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Home My WebLink About183-190MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-04 KUPARUK RIV UNIT 2F-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 2F-04 50-029-21065-00-00 183-190-0 W SPT 5764 1831900 3000 2800 2800 2800 2800 85 90 90 90 REQVAR P Bob Noble 7/6/2024 MIT-IA to max anticipated injection pressure as per AIO 2B.074 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:KUPARUK RIV UNIT 2F-04 Inspection Date: Tubing OA Packer Depth 870 3470 3350 3340IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240707132845 BBL Pumped:2.4 BBL Returned:2.3 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 999 9 9 MIT-IA AIO 2B.074 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:58:50 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-04 KUPARUK RIV UNIT 2F-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2F-04 50-029-21065-00-00 183-190-0 W SPT 5764 1831900 3000 2650 2650 2650 2650 65 80 80 80 REQVAR P Brian Bixby 7/2/2022 MITIA as per AIO 2B.074 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:KUPARUK RIV UNIT 2F-04 Inspection Date: Tubing OA Packer Depth 900 3310 3220 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704090301 BBL Pumped:2.2 BBL Returned:2.1 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 AIO 2B.074 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 15:21:17 -08'00' MEMORANDUM TO: Jim Regg 1-1-?P.I. Supervisor ly q (Z-4 1-1 tnoz-1 FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT 2F-04 IInsp Num: mitSAM211108195900 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 23, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2F-04 KUPARUK RIV UNIT 2F-04 Sre: Inspector Reviewed By�:p`p P.I. Supry c_jPjl17- Comm API Well Number 50-029-21065-00-00 Inspector Name: Austin McLeod Permit Number: 183-190-0 Inspection Date: 11/8/2021 Tuesday, November 23, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Well 217-04- Type Inj W TVD 5764 Tubing 2410 2410 - 2410 -Min —----- --- - 2410 -- PTD 1831900 J SPT Test pSl I Type . �T a Test - 3000 IA 840 � ---- 3300 - 3200 -_ 'I 3180 — BBL Pum ed: 2 BBL Returned: 2 OA ns - 120 - 120 120 Interval I- - - RFQVAR - -- P/F 1-- -- P � --- NoteS: 2 year to MAIP. AIO 213.074. Tuesday, November 23, 2021 Page 1 of 1 I0A,t zF-- 04 1'631c1eu Regg, James B (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, July 15, 2020 8:39 AM To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: KRU Non Witnessed MITIAs 7/13/20 Attachments: MIT KRU 2F PAD SI TESTS 07-13-20.xlsx; MIT KRU 1D-38 51 TEST 07-13-20-.xlsx Ia Attached are Non Witnessed MITIA's performed in Kuparuk 7/13/20. Please let me know if you have any questions. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM c«wco�f!IMvs STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regnaalaska.00vAOGCC.Insoectorsaaalaskaoov OPERATOR: FIELD/ UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc Kuparuk / KRU / 2F Pad 07/13/20 VanCamp / Weimer Phoebe. brooksAalaska.aov chns.wallacelitalaskaoev Well 2F-04 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. 4 = Four Year Cycle F = Fail PTD 1831900 Type lnj N Tubing - 21202125 2125 - 2125 - N = Not Infecting Type Test P Packer TVD 5765 BBL Pump 2.5 IA 225 + 3300 3225 - 3200- Interval V Test psi 3000, BBL Return 2.2 OA 90 90 ' 90 - 90 - Result P Notes: MITIA to maximum anticipated injection pressure per A102B.074 `/ Well 2F-14 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831590 Typelnj N Tubing 1500 1550 1550 1550 Type Test P Packer TVD 5857 BBL Pump 2.0 IA 225 3325 3260 3250 Interval V Test psi 3000 BBL Return 2.0 OA 60 60 60 fi0 Result P Notes: MITIA to maximum anticipated injection pressure per AID 2C.064 Well 2F-15 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831720 Type Inj N Tubing 1975 2025 2000 2000 Type Test P Packer TVD 5870 BBL Pump 3.0 IA 200 2760 2675 2650 Interval 4 Test psi 1500 BBL Return 2.8 OA 20 20 20 20 Result P Notes: Well 2F-16 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831770 Typelnj N Tubing 2075 2075 2075 2075 Type Test P Packer TVD 5834 BBL Pump 3.0 IA 225 2860 2775 2750 Interval 4 Test psi 1500 BBL Return 2.8 OA 80 80 80 80 Result P Notes: Well 2F-21 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD . 2141360 Typelnj N Tubing 2300 2300 2300 2300 Type Tesl P Packer TVD 6110 BBI -Pump 2,4 IA 275 1800 1750 1725 Interval 4 Test psi 1528 1 BBL Return 2.4 OA 140 255 270 270 Result P Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water - P=Pressure Test I=Initial Test P=Pace G = Gas 0 = Other (describe In Notes) 4 = Four Year Cycle F = Fail S=Slurry V= Required by Variance 1=lmmnclusive I = Industrial Wastewater O = Other (describe In notes) N = Not Infecting Form 10-426 (Revised 01/2017) MIT KRU 2F PAD $I TESTS 07-1120 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,April 15, 2018 9:14 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 2F-04 (AIO 26.074, PTD 183-190) report of rising IA pressure 4-15-18 Attachments: 2F-04 90 day TIO 4-15-18.JPG Chris, KRU injector 2F-04(AIO 26.074, PTD 183-190)is waivered for known TxIA communication while on gas injection. The well has been shut in since July 2016 and there has been a slow increase in IA pressure over the last several months with a couple of recent bleeds needed when nearing the DNE of 2000psi. At this point, it is believed that a gas slug is moving through the reservoir and has entered the near-wellbore area,causing the annulus pressure to rise as gas migrates across the leak point. Before returning the well to water injection,we intend to circulate out the backside with fresh fluid and obtain an MITIA to confirm there has been no change in the mechanical integrity of the wellbore. Attached is a 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska,Inc. Desk Phone(907)659-7224 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 29,2016 TO: Jim Regg P.I.Supervisor N<ICi 61/6(47SUBJECT: Mechanical Integrity Tests / I CONOCOPHILLIPS ALASKA INC 2F-04 FROM: Johnnie Hill KUPARUK RIV UNIT 2F-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry SP--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-04 API Well Number 50-029-21065-00-00 Inspector Name: Johnnie Hill Permit Number: 183-190-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826172420 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-04 - Type Inj N. TVD 5764 Tubing 2440 - 2440 • 2440 - 2440 -1 PTD 1831900 . Type Test SPT Test psi 3000 ' , IA i 180 3250 • 3180 ' 3160 Interval REQVAR P/F P '" OA 120 130 - 130 • 130 Notes: MITIA to max anticipated injection PSI AIO 2B.074 SCANNED JUN 1 6 2011: Monday,August 29,2016 Page 1 of 1 0 ti • V° a) a) ,`V I �70 ' >(b tic: 11 oN z OOXa C O Q T2 i v a) Oh¢NY Q N �--' L C p ,- •- e- ,- e- cot0 m 1- f0 . U V, > O M C OC 'O w a a, O O O Qr�9 C "O !o v Y H riC2 7 7 10 7 7 y O E (13 M > > E co2 N N N. N M M ) >- > N QZ O -O O >,a v afL ~ 4J > L n7❑ ❑ ❑ ❑ ❑ ❑ fo v U D- J J J J J JW W_ W_ W W W nno O ro 0 O LL LL LL LL LL LL 7, a) E 'O L^�' J J J • O C co a)OO C Z Z Z Z Z Z_ O " v 0 .W ro u .v+ LL LL LL LL LL LL a) = u a) Gaj v O '- QV o r z C O _0 C T'1 > > c u Q ate) _c ° > C, m " W a� - 'Cr) W No E 1. G ❑ 0 ❑I .a a a = Q I w U C • W J J m m co m '0 co 0 0 0 co WI DI W d > lie .7.i 011t � ti 0 a ..n as m 66 /t4 a O(19 h <.) i HW 0' I !d x v io bIC oc2 ` >> 333 333 W +i 0 = c ce cc Ce a L W W Q W W W 4 m Z Y D Y > > > uu.s Y Q ce Q Q Q a U Cl) C. D d > > > rya O Y Y Y Y Y cup > r� oc x a CO W r co CD N N o W0 e- 0 a) o 0 0 v G 0 0 0 0 m N r, O o 0 0 0 0 0 co ,� �/ v It 0 6 O 666 E o o CO W a)U U U ❑ ❑ ❑ 0 Cx ra C Iii Oo 0 O N o 0 0 0 0 0 M O t0 O N M 6 CO CO O 00 0 N /-- 0 0 0 Ln 0 N N N N N N N v n T M 0) 0) M M 0 o N 0 N N O 0 Q1 O O O — O O O O O O ti' In 11) If) 10 11) IA ,,, 7 a) aan . 00 C +a OU c Cm z E v Y CC C soN 1n m a Q Q co a = a oo i z O M Nd Vl a+ H (-a d a N W N N N M M Z 0 co SPT n 3 as c m �, 8 L I v CO F`- a` a -;--z • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday,June 06, 2016 9:04 AM To: 'NSK Problem Well Supv' Cc: NSK DHD Field Supervisor; Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: 2F-04 (PTD 183-190) Request for delay in MITIA testing Brent, With the other conditions of 2B.074 requiring a close eye on the injection operations, a small delay in the MIT to align with the established pad testing schedule is acceptable for this well. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 20� 333 West 7th Avenue �UN 1 0 Anchorage,AK 99501 �� (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, June 05, 2016 8:44 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; NSK DHD Field Supervisor Subject: 2F-04 (PTD 183-190) Request for delay in MITIA testing Chris, Kuparuk injector 2F-04(PTD 183-190) is due for its' compliance testing per AIO 26.074 by 06/07. The well had been shut in and was just returned to injection on 05/31/16. 2F pad is due for testing during the month of July as per the approved UIC testing schedule. CPAI requests a delay in the testing for 2F-04 and allow it to be tested with the rest of the pad in July. Attached is a copy of the 90 day TIO plot for reference. Please let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 WELLS TEAM ConocoPhillips1 • dwalia)1oii • C) CD o L Q N ,i , I. II . 1. 1 .I I . ,I , I, + , 1 , I .I I I. J 1 1 _ � ; t • • — 1 — • . : ; : : >1 — :: • • :: — CO s -- —Ili, •• :• • • : - • • • • • • • • • • • • • N - ` ; — `'C • E1 : • — • • • • _ • :• - - : - — r . - • : : : : : • • : : (1) - r •. • : CO - N- • LI 1 I' III 1, 1 ,1 I PI I I' I '1 II 1 ' I I I' I 'I I' I I ' ♦- Q Q Q Q i U 11 Q CD Q Q Q (N r ISd kc'3- ;ot 0 WELL LOG TRANSMITTAL DATA LOGGED -Z /ct /2015 K BENDER To: Alaska Oil and Gas Conservation Comm. June 16, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 �"' (.4. 1 k, JUN 19 2U1 RE: Perforation Record: 2F-04 Run Date: 6/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21065-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 ., ;ti Office: 907-273-3527 Satilt° Fax: 907-273-3535 FRS ANC @halliburton.com Date: Signed: STATE OF ALASKA A .(A OIL AND GAS CONSERVATION CO, 3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing j""" Operations Shutdown fl Performed. Suspend p r Perforate r Other Stimulate 1""" Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Fbol r Repair Well r Re-enter Susp Well r Other: r- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 183-190 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service Pi 50-029-21065-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25657 KRU 2F-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8050 feet Plugs(measured) none true vertical 6319 feet Junk(measured) none Effective Depth measured 7954 feet Packer(measured) 7383 true vertical 6235 feet (true vertical) 5765 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 108 108 SURFACE 2986 9.625 3016 2750 PRODUCTION 8010 7 8039 6310 RECEIVED JUN 12 2015 Perforation depth: Measured depth: 7617-7627, 7641-7675, 7728-7742 AOGCC True Vertical Depth: 5950-5958, 5969-5997,6041-6052 ED !uLWOW _ ? `L�1`.1 Tubing(size,grade,MD,and TVD) 3.5, J-55, 7454 MD, 5819 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL HYD RETRIEVABLE PACKER @ 7383 MD and 5765 ND SAFETY VLV-OTIS QLP SAFETY VALVE (LOCKED OUT 3/30/96) @ 1814 MD and 1791 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1689 Subsequent to operation 1446 14.Attachments(required per 20 MC 25 070,25.071,&25 283) 15 Well Class after work: Daily Report of Well Operations ld Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ j WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt none Contact John Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date ./A ' -� C�1l/1S / RBDMS JUN 2 5 2015 v 17- 11615 A r///�,� Form 10-404 Revised 5/2015 Submit Original Only 2F-04 WELL WORK SUMMARY DATE SUMMARY 5/12/2015 Perform FCO in 7" casing from TOF at 7,716' CTMD to hard tag @ 7,764' CTMD (7,774 RKB). Unable to go past hard tag after numerous attempts. Schmoo in returns and no soild samples recovered. Well freeze protected and ready for Slickline. 5/13/2015 TAGGED @ 7744' SLM. DRIFTED TBG WITH 15' x 2.5" BAILER TO 7744' SLM. READY FOR E/L. 5/16/2015 MEASURED BHP @ 7568' RKB: 4964 PSI. COMPLETE. 6/1/2015 ATTEMPT TO PERFORATE INTERVAL 7727.7'-7742.7' USING 2.125" DEEP STAR CAPSULE GUN, 6 SPF, TRI-PHASED, MILLENIUM 2 HMX 15.9 GM CHARGES. UPON POOH, DISCOVERED THAT ONLY THE TOP 21 OF 90 CHARGES (3.5') FIRED. APPEARS EXPOSED DET CORD RUBBED ON THE TRIP IN HOLE CAUSING THE CORD TO FRAY STOPPING THE EXPLOSIVE TRAIN. TAGGED HIGH AT 7744'. LOG CORRELATED TO GEARHART CEMENT BOND LOG DATED 13 MAY 1984 TO GAMMA RAY. WELL LEFT SHUT IN FOR DSO TO BOL. JOB COMPLETE. 6/3/2015 SHOOT PERFORATIONS FROM 7730.5'TO 7741.5'WITH 2.5" 6 SPF 60 DEG PHASED MILLENNIUM HMX CHARGES. JOB COMPLETE. KUP INJ 2F-04 ConocoPhitlip$ m Well Attributes Max Angle MD TD Alaska inc. Wellbore API/UWI Field Name Wellbore Status ncl El MD(MB) Act Btm(ftKB) cr.,.,..,,,,,,,,,N 500292106500 KUPARUK RIVER UNIT INJ 50.12 6,700.00 8,050.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2F-04,6/4/2015 10 00.23 AM SSSV:LOCKED OUT Last WO: 2/6/1987 29.00 2/2/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,744.0 5/13/2015 Rev Reason:PERFORATIONS hipshkf 6/4/2015 HANGER:237 -Casing Stings LI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) .ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread 95/8- 8.921 30.5 3,016.1 2,750.1 36.00 J-55 BUTT Casing Description OD(in) ID(in) Top ftK)Set Depth(ftKB) Set Depth(ND)... WI/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.5 8,039.1 6,309.6 26.00 J-55 BTC Tubing'Strings Tubing Description String Mc...ID(in) Top(ftKB) Set Depth(It..l Set Depth(ND)(...Wt(II Grade lop Connection - TUBING 312 2.992 23.7 7,454.4 5,819.9 9.30 J-55 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 23.7 23.7 0.17 HANGER FMC TUBING HANGER 3.500 -A-",-/CONDUCTOR;31.0-700.0--d+�+.J, -n��...n. 1,813.8 1,790.8 23.53 SAFETY VLV OTIS QLP SAFETY VALVE(LOCKED OUT 3/30/96) 2.812 7,367.9 5,753.6 40.80 PBR BAKER PBR w/LOCATOR 2.810 --- 7,382.6 5,764.7 40.51'PACKER BAKER FHL HYD RETRIEVABLE PACKER 2.890 7,421.1 5,794.2 39.68 NIPPLE CAMCO D NIPPLE 2.750 7,453.6 5,819.3 38.92 SOS BAKER SHEAR OUT SUB 2.992 SAFETY VLV;1,813.8 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotsif Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,617.0 7,627.0 5,949.7 5,957.8 A-5,2F-04 3/31/1984 4.0 (PERF 4"Schlumberger Casing 7,641.0 7,675.0 5,969.3 5,997.2 A-4,2F-04 3/31/1984 4.0 IPERF 90 deg.Phasing,4" SPF, SchlumbergerTRI-PHASE,Casing 7,728.0 7,731.5 6,041.1 6,044.0 A-4,2F-04 6/1/2015 6.0 APERF 2.125"DEEP STAR SURFACE;30.53,016.1-- CAPSULE GUNS,6 MILLENIUM 2HMX,15.9 GRAM CHARGES GAS LIFT 7.3x.1 �. 7,730.5 7,741.5 6,043.2 6,052.4 A-4,2F-04 6/3/2015 6.0 APERF 2.5"MILLENIUM I)HSC, 6 SPF,60 DEG PHASE Mandrel Inserts F. st at on Top(TVD) Valve Latch Port Size TRO Run r --� N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PBR;7,367.9 lt`'I�IJJ f 7,321.1 5,718.4 OTIS LBX 11/2 GAS LIFT DMY RO5 0.000 0.0 2/26/1987 Notes:General&Safety 11 r End Date Annotation 10/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;7,3826 3/13/2013 NOTE:WIAVERED WELL-WI ONLY;T x IA COMMUNICATION WHILE ON GAS NIPPLE;7.421.1 SOS;7,453.6- 1PERF;7,617.0-7.627.0 . IPERF;7,641.0-7,675.0--. APERF;7,728.0.7,731.5 , I. APERF;7,730.S-7,741.5-_- PRODUCTION;29.5-8,039.1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 18, 2012 TO: Jim Regg / P.I. Supervisor �� 6 1 u'( Z SUB Mechanical Integrity Tests ' CONOCOPHILLIPS ALASKA INC 2F -04 FROM: Lou Grimaldi KUPARUK RIV UNIT 2F -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ( 2--- NON - CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F - 04 . API Well Number 50- 029 - 21065 -00 -00 Inspector Name: Lou Grimaldi Permit Number: 183 - 190 - Inspection Date: 6/7/2012 Insp Num: mitLG120607081010 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F -04 ' Type Inj W TVD 5764 • IA 1220 1760 , 1730 1720 . PTD 1831900 ' Type Test S Test psi 1500 OA 350 - 350 355 350 - Interval 4YRTST P/F P . Tubing 2450 - 2450 1 2450 2450 - ■ Notes: 1.1 bbl's up, .9 down. Good stable test. itANNED JUL z 0 LJ1ir Monday, June 18, 2012 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: 71m Re gg + DATE: Thursday, October 27, 2011 , q 1 � l I f SUBJECT: Mechanical Integrity Tests P.I. Supervisor � G I g � Y CONOCOPHILLIPS ALASKA INC 2F -04 FROM: Bob Noble KUPARUK RIV UNIT 2F -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JG€— " NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2F - 04 API Well Number: 50 029 - 21065 - 00 - 00 Inspector Name: Bob Noble lnsp Num: mitRCN111025185731 Permit Number: 183 - 190 - Inspection Date: 10/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2F -04 - Type Inj. W ' TVD 5764 - IA 1278 3300 ' I 3233 I 3217 ' P. 1831900 ' TypeTest SPT Test psi 1500 OA 340 - 340 340 340 , Interval OTHER P/F P ' Tubing 2675 2675 2675 2675 Notes: Test for AA application Thursday, October 27, 2011 Page 1 of 1 ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 3,~~0 ~~ ~ o ~ ~- r,~~~,~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 27 and October 30, 2008. The corrosion inhibitor/sealant was pumped November 2, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. , . . _.. _ .. _ ...._. ....> ..._ r.,_..... . Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry m ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Datp 11/3/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor. Corrosion inhibitor/ sealant date ft bbls ft al 2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008 2F-04 183-190 48" NA 48" NA 25.5 11/2/2008 2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008 2F-08 184-021 SF NA 20" NA 2.55 11/2/2008 2F-09 184-036 18" NA 18" NA 1.7 11/2/2008 2F-10 184-040 22" NA 22" NA 1.28 11/2/2008 2F-12 184-043 20" NA 20" NA 2.12 11/2/2008 2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008 2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008 ~+ ® ~~~~ • To: Jim Regg ~ -~ P.I. Supervisor hc;~ ~ ~~ i ~ ~ J FROM: Bob Noble Petroleum Inspector State ®f Alaska . Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA 1NC 2F-04 KUPARLTC RIV UNIT 2F-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~'~ Comm Well Name• KUPARUK RN UNIT 2F-04 API Well Number: 50-029-21065-00-00 Inspector Name: Bob Noble Insp Num: mitRCN08070714 1 1 1 2 permit Number: 183-190-0 Inspection Date: 7/5/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. `7~Iel~-2F-04 ,Type Inj. N ~ TVD 5770 I IA i 1740 2440 i 2430 ~ 2430 ~~ p_T. i ]s319oo TypeTest SPT I Test psi z4ao pA ao ~ 40 ! 4o ao 'I Interval 4YRTST p~F P ,, Tubing ~ 3050 3060 I 3060 3060 i i Notes: :~~l~~~r A~ G ~ ~ 208 Tuesday, July 08, 2008 Page 1 of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K~~1' 'DIII/07 DATE: Friday, August 17,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-04 KUPARUK RIV UNIT 2F-04 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \ ')S.L- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2F-04 API Well Number: 50-029-21065-00-00 Inspector Name: Bob Noble Insp N urn: mitRCN070806132425 Permit Number: 183-190-0 Inspection Date: 8/5/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 2F-04 IType Inj. I N i TVD 5770 /] IA t320 2210 2180 I 2170 i i I --+ P.T. i 1831900 ¡TypeTest! SPT ¡ Test psi 2210 '10A 40 40 40 i 40 ì Interval 4YRTST P/F P Tubing 3000 3000 3000 i 3000 I I Notes: Well was S/I SCANNED AUG 232007 Friday, August 17, 2007 Page 1 of 1 RE: FW: 2F-04 (PTD 1831900) Report of passing diagnostic MIT -... . Jim, Thanks for conditional approval for water only injection; however, the ~ well will remain SI while waiting on wellwork to diagnose the low injectivity rate. The well was barely taking any MI before it was wagged to water for diagnostics. MI injection was sporadic, only taking MI during MI header pressure peaks. A high SBHP is suspected to be the cause of low injectivity. A SL tag is planned to check if the perfs are obstructed and check the SBHP. There are several wells that only leak with MI in the tbg; however, it is inconclusive if this well is one of those wells. It is possible that, due to the intermittent injection rate on MI, the IA bleeds were thermal. There have been several wells in the past that seemed to have a slow communication problem on MI that were successfully put back on MI after passing diagnostics without further symptoms of communication. If 2F-04 has a communication problem on MI, there is a new sonic logging tool that may be able to locate the leak while logging the well in MI service. This is a new tool that we've had very good success with and are exploring the limits of it's leak detection capabilities. Attempting to repair a leak is preferable to waivering a well, ~~ especially if the leak is at a dummy valve or thread. Once 2F-04's injectivity problem is investigated, an update will be submitted to work out an acceptable plan forward. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 ~~?~.?~<;<?~,?q<2PÞ~~~.~EE3.:s:..c>.f.1.l SCANNED MAY 2 9 2007 -----Original Message----- From: James Regg [mailto:ji.m regg@adrnin.state.ak.us] Sent: Friday, May 18, 2007 4:23 PM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: FW: 2F-04 (PTD 1831900) Report of passing diagnostic MIT - request to BOI Like so many other wells that leak to gas but pass the MITs (tested with diesel or water), the administrative approval is the process we use to authorize continued operation of a well that fails to meet the well integrity criteria of an injection order (AIO 2B, Rule 7 and Rule 9). My email dated 3/9/2007 identified the need to obtain an administrative approval to continue injecting in this well. KRU 2F-04 should be added to the monthly report (it is not just for wells failing a MIT) if it is brought online. ConocoPhillips may restart the well by injecting water only; an administrative approval request should be received by the Commission within 14 days of commencing injection. The well must be made available for a Commission-witnessed MIT following commencement of water injection. The well will be shut in if we do not receive the admin approval by May lof4 5/23/20078:28 AM RE: FW: 2F-04 (PTD 1831900) Report of passing diagnostic MIT - ... . . 29, 2007. Jim Regg AOGCC NSK Problem Well Supv wrote: Tom & Jim, Correction, this well isn't on the failed MIT report. I had assumed it was one of the several SI wells on the report. Please disregard the request to remove it from the report. Thanks, Marie -----Original Message----- From: NSK Problem Well Supv Sent: Friday, May 18, 2007 11:48 AM To: 'James Regg'; 'Thomas Maunder'; Robert Fleckenstein Subject: 2F-04 (PTD 1831900) Report of passing diagnostic MIT - request to BOI Tom, Jim, & Bob, Diagnostic MITs passed on Wag injector 2F-04 yesterday, 5/17/07. Both a positive pressure test and a drawdown test passed. The injector has been SI since 3/9/07 after permission to continue injection while troubleshooting possible communication was denied. The well is also on the failed MIT report. Since the well appears to have integrity while SI, permission is requested to bring the well on water injection and continue to monitor closely for any signs of TxIA communication. The well is scheduled for a 4 yr witnessed MIT this summer. I'd like to propose removing the well from the failed MIT report once the witnessed MITIA passes in a few months. Please let me know if this plan is acceptable. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com -----Original Message----- From: NSK Problem Well Supv Sent: Friday, March 09, 2007 2:19 PM To: 'James Regg' Cc: 'Thomas Maunder' Subject: RE: 2F-04 (PTD 1831900) Report of suspected TxIA comm in MI service Jim, We will be freeze protecting the well and shutting it in long term. We will continue diagnostics to determine if there is an annular communication issue with this well. The results from the diagnostics will dictate any future action. Let me know if you have any questions. Perry Klein 20f4 5/23/2007 8:28 AM RE: FW: 2F-04 (PTD 1831900) Report of passing diagnostic MIT - ... . . Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, March 09, 2007 10:23 AM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: 2F-04 (PTD 1831900) Report of suspected TxIA comm in MI service requires an admin approval NSK Problem Well Supv wrote: Tom & Jim, Kuparuk Wag injector 2F-04 (PTD 1831900) is suspected to have TxIA comm in MI service after the IA was bleed more than twice in the last 2 days. The well was wagged to water injection this morning. Diagnostics are planned as soon as the well stabilizes on water injection, the packoffs will be tested and an MITIA performed. permission to keep the well on line in water service while diagnostics are in progress is requested. Attached is a schematic and 90 day T/I/O plot. The plot shows a lot of swings in the IA pressure, not all of which are bleeds, but are due to swings in the MI injection rate. The well needs full MI header pressure to keep injection going and injects at a low rate when it does inject. A small drop of 20 to 30 psi in the supply pressure can be enough for this well to stop taking MI for a while. The swings in MI injection rate when the header sags for hours to days causes the downhole temperature in the permafrost to swing even though the surface injection temperature is relatively stable. This is a difficult well to tell the difference between thermal and pressure bleeds and trends. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «2F-04 90 day TIO plot 3-06-07.gif» «2F-04.pdf» 3 of4 5/23/20078:28 AM RE: FW: 2F-04 (PTD 1831900) Report of passing diagnostic MIT -... . . > 40f4 5/23/2007 8:28 AM Re: FW: 2F -04 (PTD 1831900) Report of passing diagnostic MIT - ... .- . Like so many other wells that leak to gas but pass the MITs (tested with diesel or water), the administrative approval is the process we use to authorize continued operation of a well that fails to meet the well integrity criteria of an injection order (AIO 2B, Rule 7 and Rule 9). My email dated 3/9/2007 identified the need to obtain an administrative approval to continue injecting in this well. KRU 2F-04 should be added to the monthly report (it is not just for wells failing a MIT) if it is brought online. ConocoPhillips may restart the well by injecting water only; an administrative approval request should be received by the Commission within 14 days of commencing injection. The well must be made available for a Commission-witnessed MIT following commencement of water injection. The well will be shut in if we do not receive the admin approval by May 29, 2007. Jim Regg AOGCC 5~ MAY ..2 1 20D7 NSK Problem Well Supv wrote: Tom & Jim, Correction, this well isn't on the failed MIT report. I had assumed it was one of the several SI wells on the report. Please disregard the request to remove it from the report. Thanks, Marie -----Original Message----- From: NSK Problem Well Supv Sent: Friday, May 18, 2007 11:48 AM To: 'James Regg'; 'Thomas Maunder'; Robert Fleckenstein Subject: 2F-04 (PTD 1831900) Report of passing diagnostic MIT - request to BOI Tom, Jim, & Bob, Diagnostic MITs passed on Wag injector 2F-04 yesterday, 5/17/07. Both a positive pressure test and a drawdown test passed. The injector has been SI since 3/9/07 after permission to continue injection while troubleshooting possible communication was denied. The well is also on the failed MIT report. Since the well appears to have integrity while SI, permission is requested to bring the well on water injection and continue to monitor closely for any signs of TxIA communication. The well is scheduled for a 4 yr witnessed MIT this summer. I'd like to propose removing the well from the failed MIT report once the witnessed MITIA passes in a few months. Please let me know if this plan is acceptable. Marie McConnell Problem Well Supervisor (907) 659-7224 n16 II. com lof3 5/20/2007 9:39 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 12F-04 05/17/07 Rogers 1 Johnson 1 Colee Packer Depth Pretest Initial 15 Min. 30 Min. Well2F-04 I Type Inj. I N TVD I 5,770' Tubing 2900 2900 2900 2900 Interval 0 P .T.D.1831900 I Type test I P Test psil 1500 Casing 1800 2300 2190 2090 P/FI F Notes: OA 30 40 40 40 We1l12F-04 I Type Inj. I N TVD I 5,770' Tubing 2900 2900 2900 2900 Intervall 0 P.T.D.11831900 Type test I P Test psil 1500 Casing 2010 2340 2300 2300 P/F P Notes: OA 40 40 40 40 We1l12F-04 I Tvpe Inj. I N TVD I 5,770' Tubing 2900 2900 2900 2900 I nterval 0 PTD.11831900 I Type test I M Test psil 1500 Casing 2010 1250 1260 1260 P/F P Notes: IA found at 1290 psi after -18 hrs on 5/18/07 am. OA 40 30 30 30 Weill I Type Inj.1 TVD I Tubing Interval PTD.I I Type test! Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval PTD.I I Type test! Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test I Test psil Casing P/F Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 2F-04 05-17-07.xls 90 ¡ of 5/20/2007 9:44 AM . . -------- Original Message -------- Subject:RE: 2F-04 (PTD 1831900) Report of suspected TxIA comm in MI service Date:Fri, 09 Mar 2007 14:19:19 -0900 From:NSK Problem Well Supv <n1617@conocophillips.com> To:J ames Regg <jim Jegg@adrnin.state.ak.us> CC : Thomas Maunder <torn _ maunder@admin.state.ak.us> References:<F 1912988BDE9804BBC 1435C7E5F412AD5A9626@nskexmb2.conoco.net> <45F 1 B40E. 709030 1@admin.state.ak.us> Jim, We will be freeze protecting the well and shutting it in long term. We will continue diagnostics to determine if there is an annular communication issue with this well. The results from the diagnostics will dictate any future action. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCJ\NNEO APR 1 9 2007 -----Original Message----- From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, March 09, 2007 10:23 AM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: 2F-04 (PTD 1831900) Report of suspected TxIA comm in MI service requires an admin approval NSK Problem Well Supv wrote: > Tom & Jim, > > Kuparuk Wag injector 2F-04 (PTD 1831900) is suspected to have TxIA > comm in MI service after the IA was bleed more than twice in the last > 2 days. The well was wagged to water injection this morning. > Diagnostics are planned as soon as the well stabilizes on water > injection, the packoffs will be tested and an MITIA performed. > Permission to keep the well on line in water service while diagnostics > are in progress is requested. > > Attached is a schematic and 90 day T/I/O plot. The plot shows a lot > of swings in the IA pressure, not all of which are bleeds, but are due > to swings in the MI injection rate. The well needs full MI header > pressure to keep injection going and injects at a low rate when it > does inject. A small drop of 20 to 30 psi in the supply pressure can > be enough for this well to stop taking MI for a while. The swings in > MI injection rate when the header sags for hours to days causes the > downhole temperature in the permafrost to swing even though the of2 4/19/2007 12:23 PM . . > surface injection temperature is relatively stable. This is a > difficult well to tell the difference between thermal and pressure > bleeds and trends. > > Please let me know if there are any questions. > > Marie McConnell > Problem Well Supervisor > (907) 659-7224 > n1617@conocophillips.com > > > «2F-04 90 day TIO plot 3-06-07.gif» «2F-04.pdf» > 2 of2 4/19/200712:23 PM 2F -04 (PTD 1831900) Report of suspected TxIA comm in MI service . . Tom & Jim, Kuparuk Wag injector 2F-04 (PTD 1831900) is suspected to have TxlA comm in MI service after the IA was bleed more than twice in the last 2 days. The well was wagged to water injection this morning. Diagnostics are planned as soon as the well stabilizes on water injection, the packoffs will be tested and an MITIA performed. Permission to keep the well on line in water service while diagnostics are in progress is requested. Attached is a schematic and 90 day T/I/O plot. The plot shows a lot of swings in the IA pressure, not all of which are bleeds, but are due to swings in the MI injection rate. The well needs full MI header pressure to keep injection going and injects at a low rate when it does inject. A small drop of 20 to 30 psi in the supply pressure can be enough for this well to stop taking MI for a while. The swings in MI injection rate when the header sags for hours to days causes the downhole temperature in the permafrost to swing even though the surface injection temperaJLJre ip relêithvely stable. This is a difficult well to tell the difference between thermal and pressure bleeds and trends. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com ~~NE.Ð MAR ø 9 Z007 «2F-04 90 day TIO plot 3-06-07.gif» «2F-04.pdf» Content-Description: 2F-04 90 day no plot 3-06-07.gif 2F-04 90 day TIO plot Content-Type: image/gif Content-Encoding: base64 Content-Description: 2F-04.pdf 2F -04.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 3/9/2007 10:26 AM ARca Alaska, Inc.A SSSV (1833-1834, OD3.500) TUBING (0-7455, OD:3.500, ID2.992) Gas Lift !andrel/Dummy Valve 1 (7330-7331, OD:5.940) PBR (7382-7383, OD:3.500) PROD. CASING (0-8039, OD:7.000, Wt:26.00) PKR (7390-7391, OD:3.500) NO GO (7423-7424, OD:3500) SOS (7454-7455, OD:3500) TTL (7455-7456, OD:3.500) Perf (7617-7627) Perf (7641-7675) . . GKA : 2F-04 2 F -04 Depth TVD 1833 1809 7382 5764 7390 5770 ~-7'423 5796 7454 5820 I 7455 5821 Type SSSV PBR PKR NO GO SOS TTL Description Otis 'QlP' locked Out 3/30/9§L Baker wi locator Baker 'FHL' hyd. set Retr. H Camco 'D' Nip Ie Baker ID 2.812 2.810 2.890 2.750 2.992 ' 2.992 i DM'? 1.5 - ---------~~- 2F-04 90 TIO I 246x769 I of 1 3/9/2007 .~ 1"""""'\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Sf:t- 4/U(D4- Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2F-04 04/23/04 Brake I Rogers NA Packer Depth Pretest Initial 15 Min. 30 Min. well2F.Q4 I Type Inj Is I T.V.D. I 5770 I Tubing I 2310 I 2310 I 2310 I I Interval I 0 P.T.D. 1831900 Type Test P Test psi 1500 Casing 1760 3000 2750 P/F F Notes: 1st Attempt - Diagnostic test. OA: 260/300/300 Well 2F.Q4 I Type Inj! S I T.V.D. I 5770 I Tubing I 2310 I 2310 I 2310 I 2310 !Intervall 0 P.T.D. 1831900 Type Test P Test psi 1500 Casing 2750 3000 2980 2980 P/F P Notes: 2nd Attempt - Diagnostic test. OA: 300 I 300 1 300 1 300 weill I Type Inj I I T.v.D'1 I Tub~ng I Interval P.T.D. Type Test Test psi Casing P/F Notes: weill I Type Inj I I T.v.D'1 I Tubing I I: I Interval I P.T.D. Type Test T est psi 1500 Casing P/F Notes: weill I Type Inj I I Tv.D'1 I Tubing I I: I Interval I P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 2004-0423_M IT _KR U _2F-04.xls 4/26/2004 STATE OF ALASKA ~ ALAS,: OIL AND GAS CONSERVATION COMI,. SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate L~ Plugging [] Perforate ~ Pull tubing Alter Casing F~ Other ,~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 127' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 636' FSL, 1866' FEL, Sec.28, T11N, RgE, UM At top of productive interval 1232' FNL, 1146'-FWL, 5ec.28, T11N, RgE, UM At effective depth 1023' FNL, 1034' FWL, Sec.28, T11N, R9E, UM At total dFel~Lt, h 980' 1013' FWL, Sec.28, T11N, RgE, UN 7. Well number 2F-4 8. Approval number 7-25 9. APl number 50-- 029-21065 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 108' 3016' 6874' Production 8050'MD 6318'TVD 7954'MD 6235'TVD Size 16" 9-5/8" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 250 sx CS II 850 sx'AS III & 650 sx Class G 250 sx AS I & 280 sx Class G None None Measured depth 108'MD 3016'MD 8039'MD Rue Vertical depth 108'TVD 2749'TVD 6308'TVD Perforation depth: measured 7617 ' -7627 ', 7641 ' -7675' true vertical 5948 ' -5957 ', 5969' -5997 ' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail 7454' Packers and SSSV (type and measured depth) FHL pkr ~ 7383' & QLP SSSV ~ 1814' 12. Stimulation or cement squeeze summary N/A Interva s treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ I hereby certify that the foregoing is true and correct to the best of my knowledge ~ 15. Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Submit in Duplicate (DANI) SW02/036 STATE OF ALASKA ~-" ALASKA UIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service *eli Water Injector / OIL [] GAS [] SUSPENDED [] ABANDONED [] . SERVICE I~ . . , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-190 3. Address 8. APi Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21065 4. Location of well at surface 9. Unit or Lease Name 636' FSL, 1866' FEL, Se¢.28, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1232' FNL, 1146' FWL, Sec..28, T11N, R9E, UM 2F-4 At Total Depth 11. Field and Pool 980' FNL, 1013' FWL, Sec.28, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 127' RKBI ADL 25657, ALK 2583 12. Date Spudded01/24/84 13. Date T,D. Reached01/31/84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' I~°' °f C°mpleti°ns04/01/84* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVI~) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8050'MD,6318'TVD 7954'MD,6235'TVD YES E~ NO []I 1814 feet MD 1400' (approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 16" 62.5# H-40 Surf 108' 24" 250 sx CS Il 9-5/8" 36.0# J-55 Surf 3016' 12-1/4" 850 sx AS Ill & 650 sx ;lass G 7" .26.0# J-55 Surf 8039' 8-1/2,' 280 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING REC'ORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 761 7 '-7627 'MD 3-1/2" 7454 ' 7~,8~ ' 7641'-7675'MD w/4 spf,90° phasing '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5948 '-5957 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5969'-5997'TVD See attached Addem]um. dated 10/11 for Fracture datl. . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc,) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-M%: WATER-BBL' CHC~KESlZE' I~AS-OI'LRATIO TEST PERIOD I~ I ,_ Flow Tubing Casing Pressure ' CALCULATED OIL-BBL GAs-McF wATER-BBL OIL GRAVIS'Y-APl (corr) ° ' ' Press. 24-HOUR RATE 28, coRE DATA Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ct'~ ,c~iF:~ IV E D None. L ,~-, L Alaska 0ii & r:as Oons. Commissio~ Anchorage *NOTE: DRilled RR 02/02/84. Perforated well & ran 'cubing 04/01/84. Well worked over 02/06/87. Form 10-407 WC2/O56/DANI Submit in duplicate, /~/ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,.'. ~ " " ; 30.;' ( GEOLOGIC MARI(ER~ ' - :; . ' 'FoI~MAT'ION TESTS · ,. . - . .. '-: . . . ~ ~ ~ '; . . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , Top "B" Sand 75t7' 5869' N/A Top Lower Sand 7605' 5939' Base Lower Sand 7766' 6072' 31. LIST OF ATTACHMENTS Addendum (dated 10/11/84). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _ j~ Associate Engineer 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". Form 10-407 ARCO Oil and Gas Company,~,'~' Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on Ihe first Wednesday aftei' a well is spudded or workover operations are started. Daily work prior to Sledding should be summarized on the form giving inclusive dates only. District Alaska County, parish or borough North Slope Borough Lease or Unit ADL 25657 JTitle Completion ISlale Alaska Kuparuk River JWell no. 2F-4 Auth. or W.O. no. AFE AK1924 Nordic 1 API 50-029-21065 OperatorI I IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun ]Date ]Hour Prior status ii a W.O. Complete 2/03/87 2345 hrs. Date and depth as of 8:00 a.m. 21o4187 2/05/87 Complete record for each day reported 56.24% 7" @ 8039' 7954' PBTD, Set BPV 10.0 ppg brine Accept ri~ @ 2345 hrs, 2/03/87. Att to rev circ; orifice plugged. RU WL, tst lubr to 1000 psi. RIH, pull ck vlv f/GLM #4, POH, RD WL. Circ & displ well w/10.O ppg brine. 7" @ 8039' 7.954' PBTD, Circ 10.2 ppg brine 10.2 ppg NaCl/NaBr Displ well w/10.0 ppg brine. ND tree, NU & tst BOPE. Pull tbg hgr; pkr moving up hole. Pull BP, circ hole vol; well flowing. Wt up brine to 10.2 ppg. Signature~j..~ ~ Fo~oo rm- prepar~ see Procedures'f~anual, Section 10, Drilling, Pages 86 and 87. lDate Drilling Supervisor AR3B-459-1-D Number aH daily well history forms consecutively las hey are prepared for each well. iPa~ no. ARC~, Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitte(~ also when operations are suspenaed for an ~ndefimte or appreciable length of lime. On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation ~f space is available. Accounting cost center code District ICounty or Parish Alaska Lease Field or Unit Kuparuk River ADL 25657 Auth. or W.O. no. T tie AFE AK1924 Completion Nordic 1 API 50-029-21065 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 2/03/87 Stale North Slope Borough Alaska 1915 hrs. Date and depth as of 8:00 a.m Old TD 2/06/87 2/07/87 Released rig Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data Complete record for each day reported Iotal number of wells (active or inactive) on this dst center prior to plugging and bandonment o! this well our IPrior status if a W.O. 2345 hrs. I IWell no. 2F-4 7" @ 8039' 7954' PBTD, POOH 10.2 ppg NaC1/NaBr POOH w/3½" tbg. Chg out couplings to AB-Mod. LD pkr. TIH w/BP, set @ 6315', tst to 1000 psi. TIH w/RTTS & storm vlv, set @ 60'. ND BOPE & tbg spool. Chg out tbg spool to 5000 psi, tst tbg spool to 3000 psi. TIH, retry RTTS. TIH, latch BP & POOH w/same. Tst SSSV to 1000 psi. Displ well w/diesel. 2/6/87. 7" @ 8039' 7954' PBTD, RR 6.8 ppg diesel RU & rn 232 jts, 3½", 9.3# J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1814', FHL Pkr @ 7383', TT@ 7454'. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree to 250/5000 psi. Tst CV w/1000 psi on tbg. RR @ 1915 hrs, : JNew TD JPB Depth 7954' PBTD 2/6/87 Rotary Type completion (single, dual. etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Oats Reservoir Producing Interval Oil or gas Tesl time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Eflective date corrected The abo,~e is correct For form prepa a~t~}n and distribute. see Procedufes'-Manuah Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C iNumber all daily well history torres consecutively as they are prepared for each well. iPage no. DlvldO~ of AtlanllcRIchfleldCompa3y STATE OF ALASKA ~--'-' ALAS~-,~ OIL AND GAS CONSERVATION COM,,,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ,~ Re-enter suspended well r~ Alter casing ~, Time extension ~ Change approved program [] Plugging [] Stimulate ~, Pull tubing '~ Amend order ~ Perforate- Other- 2. Na['Qft..of~ .Operato.r 5. Datum elevation (DF or KB) ~r~.u A/aSKa~ Inc. RKB 127' feet 3. Ad~r~SsBox 100360 Anchorage, AK 99510-0360 6. Unit or Property name · ' Kuparuk River Unit 4. Location of well at surface 636' FSL, 1866' FEL, Sec.28, T11N, R9E, UM At top of productive interval 1232, FNL, 1146' FWL, Sec.28, TllN, R9E, UM At effective depth 1023' FNL, 1034' FWL, Sec.28, T11N, R9E, UM At total depth 980, FNL, 1013' FWL, Sec.28, TllN, R9E, UM 7. Well number 2F-4 tz), ~'~ 8. Permit number 83-190 9. APl number 50-- 029-21065 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor- 108' Surface 3016' Production 6874' 8050'MD 6318'TVD 7954'MD 6235'TVD Size 1 6" 9-5/8" 7" feet feet feet feet Plugs (measured) None Junk (measured) Cemented 250 sx CS II 850 sx AS III & 650 sx CI'G' 250 sx AS I & 280 sx CI'G' None Measured depth 108 'MD 3016 'MD 8039'MD True Vertical depth 108 'TVD 2749 ' TVD 6308 ' TVD Perforation depth: measured 7617 '-7627', 7641 '-7675~ true vertical 5948' -5957', 5969'-5997~ Tubing (size, grade and measured depth) 3-1/2", J-55, ~ 7435' Packers and SSSV (type and measured depth) RRH ~ 7405' & QLP @ 1835' 12.Attachments Description summary of proposal ~,. Detailed operations program -- BOP sketch 13. Estimated date for commencing operation January 30~ 1987 . 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~'~ ~,U/~f.,h,~ Title Associate Engineer ~// Commission Use Only (JLQ)SA/201 Date Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Workovers Coupling & Wellhead Changeout Without Pulling Packer Preliminary Procedure and Cost Breakdown Pre-Ri~ Arrival Operations 1. Set positive plug in 'D' nipple & test same. Bleed pressure off tubing and annulus. 2. Pull gas lift valve from 1st mandrel above retrievable packer. 3. Circulate kill weight fluid. Test wellbore to 1000 psi. Rig Operations 1. Move in, rig up workover rig. 2. ND tree. NU BOPS & test same. 3. Pull tubing free from packer. POH 2 stands. 4. PU storm packer &mU same into tbg string. 5. GIH 1 stand. Set storm packer. Rel f/same & test to 500 psi. POH. 6. ND BOPS.Changeout wellhead to 5000 psi equipment. NU BOPS. 7. GIH & latch storm packer. POH with same. 8. Fin POH with tubing. LD GLMs & changeout couplings to AB MOD while POH. 9. Re-run completion assembly with reconditioned AB MOD GLMs. 10. ND BOPS. NU tree. 11. Displace well to diesel. 12. Release rig. 13. Move in, rig up slick line unit. 14. Pull plug from 'D' nipple. TOTP~. Anticipated Bottom Hole Pressure: 3100 psi Completion Fluid: 10.2 ppg NaC1/NaBr Brine II - ANNULAR PREVENTER 6 PIPE RAMS 4 BL I ND RAMS 5 TUBIN6 HEAD 2 . , , 10. 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD 11. 3. 11"-3000 PSI X 7-1/16"-5000 PSI 12. TUBING HEAD ! 3. 4. 7-1/16" - 5000 PSI PIPE RAMS S. 7-1/16" - 5000 PSI BLIND RAMS 14, 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. !~. ...... : :~ ,: v ~, .; BOP STACK TEST . , . [.:,', ..... ij:.i , ' , ,,,,, ;~ - ~.i ,r; FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN PIPE RAMS. BACKOFF P. UNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PS! FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. JG JULY 28, 1986 ('NORDIC RIO 9-5/8") ADDENDUM WELL: 2/1/84 3/14/84 9/16/84 9/21/84 9/23/84 2F-4 Arctic Pak w/250 sx AS I, followed by 54 bbls Arctic Pak. RIH w/GR/CBL/CCL, tag btm @ 7939' WLM, POH logging Rn gyro. Start frac @ 1734 hrs, 9/16/84 Pmp 40 bbls, 120° diesel w/5% Musol @ 15 BPM/4300 psi. Pmp 45 bbls pad of H~O/gel @ 15 BPM/3310 psi; 24 bbls Ho0/gel w/ 1 ppg, 100 mesh (1000#) @ 15 BPM/2850 psi; 25 b~ls pad of H90/gel @ 15 BPM/2720 psi; 27 bbl gel w/2#/gal 12-20 sand (2000#) @ 15 BPM/2580 psi; 59 bbls gel w/7 ppg 12-20 sand (15,200# total) @ 10 BPM/2360 psi. Flush w/74 bbls diesel/gel @ 10 BPM/2720 psi. Frac in place @ 1406 hrs. Ck sand fill inside tubing Perf's: 7617' - 7627' and 7641'-7675' RIH w/sinker bars, tag fill @ 7642' POOH RD Well SI Ck sand fill inside tbg Perf's: 7617' - 7627' and 7641'-7675' Top of sand @ 7642' RU CTU, pmp 40# gelled diesel @ 7000'. Circ dn to 7943' @ 1.6 BPM w/moderate sand ret's. Calc top @ ±7700'. Circ cln while holding ±300 psi back pressure. Pmp 175 bbls diesel, circ up to 5550'. Build back pressure up to ±500 psi; stop pmp'g, shut well in @ wing, POOH, RD CTU. Rec'd ±9± bbls crude, diesel, LW. SI well, RU S/L, RIH w/sinker bars, tag sand @ 7704' (±29' rathole below btm perf). Well rel'd to Production. Drillihg Superintendent /O-~Z~D~a te STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []iX OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. :BOX: 100360, 4. Location of Well SURFACE LOCATION: TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127 ' (RKB) ANCHORAGE, ALASKA 99510 636' FSL, 1866' FEL, SEC. 28, 6. Lease Designation and Serial No. ADL 25657 ALK 2583 7. Permit No. 83-190 8. APl Number 50- 029-21065 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2F-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 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). On November 2, 1985 KuparUk well 2F-4 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED Alaska Ou & Gas Cons. Oommissior~ Anchorarj9 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Date Signed J. //'/'~Z~-i~ ~.~./,./.~"-';~ Title The space below for Commission use 12/04/85 Conditions of Approval, if any: Approved by By Order of 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, .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed on the 1F-4 1F-5 1F-8 1G-3 1G-4 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-7 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 ~ 2F-1 5 2F-16 2D-10 2D-16 Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion ConverSion Conversion Convers,ion Conversion Conversion Conversion Conversion Conversion Conversion' Conversion Conversion Conversion Conversion Conversion Conversion' Conversion Conversion ARco Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany 10/24/85 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 1115185 1115185 1115185 11/6/85 1116185 1116185 1116185 1116185 11/6/85 1112185 1112185 1112185 11/2/85 11/6/85 1116185 ARCO Alaska, Inc/'-", Post Office. _x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .September '20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The Second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED S E P o 0~ & G~s Cons. Commission ARCO Alaska, Inc, is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASK/~"~IL AND GAS CONSERVATION ¢"--VIMISSION SUNDRY'NOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well. N/^ 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 99510 t 6 . Lease Designation and Serial No. see attached 7. Permit No. see attached 8. APl Number so- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Pull Tubing 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 [] [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10o407 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). /D Pursuant to form 10-403, it is proposed that the attached list ofJ^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion_~ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be' into the A and C sands. RECEIVED SE? 2 0 19 5 AlasKa Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :~, .~~ ~.,~,~r-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy .Returned ~ By Order of COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D' 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:009 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 -85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 '21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 I! 25658 25658 25657 !! !1 25656 25644 25643 !! 25655 25644 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 '2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " ~/15/85 SE? 2 o ~lHsk& Oi! &' Ga.~ Coris CoF,~missior, ARCO Alaska, Inc - .: Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 2F-4 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG' tw GRU7/L09 Enclosure Nesk8 0t~ & G~s Cons. commission ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~' STATE OF ALASKA -'-~ ~~ ALASKA.~ILAND GAS CONSERVATION C AMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-190 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21065 4. Location of well at surface L~-~/~"~'~ 9. Unit or Lease Name 636' FSL, 1866' FEL, Sec.28, T11N, RgE, UM At Top Producing Interval J .~- i 10. Well Number 1232' FNL, 1146' FWL, Sec.28, T11N, RgE, UMISurf'~ 2F-4 At Total Depth H. __~_~_~_1 11 Field and Pool .;, . 980' FNL, 1013' FWL, Sec.28, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKB ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1/24/84 01/31/84 04/01/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8050'MD,6318'TVD 7954'MD,6235'TVD YES ~ NO [] 1835 feet MDI 1400' (approx) 22. Type Electric or Other Logs Run D IL/$FL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" '62.5# H-40 Surf 108' 24" 250 sx CS II 9-5/8" 36.0# J-55 Surf 3016' 12-1/4" 850 sx AS Ill & 650 sx Class G 7" 26.0# J-55 Surf 8039' 8-1/2" 280 sx Class G & 250 s: AS I 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) 3-1/2" 7435 ' 7405' 7641' - 7675' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7617'-7627' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production j Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None. RECEIVED APR2 4 1984 Alaska Oil & Gas Cons, Commission Anchorage Form 10-407 GRU7/WC01 Submit in duplicate Rev. 7-1430 CONTINUED ON REVERSE SIDE · - : ;. ' : GEOEo~ICM~-RkERS :' ' ~' · ' ': :- ': ;:':!' '~ :i'.":"~:!'i.¥ ;;' !i' , ' ' 'FORMATION" ...... TESTs : -- · · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top "B" Sand 7517' 5869' Top Lower Sand 7605' 5939' N/A Base Lower Sand 77.66' 6072' . '~. '~t~ ~ -~.~ ': .'7 . i : -~ (,~7.!' "' ,; .:~ :.' !.. .I.'. ' ' ;~1:] " ," ,( 31. LIST OF ATTACHMENTS Dri I ] i ng Hi story, Comp1 etion Summary, Gyroscopic Survey (2 copi es } 32. I hereby certify that the foregoing is true and coFrect to the best of my knowledge Signed Title Area Drillinq Enqr. 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' A~tached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ;~ : ~ . - ~ -. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jectiOn, Gas' In~ieCtion, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 2F-4 DRILLING HISTORY NU 20" Hydril & diverter and tstd same. Spudded well @ 1500 hfs, 01/24/84. Drld 12-1/4" hole to 3030'. Ran 70 jts 9-5/8" csg 36# J-55 HFERW BTC csg w/shoe @ 3016", Cmtd 9-5/8" csg' w/850 sxs AS III & 650 sxs class "G". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Performed top job using 48 sxs ASI. Instld 9-5/8" packoff and tstd ok. NU BOPE & tstd to 3000 psi - ok. Witnessed by Doug Amos AOGCC state rep. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10 new form. Tstd form to 12.5 PPg - EMW - ok. Cont Drlg 8~" hole to 8050' TD as of 01/31/84. Ran logs DiL/SFL/SP/GR/FDC/CNL/CAL f/8036'to 3017'. Ran 184 jts 7" 26# HFERW "G" Bumped plug w/3000 BTC csg w/shoe @ 8039. Cmtd 7" csg w/280 sxs class · psi - floats held - ok. ND BOPE. Installed 7" packoff & tstd to 3000 psi - ok. Displace brine from top of well. Performed downsqueezed Arctic pack job using 250 sxs AS I and 54 bbls arctic pack. Secured well and released rig @ 0600 hfs on 02/02/84. HILL/DH80 2/09/84 ih RECEIVED APR 2 4 1984 Alaska Oil & Gas Cons. Commission Anchorage 2F-4 Completion Summary RU Gearhart. Ran GR/CBL/CCL; good bond. Ran Gyro. RD Gearhart. Secured wel 1. Accepted rig @ 1800 hrs, 03-31-84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran gauge ring/JB to 7930' WLM. Perforated the following intervals w/4 spf, 90° phasing: 7671' - 7675' 7661' - 7671' 7651' - 7661' 7641' - 7651' 7617' - 7627' Ran 3½" completion assy w/tail @ 7435', pkr @ 7405', & SSSV @ 1835'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel & crude oil. Dropped ball & set pkr. Opened SSSV. Set BPV. Secured well & released rig @ 2000 hrs, 04-01-84. GRU7/CS01 RECEIVED APR 2 41984 Alaska Oil & Gas Col'tS. Cornmiss/on Anchorage A R I..-.:O a I_ ASI< A, I I,,IC ,, K I...I F:'A R I_1K f=' I E L [I, N ('i R T H S L. L-I F:'liE, A !... A'-E; I< A SIGMA""GYRO., 0-7':?54 FID, L:.;URVEYOF(: F:'EFFERI':.'.OF(N/,JAHN., DATE RUN: I:3-MAF,:-:=:4. · :. T.:! I'~(..'~h'Ti~-T:~'~E P, II...I ...... :., F' Ct R [::: :.:J: I G I"'1'1": N '.:.~ :=: 7 14 :::i:URVI="EY 'I'AI':::I."'j:Ixl F:"ROH HEL. LI'iL'EA'O' Whipstock A PETROLANE COMPANY REC:ORf'I OF....c'IIRVEY RADILIS /'3F C:I_IRVATLIRE METHOD F::'AD 2F:., WIE.:.I...L IxlO: 4 S I GMA-.('.'iYRO i:ili'ijF'ARI..IK FIELD~ N(]RTH '.='";I...OF:'E~ AI.ASKA ,_10 B 1`40: A C):384 Z 0241 TRI..IE "~'-;'~='~- --: ' "'~- .......... I_..L--~I .:, K1-R E DUi..:/[..E..;, MEA:'..'i;I.,.II::{E:f'.~ I:)R I FT I]R I FT COURSE: VERT I C:AL VERT I C:AL :~;%...IB.::,E~- R E-~. T'~I.: ]LF'[.. ~ "R ..... ~ ....... '~ ......... r ................................ ....... DEF'TI-.! ANGI....E.' D I IREr':'F I ON, I..ENGTH DEPTH SECT I ON TVD.. 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'-."¢'-~. 4._,._ 6, L-.',::: 2:386.22 N '1572. 1/-,_ 14 "--:':::.=;7.,.. _ _ . ._.=,,':',_, N :3:3 2:3 W 0,:]::3 ~i:.'=.~0(),, 4/=, :=:6, N =:.% 2:=: W 1(')(') 47,J.-=.57 '2'.=./2'.=.~ 5/=, 4/_',';=5 57 c44._ /_-,:2 N 1,/_-,14 ('):2 W 29:=:(:) 21 N :2::.-'.: 2~ W (") :.=.::2: ARCO AI,ASKA~ IAIC. I:::'AD 2F I,,IEL. I .... N(]: 4 '::'IGMA--(i;YRO I:i!:i.jiSARUK FIELD~ NI]RTFI SI_OF'E., AI_ASI<A .lOB 'l ' N~ ....A (").2:84 Z 0:24.1 ''1 l R JE C 0 MI=']..] T A'T I [] N I:::' A G E N 0. ' :3 T I ME DAT'E ' I"IEASURIED DIRIF'T DRIFT C:OIJRSE VERTICAL VERTICAL F:IJBSEA R E C T A N G LI L. A R E ~. U :5 U 'fiE:. DuuLE..L:; DEF'"FI"~ ANGI_E El I RECT I liN LENI]i'T'H DEPTH REI-:T I ON TV[I Il: ID O R D I N A T E '.:S El I STANI]:E El I REC]' I F)N '.:i;EVEF~ I 'l""," F:'Ei:ET I:) M [, P1 FF:EI' FEET FEET FEET FEEl' . FEE. T I] M I:)F:;/lC)()F"t' /_.-,O(')C) 46 ""':: 3F)02,0'~ 4./:,:T~4 '-"-' 2~F)4 91 N 1 ,:: ....... ,. 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Al 2.=_:;. :2:7 W 75 . 61/-':;_,._ .78 4:294 .04 AO:3F:_ .78 .:,'"'~'-'~'.. o,:,, 12 N .-":'":'/- ':-'._, _,._,, ~':.Z_. W 4294 , ':'-~::::.. _ N :2::2: 2:'"': W 2 . ,-,,:::_ · ,, P R O...I E C l'E ]0 'r' 0 F' B"F D F:I R I-I,..I E F: 'I"E D 'T 0 1" D 9 6.. /:,::2:18.21 4379.44 61 ? 1. ?' 1 3 6, 6, 3.62 N '2400.70 W 4 ::2:8 F). 1:3 N :--: ::: 14. W 0.00 F I N A L C L I'j S I_1R E - D I R E C T I 0 Al: D I S T A N C E: .... _-: ,D E G:-=: 14 M I N.'5_-: 10 S E C S W 4:=:80. 13 FEET A PETROLANE COMPANY I:::' A :["t 2 F W E'E.L L Nt:'i: 4. '- .......... ' '" ...... :..I. b M A'-f.:, Y F',, LI I<LIF:'AF~I...IK F'IELD, NORTH F:;I..OPE, ALAL-'!;KA ,..II:"IT-'_'.~ NO: AO:BS/!-Z()I;:41 ........................... M.ARr:::ER ................. '1' Fi LIE S I_1B ::,':; E A ............................... CODE .............. MEA.::...IREB VERTICAL MD-TVD VERTICAL R E C: ]" ............................ NAME .................. DIEF'"['H DEF'TI-t DIF'F DEPTI,.t C O O R D I N A T E." '._:; I"~IS'.A _ F E:'E ]' F: EE T F EE'F FEE T F E E T F' E E T D M Eastman Whipstock A PETROLANE COMPANY - : : : - i , , : I . · i I ' ' ..... I : ...I .... ~ ~ ~ ~ : ; ~ ~ i · : ~ i , : : ' , : ~ : I I : ~ ~ ~, ; ~ ! , Suggest~ form to be inserted in each "Active" well folder to d]eck for timely compliance with our regulations. Ope-rat'or,~el ~ Na~e and Numbe~ Reports and Materials to be received by: Date Required Date Received Remarks . Cc~pletion Report Yes .~__Well History . . Yes -.. Core Chips -' C o r e De s c rip tion ~"~'~~'~'~" ' . .... " o Registered Survey Plat . .I n c l ination Survey Directional Survey ,Drill Stem Test Reports · Prcd~ctiOn Test Reports ,Y~-~ ,~ '~c~ ~ --~_~ 0/~ Digitized Data · , , ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 10, 1984 Hr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Hr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' 2F-1 2F-4 2F-2 2F-16 2F-3 2V-3 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG' tw GRU6/L91 Enclosures ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~... STATE OF ALASKA ~-. ALASK, .IL AND GAS CONSERVATIONC AMISSION 'SUNDRY NOTICES AND REPORTS ON WELLS (/ 1. DRILLING WELL[] COMPLETED WELL ~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage,' AK 99510 4. Location of Well Surface: 636' FSL, 1866' FEL, Sec.28, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 12. 7. Permit No. 83-190 8, APl Number 50- 029-21065 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-4 11. Field and Pool Kuparuk River Field I6. Lease Designation and Serial No. Kuparuk River 0i I Pool ADL 25657 ALK 2583 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). RU Gearhart. Ran GR/CBL/CCL; good bond. Ran Gyro. RD Gearhart. Secured well. Accepted rig ~ 1800 hrs, 03/31/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran gauge ring/JB to 7930'WLN Perforated the following intervals w/4 spf, 90° phasing: 7671' - 7675' 7661' - 7671' 7651' - 7661' 7641' - 7651' 7617' - 7627' \ Ran 3-1/2" completion assy w/tail ~ 7435', pkr ~ 7405', & SSSV @ 1835'. ND BOPE. ok. Disp well w/30 bbls diesel & crude oil. Dropped ball & set pkr. Opened SSSV. released rig @ 2000 hfs, 04/01/84. NU tree & tstd to 3000 psi- Set BPV. Secured well APR '}_ ;x :~:,¢~.~i 14. I hereby cer.~n-~ that the foregoing is true and correct to the best of my knowledge. //~Q~. ~ Area Drilling Engineer Signed , _ Title The space be~w f~//ss/on use Condii:ion, d'of Apprq~'r. if an~: By Order of Approved by COMMISSIONER the Commission Form 10-403 GRU6/SN40 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Date: Well Name: DISTRIBUTION NSK Operations Bluel'ine Dr ill ing Bluel ine Geolbgy /K_~3~ ~Jlm Sign &/~e: turn the attached~ copy/~./recei~t..~.f' d~a.~ t i,~.q rn to: ',!~,~i<.q :~t~ ..'%t "':'~q (.',,ti-iS. ARCO ALASKA ;r~INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING Well Name: Transmittal Lo~ Date Run DISTRIBUTION NSK Operation Blueline Dr ill ing Blu el ine Geology Bi/Se/Film R&D Bluel ine D&M Bluel ine _ F.G. Baker Blueline D.B. Schaf er Blueline Sign & return the F~%%~d~e~ copy as receip, t of data. Return to~. ~CO AI~SEA, INC. ~/ ATTN: D. Fay ALL[SON ATO-111~B P. 0. Box Anchorage, AK 99510 OHFinal KUPARUK ENGI~,iEERING TRA~ISNITTAL # ~/~ TO' FROM' D. r Fay Allison WELL NAME- see below Transmitted herewith are 'the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM TAPE, PC - PHOTOCOPY Well Description Date Run ~I'PT ACKNO. WLEDGED' /~EASE RETURh RECEIPT TO' ARCO ALASKA, I~C. ATTH: D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 995].0 MEMORANDUM TO: THRU: State¢ of Alaska ALASY~, OIL A~ GAS CONSERVATION CO~R-~SSION Lonnie C. Smith ~ ?" ~ Commissioner DATE: February 21, 1984 FILE NO: 4 I. t TELE'PHON E NO: FROM: Doug Amos ~'¢ Petroleum Inspector SUBJECT: Witness BOP Test on ARCO' s Kup 2F-4 Well SeC. 28, TllN,R9E,UM, Permit No. 83-190 on Parker Rig No. 141. Thursday, January 26, 1984: I traveled this date from Anchorage to 'P~udh0~ Bay' %o with'ess t'he BOP test on ARCO's Kup. 2F-4 Well. Friday, January 27,_. 1.98.4: The BOP-test commenced at 3.:30 am and was concluded at 5:30 am. There were no failures.and I filled out an A.O.G.C.C. BOP test report which is attached. In summary, I witnessed the successful BOP test at ARC0's Kup. 2F-4 Well. Attackment 02-O01A(Rev. 10/79) ' ARCO Alaska, Inc ~ Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-! 2V-6 WSP #3 2F-2 2V-7 WSP #13 2F-3 2V-8o Hemi Spring St #1 2F-4 2B-5 Thank you. Sincerely, ~ win ~n Engineer A~~t Dri ' g JBK/SHi:ih /.r.:c.o A,.-~.i.~t. Inc ~.-: ;, $.osidiar¥ Of Allanl:¢RichlieldCo;npa. F , ' ' STATE OF ALASKA /,~ ALASKA..~IL AND GAS CONSERVATION C.._.,1MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS/ · Drillin§ well [~ Workove~ operati ~-~ :2. Name of operator_ 7. Perr~ Nf~0 ARCO Alaska, Inc. - 3. Address 8. APl N~r21065 P. O. Bo× 100360, Anchorage, AK 99510 50-- 636' FSL, 1866' FEL, Sec.28, TllN, R9E, UM 9. Unit or LeaseName Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 98' 127' RKB 6. Lease Designation and Serial No. ADL 25657 ALK 2583 10. W ~ I~N....o~ 11. Field and Pool Kuparuk River Field West Sak Oil Pool Obj. For the Month of January ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1500 hrs, 01/24/84. Drld 12-¼" hole to 3030'. Ran, cmtd & tstd 9-5~8" csg. Cont drlg 8~" hole to 8050TD. Ran logs. Ran, cmtd and tstd 7" csg. Displ brine from top of well. Performed downsqueeze Arctic pack job. Secured well and released rig @ 0600 hrs. on 02/2/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3016. Cmtd w/850 sxs Arctic Set III and 650~ sxs class "G". 7" 26# J-55 HFERW BTC csg w/shoe @ 8039. Cmtd w/280 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DTL/SFT,/SP/GR/CAL/FDC/CNT, f/8036'-3017'. 6. 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 Ar~_~ ~]]~ng En~ineerDATE be filed in duplicate with the Alaska NOTE--Rel::;o~ on#th'i~/~/rm is required for each calendar month, regardless of the status of operations, and must Oil and Gas/Conservatld'n Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 HILL/MRj 11 Submit in duplicate 2F-4 DRILLING HISTORY NU 20" Hydril & diverter and tstd same. Spudded well @ 1500 hrs, 01/24/84. Drld 12-1/4" hole to 3030'. Ran 70 jts 9-5/8" csg 36# J-55 HFERW BTC csg w/shoe @ 3016'. Cmtd 9-5/8" csg w/850 sxs AS III & 650 sxs class "G". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Performed top job using 48 sxs ASI. Instld 9-5/8" packoff and tstd ok. NU BOPE & tstd to 3000 psi - ok. Witnessed by Doug Amos AOGCC state rep. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10 new form. Tstd form to 12.5 ppg - EMW - ok. Cont Drlg 8½" hole to 8050' TD as of 01/31/84. Ran logs DIL/SFL/SP/GR/FDC/CNL/CAL f/8036'to 3017'. Ran 184 jts 7" 26# HFERW BTC csg w/shoe @ 8039. Cmtd 7" csg w/280 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND BOPE. Installed 7" packoff & tstd to 3000 psi - ok. Displace brine from top of well. Performed downsqueezed Arctic pack job using 250 sxs AS I and 54 bbls arctic pack. Secured well and released rig @ 0600 hrs on 02/02/84. HILL/DH80 2/09/84 ih 4/8o ., STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report 5',~ Inspector Operator ~ Location: Sec Drilling Contractor Representative Permit # ~ ~..ufc~Casing Set @ Representat ivo ft. Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke nine Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres .sure ~OO0 h ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure 1~~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: (~ . . / Controls: Master ~.~ Remo to min_~!_sec min ~ sec Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. flanges I ~Test Pressure ~Test Pressure ~/Test Pressure Test Pressure % ~('Test Pressure Adjustable Chokes Hydrauically operated choke Failures ~-~ ~ ~-- Test Time ~-- hrs. Test Results: Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. days and Remarks: Distribution orig' - AO&GCC · cc - Operator cc - Supervisor .Inspector ARCO Alaska, Inc. Post Office Bo"C~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 29, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-4 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on February 5, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/GRU5L90' tw Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~.5_AND GAS CONSERVATION CL .MISSION SUNDRY NOTICES AND REPORTS-"ON WELLS 1. DRILLING WELL[] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-190 3. Address 8. APl Number Po 0. Box 100360, Anchorage, AK 99510 50- 029-21065 4. Location of Well Surface: 636' FSL, 1866' FEL, 5ec.28, TllN, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-4 11. Field and Pool Kupa ruk Ri ver Fi el d Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate ~] Alter Casing [] Perforations Stim u la te [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Puli 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). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: February 5, 1984 Subsecluent Work 1]~_.ortecI 14. I hereby certi,~hat the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri ] l ing Engineer The space b on use Conditions O'f Approval~rf any: Date I~Y I. OH~IE C. S~iTll Approved Copy Returned By Order of Approved by COMMISSIONER the Commission Date /--~ ~ 0{~/___ Form 10-403 Rev. 7-1-80 GRUS/SN51 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate December 27, 1983 Mr. Jeffrey B. Kewln Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2F-4 ARCO Alaska, Inc. Permit Ilo. 83-190 Sur. Loc. 636' FSL, 1866' FEL, Sec. 28, TllN, R9E, Btmhole Loc. 1126' FNL, 1197' .~-%4L, Sec. 28, TilN, RPE, b~. Dear Mr. Kewln: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional surwey.is required as per 20 AAC 2§.050(b)(5). 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 16.05.870 and the regulations prom~algated 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 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, pl?ase notify this office 24 hours prior to commencing tnstatlatzon of the blowout preven- tion equipment so that a representative of the Commission may ~,1r. Jeffrey B. Kewir Kuparuk River Unit D ~mber 27, 1983 be present to witness testing of the equipment before the surface casing shoe is drilled. ~q~ere a diverter system is required, please also notify this ~ o~ce 24 hours prior to commencing equipment installation so that the Commimsion may witness testing before drilling below the shoe of the conductor ~ipe. In the event of ~uspension or abandonment, please give this office adequate advance notification so that we may b~ave a witness present. ,, Very truly yours, C. V. Chatterton Chairman o~ Alaska Oil and Gas Conservation Commission lc: Enclosure cc: Department o~ Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 'r.,._..~60 Anchorage, Alaska 99510 Telephone 907 276 1215 December 19, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-4 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2F-4, along with a $100 application fee ° A diagram showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system ° Diagrams and description of the BOP equipment Since we estimate spudding this well on January 27, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG5L78' tw Attachments · ..7 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OI L'~..-~ D GAS CONSERVATION COMM~/SION PI=FIMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] ! SERVICE [] STRATIGRAPHIC I SINGLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 636' FSL, 1866' FEL, Sec.28, T11N, RgE, UN At top of proposed producing interval 1402' FNL, 1371' FWL, Sec. 28, T11N, RgE, UN At total depth 1126' FNL, 1197' FWL, Sec. 28, T11N, R9E, UN 9. Unit or lease name .. Kuparuk River Unit ~-~ 10. Well number ~.. 2F-4 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 127' PAD 98' I ADL 25657 ALK 2583 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi, NW of Deadhorse miles 1126' @ TD feet 2F-3 well 60' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 18. Approximate spud date 7839' MD, 6295' TVD fe~t 2560 I 01/27/84 19. If deviated (see 20 AAC 25.050) [20. Anticipated pressures 2858 KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 42 oI (see 20 AAC 25.035 (¢) (2) 3207 psig@ 80OF Surface psig@ ~20~ ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 24" 16" 65.5# ~ 2-1/4" 9-5/8" 36.0# -1/2" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 HF-iRW BTC J-55 BTC HF-ERW Length 80', 3016'I 7811 SETTING DEPTH MD TOP TVD 29' I 29' 29' I 29' I I 28' I 28' MD BOTTOM TVD 109'I 109' 3045'12754' I 7839'16295' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 800 sx AS III & 600 sx Class G 300 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7839' MD (6295' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3045' MD(2754' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2858 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-SS, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby cer~at the foregoing is true and correct to the best of my knowledge The spacebelo ~~~-n ~ '-- - ~~ ~ CONDITIONSOFAPPROVAL Samples required []YES Permit number .~i ~o APPROVED B Form 10-401 Mud log required r-lYES ~O Approval date DATE Directional Survey required I APl number D~.YES []NO 50--O 'Z.,'~ - '/-~i O (~.~-- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE Submit in triplicate PERMIT TO DRILL 2F-4 installed and tested upon completion of the job. 2F-4 will be 60' away from 2F-3 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6855'MD, approximately 500'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. ~,ARCO ALASKA. [,NCo - . -- '!~"PAD 2F. WELL NO, q- PROPOSED ~ L::L*L--_-'/_II_'%~_-:~-_::~X:_-_-- ~_-E-Z-ZZ '.-.f-KUPARUK FI_ELD.; NO.R.r_H_ .S_L.O_P_~_,_ A_ L_ _&S_ K_~. '-- .~ EAST.A. WHtPSTOCK.. [.O ...... ;, ' - ~ *-', xd/---; ...... t-~- i: j ---+: -~ .... ' ' ' :' -7.._-..5_._/[ ~__suar,cE: ......... ._: , : I · ; - 000 _KOP .TVD~.IOOO.._[I~-=-. 00..[)I~_?O.:L£__:Z '- - :T(-L.---q-: ? ~_,: ~-;-- ; '; :!:, ;i, --- t: ,oo ,',' ZE::f-:- .... ' :" : · "'. r~ ~:s. BASE--PER~-^F-RqS-~---TVD=l'477': THD~3-4827DEP=6! + , --- i ;;; ;-;':.1. " I%' ' e? TOP UONU SNDS: TVD=1887.:THD"~9~2: DEF-_~.._8-'- ~_~_-~7T---7~- ! ~ . MO 0 I %. TOP-W S~:: ;SND$--TVD-245~-:f-~~--~,,~'J~ : ~ .: ': ! :::. !ii:: !!iiii : ...................... ; ............... ~ - : : ' ~ ; [ : : : I [ i ; : i : ; i : i'. !I ~ : :' '-' '1 ...... '~-- 1<-"t2. TVD 27t? fI"tI~.29e$'~EI'EP~t'cJ-~ ..... I . \ .... , .....~ ~----!-- · -: ....... i----~ .-h >. - i-- .~ . .. 4;2 BEG:24::-I~'N -~-::_,U:lO.O ....... , ,..'-' ............. ':----- '.~---;-- - ~ ! +- --i- ! ;---,-~.= , i ' --I ~,. ; ..... :-7'! ...... _%_. ..... ~_ ; ? : i , ! . ' ~ I . ! , I. :' : I. : -,,-~- . - -; - -: ..... ~, ......... ~i.i- ; ! : i ' -- ~ --- ' ~ ~ : ' I · .,-4--~-:.I ~-~ · m . : - :~.~-? / ~-- ~ .... ~ ..... ;- · ' ' · * ' ~'~: ~ ~ ' ' ~ i -- .... SCALE 1 IN = 1000 FEET ..... ~-'-_' -'"-' PAD 2F. WELL NO~ ~ 4. ;-PRO~SED-'~ ..... :": .... /IIX . ~ooo--___-:'.-.-- ~oo~:_: _7:.-~o-~-_ ]ooo _~-:-: : 0_' i ...... ]..L :. ]~, .L. Oi. . · i t ] . 7 l· . . Surface Diverter System 16" - 2000 psi Tankco starting head. · Tankco quick connect assy, 16" x 20" 2000 psi double studded adapter. 20" 2000 psi drilling, spool w/lO" side outl ets. 10" ball valves, hydraulically actuated, w/lO" lines to rese~/e pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer· 20" bell nipple. · · . · . Maintenance & Operation Upon initial inslallation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every I2 hours. Close annular preventer in the event.that gas or fluid flow to surt'aca is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances.. 16" Conductor IANNULAR PREVENTER 9 BLIND RAMS PIPE RAMS 7 PIPE RhMS ~ 5 CSG HD · 1. FILL BOP STACK AND HANIFOLD t~ITH ARCTIC DIESEL. 2. .CHECK THAT ALL HOLD OOgN SCREMS ARE FULLY RETRACT- ED.. PREDETERMINE DEPTH THAT TEST PLUG TJILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCI( OOgN $CRENS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOY, ES AND BYPASS VALVES ON KaJ~IFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. G. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. 7. INCREASE PRESSURE TO 3000 PS! AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAN OF CHOKES. BLEED IX)gNSTREAN PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAIH!N6 UNTESTED HANIFOLD VALVES, IF ANY, ¥1TH 3000 PSI UPSTREAH OF VALVE AND ZERO PSI OOgNSTREAH. BLEED SYSTEH TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAHS AgO CLOSE BOTTOM SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BO'FI'OId SET OF PIPE RNdS. BACK OFF RUNNING dO!NT AND PULL OUT OF HOLE. CLOSE BL~ND RAIDS AND TEST TO 3000 PS! FOR 10 MINUTES. BLEED TO ZERO PS!. 12. OPEN BLZHD RAHS AND RECOVER TEST PLUG. HAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL 'AND ALL VALVES ARE SET ~N DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PS!. 14. TEST KELLY COCX5 AND INSIDE BOP'TO 3000 PSI gITH KOOt4EY PUMP. - 15. RECORD TEST INFORHATION ON BLOgOUT PREVENTER TEST FORH S!GN ~ SEND TO DRILLING SUPERVISOR. 16. PERFORM COHPLETE BOPE TEST ONCE A MEEK MiD FUNC- TIONALLY OPERATE BOPE DAILY. D IAGRAf4 .~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco star~ing head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool ~. 13-6/8' - SO00 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and k~11 lines 7. 13-S/8~ - SO00 psi ptpe rams 8. 13-6/8" - 6000 ps~ blind rams '9. 13-5/8' - 6000 ps~ annular ACCURULATOR CAPACITY TEST 1. CHECK AND FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL gITHHYDPaUJLZC FLUID. 2~ ASSURE THAT ACCtJgULATOR PRESSURE IS 3000 PS! gITH 1600 PS! DO--RE. OFT HE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE Tilde AND PRESSURE REKA. ININ6 AFTER. ALL UNITS ARE CLOSED gITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LONER LIMIT IS 45 SECONDS CLOSING TIME AND ~200 PSI REHA[N[HG PRESSURE. 13-6/8' 60P STACK TEST ; ANNULAR PREVENTER · 11 BLIND RAMS'. · m !, PIPE RAMS ~'"~ ' , PIPE RAM~ ) 7 HD I 2 1 O IAGR~4 ~2 13-5/8" SO00 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco sta~ing head 2. 11' - 3000 psi casing head 3. 11' - 3000 psi x 7-1/16' - 2000 psi tubing head 4. 7-1/16' - 2000 psi x ll' - 3000 psi double s:udded adapter S. 11' - 2000 psi x 13-B/8' -SOOO psi spacer spoo! 6. 13-S/8' -SOOO pst x 13-$/8' - SOO0 psi drilling spaol - 7. 13-5/8" - SO00 psi ptpe'r~ 8. 13-5/8" - 5000 psi drilling spool w/c~oke and ktll lines 9. 13-$/8" - 5000 psi pipe ram 10. 13-5/8' - SO00 psi blind rams 11. 13-5/8' - 5000 psi annular ACOJ~LATO, R C~PACITY TEST 1. OIECK ANO FILL ACCUI~JLATOR RESERVOIR TO PROPER LEVEL WITH HYORAULIC FLUID. 2. ASSURE TI4AT ACCU~TOR PRESSURE IS ~ PSI WITH 15130 PSI BOgNSTREA~ OF rdE REGULATOR. 3. OBSERVE TIH~ THEN CLOSE ALL UNITS SIMIJLTANEOUSLY AND RECORO T~IE TIME ANO PRESSURE RE~AINING AFTER ALL UNITS ARE CLOSED WITH OIARGING PUMP OFF. 4. RECORO ON NAOC REPORT. T~iE ACCEPTABLE LOgER LIMIT - IS 45 SECONILS CLOSING TIME ANO iZO0 PSI REGAINING PRESSURE. 9~ 10. 11. 13-$/8' BOP STACK TEST 1. FILL BOP STA~ AND RRNIFOLD WI'Tt'I ARCI'I.C OIF..SEL. ~. C~EOC TTIAT' ALL HOLO OOlal SCREgS ARE FULLY RETRACT- ED. PP~ET~INE OEPT~I TTIAT TEST PLUG WILL SEAT ANO SEAT I!I WELLtlEAO. RUN IN LOC~ OOgN $CREgS IN HEAl). 3. CLOSE ANNIJL~ PREVENTER ANO..OiOKES ANO BYPASS VALVES ON leUIIFOLO. 4. TEST ALL C~I~~S TO' 250 PSI ANO HOLO FOR 10 MINUTES. S. INCREASE PRESSURE TO 18gO PSI ~ HOLE FOR 10 MINUTES. BLEED TO ZFa~O PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE R~o - 7. INCREASE PRESSURE TO 3000 PSI AND HOLO FOR 10 8. CLOSE VALVES OIRECTL¥ UPSTRF~ OF CHOKES. BLEED OOkqlS'/7~r~U4 PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WIlll 3000 PSI UPSTREAM OF VALVE AND ZERO I)(TdNSTREAM. BLEED SYSTE/4 TO ZERO PSI. OP~ TOP SET' OF PIPE RAPS AND CLOSE BOTTOM SET OF PIPE INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND .RAMS ANO TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLINO P.,AMS ANO RECOVER TEST PLUG. MAKE SURE 14ANIPOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCiCS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SENO TO ORILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE OAILY. PHASE I AS BUILT CONDUCTORS I- 8 94.;5 94.4 ss....j_.~ 9~.. 4~ 6e,.~-~?' _ ~4.4 95.0 95.0 160 130 09 010 011 O~ 28 27 BASIS OF O.G. ELEV.'s INTERPOLATED FROM DWG. SR. 8F- 12- 3030 PAD ELEV. IS T. B.M. 8:5-25-49. REV. I RENUMBER ALL WELLS PER NSK DRILLING 12/2/83. ( 180° ROTATION OF NUMBERING) REV. 2 CHANGE ALL ELEVATIONS LOCATED IN PROTRACTED SECTION 28 TOWNSHIP II N.,RANGE 9 E.,UMIAT MER. ,BASIS OF LOCATION I$ MONUMENTS C~F.-2 N.E.& 2-C MIDDLE PER LND ASSOCIATES. 30 DRIL SITE AS BUILT 2'F CONDUCTORS LOCATIONS WELL ! Y.- s,949,34z. B3 ,~,~9 FSL WE:gL 2_ Y=5,949,4(:x).93 .X" 517,382.34 518' FSL i WELL 5 Y,5,~9,460.06 xa 517~372.18 577' FS L WELL 4 Y, 5,949,51 9.07 xa ~17,3~.08 636 FSL WE~ 5 xa 5~17,638.11 683 FS L WE~ 6 ~,~949,507.09 xa 517,648.17 624' FSL WELL 7 Y.5~949,448.14 ~ ~55~17,658-3. FSL W~,,,J. 8' Y"5~949,389.02 X · 517t668-3:5 506' FS L Let. 70° 1-6'21. 9780" L~nq, 1.49° 1857' FEL Lat. 70° 16'22.5595" L.O~. 149e51'53.896'' 1847' FEL Lat. ~ 16'23. 141 Long. !49°51~34. 161 1856' FEL Lat. ?Oe 16'25.7219" Lorn]. 1~49051 '$4.451 1866 FEL~ Lat.'?O e ! 6' 24. ! 811 I.om]. 1,49e 51'26.410" 1590' FE L' Let. 70° 16'23.5977" Lo rig. !.49 51 26.12 ! 1580' FEL Let. ?Oe 16' 2~. 0176" ~ 1.49°51'25.831" 1570' FEL' L~t.?O® le'22.435 7'" Le~. 14geSl' 25.54~ 156 I' FEL DAVID FILUCCI 527 i ! I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND ... THAT THIS PLAT REPRESENTS A SURVEY MADE . UNDER MY DIRECT SUPERVISION AND THAT ALL. DETAILS ARE CORRECT AS OF NOV.' 5,1983. 3l . 32 THIS 33 SURVEY Kuperu# PTOje~t Not"th SIoDe Drillif~ ~ I ll:,,_,"~,,~ DRILL SITE 2.F CONDUCTOR AS. BUILT . LOCATIONS ,.,.. ,..,~UIJ&IUUz .... drewn by · d. B.. dwg. nQ.:9~b.206.~)d4 / · . (2) .L"2 (~ th~ 8) · (3) Admin (g thru 11) (10 and 11) (4) (12 thru 20) BOPE /J/J (21 thru 24) ® Is the permit fee attached .......................................... ~__ 3. 4. 5. 6o 7. 8. Is well to be located in a defined pool ................. ~ Is' well located proper distance from property i~'i..i~222 . ..21../ Is well located proper.distance from other wells .................... Is sufficient undedicated acreage available in thispool ......... Z~_ Is well t° be deviated and is'well b°re plat included ''' i! Is operator the only affected party ............. ' ....... ' ' ~ ~ ' Can permit be approved before ten-day wait .............. ii ' . . 10. 11. Does operator have a bond in force .................................. ~-,~ . Is a conservation order needed ........................ , ............. 'Is administrative approval needed ............... . ..................... 12. 13. 14. 15f 16. 17. 18. 19. 20. 21. 22. 23, 24. Is conductor string provided ................................. Is enough cement used to circulate on conduc;;~ ;~ su~fa~e ... fl~ll Will cement tie in surface and'intermediate or production strings ,...~ . Will cement cover all known productive horizons ..................... ~_ . Will surface casing protect fresh water Zones ....................... Will all casing give adequate safety in collapse,.tension and burst.. Is this well to be kicked off from an existing wellbore .............. . Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ...................................... ~'. Are necessary diagrams of diverter and BOP equipment attached ...... ~ ,. Does BOPE have sufficient pressure rating - Test to ~Z~ 'psig' I~11 Does the choke manifold comply w/API RP-53 (Feb.78) .................. japP~aK TO t~lalC t~'t= P~/N 7-. (6) Add: 25. Additional requirements ............................................. Additional Remarks: Geology: Engiffe~r ing: HWK~ LCS -~ BEw.~ WVA~ JKT ~.~JH JAL ~.._-MTM ~..~' rev: 12/08/83 INITIAL GEO. UNIT ON/0FF poOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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 APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. .. Z$ [,VP 010,H02 VERIrZCA'TIDN b'ZSTING P.A~GE I CONTINUATION :01 PREVliO:US R~EL# ~ COMMENTS :LZBRARY TAPE: $:ERV~CE NA~E ~RIGIN AP£ N'AM~ ~t9969 CONTZ~UATZON # PREVZO'U& ?AP, E COMMEN?& IbIBRAR¥ TAPE F~LE NAMB :.EDIT ..001 8ERViC'E NAME VERSION # : ~AXIM~H ~BNGTH : 1024 PR~VIOU~ rI~ : ~N A. RC~ AT,ASKA WN : 2r-4 FN : KUPARUK '~ANG: ~OWN: 11N "8~CTI 2'8 cou.~ STAT! ASKA CTR¥~ USA ** COMMENTS ** ooo ooo 000 000 04 ooo oo~ 004 o6~ 06 000 000 002 000 000 OOg 0 000 000 00,6 06'5 000 000 00,4 065 COMPANY = ~R~O ALASKA ~NC, EL[, = 2F"4 I'ELD =. KUP:ARUK COUNTY = NORTH SLOPE BOROUGH JOB NU~B~ AT ~CC= 6896~ ~tlN #ONE, DATE LOGGEDI 3! JA~ B4 ~T..DP= R~CK K'RUWE~:L VZSCOSZTY = 9:,625" - B,Z? S:ZZE = B,5" ~ X'~C POLYMER = 6,4 C3 RH AT BHT = 4: 60. DF =2 6DF ******************************** bVP O~O.H02 VE~F~CAT~ON L~,$~NG PAGE ** D~TA FORMAT RECORD ID DEPT SFLU D L IbV 8P NPH! ~DN DRHO FDN NCN~ FDN FCN5 mDN ~A£,! FDN NPl? mDN RNRA FDN ~ mDN TYP~ 8 0 O,HM~ 7 O.H:M~ 7 OB~ ~V G/¢3 42 G/C3 42 CPS iiDE ENTRY SIZf R"EPR 1 60 I 66 0 i 0 0 0 44 Z ,0 0 0 o o o 2 0 0 4 o ~ 0 0 0 4 I 0 0 4 0 0 (~ 4 31 32 0 · 4 0 0 0 0 g I DATA ** ,~EPT 8059' 5000 8:FLU . 000 OR RHOB -32768, 000 NCNb . ,,,,., 4256.0000 FCNL lb - 3 2 '76 B 8,500'0 DEPT 8000 .4355 RNRA 0 0 0 0 8 F L U 7500 GR 4180 NCNb ]'164 RN~ D~P? ?900. S.P -4~, RHOB . ~RRT 3. P. RHOB RNRA 9HO~ .]RAT Dg'PT RHOB ~RAT OEPT RHOB D~PT RHOB ~RAT OEPT RHOB ~RAT ~EPT RHOB DEPT RHOB qRAT 3 .113 600, ?'~,00,0':000 -,.00oo 5684 7400,0000 2,4043 3.g184 7300,0000 -0,0005 -999,2500 -999.2500 oooo .999.2500 999,2500 7100.0000 ~999. -999.~500 7000,0000 -41.8750 NCNb R:NRA RNRA NCNb RNRA nCNb RNRA NCNb RNRA 8F[,U NCNb 8'FLU 3.7422 i 0:~ 4648 5:6:25: 2096 ), '91 GR -225,3750 FCNL IbM .C.,R I 125 9 500 ~'rR 221~ 6 t. 2i 1'78 3 9 I:LM, ~R · · ., 6,5.$86 XLM . 4.!405 X.bD., """ -999.2500 OR 2'38, il -99~ 2500 259.5000 9,9141 .6406 1.2 5625 NPH! -99 ,2500 DRHO -999.2500 bVP OiO,H02 VER~FTCA?I'ON LZST:ZNg PAGE 5 OEP? DEPT RHOB NR~T DEP'T NRkT OEPT NR,AT DEPT SP~ NEAT DEPT NEAT DBPT RHOB D~PT NRAT OEPT N~T DEPT ,,999 6900 -9' 68.00. · I:6. -ggg. -99 ~500 $:FbU RNRA NCNb RNRA 651 9 2500 RNRA 6200,0000 SFLU ~0,8594 :999,2~00 ~CNb 999,2500 RNRA ,oo'oooo '999.2500 RNRA 6000 0000 SFbU -51::3'750 ~R -999,2500 NCNb -999,2500 RNRA 5900.0000 SFLLI .. -99 .00 GR ill · .99" ~..:LM 10:9 IL: ,000 "999.~500 OR '999. .126.L&87'5 NPH! -999,2500 999,2500 '999,2'S'00 6.445 -999.250o g~ -999.~560 2oi:5195 ,7so -999.~500 ~999.)500 1.6895 ~bM 1.8555 CAbI DRHO ILl), DRHO Cl~bI 9.9766 '9' 10 ~L 8 '99 O0 3~ -999.25'00 -999. 2500 1,$516 DEPT 5800 SP 'I3 RROB 8P NRAT -999 bU .114,i000 ~99, O0 '999. ~00 NPHi -" ~0 FCNI, .! ~0 GR =9! )0 'Nb GR ii.I ORHO C A t, I -999,. 2500 ",9:99,2500 ,,9 ~'0 RHOB NR~T R~OB OEPT SP. RHO~ SP_ ~T OgPT RHOB OEPT ~HOB 5500 -99! 540~ 5)00 }00 -999 2500 si g.oooo .2500 o999,2500 -999.~$00 5100.000'0 =47.g125 -999,~00 -999.2500 '999.2500 -999.2'500 4900~0000 '999, O0 =999o2500 RNRA NCNb RNRA 8Fi, U RNRA NCNb RNRA SFbU GR NCNb RNRA mI :'999 2'500 · 's,o o lii. O000 -999.2500 999,2500 -999.2500 2,5918 ~06.6250 -g99;2500 -999.2500 l'L:N NPHI GR NPNI FCNL L'O0 -999 00 '9 9. 0 -999,2500 ' ~,. ~=-'~ · -999.25~0 -999,2'500 . 99', O0 .,,;.;Ioo =999.2500 ,% ILD- DRHO CALl CALl ILD DRHO CALl ~,.8496 "999,25:00 2.79~o '999.2500 :999,2soo 999.2500 5VP 010.H02 VERlrlCA?~ON [,,~8?Z'NG PAGE 7 D£PT RHOB NRA? DEP? NRA? DEPT SP RHOB NRAT r)E:PT ~0 NCNb '999, ~00 -999, tm'Nt~,~ -99'9 !500 45O =999 O0 FCNL ~R GR '999 ~00 '99 'CALl ~00 RHOB MART RHOB NRAT DEPT SP_ RHOB NR.~T DEPT SP RHOB DEPT RHOB NRR? ~PT SP ~HOR 4~ -999 2500 4200,0000 -999. 4i00,0000 -999,2500 '999,2500 4000,0000 -12.,6250 -999,2500 '999,25'0'0 3900,0000 -63.,6895 -99~,2'$00 -999,2500 3~00,0000 91,1895 -999,2500 '999,2500 GR M~Nb RNRA 8FLU RNR'A OR ~CNL SFbU OR NCNb RNRA B?bU ~R NCNb RNRA SFLU ~R NCNb -999 91,9375 :999.2500 999~00 . ~ ,. '0 3.$;$35 . 96,2500 ,999,2S00 999,2500 -999,2500 '999,2900 NPHI 'rCNL GR FCNL NPH! FCNL OR 3,437~ -,999,2500 -999, ,999,2800 {,~0{9 -999, 0 070{ 999,2500 -999,2500 CALl X bO DRHO C{~LZ ! D D~HO CALl ii, D, DRHO CALl 'R,.HO CALl 0 3, -999,2500 -999,2800 '999,2500 $.6484 '9991, 2500 '9'99,25'00 -999, -999,2500 LVP 010.HO~ VERTFZCATTON LISTING PAGE 8 N~A,T D'EPT RHOB RHOB RHOg NRAT DEPT DEPT ~O~ NR~T NEAT N~AT 3700 0000 '49 '8437 -999 2500 -999 2500 .0000 "999,2500 '999'~500 3~00 ~000 -999 330'0. -999, -999, ~00 3200.0000 ~999.~~. -99.9.2500 ~000o~ -999.~500 -999. 500 2~?e,SO00 "997,2500 '999.2500 NCNb RNRA RNRA SFLU NCNb GR NCNb 8FLU NCNb RNRA GR NCNb ~N~A F~b~ NAME :~OtT ,001 VERSION # DATE l ~AXIPUN LENGTH : 1024 ~I[,E TYPE 3965 150.0 , -999, "999, -999 I NPHI FCN'L OR -99 lO0 !:I.,~ NPH! !L, M -999 '999 86,$750 NPHI -999;.2'S00 PCNb "999.2500 GE . 999,2500 2.3945 IbH 50.4375 NPH! -999,2500 FC~L -999.2500 GR '9 99 !500 3.9805 -999~2500 -999,.2S'.00 -999.2500 2000.0000 '999,2'$00 '999,2500 2000.0000 '999,2500 "999,25'00 -999.2500 I:LD .. CAI, I: ERG CAbI DRHO CA~! 3 "999 0 -999' -99 i'O0 -99' O0 500 -999,250'0 ~999.2500 - .2500 D.AT~ 184102t2! ORT'GZ~ :l~O00O