING UP TIGHT. @9917 & 9852. RECOVERED PKR & TAIL PIPE ASSY. LD SPEAR, PKR & TAIL PIPE ASSY. PU REV. CIRC BASKT & 9-5/8" SCRAPPER. TIH. TRIP IN W/5 3/4" REV BASKET MW: 8.5 Seawater TRIP IN HOLE. SLIP & CUT DRLG LINE. P/U KELLY TAG JUNK @ 11078' DROP BALL ON REVERSE CIRC. BASKET, PULL BACK TO 11017' DUE TO HANGING UP. ROTATE DOWN TO 11077' TORQUEING UP & FIRM ON BOTTOM. TRIP OUT. SLM. L/D CSG SCRAPPER. LARGE GOUGES IN BLADES. NO JUNK IN BASKET. SIDES WORN SMOOTH, NO WEAR ON BTTM. TRIP IN W/8" REVERSE CIRC. BASKET. WASH & WORK REVERSE BASKET 11039' TO 11082' FIRM ON BTTM INDICATING LINER TOP. TRIP OUT. L/D 6 1/4" DCS & 7 7/8" REVERSE CIRC. BASKET ASSY. MAKE UP 5 75" REV. BASKET, 4 3/4" DCS 3.5" DP. TIH. RECEIVED NOV 0 1994 Alaska Oil & Gas Cons. Commission Anchor~.. WELL : DS 16-13 OPERATION: RIG : DOYON 16 PAGE: 3 09/04/94 (9) TD:12690 PB:12658 09/05/94 (10) TD:12690 PB:12658 09/06/94 (11) TD:12690 PB:12658 09/07/94 (12) TD:12690 PB:12658 TRIP OUT FOR TEST PACKER MW: 8.5 Seawater TRIP IN W/5 3/4" REVERSE CIRC. BASKET. TAG JUNK @ 11575'. RIG UP TO REVERSE CIRC. REV. CIRC TAG BTTM. PRES INCREASE ATTEMPTING TO PLUG OFF. CIRC. BTTMS. UP. STILL PARTIALLY PLUGGED. TRIP OUT ASSUMING BASKET FULL OF JUNK OR RUBBER. (WET). EMPTY BASKET RECOVERED APPROX. 1 GALLON JUNK IRON. M/U REVERSE CIRC. BASKET TIH. REVERSE CIRC. & WASH DOWN F/11499' TO 11621'. (RECOVERING SAND). REVERSE CIRC. CHG. OVER SYSTEM TO CLEAN INHIBITED SEAWATER. TRIP OUT. FOR TEST PACKER. RUN COMP STRING MW: 8.5 Seawater TOOH LD 3.5" DP DC'S & JARS. CLEAN REV. BSKT. PU 9-5/8" PKR. TIH. SET PKR @ 11000. RU & TEST CASG T/3500/30 MIN. TOOH LD 5" & DP & PKR. PULL WEAR BUSHING. RU CASG TONG T/RUN 4,5" 12.6# 13 CR 80 TBG. U-TUBE T/TBG MW: 8.5 Seawater RUN COMPLETION STRING. INSTALL SSSV HOOK UP CL. TEST T/5000. OK. CON'T RUNNING COMPLETION STRING. MU HNGR. INSTALL CL & TEST T/5000. OK. LAND STRING, LD LNBDG JT & INSTALL BPV. CLEAR FLOOR ND BOPE NU ADPTR FLNG. TREE & CL. TEST ALL T/5000. PRESS TBG T/4000. SET PKR FL. LADKING BY BALL. PRESS ANNUL. T/3500 W/1500 ON TBG F/30 MIN. OK. SHEAR OUT RP W/3000. PUMP 6300 GAL DIESEL DOWN ANNUL. & U-TUBE T/TBG. RIG RELEASED MW: 8,5 Seawater CLEAR FLOOR RELEASE RIG @ 08:00 HRS ON 9/6/94 SIGNATURE: (drilling superintendent) DATE: RECEIVED N0V 3 0 1994 ~taska Oil & Gas Cons. Commission ARCO Alaska, Inc. Date' Subject: From/Location' Telephone: To/Location' P.O. Box 100360, horage, AK August 25, 1994 Transmittal #: ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution 94099 99510,~ ~ Well [ Log Date i Tool Type i Numberl (M-D-Y) ~ · i 16-13 i 8-22-94 i Collar Log Number of Records: 1 Run, Scale Contractor Atlas Karla Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. B y.~_ ~.~;~~......~.~ -Date: RECEIVED AUG 29 1994 kl~.s~a 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompany 600 W. International Airport Road Anchorage, AK 99618-1199 AI"rN: Sherde Well NO. 8858 '/~/,.., Company: Alaska Oil & Gas Cons Camm 4/~6'~ 3001 Porcupine Drive ~/?"~.6'e~.v_ ,7 c~ C~ Anchorage. AK 99501 ~'/'~,q~' ~ Field: Prudhoe Bay L~ De~dption ~/o~ BL RR ~pla RF ~pla Mylar D.$. 5-13A GAMMA RAY-OCL (7-23-94) 1 1 D.$. 5.13A JEWELRY LOG (7-25-94) 1 1 D.$. 12.7A IBP SETTING RECORD (7-25-94) 1 1 D.S. 9-7 IBP SETTING RECORD (-23-94) 1 1 D.S. 16-13 ~. IBP SETTING RECORD (-23-94) 1 1 8/11/94 SIGNE Please sign and retum one copy of this transmittal to Sherrle at the above address. Thank you. DATE: Date: June 14, 1994 P.O. Box 100360,~ chorage, AK 99510,~~, Transmittal#: 94045 'I~ ~' Subject: From/Location: Telephone: To/Location: q~ ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well ] Tool Type Number 1 - 10A /' USIT 2-33 3-18A I 05-19-94 ,- CCL 3-27 i 05-24-94 ,/BAKER IBP REC I4-07STi05-26-94 ' PERFREC ! 4-11A } 06-04-94 -~ INJPROFILE 4-19 i 05-25-94 / USIT 4-46 i 06-04-94 -Production P. mfile ~ 1, 1" 5" i 06-02-94 / CCL Log Date , (M-D-Y) 06-02-94 } 05-22-94 CNL RECEIVED ,]UN 2 0 1994 5-3A 6-3 i06-03-94 / PERFREC 6-10 05-22-94 'atch Settin( 6-16 i06-05-94 Puncher I 6-22A !05-22-94 CNL 7-4A i 05-21-94 CNL 7-6 I05-21-94 Profile 7-7A 05-20-94 / 7-18 {05-21-94 7-23 I 05-24-94 -/ 7-26 [ 05-21-94 7-28 f 05-26-94 9-13 ! 05~25-94 9-44 ! 05-20-94 9-50 i05-20-94 11-291 i05-31-94 1-291 i05-30-94 1 11-291 i05-31-94 11-291 i05-30-94 11-35 105-31-94 -35 i 05-31-94 1 1 11-36 I 05-23-94 J 14-3 !06-03-94 14-12 f05-28-94 14-12 I05-28-94 14-20 ~06-01-94 14-34 f06-01-94 16-13 f05-24-94 17-12 i06-05-94 17-19 I05-26-94 18-1 ~06-04-94 18'1 i 06'04-94 Pref Rec CNL CCL Prod Profile Perf Rec ~,' Bridge Plug ,'Production Profile ~Pmduction Profile / CNL USIT TDT-~' CBT USIT --' CBT CBT ~ PERF REC ~' GR LOG "Production Profile · /" PERF REC / PERF REC ' Baker IBP Rec t./Leak Detection // PERF REC Pack Off Gas Lift t/Tubing Puncher 1,1"5" 1,5" 1,5" ~aska 0J! & Gas Cons. Commission .h rage R u n, Con.actor 1 5" SCH I 5" SCH 1 5" SCH 1 5" SCH 1 5" SCH 1 5" SCH I 5" SCH SCH 1 5" SOH 1 5" SCH I 5" SCH 1 5" SCH I 5" SCH i 1 5" SCH 1 5" SCH 1 5" SCH I 5" SCH SCH SCH SCH 1, 5" SCH 1, 1" 5" SCH I 5" SCH 1 5" I 5" i SOH 1 5" ~ SCH 1 5" ~ SCH 1 5" SCH 1 5" SCH I 5" SCH 5" SCH 5" SCH 5" SCH 5" SCH 5" SCH 2" 5" SCH ,5" SCH ,5" SCH ,5" SCH 1 1 1 1 1,1 1 1 1 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany Drill Site: i5 Well: 13 Mon Feb 14 15:44:31 1994 K-VALVE DESIGN DOME SET PRESSURE: 300 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 255 PSIG K-VALVE CLASS (A,B,C): B C O~:~.[ENT S: Well is in 16D common line which is typically about 20-30 psi higher than i6C. The K-valve should dump b~ changing commoniines. Some choking back .may be required if the well spikes. CC: ENGINEERING FILE / COORDINATOR PRB 24 J. Y. Julian, ATO-iL09 (WITH ATTACNL~NTS) (WITHOUT ATTACNMENTS) J.C. SMART / M.G. SHO~J~XE PRB 20 STATE OF ALASKA (COVER ONLY) (WITHOUT ATTACHmeNTS) R.A.~%~LLS / K.L. BLACKBURN PRB 14 (CO'FER ONLY) Printing contents of current screen - wait for message to clear DESIGNED BY: K. L. Martin .. RECEIVED APR 2. 8 1994 AlaSka Oil & Gas Cons'. Commissi°'n Anchorage ,. Drill Site: 16 Well: 13 Mon Apr 18 12:18:35 1994 K-VALVE DESIGN DOME SET PRESSURE: 350 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 310 PSIG K-VALVE CLASS (A,B,C): B COMMENTS: K-valv. e is designed to be tested in the hole. Well may have to be choked back to flow without accidental dumping. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.~. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) R.A. WELLS / K.L. BLACKBURN PRB 14 (COVER ONLY) D.A. Cismoski ATO 1509 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: A.W' Brooks Drill~-"~+--~. 16 Well'. 13 Tue Sep 28 09:40:03 1993 K-VALVE DESION mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmm~m~m~mm~mmmm~m~~ DOME SET PRESS'JRE: 235 PSIG @ 60 DE~ F FTP @ CLOSE (PSIO): 190 PSIC K-VALVE CL;%SS (A,B,C): B K-valve is designed to be tested by dumping to a depressured separator or tank or by shutting d=~ lift gas. Well may have to be choked back to prevent accidental closure of k-valve. ~C. ENOINEERING FILE./ COORDINATOR (WITH ATTACH~,~fS ) J.C. S~%/{T / M. (WITHOUT ATTACH~NTS) R.A. %TELLS / K.L. BLACF~UP~ PRB 14 (COVER ONLY) M.A. WILSON ATO (WITHOUT ATTACHMENTS) STATE OF ALASKA ( COVER ONLY) DESIGNED BY: A.W. BROOKS Drill Site: 16 well: 13 K-VALVE DESIGN Mon Sep 06 10:03:41 1993 DOME SET PRESSURE: 245 PSIG @ '60 DEG F FTP @ CLOSE (PSIG): 180 PSIG K-VALVE CLASS (A, B, C ): B COMMENTS: Test dump into depressured separator design is at 50 psi higher closing ftp than previous design well should stay in higher pressured common line if kvalv dumps, previous valve failed mechanically. CC: ENGINEERING FILE / COORDINATOR PRB 2~_M.A. WILSON ATO 1502 (WITH ATTACHMENTS) ~-- (WiTHQ~~TA~NTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) R.A. WELLS / K.L. BLACKBURN PRB 14 DESIGNED BY: K.L. Martin (COVER ONLY) Printing contents of current screen - wait for message to clear Drill situ: 16 W~ll: 13 Mon Sep 06 10:04:35 1993 K-VALVE DESIGN CHECKLIST RECENT WELL TEST DATA IS ACCURATE AND SHAKEOUT DATA CONFIRMS WATERCUT ? y SUBJECT WELL IS PRODUCING INTO THE HIGH OR LOW PRESSURE COMMONLINE ? lp PAST 7~DAY AVERAGE COMMONLINE PRESSURE: 240 AND LOW PRESSURE: 200 SUBJECT WELL'S PAST 7 DAY AVERAGE SURFACE FLOWING TUBING PRESSURE: 260 PAST 7 DAY LOW FTP: 200 REASON: fs2 down y IS THE FTP SWINGING OR SPIKING ? y HOW MUCH ? 40 DOES THE FTP vs CML PRESSURE INDICATE A CHOKE RESTRICTION OR UNDERSIZE ? n CURRENT CHOKE SETTING IS AT CFR OR HIGH LIMIT (WIDE OPEN) ? y SUBJECT WELL IS GAS LIFTED ? y GAS LIFT OPERATING SMOOTHLY ? n Printing contents of current screen - wait for message to clear STATE OF ALASKA ALASK.[ 'ILAND GAS CONSERVATION ~ IMISSION REPORT OF SUNDRY WELL OP -RATIONS Pull tubing .-.-- Alter casing ~=- 1. Operations performed: Name of Operator ARCO Alaska Inc. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1653' S & 548' E of NE cr., Sec. 24, T10N, R15E, UM At top of productive interval 1062' S & 2007' W of NE cr., Sec. 13, T10N, R15E, UM At effective depth At total depth 566' S & 1589' W of NE cr., Sec. 13, T10N, R15E, UM Stimulate X~ Plugging -.-. I:~l~r well 5. Type of Well oevaopment X I=xpioratmy Stra~raphic RECEIVED Alaska 0il & Gas Cons. C0mm'~ss't( ~nch0rage 12. Present well condition summary Total depth: measured true vertical 12690 feet 9305 feet Pm 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-13 9. Permit number/approval number 81-27 10. APl number 50 - 029-20566 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill @ 12000' MD (1/22/93) Effective depth: measured 12000 feet true vertical 8916 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Surface 2584' 13-3/8" 3200 sx Fondu & 400 sx PF 2654' 2654' Production 11702' 9-5/8" 333 sx CIG 11772' 8772' Liner 1576' 7.' 700 sx CIG 12685' 9303' Perforation depth: measured 11900-11940'; 12048-12060' true vertical 8855-8880'; 8948-8956' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 11004' MD; 4-1/2", 12.6#, N-80, PCT Tail @ 11064' MD Packers and SSSV (type and measured depth) Baker SAB pkr @ 10971' MD; 5-1/2" camco BAL-O SSSV @ 2161' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 990 y' 2576 4174 -- 1471 ~' 2779 5448 -- 16. Status of well classification as: Oil x. Gas ..... Suspended Service Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Tubing Pressure 356 341 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~ ?-' ~'~~ Form 10-404 Rev 06/15/88 966/1 KRF cc: SW, JWP Title Engineering Supervisor Date SUBMIT IN DUPLICATE 16-13 DESCRIPTION OF WORK COMPLETED FOAMED ACID SCALE REMOVAL TREATMENT 1/22/93: RIH & tagged bottom fill at 12000' MD. 2/15/93: A five stage fullbore Foamed Acid Stimulation was performed as follows: MIRU CT & PT equipment to 4000 psi. Established pumpdown w/25 bbls of 1% NH4CI Water w/foaming agent @ 10 bpm, treating the perforations located above the sand/fill plug, at: 11900 - 11940' MD (Z4) Ref. Log: BHCS 6/8/81. Pumped stage #1: a) 25 bbls 50% Diesel / 50% Xylene w/additives @ 10 bpm, followed by b) 10 bbls 1% NH4CI Water w/foaming agent @ 10 bpm, followed by c) 40 bbls 7.5% HCl w/additives & 700 scf/bbl injected Nitrogen, followed by d) 20 bbls 6% HCl - 0.5% HF foamed w/700 scf/bbl injected Nitrogen, followed by e) 120 bbls 1% NH4Cl Water w/700 scf/bbl injected Nitrogen, followed by f) 25 bbls 1% NH4Cl Water nitrified w/3700 scf/bbl Nitrogen, followed by g) 10 bbls 1% NH4CI Water spacer w/foaming agent @ 10 bpm. Continued Pumping stages #2 - 5: h) repeated steps a through g (listed above), for four additional stages omitting the diverter/spacer on the final stage (steps f & g). Displaced the final stage w/120 bbls 1% NH4CI Water w/700 scf/bbl, followed by 290 bbls 1% NH4Cl Water displacement, followed by Shutdown. Rigged down & flowed well. 2~20/93: Pumped an ESL Scale Inhibition Treatment. Returned well to production w/gaslift & obtained a valid production welltest. Aias~ 0ii & sas Cons. C0m~ss't°~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO CASED HOLE FINALS 10-3-92 9-28-92 9-14-92 9-29-92 10-2-92 9-19-92 9-26-92 9-27-92 9-25-92 9-14-92 10-2-92 9-4-92 10-4-92 9-26-92 9-26-92 10-5-92 9-27-92 9-19-92 9-27-92 10-4-92 10-2-92 10-2-92 10-1-92 9-15-92 9-17-92 10-1-92 9-28-92 9-26-92 9-15-92 10-1-92 Prod Profile Run 1, ~' Camco Leak Detect (Flexstak) Run 1, [~' Camco InJ Profile Run 1, I~' Camco InJ Profile Run 1, [~* Camco Prod-InJ (Flexstak) Run 1, I~* Camco Leak Detect Run 1, [~* Camco GR/Collar Run 1, [~* Camco GR/Collar Run 1, [~' Camco Prod Profile Run 1, [~* Camco Prod Profile Run 1, [~* Camco InJ Profile Run 1, [~* Camco Prod Profile Run 1. [~' Camco InJ Profile Run 1, [~' Camco Prod Profile Run 1, [~' Camco GR/Collar Run 1.1~* Camco InJ Profile/PITS Run 1, [~' Camco InJ Profile Run 1, [~* Camco Leak Detect Run 1, ~' Camco Prod Profile Run 1, [~' Camco InJ/Shut-In Tamp Run 1, [~* Camco InJ Profile Run 1, [~* Camco InJ Profile (Flexstak) Run 1, I~* Camco InJ Profile Run 1, [~' Camco l~J PrOfile Run 1. I~' Camco Prod Profile (Flexatak) Run 1. ~' Camco Prod Profile Run 1. ~' Camco GR/Collar Run 1, ~' Camco Prod Profile Run 1, ~' Camco Prod Profile Run 1, ~' Camco Prod Profile Run 1, ~' Camco Please sign and return ~e attac~e~d copy as receipt of ~:~,~' E i V E D RECEIVED B~_~~__~'M~ 09 ,~J Have A Nice D~ ~ ,/' ~ Alaska Oil & Gas Cons. COmmission # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILES # BPX # STATE OF ALASKA MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh A Griffin date: Commissioner November 12, 1992 file: JER11032. DOC thru: Blair E Wondzell Sr Petr Engineer from: ~Jerry Herring Petr Inspector subjec .t~ K-Valve Bench Test ~0.,~.'''~ For PBU Wells v '7 '%19& 16-13 Prudhoe Bay Field' Tuesday~..November 3, 1992: I witnessed K-Valve Bench Tests for ARCO PBU Wells 7-19 and 16-13, Prudhoe Bay Field. Bench tests were completed at the Otis Shop at Dead Horse with John Winters from ARCO Alaska, Inc. In summary, the two bench tests were completed satisfactorily. Attachment AOGCC SAFETY VALVE TEST REPO~* K-VALVE BENCH TEST FIELD: Prudhoe Bay (EOA) DATE: 11/3/92 OPERATOR: ~;RCO Alaska, Inc. REPRESENTATIVF~ (OTIS) C. VALADI wELL PERVlT SVTEST PILOT FLOWING S SSV SSV SSSV SSS N , ~ ~ DUE (LOW) i TUBING TUBING INIT POINT FIN POINT TEST P FP TST T 13-1482-01710! Sep-92 200 1,90 P ,,, 7-1982-0217 Jul-92 865 780 P 16-13~81-00270 Sep-92 ,, 150 150 P .,, , , ,, ,,, , · · . , ,, R~I.~O:IKS: ' " . . , "JERRY HERRING PRESENT , , ,,, , INSPECTOR: WINT-uJ~ Drill Site: 16 Well: 13 K-VALVE DESIGN Sat Oct 31 21; 18; 42 1992 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A,B,C): 150 PSIG @ 60 DEG F 132 PSIG C COMMENTS: The K-valve will have to be bench tested. This design will work with or without gas lift or with an increase in PI up to 50%. The well will not have to be choked back. CC- / W.D. COOPER J.C. SMART / M.G. SHOEMAKE C.L. CLARK / K.L. BLACKBURN. ENGINEERING WELL FILE PRB 24 PRB 20 PRB 14 J. S . ROGERS ATO 1505 STATE OF ALASKA (COVER) DESIGNED BY: A. W, Brooks RECEIVED NOV 0 9 1992 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ( _A. ND GAS CONSERVATION C(~ llSSION O I{ i ~ REPORT Ct- SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1653' S & 548' E of NE cr., Sec. 24, T10N, R15E, UM At top of productive interval 1062' S & 2007' W of NE cr., Sec. 13, T10N, R15E, UM At effective depth At total depth 566'S & 1589' W of NE cr., Sec. 13, T10N, R15E, UM 5. Type of Well Development Exploratory StralJgraphic 6. Datum of elevation(DF or KB) 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-13 9. Permit number/approval number 81-27 10. APl number 50 - 029-20566 11., Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12690 feet 9305 feet Plugs(measured) FILL @ 12090' MD (9/10/92) Effective depth: measured true vertical Casing Length Conductor 110' Surface 2584' Production 11702' Liner 1576' 12090 feet 8973 feet Junk(measured) Size 20" 13-3/8" 9 -5/8" 7" Cemented 300 sx PF 3200 sx Fondu & 400 sx PF 333 sx C l G 700 sx Cl G Measured depth 110' 2654' 11772' True vertical depth 110' 2654' 8772' 9303' Perforation depth: measured 11900-11940'; 12048-12060' true vertical 8855-8880'; 8948-8956' OCT - 6 1992 Alaska 0il & Gas Cons. C0m~$Si0~ Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 11004' MD; 4-1/2", 12.6~, N-80, PCT Tail @ 11064' MD Packers and SSSV (type and measured depth) Baker SAR pkr @ 10971' MD; 5-1/2" Camco BAL-0 SSSV @ 2161' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Reoresentative Daily Averaae Production or Injection Data Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Gas-Md W~e>Bbl 2067 3026 3346 1997'~'~''''~ 3697 4209 Casing Pressure .- 16. Status of well classification as: Oil x.~_ Gas__ Suspended.._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 889/11 DRR cc: SW, JWP Tubing Pressure 247 37O Title Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE 16-13 DESCRIPTION OF WORK COMPLETED NITRIFIED ACID STIMULATION TREATMENT 4~24/92: RIH & tagged bottom at 12074' MD. 5/1/92: MIRU CT & PT equipment to 4000 psi. RIH w/CT & pumped 21 bbls of slurry containing 4300 lbs 20/40 mesh sand, to isolate the perforations at: 12048 - 12060' MD (Z4) Ref. Log: BHCS 6/8/81. Placed a sand plug to 11945' MD. POOH w/CT. Rigged down. 5/2/92: RIH w/CT & loaded wellbore w/Seawater, then jetted tubing from 940 - 11900' MD w/46 bbls 7.5% HCl/30% Xylene. Displaced acid to surface w/Slickwater & Meth Water. Rigged down. 5/3/92: A four stage Nitrified HCL Stimulation was performed as follows: MIRU CT & PT equipment to 4000 psi. RIH w/CT & loaded the wellbore backside w/250 bbls Seawater w/foamer, then reciprocated the treatment across the perforations located above the sand plug, at: 11900 - 11940' MD (Z4) Ref. Log: BHCS 6/8/81. Pumped stage #1: a) 24 bbls 50% Diesel / 50% Xylene preflush, followed by b) 24 bbls 7.5% HCl w/foaming agent, followed by c) 24 bbls Seawater overflush w/foaming agents & additives, followed by d) CT displacement w/nitrogen @ 2000 scfm, while pumping 27 bbls Seawater/foamer down the CT x Tubing annulus, followed by e) Nitrogen shutdown. Displaced nitrogen from CT w/Seawater/foamer. Pumped stage #2: f) repeated steps a through e (listed above). Pumped stage #3: g) repeated steps a through e (listed above). Pumped stage #4: h) 18 bbls 50% Diesel / 50% Xylene preflush, followed by i) 18 bbls 7.5% HCl w/foaming agent, followed by RECEIVED OCT - 6 Alaska Oil & Gas Cons. Commission Anchorage j) 30 bbls Seawater overflush w/foaming agents & additives, followed by k) 288 bbls Seawater displacement, follOwed by I) Shutdown. POOH w/CT. Rigged down. 9/9/92 - 9/10/92: Performed a sand/fill cleanout to 12125' MD, and made a final bottom tag at 12090' MD. Returned well to production with gaslift & obtained a valid production welltest. Drill Site: 16 Well: 13 K-VALVE DESIGN Fri Aug 21 14:32:28 1992 DOME SET PRESSURE: 215 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 146 PSIG K-VALVE CLASS (A,B,C): C m--mmmmmmmmmmmmmm~~--m--mmmmmmmmmmmmmmmmmmmmmmmmmmm COMMENTS: CC: The K-valve will have to be bench tested. This design will work with or without gas lift or with an increase in PI up to 50%. The well will not have to be choked back. [ W.D. ¢OO~ER ~RB 2~ C.L. C~ / K.L. B~C~~ P~ 14 EN~INEERIN~ ~LL FILE J.S. ROGERS ATO 1505 STAT~ OF ALASKA (COVEa) DESIGNED BY: A.W. BROOKS RECEIVED SEP 05 1~2 ' Alaska Oil & Gas Cons. Commiss~ Anchorage Drill Site: 16 Well: 13 Fri Aug 21 14:28:32 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2161 FTP @ CLOSE (PSIG): 146 PRESS ADJUSTMENT: 226 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 85 3503 370 1997 67.8 1851 1160 6206 1787 3.20 139 0 08/14/92 Y CONDITIONS AT CLOSURE: 85 3503 146 2219 67.8 1851 1103 6897 1431 3.20 139 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 155 156 PRESSURE @ SSSV: 581 354 DOME SET PRESSURE: 215 PRIOR DESIGNS: DATE: 05/16/92 SET PRESSURE: 205 FTP @ CLOSURE: 166 02/09/92 220 227 o /o5/9 o TEMP: PIPROF PIPROF LINEAR ESC=EXIT; Fi=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..82587e-3 N= 1.000000 NEW C= ..84665e-3 ENTERED N= 1.000000 Drill Site: 16 Well: 13 SENSITIVITY TABLE Fri Aug 21 14:28:53 1992 P.I. 3.20 4.80 3.20 3.20 %WTR 68.0 68.0 90.0 68.0 GOR 1850 1850 1850 1850 LGR 3500 3500 3500 0 FTP 1 146 358 359 339 359 FTP 2 140 357 358 335 354 FTP 3 100 322 324 291 306 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-19-92 REFERENCE: ARCO CASED HOLE FINALS ~/~ ~' * 1-1B 4-8-92 GR Run 1, 5" 72-;~ 7~9 3-22-92 Perf Run 1, 5" ?*-/~ 9-46 2-10-92 PerfRecord R~_~_n 1, 5" 9-47 3-22-92 Pe~ R~m 1, 5" ~- ~ 14-4 3-6-92 Pe~ Record R~ 1, 5" ~/->~ 16-13 3-29-92 Pe~ Record R~ 1, 5" ~- ~ 16-18 3-30-92 Pe~ Record R~ 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY ~~__'__'~__ ~.~__~________ Have A Nice Day! Sonya Wallace ATO-1529 R CEIVF. D JUN Alaska Oil & Gas Go. ns. Commission Anchorage # CEN?~ FILES # C[-]~ON # EZTENSION EZP[Z)~?ION # EZXON ~THON APPROVED Trans# 92122 # PIHLLIPS PB WELL FILES R&D # BPX '# STATE OF'ALASKA TEXACO * The correct APl# for 1-1B is 50-029-21007-01. Drill Site: 1~ ~ell: 1~ K-V~LVE DESIGN Fri May 15 18:49:15 1992 DOME SET PRESSURE: 205 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 166 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: This design will work with or without gas lift or with an increase in PI up to 50%. Under normal flow conditions the well should not be choked back. CC: W. D. Cooper / ~g%~Ant J.C. SMART / M.G. SHOEMAKE C.L. CLARK / K.L. BLACKBURN ENGINEERING WELL FILE PRB' 24 PRB 20 PRB 14 J. S. Rogers ATO 1586 STATE OF ALASKA (COVER) DESIGNED BY: A.W. Brooks R£crc ¥[D M X¥ 2. 'i 1992. Alaska Oil & Gas Cons. Commission Anchorage // ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ?~'~'! 14-2 ?~-r~- 14-3 ?~'~ 14-4 ~z~-/ }14-5A *~14-5A ?~'~14-6 ~/ *~*/16-9A /~ ~ 16-9A ~/-~ 16-13 ~Y-~ff 16-15 ~- ~/~ 16-21 ~/16-22 7-8 18- 6 ARCO CASED HOLE FINALS 3-3-92 PITS Run 1, 2-10-92 Leak Detect Run 1, 2-11-92 Prod Prof R,,n 1, 2-29-92 Prod Prof Run 1, 3-17-92 PITS R~_m 1, 2-13-92 Jewelry Rl~n 1, 3-12-92 PITS R~_m 1, 2-24-92 Jewelry Run 1, 3-16-92 Prod Prof R,_m 1, 2-25-92 Prod Prof R~_m 1, 2-24-92 Prod Prof R,m 1, 3-8-92 PITS R~_m 1, 2-26-92 InJ Profile Run 1, 2-20-92 PITS Run 1, 5't 5" 5" 5t' 5" 5" 5" 5" 5" Calnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the RECEIVED BY Have A Nice Day! Sonyn Wallace ATO-1529 attached copy u receipt of data. RECEIVED APR b 0 1992 Alaska Oil/& I~a$ Cons. APPROVED~/~~f__ Anchorage Trans# 92080 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PIHLLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO The correct well name for this log is 14-5A. The correct well name for this log is 16-9A. STATE OF ALASKA ALASKa: :LAND GAS CONSERVATION Ck( MISSION ~ ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Olher 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1653' S & 548' E of NE. cr., Sec. 24, T10N, R15E, UM At top of productive interval 1062' S & 2007' W of NE. cr., Sec 13, T10N, R15E, UM At effective depth At total depth 566' S & 1589' W of NE. cr., Sec. 13, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 12690 feet 9305 feet 5. Type of Well Development X Exploratory Stratigraphic Plugs(measured) 6. Datum of elevation(DF or KB) 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-13 9. Permit number/approval number 81-27 10. APl number 50 - 029-20566 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 12141 feet true vertical 9003 feet Junk(measured) Casing Length Size Conductor 110' 20" Surface 2654' 13-3/8" Production 8702' 9-5/8" Liner 9233' 7" Cemented 300 sx PF 3200 sx Fondu & 400 sx PF 333 sx CI 'G' Measured depth 110' 2654' 11772' 700 sx CI 'G' RECEIVED True vertical depth 110' 2654' 8772' 9303' Perforation depth: measured 11900-11940';12048-12060' true vertical 8855-8880' ;8948-8956' APR 2 4 199?- Alaska 0il & Gas Cons. C0mm'tssi0~ Anchorage Tubing (size, grade, and measured depth) 5-1/2",17#,L-80, PCT @ 11004' MD,4-1/2",12.68, N-80,PCT Tail @ 11064' MD Packers and SSSV (type and measured depth) Baker SAR pkr @ 10971' MD;5-1/2" Camco BAL-O SSSV @ 2161' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1412 f 6400 1965 - Subsequent to operation 2181 ,'~' 6475 2910 - Tubing Pressure 25O 260 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X~ 16. Status of well classification as: OilX Gas.__ Suspended..__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned ~~. ~ Title FS-2 Regional Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~AILY REPORT OF WELL OPE[" .£IONS DS 16-13 Perforating Operations: ARCO Alaska, Inc. perforated DS 16-13 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 3/29/92. The intervals perforated were the following: 11900'-11940'; 12048'-12060' MD (Reference Log: DA-CNL dated 6/19/81). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 3/29/92. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, okay. RIH and perforated 12048'-12060' MD at I SPF, POOH, and confirmed all shots fired. RIH and perforated 11920'-11940' MD at 2 SPF, POOH, and confirmed all shots fired. RIH and perforated 11900'-11900' MD at 2 SPF, POOH, and confirmed all shots fired. (ref: DA-CNL of 6/19/81). Rigged down and secured well. RECIEIVED APR 2 4 '1992 Alaska Oil & Gas Cons. Com~'mss~;' Anchorago RDC: 4/22/92 Drill Site: 16 Well: 13 K-VAL¥-E DESIGN Sun Feb 09 un:mo:z/ z~z ti I I FTP ~ CLOSE it This design will work with or with out gas lift or with an increase in PI up to 50%. Under normal flow conditions the well should'not be choked back. CC: C.P. FARMER / W.D. CxDOPERTM J.C. S~T~/ M.~. SHOEMAKE C.L. CLARK / K.L. BLACKBURN EN~INEERiN~ WELL FILE PRB 24 PRB zu PRB 14 K.L. W~fSOCKi ATf; 1586 STATE OF ALASKA (Cx~VER) DESigNED BY: A.W. Brooks RECEIVED FEB 2 5 199 Alaska Oil & (;as Cons. Commission Anchorage STATE OF ALASKA ALASKA( .AND GAS CONSERVATION CO(r' IISSIOI~ J:{ J ~.1 I ~ ~'~ REPORT.OF SUNDRY WELL OPEl-rATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pedorate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratmy Stra~graphk: 4. Location of well at surface 1653' S & 548' E of NE cr. Sec. 24, T10N, R15E, UM At top of productive interval 1062' $ & 2007' W of NE cr. Sec. 13, T10N, R 15E, UM At effective depth At total depth 566' S & 1589' W of NE cr. Sec. 13, T10N, R15E, UM 12. Present well condition summary Total depth: 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-13 9. Permit number/approval number 81-27 10. APl number 50 - 029-20566 11. Field/Pool Prudhoe Bay Oil Pool feet measured 12690 feet true vertical 9305 feet Plugs(measured) Cement Plug w/Top @ 12141' MD. Effective depth: measured 12141 feet true vertical 9003 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110° 20" 300 sx permafrost 110' 110' Sudace 2584' 13-3/8" 3200 sx Fondu & 400 sx PF 2654' 2654' Production 8702' 9-5/8" 333 sx Cl "G" 11772' 8772' Liner 9233' 7" 700 sx Cl "G" 12685' 9303' PerforatiOn depth: measured 11900-11940' true vertical 8853-8878' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 11004' MD; 4-1/2", 12.6~, N-80, PCT Tail @ 11064' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10971' MD; 5-1/2" Camco Bal-0 SSSV @ 2161' MD. 13. Stimulation or cement squeeze summary ~ r,, ~ l i ¥ t.. ~ 14. Intervals treated(measured) See attached. JAN Treatment description including volumes used and final pressure ~a$.[~[ 0il & Gas Cons. C0mm'tss~0~ Reoresentative Daily Average Production or Iniection Data Oii-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2256 6071 8824 -- 488 Subsequent to operation 751 963 111 -- 270 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x...~. Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 792/6 DCR/MJB cc: SW, JWP 16-13 ~' DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & ZONE 4 FRACTURE TREATMENT 8/1 0/91: MIRU & PT equipment to 4000. RIH w/CT & loaded wellbore w/hot seawater, then reciprocated an acid wash over the perforation intervals, at: 11900 - 11940' MD (Z4) 11994 - 12028' MD (Z4) 12054 - 12094' MD (Z3) 12140 - 12180' MD (Z2) 12196 - 12216' MD (Z2) 12236 - 12248' MD (Z2) 12267 - 12274' MD (Z2) 12284 - 12298' MD (Z2) Ref. Log: BHCS 6/8/81. Jetted 100 bbls 15% HCl w/10% Xylene, followed by 98 bbls 12% HCl - 3% HF, followed by 97 bbls NH4Cl Water. Displaced CT w/seawater & tagged bottom @ 12422' MD. POOH w/CT & rigged down. 8/1 I/91 .' A Water Shutoff CTU Squeeze was performed as follows: MIRU CT & PT equipment to 4000 psi. RIH w/CT & fluid packed the wellbore w/seawater, then pumped 60 bbls of acid resistive cement w/20# aggregate/bbl, squeezing the perforations (listed above). Placed 4 bbls of cement behind pipe at 3500 psi maximum squeeze pressure held for one hour. Contaminated cement & jetted out contaminated cement to 12141' MD. POOH w/CT leaving a cement plug in the wellbore w/top @ 12141' MD. Rigged down. 9/20191: Reperforated: 11900 - 11940' MD (Z4) Ref. Log: BHCS 6/8/81. I 0/1 0/91: MIRU & PT equipment to 4000 psi. RIH w/CT & loaded wellbore w/seawater. Tagged bottom, then pumped 15 bbls of slurry containing 2700 lbs of 20/40 mesh sand, to isolate the squeezed perforations above the cement plug. Targeted for sand plug top at 11950' MD. POOH w/CT. Rigged down. 10/11/91: RIH & tagged top of sand plug at 11941' MD. 10/14/91: MIRU & PT equipment to 8100 psi. (listed above). Performed a Perforation Breakdown Treatment of the perforations Pumped 100 bbls 20# Slickwater Gel, followed by 300 bbls 50# Crosslinked Gel @ 13 bpm, followed by 20# Slickwater Flush. Shutdown. ISIP @ 2923. Resumed pumping 50 bbls 20# Slickwater, followed by 200 bbls 50# Gel w/160 ball sealers, followed by 20# Slickwater Flush, followed by 300 bbls 20# Slickwater Flush. Shutdown. Surged well to unseat balls, then proceeded to pump a Hydraulic Propped Fracture Treatment, using 12/18 mesh & resin coated proppants, through the open perforations (listed above). Pumped 329 bbls Pre Pad Gel @ 35 bpm, followed by Shutdown. ISIP @ 1966. Resumed pumping 823 bbls Pad @ 35 bpm, followed by 337 bbls Cross Linked Slurry @ 1-10 ppg, followed by 285 bbls Flush, followed by Shutdown. Placed a total of 54,645 lbs of proppant into the formation. Rigged down. RE~EIVqED 10/20/91 - 11/10/91: Performed proppant fill cleanouts (10/20, 10/24, & 11/10/91), to 11986' MD. Returned well to production & obtained a valid welltest. JAN Alaska Oil & Gas Cons. Anchorage ,~I-.L:U ALASKA IN(] P~O. BOX t ()(~S6~) ii~ ANCHORAGE, ALASKA 9~,_ ,~ DATE- t t -8-9t REFERENCE: ARCO CASED HOLE FINALS i(>-t6-9i INJ PROFILE iO-iT-Dt INJ PROFILE iO-i6-Di F'ROD PROFILE 0-i7-9t PROD PROFILE 0-9-9t TEMPERATURE 0-9-9i GR-CCL 0-6-9i F'FC -0-5-9 i C OLLAI-;,'-F'ER F O-tt-Dt LEAK DETECT O-tt-Dt INJ PROKILE £~-tt-gt INJ F'ROFILE ()-iS-Dt GAS L. IFT 0-5-9t COLLAR-F'ERF ~)-t 3-9t LEAK DETECT E:'ASE SIGN AND F;,'E'I"LJF;.:N THE ATTACHED COPY RECEIVED B Y~._ ~ HAVE A NIC~ DAY! SONYA WALLACE ATO-i 529 CENTRAL FII_E£ CHEVRON D & M EXTENSION E;XF'LORATION EXXON HARATHON MOBIL * ]"FIE CORRFCT DS!WEi..L. F4UMBEF;: IS i S--23A. RUN i , RUN i , RUN t, RUN i, RUN t, RUN t, RUN t, RUN t, RL!N i , RUN i, RUN i , RUN i , RUN i , RUN t, AS' RECEIF:'T Of: DATA. 5" CAMCO 5' CAMCO s' CAMCO 5' CAMCO 5' CAMCO 5" CAMCO 5" ATLAS 5' ATLAS 2"&5" CAMCO 5" CAMCO 5' CAMCO 5" CAMCO 5" - ATLAS 5"&t8' ..... 31~CAMCO AF'F'RO VEI;~~' 'FRANS:,~ 9J$59 F'HIL_L IF'S PB WELL FILES Iq& D -,." BF'X · $ 'STATE OF ALASKA TEXACO AnC. horag~ ARCO ALASKA, INC· F'.O. BOX i06'36(9 ~ ANCHORAGE, ALASKA %,~5i'~ DATE' ie-9-9t REFERENCE' ARCO CASED HOLE FINALS ~'0o°ci-O i-iT '7-i7-9i t-oil!~° 2-32 9-20-9~ cj. 0095--'o 3-t 6 9-i9-9i 0 - 00~2' 0 4-i 9-~ 3-9t '~-oo~S'O 4-~2 9-23-9t ~4-~ 9-24-9t ~- oo ~q'o ~4-~ 9-24-9i DSN RUN t, ~'.., COLLAR-PERF RUN i, 5' COLLAR-PERF RUN i, 5' PERF RUN COLLAR-PERF RUN i, 5" CBT RUN CET RUN i, 5" CCL I~UN i, 5" F'I_EA&'E SIGN AND RETUF(N THE A't'TACHED COPY A~' F,'ECEIPf OF' RECEIVED BY ' ATO-~ S2,9 ' OCT 1 5 199{rRA~S~ 9~ ~22 'Alaska Oil & Gas Cons. commi$$io~ D I S T R I B U T I Ct~lcborage CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MuB£L ~' PHILLIPS PB WELL FILES R & ~ ~ BF'X "I' :~ STATE OF ALASKA TEX~CU ATLAL Al'LA... Ai'LA."- SCH A i'I_AZ Drill Site' 16 Well' 13 K-VALVE DESIGN Wed Mar 20 17:27'19 1991 COMMENTS' II !! 1: DOME SET PRESSURE. 415 PSIG @ 60 DEG F : : FTP (~ CLOSE (PSIG~- 275 PSIG '' K-VALVE CLASS (A B Cl' C fl ~ I REDESIGNED FOR SSSV STATE TESTS. I I I I I I I I I CC' C.P. FARMER ./ ~',~D.~eo~oet' PRB 24 K.M. KENNEDY / W.S. W[[LDER PRB 20 C.L. CLARK / B,R. ROBERTSON PRB 14 ENGINEERING WELL FILE K.L. WYSOCKI ATO 1586 STATE OF ALA-SKA (COVER) DESIGNED BY' R.' R E.I,N~~ .~rinting contents of current screen - wait for message to clear RECEIVED APR ;99] Alaska Oil & Gas Cons. CommiS$io~ A~chorage · ... DATE' 3-2D-9t .F;:.EFIEI;:FNCF-' ARCO CASED HOLE FINALS F:'F;:ODLICT I ON PROF I LE COL. L. AF~/F:'ERF ;ii:BL. (F:'C:L. >/C;R/CCL. ,S'BL (WCI_)/GI;,:/CCL_ F:' R 0 D U C i' I 0 N P R C) F:' ]: 1.. E D ;";J N P F;.: 0 D L.I C 1' I 0 N F.' R 0 F: ]: L. E. C 0 L !.. A I-? / PIE R F F:' R 0 D U C'i" ]; 0 N P R 0 F' I I_ E:' P R 0 D U C: 'f' I 0 N P R 0 F:' :[ i.. E P R 0 D L! C T ]: 0 N I::' R 0 F I L. Iii: I.. E A K D Iii; T E C 'f' I 0 N RUN i , RUN I , RUN i , RUN t , RUN t , RUN i, F,:L.IN i , K'UN i, F,: UNi , RUN i , F;.'.t. JN i , RUN t , F:'I... I_::.: A Y E: S 15 N A N D [';;F T U R N T I--HE /.~'l' T A C H E D C 0 P Y HA V E A N -- ,, ;.~;' t"t A R 0 N 14 ]: L.,'.? C~ N A T 0 - t "''' ''~ o D I ,S' T R I B U l' ]: 0 N :.":CE:NTRAI_ 'F' I LES '"' C: I'.1F V R 0 N D &.M ........ :,",,EXI"EN$ I ON EXPLOF~AI"I ON ~ EXXON - MARATHON ~ MOBIL .... .' V' ~;:Z ' r-:.:~.,~,.,,, . . ...... ~/, j:.,-,, ,, : . . . ~;.J :t~;'~' .' AS' RECEIPT OF:' I) ATA, F F.OVE. I, AP";" "'~ 'I'RAN,~'~ 9 MAP, 2 6 1991 ... F, i--! :[ L. L .~[.l~kti QII & Gas Cons. Commi~ion F:'D WELl_ FILE,S' R.& b ............. ~ BP ~, X STATE OF ALASKA TEXACO CAMCO AI'I_F~.S' ATL. A,S' C A M C O HL_5' C A f.i C 0 r::~ f' i... f~ ;:';' C A t'i CCI C f::~ i,'] C tJ C A t.i CCI C R ,,"l C 0 PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillslte-Well:I 16-13 Comments I°Id design would not shut in well at FTP=250. :lNew design for state bench test. IValve now out of hole: measured dome pressure = 405. oate:J 9/10/90 Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) 460 250 Date 3/22/90 Production Data: ROR= 3000 BOPD CFR -- BOPD Swing Well (very hi0h or Iow GOR): No @ 9 0 Deg choke @ Deg choke Choke Priority Well: No Design Parameters: Basis:I 9/9/90X Rates (if needed): Oil Rate 3087 Watercut 77.1 Formation GOR 1 632 Gas Lift Gas Rate 2852 Total GLR 584 =lowing Tbg. Pressure 322 :low. Wellhead Temp. 1 63 Choke Setting 84H IActual well test date. Flowing-pressure survey and date. Rates used with hydraulics program (one only)' I x % SCF/STB MSCF/D SCF/STB PSIG DegF IPH2 PRUDHYD Conditions at Valve: Temp. @ SSSV 1 67 Deg F Pres. @ SSSV 729 PSIG Pres. Adjustment ~ SSSV 69 PSlG Notice: This adjustment is at the valve, not surface. I Calc. Dome Set Pres. 414.0 PSIG ~ 60 Deg F Actual Dome Set Pres. ,, FTP at K-valve Closure K-valve Type 41 5 PSIG @ 60 Deg F 25 0 PSIG @ Surface , C (Ar BT or C) cc: Ferguson / Farme~,'~'l Wilder/Kennedy (2 copies) State of Alaska cc: D.S. Eng: K.L. Wysocki ATO-1586 D.S. Supv: Clark /Roberts, qn ,// /,~ PRB-14 Prep. by: D.A. Bradley /~~~ PRB-24 RECEIVED S EP 1 9 1990 ~ Oil & 6as Cons. Zir. i ! ]. !L::: i '~'' ,:::'" i ,:;~, ' ,.. j .,. ~'~,_.~ ~ . . ........,- ~.-' . '~ ' ..'; ill; '-' ~ ....... :.5.; e.:, i ~-'~- ..... ' i' p: ...... ~/-;.'i:::~:E.; ]' ?'-l, ~'_'.i.-' F': "f" i F!i'-.i i-':"i r"; ]" .......i. i~ g,t ~ i"i i L 7 i.,.i T .gl i'.:i i'-i R iZi L F;; i.... .,.'r i...7! r--:'"': :.,.i r- ~ :'"' ~ i'": S G F:: ....'n ::::~. 7, r.:: .... ,-- i--. ~:..: :.:., .. r:.,_ .::' '-'-' ?: ...,. ...... I ,:::,3 2 ...... '-' "=' ........./~'. j.' tr.-i; i "-:' .",. .,;. '...' --' .,:.. ...;,-.;, --,-..Z, ," ,," ..1. .~.~ ,":: :;'.i. ':~. 'Z, ,- · -'~ ,"', ......... -' '* ,:::,-~-.:, l-:,. -_, ,::.,,-.. O . ,.-.'-::;:[ ......... i ......... ii_ ..................... i "' ............ ~ ............................................................................................................... i, '"'":'::': : .'-'"' :'"'.- i ~ :~ i:::' i-.i 'T [-: ~:::., .-.'5.::' T ~ 'F:-. i:..' P:, T --~ : ~ ': ' i "r':.- ii': 5:' i II :' ii, ~ ii ~ · :.~-_-_i:~'..7.i; .......... : .... :: .~ ......... i .... ~-~" 'i'.--~:::' ,:::, T' !.--i ...... .,::. ~ ' :_} ~i ! 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I I i .... ..=:..=i.::::., i . i i:::' 'i =:!-...iF: :'::"~ i I i ............................. i;"'~ i .... ! o- ...................................... i ............................. ~ ..................... .i.' .................. :,.-, .:.i. ................................ i ..................................................... ~ ........................... ?.! , , .... :.-, , , .t.,..., !':-~ ~ ...; c;,....., =: , . .,-t, t,."i' :: .'.':::',-.~"' ...... .... ~",,"' ~..~""'"'~ ........... ~:::..:::= -~ i:::' ti!f; ..... {.,?:i ..... 'T' !:::' ':::: 'T' i"-.; ~ ~.- ,~. ,,..- .,.,. ,_.. a. ·., ~.......- .,... ~ ..,......, .... . .... ~.'-"; ,"',, , 'T' !:7.'.,':-I I:' !7.[: ~'..~; E ": ',.'"- .7: '~ .................. :: ......................... ~" ~...L..i?4 ....... ,, r-',:~ r'--=~-. -r'~ i'!:;tiZ7 U':' I::;, ?' C:: '~II~Q l~/,..10--~ 073~ I)I~[LL SITE l& HELL 1~ ACT PIm,J OIL TnTGAS FONII ltikTD! GIG FTP FTP ; ~ S1'~ fi~d~'l) ~OE BIa~(Z) I~FD ~d~ PSIG PSIG I)I[T 84H(i~ )flu 310~ 73~ 1409 8447(73) 29~ ~ 290 C[]191~ LINE: .... -ItlXTUfl[ UELDCITY----- FS TWIIN --LINE:-- PRES CURRENT8 HOUI~ ~ LlltlT CUfllENT C i) PSIC (FPS) (FPS) (FPS) laC (Z) I~ i~ 2 [c ~ ~ 217 20.41 20.45 2~.00 53 532f l, ~~D WITE ~TAI LFR = O( ) LAST Iflq)dTE: 03-2~-8f 684:L ~i~ = ~)OO( ) LAST UPO~TE: 08-17-96 1449 flEC CLC = ~)OO EPDll ~ITCfl: I1UST PRODUCE ALLOCATION FACTDI~ OIL: 1.0180 (ItoNTH) CAS: 1.0119 H:21]:1.0095 WELL TEST REPORT AUG P~G ~UG TOTAL LIFT FDRII TOTAL TT~F DRIFC D~TE ~~P ~P DIL ~Tfi~ GAS Z ~ ~R TEST S~L ~IA POS~TEST~ ~T~ ~~D~TR~/B~TI~TRG 09-09 ~164 ~ 2~ ~710412 7892 2~ ?? 1~ 5~ 4.1E~G S. 25 09-05 84162 ~ 2~ 2~9 87~ 7191 ~ 7~ 15~ ~ 7.5~NG 3.25 08-27 83 160 2~ 24? 2694 ~0~ 5~5 19~ 77 1~7 ~7 4.~ H~G 3.~ 08-24 83 16~ 2~ 245 2~9 81f6 5923 1~f 74 1~2 5~ 10.1 N~g 3.25 08-20 ~ 1~ 2fl 2~ 2871 8207 5~52 lf71 74 1387 ~7 ~.~ NRNG 3.25 08-15 ~ 1~2 310 2~ 2~ 803S ~1~ lf~ ~ 1418 ~ 10.0 ~G 3.25 08-63 84 162 309 256 24~8 ~3 ~700 19~ ~ 1911 58410.1 E~G 3.25 07-22 8~ 160 345 284 2551 ~156 7938 ~ 78 1~ 678f. 6 ERNG 3.25 0&-22 84 159 354 25~ 2479 106041045~ 2910 81 3~ 79~10.0 E~G 3.25 0~-0~ ~ 159 347 259 32~ f760 98~9 0 75 ~4 7~ 10.0 ERRG 3.25 T~ UELL 1S C~LY S~ED~ED F~ TEST[~ m mm mm mm mm ~mm mm mm mm mm mm mm mm mm mm mm mm mm mm mmmmgm ~mmmm m R~TE TABLE L~ST ~TE: ~-17-90 1~0 C~E FTP D]L R~TE ~TR RME G~ R~TE CDR ~TER~T ]NC G~ ~RT~F]C~ LZFT ~ELL HAS 3 T~ES (SEE TP14) C ............. Alaska Oil & Gas Cons. Commission Anchorage APCO Ai~skm, Ir, c· P.O. Box Anchorm~e, A . _ --.2, i C '¢ .B O, '-7'-'-'"~: -.3~ -:' '-"- 3-.'5, t -,'~-o-::::o '-~3-32 4-9-86 $!'a I' J c i.}rad i e'n't '~3-33 4-2i -86 Static: tCradie;"~t '~ 3-34 4-.~ 6 '~, 4 :-~ _--, ,.~ _ c.. z ,[: i' a * .- ,4 -1- -- -~ .--r -...,,_, .. ~ c b'f.F.i,_, i eli . ~4--5 4--24-86 ~ ~.-~,, 6 .a -- 27 --. 86,. S*:. a ,.; c* 6r a,_~' i e'n",. ~7-~x,~ -?'~-27-88 $±a+, ic 6radie'n~ ~o-2 :~-26-°: S* :' ' .-. r. * "~ 9'-6 4-2= :':" Z.-:ta * i ,~';-...- .~ + _.'--oo : c a i eli "'""i i-iO R-'.::'-86 .'-':?ai' ~c =, =..., i~'n, -'--I ! -i 7, ~-~-R.z.. $'t... a + i cbrad i er~ -"i4-ii 4-9-86 S:,'l:.a~ ic G':.-ad ier.,t ---i4_oo ~_4 , - ' · ., _:. ,.t::,-S:6 c:.'owing b'r'..~d~er~ · -~-.-',z,-86 S±a , i c t:;-ao :: .=_-r:. ~-16-~, 3 4-2,_4-86 ~:'t a'~: i c ",~r ad i e'nt;. ---,i -,-=.,. _.- 4_27_o.::,_..,_, ...e~' .. ,,..=, ,.-, ,_ 6',.-a d i er.-.. * r--'i~,~...= _-.i?"---, a'nd '.,-:_:?~ur'n ",.'he a+±ached nc;r;,y a'-- '..:"e,-~, p-i- of da~'a, , _ ~:~ .'. .... : .... H~¥E ~ NiCE ~ ..... ~.__~;_ AT0-!529 · LT., Z -2 T F: Z }: U m Z :7 ::'..~ · ARCO Alaska, Inc· P. 0 · BOX i Anchorage, ALaska 995t0 DATE' Mmrch 27, i986 REFERENCE' ARCO Cased HoLe Final -- "-' DS '-/ DS ,'"J DS "".J DS '~ DS ~",,,4 DS '"J DS ...' ",.f DS '~ ""' DS ,..,o DS -~ DS .~ DS ., .~ DS 4- t t G-" 85 ~' ~'. 4-' C N L R u r, t ., 4-t i 8-24-85 Ep i Log Run 4-7 2-3-85 CET Run t 5' 4-t~ t2-26-85 Diff Temp Run 4-.i5 t~ 2 85 D iff Temp Run i 4-24 t t -~---85 Ep i ~og Run ~ /~ t t-9-85 . CNL ~.~. ~ Rut. t 5' 4-28 ~--'~ ~ -85 Diff Temp ' Run ~-c~3-.85 Diff Temp Run i 5' 4-29 l ~... t 5 - 7 '~- '~ n ~ ", 5 ~. ~:v-._,6 ..,,p inner Run .,-,= ,.. ~..~,.-.86 Sp i nne~ .... Temp Run t ., 6-3 ,~:.- 6-8c. Sp J nner-Temp Run 6--~ 3 v-.~,. .... 9--86 Sp i r,r~er--Gl::: Run t "~," 6--i ~ i" '"' '=' ~ VI)I_/'" 5" _, ~.:--,s. 8-8_, AC~.I../ . .~ i g/GR Run i 6 -- t 6 2 .... 1 9.-. 8 6 W a t e r I n j e c: ~ i o n R u ~'~ t 6-t 9 t -t --Eo- ~.~,.,}..L.., VI.L., .:~ i g./GR Run t ........ ? ~.-.2(~ 1-?-..>..:6 ACBL/VI)L./Si q/GF. R. un t DA I) A Sch I) A DA I)A DA I) A DA C 8 fll C 0 PLease :~;ign and ret'urr~ t'he attached C:Ol:~y a~ rec:eipt' o'f dat'a, I r m m C a r L in ~ NO~ 011 & Gas Cons, ~m~Wn . A T O- t 429 F ~chomge I'RANS ~:862t5 DISI'RIBUTION ARCO Alaska, Inc.~ ~ Post Office~ox 100360 Anchorage. Alaska 99510 Telel~hone 907 276 1215 Date: August /, 1985 Reference: ARCO CH Finals 3-7~ Temp./Spinner 7-24/25-85 Run 1 5" Camco 3-16' CET 3-16~ CET 5-13; CNL 5-13 ~ CET 6-19- Perf Record 7-22/ CNL 9-4~ EPL 9-.16x CET 9-16/' CBL 9-35' PDK 100 11-8'~ CBL ll-13ZCBL 12-21"'CCL/Perf 16-13zSpinner 17-14/CBL 4-3-85 1 5" Sch 4-7-85 2 5" Sch 11-26-84 3 5" Sch 4-29-85 1 5" Sch 6-9-85 1 5" Sch 5-16-85 1 5" GO 6-13-85 1 5" Sch 4-26-85 · 1 5" Sch 4-26-85 1 5" Sch 7-8-85 1 5" DA 7-/3/4-85 1 5" DA 7-3-85 1 5" DA 11-29-84 1 5" Sch 7-25/26-85 1 5" Camco 4-14-85 1 5" Sch Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 252 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil *""~ ~'~ ~ G,~s Cons. Commission /mChorage Phillips PB Well Files R&D Sohio State of Alaska Texaco ARCO Alaska, Inc, is a SuDsidiary of AtlanticRichfietdComDanv ARCO Alaska, Inc. Prudhoe Ba, engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 17, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-13 Permit No. 81-27 Enclosed is the "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:pr Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 16-13)Wl-3 D JUL ~ ~ ~llt§ ~:"-'??, ~'~,~ ,~ G~s Cons. Commission ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany ~ OI '~u STATE OF ALASKA ALASK L AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address :P.O. :Box 100360, Anchorage, Alaska 99510 4. Location of Well (fst].rface) 1653'S & 548'E of NW cr Sec. 24, T10N, R15E, OM (Producing Interval) 1062'S & 2007'W of NE cr Sec. 13, T10N, R15E, UM (Total Depth) 566'S & 1589'W of NE cr Sec. 13, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and Serial No. ADL 28332 7. Permit No. 81-27 8. APl Number 50-- 029-20566 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · Began re-perforating operation on 6-17-85. RU perforating unit and pressure tested equipment. RIH with gun 91, shot interval 12284' - 12298' MD (4SPF). Shut-in well, POOH, all shots fired. RIH with gun 92, shot select-fire interval 12267' - 12274' MD (4SPF); pulled up and shot select-fire interval 12236' - 12248' MD (4SPF). Shut-in well, POOH, all shots fired. RIH with gun 93, shot interval 11920' - 11940' MD (4SPF). Shut-in well, POOH, all shots fired. RIH with gun 94, shot interval 11900' - 11920' MD (4SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Note: A 20%'decentralizer was lost downhole during the re-perf operation. Ref: BHCS 6-8-81 RECEIVED JUL2 21 B5 Alaska Oil & Gas Cons, Commission Anchorage 14. I hereby,/~tify that the foregoing is true and correct to the best of my knowledge. The space'below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALas'l<a, Inc F' ,. O. Box Anchorage, ALaska 995 ~ (~ DATE' ,.lanua'ry i R IE F' E F;,' E N C E ' A R C 0 C a :'.:.: e d HoLe l'-'inat. D S i ":'-;'" i _ :..,.., Spinne'r' ........ 4 .... C:, ~:.' D., ..'~ i ; I i --' '~':::'---- o ,~ "~ .... ' .... ,... ......... D i f f 'f' e m I::' I... o g D, ,',, i .... ; i t .... :.."-.!8.--.84 CF';?/;fi;p i nne'r D~,?, ~ .... '26--~ ii .... i6,-.-.84 CI-.t CNL.. D,. ,"~' , 3; .... t "~'_,- ~-' t 2 ..... I 7-84 PL.S D L:~' 4 - i ,3 ~ 'i "' i 6.---o 4 ;!.;' p i n n e'r' I... o g D %' '"' ""-/ ~2 .... i4-84 ~ ~ :', .... ,--- F:'L:'.;' D., ,?.,o.....-.,,. ~/- 'i 2 i 3 -.. 8 :.I. r', -:', ! ~,-~ .... I°" L. D~,S'~ 9 ..... 4~' i2 .... t..,. ":: .... 84 PI...,? D ,? o_, ~'~ ,,'., o, ., ~ ., '~i '~,....-"-i6 ,...4 "' '"" .... I-' I... ,:~. D ,. ;?;, i 3 .... 2A ~' i i --'23;-8,:'~, Cc, L I...:'~ 'r'/F:'e'r' f Log D Y 'i S..--21 i .... 6-... 8':: ' ..... ., ,!.;; i::' i n n e ¥' L.. o g D '1';' i 3 .... 2 i i .... 6-8":" C c, L L a 'r' L.. ,:::, g D.,,?., 'i?'!;-S4~' ii .... 9..--84 CH CNL.. D ,'.:':,' i "; .... ' "' · ..., '~ 4/ i 2-2'--.~::~ '''~ f":F:'.S',,"S'p inne'r' D ~" i..~ .... · -'"' o .... :. .-.¢ . .. . ,.,., '~ 6 i i .... 2., 84 C F' S / S ~::, i n n,:::,'r', D., ,"'],', i 5 .... 4 ~ i i .... i ('9- 8 q f;'; H C N t... D., £ ., i '~'..,. .... '"',: -'9----6-... 8 q ,'i;.. R. D,.S~ i6 ....7-" i2 .... i2.-84 CF:'S/Spinne'r' ..lb..:. S , i 6- ?'.'; "'" i 2 ..... 'i i:!:- ,..:'::: ...,':'.'- ;'"',.,. i I': i: T e m p L o ,.';.4 D,. 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E x x o n F;.: ,..'!: D Ge t t y $oh i o Ha'r'a'~h,.'::,n State of ALa.ska J::' J I. e .':i: ARCO Alaska, Inc.tr~ Prudhoe Bay[,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 2, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-6 DS 16-9 DS 16-12 DS 16-13 Permit No. 81-51 Permit No. 81-19 Permit No. 81-26 Permit No. 81-27 Enclosed are the Completion Reports for work done on the above mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosures CC: SOHIO Alaska Petroleum Co. File P1 (DS 16-6)W4-3 File P1 (DS 16-9)W4-3 File P1 (DS 16-12)W4-3 File Pl (DS 16-13)W4-3 RECEIVED JUL ! 6 AJask;~ 0il & Gas Cons. Commission ARCO Alalka, Inc. Is I Sublldllry of AtlllntlcRIchfleldComplny LASK( iL AND GAS CONSERVATION (' .... IMISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOllS, 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-27 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20566 4. Location of well at surface 9. Unit or Lease Name ,, 1635' S & 548' E of NW Cr, Sec 24, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1062' S & 2007' W of NE Cr, Sec 13, T10N, R15E, UM DS 16-13 At Total Depth 11. Field and Pool 566' S & 1589' W of NE Cr, Sec 13, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 70' RKBI ADL 28332 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4/6/81 6/8/81 6/16/81 -- feet MSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV sot I 21. Thickness of Permafrost 12690'MD - 9305'TVD 12658'MD - 9288'TVD YES F~ NO [] 2161 feet MD 1975' (Ref: DS 16-1) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, CBL/CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-80 Surf. 110' 32" 300 sx Permafrost 13-3/8" 72~ L-80 Surf. 2654' 17%" 3200 sx Fondu & 400 sx Permafrost 9-5/8" 47~ L-80 & Surf. 11442' 12~" 333 sx Class G 9-5/8 (plugged) S00-95 11442' 11772' 12~ 167 sx Class G 7" 29# L-80 11109' 12685' 8½" 700 sx Class G 24. Perforations open to prOduction (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) *blew ?errs w/4spf SIZE DEPTH SET (MD) PACKER SET (MD) *11900 - 11940' MD (40') 8855 - 9096' TVD 5~" 11064 10911 11996 - 12030' MD (34') 12054 - 12094' MD (40') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12140 - 12180' MD'(40') ~ . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED *12196 - 12216' MD (20') *12236 - 12248' MD (12') *12267 - 12274' MD (7') . . .' ~ ~ *12284- 12298' MD (14') ~ "",'- . . . 27. PRODUCTION TEST t Date First Production Method 0f Operation (Flowing, gas lift, etc.) 3/20/82 Flowing ., : . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 6/11/84 6.3 · TEST'PERiOD I~ 1704 '6672 -- 50.'I 3914 · Flow Tubing Casing Pressure CALCULi, TED' i~.~ :OIL-BB'L GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1984 180 ' "24_HOUR RATE '~' .649-3' "' · 25417 ~. -- 27.0 28. CORE DATA ' ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . NONE ~ · ' · "' ' , RECEIVED .. JUL/6 1984 · . Alaska Oil & (~as Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 11901' 12384' 12591' TRUE VERT. DEPTH 8855' 9143' 9254' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ........ ..--"' Title Regional Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where' not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produ, ced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, In't.'( Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 25, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 16-6 DS 16-9 DS 16-12 DS 16-13 Permit No. 81-51 Permit No. 81-19 Permit No. 81-26 Permit No. 81-27 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File P1 (DS 16-6) W1-3 File P1 (DS 16-9) W1-3 File P1 (DS 16-12) Wl-3 File P1 (DS 16-13) Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany STATE OF ALASKA ALASKA( L AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L L)rE~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (surface) 1653'S & 548'E of NW cr Sec. 24, T10N, R15E, UM (Producing Interval) 1062'S & 2007'W of NE cr Sec. 13, T10N, R15E, UM (Total Depth) 566'S & 1589'W of NE cr Sec. 13, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and Serial No. ADL 28332 7. Permit No. 81-27 8. APl Number 50-- 029--20566 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, inclUding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 5/19/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 12284 - 12298' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. RIH with gun #2, shot interval 12267 - 12274' MD and 12236 - 12248' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. RIH with gun #3, shot interval 12196 - 12216' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. RIH with gun #4, shot interval 11920 - 11940 ' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. RIH with gun #5, shot interval 11900 - 11920' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 6/8/81 RECEIVED JUN2 81984 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby,e~rtify that th, A foregoing is true and correct to the best of my knowledge. Signed Title The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( ARCO Alaska. Inc.'~ Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 6, 1984 Reference: ARCO Cased Hole Finals D.S. 1-26-~ 5-17-84 D.S. 2-17.?~ 5-12-84 D.S. 4-1 5-6-84 D.S. 5-8-' 5-5-84 D.S. 6-18~ 5-22-84 D.S. 9-4~/' 5-7-84 D.S. 9-6-~' 5-7-84 D.S. 12-17j' 5~14-84 D.S. 12-23~ 5-16-84 D.S. 13-98~./5 16-84 D S. 16-13" 5 20-84 D.S. 17-7/ 5-25-84 D.S. 17-10 '~'"5-18-84 D.S. 17-10~'~ 5-18-84 D.S. 18-~- 5-14-84 Collar/Perf Log Run 1 5" 'GO Collar Log to set Casing Patch Run 1 5" GO CN/MSN/GR CN/MSN/GR CPL/TDT-M w/listing CN/MSN/GR CH CNL CPL/TDT-m w/listing Run 2 5" DA Run 1 5" DA 5" Sch Run 1 5" DA Run 1 5" GO 5" Sch X-Y Caliper Log w/Borehole Volume Run 1 5" GO CPL/TDT-M w/listing CH DIL Collar/Perf Log Collar/Perf Log CET Log CCL/Perf Record Temperature Log 5" Sch . Run 12 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" GO /~ase sign and return the attached copy as receipt of data. Be PATRIOTIC! - Hang out your flag on the 14th. Kelly McFarland ATO-1429F Trans. #231 DISTRIBUTION 'Chevron D&M Drilling Exp. Services Ext. Exploration Exxon .~etty Marathon Prudhoe Bay Well'"'Fil~S ..?,.:. '"~%17 ..... Carolyn Smith Sohio ,State of Alaska ARCO Alaska, In{'" ~ Prudhoe B%~ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 3, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 16-4 DS 16-6 DS 16-8 DS 16-9'~ DS 16-12 DS 16-13 DS 16-14 Permit No. 81-20 Permit No. 81-51 Permit No. 81-2 Permit No. 81-19 Permit No. 81-26 Permit No. 81,27 Permit No. 81-32 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File Pi(DS 16-4,6,8,9,12,13,14)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ' STATE OF ALASKA (? ALASI~ ~ILAND GAS CONSERVATION .MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL :~3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-27 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20566 4. Location of Well 1653'S & 548'E of NW er Sec. 24, T10N, R15E, UM 1062'S & 2007'W of NE cr Sec. 13, T10N, R15E, UM 566'S & 1589'W of NE cr Sec. 13, T10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-13 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' 70' RKB I ADL 27332 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 16-13 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay'Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11900-11940' MD 12196-12216.' MD 12236-12248' MD 12267-12274' MD 12284-12298' MD Ref: BHCS 6/8/81 14. I hereby c~,rtify that the foregoing is true and correct to the best of my knowledge. Signed ~//,~1~' ~/~,~__~~' Title The space below for Commission use Regional Engineer Date Conditions of APproval, if any: Approved by Form 10-403 Approved Cc~a~ By Order of COMMISSIONER the, Commission Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 11, 1983 Reference: Arco Cased Hole Finals D.S. 1-24 ~1-19-83 EPL 1-18-83 CBL/VD D.S. 1-25~/ 2-13-83 CBL/VD s %tI~,-/D]S[ 2-20' 1-27-83 Perforating Record D.S. 3-15~ 12-9-82 CNL/GR/MSN ----D.S. 6-11 11-29-82 CNL/GR/MSN D.S. 12-12' 2223-83 Temperature Survey p.S. 12-17~'1-28-83 Temperature Log D.S. 13-2A~'2-7-83 CBL/VD 1-29-83 'Tubing Puncher 'Record D.S. 13-9/ 1-24,83 CEL 1-2.7-83 1-30-83 1-?-83 2-3-83 1-28-83 1-28-83 CET CBL/VDL & Waveforms Temperature Log EPL CCL & Perf Record CET D.S. 14-15,/ 12-15-82 CNL/GR/MSN D.S. 16-13 ~12-10/11-82 CNL/GR/MSN Run 1 2" & 5" Sci Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 2 5" DA Run 2 5" DA Run 1' 5" Camco Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" S ch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 3 5" Sch Run 2 5" DA Run 2 5" DA se sign and return the attached copy as receipt of data. ,Kelly McFarland AFA-4 03 Trans. # 207 NORTH GEOLOGY R & D DRILLING. PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOB I L D&M' '~'~ STATE OF 'ALASKA DALLAS CAROLINE SMITH February 16, 19 83 ARCO Alas ka' Inc. P.O. Box 360 Anchorage, Alas 'ka,.99510 Re~ Subsequent Reports, Sundry };otices and Reports on Wells (Form 10-403 ) Attn~ Pete Van Dus en Distriot Drilling Engineer For the following lists of "Notice of Intention To:' Sundry Notices and Reports on Wells (form 10-403) this office does not have on record the "Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the dispogition of the intention. Well DS 14-18 Wo Sak River State B5 .~ DS, 12-8A · .. DS I DS 13-3 DS 12-4 BP 24-10-14 DS 13-2 West Bay St ate 1 BP 31-10-16 DS 15-3 ' Oliktok Pt. 1 DS 15-3 DS 5-11 DS i16-13- N. Prudhoe Bay St. 2 ~uparuk 1E-12 ARCO Date 2/11/81 6/9./I~1 10/23/81 · 11/23/81 11/2/81 12/15/81 12/15/81 12/23/81 2/2/82 2/23/82 3/17/82 3/23/82 -3/23/82 4/2/82 4/5/ 2 6/2/82 6/2/82 Brief_ Description of.. Intent...'%,9.n Change course of this well . Workover Abandon lower borehole' prior to sidetrack Abandon lower borehol~ prior .to sidetrack Pull and replace tubing Abandon lower borehole prior to sidetrack Plug and abandon Pull and replace tubing Test Lisburne formation Plug and abandon Change setting depth 9 5/8" casing Deepen 8% hole to basement Change setting depth 9 5/$" casing Pull tubing and repair casing Sider rack - Abandonment procedure C~ange grade L-80 portion of 7" casing ARCO Alaska, inc. Post Office BI' 160 Anchorage.Ab ~(a 99510 Telephone 907 277 5637 January 24, Reference: 1983 Arco Magnetic tape and list .D.S. 16-13 12-10-82 5 pass CN/MSN # 1570 DA Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 080 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBILE GETTY D&M Alaska 0il & Gas Cons, C0mmJssion Anchorage ARCO Alaska, Inc, is a Subsidiarv of At!anticRichfietdCompan,/ ARCO Alaska, Inc. Post Office B("~ '60 Anchorage. Al~=l(a'~' 99510 Telephone 907 277 5637 November 23, 1982 RE' ARCO Cased Hole Finals D.S. 1-8 10-24-82 CH CNL DoS. 1-22~ 11-6-82 CBL/VD D.S. 4-1~' 10-30-82 ' CH CNL D.S. 5-7f 10-26/5-14/10-22-82 CNL Gas Monitor Log D.S. 5-7~ 10-22/5-14-82 CNL Gas Monitor Log D.S. 5-7~ 10-22-82 1).S. 5-14~/ 10-30-82 D.S. 5-12~-~' 10-23-82 D.S. 6-23 ~ 10-21-82 D.S. 6-24~ 11-4-82 D.S. 13-5~ 8-20/11-1-82 D.S. 13-15/ 10-21-82 D.S. 13-16-'~10-3-82 ~S.,--16,~--~ 7- 22 - 82 D.S; 18;lOv 10-21-82 Run 5 SCH Run 1 SCH Run 6 SCH · Run 3, lO, & 11 SCH ;'~Run 10 & 11 SCH CH CNL Run ll SCH CH CNL Run 3 SCH CH CNL Run 7 SCH ACBL Run 1 D/A CBL/VD Run 1 SCH CH CNL (CNL Monitor Overlay) Run I & 2 SCH CBL/VD Run 1 SCH ACBL Run 1 D/A Spinner Camco ACBL Run 1 D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #625 DISTRIBUTION NORTH GEOLOGY .. EXXON R & D MOBIL DRILLING GETTY PHILLIPS D & M SOHIO ,~!:-~,~,., STATE OF ALASKA~'"'~ MARATHON DALLAS · CHEVRON ARCO Alaska, inc. Post Office B ~60 Anchorage. Alaska 99510 Telephone 907 277 5637 August 24, 1982 Reference: Arco Pressure Data D.S. 16-13 7-22/23-82 HP Pressure Analysis Camco e sign and return the attached Copy as receipt of data. Kelly McFarland Trans. ~/ 410 DISTRIBUTION NORTH GEOLOGY R&D DRILLING pHILlips SOHIO GETTY D&M GEOLOGY - o. MARATHON CHEVRON STATE OF ALASKA DALLAS ARCO Alaska, In, A,chc',ragc, :',.Jo. :,:; :.~' May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive ~chorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 16-5 Permit No. 81-37 D.S. 16-6 Permit No. 81-51 iii~S~.:??~:~.~3i~i,Permit No. 81-27 D.S. 16-14 Permit No. 81-32 Enclosed are Subsequent Sundry Notices for work done on the above-mentioned wells. Very truly yours,f .,"D. F. Scheve ~istrict Operations Engineer DFS:TKKW:mlc Enclosures Distribution: Sohio Petroleum Co. STATE OF ALASKA ALASKA ~LAND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL::~;~: OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-27 3. Address 8. APl Number P,O. BOX 360 Anchorage, AK 99510 50~29-20566 4. Location of Well 1653'S & 548'E of NW cr Sec 24, T10N,R15E,UM (surface) 1062'S & 2007'W of NE cr Sec 13,T10N,R15P.,UM (top producing) 566'S & 1589'W of NE cr Sec 13, T10N,R15E,UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) __ RKB 70' 12. 6. Lease Designation and Serial No. ADL 28332 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 16-13 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations J~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 3/18/82. Tested tubing and annulus. Tested tree. NU and tested perforating equipment. NU and test wireline BOP and lubricator. Perforated 12160-12180'MD with 4 spf. Perforated 12140-12160'MD with 4 spf.. Perforated 12074-12094' with 4 spf. Perforated 12054-12074'MD with 4 spf. Perforated 12008- 12028'MD with 4 spf. Perforated 11994-12008'MD with 4 spf. Rigged down perforating euipment unit. Rigged up wireline unit. Tested wireline BOP and lubricator. Recorded static bottomhole pressure. Rigged wireiine unit. Secured well, 3/21/82. MAY 2. ? i982 Anchorage 14. I hereby ~d~/that the for~ng is t~and correct to the best of my knowledge. Signed /~_~/('~ ~'/~ ~ ~'¢--,'~_~-~/,~'~-.-"-- ---------~.- Title Dist. Oprs. The spac¢,~w for Commission use Enqineer Date Conditions of Approval, if any: By Order of Approved by. 'COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 16-5 Permit No. 81-37 D.S. 16-6 Permit No. 81-51 ermit No. 81-27 D.S. 16-14 Permit No. 81-32 Enclosed are Completion Reports for work done on the above-mentioned wells. Very truly yours, .~'% ,"7 ///2 J '/ _.~ ,~' '// ~./' % ....!:>-~ /.:Z.~.~,. 'zc, .,,,.----,x~. , /~.~.-~--',,; .... ,,~~D, F. Scheve District Operations Engineer DFS:TKKW:ml¢ Enclosures Distribution: Sohio Petroleum Co. , STATE OF ALASKA ' ALASKa' '~L AND GAS CONSERVATION ~' VIMISSION WELL COMPLETi' .,N OR RECOMPLETIOh rlEPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-27 3. Address 8. APl Number' P.O. Box 360 Anchorage, AK 99510 50-029-20566 4. Location of well at surface 9. Unit or Lease Name 1653'S & 548'E of NW er Sec 24, T10N,R15E,UM Prudhoe Bay Unit At Top Producing Interval. 10. Well Number 1062'S & 2007'W of NE er Sec 13,T10N,R15E,UM D.S.16-13 At Total Depth 11. Field and Pool 566'S & 1589'W of NE er Sec 13, T10N,R15E,UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool RKB 70 'I ADL 28332 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 4/6/81 6/8/81 6/16/81 --- feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12690'tvD 9305'~I) 12658'tvD 9288'~v'D YES ~] NO []I 2161 feet MD 1975' (Ref: DS 16-1)! 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, CBL/~GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-80 surf 110 ' 32" 300sx Permafrost 13-3/8" 72~ L-80 surf 2654' 17-1/2" 3200sx Fondu & 400 ~[ Permafrost 9-5/8" 479 L-80 & surf 11442' 12-1/4" 333sx Class G 9-5/8" (plu~fqed S00-95 11442' 11772' 12-1/4" 167sx Class G 7" 299 L-80 11109' 12685' 8-1/2" 700sx Class G 24. Perforations open to Production IMD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and nurr',..er) SIZE DEPTH SET (MD) PACKER SET (MD) 4 shots per foot 5-1/2" 11064 10911 11994-12008 '/¢~3 ~ 8914-9027 ' TVD 12008-12028 'tVJD-~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12054-1:20'74 'MD ~ 3/2 I.,/~ c~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12074-12094 'MD'~5 12140-12160 'MD } 12160-12180 'MD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 3 / 21/82I FLOWING Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO 4-13-82 6.0 :TEST PERIOD I~ 2425 1569 0 49 930 Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 1153 NA i24-HOUR RATE I~ 8289 7710 0 26.6 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of Oil, gas or water. Submit core chips. RECEIVED MAY 2 71982 ~ 0il & Gas Cons. Commi~ A~orage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ARCO Alaska, Inc. Pos! Office 9 360 Anchorage. A...Ka 99510 Telephone 907 277 5637 April 21, 1982 Reference: ARCO CASED HOLE FINALS ......... '..,r.~ '"'/ ' '" 5" D S 15-2 ~" 5" . . 3/7/82 CBL/VD Run 1 D. S.5-17 ~/ 2/26/82 EPL Run - 5" D. S.2-19~ .... 3/20/82 ACBL/VDL Run 1 5" D.S.2-19. 3/24/82 CNL Run 1 5" D.S.15-3 ~' 3/23/82 ACBL/VD Run 1 5" D.S.16-5'" 3/22/82 Collar & Perf Log Run 1 5" D.S.16-12~ 3/20/82 Collar & Perf Log Run - 5" D.S.16-6 /" 3/24/82 Collar & Perf Log Run - 5" D:.S,16-13 3/18/82 Collar & Perf Log Run - 5" D.S.4-14 '' 3/27/82 Collar & Perf Log Run 3 5" D.S.4-!4 ~ .... 3/26/82 Fluid Density Log Run 1 5" ~/ Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 117 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON A,I~CO AJ.'lsk~ :,'~C. Is a s'Jbs~g~:~ry Ol A l.ln~c,qichtleldCo;:lp,lny E%~XON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ,"-~-" · /'%' L- /', [ ~."..-~ ~. ARCO Alaska, Inc. North Siopo [' ct Post Office B(.,~ ,~F, 0 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 29, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Subject- D.S. 16-5 Permit No. 81-37 D.S. 16-6 Permit No. 81-51 D.S. 16-12 Permit No. 81-26 ~ ~'~'~iS~:~ 16.~:13?~P~rmit No. 81-27 D.S. 16-14 Permit No. 81-32 D.S. 17-7 Permit No. 81 -66 D.S. 17-8 Permit No. 81-74 D.S. 17-9 Permit No. 81-90 D.S. 17-10 Permit No. 81-97 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned wells. Very truly your. s, ~"~--~ ~ ?k~ ,,, JAR 'TKKW :ml c Enclosures ARCO Alaska. Inc. Is a s.,Jbsidiary of AllarHicRich['ieldConlpany ( STATE OF ALASKA ( ALASKA &'IL AND GAS CONSERVATION C0M MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:/] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska Inc. 81-27 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20566 4. Location of Well 1653' S, 548' E of NW Cr. Sec. 24, T10N, R15E, UM 1062' S, 2007' W of NE Cr. Sec. 13, T10N, R15E, UM 566' S, 1589' W of NE Cr. Sec. 13, TiON, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and Serial No. ADL 28332 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 16-13 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaskaproposes toperforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating the well will be flowed to the flow station for clean up and production. Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The perforated intervals will be given in the subsequent report. Ail wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean up operation. i ECEIVED FEB 0 3 ]982 Alaska Oil & Gas Cons. C0mmJssi0. Anchorage 14. ' hereby ~hat the f)o~ true and correct to the best of my knowledge. Signed ..... Title Distr±ct Eng±neer , The spac~e~'~)w for Commission use Date Conditions of Approval, if any: Approved by ORgG!NAL SIGNED BY [GN?!E C., S~ITH ~etumed By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas [ '~pany North Alaska ,.,mtrict[ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 31, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.16-13 7/8/81 TaPe #CN 2380-12460 Dresser sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #480 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany EXXON MOBIL GETTY PHILLIPS SOHIO ARCO Alaska, Inc. PoM Office .~ 360 Anchorage. /'...l¢~s.-,a 995 tO Telephone 907 277 56?,7 July 21, 1981 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Con, hi ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 12-10 DS 16-14 DS 12-11 DS 17-7 DS 14-18 DS 17-8 DS 14-19 A-1 DS 14-20 A-2 ~,~ ..... B-3 13-4 Dear Sir' Enclosed 1 ) The please find' monthly reports for DS 16-14 & B-4. 2) The subsequent Sundry Notice for DS 14-18. 3) The 14-20,C°mpleti~°~~~ep°rts for 17-7, DS 12~ ~)lO DS 12-11, DS 1~-19, ~s ~]6-~ ~s ~s ,~-o, A-~, A-~ ~ ~- . 4) The Gyroscopic Surveys for DS 12-10, DS 14-20, DS 16-13, A-1 and B-3. Si ncerely, P. A. VanDusen District Drilling Engineer PAV/KJG'sp Enclosures .JUL 2 1 I.S¢~ 0ii & Gas Corm. C(mm,;~ :,- o RIG A [ STATE OF ALASKA O~ ALASKA OIL AND GAS CONSERVATION C ,,vtlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well OIL IX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-27 3. Address 8. APl Number P.O. Box 360, Anchorage, Ak 99510 5o-029-20566 4. Location of well at surface 9. Unit or Lease Name 1653'S, 548'E of NW cr Sec 24, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval "~'0. Welt Number 1062'S, 2007'W of NE cr Sec 13, T10N, R15E, UM DS 16-13 ,,, At Total Depth 11. Field and Pool 566'S, 1589'W of NE cr Sec 13, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool 70' RKBI ADL 28332 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4-6-81 6-8-81. 6-16-81 -- feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of PermafroSt 12690'MD 9305'TV~ 12658'MD... 9288'TID'ES~ NoD 2161 feetMDI 1975' (Ref' DS 16- 22. Type Electric or Other Logs Run DTL/SP/BHCS/GR: CBL/CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-80 surf llO' 32" 300 sx Permafrost 13-3/8" 72# L-80 surf 2654' 17~" 3200 sx Fondu & 400 sx Permafrost , , 9-5/8" 47# L-80 & surf 11,442' 12¼,' 333 sx Class G 9-5/8" (pluqqed) S00-95i 11,442' 11,772' 12¼" -1'67' sx Class G 7" 29'# L-80 1'1,109' 12,685' 8½" 700 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD . . interval~ size and number) SIZE DEPTH SET (MD) PACKER sET (MD) 5½" 11,064 !0,911 .... · n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .... , DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , , ~ . .: :, .. , .' , . , _ , , . "' 27. ': PRODUCTION ~FEST Date First Production . I Method of Operation (Flowing, gas. lift, etc.) I :""' n/a ,. ., DateofTest Hours Tested FJRODUCTION FOR OIL-BBL GAS-MCF 'I ~A:T"ER]BBL CHOKESIZE I GAS-OILRATIO i TEST PERIOD I~ . Flow Tubing Casing Pressure CALCUL/<-r:ED '"' (~IL-BBL GAS-MCF WATER-BBL OI'L GRAVITY-APl (corr) 'Press. 24-HOUR RATE' ]~ " ' ' 28. CORE ~ATA ...... Brief description of lithology, porosity, fr§ctures, apparent dips and ,presence of oil, gas or water. Submit core chips. JUL 2 , : . Alaska Oil &/~a~ Cons. Cornrr!i$$~or~ .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS -- ,. NAME ................. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sadl erochi t 11,898' 8852' n/a ., ; , .................... LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ 7/~ Title Dist, Drlg. Eng. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 16-13 Drilling History Spudded well @ 0900 hrs, 4/6/81. Instld 20" riser. Drld 17½" hole to 2677'. Ran 65 its 13-3/8" L-80 72# Butt csg w/shoe @ 2654'. Cmtd csg w/3200 sx Fondu & 400 sx Permafrost. ND 20" riser. Instld 13-3/8" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi f/15 rain - ok. Drld FC, cmt, FS & new form to 2687'. Tstd form to 12.5 ppg EMW - ok. Drld 12¼" hole to 8064' - torque backed out pin in DP @ 3125' RIH to fish & workover POOH w/fish. Drld 12¼" hole to 11,879'. ~an 281 its 9-5/8" 47# L-~O & S00-95 csg w/shoe @ 11,772'. Cmtd csg w/500 sx Class G. Instld 9-5/8" pkoff and tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt, tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Ran CBL. Drld 10' of 8½" hole - DP kept hanging up while POOH. Stand back DP & set cmt pl.ug @ 11,795' w/150 sx Class G. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H O, 300 sx Permafrost C & 131 bbls Arctic Pack. Drld to 11,816' - pipe 2started packing off. POOH. RIH w_/~ll. POOH Ran Gyro/CCL. _R~H w/ream - h~o]_le_ .~ticking, packing,off & DP ~nging ~p on 9-5/8" shoe~-P-~O'H'J Ran CBL~- ........ ~6{'-Fet @ 11,650 .~ Tstd csg to 2000 psi - ok. S..~goueezed cmt thru ret & oz. top .of ret - < ~tota_l o~f 30(1 ~ C,lass G. Milled-cSg f/lljZ~'Ol - 11'442'' "set"'c'6-~-~ pldg f/ll,~8-Lll,557' w'/156 Sx Class G. 'Tstd csg to 15'00 psi - ok. DD to 11,437' ~ still had high torque. POOH. Set cmt pl.ug w/120 sx Class G. TOP @ 11,139' Tstd csg to 1500 psi - ok. DD to 11,442'. Attempted to sidetrack ~ 11,430" - Drld 4' then drld into old hole. Set cmt plug f/11,200-11,442' w/125 sx Class G. Drld cmt to 11,407'. RIH w/Whipstock assy & drld 6-5/8"' hole fr/11,407-11,432'. POH w/Whipstock assy. RIH w/8½" hole opener to 11,432'. Drld 8½" hole to 12,690' TD. Ran DIL/SP/BHCS/GR: FDC/CNL/GR/CAL - had tool failure. Ran 54 its 7" 29# L-80 lnr fr/11,109-12,685'. Cmtd lnr w/700 sx Class G. Drld cmt to 12,658' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL/CNL/GR. Ran 5½" completion assy w/tail @ 11,064' & pkr @ 10,911'. Tstd tbg hanger & pk-off to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. DiSplaced well to diesel. Dropped ball & set pkr. Tstd tbg to 3500 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi -ok. Began .long term tbg tst. Secured well & released rig @ 1700 hrs, 6/16/81. REC IVED Mr. Bob Hines ARCO Aalska, Inc. P. O. Box 360 Anchorage, Alaska 99510 June 22, 1981 Daer Mr. Hines: Re: Our Boss Gyroscopic Survey Job No. Boss-16831 D.S. 16-13 (SEC24 T10N R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: June 20, 1981 Operator: John Samec Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures COMPLETION REPORT FOR SPERRY"$uN B¥1;~FM LYNDSEY, :RADIUS OF CURVATURE METHOD· ARCO ALASKA INC, WELL. 16'13'~ : PRUDHOE BAY FIELD ...... NORTH SLOPE~"AEASK'A ..................................... ~- ......... i ........... SURVEY' DATE" JUNE 20'1981 GYROSCOPIC SURVEY OPERATOR JOHN SAMEC B055 I683I COMPUTER DATE 2~ JUNE :MEA$ ·::'DR!FT :' VERT !CAL': '--ii EP T H--AN GL-E .............. [JE PTH ......... D M RECORD OF SURVEY i~TR DEG· SEVERITY 5ECTI~ DISTANCE ........... -AN'G ['E ........... DEG/'100FT .......... D I 5TANu,.. D M 5 : 200 o ~+5 ::199.99 :129.~9':::::s:9'~oW:i.::/!:::i':'::l.~e $' ::: 0.0~ E ' 1.z. 8:S:: 2:30 18 E 0.2~7 ;..z~: ............. ~ ............ ._.~: ...... 300 0 36 299.98 229.98 516.00W .......... 2,~3 S 0'19 W .......... 2,64'-~ ....... ~--14-44-W ....... 0,150 ............. -2'39 400 0 ~6 399,97 329,97 512,50W 3,79 S 0'48 W 3,82 5 7 21 3 W 0,1~7 -3,54 500 0 39 ~99*97 429,97 518,90W 4,98 5 0,82 W 5,04 5 9' 13 14 W 0,117 -~,7~ :. 700 0 '33 ;~:: 699,95 S le37 W. 7,26 ::$ :10'::54 ~7 W 0,133 -~,88 800 0:3~: ;::: 799,95 :: ~: S 1,39 W ; :::8,20' G: 9 '47 47 'W 0,128 -7,73 ...... 900 ...... 0--46 ......... 899'e94'-': ..... 829'~9'4"'"':'$~2-~'%'"~'0W-';:~-~:'~':9,18 .... S~:~:~'::'-'::-le71-W'-;': ........ 9e~4'~ S'-iO ..... 34'"'46'W ........... 0,217 1000 0 ~6 999,93 929,93 5 6*80E 10*~9 S 1,91 W 10,66 5 10 21 3'2 W 0,4~2 -10,08 ........ !100 .... 0....29 ......... 1099,93 1029,93 S 5,10W 11,58 S 1,90 W 1~,73 S 9 ~9 ~2 W 0,28~ 1200 0 25 1199,92'~: 1129'~~"~';'~205~ ~ 1'2,96 $':'~'~' 1'90 W ~ ~"~ 12,51 S ~ 8"~g~ "17"W ............ 0,067 1300 0 27 1299'92 S' :. : 1'97 w 13,26 S 8 32 56 W 0e033 1500 0 23 1499e92 1429,92 576,60E 13,55"5 ........... lelO W ' 13,59 .... S ...... ~'-'~0'--26 'W' ' ' 0,150 ~600 0 25 ~599,92 ~529,92 561*~0E 13,80 S 0,~5 W ~3*80 5 1 5~ ~ W 0,033 1700 0 22 1699,91 1629.91 5~9,60E 14,18 5 OelO E 1~,~8 5 0 25 1~ E 0,050 '-':'"~Soo '":"o~~ag: .... ~7~9.~z ":'z~zg';9i~:g~;.SOk'~?:~z~-'~s :s :::~:'~: .~ E ~.~e: S'::Z":~ '"~ 'E : 1900 15'21 S ~'17 E :~15,26 $ ~; 2~ 1~ ~ 0,1t7 2000 ~ ~: s ~'27 E 8 az ~7 a 0.7~ ...... '~100 .... i--i9 ......... 20'99,:'~' ....... :~6~;"~"~ .... ~-~"6;~OE ......... i3"~s S ........ ~,57'E' " ......... 13.~5"-'~"~4'~'~1 2'0"'~ ...... 0.233 2200 1 23 2199,85 2129,85 N55,30E 11,89 5 5,34 E 13,03 S 2~ 11 42 E 0,067 ...... ~300 .. 1 ....... 1 ..... 2299e83 2229,83 N73e20E 10,97 $ 7e2~ E 13,1~ $ 33 26 ~5 E 0,367 2400 0 52 2399,81 2329eS'i:~Y'~86~80E~;?':':: 10,68 S '8~87 E .... 13,89 5 '39 ~3';' 3 i 0,167 :. ;::. :~:.:: : . -11,02 -11,~ -12·. -12·57 -12,35 -12,25 -12.32 -12,47 -12,68 -12,09 -9,99 -7,74 -6,00 -4,95 ARCO WELL 16-13 BOSS 16831 24 JUNE 81 RECORD Of SURVEY ............................... TRUE .......................................................... .: ................ DOG LEG MEAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES ..... C~'~ O"~'U 'R'~-E"-'~ .......... SEVERITY DEPTH ANGLE DEPTH SEA DIRE¢ DISTANCE ANGLE DEG/IOOFT . D .M ....................... PEG, ................................ D ....... -z.600...o:__5.a..:Lh25,g9,80 2529,8'0:':?556".70Eii:i~-i??'i~,40'S.'::~i-:.~':'-:1~.25 E.r ".' 16,02 S 44 !~ ~9 ~ 0.28~ 2700 0 56 2699.78 2629.78 S79.70E ~1.98 S 12.70 .... E .............. 17,46'-~'~4'~-~ ....... 6"'E .......... 0.067 2800 1 3 2799,77 2729,77 N72,40E 11.87 $ 14,43 E 18.68 $ 50 33 39 E 0,134 2900 _4 ..... 15 .... 2899,65 2829,65 N46,20E 9.51 $ 18,39 E 20.71 $ 62 38 52 E 3.203 · , . 3000 7 1~. 29~.~3"-/~92~.i~.-~~.20E721;'i~-iii'2.~0 s i.~"~5.12 E'.~" 25.20 ..... $'~5"i'~' ~'E ........... 2.969 3100 ~0 0 E:~' ' ~4.50. N 71 E ~.~19 3300 15 52 3293,04 3223.04 N ?,50E 53.39 N 42,08 E 67.98 N 38 14 36 E 3.522 3400 19 55 3388,18 3318,18 N 9.90E 83,?? N 46,73 E 95,93 N 29 9 ? E 4,C60 3500 23 ? 3481,19 3411,19 N 9,60E 119,94 N 52.94 E 131,11 N 23 ~9 0 E 3.200 ....... ~'3600'"·2~i~i-'4 ~-'"3572,'lO-i!~·~02'~i~7~iN'iO;-~OE~77160.93 -N'~'~'~: .... 6o.24 E ......... 171.84~N ~20-'31""23 E- ' 2.9~ 3?00 28:'~2 '3660,87 ':.3590'.871~N12'e~'oE?~?~;206,04 N'~;:;!-..'69,34 E 217,40'::-N't.:18 :.36 0 E 2,659 4000 37 45 3911.43 3841,43 N15,10E 365.92 N 4100 40 57 3988.74 3918.74 N15.60E 427,06 N 4200"4~"'"41 ...... 4062'06'-~V~992"O~-~'i6~50E~i~'492.39 N 4300 48 18 ~130,87. 4060'87? Nl'7"BOE~ :i':-561,79 N ...... ~400 ~.l_.~a ........ 4!95.,.22 ........ ~!25~2~..t_.N~Z~.9.O~ ...... 634,74 N 4500 54 8 4255,60 4185.60 N17,gOE 710,59 N 4600 54 31 4313,89 4243.89 N18,40E 787.79 N ..... ~700_.5~.~28 ...... 4371,95 ..... 4301,~5 .Ni~.~OE ............ 865.18 N 4800 54 4 4430,33 4360,33-.. N17',90E 942.47 N 4900 53 36 4489.32 44~9,32~ N17,90E~'-1019,31 N 107,80 E 381,47 N 16 24 54 E 3,216 124,58 E 444.86 N 16 15 47 E 3.224 143,37 E 164,46 E 585,37 N 16 19 2 E 187.60 E 661,88 N 16 27 56 E 212,10 E 741,57 N 16 37 '11E 237,41 E 822,79 N 16 46 15 E 262,70 E 904,19 N 16 53 26 E .. 985e37 N 16 58 10 E 1066.11N 17 2 24 E 512.84 N 16 14 5 E 3,760 3,644 3,271 2,583 0,507 0,401 0.405 0,46? 287.59 E 312,41 E 5100 53 13 4608,92 4538.92 N18.60E 1171,64 N 362,27 E 1226,38 N 17 10 54 E 0.402 5200 53 15 4668.76 4598.76 N18.20E 1247,67 N 387,57 E 1306,48 N 17 15 23 E 0,259 .5300 5~ .... 9 4728.64 4658.6~ ..... ~.!9.,OOE. ......... 13z3..58 N Q.l:~.ll E 1386,5.5 N 17 20 2 E 0.52g SE, CT I ON DISTANC~ -4.49 -3,26 0,72 10,48 25e43 44.~3 95,93 130.49 169,80 213.57 261.99 371,76 433,28 570,, 645,17 723,29 802e99 882,84 962e39 1041,53 1120.19 1198e75 1277.41 1D:5,$e 09 ARCO WELL 16'13 ....................... BO'~'$ 16831 ' ·· 24 JUNE 81 ........................................ = ...... RECORD. OF. SURVEY ..... ; ..... TRUE "' ' :..= ...... : ................. : .... DOG LEG MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY DEPTH ANGLE DEPTH SEA DIRE¢ DISTANCE ANGLE DEG/IOOFT D M DEG. D M $ - . 5'400 51:-1 4790'06 -472'O'"06-;:i::!N~O:'80E'!iii':1397,77 N-i. 439,97. E 1~5,~ N 17 28 20 E ....... 550~_....5~_~__.~..853.736 ........ ~.?~.~.~..~6:'?":;.N2'_i_~._~,~E?'1470'O1 N 467,77 E. 15~2,65 N 17.39 6 E 0,68~ 5600 50 15 4917,20 48~7,20 N22.30E 1541,fl9 N ~96.36 E 5700 50 21 ~981.06 ~911,06 N24,20E ~612.18 N 526,7~ E ........ 5800,..fi9...51 ..... 5045,18 .......... ~975.18 N24,50E 1682.09 N 558.37 E 6000 50 30 5172,86 5102,867~?N25'80E'~;~?~1821,12 N ··624,46 'E 1925.21 N 18'55 37 E 6200 50 ~ 5~00,89 52~0,89 N25,50E 1959,7~'"N ....... 690~67 E ...... 2077'92'-N'-lg~4--~9-E 6~00 50 6 5~65,05 5295,05 N25,60E 2028,98 N 72~,76 E 215~,20 N 19 ~7 6~00 50 19 5429.02 5359.02 N25.50E 2098.32 N 756,90 E 22~0.66 N 19 50 7 E - 6500"~50"-~ ............. 5492.86 ........ 5~22~'8~'~'5-~'80~'=2~67.71 N 790.22 E ....... Za07.25 N'"'20 ........ [ 6600 50 52 5556.32 5486,32:~?'?/-NZ6'OOE:~;~ 2237,22 N 823,98 E 2384,14 N 20 13 8 ..... ~700_.5.1 ..... ~ ..... ~61~,33 ..... 5549.,33 ~-~.NZS,80E 2307,08 N 857,90 E 2461.43 N 20 23 6800 52 lO 5681,~5 5611,~ ...... A~'~;70E~'2377,66'N .......... 891,9~ E ........ 2539.45-N"20-33-'~6"E ............ ~,185 -' 1619,43 N 17 50 55 E 0,614 1696.05 N 18 5 36 E 1,133 1772.35 N 18 21 49 E 0.530 0.932 0.078 0,479 0.068 0.077 0.225 0,231 0.563 0.168 2618.37 N 20 43 21E 0.504 2698.10 N 20 52 23 E 1.049 2778.87 N 21 ....... 0 54 E ...... 0.987 2859.74 N 21 8 52 E 2940.15 N 21 16 16 E 3020,59 N 21 23 17 E 3101.61 N 21 29 25 E 3183,32 N 21 35 8 E 3265,74 N 21 '39"56 E 3349e01N 21 44 10 E 0,841 0.246 0,268 0,891 0,518 1.126 0.964 0,682 0,367 0,244 0,380 6900 52 38 5742.45 5672,45 N26.00E 2448,97 N 926,49 E ........ 7000..53 ..... 39 ....... 5802.41 5732.41 N25.60E 2521,03 N 961.33 E 7100 54 37 5860,97 ..... 5'790'97:;; ...... ~25';90E-W-2594,03 N 996,54 E 7200 53 49 5919.42 5849,42.' N25,50E.i'. 2667.14 N 1031.73 E ......... 7300....53...~40 ...... 5978,54 ..... 59·08,5~.:]i._N2.5~80E .......2739,85 N 1066,64 E 7400 53 51 6037,63 5967.63 N25.50E 2812.57 N-'1101.56 E 7500 54 42 6096.00 6026.00 N25.10E 2885.98 N 1136,26 E 7600...55~12 ~. 6153,41 6083,41 .... N25,30E ..... 2960.07 N 1171,12 E _ 7700 56 2 6209.85 6139,85.':N2~,20~ 3035.03 N 1205,68 E 7800 56 54 6265,07 6195,07'""~N24,80£~:.3110,89 N 1240,25 £ .......... 79.00_.~.7_.3~ .... 631~.1~ ........... 6.2.~,~.7 , ~_.t~.OE':-:.._~187,3O..N ...... 1275.40 E ....... 3433.01 N 21 48 31 E 8000 57 12 6373o0~ 6303~0~ N24.60E 3263.90 N 1310.47 E 3527';'X6'-'N"21 .... ~2"32'-E 8100 56 58 6427.36 6357.36 N24.SOE 3340.27 N 1345.35 E 3601.03 N 21 56 16 E 8200 56..39 _. 6482-08 6412,08 N24,20E 3~16,53 N 1379,86 E 368~,66 N 21 59 33 g .... SECTION DISTANCE 1433.91 1510,~ 1586.~ 1663.32 1739,76 1816.34 1893.34 1970.12 2046.64 2123,18 2199,87 2276.68 2353,82 2431,33 2509.53 2588.63 2668.50 2830,, 2910,85 2991.35 3072,35 3154,01 323~,29 3403,18 3487,14 3570.80 ARCO WELL 16-13 BOSS 16831 24 JUNE 81 RECORD OF SURVEY ~ DOG LEG MEAS, DRIFT VERTICAL SUB DRIFT TOTAL'COORDINATES C L o s u R E S SEVERITY DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/IOOFT D M S .... D. M ....................... DEG.' . 8400 57 53 ........ 6590.10 6520,1~_::]:]L:N.23,00E!:!]:~:~3570.59 N 1447.65 E 3852,89 N 22 4 10 E . 0.859 ....... 8500'59 3 6642,38 ...... 6572,38 N23,IOE 3649,03 N ..... 1481.02 E '" 3938,13 N 22- 5'26 E 8600 59 15 6693.63 6623,63 N22,70E 3728,13 N 1514,44 E 4023.98 N 22 6 28 E 0.357 8700 58 34 6745,25 . 6675,25 ....... N23,10E .......3807,02 N .. 1547.76 E 4109,62. .N 22 .... 7.28 E 0,743 8800 57 15 '"6798,35 6728e35:1'ii N22,EOEi?ii!3885.14 N 1580,60 E 4194.35 N 22 8 17 E 1,383 8900 56 8 6853,24 6783,24;?i:iN22,10Eii:!:i!ii:i~3962,47 N 1612,32 E 4277.94 N 22 8 28 E 1,150 ........... 9000..55 ..... 17 ...... 6909.55 ...... 6839~55_.:!ii!ZiNZl,.~OEi!ij:Z.4039,22 N 1642,94 E ~360.57 N 21 8 1 E 0,973 9100 54 15 6967.22 6897.22 N20.70E 4115'47 N ..... 1672.28 E 4442.2'5-'N22 ..... 6"50'E ............. 1.132 9200 53 39 7026.05 6956.05 N20,iOE 4191.26 N 1700.47 E ~523,08 N 22 4 59 E 0.715 9300 52 20 7086.21 7016.21 NIg,20E 4266.48 N 1727e33 E 4602.88 N 22' 2 27 E 1,432 ....... 940o 50"'52 - 714s.30'"' 'CTO78.30 ]. ]i Ni6'60E'!iT?!43 0.41 175 .36"E 4681.19 N 21t59' " 9500 49 46 7212,14 7142.1411i~!iN19e30Ei! ~413.00 N 1779,00 E '4758.09 N 21'"57 20 E 9600 48 13 7277e73 7207e73'i~N21.TOE 4483.69 N 1805.43 E , 4833.54. ..... N 21 55 58 E ........ 9700'46-42 ........ 7345'32 .......7275;'~2~--'N25;OOE .... 4551.34 N ..... 1834.63'E~' 49O7.20 N 21 57 15 E 2.315 9800 46 11 7414.21 73~4.21 N24,10E 4617,28 N 1864.75 E 4979.61 N 21 59 31 E 0,698 9900.~.45 .... 30 ....... 7~83.86 .... 7413,86.~N2~,50E ..... 4682.67 N ~894.28 E 5051.31N 22 1 29 E 0.729 10000 44 55 7554.30 7484'307:NZ4.40E? 4747.28 N "1923'65 E 5122'22-N 22~"3 30'E 0.569 10100 4~ 31 N 1953,73 E 5192,~9 N 22 6 8 E 0,972 ...... 10200..43 ...... !5 ......... 7697,39 ....... 5261,36_.N._._.22 ....11 .... 18 E 2,627 .. 10300 4~ 1 7769e75 7699,75 N32,SOE 4930,31 N 2023,49 E 5329,39 N 22 18 51 E 10400 45 0 7841,04 7771,04 N33,70E 4988,95 N 2061,94 E 5398,26 N 22 27 19 E 1,082 10500 45...57 ........ 7911,14 7841.,16 .... N34,20E ...... 5048,10 N 2101,76 E 5468,16 N 22 36.15 E 0,985 10600 46 ~7 7980,23 7910,2~. N34,4OE- 5107,83 N 2142,50 E 5538,97 N 22 45 21E 0,675 10700 47 46 8048,16 7978,16']i:ii N34'70E.!ill 5168,27 N 2184,12 E 5610,83 N 22 5~ 32 E 1,162 !.0800.._..~8_~9 ........ 8114e78. BO$~?7.~ii,~3.5.e4QE~ii-___.5229,~2 N 2226,95 E 56B~,76 N 23 ~ 1 E 0,967 10900 49 18 8180,40 8110,40 N36,10E 5290'56 N"2271,04 E ' 5757,40 'N23 .... 13 55 E'' 0,76~ 11000 48 16 8246,27 8176,27 N35,50E 5351,58 N 2315,05 E 5830,86 N 23 23 34 E 1,086 .1..1!Q0..~7....45 8313e15... 82~.3e.!~ .....N3_~.e.90~ ...... 961!,96. N 2398e43 E ~903,~2 N 23 .... 32 '8 E 0,561 · SECTION DISTANCE 3737,69 3821,~ 3906,~ 3991,73 4076.84 4161.01 4243.97 4325.87 4406,71 4~86,58 4565.31 4&42.51 4718.34 4792e91 4866,19 4938.42 5009.89 5080,~ 5150.c 5220.12 5289,07 5359,03 5430,11 5502.14 5575,22 5724,43 5799.19 5873,Q8 ARCO WELL 16-13 'BOSS 16831 · JUNE 81 RECORD OF SURVEY · HE'AS, DR'i'FT'-gERTICAL SUB DRIFT TOTAL COORDINATES C L 0 $ U R E $ SEVERITY DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/iOOFT .... D .M : ......... DEG, : ........ . .......... D.. M s · . · . . '. ...... 11~00~44 1 8521,11 8451,11 ND6,10E 5586,38 N 2486,08 E 6114,60 N 23 59 24 E 1,536 11500 46 50 8591,27 8521,27 NBg,50E 5642,67 N 2529,7~ E 618~,80 N 24 8 52 E 11600 47 48 8659,04 8589,04 N39,60E 5699,37 N 2576,56 E ~254,72 N 24,.19 36 E 0,968 11800 N'~ 2675'06 5 6400'60 N 24~42 1~ 5 1,2~7 · 587Z ~23 _ N... :_2726., 69: E ..... 12000 50 ~3 8916,27 88~6,27 - N~2,80E 5928,93 N 2779,20 E 65~7,99"N"-25 .... 6-5~'E .......... 0,250 12~00 52 15 8978,53 8908,53 N42,.20E 5986,62 N 2832,07 E 6622,71 N 25 19 2 E ~,562 12200 54 ~0 9038,17 8968,17 N40,90E 60~6,69 N 2885,30 E 6699,81 N 25 12400 57 30 9149'60 .9079'60:::<Naa'ZOE?~ 6174.~0 N "299~'40 E 6860,89 'N 25 50 58 E ~,727 . : · : ':::::/.: :: .:: ~ .~:::' ..... .... ..... ' ..... ............. ........................ 12690~"57 30 9305,42 9235,42 N38,20E 6366,61 N 3142,66 'E 7100,00 N 26 16 18 E 0,000 BOTTOM HOLE CLOSURE 7100.O0/FEET<ii:'AT N-1:26-16 18 E SECTION DISTANCE 59~6,11 6017,~"~ 6087,~ 615B,16 6230,53 6~04,27 6~79,42 6529e97 6606,17 6684,62 6765,40 6847,96 7089,6/+ ARCO WELL 16-13 BOSS 16831 ............ INTERPOLATED.TRUE VERTXCAL.]'DEPTHs~,]'COORDINATEs AND CLOSURES FOR GIVEN DEPTHS TRUE {ODE . MEASURED VERTI(:AL TOTAL (:OORDINATE$ ¢ L O S NAME DEPTH DEPTH :: :ii DISTANCE _ JUNE U R E SUB ANGLE SEA D M 5 TOP SADe 11898 8851,56 5871,47 N 2725,20 E 6473,09 N 24 53 52 E 8781e56 PBTD ..... 12658 9288e23 ........... 63~,5,87 N 3125e37 E 7073,76 N 26 13 13 E 9218.23 TD, 12690 ! . ii9305e~2.' 6:366,61N 31~2e66 E 7100.00 N 26 16 18 E 9235,~2 · '~ ';~ ~i ~ ARCO WELL 16-13 Boss MEASURED DEPTH AND OTHER DATA FOR;EVERY'EVEN 100 FEET OF SUB SEA DEPTH. 24 JUNE 81 TRUE M'EASURED .......... VERTICAL S-UB::i' T ¥'NI-D;YgD'?" ' "VERT ICAL ..... DEPTH · DEPTH SEA DIFFERENCE; CORRECTION TOTAL COORDINATES . 170 170. 100 0 0 1.11 S 0,09 E 270 270. 200 0 0 2e32 $ 0.10 W 370 370, 300. 0 0 3.41 $ 0,39 W 470 470e : ::400 0 4,65 S 0.70 W 570 : 570,. ::: ::::::::::::::::::::: · 0 : 5,74 S 1,08 W 670 670. 600 0 0 6,83 $ 1,38 W 770 770. 700 0 0 , 7,80 & 1,36 W 870 870, 800 0 0 8,82 $ .... 1,57 W .................. 970 ..... · ............. 970,'i::'i'!i"90011i .:i"iO 0 ' 10,09 $ 1,93 W 1070 :;. : : .;1070.~ ! :.::1000.";:::::::::.:i0 :: o ii.3: $ i.88 w ....... iiTO ........................... 17o. ..... o :: ..:_:L::. 12.i4 $ i.92 w 1270 1270, 1200 0 0 12,88 $ ......... 1,92 W 1370 1370. 1300 '0' 0 13.50 S 1,79 W 1470 1470, 1400 0 0 13e52 $ le29 W : 167 : 670. :: .0 0 14,06 S 0,05 W :' 1770 1770, ' 1700 :.iii.::': 0 · 0 14.51 $ 0e47 E 1870 1870. 1800 0 0 15.06 $ ....... i'03' E 1970 1970, 1900 0 0 15,37 2070 2070, 2000 0 0 14,01 S 3ell E 2270 : : : 70, :::2200:..":':'i'::::'i::::0 0 : 11,15 S 6,68 E ...................... 2370 2370, 2300::::~. : 0 0 10,71 S 8,39 E .. 2470 2470, 2400 0 0 10,75 S 9,80 E 2570 2570e 2500 0 0 11,19 S 10.88 E ................ 2670 ......................... 2670, 2600 0 0 ,. 11,87 S .... 12e23 E 2770 277©. 2700~:~:::!© :?:: '--":":':' o ii.99 s i3.89 E 2870 ' 2870, 2800' :':;:: 0 : : : O- 10,66 s 16.78 E .............................2971 .......... : .............. 2970e...-_....290.0.. :__: ..... '_..0_..::_::::.~. ........... ' ........... 0 ............................4.76 S 22,85 E 3072 3070, 3000 1 1 6,50 N ......... 30'62 E ...... 3173 3170, 3100 3 2 23,78 N 37.08 E 3276 3270. 3200 & 3 /+7.0/+ N /+1,13 E ................ 3381 3370, ....... 3300""/"::":'-10 "": 4 ..... 77.43 N 45,37 E 3488 3470. 3400 :. 17 7 115,32 N 51.72 E 3598 3570, 3500 27 10 159,97 N 59e63 E ARCO WELL ~6-13 ....... BOSS 1~831 24 JUNE MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, · TRUE MEASURED VERT!CAL SUB MD-TVD VERT!¢AL DEPTH "'~; ...... DEPTH :'-'SEA'i;i"[~"i~FFEREN~'E: i:;":"i"CORRECTION TOTAL 'COORDINATES ..... ' . 3710 3670. 3600 40 13 210,76 N 70;35 3827 3770, 3700 57 17 269,43 N 83,70 3948 38700 3800 78 21 335.75 N 99,65 4075 ':i'' :" 397O, ~" :"3900~::~'.".~'105:~S?.:~.;::' 27" ~ZZ.47' N .... 120.00 4360~' ; : :: ~. ~8 ':::.; 605,28N.:._~=._ Z77,76 4524 42700 4200 254 65 729018 N 217083 ~696 4370, ~300 326 72 862,32 N 4867 ~70e ~400 397 71 5035 ....... :""" ~':~'4570, ~'4500~ ? 4~5:~'.:~;;~':':' :': ':~ 68. 1122,27 N 3~5,79 .; · .. : . · ' ::. .1249020 N 5202 ~670, '::::~600 :;67 .' 5368 ....... : ..... L.~.t~:...~.4770e 47 ~:;~.. 598 : 66 5526 ~870" ........... ~800 ......... -656 ............................... 58 ...................1~88,70 N ......... ~7~, 5682 4970, 4900 712' 56 1599,63 N 520e83 5838 5070, 5000 768 56 1708,63 N 570,30 5995 ........ ¥""'~ .... ' 57' ~"' '~ :-~ 6152 : : 5270e 57 -: 1926,'55 N '' 67~,51 6307: : 5370e 55 2033,85 N 726,03 6~4 ....................... ~ ........ 5~70, ~ ............ 5~00----~99~ .....~ ..................... ' 57 21~2,96 N ....... 777'72 6621 5570, 5500 1051 57 2251,89 N 831,10 678~ 5~70, 5600 llll 60 236~,51 N 88~,68 694 5 ~'~-' :~'T. ~:~ ' 5770 ' ~;'?:T: 5700:' ~:~;~ ~ 75'~?~;~ ~'~r~:: 6~ ~'~'~ ~ 7115 ;'' 70 2605,11 N 7~55 6070, 6000 1385 70 2852e9~"N ..........1120, 7629 6170, 6100 1459 74 2981,71 N llSle 7809 ................................... 6270, 6200 1539 80 3117,78 N 12~3, ~[78 6~700 8~ 3399~89 N ~ ~37Z.89 ..........8362' .:. 6570' 84: 3541,24 N 1434,47 8553 6670, 6600 _ 1883 9~ 3690,97 N 1498,.60 8747 6770, 6700 1977 94 38~3,9~ N 8930 6870, 6800 Z060 83 3~85,53 N %62%,57 9273 ' 7070, 7000 '~:~2203;: .;::::.::'. ' 69: E E E E E E E E E E E E 99 E E E E E E E E E 09 E 70 E 70 E · 38 E .15 E 32 E 60 E E 81 : ...... HEA_SURED DEPTH AND OTHER DATA FORiEVERY'iEVEN 100 FEET OF..$UB ..REA DEPTH. 24 JUNE 81 TRUE MEASURED VERTICAL SUB ' !i:"'--'i~'6'g Y'9 t:>'";; ]' VERT Z CAL "'; ' DEPTH DEPTH SEAl DIFFERENCE;: CORRECTION - TOTAL: COORDINATE$ 9434 7170, 7100 2264 61 4365,z~5 9588 7270, 720.0 2318 5~+ 4~+75,53 9736 ...... : 48 4575,03 9880' 44 -' :: : 4669,77 10022 ::i-:; :: 7570,i'i'"::75 42 · : ' .: 4761.44 10162 7670, 7600 2492 40 48~9,30 10300 7770, 7700 2530 38 ~930,31 10~41 7870. 7800 2571 41 901~e29 11035 .......................... 8270, 8200 2765 51 11184 8370. 8300 2814' 49 11328 8470. 8400 2858 44 11469 .................. 8570. .... 85007.i';2899 ~-~ ......... 41 11616 8670, 8600 2946-''~;:;' ~7 11769 8770, ~ 8700 :2999 '~ ................... 53 11927 ....................8870' ......... 8800 ...... ~057 ...... 58 12086 8970. 8900 3116 59 12256 9070. 9000 3185 69 12438 .......... : ............. 9170, ..... :~91007~--3268 ................. 83 12624 9270, 9200'3354 86 5372,95 5462.28 5545.88 5625,32 5708,59 5796.98 5887,71 5978.86 608~,97 6199e63 6323.27 1761,98 E 1801,61 E 1845,59 E 1888,12 E 1930,02 E ......... 1973',76' E 2023,~9 E 2077,87 g · 2136,09 E 11.2197,46 E 2263.65 E '-2330'01 E 2394.22 E 2456,12 E 2515.47 E" 258~.05 E 2659,06 E ......... 2740,63--'E 2824,16 E 2914,61 E .... 301'1.11 E 3107,71 E ARCO WELL 16-13 : BOSS 16831 · I'NT'E'RPO'L~T'ED'"9'AL'UES' FOR,' EvE'~-~'"i-iJO'O'=~F'EET~' OF` MEASURED DEPTH, 24 JUNE 81 TRUE MEASURED -VER T I CAL ~.i SUB .... DEPTH DEPTH i~ ~SEA' ~' ~ TOTAL COORDINATES 929 1000 2000 3000 ......... ,ooo 5000 6000 7000 8000 9000 10000 11000 12000 999, 1999, 1,929, 15 2999. ......... 2929. .............. 2 3911, ":' 3841,. 365 4549, 5802, .......5732" ................. 2521 6373. 6303, 3264 6909. 6839. 4039 8 2 ~6,. !····81 ?e·.·?!? ·'··?~:5 3 51 89.!6. ............ 8~4.6~,_.!'~.., ........... 5929 ,15 $ 2.26 · 09 S 25,07 .99 N 107,44 ,82 N 336.53 ,54 ' N 623.54 · 19- N 960,94 · 25 N 1309.66 ,34 N 1642,60 .50 N 1923,14 .80 N 2314,72 · 65 N 2778,39 E .... HORIZONTAL VIEW ARCO ALASKA, INC. WELL 16- 15 RADIUS OF CURVATURE GYROSCOPIC SCALE= I" = I000' ,JUNE 25, 1981 TVD = 9505' TMD = 12,690' T. I0 N., R. 15 E., U.M. ~'Oon. ............................................... I~. ...... 13 ....... 2 4 '~eOo f' 548' ALL DEPTHS SHOWN ARE TVD 400' 800- 1200' 1600' SURFACE LOCATION IS 1653' SNL, 548' EWL, SEC. A4 T. I0 N., R. 15 E., U.M. VERTICAL SECTION ARCO ALASKA, INC. WELL 16- 1:3 RADIUS OF CURVATURE GYROSCOPIC SCALE.' I" = I000' dUNE 25~ 1981 20O0 2400 28O0 3200 440( ALL DEPTHS SHOWN ARE TVD 4800~ · 5600 ~ .............................................. 6000~ .-.-, ......................................................................... ....... '. ......................... 6400 ~ 6800~ 7200 ~ 7600 ~ ........... 8000 a~ '.' ........ 8400 · TVD : 9:305' TMD = 17.~690'* 1111 East 80th Anchorage, Alaska 99502 Phone 349-3541 Telex: 25-364 World Leader in Service to the Oil Industry June 7, 1981 Job #5471 North Slope - Enclosed please find our Gyro Survey on Drillsite 12-10 along with our Vertical Section and Horizontal View maps. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely/ Manager RECEIVED JUL 1 ? 1981 OJ! & Gas Cons, Commission Anchorage COMPLETION REPORT ARCO OIL 6, GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 23 JUNE 81 WELL DS 12-10 KB ELEV 71, FT, JOB NO 5471 RECORD OF SURVEY TRUE ~S, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 0 0 0,00 100 0 0 100,00 200 0 0 200,00 300 0 0 300,00 400 0 15 399e99 500 0 0 499,99 600 0 0 599,99 700 0 0 699,99 800 0 15 799,99 900 0 25 899,99 1000 0 0 999.99 -71.00 N O,OOg 29,00 N O,OOE 129,00 N O,OOE 229,00 N O,OOE 328,99 S52,00E 428,99 N O,OOE 528.99 N O.OOE 628e99 N 0.005 728,99 $35,00E 82B,99 N80,OOE 928,99 N O,OOE 1100 0 0 1099,99 1028,99 N O,OOE ~ j..O0 0 0 1199,99 1128.99 N .O,OOE '~'~00 0 0 1299.99 1228e99 N O.OOE 1400 0 15 1399.99 1328e99 S56eOOE 1500 0 0 1499e99 1428e99 N O.OOE 1600 0 0 1599,99 1528.99 N O.OOE 1700 0 0 1699.99 1628.99 N O'OOE 1800 0 0 1799.99 1728.99 N OmOOE 1900 0 0 1899.99 1828e99 N OeOOE 2000 1 30 1999.98 1928.98 N53,BSE 2100 0 45 2099.96 2028,96 $52,00E 2200 0 30 2199.95 2128e95 S6OeOOE 2300 0 0 2299e95 2228e95 N O,OOE 2400 0 0 2399.95 2328,95 N O.OOE TOTAL COORDINATES 0,00 S 0,00 W 0.00 S 0,00 W 0,00 S 0,00 W 0,00 S 0,00 W 0.07 N 0,15 E 0,15 N 0.31 E .. 0.15 N~: 0.31 E 0,15 'N:~ !~-:i0.31 E 0,20~. N'" !.>! 0 · 47. E 0,00 S 0,98 E 0,2~ N 1,19 E 0.24 N 1,19 E 0,24 N 1,19 E 0,24 N 1.19 E 0,33 N 1.35 E 0.41 N 1.51 E 0.41 N 1.51 E 0.41 N 1.51 E. 0.41 N ' leS'l E 0,41 N 1,51 E 1,54 N 2,07 E 1,52 N 3.90 E 0,91 N 4.80 E 1.09 N 5,12 E 1.09 N 5,12 E C L 0 S U R E S DISTANCE ANGLE D M S 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0.17 N 64 0 0 E' 0,35 N 6~ 0 0 E 0,35 N 64 0 0 E 0.35 N 64 0 0 E 0,51N 66 42 31E 0.98 S 89 33 44 E 1.22 N 78 14 52 E "1.22 N 78 14 52 E 1.22 N 78 14 52 E 1,22 N 78 14 52 E 1.39 N 76 12 1 E 1,54 N 74 36 13 E 1.56 N 7~ 36 13 E 1.5~ N 7~ ~6 13 E 1.56 N 74 36 13 E 1,56 N 74 36 13 E 2,58 N 53 23 5 E 4,19 N 68 42 4 E 4,89 N 79 15 0 E 5,23 N ?? 56 53 E 5.23 N 7? 56 53 E DOG LEG SEVERITY DEG/IOOFT 0,000 0,000 0.000 0,000 0.250 0.2.50 0,000 0,000 0.250 0,167 0.~+17 0.000 0,000 0,000 0,250 0.250 0,000 0,000 0.000 0.000 1,500 0,750 0.250 0,500 0.000 SECTION DISTANCE 0.00 0,00 0,00 0.00 0.07 0.14 0.14 0,14 0,22 0.75 0.7~ 0,74 0e74 0,74 0,81 0,87 0.87 0,87 0.87 0.87 0.57 1,98 3,06 3.18 3.18 ARC.O DS 12.-10 GYROSCOPIC SURVEY JOB NO 5471 23 JUNE. 81 RECORD OF SURVEY TRUE MEAS. DRIFT~'.VERTICAL SUB DRIFT - DEPTH ANGLE' DEPTH SEA DIRE¢ D N DEG, '500 0 30 2499,95 2428.95 $45,685 ~00 I 0 2599,94 2528,94 $11,705 2700 0 30 2699.93 2628.93 S50.71E 2800 1 0 2799,92 2728,92 $70.71E 2900 2 45 2899,87 2828,87 S85,75E 3000 3 0 2999.74 2928.74 868,73E 3100 3 15 3099e59 3028,59 S64,81E 3200 2 30 3199,47 3128,47 $65,81E 3300 2 0 3299.39 3228.39 $65.85E 3400 ! 0 3399.35 3328,35 S48,86E 3500 1 15 3499,33 3428,33 855,88E 3600 1 0 3599.31 3528,31 $65,88E 3700 0 45 3699,30 3628,30 $55.75E 3800 1 0 3799,29 3728.29 $60,91E 3900 1 0 3899,28 3828,28 $53,93E 4000 1 0 3999,26 3928.26 525.935 4100' 3 0 4099.19 4028,19 $56.005 ~ ~700 4 45 4198,96 4127,96 $66,00E ~gSO0 6 30 4298,48 4227'48 $63,00E 4400 9 0 4397,55 4326,55 S62.00E 4500 11 15 4495,99 4424.99 S64,00E 4600 13 15 4593,71 4522,71 S65,05E 4700 16 30 4690,35 4619,35 864.00E 4800 19 0 4785,58 4714.58 S63.00E 4900 22 0 4879.23 4808,23 562.00E 5000 26 15 4970,48 4899,48 S59.20E 5100 29 30 5058,86 4987,86 $56,61E 5200 31 0 5145.24 5074,24 S54,03E 5300 31 30 5230.74 5159.74 S54,10E TOTAL COORDINATES 1.22 N 5,43 E 0,09 N 6,05 E 1,00 S 6,72 E 1.63 5 7,85 E 2.,30 S 11,05 E 3.40 S 15.92 E 5.55 S 20,93 E ~. 7.65 S 25.49 E 9;,25 S 29,07 E 10.66 5 31.26 E 11,86~S ~32,82. E ~. 12,81S::i~~ ~:34.53:E 13'56~'S:~? ~35.86 E 15.30 S 38.63 E 16.62 S 39,74 E 19,23 S 42,00 E 22.50 S 47,91 E 26-72 S 56,75 E 32.95 S 68.71E 40.93 S 84.37 E 50.05 S 103.53 E 61,09 S 126,70 E 74,69 S '153.98 E 90.86 $ 185.04 E 110.92 S 220.64 E 135,75 S 260,24 E 164.41 S 301.66 E 194,85 S 3~3,67 E CLOSURES DISTANCE ANGLE O M' $ 5.57 N 77 17 16 E 6,05 N 89 6 2 E 6.79 S 81 30 48 E 8.02 S 78 12 40 E 11,28 S 78 13 3,E 16.28 $ 77 55 5 E 21,65 S 75 7 50 E 26.61 S 73 17 23 E 30,51 S 72 19 59 E 33.03 S 71 9 51 E 34,90 S 70 7 36 36.83 $ 69 38 13 E 38,34 S 69 17 15 E 39,84 S 68 52 13 E 41.55 S 68 23 35 E 43.08 S 67 17 53 E ~6.20 S 65 24 0 E 52.93 S 64 50 22 E 62.73 $ 64 47 11 E 76,20 S 64 22 55 £ 93.78 S 64 7 23 E 114,99 S 64 11 50 E 140,66 S 64 15 25 E 171.14 S 64 7 19 E 206.15 S 63 50 48 E 246,95 S'63 18 35 E 293,52 S 62 27 3 E 343,56 S 61 24 31 E 395,07 $ 60 26 5Q E DOG LEG SEVERITY DEG/iOOFT 0.500 0,500 0,500 0,500 1.750 0,254 0,250 0.750 0.500 1.000 0.250 0.250 0.250 0.250 0.122 0.484 2,002 1.751 1,750 2,500 2.251 2.001 3,251 2.502 3.003 4,285 1,649 0,500 SECTION DISTANCE 3,33 5,76 7,04 9,90 14,32 19.53 24.35 28,12 30.71 32,67 34,59 36.08 37,59 39.32 41,02 44,43 51,05 60,52 73.66 90,79 111,24 136,04 165.62 199,74 239.84 286.08 336,20 387,91 ARCD DS 12=10 GYROSCOPIC SURVEY JOB NO 5471 JUNE 81 RECORD OF SURVEY · TRUE MEAS, DRIFT".VERTICAL SUB DRIFT DEPTH ANGLE' DEPTH SEA DIREC D M DEG, TOTAL COORDINATES C L 0 S U R E S DISTANCE ANGLE D M S ~'~'400 31 30 5316,00 5245,00 $52,43E 226,10 S 385.54 E ~500 31 30 5401,26 5330,26 S52,66E 257'88 S 427.02 E 5600 31 15 5486,64 5415.64 S52.68E 289,44 S 468.42 E 5700 31 30 5572.02 5501,02 $51,88E 321,29 S 509.61 E 5800 31 15 5657.40 5586,40 552,605 353,17 S- 550.77 E 5900 31 0 5743,00 5672,00 550.20E 385,42 S 591.16 E 6000 31 15 5828.60 5757.60 S51,13E 6100 32 30 5913.52 5842,52 S51,25E 6200 34 30 5996.91 5925,91 S51,43E 6300 36 15 6078.44 6007.44 S49.93E 6400 38 0 6158.17 6087,17 $47,71E 6500 38 30 6236,70 6165,70 S49,36E 6600 38 30 6314,96 6243.96 S48,56E 6700 39 0 6392.95 6321,95 $48.63E 6800 39 45 6470.25 6399,25 S49,51E 6900 40 0 6547.00 6476.00 $47.98E ~,.~.000 40 30 6623,32 6552,32 $48,035 100 40 15 6699,50 6628,50 849,215 7200 40 0 6775,97 6704,97 $49,51E 7300 40 0 6852,57 6781,57 SSleO6E 7400 40 15 6929.03 6858,03 548,76E 418,18 S 631,14 E. 451,28 S 672,29 E 485,75 S 715,39 E 522.43 S 760,18 E 562,16 S.::: 805,60 .~ ' 446.95 S 59 36 36 E 498,85 S 58 52 20 E 550,64 $ 58 17 15 E 602,44 S 57 46 10 E 654,28 S 57 19 49 E 705,71S 56 53 48 E 757,12 S 56 28 20 E 809.71 S 56 7 42 E 864,72 $ 55 49 23 E 922,39 $ 55 30 .4 E 982,36 S 55 5 30 E 603,i5~Si;.:i~ 852'00:E 1043,88 S 54 42 15 E s zz E 685,41~.S~ 945',91!'E~iii- 1168,13 $ 54 4 21E 726,97 S 993,84 E 1231,34 S 53 48 55 E 769,24 S 1042.04 E 1292,21S 53 33 54 E 812,46 S 1090.06 E 1359,54 S 53 18 4 E 855,28 S 1138,67 E 1424,11 S 53 5 20 E 897,25 $ 1187,58 E 1488,42 S 52 55 40 E 938.31 S 1237,03 E 1552,63 S 52 49 7 5 979,81 S 1286,33 E 1617,00 S 52 42 11 E 7500 40 30 7005'22 6934,22 548,01E 1022,82 S 1334,77 E 7600 40 0 7081,54 7010,54 S47,93E 1066,08 $ 1382,76 E · 7700 40 0 7158,14 7087,14 S47,18E 1109,46 S 1430,20 E 7800 40 0 7234,75 7163~75 S45,70E 1153,75 $ 1476.78 E '7900 40 0 7311.35 7240,35 $48'13E 1197,65 S 1523,72 E 8000 39 30 7388,24 7317.24 S47,35E 1240.65 S 1571,05 E 8100 39 15 7465.54 7394,54 846.60E 1283.94 S 1617e42 E 8200 39 30 7542.84 7471.84 $47.505 1327.16 S 1663.86 E 1681,60 S 52 32 13 E 1746,01S 52 22 6 E 1810,07 S 52 11 52 E 1874e04 & 52 0 3 E 1938.07 S 51 49 56 E 2001.85 S 51 42 6 E 2065,08 S 51 33 24 E 2128,33 S 51 25 21 E DOG LEG SEVERITY DEG/iOOFT 0,871 0,122 0,250 0,332 0,316 0,684 0,354 1,250 2,001 1,827 le941 0,812 0,498 0,501 0.832 0.681 0.500 0,554 0,279 0,99~ 0,992 0,403 0.501 0.482 0,953 1,564 0.592 0,391 0.442 SECTION DISTANCE 492,22 544,21 596,21 648,22 699.88 751,56 804,~4 859,50 917,38 977,72 1039.62 1101,87 1164,45 1227,89 1291,99 1356.58 1421,35 1485,80 1550,07 1614,51 1679,28 1743,86 1808,10 1872.29 1936,50 2000.41 2063e78 2127.16 ARCO DS 12-10 GYROSCOPIC SURVEY JOB NO 5471 23 JUNE 81 RECORD OF SURVEY . TRUE MEA5, DR I FT.--YERT ICAL DEPTH ANGLE DEPTH D N SUB DRIFT SEA DIREC DEG, TOTAL COORDINATE5 C L 0 5 U R E 5 DISTANCE. ANGLE D M 5 DOG LEG SEVERITY DEG/iOOFT ~00 39 0 7620.28 7549,28 548.30E 1369,58 S 1710,80 E 2191.48 S 51 19 15 E _*00 38 45 7698.13 7627.13 $47,55E 1411.64 S 1757.39 E 2254.14 S 51 13 35 E 8500 38 0 7776e53 7705,53 548,68E 1453,08 S 1803.61 E 2316.13 S 51 8 35 E 8600 36 30 7856.12 7785.12 S48.56E 1493,09 S 1849.03 E 2376e60 $ 51 4 44 ~ 8700 35 0 7937.28 7866.28 547.60E 1532.12 S 1892.50 E 2434.94 S 51 0 26 E 8800 34 30 8019,44 7948,44 $46,78E 1570,85 $ 1934,32 E' 2491.82 S 50 55 12 E 8900 32 45 8102.71 8031.71 548.31E 1608.23 S 1975.17 E . 2547.10 $ 50 50 48 E 9000 32 0 8187.16 8116,16 SEO.O1E 1643.24 S 2015.68 E 2600,62 $ 50 48 44 E 9100 31 0 827~.43 8201,43 $49.13E 1677.12 $ 2055,46 E 2652.86 S 50 47 16 E 9200 29 45 8358,70 8287,70 549.865 1709,95 S 2093,91 E 2703,41 $ 50 45 49 E 9300 27 0 8446,67 8375,67 549,35E 1740,75 $:i~.2130,10 E 2750.92 $ 50 44 37 E 9400 24 0 8536,92 8465,92 S44,53E 1770'13 i~S:ii~12161.54 E 2793,86 $ 50 41 7 E 9500 22 30 8628,80 8557.80 $48,00E 1797e41:::~$?~:2190'O6:E 2833,21 $ 50 37 25 E 9500 22 30 8721,19 8650,19 542,15E 1824,43 S~ 2217,15 E '- 2871,28 $ 50 33 0 E 9700 22 30 8813.58 8742,58 S42,05E 1852,82 S 2242.80 E 2909.14 S 50 26 21 E 9800 22 0 8906.13 8835.13 S42.35E 1880,87 S 2268,24 E 2946.62 S 50 20 i E .~900 22 0 8998.85 8927,85 $39,43E 1909.18 S 2292,76 E 29~3.58 $ 50 12 56 E 300 21 30 9091,73 9020,73 S40,21E 1937.64 S 2316,49 E 3020,03 S 50 5 20 E 10100 21 0 9184,93 9113,93 S39.00E 1965,57 S 2339,59 E 3055,68 S 49 57 55 E 10200 21 0 9278,29 9207,29 539.00E 1993,42 5 2362,15 E 3090.87 S 49 50 20 E 10300 20 0 9371.95 9300,95 $39.00E 2020,63 S 2384,19 E 3125,27 $ 49 43 5 E 10400 19 30 9466,07 9395,07 S41.OOE 2046,52 $ 2405e91 E 3158.58 5 49 36 53 E 10500 19 30 9560.33 9489,33 541.00E 2071,71 S 2427,81 E 3191.59 $ 49 31 29 E [o~o~ ~q %o Sql,DOE BOTTOM HOLE CLOSURE 3191,59 FEET AT S 49 31 29 E 0,592 0.386 0.864 1.501 1,533 0.564 ~.807 0.889 1.027 1,263 2,752 3.10~ 1,58~ 2,238 0,038 0,502 1e093 OeEll 0,524 0.000 1,000 0.547 0.000 SECTION DISTANCE 2190,41 2253,14 2315,21 2375,73 2434,13 2491,08 25~6.42 2599e96 2652.21 2702.78 2750.29 2793.28 2832e69 2870,82 2908,77 2946,33 2983,36 3019.89 3055,59 3090.82 3125,25 3158,5~ 3191.59 ARCO DS 12-10 GYROSCOPIC SURVEY JOB NO 5/+71 INTERPOLATED TRUE VERTICAL DEPTHSm COORDINATES AND CLOSURES FOR GIVEN DEPTHS 23 JUNE $1 TRUE CODE MEASURED VERTICAL NAi'4E DEPTH DEPTH TOP SAD 980/+ 8909,84 OIL/WATER 9996 9088,01 PBTD 10475 9536.77 ~- 10505 9565,05 TOTAL COORDINATES 1881,98 S 1936.65 S 2065,41 S 2072,95 S 2269,24 E 2315,38 E 2422,33 E 2428,91 E C L 0 S U R E DISTANCE ANGLE D M SUB ,SEA 2948.10 S 50 19 46 E 3018,55 S 50 5 23 E 9017,01 3183,33 S 49 32 50 E 9465,77 3193.23 S 49 31 15 E 9494,05 ARCO DS 12-10 GYRosCOPIC SURVEY JOB NO 5471 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 JUNE 81 HEASURED DEPTH 171 271 371 471 571 671 771 871 971 1071 1171 1271 1371 1471 1571 1671 1771 1871 1971 2071 2171 2271 2371 2471 2571 2671 2771 2871 2971 3071 3171 3272 3372 3472 3572 TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE 171. 100 0 271. 200 0 371, 300 0 471. 400 0 571. 500 0 671. 600 0 771. 700 0 871. 800 0 971. 900 0 1071. 1000 0 1171. 1100 0 1271. 1200 0 1371e 1300 0 1471. 1400 0 1571. 1500 0 1671. 1600 0 1771, 1700 0 1871, 1800 0 1971. 1900 O' 2071. 2000 0 2171. 2100 0 2271. 2200 0 2371, 2300 0 2471. 2400 0 2571. 2500 0 2671. 2600 0 2771. 2700 0 2871. 2800 0 2971. 2900 0 3071e 3000 0 3171. 3100 0 3271. 3200 1 3371, 3300 1 3471, 3400 0 3571. 3500 1 VERTICAL CORRECTION 0 0 0 0 0 0 0 0 0 0 0 0 0 7. ~..~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 -1 1 TOTAL COORDINATES 0.00 S 0.00 $ 0.06 N 0.10 N O. 15 N 0.15 N 0.21 N 0,00 N 0.19 N 0.24 N 0.24 N 0.24 N 0.32 N 0.36 N 0.41 N 0.41 N Oe41 N 0.41 N 1.02 N 1.~0 N 1.05 N 0.99 N 1,09 N 1.22 N 0.52 N 0,82 S 1,45 S 2.14 S 2.97 4.92 S 7.15 $ 8,87 S 10,31 $ 11,53 S 12.62 S 0.00 W 0.00 W 0,07 E 0.33 E 0.31 E 0.31 E 0.39 E 0.78 E 1,23 E 1,19 E 1.19 E 1.19 E 1.26 E 1.53 E 1.51 E 1.51 E leS1 E 1,51 E 1.72 E 3.52 E 4,57 E 5.16 E 5,12 E 5.26 E 5.89 E 6.48 E 7,42 E 9e79 E 14e49 E 19e43 E 24,25 E 28.11 E 30,82 E 32.32 E 34e06 E ARCO DS 12-10 GYRO$COPXC SURVEY JOB NO 5471 NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, JUNE. -& MEASURED DEPTH 3672 3772 3872 3972 4O72 4172 4272 4373 4475 4577 4680 4785 4891 5ool 5114 5230 5~47 5464 5582 5699 5816 5933 6O50 6169 6291 6416 6544 6672 6801 6931 7062 7193 7324 7455 7586 TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE 3671, 3600 1 3771. 3700 0 3871. 3800 1 3971. 3900 1 4071, 4000 0 4171e 4100 0 4271. 4200 1 4371. 4300 2 4471. 4400 3 4571. 4500 '5 4671. 4600 8 4771, 4700 13 4871. 4800 20 4971, 4900 29 5071. 5000 42 5171. 5100 59 5271, 5200 76 5371. 5300 93 5471, 5400 111 5571, 5500 127 5671, 5600 145 5771, 5700 161 5871, 5800 178 5971, 5900 197 6071, 6000 219 6171, 6100 245 6271, 6200 273 6371. 6300 300 6471. 6400 329 6571, 6500 360 6671, 6600 391 6771, 6700 422 6871. 6800 453 6971, 6900 484 7071. 7000 515 VERTICAL CORRECTION TOTAL COORDINATES 0 13.36 -1 14.13 1 15.03 0 16.21 -1 18 · 35 0 21.53 1 25.36 1 31.05 1 38.78 2 47,83 3 58,66 5 72.45 7 89.29 173,51 S ":17 17 18 16 18 16 17 19 22 26 28 27 29 31 31 31 31 31 ...... 209.45 246,69 284.08 321,46 358,27 396.21 434.57 474,94 519,40 568,87 621.12 674, 03 727.37 782,81 839e 20 894.61 948,10 1003,62 1060,34 35.53 E 36.74 E 38,22 E 39,48 E 41,00 E 45.93 E 54.02 E 65,12 g 80.04 E 98,77 E 121e65 E 149,55 E 182,08 E 220.~6 E 265e96 E 314.19 E 363e42 ~ 411.89 E 460.56 E 508.68 E 557.25 E 604.10 E 651.38 E 701.51 E 755.62 ~ 812.83 ~ 872,52 E 932.29 E 994.30 E 1056.67 E 1120,08 E 1183.91 E 1248.96 E 1312.78 E 1375,81 E ARCO DS · MEASURED 12-10 DEPTH AND OTHER GYROSCOPIC SURVEY JOB NO 5471 DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 JUNE. 81 MEASURED DEPTH ,.- · 7717 7847 7977 8107 8236 8365 8493 8619 8741 8862 8981 9098 9214 9327 9437 9546 9654 9762 9870 9978 10085 10192 10299 10405 TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE 7171. 7100 546 7271. 7200 576 7371. 7300 606 7471. 7400 636 7571, 7500 665 7671. 7600 694 7771. 7700 722 7871, 7800 747 7971, 7900 770 8071. 8000 791 8171. 8100 810 8271, 8200 827 8371, 8300 843 8471. 8400 856 8571. 8500 866 8671, 8600 875 8771, 8700 883 8871. 8800 891 8971. 8900 899 9071. 9000 907 9171. 9100 '914 9271, 9200 921 9371. 9300 928 9471, 9400 934 VERTICAL CORRECTION TOTAL 31 3O 3O 3O 29 29 28 25 23 21 19 17 16 13 10 9 8 8 8 8 7 7 7 6 1116 llTZ+ 1230 1287 1342 1397 1450 1500 1548 1594 1636 1676 1714 1748 1780 1809 . ~ :: - 1839 1870 1900 1931 1961 1991 2020 2047 COORDINATES .83 S .84 S · 88 S · 01 S .70 S ,08 S · 68 S .24 S .18 S .69 S · 82 S e49 ,53 S .84 S · 70 S ,41 S · 76 S ,34 S · 66 S · 49 S ,43 $ .19 S .36 S .78 S 1438.06 E 1498.40 E 1560.13 E 1620.61 E 1580.62 E 1740.99 E 1799,94 E 1856.95 E 1909.60 E 1959.55 E 2007.84 E 2054e63 E 2099.17 E 2139.19 E 2172,02 E 2202.77 E 2230.95 E 2258.57 E 2285e41 E 2311,07 E 2336.15 E 2360,34 E 2383.97 E 2407,00 E ARCO DS 12-10 GYROSCOPIC SURVEY JOB NO 5471 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1001011'. 999. 928. o..z~+ N 1.19 E 2000 1999, 1928. 1,5/+ N 2.07 E 3000 2999. 2928. 3,47 S 15,91 E 4000 3999, 3928, 16.64 S 39,72 E 5000 /+970. 4899, 110.98 S 220.60 E 6000 5828. 5757. ~+18.30 S 631.05 E 7000 6623. 6552. 812.89 S 1089,68 E 8000 7388. 7317, 12~+0,85 S 1570.8(~ E 9000 8187, 8116. 1643.35 S 2015.58 E 10000 9091. 9020, 1937,78 $ 2316,33 E : 23 JUNE. HORIZONTAL VIEW ARCO OIL a GAS WELL DS 12 -IO GYROSCOPIC SURVEY RADIUS OF CURVATURE SCALE I "= I000' JUNE 24~ 1981 ALLARE DEPTHSTvD SHOWN TVD = '9560 ' TMD = 10500 ' 8O0 1200 SURFACE LOCATION IS SEC. 18, 768' NSL, 733' WEL,TION, R 15E , U.M. VERTICAL PROJECTION ARCO OIL ~ GAS WELL DS 12-10 GYROSCOPIC SURVEY RABIUS OF CURVATURE SCALE I" = I000' " JUNE ?.4t 1981 1600 2400 2800 3200 I[4~00 ...... I ALL DEPTHS SHOWN ! ................. ~6400 ............. 800 Eastman / , Whipstock i)) A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC, COMPANY DS 16-13 WELL NAME PRUDHOE DAY, NQRTH SLOPE.. ALASKA LOCATION JOB NUMBER A481D0291 TYPE OF SURVEY Directional Single ShOt · DATE 6/17/81 De SURVEY BY Prescott/L. Hensley OFFICE Alaska Eastman Whipstock A PETROLANE COMPANY P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066/Cable: EASTCO June 17, 1981 Arco Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: DS 16-13 .~ Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 6/17/81 Method of Computation:. Radius of Curvature Driller: D. Prescott/L. Hensley Job Number: A481D0291 Attn: Bob .Hines Dear Mr. Hines: I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, Leroy Keys District Directional Drilling SUpervisor Alaska District LK/kp enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA, INC. DS 16, WELL. NO: 1;5 r;SS/SIZ}ETRACK PRUOl..IOE E~AY, NORTH SLOPE, ALASKA DSS, 0-12e.'_,30 Mr;, DRILLER: PRESCOTT/HENSLEY RIG: ROWAN 26 I)ECt..IN; 30 1/2 DEG EAST FILM CORRECTED PER F'RESCOTT SIDETRACK TIE IN AT 11396 MD SUPF'ORT FOR SETTING WHIPSTOCK: C KING/L KEYS dOB NO; A481D0291 VERTICAL SECTION CALCULATED IN PLANE OF PROPOSAL ... OlRECTION; N ~90EG.-.--~"* ..-. . ~4IN. E RECOREI OF' SURVEY RAr~IUS OF' CUR. VATURE f4ETHOD ARCO ALASKA, INC, DS 16, WELL NO; 13 DSS/SIDETRACK PRUDHOE BAY, NORTH SLOPE, ALASKA JOB NO; A481D0291- COMPUTATION TIME DATE 09;05;27 17-JUN--81 PAGE NO., i TRUE - - MEASURED [;RIFT DRIFI' COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E I)OGLE~ BEF:'TH ANGLE DIRECI'ION LENGTH DEPI'H SECTION TVD C 0 0 R D I N A T E S DISTANCE DIREC'¥ION SEVERI' F' E E T D M D M F E E 1' F E E 1' F' E E T F E E: T F E E T F E E T D M D G / 100 i Oo 0 0 0 0 O, 0o00 0,00 -70,00 0,00 0o00 0,00 0 0 0,00 476, 0 S0 S 6 0 W 476, 475,99 -1,91 405~99 2,07 S 0,22 W 2,08 S 6 0 W 0,11 957, 0 45 S 57 0 -E 481, 956,97 --4,77 886,97 6,56 S 1,93 E 6,84 S 16 22 E 0,14 1560, 0 15 N 14 0 E 60S, 1559,94 -1,28 1489,94 4,91 S 6,12 E 7,85 S 51 15 E 0,14 2677, 1 0 S 42 SO E 1117, 2676,87 5,59 2606,87 2,46 S 15,77 E 15,96 S 81 8 E 0,10 2877, 2 45 N 40 S0 E 2960, 5 15 N 40 ~0 E sr,.~, 7 0 N ~ 0 E S085, 8 45 N 26 S0 E S204, 11 45 N 1S S0 E 3S27, 17 0 N 9 S0 E S452, 21 0 N 12 0 E 358S, 25 0 N 11 0 E ~7S8, 29 15 N 14 ~0 E S~8So S6 45 N 15 S0 E 200, 2876,75 8S, 2959,54 62, S021,19 6S, S08S~59 119, S200,68 8,51 2806,75 14,~0 2889, 20,7S 2951,19 29,S5 ~01S,59 50,19 SIS0,68 2,S6 S 21,56 E 2,04 N 25,S2 E 7,2S N 29,41E 14,61N SS,89 E S4,46 N 41,11E 12S0 SS19,78 · 79,24 S249078 64,~7 N 47,20 E 125,' S4S7,95~ 117,80 SS67,95 1040S4 N 54,79 E 1S1, ~ S558~,51'" 166,50 S488,51 154,48 N '~ 64,99 E 155, S696,4S 2S4,20 S626,4S ~S,S8 N ~ 80,58 E 245,'-~S901076..~ S6S,S7 S8S1~76 -~ S52018~N ..115009 E 21,69 S 8S 45 E ~52 25,40 N 85 2S E .01 S0,29 N 76 11E 2,92 S6,90 N 66 41 E S,45 5S,64 N 50 2 E S,17 79,82 N S6 15 E 117,85 N 27 42 E 167,60 N 22 49 E 2S7,47 N 19 50 E S70051 N 18 6 E S,26 S,07 2,9S S,07 42S20 45 0 N 17 S0 E 4445, 52 45 N 20 0 E 49S5, 54 45 N 20 0 E 5179, 5S 45 N 19 0 E 5486, 51 15 N 20 0 E 5765, 50 45 N 24 ~0 E 6104, 51 0 N '~=' ~ SO E 6528~ 51 15 N 25 SO E 69~'1~, ~ 5S 45 N 25 0 E 7075~ 54 4~., N ~..~5 0 E 249, 4089,88 522,08 4019,88 508,28 N 21S, 4229,86 679,65 4159,86 660,08 N 490, 4519,59 1069,51 4449,59 10S1,S9 N 244, 4662,14 1264,60 4592,14 1218,05 N S07, .... 4849,02' 1504,54 4779,02 1447,62 N 161,SS E 5S~,26 N 17 S7 E 212,86 E 69S,55 N 17 52 E S48000 E 1088,52 N 18 S9 E 414,10 E 1286,52 N 18 47 E 495,.40 E 15S0,04 N 18 54 E 279, 5024,60 1719,6S 4954,60 1648,24 N 577,47 E 1746,48 N 19 19 E SS9, 52~8,51' 1981,86 . 5168,51 1886,59 N 688,62 E 2008,S4 N 20 S E 424, 5504,6S 2Sl1,19 54S4,6S 2184,51N 8S0,72 E 2SS7,1S N 20 49 E 42S, 5762,12 2645,88 5692,12 2488,01N 97S,86 E 2671,82 N 21 2S E 124, 58S4,56 "2746,22 5764,56 2579,22 N 1016,S9 E 2772,26 N 21S0 E S,74 0,41 0,85 ~027 0,24 0,06 0,60 0,81 7290, 54 15 N 25 0 E 7556, 55 15 N 24 0 E 7860, 58 0 N 24 0 E 80S5, 57 15 N 2S 0 E 8208, 57 S0 N 2S 0 E 215, 5959,41 2920,74 5889,41 27S7,85 N 1090,S6 E 2946,98 N 21 4S E 266, -6112,9S SiS7,19 ~-604209S ~29S5,52 N· 1180,44 E S16S,97 N 21 54 E S04, 6280,15 SS89,91 6210,15 S167,41N 1~oS,69 E 3417,65 N 22 4 E 175, 6S7S,86 S5S6,94 6SOS,86 SS02o95 N 1S42,62 E S565,41 N 22 7 E 173, 6467,1S S681,75 6397,13 S437,08 N 1399,56 E 3711,10 N 22 ~ E 0.49 0,90 0,65 :il:;,:CO AI...ASKA, INC. :iS 16, WELL NO,; 13 DSS/SIDETRACK :'RLJDI-.IOE BAY, NORTH SLOPE, AL. ASKA BO..-¥ 1- JOB NO; A481 '~" COMPUTATION TIME DATE 09~05~27 17-JUN-81 PAGE TRUE' 'iEASURE:[~ DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U t.. A R C L 0 S U R E 'OOGLEG Bf'.".PI'H ANGLE DIRECTION LENGTH BEF'TH SECTION TVD C 0 0 R D I N A l' E S DISTANCE DIRECTION SEVERIT' FEET D M D M FEET FEET F'E:EI' FEET FEET FEET D M [ G/1OOF' 8587, 57 45 N 2S 0 E 8643, 60 0 N 22 JO E . =;' 21 8911 ..7 SO N 0 E 9308, 53 45 N 18 30 E · 9582. 50 0 N 18 0 E ].79, 6562.97 3852,00 6492,97 3576,24 N 1458,63 E 3862,26 N 22 11 E 256, 6695,29 ' 4049.67 6625,29 3778,32 N 1543,37 E 4081,39 N 22 13 E 268, 6834.31 4276,74 6764,31 3991,11 N 1628,26 E 4310,47 N 22 12 E S97, 7058,42 4599,72 6988,42 4299,42 N 1738.95 E 4637,78 N 22 i E ~')' 4811 18 7157,55 4504,09 N 1806,44 E 4852,84 N 21 51 E 274, 7~7,='~ 0,14- 0,89 1,05 1,08 9693, 47 15'N 25 0 E 9999, 45 45 N 23 30 E 10153. 43 SO N 28 30 E 10297. 44 45 N S2 0 E 10482, 46 45 N 32 0 E 111, 7300,92 4893,63 7230,92 4581,53 N 1836,95 E 4936,07 N 21 51 E 306, 7511,55 5114.70 7441.55 4783,90 N 1928,11 E 5157,83 N 21 57 E 154. 7621,15 5222.65 7551,15 4881.09 N 1975,51 E 5265,71 N 22 2 E 144, 7724.51 5322.88 7654,51 4967.68 N 2026.01 E 5364,94 N 22 11 E 185, 7853,59 5455.25 7783,59 5080,05 N 2096,23 E 5495,56 N 22 25 E ~4 ¢ 2,71 1,90 1,08 10787. 49 0 N 33 30 E 11046. 49 0 N 35 0 E 11396. 46 45 N 35 0 E ~ ~ ~, 60 E 5718.23 N~°° 50 E ,0~. 80~8.16~ 5681.05 7988.16 5270.29 N o-~ ~59, 8°~8,08 5875,80 8158,08 5431,86 N 2328,60 E 5909,95 N 23 12 E S50, 8462.83 6134012 8392,83 5644,49 N 2477,49 E 6164,27 N 23 42 E 0,82 0.4'; 0.64 1.1396 MD IS TIE IN POINT FROM OLD HOLE FOR SIDETRACK.:!'~ ;,-:' :. .'..:;: ;; · :, ,, ,, 4.,¢ 70 8647,26 E 6446,~° N 24 16 E 11781. 50. 30 N 38 0 E ~.8u, 8717,~o 6 ~0 5876,66 N 2649,28 12630. 62 SO N 37 0 E 849, 9185,00 7120,26 9115.00 6437,29 N 3079,47 E 7135,95 N 25 34 E 1,14 1,42 FINAL CLOSURE - DIRECTION; DISTANCE~ N 25 DE:GS 33 MINS 56 SECS E 7135,95 F'EEET p ]SS/SIDETRRCK ............... : ' ' LL'SCRLE 1 iN. : 2000 FEET OPE RLRSKR ............ . ~- ......· ......., ...... ; ......... ; .............. ~ .... ........ :- ................................................................ ; ........................ : .......... ~ ............ ..... ~ ........... ; ................... ~ .......... t. ................... ,L~. .............................. · .... ~,.~ .......... .......... i ...................... L ....... L-: -.-: .....~ i ' ' : ',._.~,_;_L_:.' ". ....... ,.- ..................... ...... ~ .................... : ....... ~ ..............; ............... ~ .............. : .......... ~ .............. ........ : .......................................... , .................. .: .............................. ~ ....... ..... -~ 4'- ........... ~ ........... ~ ......................................................... :-* ~' ........ , - ~ .-- .......... ~ ................. ....... i ........ ~ ..... ~, .............. ~ ........... ~. ............................................ ."- .......... · ..... ..+. .... ,,...,,,....__:, ..................... ,, .......... ,k. .............. ! .......... ~ .................. '"' '~" ~""~ .... ~ ................ ......... $ ............................ ~, ................... ~ ......... ." ................... '~ ......... '--t.,-~'"-~.-~"t- ............... .......... ............. ~ ......................................... ~ ................................ ~ ........................ r ........... ~ ...... Il, ._ ...... RRCO RLRSKR, --iNC.' .... :- ............... :'T T' " ';'"T;' -.-:-.:: .... :'--'--:::: ......... HORIZONTRL"'PROJECTI ....... D5 lB. ~[LL Rtl: 13 B55/5ID[TRflEK ......... -- ...... PRUDHOE BRY. NORTH SLOPE, .... RLRSKR ........... .................. _"' . - ERSTHRN NH]PSTOCK, ]NC ................... - ..... .................................. .................................... ; . .............................................. ; ...................................... .................. . ........ ~ ............................................ .................................................... .................. ,.. .............. .............. ; ............................... . .................... -, .................... 8058 ...... ......... ~ ...... . ..................................................................... .................. , ................................... . . . ............ , ......... ; ............... ~ ............ ~ ...... ................. : ....................... 7300 .............................................. .................................. ; .................. : ............. . ............ ~ ......................... ............................ ' ............... ............................................ .............. , .... . .................................................. ; ..... 5959 .......... ................................................................ 40~ .... ......................... ~ ........... ; .......... ~ ............... ~.. ~ .... ,, ......... ~ .................... ~ ............ ~ ................ ~ .... -' ,- , ......................... DEPTH .1~630 HD, .9t84,99 TVD ........................... ; ................................. ;._7;;."__NORTH 6437,29 EAST 3079,46 .......................... ~ ................................... April 29, 1981 Mr. Bob Hines Arco Oil & Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re: Our Magnetic Multishot Survey Job No. MS-16780 Well: D.S. 16-13 (SEC24 T10N R15E) Prudhoe Bay Field North Slope, Alaska Operator: Blaine Baertsch Date of Survey: 4/28/81 ~ Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Magnetic Multishot Directional Survey on the above well. Also included are the field data sheet and film. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/pr Enclosures DRILL. SITE 16-13 .-.'.. !'.::i'"'.- ' .:.::':'...':::.t.'..::!:::.'.:-:':~i::.:/.:.'/.:f..:.....::.--...'.'::::'/.": :.. DATK OF SURVEY APR L 28, 19~.1' F..qUDHCE ,:~Y FIELC '' - .]:. ......... V'E':'R'T'IC~L' ~ ~ECTICN D IRE~'~Ir'N,- N 2'a-22-~q F~GNETIC ~ULTISHOT KS-167F2 SPERRY-SUN~ INC. "[.~_~}.?~_.[.D ....... V~.T.!~.~L SEA INCL!_~..~T..ION "'OI'REcTIc~:' ::: SEV ' F. ECTAI,;GIJLA~ C~ORDINATES VERTICAL DE~TH [}EPTtt TVD DEG MIN DEG ~,~IN DE-~7'i-~Z~'~"O~'T~'%SO'UTH .......... E'I"S'TT~E'S-T ....... SECTIOtJ 26PO.O0 2670.0,3 253C.t2,S ASSU~'.~E VERT!CAL TO 2G:)C' FFF_T 5°00 N 2.90 E · .................................. 71 ..:u.'.E :' ..... .-.'.?,.:' .':. .... ':. .. '..1~ , .~.. E ............... ,'2 '::". ~7~:~,. o~ ~7:~,.~ ~.~.~ ..:-:... '-:: ~ :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::.'.i::: :::..:-..: :.::-.:/' .~:o ,,~- : .~, £ _ ,, -... ":' 2 ~ ~' ~ · 00 ,. ,~ o 3 · 8. 4 27 i~ ,,. · 84 . :':' ~ ' ~': [~, ." "::"'::::.. --.::::::.:. N". 51.";:-::::".~ ::::::::::??::::::::::: .: ~ ("~ ..':::. ": :-' :': · ': ~:'. ~ ,5 ~ - · 82 E 5 · P, ,..- . ?~, . ............................................................... --.... ..... . . , .... 2. gQ7.8E 2q qE... ~5 2876,45 G 15 ......... ~:--"~('~ .... :"-K ~';-~; '3 .................. 9'; 3' 7--'~ .................. :"F ;"5'~'"K' 13.85 35~4.fiC 3qF_',2.96 3912.96 24 0 N 12 ~ E 2.96 144..26 k, 47.11 [ ]. {' S 7 ~ ~ · 0 ~ ...........::. 7~: 6_~ ~: ...."x ''= ' ' :' ' ::' ~''" :':"" ' ' ':":" ::'::::":?': '''j :" :'::':'"' :':' '::::<":' '?/'::' ~ ' '..-::-.;: "::7"-"':':' ':"' ~6,.:6.85 ,,,_':.? 6 .... - .... N:. 16:-"-:0. E.:'..-::-:-----,...,,,:I ..... . ..... 3810.27 37 3,9 N 17 8 E '3.77 369.69 N 108.60 E. 3 ~ A'~.':i";"? ~::~-.-..F%7'4'~ T'~ O:':.'T:.:-:?T:: ~7:"f'~:77~:::~::.::~?~ '; ::::::::::::::::::::::::::::::2'4; ~ ~-':'~". .................... "'~ ~ ~;'; ~ ~'""~".':. ...... ~ -' - :/::.:-' s ~:: ' ~ i..:' :::' ?:':.: '": ~:~-::"~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: =============================== ::::::~ ~ ~" ,5: ':'r.~ : ~ ~,'~ o ~. ~ qG76.88 5~ 15 N 2D '~--E- 3.3~' ................. (;11.";6-2 .... ~,f .............. I'~'0";6'I ..... K ............ 6 73.1~ 21. 75,,46 32.1'~'' 5~..28 26 9.0['', q20a.6! fl13fl.61 5.3 0 N 20 0 £ 2.96 £.P[.13 N 215.34 F 698.35 ~. [:'[, ............. 4 e 5 ~-';--: ~--", a: IJ~ 4312.'03 7 60 Q365o ~7 5u-...0 .:..'..-.:-.:.:-,.~.:2O....:-G..E-:,.-:.:?: ....... ...:--., 88.' .... · -: .... · 8:~,:,2,. ~ .295.38 E. 922.5,1. 1.6C Z~419.62 43~9.62 54 30 N 2D ~ E .53 --96.~.4-3.--1kT .............. ~:'~'-f'-~'~"4'-'£' ......... 9S8.25' AP. CO ALASKA, INC. ''" ....L-.~;,:". ' '- ~TLL SITE 16-]] - ":~..:... D~.TE OF SURVEY t, FRIL 28, 19~.1 ' .... .E_.R_,L.!~..H...(,.F..BAY FIELr, ' ' ':' ' VEPTICAL SECTION DIRECTIOL~I NQ~T~: SL,~PE~ ALASKA 31 DEG. EAST Cr~RRECTION t,F'PLIL-I3 P'/~ G~.:F l ] [. t.'ULTI SHeT FiS-167~2 SF'£RRY- SUN ~ INC, ..................................................................... . .................. .,,~, REC£RD OF SUP,VEY TRUE SU~ COURSE. COURSE DOG-LEG TOTAL DEPTFi DFPT~t TVD DEG P,I,N rJEG ,~iIN DEG/lOO., I'JCRTH/SOUTh E~ST/WEST SECTION 17f:..6.t+5 N 61q,52 E 1791,Z~2 1770.20 N 651.31 E 1862.17 1. g--',",,,;,15 N G~2.. .70 E 193~.z+2_ 1897.53 N 71~,1~ E 2003,93 1960.48 N 7~.F.,.~,9 E 2d7q,.18 F, 72~.O0 ~¢'>16.99... 554¢...~9.., 52 ~) ..... N 26 n ';:", ....1..C2 2340.,...'"',g N ~3~.7q.. . E 25nn.~5.., &"~ 1,00 5727.39 ';; .-" 5657'30 ..'~;-/'.-' ': 53"' "N · :' Z0~3.~9 E'" 2&~.9. 700,'60~ 57R1.,7 ". 5711,87'" :' '5~'''~.- n' ',]' {..'.;:7. NV-.26'-:':"'.~P':"'.E':.;~-:-':;.:~';~:'~L'.:';."-':'"~,2''; ~ .':'".25Z, 6,97 N 1035.66-E 271.~,90 7O9~.r~O 583~,5~ 576~.5q 55 15 N 2& 0 E 1.37 2603.66 N 106~.lq 5 2792.~& 71F6,0e 5887,80 ,5617,g0 5fi O N 26 0 E 1,36 2671.08 i",~ 11~1.(i7 E 21:!67,~5 ...... 7-~"?"~"; ~0 ........... 5.6"~ i' ~-'~'i ................ ~'~71.61 ... ~-.~3-.-,~0 ~''~' ..... ~..-..- ....... '::~r":'¥";~';'"~:":::v~'~"'-':;'~'~:'~:::'v-':'"'""~..-.N. ,.6.-...,.-~.. L:...E ........ ..... .... .'.....,~ .... ::'"':":'?"~'.. z l.,7.,,~ ~''= ' ~ ....... ..~ ..................... .. lZ3$, 2'4'.'T~' ................ 25q Z · Z O. '7~61,06 6049.11 ' 59 '~ : ~= ;~ ;"'""' ":.:' v:' o ¢;" ~:"F ;;-;:' ?'::/' "-" -. " 8 ":' -~'" ;"' ": ; :":"''' :,°5'~' ' 9~, .......................... ................................................ 7,,.11 . ¢.2 0 .-..~,. ~ .... O. B-~.-::,-,..:.,- .... ,..2 .........,~E. 71 ~ .,, .,~.,:~$ ....:,.7[I E 3090.17 7552.00 6100,98 6030,98 55 30 N 26 O E ,55'~ 2g~,q5 N 123],~A E 316q,81 76~.0[i 6.1.52.19 6a82.19 56 ..... ' Y'~"~-~;'~ 6 ................ ~ 2'5 i' ;"~ ¢ ....... ' ........ g'~' ~'~'j'"~ f'i ............... ~' 7"~' ~' 7 7 '"777[~ ;7:':~'"72-5-';77'~-~'~'%~T.7~;:]:'i"',"i i. '3'.; ?;[:;-?' '~ (S'7 ~ ' 3 6 '7'N .............. .7 .... i ~ '~'5'; 5 ¢' "~"" ......... I 331~,6,~ 7825. O0 6251.80 61a. 1.80- 5 '1 '"';1 5'-N. ~Z2~,.23 E' 3391,73 L.79] 7, O~ ......... ~L3.{~!.t.~.(~ .......... ~.~3.~...~..~ 5B_:...~._.:.,,].L~]:]~..]..~5 ".:':0 E--,':.?~':"/:.:':'.,2~..:.~.::.~,.~!.~.~.~ .... ~ ........ ,:.__~.~A~L~-_.~!'.~,..~ .............. 3q69.2C ~C~9.00 63~9.99 6279.99 57 ~5 N 25 0 E .27 Z285.~ N ~393.~9 E 35~6.89 DRILL SIT[ 16-13 . . '' ...~......' :..:: DATE. OF StJRVKY APRIL PRUDPC'~." ~.?/,Y FIELD . -"-' :'.]":'.~ .VERTICAL SECTIDN DTRECTIDtl -%.~-?;~"Y'~"SL'oFE ,' A E~c, KA ~: ........................ 3'1 .... G~B"; ..... E'~' S'T ..... C"OR'R E~'T'i'C:'~:" IPPLI ~A. GNE. I IC KULTISHOT P.S-167R2 ' SPERRY-SUNi TRUE ' SU~ COUNSE COURSE DOG-LEG T r:T~.L [~F~StlRED VERTICAL SE:, !~CLINATIuN' ¢ ' DIRECTION~ SEV RE'CT~.NGUL~R CCO~[;]NATES VERTICAL DEPTH DEPTId TVD BEG HIN DKG rain DEG/] 03 NORTN/SOtJTH EAST'/~i~'~'Y ............ 81P],O{~ 6~'-~9,42 6..:2.q,q2 57 15 N 25 D E ,Sq 3}55,7q N l~2fi,TR E Z62~.2~ ' :.. ~ ~,~ 00' ....... ~:i'. 7: .... : ..... ~".~7'~ ~S'" ......... 57'-is ........ :"':7'~F'~.'S'": ..... ~ ...... ~".:"':':'~'~i'~"a':' ................ ."~,,~.R ..... r: .................. ~,~.~i' E ...... :7~.~.2s ' '~2~6.~ 6~98.99 6428.99 58" 0. ': .':' N 2~..- ~ E ":'{" 1.23 -'-'.:' 3A97,33'N ' 1~92.06 g 377~.~ ' ~37~.,00 ~.5~+7,7~ · 6A77,7q :- 5-8 :."0' '~ '- .' ~": ':::. N."2~-'-:-'[~"E'{:.'::' '.'~ ,S2 ..':.'-"'.:':'356~,87'.N' ' 15_23~.1.g .... ~ ........... 3~57,, Fq7O.~O 6595.~7 6525.q7 59 3C' N 2q 0 E 1,F8 3t:qD.99 N 155A.53 E 3935.51 pr.~..-~.., ,.,i;O (,6A9...,67 65'72,67 Sq., 3r'.., N ;'3 i'.i E ,<~=. ~ 371q,47 N l:~g,q~'...:. . .. E 40!5,22 '--'T'~l'~T:.;'o~, .........6gS"~'i'g'g .......'"g"~'-i ~ ,'~ ........ ."'""'"-'~'~":".~'0-T:?":::....?:::ri'."~4':"::'::.'~'.::'::.'~:?~::TT:::;'~'~ ............ :' '57P, 7.16 ~:J ........... i ~;~ A.'O~'' E ...... q ~94. :. ~ ' ' ~ ' ' ' ' ' '" ~ ' 3 ~ ' ' ;'""":": ' ' ~ ~'::'::'::' r/:: :'::'::'::.::::::.:'.':: :' -;. ~ ~ ~:5, ..... ~7~ .0~ g73~.7fl. 6~6~,7~ . .::8 c~ .-.: N:.'.Z~ ...... u.E..'-' .... .:...-1 ... ~ 9.,~8 N 1:49.53 E q1.72 ~:1 .... N ~...~ -.:., -~ .. 1,3: 3~=~ - BB41.C6 678~,.72 6716,72 57 15 ' ~= i ........ ...,,:..75 r,~ 168[~.6~ E 425 qO?5, (i{' 6~ ~.~9.26 681.9.26 55 15 92~70~ ~9~5 91 ~25.91 5~ '15 :' '" < '" '""'"':' ':'""" :"' ~ " .. . . . . N.z.l . :-.E . .... . .,. ~ A211..56 N 1791.95 g ' q54 q2me.. , D6 7B5. 1 · 1 q 6981 · 1 ~52 0 -:..'.:::'~N'.-2:{)':.:,-::~-'~'..E;:~5~?:~-~':--.:::::'I',63" q. 279,29 N 1817.27 E 46~_ ' e: ~ e. o o ............... 7Y C- a-Ti-6 .... ~-~:g';"i-6 .................. 3,21 6,71 9.19 .5,6q 2,32 ¢93~_.C6 7474.62 7~q.62 45 ~0 N 25 t, E oc~6 ~71F.:o68 N 20~7.fi5 E ............. ~-~ '-:.' ........... ~- -- ~: ~ .........c ....... : ....... : ....... ~x-, ............. ~: .... ~ .... 5:' :-:: ?:7:¢'".~':~"' :7'~U~-:'~':~'~': ....... ~"-: ...... : .................. ' .................... ~ .... - ............. 1002. ~0 7~8~'~i~ 7~68.82 ..:.--. ~. ~.~ ... ,-. 4777'~12 N . 20'3'4"9 ~ 5161. ~ ~: ' ' = ~ ": = ' ' '"": 2:-'"::'"'::'::'"~::'::"':~::'5::::¥:':"' ::':':":":"::'~"'::'::'::' ':'1'r~' :'"'"':"~: 4 10122.00 76u5..a 7a3~.~5.. .4.,:-45 . N...2~...-: ...... {...~.g .:.:.....:~,. .,... 8 ~.93 hi ' 20E~..33 E 5226..35 ~03C~.0C 7737.81 76~7.81~ 4~ 45 N 33 0 E --1..3~, ~9"~-~;-~'7 N ~'~'3'~%'~-"g ........... 5353.72 ll:3qP..,O0.. 78,q2o72 7732,72 10 ~90."~; ............ 7'~"~';'~'3' ................. ?'~'~'~-;'~ 3-'~7-::. 46:3~ : ...:-...-:-N-:::.'-~..:?::~::..O:::'~'TT~::iT;-3'~ .: ':: :5"~53 ;'7.~ .... r~ ......... '"':'"22 ~"3";'l'[:'-'E ........... 54B~, 78 '165F1.00 7928.~9 795~.69 A7 .:30.-.' ':'.:.-.:.:T: :::::::: :::::::::::::::::::::::::::::::::::::::::::::::::" 1..16..':.57..":~.:::':'51{~8.90 N : 2240.33 E 5551.12 10~,72..00 798~.~7 7919.87 . q8 .-0 :.' :?':.,"~:::.N':35"?:::.'}~::'E:':'{::':~':'.-::.."".".98'.:'.:::':"'::" 51.6~.qI N '2278.~8 E 5618.2~ 1076/, O0 R050,17 7980,1 7 ~9 O-- '"~3"5~:-K .... :TI:'J' 5'22'~:'2'"~--~ '23'I"7T5~ ...... 56'86,22' DRILl. SITE 1E-1'~ ' 'DATE 0¢ ~ljrVEY AFRIL 2~. · ~. . . : .. .- .' .: · . : . ,,. . F'PUDHflE ~AY FIELE ..... VE~.TICAL SECTION [.lqECTIO,~' NORTH SLOPE, ALASKA 51 DEG, EAST CORRECTION A Ft. GNETI£ N'ULT!ShOT RECORD OF SURVEY TRUE SUB CCURSE COURSE' DOG-LEG TOTAL DF. Pl~ F, EPTH TV~ DFG t".I,"~ DEG !-";.IN DE6/1C, O NCRI'~!/SOUT~ EAST/NE'ST S PPL]SD RTICSL J~PF,'7-..[.',C, PllD.22 8Ca5.22 tim 30 N 36 0 E .99 5276,97 1',: 235P,0~ E 5755,32 l~q7. CC ~!70.28 8!00.28 ~5 O N 36 0 E .5~ 5333,36 N 2~99,01 E 5~2~.55 11C~7,~0 P. 229,62 ~159,62 ~8 3D N 36 0 E' ,5-~ 53~.,1~ N 2~3f~.'Z8 E 5~91,76 ~' ~, " -,', s ~ .... ~ ~'~ · - ~ ' " " ..... . ....... : ?.~.._~.~ ..... ................ · ..........~ ~,, · {.,c~-'~' ................... ~':"~ '~. ~...~ ''~' ' '~'''' ........... ~ 2e,,...,~~: ...... "¥ ..... ~ ......................... ~=~' ....... o~ ...................... N; ............... ~ ~, ................... E .Z .,~,,:~"¥ ............... g ~'7: ;~ 2'""i}- ............. ~,~, 7.. z""" "" E ~C;S · ;+~,. l] 771 o G[ ll ~,. 7 c,. tiOi~IZCNT~L DISPLACE'~ENT = 6q8[!,55 FEET AT NORTH 25 bEG, 2£:; PiIN. EAST tTRUE') DRILL SIT~-' lA-]3 ' ' :. ' ":' ~: "':i'' '-''I . ' [)ATE OF' SURVEY APRIL. 25!,, lqgi' ~t-'r:'-;~ ~iY ~LL~ · .~ · ' ."..' '...'-'.--~.'.., ~.i.~.: ~.'.--'.~....... i~... · · . . ................................................................ - NOPTH $I. OF~E, ALASK~ I~ GFiF T It. F'.UL T l SH(', T MS-16782 I NTERP. CLAT£D RECORD.. OF SURVEY TRUE T£:T AL M E A S U R E[:) ............................................................................. L-"F' .... R T I CAL = .... SOB'-- <J E A' 'T'R"U'E .............................. R E'CT -[if:,~'G.. U'[A R ...... C'O'~' R D'I [4 A T ? S GFPTH DEPTH TV.;q ELEV/'.T'I ['>~, ,,', OR TH/SOUTH EAST/WEST 3fi7,r!, 3800' ' ' -':'.----.:.:-"' "":'. -$~{;- 362. N 106, 3970, 39,',.)0, -':t~O..,. ........................... 44U. N' 1~1.,-. 4070. 40 :lO. -'q ['.0 O · 53G. N 162. ' ' "' "' .... -q2g. t,,. 765. N 2.'+7. -~ZC, O. 898° N 298° ·, .................... g. q 46 ~:'~- ........................................ ]'OZ£ ;"N ....................... 346. -4;00..: 1159. Iq 394. .. j DRTLL. SITE' 1~-13 - :....:'.-...:...:.. [.'..,ATE OF' SUF',VE:Y APRIL 28, 1981 ~ .... E~.~ PP 0 e .iT: ~ Y _ e: E L :~ ............................................................................................... L_.,_' .'=:_-- .............................................................................................................. NOFTf~ SLOPE, ALASKA PAGN.rI'IC '~.UL 1'I SHOT .............................................................................................. ' · .: ,- INTERPCL. ATED RECCED'OF SUR. V[:'.'Y ............................................ :5.8 P [. ....... ] .................................................... ..,:,::_::._ '-. ,::, .................... ,.'_: ................................................. T.'.:: T..~.L- ................ YE ASLJF' El] YERTIC~L SUB SEA TRUE ~' E C T.a r.,~ F-, U L ~.R CO CRD I!',A [' FF'T ~! ~EPTH Tv.r]. 5LFV~TI C,I~ ;,~0 R T :-:/S ¢:,t.}TH EAST/~ = 6~73. 5776, -' ' ' 5700, :'' '.--::.i:: ?:':..:':..:' -5700° ' ' 252~. .... <:.. e :, O. 2772. N 11 7:2 ~' ~970 · ~:q ~ ~ · ' -., .' 7458. 6070. 6C~iO. -6C:O[;. 289~. N 12 7 e 7 5, ................................................. :"6'{~ ~'~ .... :',7'7":77": .... .' 61 00. ':.'::' '7:::7":5:75:~:~:~7'5:::~:~ 57~."::/'2'6'1'0 0','' :'. ...... : ":"'.::'"': ........... S O' 3'0"," ~} .................... I. 2 , = :o-~ · ' : '.6~,. ' '-":-' ...... :::'.::: ::-:':'L". . 620C', 7~ ~, 6,:/J, .':' · .:' ...~:.u-, .:: '-:.: .:. :...:-<.:..:'.':--.. ..... '.'.:'.' ' -? ' ' ~ ' .. · ' '. : FA2'G. 6:570. 65i.)0. -65ti(:. '~6 ~'2 · N 1 ...................... ........ ...... .......................................... ........................... . :.. ............ ..... ========================================================================: ............................ ~81 O. 677g ...' '- 67 .......... · ...... - G 7~'.: 6 ~1 6,~70 ' ~164. 6970. ~9S0, -g960. q179. N 17 : o=29. 7~7~. 7000. -7C00. 43P2. N = 948.. .' 1o · · 7~7~0 ' .- .' :: ..-7~.:~0, -7~::UUo .... · 4a24o N 1.9 ~ ,- · ' "' -~ e, ; '" ':: ':"':':':<: ::'::'?" :":'5':'"":'"'"' ':' ' ~ '~ :" 'l " ' 4 '> · 7, 7o7u0 . 7.: ~...~0, ...... .- l.,~g · 6,.1. .......... ?i ..................... 1 c, 1 · 7470. 7400. -7400. 471q, N 20 3. 7573. 75!70. -7500. 4805. I',1 20 1C' I l~Pll. ' l~.7{J. . .. . ..'........7,~..-~. ...... ......:.::. ..... . ..... -7~}~l]. 1l~351, 777D,' :' :' .'::'77g:0, .':..". ':..:::i<:'.':'-':>:?>::i:...-..:::::.:,: '::::".: ."-7700 o 4971o N 21 . ._' _1_.0:.~_?_.:5.,~,. ......... 7870. ·" "' ' .:." '' . 7~{08 ' ::.7-. ========= == = ======= === J==?= == === ============== === = '.- -71~G6,. .......................................... ~iO~,... :::7_.._ ..... !',! .............. 22.. 1 OF, aDo 7970. 7900° "~ 79 O0 · 51~6. N 22 ' 1 ~8 50 ,4o-16 7~2 TEs EST 70. E 29. ~,~ 5C. E. 12. ~': 7'5. E :37, E .. 7 TM E 37. E 05. E 70. E 2~:, El.. 75, E: 26. 14, ~.. g E 05. E · . 66. E' 31.£ 39.9 . E 4F.,5. E .:> ,:. g · · 644. E DRILL SITE !~.-13 ' ''. :'.'.:? '~'.:'-':.."~:i.."' [;ATE CF SURVEY APRIL 28, 19~.1 · · . FRL!P~6E [-;AY F~ELD . : ~::-,:...:' : . .. · ~OFTH cL. OFE~ ~.LA~ .... ~A . P~ G~,~ST ]C FULT[SHOT r~S-[6782 INTERPCLSTED.RECDRD OF SURVEY TRUE .- TF)TAL PF ~ SUFi EE~ ............................... '~?.'F~. i'"~I' ~"'~'!~- .......................... ~~U'B"-~-'?A~- T'R-U"E ................................. R'E C'T At~ GO EAR .........CC. [R'DI NAT ES DF FT H DEPTd, TV6 E.I..EV ATI CN. ;~ORTt~/S'2UIH EA ST !'~,EST INTERPOLATED CCORDINATES FOR EVERY 10~]o[~0 FE[:YT C;F SU~.:-.SEA DEPTH WI ERRY-SUN WELL SURVEYING COM MAGNETIC MULTISHOT FIELD DATA AND TIME SHEET NO. 1 ~ ~ JOB NO .... 1~v"J 0 f{-~' '~ q~ COMPANY ~', ,;C- · , ~'6' ~ DATE _ STATE ~ ~,,~ ' ./~/' ~ ~~ ~ ~ ~ COUNTY/PARISH r FIELD m-~ J ~ ~ SURVEYED FROM ~ ~ TO ~ FEE' LEASE ~ -,. · WELL NO. ~, '~ CLOCK NO. ~' /~ ~ ~/~ ~CENTRALIZER FRAME~NO. ~,__Z~I MAGAZINE NO. ~- COMPASS NO. i /~, /--- COMPASS SPACING , FROM BgT~P~TOP LENGTH OF COLLAR FILM LENGTH.CALC. MEASURED FIRST FLASH ~-~ LAST FLASH REMARKS: ~,,, C~~ ?~ ~'~ ~ 4' ' ~ ,~' ~ ~~ ~'~'~*'. ~.~,-- -~ OPERATOR IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEASURED {:)UT RUN SURFACE TIME DEPTH SURFACE TIME ISURFACE TIME DEPTh SURFACE TIME SURFACE TIME DEPTH SURFACE TIM: I .-75':- ~ , I~');~o ~ -~ ~ ~.~. '=~; ,._ ' '=~". ~ ff~ Z?~ /)~,.--~- ._ ~ /m.'/zz ~ - z.~ .... ..'.;~ ..... : :,' ~,:.::,-- ~,,~ - ge .' ..'?,, ~ . . . L 01-2.03(4/76)5M (' ERRY-SUN WELL SURVEYING COMIC' ¥ MAGNETIC MULTISHOT FIELD DATA AND TIME SHEET NO. 1 COMPANY STATE LEASE JOB NO DATE COUNTY/PARISH FIELD WELL NO. SURVEYED FROM TO_ FEE' CLOCK NO. FRAME NO. COMPASSSPACING FROM BOTTOM/TOP FILM LENGTH CALCo MEASURED REMARKS: MAGAZINE NO. COMPASS NO, LENGTH OF COLLAR FIRST FLASH CENTRALIZER TYPE COLLAR LAST FLASH OPERATOR ///////////////////~il//////////// /////~...- :~ o ~ :/ ~- /////// ///////////~.~ // /// ///,////,K~ ~ / / L_ k ~ GO DEVIL IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN SURFACE TIME DEPTH SURFACE TIME SUI~FACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE .-:-;; c:~.,c , , ,, .... .-.- , ?~ ~ ~?~ ~ ,~. '~..~ :,, ~3 ,', '" 71] ..... ~ m ~ 7~ :~.~ ,, , ' .,,, · .~.. ~ ~,,'~,'.. / ~ ~...~ , ,, .,' ~-i,'~Z ~,~ tz U:~: ""' ~y ;'~')' , 'a?, '~-. 101-2.03(4/76) 5M LOCATED IN THE APPENDIX ~ WFL UI IPR LOG UI CALIPER SURVEY UI VOLAN ffi CURVE DATA UI STRATIGRAPHIC HIGH RESOLUTION DIPMETER 'UI OTHER: " Check Fetch for tinmly c~:~p!i~ce with out- regulations. O[~rator, Well i;-dre and Reperts ~d Haterials to be received by: Re{faired Co~p letion Rq~rt Yes Wel 1 History s.~o~ ! Mud Log. Core Chips Core Description '{'~'~ Registered Survey Plat Incl±n~tion Survey Date Received h'Qma ~l ~. S I Directional Survey I "f..~?d_--.._.~.._! ....... Y~i ~ /-' ~f-..~ Drill Stem Test Reports . _z~._~_ ._~:~ .......... ' - I Pr~u~ion Test Rc~rts ~s R~ Yes 7-/?. ...... J/< ARCO Oil and Gas -npany North Alaska district Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon Dislrict Operations Engineer July 13, 1981 Reference: ARCO Directional Surveys ~'.:'S']'lg.Z'i'3 ~:',, 6/20/81 Gyroscopic D. S. 12-10 6/7/81 Gyroscopic D. S. 14-19 6/30/81 Single-Shot D. S. 12-11 6/26/81 Single-Shot D. S. 17-7 6/30/81 Single-Shot Mary F. Kellis North Engineering Transmittal #428 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY SOHIO - ~.~.. MARATHO~AI~ska~' 0il & Gas Cons. Commiss~or~ CHEVRON Anchorage ARCO Oil and Gas Company is a Division Gl AllanticRichlieldCompany ARCO Oil and Gas mpany North Alask. Jislricl Posl Otlice [3ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon Dislricl Operations Engineer July 10, 1981 Reference: ARCO Cased Hole Finals D.S. 14-19 6/8/81 CNL/Gamma Ray Run 1 2"/5" D~'S':"i6-13'!, 6/19/81 CNL/Gamma Ray Run 1 2"/5" e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #424 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON, ~.~ h,.. GETTY ,/~, PHI L[' ~'~S.~ Oil ~ ~,~s Oo~ SOH I 0 MARATHON ..... CHEVRON' ARCO Od and OJs Company ts a D~wsmn ol'AllanlicRtchheldCompan¥ ARCO Oil and Gas '"-mpany North Alask istrict Post Oftice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 9, 1981 Reference: ARCO Cased Hole Finals ~.~ D',S~.16'13 6/14/81 D.S.17-6 6/13/81 D.S.17-7 6/16/81 ACBL/VDL/Gamma Ray Fluid Density cNL/Gamma Ray Run 1 5" Run 10 5" Run 1 2"/5" Mary F. Kellis North Engineering Transmittal #423 DI STRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHI LL_I P..S . RE£EIVFD MARATHON JUL CHEVRON Alaska 0il & Gas Cons. Commissio~ Anchorage ARCO Oil and Gas Company is a Division ol AllanticRichfieldCompany ARCO Oil and Gas Company North Alaska ,trict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operalions Engineer July 6, 1981 Reference: ARCO Cased Hole Finals D. S. 12-9'.. 5/11/81 D.S.12-11 ~6/24/81 D.S.12-11 v/ 6/25/81 D. S. 14-20 6/23/81 D/'S ~.i1~'~6'~ i~3 ~.?'' 5 / 10 / 81 CNL Run 1 5" Cement Volume Log Run 1 5" CNL Run 1 5" CNL CB~./VDL Run 1 5" Run 1 5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #409 DI STRt BUTI ON NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division o! AllanticRichlieldCompany ARCO Oil and Gas ' npany North Alaska ..,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 30, 1981 Reference: ARCO Magnetic Tapes & Lists ~:~D'~S'~'16~'f3??~ 6/8/81 Tape #61711 D.S.12-10 6/7/81 Tape #61707 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TransmittaI#397 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY MARATHON Alaska Oil & Gas Co.s. Commi~;~ion CHEVRON Anchora~ ARCO Oil and Gas Company is a Division o! AllanticRichlieldCompany ARCO Oil and Gas Company North Alask~ 'strict Post O Ifice L , 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 26, 1981 Reference; · ARCO Cased Hole Final Prints D.S. 12-10 D.S. 14-19 D.S. 16-2 D.'S~ 16-13 6-3-81 ACBL/VDL 6-1-81 ACBL/VDL 4-14/15-81 CCL 6-9-81 CNL D.S. 17-5 6-4-81 D.S. 17-7 6.7-81 run 1 2" %~, run 1 5" CNL' Ganma Ray Multi-Spaced Neutron . ACBL/VDL Gann~ Ray run 1 5" ~/ runl 'Please sign and return the attached copy as receipt of data. Kelly McFarland No./~/ Engineering Transmittal # 375 DISTRIBUTION NORTH GEOLOGY R&D DRILLING 'ENG. MANAGER 'D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON RECEIVED JUN 0 19 1 Ol~ & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Divesion ol AllanlicRichlieldCompany ARCO Oil and Gas~'~ mpany North Alask~'~ .3istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 23, 1981 Reference; ARCO Open Hole Final Prints D.s. 16-13 6-9-81 FDC run 1 5" D.S. 16-13 6-9-81 FDC/CNL run 1 5" D.S. 16-13 6-8-81 BHCS run 1 2" D.S. 16-13 6-8-81 BHCS run 1 5" D.S. 16-13 6-8-81 Dual Induction-SFL run 1 D.S. 16-13 .6-8-81 Dual Induction run 1 5" D.S. 16-13 6-9-81 CPL Cyberlook run 1 5" 1! Please ~ign and return the attached copy as receipt of data. Kelly McFarland North Engineering Transmittal # 378 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON RE£EIVEI) JUN O 1981 Naska 011 & Gas Cons. Commission ARCO Oil and Gas Company is a Division of AllanticRichfieldCompany .. ARCO Oil and Gas Company North Alasl, islrict Post Oflice bOX 3-50 Anchorage, Alaska 995'f0 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 23, 1981 Reference: ARCO DIRECTIONAL SUP~EYS · .l ii8'~ 5/10/81 Gyroscopic ~ D.S.-16'6 ~ 5/19/81 Gyroscopic ~~~:162~i'~) .... 6/17/81 Single-Shot 4'12-10 6/2/81 Single-Shot //D.S.16-6 6/16/81 Single-Shot ~.S.12-9 5/11/81 Gyroscopic Job#4771 Job#Boss-16803 Job A481D0291 Job# AL 5-81-D12 'Job# A481D0324 Job#4772 4 ENG 1 GEOL 2 GEOL 3 GEOL STAT TEC STAT TEC '~ONFER: I FILF: Please sign and return the attached copy as receipt of data. · , Mary F. Kellis North Engineering Transmittal #3'70 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ,s a DIv,s:on o! AHanlicR~chtieldCompany MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I-~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-27 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 so-029-20566 4. Location of Well at surface 1653'S, 548'E of NW cr Sec 24, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 70' RKB 6. Lease Designation and Serial No. ADL 2~3~2 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 16-13 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool For the Month of M~_Y ~ - , 19 81 "12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0900 hrs, 4/6/81. Drld 12¼" hole to 8064'. RIH w/Whipstock assy, as of 6/1/81. See attached Drilling History. 13. Casing or liner run and quantities of cement, results of pressure tests 20" conductor to 80', cmtd w/334 sx Arctic Set. 13-3/8" csg w/shoe @ 2654'. Cmtd w/3200 sx Fondy & 400 sx Permafrost. 9-5/8" csg w/shoe @ 11,772'. Cmtd w/500 sx Class G. See attached Drilling History. 14. Coring resume and brief description n/a 15. Logs run and depth where run CBL, Gyro/CCL. ,.16. DST data, perforating data, shows of H2S, miscellaneous data n/a 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "SIGNED _ TITLE District Drillin§ Eng. DATE NOTE--ReI~ort on this form is required for each calendar month, regardless of the status of operations, and must be Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 fired in duplicate with the Alaska Submit in duplicate DS 16-13 Dri 11 ing Hi story Spudded well @ 0900 hrs, 4/6/81. Instld 20" riser. Drld 17½" hole to 2677'. Ran 65 jts 13-3/8" L-80 72# Butt csg w/shoe @ 2654'. Cmtd csg w/3200 sx Fondu & 400 sx Permafrost. ND 20" riser. Instld 13-3/8" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi f/15 min - ok. Drld FC, cmt, FS & new form to 2687'. Tstd form to 12.5 ppg EMW - ok. Drld 12¼" hole to 8064' - torque backed out pin in DP @ 3125'. RIH to fish & workover. PO1DH w/fish. Drld 12¼" hole to 11,879'. Ran 281 its 9-5/8" 47# L-80 & S00-95 csg w/shoe @ 11,772'. Cmtd csg w/500 sx Class G. Instld 9-5/8" pkoff and tstd to 5000 psi - ok. T~td csg to 3000 psi - ok. Drld FC & cmt, tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Ran CBL. Drld 10' of 8½" hole - DP kept hanging up while POOH. Stand back DP & set cmt plug @ 11,795' w/150 sx Class G. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C & 131 bbls Arctic Pack. Drld to 11,816' - pipe started packing off. POOH. RIH w/mill. POOH. Ran Gyro/CCL. RIH w/ream - hole sticking, packing off & DP hanging up on 9-5/8" shoe. POOH. Ran CBL. Set ret @ 11,650'. Tstd csg to 2000 psi - ok. Squeezed cmt thru ret & on top of ret - total of 300 sx Class G. Milled csg f/ll,401 - 11,442' Set cmt plug f/11,248-11,557' w/150 sx Class G. Tstd csg to 1500 psi - ok. DD to 11,437' - still had high torque. POOH. Set'cmt plug w/120 sx Class G. TOP @ 11,139' Tstd csg to 1500 psi - ok. DD to 11,442'. Attempted to sidetrack ~ 11,430' - Drld 4' then drld into old hole. Set cmt plug f/11,200-11,442' w/125 sx Class G. RIH w/Whipstock assy, as of 6/1/81. ARCO Alaska, Inc. Post Olllce Uox 3G0 Anchoring,:. ', ~, I,.;-~ Telephone. June 22, 1931 Mr. itoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Conlnli ssiol~ 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 4-13 DS 5-1 DS 12-9 DS 12-10 DS 13-12 DS 14-18 DS 14-19 DS 16-6 DS 17-7 A-1 "3 -2 B-3 C-8 Dear S i r' Enclosed please find' 1 ) The subsequent sundries for DS',4 1~ & DS 5-1. 2.) The monthly reports for DS 12L10, DS 14'-19, DS 16113~ DS & B-3'./ 3.) The completion reports for DS 12L9, DS 13 DS ~J~/~/Sincerely' ~. P.A. VanDusen District Drilling Engineer PAV/KJG' sr Enclosure ARCO Alaska, Inc./ Post Office~, ,< 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 14, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 16-13 Dear Mr. Hamil ton: Enclosed please find the Sundry Notice of intent for DS 16-13. Sincerely, P, ^, VanDusen District Drilling Engineer PAV/KJG:sp Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Znc. 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50- 4. Location of Well Surface' 1653'S & 548'E of NW cr Sec 24, TION, R15E, UM Target- 1312'S & 1570'W of NE cr Sec 13, TION, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-13 TD: 780'S & 1271'W of NE cr Sec 13, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 70' I ADL 28332 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans ~ Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operat'ions (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to deteriorating open hole conditions from 11,889' to 9-5/8" casing shoe at 11,772' it has become necessary to set a retainer at 11,650' and squeeze + 250 sx cmt~.below the retainer and dump + 50 sx on top. After cleaning out to top of plug, a mill has begun to cut a + 70' wind-ow in the 9-5/8" casing at + 11,400' to + 11,470' A balanced plug will be la--yed across the window and after WOC d--ress off plu~ to + 11~410' (10' below top of window). A 20 bent sub and Dyna Drill will be run, the we-ll will be.~.~ide tracked around the old hole and drilled to TD toward the same bottom hole target ~r6'~'~'~-~)"~'~'a~s' 'p~re~i0u~ly permitted. MAy £ 2 ]981 Alaska Oil & Oas Cons. '~Chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed, .~J~. _'~~~.-~,~ Title District D rillinq E n.qineer The space below for Commission use Conditions of Approval, if any: Approved by. Approved Copy Returned ORIGINAL SIGNED ~Z/~?/~¢/ BY LOH~IE C. SMITIi -'-:'-'-'~ ~'~': o: ''~'---- COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~'~ Chairman Thru.. Lonnie C. Smith ~/'~ Commissioner ~ Petroleum Inspector May 14, 1981 Wi tnes s Squeeze Job on ARCO'S D.S. 16-13 Sec. 24, T10N, R15E, UM Permit #81-27 Sund~ May 10, 1981~ I traveled this date to Arco's D.S. 16-13 k© WitneSS the UpComing squeeze job to abandon the well bore below 11,650+. This decision was made by Arco after encountering numerous casing and open hole bore problems. When I arrived at the location I was informed by Peggy Fisher, Arco Drilling foreperson that the 9 5/8" E-Z drill bridge plug had been set earlier with a wire line unit at 11,650' W.L.M. The D.P. was strapped in the hole and the E-Z drill was tagged with 50, 000% at 11, 671' D.P.M. Mgnday May 11, 1981~ A 300 sk. slurry of class "G" cement with 1.8%' salt and .7% HL-7 was m/xed and pumped down the D..P. The D.P. was then stung into the retainer and 250 sks. were squeezed into the formation. Initial pump in rate was 2.5 bbl/min @ 1,500 psig with a final rate of 2.5 bbl/min at 2,000 psig. At this point the pumps were shut down and final pressure of 2,000 psig was held for 3 minutes. The D.P. was then unstung and the re- mainder of the slurry was placed on top of the E-Z drill, bridge plug, the D.P. was pulled up 150'+ and reversed out. In summary, I witnessed the squeeze job on ARCO'S D.S. 16-13. · ARCO Alaska, Inc.[ Post Office F~ 36{'} ~-~Anchoi'age. Alaska 99510 Telephone 907 277 5637 May 13, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 5-1 DS 5-10 DS 9-18 DS 12-9 DS 14-18 DS 16-5 DS 16-6 Dear Sir" Enclosed please find- · e 0 DS 16-13 B-2 C-7 C-8 T-3C CONFIDENTIAL W. Sak #18 CONFIDENTIAL The Completion Report for DS 16-5. The Co~pletion Reports and Gyroscopic Surveys for C-7, W. Sak#18& T-3C. (Please note that W. Sak #18 & T-3C are to be considered confidential). The Monthly Reports of Drilling & Workover Operations for DS 5-1, DS 14-18, DS 12-.9, DS 16-6, DS 16-13, B-2 & C-8. · Sincerely; P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures The Subsequent Sundry Notices for DS 5-10 and DS 9-18. ARCO Oil and Gas~- mpany North Alask~ district Post Office box 360 Anchorage, Alaska 99510 · Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 7, 1981 Reference: ARCO DIRECTIONAL SURVEYS D.S.T-3C 4/16/81 Gyroscopic D.S.16-3 4/4/81 Gyroscopic D.S.16-13 4/28/81 Multi-Shot NOTE: D.S.16-3 Gyroscopic is a replacement as survey date was incorrect on previous Gyroscopic, and D.S.T-3C is a replacement as KB height was incorrect on previous T-3C Gyroscopic. ~'~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #2.56 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON PHILLIPS SOH I 0 Ai~.ska Oil & Gas Cons, Comm'issJor~ Ar~chorage NARATHON CHEVRON ARCO Oil and Gas Company ~s a Division o~ AttanhcRichfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION Royle H. Hamilton/V~''~ chairman Thru: Lonnie C. Smith~ ~ / ~Y~ ' Commissioner ~~ Ben LeNorman Petroleum Inspector April 14, 1981 B.O.P.E. Tests on ARCO'S DS 16-13 Sec. 24, T10N, R15E, UM PRUDHOE BAY UNIT. ~.u~d..ay, April 5,. 19812 I departed my home at 5:30 am for a 6:00 am showup and. 7200 am departure via Wien flight #71 for Dead- horse. Enroute an electrical fire developed and we were forced to return to Anchorage. We departed a second time at 8: 30am and finally arrived in Deadhorse via Fairbanks at 10:40 am. Weather.. -10"F, high overcast, light wind. Monday. April 6, 1981: Tests began at Sohio~'s M-8 but were suSpende.d 'due' 't°'equipment failure, the su~ect of a separate report. T~esday~ Apri!~ 7, 1.98.12 Standing by on well M-8. Wednesday ~ April 8,. 1981: Tests on well M-8 were completed during' the mOrning. Tests on well A-9 began at 1..15 pm and were completed at 3:45 pm, the subject of a separate report. Thursday. APri!~_ 9, _198!.' B.O.P.E. tests on ARCO'S DS 16-13 began at 8.-45 am and were completed at 11..00 am. B.O.P.E. test report is attached. I departed Deadhorse via the Sohio Charter at 7..00 pm arriving in Anchorage at 8230 pm and at my home at 9..00 pm. MPnday April_ 13, 198_1-. Pegg~y Fisher, Arco drilling foreman, advised my phone the check valve in the kill line was repaired and successfully tested to 5000 psig. In summary, I witnessed successful B.O.P.E. test on ARCO'S DS 16-13. O G. #4 4.,/80 ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator .... .../,~.-.,,,,~ ~ Representative/~5/ ",,~F'~,'~:~¢~---')'~----- . Well 0.-? /~-/3 Permit ~ i ~ / _ a 7 Location: Sec 2~ T/~R/~E M OF~ /~Casing Set @ ~ ~ ~ f.t. Drilling Contractor /~O~A~ Rig #m~ Representativ~_~,~? ~-~-~-o.~/ r. Location, General Well Sign General Housekeeping Reserve pit BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Test Pressure . .-~--<~ ~ , Kill Line Valves Check Valve Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ~D~%) psJ. g Pressure After Closure ,/~D4~ psig 200 psig Above Precharge Attained: mit ~s. Full Charge Pressure Attained.~ ~ min ~ s ~~'./~,.. ~ o. ~/~ ~ ' " N2 ~;~J~. ~~/~~..~¢~ ps ig Controls: Master ~ Remote ~ Blinds switch cover~ Kelly and Floor Safety Valves Upper Kelly. Test Pressure ~'--(D~9(9 Lower Kelly Test Pressure ~-Z)~9~; Ball Type ~ Test Pressure Inside BOP ~/~- Test Pressure ChOke Manifold Test Pressure No. Valves /~ No. flanges Adjustable Chokes Hydrauically operated choke Test Time ,-~.Y,'!~[ hrs .... Repair or Replacement of failed equipment to be made within .~. days and Inspector/Commission office, noti. fied,. Remarks: ~I'~ ~ DistributiOn orig. - AC&GCC cc - Operator cc - Supervisor M~rch 4, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. BOx 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit Atlantic Richfield Company Permit No. 81-27 Sur. Loc.: 1653'S, 548'E of NW cr Sec 24, T10N, R15E, UM. Bottomhole Loc.: 780'S, 1271'W of NE cr Sec 13, T10N, R15E, UM. Dear Mr. VanDusen ~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Nr. P. &. VanDusen Vrudhoe BaY Un/t DS 16'13 -2- March 4, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dri 11. To aid us in scheduling field work, w~ would appreciate your notifying this office within 4-8 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of bIowout preventer equipment before surface casing shoe is dri ! led. In the event of suspension or abandonment, please give this office adequate advance notification so that w~ may have a witness present. Very truly yours, H. Hamilton Chairman of Alas~ Oil ~'.~s, Conservation C~mlssion Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ supervisor, Labor Law Compliance DiviSion w/o encl. February 23, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen ~ This is to inform you that two of the drilling permit applications that we received from you on February 23, 1981 contained only one copy of the application form (No. 10-401} Sincerely, Ho~ H. P~mi lton Chai~an MHH: be ARCO Alaska, Inc.~ Post Office I~.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 20, 1981 Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 16-13 Permit to Drill Dear Sir: Enclosed please find the Application for Permit to Drill DS 16-13 and the required $100.00 filing fee. Attached to the application are: a drawing, of the proposed well path, a drawing showing all wells within 200', and a drawing and description of the BOP equipment. The requirement of using a surface hole diverter system on this well has been waived, as per your letter dated 10/15/80. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/PJT:sp Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL X~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I-1 REDRILL [] DEVELOPMENT OIL [~ SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator~' ~'-E Atlantic Richfield Company 3. Address ' ~ ~ P.O. Box 360, Anchorage, AK 99510 4. Location of well at surface ,41aslm Oil & ]9 ~]1' Unit °r lease nameprudhoe Bay Unit 1653'S & 548'E of NW cr Sec 24, T10N, R15E, UM- At top of proposed producing interval ~d?OhOI.c~~ C(,rR~.,Well number 1312'S & 1570'W of NE cr Sec 13, T10N, R15E, UM '""/S~ioa DS 16-13 At total depth 11. Field and pool 780'S & 1271'N of NE cr Sec 13, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe 0i 1 Pool Tundra 34' Pad 39' RKB 70'I ADL 28332 12. Bond information (see ~0 AAC 25.025) Type Statewi de Suretvand/ornumberFed Ins Co. #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest pr.operty or lease line 15. Distance to nearest drilling or completed ' 5 mi NE of Deadhorse re,es 1312 feet well 2640 feet , 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date (9370'TVD) 12682'MD feet 160 April 6, 1981 '-19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures * .;J~56U psig@ ~.l<B Surface KICK OFF POINT 2800 feet. MAXIMUM HOLE ANGLE 53 °l(see 20 AAC 25.035 (c) (2) 43Rfl psig@Rcjr).r) ft. TD (T.VD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD'BOTTOM TVD (include stage data) 30" 20" 94# H-40 PEB R, 3 0 I 0 110"' .~1 110.' 2505x PF II to Surf.'" 17½" ]3-3/8":. 72# L-80 BTC R-3 0 I~ 0 2700' i 2700' 23008x Fondu, 400sx Pi' 12~" 9-5/8" 47# L-80 & BTC R-3 0 , 0 11748'1 8800' 500 sx "G" 1st st.q · I S00-95 ~ I +300sx PF II 2.nd'stg'. 8½" 7" 29# L-80 BTC R-3 11448' ~, 8617' 12682'~9370' +350 sx "G" '~down"squ.~( 22. Describe proposed program: Atlantic Richfield Company proposes to directionally drill this well to 12682'MD (9370'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be .installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5½" 17# L,80 tubing, packer and necessary provisions for subsurface safety equipment will be run. A' non-freezing fluid will be left in all uncemented annuli within the permafrost interval The packer will be set above the Sadlerochit. The downhole safety valve will be tested" and installed upon conclusion of job. · Bottom hole pressure based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. . 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~~. ~~~ TITLE District Dril 1 inQ Eng' DATE ~/~-O/~/ ~ . The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud I°g required Directional Survey required I APl number ~YES ~o []Y~S ~o .~J~[¥ES ~NOI 50- O~.¢'-- r' Permit number Approval date ~/-'L;'~ ~ n~/n~/~ I SEE COVER LETTER FOR OTHER REQUIREMENTS ~ -/~, e- - ~- by order of the Commission ~[~r,~! 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"' / : .............. :..~ . L:.L~ ......... '~ ....... 'J'~ ..... :~L':. ~.:.LL'~ ::~.:~ ': ~-; ~ .'L_..:.__; .... ......... '400 '- ...... : ..... : ......... _ . ; , ,, , , :.~ .......... ~ ....... ~~~--~-,-~'~- ~-~ . . - ~ - -. ,: , · ~ ~. ~, m~.~ , ' ' ~ t ~ - ~-~--.+.- r-.4 ........ ~.~-~..~ ' ..-. ~..~- -,-.-~.~ '~ '~ - ............. ~ ...... ~-' ~ ' ~ ~ ' ~ ....... ' , ' ' ~ ' ' ' ' L' J .... ~ "' ~ ' ' ' ~ ' ' , ' ' ' ' ' ~ ' i ................ ~ ..... ~ ....... ~--~ .... -~--.~.~--:t, .... T~+---=--~:-~:,- .-, ~.*-.~ : ....... I :.; ..... ~ ,-: ........ , ..... /4 570 ' ! HEREBY CERTIFY THAT I AH PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A'N AS- BUILT SURVEY HADE BY HE, AND THAT ALL DIMENSIONS AND OTHER '. DETAILS ~,RE I;ORRECT, AS OF: AS-BUILT LOCATIONS STATE PLANE LAT & LONg /77/' 12o 13. 14o Y = 5,929,396°43 X = 719,306o30 LAT = '70°12'34o664'' LONG = 148°13'53.162'' ]50 Y = 5,929,5]2o87 X = 719,280o83 LAT = 70ol2~35o816" LONG = 148°13~53.803'' y._. X = LAT = LONG = yLAT LONg 16. Y = X = 5,929o160o99 LAT = 719,356 o 93 ' ~_~,~- ' 70o12,32o335', ~'~ OFA~}~iI~. '.O~G ~ -x~.. ...... .~ ~-~ 148°13'51.892'' ~&~..' ~".~, 5,929,278.37 ~-~ ....... ~.:.. ......... ~,..v 7 o° 12' 3 148°13 ~F2 C~~ 4277-~ ~ ~?.. ', ...'.~-~ NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT-- PRUDHOE BAY i ii i i J i iii iiii i Atlantic'RichfieldComPany <> DATE' 5,929,630.65 7]9,255°58 70°] 2 ' 360982" 148°i3~54.437'' 13_5/8"~jP STACK DIAGRAM Accumulator Capacity Test ANNULAR PREVENTER BL I ND:' RRHS · 2~ e Check and fill accumulator reservoir to proper level ~vith hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. Record on IADC report. (The acceptable lo~er limit is 45 seconds closing time and 1200 psi remaining pressur.e. ) 13-5/8" BOP Stack Test PIPE RRHS DRILL[ SPOOL PIPE RRHS RECEIVED "";:FEB 2 '? ]98! Rlaska 0ii & G~ Cons. Commission Anchorage · . Fill BOP stack and manifold wi th a non- freezing 1 iquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint, Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. 2. Close annular preventer and chokes and bypass valves on manifold. 4.' In each of the following tests, 'first hold a-- 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 5. Increase~pressure to 3000 psi and hold for a " min~m'~o~i 3;~.;minutes. Bleed pressure to zero. 6. open annular preventer and close top set of pipe '-rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 7. Cl'ose valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. 8. Open top 'set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. -.. 10. Bleed pressure to zero. Open bottom set of pipe rams. .. ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least $ mi nutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set_in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of De Gasser. 16. Record test information on Blowout preventer test form. Sign and send to Drilling Super. ,, "'-"~ ..........~ ....... L,J' ...... ' '";"'it" ' ~17, Perform complete BOPE test once . functional operate BOPE daily. CHECK LIST FOR NEW WELL PERMITS Item Approve (1) Fee Date L-L~ 1. Is the permit fee attached .......................................... 2. Is w~ll to be located in a defined pool ............................. 3. Is a registered survey plat attached ................................ No Lease & Well No. f.~ Remarks (2) Loc.//~~ %"~ ~1-~'/ ~. 4. Is well 'located proper distance frcm property line .................. 5. Is well located proper distance frcm other ~lls ................... 6 Is sufficient undedicated acreage available in this pool 7. Is ~11 to be deviated .............................................. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... 10. Does operator have a Bond in force ................................. 11. Is a conser~at±on order needed ................... 12. Is administrative approval needed ...................... ......... 13. Is conductor string provided ................................... 14. Is enough cement used to circulate on conductor and surface ........ (4) Cas~ 2-Z~--~_~ 15. Will c~nent tie in surface and intermediate or production strings ...~ '16 Will cement cover all known productive horizons .................. 17. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst. (5)BOPE ~~Z- ~-~~ 19. Does BOPE have sufficient pressure rating-Test to ~6)o~ psig .~~-~ ~' Approval Receded: - . - Additional Requirements: Z~/~,,~TzS~ d~,/~~ -~~ology: Engin~ring: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Company LIBKARY 7APE CURVE SPECIFICATION5 ARCO ' ALASKA, INC. D.S. 16-13 Field County, State PRUDHOE BAY N. SLOPE, A~ASKA Date 12-10-82 Curve Kame (Abbrev.) Standard Curve Name Logs Used Scale LSN1 Long Spaced Neutron Pass 1 CN/MSN 0 - 1250 SSN1 Short " " " 1 " 0 - 1000 CN1 Compensated Neutron Pass 1 " 60 - 0 GR1 Gamma Ray Pass 1 " 0-100, 100-200 I! CCL1 LSN2 SSN2 CN2 Casing Collar Locator Pass 1 Long Spaced Neutron Pass 2 Short " " " 2 'Compensated Neutron Pass 2 0 - 10 0 - 1250 0 - 1000 60 - 0 · _ -, GR2 Gamma Ray Pass 2 " 0-100, 100-200 CCL2 Casing Collar Locator Pass 2 " 0 - 10 LSN3 Long Spaced Neutron Pass 3 " 0 - 1250 Short " " "3 " 0 - 1000 SSN3 ,, CN3 GR3 CCL3 LSN4 _- SSN4 CN4 Compensated Neutron Pass .3 Gamma Ray Pass 3 Casing Collar Locator Pass 3 Long Spaced Neutron Pass 4 Short " " " 4 Compensated Neutron Pass 4 60 - 0 0-100, 100-200 0 - 10 ,, 0 - 1250 0 - 1000 60 - 0 LIBRARY IAPE CURVE SPECIF1CAT] ON5 Company ARCO --' ALASKA, INC. Well D.S. 16-13 Field County, State PRUDHOE BAY N. SLOPE, ALASKA Date 12-10-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale GR4 CCL4 LSN5 SSN5 CN5 GR5 i CCL5 Gamma Ray Pass 4 CN/MSN 0-100, 100-200 Casing Collar Locator Pass 4 " 0 - 10 Long Spaced Neutron Pass 5 , Shor.t " " " 5 Compensated Neutron Pass 5 Gamma Ray Pass 5 Casing Collar Locator PaSs 5 II 0 _ 1250 · -- '0 - 1000 60 - 0 0-100, 100-200 0 - 10 JAN2 6 Alaska 0ii & ,Sas '"~ uor~s. Col~rr ECc NUMBER 1570,00 ARCO ALASKA INC. D,S, 16-1~ 25 CURVES : GR1 CCL1 cN1 .<;sN1LSNI GR2 CCL2 C~,~2 SSN2 LSN2 GR5 CCL25 CN5 SSN3 i'SN,5 GR~+ GR5 CCL5 CN5 SSN5 LSN5 ...... L.Ex!E..L. SP. AC !.N.$ ........ 0..,.25..0..0 G2, SAM. PLES...PER..RECORD PAGE ARCO ALASKA INC, 0,$. 1G-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 GR2 LSN2 SSN2 CN2 FT. API ~ API ~ CCL2 11690. 0,.0 -2.12,7 -5..50...0 ..... !6,0 8.5 0.0 . 6.3 0.0 1,0 11691, 0,1 -68.8 -215.1 48.0 8.5 0.0 -~18.7 -350.0 33.0 11692, 74,0 3.,0,.1~7,0 ~.8.,.0 8,5 1~7,2-3.0-!~7.7 47,9 11693. 272.8 3.2 -i47.7 48.0 8.5 272.9 -3.3 -147.5 ~8.0 1169~., 272..,.9 ............ ............. 48.,,,0 ........ 8,.,,5 272,6 ,2,8 -147.3 .... 11695. 27.2,,,9 2,,.7.,,.!~7,,,.5 ......... ~.8.,,0 8.5 272.8 -2.8.-!~7.3 .8.~, 5 11597. 272.8 3,.2...-!.~.7..,5 ~8.0 8.5 272.3 -2.8 ,147.7 11.6.~8..? 27.2..-..8 5..,,.0 ....... ~..i~..7..,..5 ................ ~7...,...~ 8.,5 ...... 25.7,! ....... -2.2 -147,5 11699. 272.9 8.1 -135.7 38.0 8.5 251,0 ~.4 -126.5 11'7"0"'6; ~'72,'7 256.5 34~.5 38.4 8.5 1170~, 190.0 356.6 ~48.6 ~7.8 8 5 146,8 ~29.9 3~0,6 .~ ~25.6 321,6 ,7 ,6 11710, 189.8 8 ....~ 0....2 ..................... 8 - 5 9 ~5.3 8,5 11714, 186.5 11716. 186,0 ~88,1 515,5 55.3 8.5 178,7 ~85.1 575.5 55.5 8.5 ............. i ":" :¥ ~1718, 182,~ 398,0 57~,3 35,8 8,5 165~7 ~50,8 11720. 175.2 372.9 356.4 38.0 8.5 1~8.3 353.1 3~6.2 38..0.. ~ ....~. 11722, 157,7 362,2 3~7,6 56,9 8.5 141,2 ~53,1 3q. 2,1 38,4 8,5 1172~, 145,7 359,4 5~1.9 36,3 8m 5 150,4 3~7.8 339,8 37 8 11.726. 1~4.7 356.9 33~.3 35.9 8.5 186.2 339.6 341,1 38.8 8.5 11730, 191,8 556.3 3~6,6 38,6 8,5 198,2 373.6 373,0 37 8 PAGE 2 ARCO ALASKA INC. o.s. 1~-13 DEPTH FT. GR1 LsN1 SSN1 API CCL1 GR2 LSN2 SSN2 CN2 CCL2 API ~ 11741. 230,.~3G.7.8 349°3 37.2 8.5 271.9 337.6 547.4 ~0.3 8.5 1174.2, 2~77..3 36.8,3 5.5.9,1 8,5 267,2 ~33,5 337,~ 40,1 n..5 375,7 360.5 3G...g 8.5 265,2 ~30.7 335.3 !,,17~,~- 272,..8 ........ 35~.,.8 3,6.,..! 8,.5 259-! ~25.,1 33,5.! ~2,.2 8,5 117,~5, 27,0,,2 3.66'5 3~&.2 36'8 8,5 2~1.2 325.6 338.q 8,5 !1.1.~., 2..65..~..8 3.6.3.,? ............ 3.~..3...,.5 37..,~ 8.,5 2~.2,.7 336,8 3~2,5 3.9,6 8.5. !!7.~7., 2...5.?..~1 ....... 3.5.1~.,~,.? 3~i.~.,5~ 39.,! 8-5 229,3 3~3,1 33.4 ~ 5 Z.!7..~..8., ......... 2,~,5..,...0 ~..55~,...6 35.0...,...~ 39..,.0 8,5 232,8 ~0,3 3~,...6 8.5 11754. 209,7 361,2 11756. 208, 117S~. 138. 11760. 185, 11762. 171, 11766. 159.8 380,8 11768, 173,2 380.8 11770. 17~.9 37~.2 ~+ 355..,~G. 36..,.,~ 8,..5 36~.~ 35.8 8.5 179.7 378.4 377.6 36~.6 37.2 8.5 173.5 ~8~.8 390.9 369.1 36.8 8.5 170,7 37~.3 351.1 11776, 147,8 373. B 36q*. q* 11777' 35.7 8.5 lq'7.3 ~13.1 396 'G PAGE 3 ARCO ALASKA INC. D.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 FT. API ~ CCL1 GR2 LSN2 SSN2 CN2 API ~ CCL2 11790, 180,6 368,1 350,1. 36,5 11791, 169,0 369.9 3~7,0 38,0 11792, 155,9 361.7 3~6,~ 38.3 11793. 15G,7 358,9 351,5 36.~ 1179~, 155,0 36~,8 3~9,3 36.1 11795, 150,9 362.7 338,2 36,5 11796, 1~,2 359,4 334,3 36,~ 11797, 138,7 357,~ 339,~ 36,5 11798, 137,0 365.7 3~3,3 36,3 11799, 157,0 365,8 3q9.3 36.7 8,5 162,5 359,3 3~3,7 35,8 8,5 158,8 365.9 3~0,2 33,9 8,5 15~,0 365.9 33~.7 3~,0 8.5 1~8.2 361.3 335.9 36,2 8.5 1~0,9 352,4 3~1,1 37,3 8.5 1~0,0 351.~ 3~6,~ 38,1 8,5 !~1.,~ 359.0 355,0 37,.1 8.5 139,3 372.3 366,5 36,5 8.5 137.3 379.2 369.6 36.,.3 8.5 137,3 368.7 361,A 37.5 11801. 131.3 373,~ ..... 359.,~ 35,3 8.5 151.3 358.8 353....7 38.6 11802. 3. 33.8 378.3 35..e,..,..,,..~ .................... _As_.,..~.~....,....5. ............ i.~..P..,....8 .~.T...~.,...6 ............ 3..~._9,.0 ........... ~.7....~ 11803, 1~0,1 371,1 3~7,~ 35,9 8,5 167,9 387,~ 387,0 3.7. ,..[ 8.5 ~.5 8.5 R.5 ~.5 ~...5 ~.5 ~.5 ~I ~5, 11810. 187.6 i"~ 8'ii ~ i'~:~:',"~ 11812. ~50.2: 1181~. 152.5 ...... : 11816. 189.1 · .0:379,0 33.8 8.5: 3~,S 8 192,9 ~53-0 ~10,7 37~.3 37,9 8,5 187,7 ~23,5 1182~, 196.1 357.1 351.9 39.7 8.5 192.3 .~62.6 371 9 39 ~ 11832. 178.8 ~07.7 ~09.9 35.3 8.5 17L~.~ 381.7 365,8 36.5 8.5 - .................................. ,: .................................. ,,,-,,.,,,.~-,:.,: ......................................... ~-.,,,-:?,,~.: ~,--.~-, :,:,~ ?": '"",'~ ?":"'"' ?-' .................... ' ............. ~"'~' "~T"Ti ..... ~,8..3.3, !.. 2,~,0 !,7. :~!0 3:3 : . !.70 .~56::,',: ~: 38 : ' 5 I~837' 170'0 363'7 3~3'7 37'6 11838. 168.~ 358.1 3~1.1 37.~ 11839. 165.8 3 3~1'3 37-6 8.5 8, 5 I76,2 ..... 35! ,6 336,0 37 PAGE ARCO ALASKA INC. D.S. 16-13 DEPTH GR1 LSN1 SSN1 FT, API CN1 CCL1 GR2 LSN2 · API SSN2 CN2 CCL2 11840. 165.9 ~D.9.7341.1 11841. 166,7 354.8 340.2 11842..171,3 362.,2 . 335.9 11843. 178.3 360.9 338.6 11845. 202.3 353.0 3~5.0 37,1 35.7 37.6 38.6 38.4 38.9 8,5 181,9 ~45,0 8.5 188.5 ~39.6 8.5 201.8 ~44.0 8.5 215.3 346.5 8,5 221.4. ~52,1 8,5 218.9 ~59.5 335,9 38.7 8,5 332.2 38.6 8,.5 331.6 38,3 8,.5 337.1 38.4 8.5 342.9 38,1 8.5 349.3 36.9 8,5 346.6 37,1 8.5 351,.7 39,3 8,5 356.6 38,3 8,5 11850, 225,9 368.6 353.2 39,2 8.5 21~,_6 ..... ~67.,.7 ~.~2,5 57.,~ 11852, 218,6 363,7 363.2 ........... ............. 11854. 207.6 380.1 377.8 37.2 8.5 17 5.,.,~ ........... 3.,~.,8.,,., O. 37.6..,.,3 .... 3,8,~ . ,,,,,,..,,,,,..,,, ~68-7.: .,~g~,, ~ 38,5 11,856. 188.0 5 37.~ 8 11864. 254. 11866. 192.9 387.5 388.4 36.& 8.5 143.1 ~68.0 352.8 36.8 8.5 11868, 156,9 378,5 361.6 36.0 8.5 137,5 ~64.9 347.9 36.3 8.5 11870. 143.4 385.2 367.1 36.~ 8.5 132.0 555,2 346.3 37.6 a.5 11872. 131.6 373.7 357.5 39.2 8.5 125.4 358.0 342,0 37.7 8.5 11876. 128,1 365.5 355.2 36.3 8,5 97.5 580.0 369.5 56.5 8.5 PAGE 5 ARCO D.S. ALASKA INC. 16-15 DEPTH GRZ LSN1 SSN1 CN1 CCL1 GR2 LSN2 SSN2 CN2 CCL2 FT, API ~ API ~ 11891. 131.9 367.G373.0 38.1 8.5 109.7 363.9 36~.6 37.9 .... 11892, !21,2 3.6.7,6. 3.62,~ 38~,..2 8.5 110.2 . ~92.2 3.8~,8 35.8 11893, 108,5 365~5 37...4 8.5 124.9 420.3 40,3.5 3~.0 8.5 ....... 3.~.6.,.0 ~7,2..,~ ......... 35.,,.& 8,5 126,.0 ~2,~..6 ~.06,.? 33.8 ~8.5 1!895., 9.8,.~ ........ ~,03,! 8,5 ieo,e ~!0.3 385,~ 3~..,.1 1~,8,9,7, ~.2~,3 33.,7 !8,5 89,,o ~3!,0 ~05.2 32,,5 8,5 1190~. ~2,9 702.3 582,6 23.2 8.5 68.9 &55.7 561 A 11906. 56. 11908, 76,11 25 2 8.5 11912. ~0, S 1191g. 38, 11916. 46.8 657.6 560.4 24.7 8.5 77.2 &SS 0 553 6 25 0 ~ 11918, 58,9 6~4,3 558,% 2%.7 8,5 50,1 &3l % 554~ $ 24 a 1192~. 45,2 716.6 582.8 22.2 8.5 44.q. ATO 0 579 1 2 2 R 11950, 38.6 670,9 572.7 23.7 8.5 39.3 &57 0 570.3 PAGE ARCO ALASKA INC. D,S. 16-15 DEPTH GR! LSN1 SsN1 CN1 CCL1 GR2 LSN2 FT, API ~l API SSN2 CN2 CCL2 119,!, 59..1 708..7 580.7 23,.8 8.5 85.0 598,2 515,5 25.7 1.19~2., 76,?3 67.7,..~ 5,65~,~ 2.,~_..3 S.5 83.i sS,O.O ~8!.5 27..,7 ~..,.5 119,~,5. 88-6 6~5,5 5~.,6 25'0 8,5 81,5 515.3~6.5.0 28'~ ~.,5 1[~57 837.! ...... 562,.~ ~7,2'9 25,,7 ...... 8,5 ?8,2 507,.~ ~.,8 28,3 8.5 1~6... 8!,,..,5 5~8..6 _,~6!.2 ~26,2 ................... 8..,,5 6!.,6 ~,9.6,,.,6 ........... ~,~.8,,,9 29~,~ .... ....... [,[.9,~7, 80.,..,,.6 ........... 5.,~.~,.8,.,,.;~i,5,:~?,,~.., 8-5 ~.01,..o ~55.~ 28-,,0, 1195~. 88.0 50~.9 ~6.8 27.1 8.5 92.~ 530.8 ~68 6 2t 5 8 11956. 89, ~ 90. 11960. 69. 11962. 65. 1196~. 11966. 11968. 8 25 6 93.1 597.6 ~83.1 26.6 8.5 91.3 508.6 ~g3.8 27.5 93,6 520.5 g~7.7 26.2 8.5 97,2 ~89.5 ~26.1 28 ~ 11972. 1197~. 97.5 461.8 ~09.1 32.0 8.5 98.5 ~56.~ 398.5 97'5 ~5.2 596.2 31.~ 8.5 95.2 ~17'.7 38~.5 PAGE 7 ARCo ALASKA INC. D,S. 16-15 DEPTH GR1 LSN1 SSN! CN1 CCL1 GR2 LSN2 SSN2 CN2 CCL2 FT, API · API ~ 11990. 98.4 ~90.,i 42.9.,.~ 27,3 8.5 74.5 ~47.4 496.5 26.7 11991. 97.8 505.2 437.0 27.8 8.5 65.~ &18.2 561.~ 25.1 11992. 91,7 5!8.7 455.5 2.5.8. 8,5 58.9 700,4 608.2 22..~ 11993. 77,6 555.7 491.5 23.7 8.3 57.5 741.0 620.3 21.6 761.6 6.25,,~ 21,0 11,99.5,· 59.,.9 7.,36,.0 ...... 6,2,..1.,,9 20...! 8,5 53,2 .76~..5 622,3 20.,6 11997, ........5~.?,9 8.0.3,..! ....... 6.30,,,,,9 ........ 20...,..,3 8.5 55.5 748.4 610.0 21.7 1!9,9,8, ........... 5,8,~,.9 ........ 7.9.,~,.,~ .......... 62.,$.,..! ............... 20.,a. 8.5 5~.0 719,8 60,~.,.5 22,7 11999, ....... 6~..,i~ 7,75.,8 .....6.25.,...6 21,9 8.5 57.7 711.9 604.5 22.7 12000. 68.6 756.7 614.5 21.9 8.5 68.9 7~6,.,,.,.~ 12002. 55.4 718,4 597.9 22.9 8,5 97,9 765.6 12..00.,5,- 65.6 74.0 765.~ 61.0,,,~ 22.8 8.5 !.eO~,06 · 6 12007, 19.6 8.5 12008. 70.7 12010. 7..'3,9 0 25,5 ....................... 8..5 1201~. 43. 12018. 37.3 681.9 570.0 23.1 8.5 41.3 ¢-,99.5 :579.7 12026. 47.5 722.5 594.0 21.2 8.5 94.0 74~.4 569.9 20.5 8.5 12030. 98.2 652.0 502.0 23.8 8.5 88.0 .~48.*+ 452.4 ............................ ~.,~.~.5,.,~. PAGE 8 ARCO ALASKA INC. O.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 FT. AP! · GR2 LSN2 SSN2 API CN2 CCL2 12040. 61,3 .7!2,0 594,8 22.~ 8,5 12041. 64.1 715.8 598.3 21.2 8.5 12042,. 68,6.. 720,4 582,! 21,~. 8.5 12043. 69.1 699.7 565.0 21.6 8.2 !.2044, 69..2,.3 562,.0 2.2,6 8.5 1204.5, 66,2 697.2 579.6 21,3 8.5 1204~6.... 57.,5 740.! 6!7,.! ...... !9,6 8,5 12047, 47,9 8:1.9,7 637,8 17,9 8,5 12o~8., 35..,.98.47..6 656.8 18. o 8.5 69.1 743.1 585,1 68,9 738.7 580.7 59.7 737.8 580,6 50,7 763.9 590.1 ~3.3 812.5 . 6!9,3 39.3 858.8 642,3 36,4 ~72,5 648,8 34.,8 a65.5 64.6.7 35,0 R55,2 642,7 1204.9, 32,2. 873.1 6:54.,5 18,7 8,5 33,0 R47.4 648,0 !_~..0...5..0........, ................. 3.2_~._.!. 8~8..~ ............ 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D,S. 16-15 DEPTH GR1 LSN1 SSN1 CN1 CCL1 GR2 FT, API · API LSN2 SSN2 CN2 CCL2 % 12090. $~.8 682.4 557.5 23.6 8.5 ~2.0 12091, 55,7 671.5 548.3 2~.~ 8.5 45.7 12092, 56.9 677.0 556.~ 2~.5 8.5 ~2.~ . . 12095, 58.7 696.3 579.0 22.9 8.5 1~09.~. ~3..0 71~..,6 5~2.,,6 2!.9 8.5 50.0 12095. ~0.0 731,0 59~,1 2~.5 8.5 55.8 .............................. 12096. ~2.8 7~0.7 610,8 21.! 8.5 64.5 .............................................................................................................................................. 12097, ~7,8 751.7 631.0 20,1 8,5 68.1 ............................... 12098. 56.1 773.1 637.1 20.2 8.5 39.1 .................................... 12099, ~8,8 788,2 627.1 20.2 8.5 $8o! 716.6 604,9 23.6 8.5 760.5 626.2 24.6 8.5 758.0 649.2 26.3 A.5 78~.0 689.2 22,9 A.1 822.8 662,5 21.9 ~.5 R58.6 659.8 21,5 862.6 663.1 21.1 8.5 ~61.6 655.5 20,1 7.9 ~6~.5 648,6 20,2 ~67.5 659.6 20.2 ~.~ 19.102. 38.5 773.8 63~.8 19.P, 8.5 38,1 P, 75.1 12104. 41.3 L !2 12106. 38.7 12108. 39. ................... ~,i ~ 12110. qO.2 1211 e 12114 779.0 6~0.0 20.3 8.5 .2 20.5 8.5 40.2 ~27.I 658,6 20,8 ~.2 659.8 20,5 20.6 ~..5 6 2!.2 ~,5 2..0..~ ..... 9 21 1 A 12116, ~0.3 756.3 616.2 20.7 8.5 39.6 759.5 615,6 20.7 8.5 12118, 58,4 771.7 620.3 21.~ 8.5 ~0.7 767.0 618,8 21 12120, qO,1 747.0 612.4 22,1 8.5 42,0 781.3 62~.6 20 12122, ~1,2 752.1 621.5 21.2 8.5 ~0.2 773 3 607 2 20 1 R 1212~. ~1.8 755,9 61~.1 21,3 8,5 ~0,9 747.9 588.5 20,7 767.6 ~,.:l..~...,..3 ........... 20.D 8.5 PAGE lO ARCO ALASKA INC. D.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 FT, API ~ GR2 LSN2 SSN2 CN2 API CCL2 12140. 42,4 709,7 589.9 25,5 8.5 12141. 40.1 680.1 557.5 12142. 40.4 646,1 542.0 24.5 8.5 12145. 40.9 641.0 544.0 2~.~ 8.5 121_4~.%2,2 6.~2.,..6 5~.6.,9 2..~.8 8.5 12145. 40.4 644.1 547.7 25.0 8.5 ............... .......... !2!_46, ~.2.,0 65.5,! ...... 5.~9.~8 ........... 12147. 42.9 636.2 548.7 24.6 12,!.~.8, q..~.,,O ....... 6.~,Y_-,,2 ........ 5~,6,_9 25,5 12149. 50,7 6.~6,..7 55.0.8 25,2 12150. 60.8 6~1.5 552.4 24.7 59.8 A60,7 545,9 22.9 40.0 A65.1 5~7,9 25.1 40.1 ~57.9 5~9.5 25,2 59.0 &59.1 550,2 22.7 40.6 &65.2 550.2. .22.7 44.1 R65.0 550.2 22,7 8.5 ~7.,~ &67.4 551.2 25,2 8.5 55.8 ~62.1 555.2 2~.0 8,5 50.4 A51.9 556.1 2~,5 8,5 48,9 ~7.9 556.5 25.5 8,5 45.6 R46.7 555,~ ............. 2,6..~ R.5 8.5 8.5 ~. 5 ~.5 a.& 5 R.~.5 ~ 1 5 ~.5 1~152. 44.1 646.1 554.7 24.q. 12154, 45.5 652.5 558.0 25.~ 8.5 12160. ~8.4 12170. 47.9 606.2 549.8 24.4 8.5 ~4.6 ~56.3 556.2 25,7 8.5 12174, 76.5 616.2 557.9 21,1 8.5 44.4 688.6 556.9 20 0 8 1P..188, 18.7 586.1 457.1 2.~.,.,2 .......... 8,.,,5 ....... 36.,,8 ........ 5,1,9,.1 ~,.~.7.,.5 ....... 26.,.6 .................. 8........5 ....... PAGE 11 ARCO ALASKA INC. O.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 $R2 FT. AP! · API LSN2 SSN2 CN2 CCL2 z219o. 39.0 5~.9..7 ~.33,5. 24,~ 8.5 34.1 12191. 38.7 543.5 431.5 25.4 8.5 34.4 12192. .37.9 526.0 .430.2 25.9. 8.5 3~.2 12193. 36.2 515.B 423.7 25.5 8.5 32.0 .12!.9~., 5~..,.! ...... 5.0..8..~! ~.~..5 ........ 2.5,.! 8.,5 12195. 33.6 505.6 411.0 24.9 8.5 32.6 510.2 505.6 507.9 50B,9 497.7 485.9 12197, .... 53,8 .....508.1 ~+11.0 25.5 8.5 33.6 ~84.9 .......... 1.e.!.78., 3.3.,.9 .......... 5.0..3..?..2 ............ ~.i2_.?..~ 2.~.,.0 8, 5 ......... 3.5, ~ ~8.5, 7 121cj9, ~5'4 5:05,0 ~13.8 27,1 8,5 56,4 ~84,9 393.7 430.6 26.0 8.5 421.4 25.5 421.8 25,6 R.5 421.6 25.6 ~.1 415,3 26.2 408.5 27.0 8,5 ~.0.6,3 26.,..6 a~.5. 402.2 25.6 ~.5 395,6 25..5 8._5 25.1 8.5 12202. 55.2 487.6 424.9 26.9 5.7 34.6 485.4 12204. 33.2 12206. 32.0 12210. 34.6 510.8 432.1 25.~ 8.5 35.0 ~97 25,0 ~.5 26...~ .......................... 8....._5.... 26, 9 8,5 12212. 36. 12214, 12216, 39,1 12218. 48.8 480.9 40~.5 27.0 8.5 65.7 48'5.9 486.5 405.~ 25.~ 8.5 99 6 ~5618 398 3 8 377 8 12222. 96,1 12224. 9~,0 459.0 368.9 27.2 8, 5 93.5 463 4 4t~1'~ 362.4 27.0 8 5 95 0 461 7 38O 399, 25 7 PAGE ARCO ALASKA INC. 0.S. 16-13 DEPTH FT, API LSN1 SSN1 CN1 CCLZ GR2 LSN2 SSN2 ~ API CN2 CCL2 12242, 51,7 5.6~,7 _~50,3 22,9 8.5 35,0~80.9 12243. 32.2 577.2 ~5~.6 23,6 8.,5 5~,6 597.7 476.6 21.9 8.5 !2,2~.~.? ~.5.,.,.8 5.67..,..0 ~,55..,.5 2.2,.? 8,5 33,1 61.5.6 4,89,.5 22.1 8,5 122~5. 3~.9 573.4 461'6 22.0 8,5 33,6 605.6 487.6 22..8 8,5 .............................................................................................. 12248. 31.0 628.5 ~86.8 21.0 8.5 3~.2 &~l.O g80,.1 .... 21.,1 ................ 8..,...5 ...... !2.2.~,9' ..~2'7. i,,,,~i8,~,:~:.~ 2:.!.:.'!.. 8'5 ~,:,~,3 ~20.7 ~81.5 ' 21'2 12254, 1225&, 12258. 12260, 12262. 1226~. 33.5 611.1 482.9 20.8 8 5 36.3 S80 37, 4 471.0 22.6 8 5 1 459 8 5 48, 77,2 81, ~ 25 12280. 8i.7 420.9 337.8 2~.9 8.4 84.8 ~!,~.,7 ........ 3'$'g";'9 ............... e'.4 8.5 77.1 ~32.,3 26,..,,3. i~'2'"~', ~"~;'6 ........... 403.8 5'3'4'7 28.9 8.5 67.~ ~35.6 3~6.0 26,...0 383 . 1. 26,. 2 8., 5 380.,..2 26..,.0 .......... 8.., 5 376 . 7 25 ,..7 8.5 PAGE 13 ARCO ALASKA INC. D.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 FT. API ~ GR2 LSN2 SSN2 CN2 CCL2 APl 12290. 4o.1 ~78,4 3.8!,9 26.0 8.5 12291, 40,0 469.4 382,9 26.1 8,5 12292. .... 59~2 474.8 38~.3_ 25.3 8.5 12293. 39.8 476,1. 382.1 25.8 8.5 1229~., 43..~ ......... ~.73.,,0 .... 375.,.,1 25.7 8.5 12295, ~8,-.5 ~.65,,~6 .~72...~ 25,.,! 8,.5 .............. !.229,6,., ............ 57.?.8 ~..6.5,,,..~ ~.69..,~ ............... 2~.,.9 8.5 12,,297, 67~2 4.66,,..~. 362.0 24.7 8.5 12298.- ...... 6.~,~,.2 .......... ~.62,.5 35.9.,_9 ........2~,9 .8.5 12299. 61~ ~67,.~ $6.6~,7 2~,7 8.5 42.8 ~67.5 377.1 25.8 4~.5 ~62.2 375.3 25.6 8.5 50.0 ~60.1 370.8 25,7 ~,5 56.6 ~57.6 371.0 26.2 ~.5 61.3 450.9 366..3 26.2 8,5 6~,3 4~9.4 365.7 26.5 8,5 63,0 .~55..5 37~,0 25,.~ 59.~ 476.7 $82.5 2~,7 ~,,5 57.,. 1 4.76., 5 ;379,.0 ..... 25.5 8,.5 5,5.7 q. 72.1 389.6 26,,.,~ 8.5 12300. 58.5 481.7 374.9 25.5 8.5 50,7 ~85,9 ~0~,5., 25.,5 ............. 8 ....... 5 .......... 12302. 5~.5 ~72.8 ~78.4 25,G 8,5 ~8,5 ~9~.3 ............. ~..~,.0...,,6 .................. 2.6..,,~ ......................... 8,,5. ~2~0~. *~.5 50~.9 ~10.8 2~.~ 8.5 ~.~1 ~78.,.5 ........... ~,!!,,0 ............. 27..0 8.,.2 12310. 48.3 12312. 72.5 ............................... i'~'~'~'~"; ............ : ......... 1~"~i-~"; ................................. 6 ........ 8,5 42.8 2 406.0 25.8 8 5 ~9~. 1 417.5 2,5-6 q. 2.~.,~,.,4;... ..................... .25,8 ............ 8..,5 .8 24,5 ~. 5 !.9. ........... 2,.~..2 8,5 .9 24-2 8 ~.5 ...2. 23.. 0 ..~ .............. .2_~.,..~ 8,5 22-7 12318. 55.5 513.9 419,2 26.3 8 5 q. 1,8 525 0 437 12322. 49.6 55~.5 448.7 23 8 8 5 41.2 ~19, 9 439 9 25,9 R, 12324. 49.8 545.5 440.3 24.3 8.5 39.2 532.9 439 5 ~, 12326. 34.1 556.0 447.7 24.7 8.5 52.8 540.5 440.5 24.4 8.5 12330. 63.6 539.~ 425.7 .....'"~ i~-:~:i"~~ '; 24.1 8.5 87.6 477.7 366.7 24 P, 8 4~7'6 ~ ~'5 12336. 81.9 381.9 306.6 30.6 8.5 84.3 371,8 303,.,~ 28,,,5..~,~ ........ P~.,5 PAGE ARCO ALASKA INC, O,S. 16-15 DEPTH GR1 LSN1 SSN1 CN1 CCL1 GR2 LSN2 SSN2 FT, API ~ API CN2 CCL2 125~.0, .7.7.,5 37~.~ . 308.! 27.6 ~ 8.5 82.7 ~5~.5 371.2 123~1. 76.5 395.1 322.~ 26.~ 8.5 88.5 ~62.9 363.0 123~2. 74,1 ~31,1 3~3.5 2~.G 8.5 87.1 ~0.5 352.1 , 125~3. 76.2 ~62.5 368.7 2~.8 8.5 8X,~ ~29.7 352.3 .123,.~.~, 83.,,0 ~72..,,5 ...... 36.1,,...8 2,.6.~ 8.5 7.2,8 ~..~.0,5 365.0 123~5. 85....8 ~8.,.5 ......~52.,5 ............ 2..7,4 8,5 6.3.~ .456.3. 3.92,7 ..................... ~..2~.~.~, 8.,!..,..~ ........ ~.~.6.72 ............ 350~.9 .............. 27_~..~ 8.,.5 55,! ~97,7. 173,,~,7, 70,.7 ~,~:,!.,,~ ~63,,2 26.~ 8.5 52.7 5~8.2 .................. ~2,~8..- 6.2.~.~ ~..59.,7 58.~_.,.3 25.2 8.5 51.7 ~52.8 !2,3~,9:, 56,! ~5,0. ~08.,3 8.5 53.7 5~$.6 ~30.9 25.3 ~.5 25.3 ~.5 26.8 8.5 27.0 8.5 27.6 8.5 2.7o~ 8,5 25,7 ~.5 22,6 8.5 23,0 8.5 23.7 ~.5 12352. 52.5 535.6 ~31.5 25.8 7.9 65,0 .~22.7 ~$6.5 25.3 1~5~, 62,9 517.~ 1~35~, 61, ~33.1 25.7 8.5 5~. ~ 526 ..0 ...... ~,3,8 · ~ 25, ~ .............. 8..,.. 5 ,0 25. ~ ~, 5 25.8 ~,..5 26.0 8.~ 26.5 8.,,5 ~ 9 ~ ..5 12360. ~2.3 8 26,7 ................. ~,5 12 5 26.'. 5 ~...,..~: 12~62. ~5. 1256%. 5~. 12370. 8~.1 522.5 %22,0 25.8 8.2 76.1 52~.5 %~2.7 25~ a, 5 12372. 79,7 52~.8 ~36.~ 25.3 8.5 83.9 558.~ 460,6 2~.5 8.2 1237~. 79.5 5~9.1 ~56.5 2q.1 7.1 93.6 ~23.2 ~6.~ 25 9 8 12380. 98.0 505.% %18.6 27.2 8.~ 93.1 ~28.2 371.2 30,1 PAGE 15 ARCO ALASKA INC. D.S. 16-13 DEPTH GR1 LSN1 SSN1 CN1 CCL1 GR2 FT, AP1 · API LSN2 SSN2 CN2 CCL2 12590. 86.9 %%2.6 372.2 29.0 7.9 86.2 12391. 88.6 %31.9 366.9 27.3 8.5 89.6 12392. 89.1 443.4, 373.7 24.& 8.5 94.4 12593. 90.3 471.7 380.~ 20.& 8.5 96.2 12394,. 92.9 51.?,4 1~.5 8.5 9?.7 12595. 93.0 596.5 ~14.7 24.2 8.5 102.5 12597. 91.1 502.4. %03.0 24,.8 8.5 111.9 le,~,9,~.? 9.0..~.8 ~.0..!.,,..~ ~.0.~.,_8 ,2.~. 8,, 5 i 15. o 12599. 92.8 507.5 404.6 25.2 8.5 13.7.4 397.8 346.2 30,1 8.5 ~07.5 345.2 28.5 8.5 ~20.5 354.0 28.1 ~37.9 ~69.1 27,% ~66,8 392.7 25,5 3,5 ~94.6 398.1 24,8 a,5 ~94.1 399.7 2~,9 8.5 ~90.8 40~,0 25,7 ~.,5 ~87,7 ~06,5 26,4 S,.5 ~92.3 410.4 24.9 i2401. 96.,2 %94.2 ~06'5 .... ;2.7.,8 .... 8,5 1!9,5 529,8 ~.t~,.2,1 25,.0 8..5 .............................. .!_..2.4,.0.2..: ....................... 96...~.~ .................. ~ 92...,....7.. ............ ~_!..3...~_2 2..9..~...9 ........... 8 ,...5 ......... ! !8..,6.. 575._,. 5 ~.91......~ 2.~.....~ 8.5 12403. 96 ,T ~86.0 ~_~.7,.8 30 · ~ 8,,5 1!7,,9 ~,1,2,,,8 507 8, 5 97.2 511.5 478.4 29.2 .7 26.q' 8-5 119.4 ~,06.7 465.9 2:0'9 ~.5 456 2!,,0 8_....5 21...1 R. 5 ..8 .......... 2!..,.! ........ 8... ~8 ....... .21.,.6 ...... 8,5 LO ........ 21...,.6 6 22,1 12%1%, '0 124,18. '0,~ 3,2 -1~7.7 %8.0 8.5 120.0 589.1 4,56 5 6 B 12%22. -0.4 3.2 -147.9 48.0 12%2%. -0.4 3.2 -147.5 ~8.0 8.5 10~.7 575,8 457 ~ 22 al 8.5 -0.4 575 5 459 5 ~ 12430. '0,~ -277.5 '382.2 12 O' 45,0 8.5 -0,~ 281.1 6 12438. 0.0 0.0 0.0 0.0 0.0 '0.2 -3,5 -147,'7 .... ~8,0 ...... ARCO ALASKA O.s. INC, PAGE 16 DEPTH GR1 LSN1 SSN1 CN1 FT, API · CCL1 GR2 LSN2 SSN2 CN2 CCL2 API -0.2 -2.a .1~7.:5 ECC N'UMBER 1570.00 ARCO ALASKA INC, D,S. 16-15 25 CURVES : GR1 CCL1 CN1 SSN1 LSN1 GR2 CCL2 Cr~t2 $SN2 LSN2 OR5 CCL5 CN5 SSN5 i SN5 GR~ GR5 CCL5 CN5 SSN5 LSN5 FRoM 11690,00 TO 12~0,00 LEVEL SPACING 0,2500 62. SAMPLES PER RECORD · PAGE I ARCO ALASKA INC. O.S. 16-15 DEPTH FT, GR5 LSN3 SSN$ CN3 CCL3 GR4 LSN4 SSN4 CN4 CCL4 GR5 LSN5 RSN5 CN5 AP1 % API ~ AP1 ~ 218.7-350.0 18, 8.5 O. 0.0 0,0 0I 11971. O. 0.0 0,0 O, 0,0 0..- 11972. O' 0.0 0.0 O. 0.0 98..-3.3-147.7 48. 8.5 O. 0,0 0.0 O. 11973, 0.. 0,0 0,.0 O. 0.0 95.. -3,0-147.5 48. 8.5 O, 0,0 0.0 O. 1197.~.~ O, 0.,0 O,.O 0., O~.O 95. 8,5 O, 0.,0 0.,.0 0 11~75, O, 0~.0 0,.0 0,, 0,,0 9~i. ,2,8,147,5 ~8, 8,5 O, 0.,0 0,,0 O, i.i.~.76.? 0., 0.,..0 0..~..0 ~..,0.,..09~..~ 8,5 0.., 0....0 0., 0,.0 0.,.0 0.,..0,.0 971. 8.5 o, 11978. O. 0.0 0.0 O, 0.0 %00~ -2.8-147,5 qB. 8,5 O, 0,0 0 11979. O, 0'0 0'0 O, 0,0 9B~ '2,5-I45'4 48, 8,5 O, : 0,,0 0,,,,0 0 119B4.. O. 11986. O. 11988, O, 0.0 0,0 O. 0.0 88. 48&.2 4.48.9 30. 8.5 O. 0,,,~ '5 0 0.0 0 0 0 0 0 11990. O. -7 i ' 11992. 27, -5.0 .1 .... 3 4B 11994. 3 2-'152..~ ~8 11996. 60, -8.8-152.7 48. 8.5 71. 770.6 626.2 20. 8.5 68. 3.2-152.7 48 12000. 78. 263.9 586.1 31. 8.5 61. 671.3 584.0 2~. 8.5 82. 504.9 ~B1.2 22 12002. 60. 692.8 590.9 23. B.5 59. 74~.5 628.9 2~. B.5 96. 7~9.0 ~23.~ 22 12012. 73. 712.0 552.7 22. 8,5 5~, 646.0 587.1 25. 8.5 ARCO ALASKA O.S. 16-15 INC. PAGE 2 DEPTH GR3 LSN3 SSN3 CN5 CCL3 GR~ LSN~ SSN~ CN4 CCL4 GR5 LSN5 ~SN5 .CN5 FT· AP1 % API ~ API ~ 12021. ffl. 686.2 586.4 23. 8.5 ~7. 662.6 559.6 2~. 8,5 50. 677.0 ~50.! 12022. 4~. 680.,5.57.7.1 23, 8.5 661.8 551.0 P2. 8.5 50. ~72.9 ~.R 23, 12025. 42, 696.9 555,2 21, 8.5 ~7. 678.9 569.2 ~p. 7.0 51. 1202~. ~5,., 72~,,,..,257~,5,..,.20., 8.5 57, 724,,6 ~7.5.,0 21. 90.~ 8.,5 6~,, 728.1 12026., 58, 8,.5 8~. 749.9. 604.1 2~. B.,5 7.16..~ .5~.~ 1~027., 5~., ?~,.4 5.74,8 ~o, 8,5 99, 1.20.28. ..... 7.6.., ...... ~6~..5 .... 8,5 ZoO- 570,~ 12054. 98. 120~5'9~' 12036. 97. 120:37' 506.7 ~50.5 29. 9 8 26 8.5 90. 595 12040. 63. 68 12044. 80. 6 8.5 109. 60 726.5 ~75.5..21 !_,.,,,W ....... ~96,~ 20 120~6. 52. 697.2 579.6 22. 8.5 50- 82~.q. 64~.7 1.9. 8.5 55. 820,7 12048. ~. 819.7 657.8 19. 8.5 ~6. 821.6 627,0 18. 8.5 56. .................. i'~'"6~"~'; ................... ~"; ........... ~"~'~'"ig"'"'"'g'~"~'T¥'i'd"; ............... a'T~~' ................ '~"~ ............. 8'25 ....... 5'~. 12050. ~5. 815.6 621.0 18. 8.5 ~8. 778.2 618.2 20. 6.5 57. 819.2 ~2'0~"~9 12052. ~2. 810.3 656.5 20. 8.5 ~9. 885.7 690.6 18. 8.5 67. 865.2 ~82.5 19 12054. 49. 880.7 680.3 18. 8.5 114~ 804.8 625.4 19. 8.5 !29. 826.9 A52.7 ~0 12056. 159. 802.6 624.3 19. 8"*"'~"2~3~'~ 791.~ 6~6.~ 20. 8.5 273. 794.~ ~51.~ 20 ...................... i" o57'-; ....... ..... ....... 12058. 257. 802.6 646.~ 20. 8.5 ~8. 78~.1 638.5 PO. 8.5 6~. 79~.~ ~29.6 20 12060. 36. 790.1 633.1 20. 8.5 38. 780.5 627.0 20. 8.5 ~7. 776.3 ~27.0 ~,..: -..,. 120~6, ~0~,. 703.~05..e.6~.~ 22, 8,5 ~.5;.. 6.~7.z 8,5 ~9., 705.,3 ~6.7,,3 22 zao~7, 55. eez.9 5vo,~ am. 8,5 ~' s~v,e 557.~ ~. 8,5 52., ~7~:.,~ ~50,,m PAGE ARCO ALASKA INC, D.S. 16-13 DEPTH FT, GR3 LSN3 SSN5 CN3 CCL3 GRL~ LSN4 SSNq. CN4 CCLq GR5 LSN5 .~SN5 CN5 APl ~ AP1 ?,~ API ~ 12071, 36. 680.3 568.5 23. 8.5 ~0, 692.5 582.3 ap. 8.5 ~7, 70~.6 ~67.5 22, 12072. 6.90,5. 567.,7 22. 8..5 ~2, 705,7 580.7 22. 8.5 ~7, 703.3 ~72,A.22, 12073, 34. 682.,6 573,0 23. 8.5 ~5 69~.2 57~,1 2~. 8.5 ~9. 70~.1 s69.~ 22, 12,07~,, 3.7,.,? 6..77~,.0 5.72,,,,,2.23,~ 8.,5 ~,7~ 67~,6..56.5,! 23. 8,5 50, !207,5, 3.8, 8,5 5,01~ 658,5 55~,7 23,, 8.5 53, 120.7.6, ~0, 678.~0 .....558.,.$...2,2.., 8.,~5 ........ 5!,., 653,~55,~,3 2.~. 8,5, 58, '1207,.7,~ ~6,,, 8.,5 ~5 6~.2 7,,9 ,55, 6&0,7 ~55.0 23 12086. 35 12088. 12090. 111. 12 12092, 273, 1209~ 2 '~52 ,.9,22. ,9 ,~,.2,,,3,, , 722 3 ~95.8 21 12100. 56. 757.8 633,9 22. 8.5 ~2. 791.5 6~0,7 19, 8,5 53. 802.7 mq8.9 19 12102. 34. 791.5 640,7 21. 8.5 ~3. 806.3 655.5 20. 7.2 45. 786.2 A39.1 20 12106. 57. 800.2 652.2 20, 8.5 g2, 8~0.8 665.5 21. 8.5 ~8. 811.~ ~82.P 21 7 21 12112. 33. 702.~ 593,7 21, 8.5 38. 770.5 619,0 20, 8.5 ~. 738.~ A18,9 22 1211~. 37, 7~7.3 629.2 22. 8.5 ~3. 728.5 593,~ 21. 8.5 52, 7~,7 ~0.,,9,..,,,.5. ~2 12116. 56. 724.6 609,1 22, 8,5 39, 7~0.2 604,7 21, 8.5 48. 75,3,5,,,,..~.2~,,,~ ~1 121!8. 33. 7~.2 607,9 22. ~,5 ~0. ............ 720.~ 60~.~; 2~.; 8.5~ ~, 732,5 ~O~,gL.: ............................. 22 PAGE ARCO ALASKA INC. O,S. 16-13 DEPTH FT. GR3 LSN3 SSN3 CN5 CCL3 GR4 LSN4 SSN4 CN4 CCL4 GR5 LSN5 ~SN5 CN5 API ) AP1 ~ AP1 ~ 12120. 35. 719...0.~608,9 22..8.5 41' 749.~ G37.3 2~. 8.5 49. 730,0 ~11.9 23. 12121. 55. 741.6 628.8 22. 8.5 %2~ 765.5 656.9 21. 8.5 48. 749.0 A22.0 22, 12122. 57. 771.2 657.0 21. 8.5 44. 777.5 629.1 21. 8.5 48. 754.9 12123. 56. 773.5 655.8 21. 8.5 44. 750.9 618.6 22. 8.5 50. 743.6 A08.9 22, !212.4`. 37. 7.54..4...632.,!.22...8,5. 42. 719.8 595.5 2P. 8.5 50. 723.7 ~97.8 23, 12128. 37. 6~6,2 59.0.,9.2.~. 8,5 45'. 709.0 599.6 2M. 8.5 ~8. 714,5 AO.1.M 2.3, ~a~..~l. ~0., ....... 6.P~.?Z..Se.~...,.~ 2~, 8,5 ~.6~6.~8.~59~..6.2~, ~.5 5~. 724.~ ~9~.z 22. 121~2. ~2. 709.2 592.5 22. a.5 50. ....... 7P.~........5......58.~.....,....~....~2~., 8...55..~. ..... ?27..0 ..... 57.~..9 22. 1215~. 45' 6§'"~'"'~"~'=':~'~"~'~'"~"'25. 8.5 51. 70~.2 59~.2 2P. 8.5 52. 72~.0 ~98.~ 2~. 12136; 38. 8.5 ~3. 776 5 12~ 12138. 38. 12140. 39. 7 12144. 38 9 2.5 12148. ~8, 6;50.0 54.1.9 24. 8.5 4.8, 642.2 554,7 2~. 8.5 54.. 64. 9 24 12i50, 57. 626,3 555,3 26. 8.2 55:. 6:50,1 564,3 2¢,. 8.5 59, 6; 0 27 12152. 4-7. 617.:5 553.6 26. 8.5 50' 629.5 559.4. 2r-,o 8.5 5:5. ~,23 8 J, 53 4 2~ 12154. 4-4-. 629.5 54,7;! 25. 8,5 q. 4'. 634-.i 556.3 2.~. 8.5 45 62 7 25 1~i'56. ~6, 637.2 54-9,9 24, 8,5 42: 615.3 529,0 2~. 8.5 45, 618.9 ~26,5 25 12160, 54. 615.2 52g.7 2~. 8.5 40, 604-.5 496,5 25, 8,5 4'7, 592 12162, 55. 575.4 4-8q-.8 25. 8.5 4-6'. 56;5.1 509,2 2A. 8.5 58. 57~ 12 ~' ARCO ALASKA D.S. 16-1 -5 INC · PAGE 5 DEPTH GR$ LSN$ SSN5 CN3 CCL3 GR4. LSN4. SSN4. CN4 FT. API % AP1 ~ CCL4 GR5 LSN5 ~SN5 CN5 AP1 ~ 12170. 27. 8.5 4.5r 604..9 529.3 2.~. 8.5 12171. 4.5.602,6 530.3 26. 8.5 ~6. 606.0 532.1 24. 8.3 12172. 57, 599.4. 52G.5 26.. 8.5 q. 5,. 618.9 557.9 25. B.~ 71. 628.5 ~q~4..S 20, 54.. 624..B ~3.9 52. 624.8 ~40.7 26, 12173. ~2. 607.,1.525.0 25. 8.0 ~5 616.8 55~.5 ~s. 8.5 52. 637,6 ~53.~ 25, 1217~. ~0. 609.4. 535.3 25. 8,..5. ~6~ 6~6,0, 565.5, 24, 8,5 5~. 652.7 S58.5 2~, i2175, 8,5, ~7~ 66~.5 566,~ e~. 8.5 !2,!.7.6~, ~,0., 6.5.67,.~..56!.~.5..2~.,, 8?5 ~8, 661,2 5.67.8 2q;. 8,5 58, 655....~ ~4.6.8 23~. 12!.7,7, ~1,. 6.65~,~,,.56.!,,7,,23, 8,5 52- 661',0 56.3,1 8.5 60. 12178,? ~6, ...... 6.6.!..71 ...... 8?,5 56~, 8,5 12179' ~8. 635'6 535'5 26' 8,5 53- 608.~ 501.6 2~. 8.5 5~, 622.6 ~83.0 22. : ..: ; 12184.. 41. 12186, 56, 12188. 12192. 52, 12194.. -0 ~ 54.5.0 4.62,2 25. 8.5 W3 54.6 9 4.78 I 8 '5 ~,6 ',,: .597.:',7, :~5.':.~ 22 572i 5~ 527.5 ~10.7 25, 12196. -0. 4.90.8 4-09.8 26. 8.0 -0. 504..2 4.08.7 2S. 8.5 -0. 503.5 ~98.R 25~ ........................ '-''' .......... ................ .................. ~"~'9"~'"" ......... i'"~'"; .......... 8'5 ............... 2'"0"~' ~71.9 397.2 2A. 8.5 -0. ~82.2 ~85.R 25 12200. -0. ~57.7 590.~ ~1. 8.5 -0. ~65.2 68.~ ~. 8.5 -0. ~87.~ -20.6 ~2202. -0. -8.8-~52.7 ~8. 8.5 -0. -2.8-~7.7 ~8. 8.5 -0. 2.5-152.7 ,. ~220'~'"~' .......... ;'"0"; ............. ;'"~';'"~'152.7 ~8. 8.5 -0. -~.3-~7.7 ~8. 8.5 -0. ~.2-~52.7 LIBRARY TAPE CURVE SPECIFICATIONS Field Prudhoe Bay County,State North Slope, Alaska Date 7-8-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR Gamma Ray CN 0-100 LS Long Space CN - 2-20~0 SS Short Space CN 2-2000 ...... CN Compensated NeutrOn CN 0- 0 ....... . .r ., .... 7059°O0 ~RCO ALASKA INC · ,_-_-_~._-__DS_-_~_~_7__i..~ ...................................................................................................................................................... UDHOE BAY .... N.SLOPE ALASKA, HLAC-~059, SS _IS _ NROR ~U7UU,OU TO 125, SAMPLES pER RECORD PAGE 1 ARCO ALASKA iNC., .... PRUDHOE,BAy .... N.SLOPE ALASKA. HLAC-7059. _ _ DATA EVERY 1 SAMPLK_$ GE _SS LS ~:: 10700-0 O .: ~ 0 · O~ ............ ~__,_69 ............... 3_~ ~___~ .......... ~_6~.,.Q~ ............................. 50 2 2 10706 50 51 2 2 31 29 O1 10707.50 5~77 2.4.1 2.35 28.99 10708,50 50.5~ 2.~3 2.2~ 30.21 i ~10 ~ ~' 2.3~ 2.~7 28.51 10711 107L2 50 10713.50 42.5; 10714.50 44.0 10715.50 4.4..2 10716,50 4.2.4.2 2.12 2.14 28.66 10717.50 42.73 2.13 2.13 28.87 10718.50 43.88 2.13 2.16 29.76 10719.50 47.01 ~.30 2.22 29.38 10720.5~,,, 4.~.4-8 2.51 2.39 29.4.8 10721.50 42.54 2.76 2.4.7 30.32 10722,50 42.39 3.08 2.68 29.39 10723.50 4.~.32 2.97 2.61 29.50 10724..50 45.99 2.77 2.55 28.73 PAGE 2 ANCO ALASKA INC., .... DM-16-1:3 PRUDNOE BAy .... N.SLOPE &LASKA. HLAC-7059. DATA .EV~R_Y ..... I S~_M_PLE_S_ GR SS LS CN 10726.00 46.46 2.55 2.24 :30.57 ':~ 0'726 ' 50:47,2.6 __. 2_~,_?-._ ............. 2,2~. ............. O0 02 10729,00 42.63 40 2.19 30,60 2.40 2.20 30.00 10730.00 42.64 2.32 2.24 27.49 10731.00 4 88 2 27 2.25 28.90 10732,00 43.12 2.16 2.17 28.98 10733.00 40,96 2.32 2.30 28.87 10734-,00 39.62 2.54 2.52 28.24 10735.00 45.04 2.50 2.44 28.46 10736.00 47.69 2.71 2.51 29.73 10737'00 50.6 10738.00 50.7! 10739,00 49.5i 10740.00 48.0 10741,00 46.9 10742.00 45.28 1.99 2.04 29.47 10743.00 41.49 2.10 2.03 29,86 10744.00 44.20 2.23 2.11 30.37 1074~00 ~ ~.~0 2.36 2.41 28.02 ~,~7~7. O0 4~.93 2,24 2.37 29.46 107,8.00 ~.56 2~0 2.Z7 29.62 107 ~,_, O,Q~ 4~.93 2.12 2.1% 29,30 10750.00 42.12 2.12 2.21 29.15 PAGE $ ANCO ALAWKA INC., .... D6-16-15 PRUOHOE.BAY .... N.SLOPE ALASKA. HLAC-7059. DATA EVERY C. R 10751.50 ~2.18 2.20 2.27 28.66 50 ~' 16 15 2.~2 i7 25.91 1 55 50 ~I 79 2.27 2.38 27.15 1 50 4: 14 2.31 2.29 28.10 10757.50 ~7.~6 2,27 2.20 28.87 10758.50 ~6.18 2.25 2.11 30.37 ......... ~.~. ....... 10759,50 LI'5,35 2,32 2,08 30,36 10760.50 43.11 2.44 2.19 30.37 10761.50 q. 3.85 2.41 2.19 30.26 10762.50 10763,50 43.2 10764.50 42,5 10765-50 43,9 10766.50 ~1.2i 10767.50 ~0.05 2.65 2.18 31.~7 10768.50 37.10 2.45 2.09 32.9.3 10769,50 ~1.05 2.72 2.11 34.85 10770,50 ~1.38 2.88 2,30 33.75 Z077Z.50 ~9,06 2,~5 2,~5 27.86 10772.50 ~0.90 2.22 2.~2 26.7~ 10773,50 37,01 2,19 2,~1 27,55 ~0775.50 ~0.28 2.~8 2.58 27.89 PAGE ~ AHCU ALASKA INC., .... D~-16-13 PRUDHOE BAy .... N.SLOPE ALASKA. HLAC-7059. _ DAT'A 'EVERY 1SAMPL[~ _-- -- --~-- ............ Ss LS CN ~,I0776.50 38.9_9 .......... ~_~_~_ _, !0777. O0 40_.87 .......... · · :0777 - 10780.00 59.65 2.71 2.68 27.46 107~1 O0 3. 33 2,66 2.67 27,25 i ?~,2 O0 3, 41 2.62 2.57 28.32 10785,00 37,16 2,56 2,37 29,30 10784., O0 37.13 2,48 2,4.2 28,68 10785,00 35,42 2,56 2.29 30,31 10786,00 34.50 2,80 2,36 30.21 10787,00 28,95 :3,10 2,85 28,55 10788,00 24,5 84 10789,00 25.8 10790,00 32,4 10792 O0 40 10793.00 42,86 2,30 2,23 29,18 10794,00 40,75 2.21 2,11 29,85 10795,00 40,92 2.1~f 2,09 29.00 10796,00 42.70 2.10 2.01 29.85 10797.00 ~5.25 2.09 1.90 10798.00 41.86 2.05 1.84 33.14 19~99.00 41.49 2.05 1.84 32.92 ~mmmmmmmmm~m~mmm~mm~ VERIFICATION LIGTING · . - _ · ... ' . ! ....... . F -< ' . PA~E PREV!OU~ RE~ SERVICE' NA~E : CATE 000 000 SIZE O2O O20 015 0O5 OO8 007 015 010 0O5 SIZE 007 COD 065 O65 O65 O65 065 O65 065 065 O65 CODE 065 LVP ** COMMENTS ** DIL RUN #1 , LOGGED CASING DRILLER CASING DRILLER CASING 50GGER BIT SIZE - LISTINc'~ - 009 HO3 VERIFICATION ! B-JUN-, 81 . : ' .- . 9.625 IN, ~ 11401 :. :- '. _ ~ :. t 95 . 5IGNO FLUID IN THE HOLE = DENS VISC PH FLUID LOSS RMF C" " ~ @ BHT POROSITY MATRI× -- 51~00 = !I'0~" -" ' '~ = 4.8 ML = · 1,44 @~ 5'5 F. ' : ' = 1.23 a 55 F, PAGE LVP 009oM0~ VERIFICATION LISTING ' . 4 ' 73 · 60 4 ~ 6-5 0 i 66 ' 0 ID ORDER # LOG TYPE CLASS MOD NO, LEVEL OHMM )' 0 4 0 IS$ IS FUN I$0 SFLU ILD SP DT GR 12715.500 SFLU -999.250 .DT Ioo.ooo 32,188 DT 12600.000 SFLU -114.375 DT 12500.000 SFLU -155'000 DT 12400.000 SFLU 'I63,656 DT ~ 0 lZ300,0 0 SFLU -171,844 DT 12200.000 SFLU -i88,000 DT 12100.000 SFLU -167.656 DT 12000.000 'SFLU '128-g]8 DT 11 LU 11800.000 SFLU -86.125 DT ** DATA DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP DERT SP DEPI SP ) 0 .4 0 ) 0 '4 0 1 MV 0 1 1 US/F 0 52 GAPI, 0 31 32 0 0 4 0 -999.250IL~ ' '999.250 ILD -999-250 GR -999,250 74'871ILM6 ' 5,184 ILD .750 GR -i14'063 5. ~ 30,396 GR < I01-500 ILD 2~ 95-563 GR ~ < 2~2,922 28. 84. 77~'67 GR ? - ::-~ 3'5,719 94,438 GR 135'375 PAGE REPR CODE 68 68 68 68 68 68 68 '999.250 6.473 7.699 3.707 7.563 13.578 24.859 37.469 19.531 11.938 3.477 LVP 009.H03 VERIFICATION 'LISTING PAGE 4 DEPT SP DEPT SP DEPT SP DEPT SP DEPT SP 11!00 59 11600.000 SFLU -36.6!25 DT 11500,000 SFLU -29.375 DT 1 4oo ooo s Lu -4'4~375 DT 1~30 ,000 99~ SFLU .250 DT 5.805' IbM 103,312- GR · 053 G~ 3.75 GR 99'250 GR ** FILE TRAILER *.~ FILE NAME :SERVIC.o0! SERVICE NA~E ~ VERSION # : DATE ~ MAXIMUM LENGTH : 1024 ILETY E EXT FI~E N1 AME : EOF ********** ** FILE HEAgER~ ~* FILE NAME )SERVIC.O02 ERVICE NAME ) ER$ION # : DAT~NI MAX '~ UM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS PRES: FDNOO1F ~* RECORD TYPE 047- ** **' RECORD TYPE 047 ** *~ RECORD TYPE 047 ~* ** DATA FORMAT RECORD ENTRY BLOCKS TYPE ~_. 4 SIZE REPR CODE 1 66 4.793 248.125 8~.813 .000 1'421 78.875 ~999.250 ~999.2S0 UNIT TYPE CATE 6,297 ENTRY 1 4,680 7.383 3,613 -999.250 SIZE CODE mmmm mmmm 000 o00 007 065 LYP 009.H03 VERIFICATION LISTING PAGE 5 DATUM SPEC!~ICATIO_N BLOCKS MNE~ SERVICE SERVICE UNIT API API DEpT ID NPHI RHOB IS CALI IS NRAT IS NCNb IS FCNL IS DATA DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCN5 DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNb DEPT CALI FCN5 ORDER U- 0 68 /C3 0 35 /' 1271~.500.084 1145 000 12700,000 1,997 1145.000 12600 00 o: o2 904.000 12500.000 1.966 1460,000 1240~,000 .975 974.500 12300.000 1 997 lo441ooo 1220~,000 ,954 1462.000 12100.000 1,957 1548,000 NPHI DRHO DRHO NPHI DRHO DRHO ~PHI RHO NPHI DRHO NPHI DRHO NPHI DRHO ~ 0 12000,0 0 NPHI 1;977 DRHO 1584.000 G/C3 0 : &4 0 42 66 .lin API API FILE SIZE 4 92 0 0 4 93 0 0 60 24,658 RHOB 0 ~124 NRAT 24.658 RHOB 0'089 NRAT 2~.73b RHOB ~001 NRAT 2~,486 RHOB - ,019 NRAT 27,734 R~OB 0'073 NRAT 204,707 ~HOB ,030 NRAT 24,85& RHOB -O.OiO NRAT ~,830 RHOB ,003 NRAT ,009 NRAT PROCESS SAMPLE bEVEL 0 o 0 0 0 ,410 GR .385 NCNb ,3-81 GR .385 NCNb .564 GR .721 NCNb ,270 GR .307 NCNb -525 GR .588 NCNb ,340 GR ,387 NCNb .154 GR .396 NCNb 2.252 GR 2,461 NCNb 2,354 GR 2'312 NCNb REPR CODE 68 68 68 68 68 68 68 108.750 2676.000 108.750 2676.000 100.438 2372.000 37.938 3226.000 95 688 84.125 2632,000 22,922 3322.000 17,438 3684,000 39.563 3496.000 LVP 009.H03 VERIFICATION LISTING ~ ~ ~ DEPT CALI FCNL DEPT CALI FCNL EPT ALI FCN5 DEPT CALI FCN5 EPT ALI FCNb DEPT CALI FCNL DEPT FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALl FCNL EPT ALI FCN5 DEPT CALl FCN5 DEPT CALI FCN5 DEPT CALI FCNL ~9oo,ooo. NeHI .~3,?~0 ~OS - _. :?.2,~61 G~ 988 DRHO 0', 005 NRAT 2' 320 NCN~ 16~ 8,000 ' _ - - ~ : ' 11800.000 NPHi 44.629RHOB . 'i2.309GR 2,035 DRHO 01078 NRAT 3,563 NCNL 487.500 - : -...r - 1170~ 540.500 11500-000 NPHI · : 31.:885 RHOB< i~2.463 GR 2.287 DRHO 0.049 NRAT 2,865 NCNL 826,.000 Nb ' . ._.' . 400..000 1120~. 38o~ooo ~, 11100-000 NPHI: - ' ~4,434 RHOB 'i ' _ 2,350 GR 2.441 DRHO 01458 NRAT 3'840 NCNL 41.1,500 : 11000.000 NPHZ . 4-7.119 RHOS ~ 2.195 GR 2' 430 DRMO -0.576 NRAT 3.988 NCNL , 7.ooo : -- , 4 .ooo .:· o o .ooo . '154 D :NL 395.000 ~ ~ - A- t - ? 10700.000 NPHI 2.213 GR 3,508 NCNb ,963 DRHO 458.500 ' . '~ ~ '_ 1060~ 429.750 : · .~-. ~ PAGE 29.391 3560.000 145.250 1730.000 253,125 1852.000 200.000 2004.000 99.813 2278.000 80 875 1603:000 77 875 1473:000 95,563 1529.000 89 312 1560:000 14 .000 58 188 1752:000 43,188 1440.000 49.969 1640,000 51.188 1508'000 LVP 009.H03 VERIFICATION LISTING PAGE 7 DEPT CAbI FCNb DEPT CALl FCNL DEPT CALI FCNL DEPT CALl FCNL DEPT CALl FCNL DEPT CALl FCNL DEPT CALl FCNL DEPT CALI FCNL DEPT CALl FCNL DEPT CALl FCNL DEPT CALI FCNL CALl FCNL DEPT DEPT CALI 10500.000 NPHI 2,506 DEMO 447.750 10400.000 NPHI 45~,771 DR~O .500 10300,000 NPHI 37~!861500 DRHO 10200.000 NPHI 2 · 625 DRHO 384,500 10i00,000 NPHI 46~,898 DRHO '250 10000,000 NPHI 9900.000 NPHI 543 DRHO 9800.000 NPHI 38~.i62 DRHO ,750 9700.000 NPHI 374,729 DRHO · 500 ' 9600.000 NPH1 3812.87 .2503 DEHO 9500.000 NPHI 2,58 409.25~ DRHO 9400000 NPHI 381.750 9300000 NPHI 46~000525 DEHO 9200.000 NPHI 3.53I DEHO 40723 EHOB 2,074 GR -0:545 NEAT 3,637 NCNb 41.016 RHOB 2.127 GR -0,551 NEAT 3'654 NCNb 48.730 RHOB -0'562 NEAT 1.832 GR 4,074 NCNb 43,01~ RHOB 2,137 GR -O.557 RAT .3,762 NCNb 40.479 RHOB 2,141 GR -0,652 NEAT 3,625 NCNb 43,408 RHOB -0,499 NRAT 2.232 GR 3,783 NCNb 48.975 RHOB 2,063 GR -0,576 NEAT 4'090 NCNb 47.363 RHOB -0,646 NBAT 2.035 GE 4,000 NCNb 52.734 RHOB 2.04! GE -0,577 NEAT 4*293 NCNb 42.480 RHOB 2,145 GR -0,886 NEAT 3,734 NCNb 41.357 RHOB 1.894 GR -0,B29 NEAT 3,670 NCNL 43.604 RHOB 1,884 GR -0.'688 NEAT 3,795 NCNb 39,990 RMOB 1,894 GA -0,588 NEAT 3.596 NCNb 42.04! RHOB 2,162 GR '0'510 NEAT 3,709 NCNb 53,500 1527,000 49.156 1638,000 50063 381:ooo 71 438 1495:000 57,469 1665,000 52125 1582:000 51,625 1492.000 61.813 1458,000 59,969 1453.000 4~.78! 152 ,000 49250 1468:000 48094 14292000 52,906 1577.000 44 031 1752:000 DEPT CALl FCNL DEPT CALI FCNL . 383.250 ~p DE-1 CALl FCNL 424'500 . DEPT CALI FCNL 5.97~:500 DEPT CALI FCNL DEPT CALI FCNL 507.500 · DEPT CALI 5 FCNL 329.2 0 . DEPT 8 CALl FCNL DEP~ ~000,_000 NPHI 41-895 R~OB 1.960 CA~I 2'805 DRHO FCNL 415,750 DBPT CALI N ' DEPT .,.... 7800-,000. NP'HZ: . 40~9~8. . _ RH-OB-. ~ ~966GR:_ . PAGE 44,188 1534.000 35.063 1660,000 4~,563 145 ,000 50 438 1318:000 52 531 1401:000 45.~63 1459. O0 , 719 18 .000 47,7t9 1317.000 28,359 1742.000 46,094 1248.000 37.719 1646.000 1583~) '656 ,000 44,813 1383.000 35.969 LVP 009.H03 VERIFICATION bISTING CALI 3,092 DRHO FCNL 442'500 DEPT 7700.000 NPHI CALI 2-600 DRHO FCNL 363,750 DEPT 7600.000 NPHI CALf 2.488 DRHO FCNL 468.250 DEPT 7500 CALI 2 FCNL 402 000 NPHI 621 DRHO 5O0 DEPT CAbI FCN5 7400.000 NPHI 3293 .145 DRHU '250 DEPT CALI FCN5 7300.000 NPHI 2.549 DRHO 440.'250 DEPT CAGI FCNL 7200.000 NPHI 3,162 DRHO 298.250 DEPT CALI FCNL 7100.000 NPHI 2,771 DRHO 370.750 DEPT CALI FCNb 7000.000 NPHI 2,848 DRHO 375'750 DEPT CAb! FCNL 6900,000 NPHI DEPT CALl FCNL 6800.000 NPHI 2,475 DRHO 395,000 DEPT CAbI FCNL 6700.000 NPH! 49~,607 DRHO .750 DEPT CALI FCNb 6600.000 NPHI DEPT CALI FCN5 6500.000 NPHI 3663 2 ,0 I DRHO .500 -0,596 NRAT 3-646 NCNb 44.238 RHOB 1.899 GR -0,608 NRAT -3,830 NCNb 39.111 RHOB 2.016 GR -0.627 NRAT 3,549 NC~ 43.604 RHOB 2.029 GR -0,592- NRAT 3,797 NCNb 50.098 RHOB 1.845 GR -0,6i6 NRAT 4.152 NCNb 37.549 RHOB 2.092 GR -0.600 ~RA~ 3.463 NCNb 46,828 RHOB 1.602 GR -0~658 NRAT 4.082 NCNb 41.895 RHOB 1.804 GR ~ '0,703 NRAT 3,699 NC}L 49.023 RHOB 1.836 GR '0'660 NRAT .4,090 NCNb 53.662 RHOB i.831 GR -0,600 NRA.T 4,348 NCNb 48,437 RHOB 2.053 GR '0 ,536 NRAT 4,059 NCNb 38.135 RHOB 2.000 GR -0.57! NRAT 3.494 NCNb 47.412 RMOB 1.939 GR -0,642 NR-AT 4,004 NCNb 45,703 RHOB 2.045 GR 0,614 RAT . ~ 3,910 NCNb PAGE 1497,000 42.063 1478,000 40.938 1624.000 36,094 1490.000 43,938 1336.000 32.063 1649.000 43.094 1246.000 40.938 1388,000 46.906 1471,000 44 375 1287:000 38.188 1503,000 40.125 1591.000 51.031 1305.000 43,469 1380.000 bVP DEPT CAbI FCNL DEPT CAbI FCNL DEPT CALI FCNL DEPT CALl FCNL DEPT CALI FCNb DEPT CAbI FCNL DEPT CALl FCNb DEPT CALI FCNb DEPT CALI FCNL DEPT CALl FCNL DEPT CALI FCN5 DEPT CALi FCNL DEPT CALI FCN5 DEPT CAL! FCNL 009.H03 VERIFICATION LISTING 6400,000 NPHI 2.781 DRHO 407.,000 620~,000 NPHI .205 DRHO 262'250 610~,000 NPHI .736 DRHO 400,500 oo :ooo 086 DRMO 268.750 590~.000 NPH~ ,295 DRH 470,500 5800.000 N.PH~ 2'979 DRH 418-000 570~,000 NPHZ '2230 DRHO 393,250 560~.000 NPHI .289 DRHO 305,500 550~ 000 NP~I 758 DRHO 315 000 000 NPH~ 464-000 5300,000 NPHI 8~781 DRHO 365.250 2o :ooo 789 DRMO 367.500 510~,000 NPHI .781 DRHO 380,000 '0 i ' -o 48.633 RHOB . I. 638 GR -0'670 NRAT 4" 070 NCNb '579 NRAT 3. 770 NCNb ,73i . '0,534 NRAT 4~ 375 NCNL NCNL '0, _ '0,610 NRAT 4,102 NCNb 48. 340 RHOB _1,975 GR PAGE 42 031 1529:000 39,719 1428.000 45.938 1180,000 33 500 1353:000 48,625 1198,000 23.594 1602,000 30.375 1548,000 19,203 1494,000 43.063 1312,000 50 281 1317:000 19,047 1496,000 46,844 1374.000 51,781 1374,000 27.813 1520.000 10 LVP 009.~03 VERIFICATION LISTING PAGE 11 DEPT 5000.000 NPMI CALI ~,781 DRHO FCNb 38 .250 DEPT 4800.000 NPHI CALI 8,789 DRHO FCN5 322.500 DEPT 4700.000 NPHI ALI 8.789 DRMO CNL 346.000 DEPT 4600.000 NPHI CALl 8,797 DRHO FCNL 330,250 DEPT 4500.000 NPMI CALI 8.789 DRMO FCNL 346.000 DEPT 4400.000 NPHI CAbI 0~.789 DR~O FCNL 4 .750 DEPT CAbI FCNL DEPT CALI FCNL DEPT CALl FCNL DEPT CALl FCNL DEPT CALI FCNL DEPT FCNL DEPT CALI 4300.000 NPHI 8,758 DRHO 347.250 4200.000 NPHI 8.758 DRHO 250.750 4100,000 NPHI 32~.758 DRHO ,000 4000.000 NPHI 8 . 766 DRHO 336'000 3900.000 NPHI 35~'789.000 DRHO 3800.000 NPHI 34~.789 DRHO '750 3700.000 NPHI 8.789 DRMO 42.969 RHOB 1 918 GR -0,644 NRAT 3:760 NCNb 48.291 RHOB 1.656 GR -0,729 NRAT .4.051 NCNb 47,461 RHOB i.700 GR -0,746 NRAT 4,008 NCNb 44.434 RHOB 0,627 NRAT 1,860 GR 2},840 NCNb 47.266 RHOB 1'884 GR -0-559 NRAT 3. 996 NCNb 55.127 RHOB 2.090 GR -0,648 NRAT 4,426 NCNb 45.996 RHOB 1'971 GR -0,702 NRAT 3,926 NCNL 50.732 RHOB 1.832 GR -0.76'6 NRAT 4'I84 NCNL 57.324 RHOB 1.753 GR -0.662 NRAT :4.547 NCNb 54.590 RHOB 2.014 GR -0-609 NR-AT 4,395 NCNb 49.463 RHOB '0,660 NRAT 1.822 GR 4.i13 NCNb 48 242 RHOB 1,938 GR -0~622 NRAT -4,047 NCNb 50,146 RHOB 1 · 770 GR -0. 708 NRAT 4,1,52 NCNb 47.754 RHOB 2,043 GR -0,654 NRAT 6.023 NCNb 35.500 1384,000 40.813 1353,000 52.688 1314,000 32 438 1376:000 34 281 1321~000 53,219 1521,000 44 906 4 563 3 :ooo 40.000 1220,000 48 719 1387:000 46.594 1294.000 36.719 1374.000 36 000 1341~000 52.094 1347.000 LVP 009.H03 VERIFICATION LISTING PAGE iR FCNL DEPT CALI FCNL DEPT CALl FCNL DEPT CALl FCN5 DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CAL! FCN5 DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALI FCNL DEPT CALl FCNL 344.250 360~,000 NPHI · 828 DRHO 345.250 3500.000 NPMI 8.805 DRHO 323.250 340~,0.00 NPHI ,789 DRHO 305,2-50 .758 DRHO 346.750 320~.000 NPHI .742 DRHO 369.000 310~.000 NPHI .750 DRHO 459.250 ooo :ooO o 289.750 290~,000 NPH! .751 DRHO 325.500 280~,000 NPHI .813 DRHO 385.750 2700.000 NPHI 8.828 DRHO 263,500 260~ 000 NPHI '844 DRHO 252.375 2500.000 NPH! 8,844 DRHO 289.S00 249~,000 NPH-I ,852 DRHO 269'750 ~0.342 RHOB 1.235 NRAT 48.633 R HOB '0.650 NRAT .570, 275 'RHOB .'74! NRAT ~.295 RHOB .604 NRAT 660 NRAT 533 NRAT .534 NRAT ~.586 RHOB .559 NR'AT .707 NRAT 2.891 RHOB ~0,730 NRAT 480 RHOB ~0.791 RHOB 0.57i NRAT ~,402 RHOB '823 NRAT .164 NCNL ,935 GR .070 NCNL 1.717 GR 4,543 NCN5 4.948 GR.. '273 NCNI~ 1.909 GR 4'094 NCNL .084 GR ~.604 NCN5 ,949 GR ,461 NCNL 4,084 OR '176 NC~L ,936 GR ,809 NCNL ,303 GR ~,852 NCNL ,2 8 GE '102 NCNL ~ G Z.459 ~R 4,738 NC~{L ,299 GR .824 NCNL 41.625 1248.000 43.438 1322.000 41 531 1338:000 44 438 1 4 '.ooo 32.594 1476.000 25.016 1570.000 41.781 1360.000 26.016 1376.000 30,172 1506.000 29.250 1207.000 23,234 1230.000 23,141 1322,000 19 094 1357:000 LVP 009.H03 VERIFICATION LISTING ** FILE TRAILER FILE NAME :SERVIC.002 SERVICE NAME VERSION # DATE ; MAXIMUM LEMGTH : I024 FILE TYPE NEXT FILE NAME EOF PA~E ~3 ~ TAPE IRAILER SERVICE NA~E :SERVlC DATE ORIGIN 1617 TAPE NAME CONTINUATIO # NEXT TAPE NAME . COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC DATE ;81106/17 ORIGIN : REEL NAME :REEL ID CONTINUATION # ~01 AME . NEXT REEL N ' COMMENTS :REEL COMMENTS EOF EOF **********
