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HomeMy WebLinkAbout183-187MEMORANDUM 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-03 KUPARUK RIV UNIT 2F-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 2F-03 50-029-21062-00-00 183-187-0 W SPT 5820 1831870 3000 2740 2810 2810 2810 50 50 50 50 REQVAR P Bob Noble 7/6/2024 MIT-IA to max anticipated injection pressure as per AIO 2C.039 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-03 Inspection Date: Tubing OA Packer Depth 550 3440 3350 3340IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240707132454 BBL Pumped:3.8 BBL Returned:3.7 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 99 9 9 9 9 9 9 9MIT-IA AIO 2C.039 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:57:09 -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-03 KUPARUK RIV UNIT 2F-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2F-03 50-029-21062-00-00 183-187-0 W SPT 5820 1831870 3000 2350 2350 2350 2350 40 40 40 40 REQVAR P Brian Bixby 7/2/2022 MITIA as per AIO 2C.039 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-03 Inspection Date: Tubing OA Packer Depth 960 3290 3140 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704090043 BBL Pumped:3 BBL Returned:3 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 AIO 2C.039 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 15:18:32 -08'00' MEMORANDUM TO: Jim Regg P.I. supervisor '— �ef q FROM: Matt Herrera Petroleum Inspector 71Z4'( 06-'0 NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 21, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2F-03 KUPARUK RIV UNIT 2F-03 Sre: Inspector Reviewed By: P.I. Supry� Comm Well Name KUPARUK RIV UNIT 2F-03 API Well Number 50-029-21062-00-00 Inspector Name: Matt Herrera Permit Number: 183-187-0 Inspection Date: 7/12/2020 v Insp Num: mitMFH2O0714161026 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2F-03 'Type InJ W - TVD 6820 Tubing 2730 2680 2700 2720 F 1831870 Type Test SPT Test psi 3000 IA 1100 3430 3260 31,40umped: 28 BBL Returned: 2.6 OA 50 50 s0 soal REQVAR P/F P Notes: Mir -IA to MAIP Per A10 20.039 ✓ Tuesday, July 21, 2020 Page 1 of 1 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 29,2016 TO: P.I.JmRupgg er ( SUBJECT: Mechanical Integrity Tests P.I.Supervisor 66//91. 111(`'U CONOCOPHILLIPS ALASKA INC 2F-03 FROM: Johnnie Hill KUPARUK RIV UNIT 2F-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv3 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-03 API Well Number 50-029-21062-00-00 Inspector Name: Johnnie Hill Permit Number: 183-187-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826171755 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-03 Type Inj G.1117D 5820 Tubing 3450 3450 • 3450 3450 PTD 1831870 'Type Test SPT Test psi, 1500 ' IA 1900 2795 - 2750 2745 Interval T4YRTST PAF P / OA 60 60 - 60 - 60 Notes: tiEDJUN162. 17 Monday,August 29,2016 Page 1 of 1 • . Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, August 16, 2016 4:32 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of IA pressurization KRU Injector 2F-03 (PTD 183-187) 7-18-16 update 8-16-16 Attachments: 2F-03 90 day TIO 8-16-16.PNG Chris, The 30 day monitor period while on gas injection is coming to an end on 2F-03 tomorrow. On 7/19/16, DHD performed passing tubing packoff tests and an IA drawdown test. The IA drawdown test was very conclusive, building no pressure in a 90 minute monitor with no gas observed in the fluid offtake. However,there has been a continued slow IA pressure increase. Based on the drawdown test results and the fact that the buildup rate had decreased significantly from what was observed when initially reported last month,the slow increase in pressure was attributed to thermal reasons. However,today we discovered a discrepancy in the actual vs recorded temperature readings. Today's temperature of the gas injection was at 75 degrees, significantly lower than the 135-degree recorded reading. Based on this data, I no longer believe the slow increase in pressure can be attributed to thermal effects. It appears there is slow TxIA communication while on gas injection. The well will be WAG'ed to water for a 30 day monitor to confirm that this is in fact a gas only leak. Pending a successful monitor on water injection, an AA application will be submitted at the conclusion of the monitor period. Please let me know if you disagree with the plan forward. Attached is the updated 90 day TIO plot. • Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED JAN 1 8 2017 From: NSK Problem Well Supv Sent: day,July 18, 2016 1:57 PM To:Wallace, is D (DOA)<chris.wallace@alaska.gov> Cc: Senden, R.Tyle .Tyler.Senden@conocophillips.com> Subject: Report of IA press 'nation KRU Injector 2F-03 (PTD 183-187) 7-18-16 Chris, Kuparuk WAG injector 2F-03 (PTD 183-187) is experiencing an unexplained IA repressurization while on gas injection, with several bleeds needing to be performed when nearing its DNE, the most recent of which occurred yesterday. The well had a passing witnessed 4 yr MIT performed on 7- 6. Because it was recently fluid packed,the bleeding was believed to be needed because of temperature effects. The perature reading is not real time and unrecorded temperature fluctuations may be contributing to the IA pressure response. DHD will be scheduled as soon as possible to complete tubing and inner casing packoff tests and an IA drawdown test. The well will be monitored for 30 days while on gas injection and if communication is confirmed, the well will be WAG'ed to water injection for a 30 day monitor on water in preparation for an AA submittal. Please let me know if you disagree with plan forward. W U C C� C9 C7 C7 4110w col = Cr CC LY Cr v5 w W W W U — — — — N W LY U C) C) `. Q. K V, A LL G o ulLU N W Q O O O u1 Q (Oo o r cov a) W En LU W Q' Up U U U S `00 M c) 54',— — N N H N W W w_ LUOry O 0 o QQQ n `. V.- C -1 o, 01 01 al J o 0 0 0 J ULLLLL W (,I (V (V N } Cl (-.I (7.1 (.1 Bap 41 .,I (1 C7 L.1 tJ LJ Ll (S, 71 . 4 1 .4: W .z 4 i u1 * t LO ii• 5 V C i ♦N1ie4, CD RI ✓ O o' E o W V L H R m D O C (n t0 C Q I (u CD • m W o N c N a LL. COC� 1CD cLo CV 4— _ 1 ~1 r � ih;1to = CLI Fi Z O Q .t c �1 N {y m n C419'az OA mRI > pd'know • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, July 18, 2016 1:57 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressurization KRU Injector 2F-03 (PTD 183-187) 7-18-16 Attachments: MIT KRU 2F-PAD 07-08-16 Revised.xls; 2F-03 schematic.pdf; 2F-03 90 day TIO 7-18-16.PNG Chris, Kuparuk WAG injector 2F-03 (PTD 183-187) is experiencing an unexplained IA repressurization while on gas injection, with several bleeds needing to be performed when nearing its DNE, the most recent of which occurred yesterday. The well had a passing witnessed 4 yr MIT performed on 7-9-16. Because it was recently fluid packed,the bleeding was believed to be needed because of temperature effects. The temperature reading is not real time and unrecorded temperature fluctuations may be contributing to the IA pressure response. DHD will be scheduled as soon as possible to complete tubing and inner casing packoff tests and an IA drawdown test. The well will be monitored for 30 days while on gas injection and if communication is confirmed, the well will be WAG'ed to water injection for a 30 day monitor on water in preparation for an AA submittal. Please let me know if you disagree with plan forward. Attached are the schematic and 90 day TIO plot and MIT data. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 Np\I 1 8816' UJ U • � _ _ [? C7 C? C? rz !s w w w w U - - - - N w K C. o N L' LL f u N °' O• Cr) • W d c a i c' aQ CO SO U 1 0) 2 a) W ▪ fJ! U U U U1 Q U U U 1V Cr V N fV F N O W o Cr; 0 f i o Cr? 0 0 J LLL L_ li LL Ws fV CV fV [V V Bap T G tt) rf C) tJ• (.1t ll! ul t -7 E OD j 3• -e _? O R I co O � O d5 cp � I O ! (.0 N CD i = r r u [p i �q r `1 O N ry 1 a 0. LCL � 1 E a) t C tJ r ' R R t7 c7 c] C11 a cii U[7 : 2 K5 ) :, u) CJU CJ Z O Q cV M r) [I f l r n N Gd111!Od�l1^• N ca T isd s in o • KUP INJ • 2F-03 ConocoPhillipss Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/OW! Field Name Wellbore Status ncl(.) MD(ftKB) Act Btm(ftKB) f rtravi>ilelhp, 500292106200 KUPARUK RIVER UNIT INJ 47.27 2,100.00 8,075.0 ,., Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2F-03,8/14/20159.48;27 AM SSSV:LOCKED OUT Last WO: 2/3/1987 29.00 1/24/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Lost Tag:SLM 7,880.0 8/10/2015 Rev Reason:TAG lehallf 8/14/2015 HANGER;23.7^-' - Casing Strings of'a Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...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 II...Grade Top Thread SURFACE 95/8 8.921 30.4 3,306.0 2,776.7 36.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 29.8 8,027.2 6,266.2 26.00 J-55 BTC Tubing Strings L Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(1VD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 23.7 7,520.2 5,845.7 9.30 J-55 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not("I Item Des Corn (in) 23.7 23.7 0.07 HANGER FMC GEN III TUBING HANGER 3.500 1,785.6 1,694.1 36.90'SAFETY VLV OTIS OLP SAFETY VALVE(LOCKED OUT 3/30/96) 2.812 M7 CONDUCTOR;31.0-108.0c-rn.i..v -n...i...� 7,462.0 5,799.5 37.86 SBR OTIS SBR 2.812 7,488.4 5,820.4 37.46 PACKER OTIS RRH PACKER 2.970 7,506.0 5,834.4 37.18 NIPPLE CAMCO D NIPPLE 2.750 7,519.4 5,845.1 36.95 SOS CAMCO SHEAR OUT SUB 3.000 Perforations&Slots Shot SAFETY VLV;1,7858IA Dens Top(TVD) Bern(TVD) Top(ftKB) Btm(ttKB) (ftKB) (ftKB) Zone Date t) Type Com XO THREAD;1.800.9 7,610.0 7,611.0 5,918.2 5,919.0 C-4,2F-03 3/14/1988 1.0 IPERF Schlumberger 21/8" 7,613.0 7,614.0 5,920.7 5,921.5 C-4,2F-03 3/14/1988 1.0 (PERF Schlumberger 2 1/8" 7,698.0 7,709.0 5,990.5 5,999.6 A-5,2F-03 3/31/1984 4.0 APERF Schlumberger 4"CSG 7,720.0 7,756.0 6,008.7 6,038.7 A-4,2F-03 3/31/1984 4.0 APERF Schlumberger 4"CSG 7,798.0 7,806.0 6,073.8 6,080.6 A-3,2F-03 3/31/1984 4.0 APERF Schlumberger 4"CSG Mandrel Inserts St SURFACE;30.43.305.0-. . all N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I 1" 7,415.1 5,762.7 OTIS LBX 1 GAS LIFT DMY 'RO5 0.000 0.0 2/12/1987 GAS LIFT;7,415.1 f Notes:General&Safety [[ • OAR.7.462 0 End Date Annotation 10/8/2010 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 04•PACKER.7,488 4 NIPPLE;7,506.0Li • SOS;7,519.4 ul - IPERF;7,810.0.7,611.0 -4 `- IPERF;7,813.07,814.0--4 - APERF;7,898.0-7,709.0 APERF;7,720.07,758.0 1 -1 t.-- APERF;7,798.07,808.0 z- PRODUCTION.29.8-8 027 2 • t-‘ sr-\46.1 • 2(05 5 2 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 10, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ' ' `� - °ATa(0i oGEG,D K BENDER RE: Static Bottom Hole Pressure Record: 2F-03 Run Date: 11/1/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21062-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-029-21062-00 SCANNU PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ✓e?.a "k-, 015,..e.oceett 2-5S-61 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 3, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 2-/ /2O15 Anchorage, Alaska 99501 K ENDER RECEIVED RE: Injection Profile : 2F-03 FEB 0 h 2015 Run Date: 1/4/2015 AOGCC 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-03 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21062-00 Injection Profile 1 Color Log 50-029-21062-00satiny 1 LL --- PLEASE -PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A IThNTION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: (x)Asa-fre‘k-,17) 6-44teeet ImaG~rP, roject Well History File' C( le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ~'~',~ - -~ ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, No. [3 Maps: [3 Grayscale items: [3 Other. No/Type -.[; Other items scannable Dy [] Poor Quality Originals: .~ large scanner , OVERSIZED (Non-Scannabl e) [] Other: ~, NOTES: B Logs of various kind s' [3 Other BY: BEVERLY BREN VINCENT SHER¥~OWELL DATE: Is~ BY: BEVERLY BRE~ SHERYL MARIA LOWELl. DATE.~-/ /S/ ScanningPreparation '~ x 30 . ~/~'~0 + /~' = TOTA, PAGES 7~ BY: BEVERLY BR~SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO ~BREN VINCENT SHERYL MARIA LOWELL DATE:It./~,~IsJ~J~J~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY BREN VINCENT~ARIA LOWELL NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE DUE TO QUALITY, GRAy,SCALE OR COLOR iMAGES) ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 18, 2012 TO: Zfc Jim Regg ¢l C�' l P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F -03 FROM: Lou Grimaldi KUPARUK RIV UNIT 2F -03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J -- NON Comm Well Name KUPARUK RIV UNIT 2F - 03 API Well Number 50 029 - 21062 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 183 - 187 - Inspection Date: 6/7/2012 Insp Num: mitLG120607093505 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F -03 - Type Inj W 'TVD 5820 ' IA 700 2000 • 1900 1900 - PTD 1831870 ' Type Test SPT Test psi 1500 - OA 80 80 80 80 - Interval 4YRTST P/F P - Tubing 2700 ' 2700 2725 2725 Notes: 1.3 bbl's up, 1.6 Down. Good stable test AM ED JUL CY 612 Monday, June 18, 2012 Page 1 of 1 • lzA WELL LOG TRANSMITTAL CCP To: Alaska Oil and Gas Conservation Comm. December 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RAID AUG (13 2 RE: Injection Profile: 2F -03 Run Date: 11/21/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -03 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -029- 21062 -00 Injection Profile Log 1 Color Log 50- 029 - 21062 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: 1 142.9 It Signed: ilitheA" 601444. • ~- . . conocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • isa-~~7 ~' aF_ o~ 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 corrosion inhibitor/sealant was pumped October 16, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ,' Sincerely, r '! . ,~ ,, G ~ ~~.i~~ ~14J t ~ d LLL/[1 MJ Lov and 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 Date 10/22/2008 i~ 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-02 183-188 20" NA 20" NA 2.21 10/16/2008 ZF-03 183-487 20" NA 20" NA 2.23 10/16/2008 2F-05X 196-203 7" NA 7" NA 1.7 10/16/2008 2F-06 184-019 18" NA 18" NA 1.72 10/16/2008 2F-11 184-041 .20" NA 20" NA 2.22 10/16/2008 2F-13 183-156 12" NA 12" NA 6.8 10!16/2008 2F-14 183-159 7" NA 7" NA 4.25 10/16/2008 2F-18 196-178 5" NA 5" NA 11.9 10/16/2008 2F-19 196-201 6" NA 6" NA 1.7 10/16/2008 ~~~®~~~ To: Jim Regg ~ P.L Supervisor ~~ ~j I ~~~ ~. 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 INC ZF-03 KUPARLtK RIV LNIT 2F-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~_ Comm Well Name: KUPARUK RN UNIT 2F-03 API Well Number: 50-029-21062-00-00 Inspector Name- Bob Noble Insp Num: mitRCN080707140758 Permit Number: 183-187-0 Inspection Date: x/5/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2F-03 Type Inj. ; ~' ~ T'~ sszo I, IA ~ 700 ! z9ao 2s7o ! 2s7o j P.T. 1183ts7o ,TypeTest SPT Test psi z9ao ~ OA ~ so I 70 70 70 ' Interval 4YRTST per, P II Tubing i 2375 2300 2300 ?300 i ! Notes: ~~~~ AU ~ ~ 20Q8 Tuesday, July 08, 2008 Page l of I RECEIVED 05/18/06 ScblmDbel'gel' MAY 2 4 2006 ~ C1t & Gas Gens. Ccrnmi$$ÍC(J ,~~~ NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman t1 333 West 7th Ave, Suite 100 \ CO \ Anchorage, AK 99501 1J..... '" \Cb , '''''',",Mío\l;:.r ,'I..I/n,.; y;, "t_: - Field: Kuparuk Well Log Description Date BL Color CD Job # 1 G-01 (REDO) 11213744 INJECTION PROFILE ì'6d -(36 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG W/DEFT IC':"\- ¡-:S'l 05/06/06 1 1A-03 11258708 PRODUCTION LOG WIDEFT I '6{ - D~1r 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG W/DEFT I C, ~ _ I <',(¡:... 05/08/06 1 1A-02 11258709 SBHP SURVEY C' :r è. I ~ t - ò-::r \ 05/09/06 1 1 R-13 11258711 INJECTION PROFILE C' ~ <-'- \ 'k'" - I,,--r:, 05/10/06 1 2M-34 11216296 INJECTION PROFILE UT~ \ Q(;~- '-Y~ 05/11/06 1 2F-03 11216298 SBHP SURVEY , \'"'\' (\ \ "Ír ~ - ¡ 4--'1- 05/14/06 1 2F-14 11216299 SBHP SURVEY !J'rf' 17I-~--I~ 05/14/06 1 1A-06 11258712 INJECTION PROFILE ~)', Q.. 14 i_I} L 05/14/06 1 3Q-11 11216301 LDL i~~-/'?í;" 05/16/06 1 1J-184 11216297 USIT r) '"t (' ;::¡ "-'(:' n':'¡¿/ 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¿1*.lt- ~/os-(o(; 9 e e Schlumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1R-16 2X-10 1 D-128 3J-06 3J-07 A 2Z-29 1A-02 1 Q-26 1G-16 2A-08 2G-15 2N-329 2Z-07 3G-02 2B-03A 3N-09 (REDO) 2C-04 '~M-07 (REDO) 2A-01A 1 R-1 0 2Z-08 1 E-170 1J-154 ../ 2F-03 SIGNED: Job# 11015756 PRODUCTION PROFILE 11015758 PRODUCTION PROFILE 11015759 INJECTION PROFILE 11072927 SBHP SURVEY 11072926 SBHP SURVEY 11072924 PRODUCTION PROFILE 11022938 INJECTION PROFILE 11022937 PRODUCTION PROFILE 11015753 INJECTION PROFILE 11015155 INJECTION PROFILE 11012919 PRODUCTION PROFILE 11022935 PRODUCTION PROFILE 11022936 PRODUCTION PROFILE 11056697 PRODUCTION PROFILE 11015149 PRODUCTION PROFILE 11015122 PRODUCTION PROFILE 11022934 INJECTION PROFILE 11015137 INJECTION PROFILE 11072922 INJECTION PROFILE 11015157 INJECTION PROFILE 11072920 INJECTION PROFILE 11015150 USIT 11022931 USIT 11015163 INJECTION PROFILE L~ ðf,u SCANNED NOV 2 3 2005 Log Description 10/31/05 NO. 3513 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~' Date BL Color CD 10/24/05 1 10/26/05 1 10/27/05 1 10/30/05 1 10/30/05 1 10/28/05 1 10/18/05 1 10/17/05 1 10/21/05 1 10/23/05 1 10/23/05 1 10/15/05 1 10/16/05 1 09/20/05 1 10/05/05 1 08/29/05 1 10/14/05 1 09/26/05 1 10/26/05 1 10/25/05 1 10/24/05 1 10/19/05 10/12/05 10/31/05 1 ~ 1 1 DATE: I ~ rJ tv "0 ~ j- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 183-J87 MEMORANDUM TO: Jim Regg ~ { 7{77(V4 P.I. Supervisor 1l FROM: Lou Grimaldi Petroleum Inspector Well Name: KUPARUK RIV UNIT ::!F-03 Insp Num: mnLG040713093211 Rellnsp Num: Packer Well If-03 Type Inj. G TVD I P.T. 1831870 T)'peTest SPT Test psi I Interval .WRIST P P/F Notes: Good tes!. no problems. Wednesday. July 14.2004 State of Alaska Alaska Oil and Gas Consen'ation Commission DATE: \\'ednesday. Jul) 14. 2004 SllBJECT: f\.1echamcallntegrlt)' Tests CONOCOPHILLIPS ALASK...:.. INC ~F-O~ KUP.-\RUK RIV UNIT ~F-03 Src: InspectOT NON-CONFIDENTIAL API Well Number: 50-029-21062-00-00 Permit Number: 183-187-0 Reviewed By: ---17"" t P.I. Supr\' ..Jt:i-- Comm Inspector Name: Lou Grimaldi Inspection Date: 7/13/2004 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6305 I IA I IO~1) 1600 1580 1575 1-155 I OA 0 0 0 0 Tubing 2300 2300 2300 2300 Page I of 1 MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair WondZell P.I. SupervisOr State of Alaska Alaska Oil and Gas Conservation Commission Petroleum InspectOr DATE: September 28, 2000 SUBJECT: Mechanical Integrity Tests ~1~..0.~ Phillips Alaska Inc. 2F Pad toi~jIcr~ 01,02,03,13,14 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL · . Pretest Initial 15 Min. 30 Min. P.T.D. ~ P ° Notes: , ' 4 ~ 2~:-02 ' Notes: 2F-0.3 ~ 1831870 Notes: 2F-13 1831560 Notes: 2F-14 1.831590 Notes: Interval Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test 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 Vadance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to philliPs Alaska's KuParuk River Field to-Witness 4 year mechanical integrity tests. Testing was conducted by Phillip's rep. jerry Dethlefs. All wells passed .either the standard annulus pressure tests or the annulus monitoring test Mr. Dethlefs conducted tests in safe & efficient manner. . .I.T?s performed:: 5__ 'Attachments: none. Number of Failures: 0__ Total Time during tests: 2 hrs... cc: MIT report form 5/12/00 L.G. MIT:KRU 2Fa 9-28-00jc.xls 10/3/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate __ Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X Location of well at surface 577' FSL, 1856' FEL, SEC 28, T11N, R9E, UM At top of productive interval 1546' FNL, 1207' FWL, SEC 27, T11N, R9E, UM At effective depth 6. Datum elevation (DF or KB) RKB 127' feet . 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-03 9. Permit number/approval number 83-187/94-306 10. APl number 5o-029-21062 1 1. Field/Pool Kuparuk River Oil Field/Pool 1402' FNL, 1327' FWL, SEC 27, T11N, R9E, UM At total depth 1348' FNL, 1373'' FWL, SEC 27, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8075 feet 6305 feet Plugs (measured) None Effective depth: measured 7945 feet true vertical 61 96 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 8 0' 1 6" 254 SX AS II 108' 3278' 9-5/8" 1500SXAS III & 3306' 250 SX AS I 7 9 9 9' 7" 610 SX Class G & 8027' 41 Bbls AS I measured 7698' - 7709', 7720' - 7756', 7798' - 7806', 7610', 7613' true vertical 5989' - 5998', 6008' - 6037', 6072' - 6080', 108' 2776' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7520' Packers and SSSV (type and measured depth) PKR: OTIS RRH @ 7488'; SSSV: OTIS QLP @ 1786' W/OTIS MCX IV 6264' RECEIVED 5917', 5920' DEC 2 7 1994 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure INSTALL INJECTION VALVE Oil & Gas Cons. Commissi Anchor.: ', 14. Prior t° well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1300 2300 1300 2350 TubingPressure 3920 3920 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Wells Superintendent Date ) 2.//~/~4 SUBMIT IN DUPLICATE ARCO Alaska, inc. r" . " KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DESCRIPTION OF WORK DATE' / CONTRACTOR/KEY PERSON We--,..3- - OPERATION AT REPORT TIME [~OMPk~E [] INCOMPLETE FIELD EST: AFC/CC ,..~'C,4-: Z-lO ( / ~' ACCUMULATED COST $ TIME LOGENTRY ,'~JH~.' ,j~i) ~..3~ 7: ,:~/(-/'O '"'~c ~,,[5 G,O~ · ,,,,~-r PAGE 1 OF .. · ~z£u ~o-rozc ro m.,,w,~ ,,,,j .~'uz~, ~'7-~u,~. 5/cco~/'u,~,~ ~o Z~,8c5 ~/Go ",-?~ouc~=' ,e,~r'~' /o~ o //~0 / ~..¢0 / '-/~? c i './'-/0 i ¥,5,5 c._~o...~ u,ee. ,-'e..~T /,,/0 '- 7. ~2~x2c2 ~ 9 7.S ,,~,-- · '/'1/0-/~: Q. ~I o-nj (~cP ~V ~o7-/_._ooc~8 00,7- I! CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I I , Temp. OF , Chill Factor oF IVisibility miles IWind Vel. knots I S'gn~ Report I AR3B-7031 298-3486 ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 November 1, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Dear Mr. Johnston: Attached in triplicate is an Applicaton for Sundry Approvals (Form 10-403) and in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. Well Form Action 2F-03 10-403 1A-07 10-403 3H-31 10-403 2F-08 10-404 1 E-05 10-404 2D-04 10-404 3H-16 10-404 Variance (Inj Vlv) Variance (Inj Vlv) Other (Conversion) Perforate Perforate Variance (Inj Vlv) Other (Conversion) If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent KUparuk Production Engineering Attachments Well Files (attach only) File: FTR110196 (w/o attach) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance X Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 577' FSL, 1856' FEL, SEC 28, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB 1 27 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-03 At top of productive interval 1546' FNL, 1207' FWL, SEC 27, Tll N, R9E, UM R E F_ i V E D9.83-187Permit number At effective depth 110. APl number z~ ~994 I 50-029-21062 1402'At totalFNL'depth1327' FWL, SEC 27, T11N, R9E, UM NOV '~ _ ! 11. Field/Pool 1348' FNL, 1373' ' FWL, SEC 27, T11N, R9E, UJ~e, ska 0ii & Gas Cons. C0mrrJi~l~llaruk River Oil Field/Pool 12.TotaIPresent well condition summarYDepth: '~l~U'lCil0rr"': ~ R I G I N A L measured 8075 feet Plugs (measured) None ,, true vertical 6305 feet Effective depth: measured 7945 feet Junk (measured) None true vertical 6196 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 254 SX AS II 108' 108' Surface 32 7 8' 9 - 5 / 8" 1500 SX AS III & 3306' 2776' Intermediate 250 SX AS I Production 7 9 99' 7" 610 SX Class G & 8027' 6264' Liner 41 Bbls AS I Perforation depth: measured 7698' - 7709', 7720' - 7756', 7798' - 7806', 7610', true vertical 5989' - 5998', 6008' - 6037', 6072' - 6080', 5917', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7520' Packers and SSSV (type and measured depth) PKR: OTIS RRH @ 7488'; SSSV: OTIS QLP @ 1786' 7613' 5920' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ I 14. 16. Estimated date for commencing operation 9/9/94 If proposal was verbally approved Name of approver 15. Status of well classification as: Oil __ Gas _ Suspended Date approved Service X (WAG) 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~ ~ ~--~ Title Wells Superintendent Date /./J~',/,'~' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by order of the Commission Original Signed By David W. Johnston IApproval No. , ? ,/-.~' lO- Approved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 2F-03 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the failed surface controlled, subsurface safety valve in Injection Well 2F-03 with a downhole, spring-controlled, injection valve. This injection valve will act as a one-way check valve, allowing downward injection of water and gas while preventing upward flow of these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. ORIGINAL RECEIVED NOV 1 4 1994 Alaska Oil & Gas Cons. Commission Anch0rc....~- STATE OF ALASKA ALASKA OIL AND ~ CONSERVATION COMMISSION REPORT-OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address Operation Shutdown Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Pull tubing Ct h e r P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 577' FSL, 1856' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1546' FNL, 1207' FWL, Sec. 27, T11N, R9E, UM At effective depth 1402' FNL, 1327' FWL, Sec. 27, T11N, R9E, UM At total depth 1348' FNL, 1373' FWL, Sec. 27, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8075' feet 6305' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 1 27' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-03 In!ector 9. Permit numb, er/approval number 83-187 /~ .-/'7~,' 10. APl number ,50-029-21062 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7945' true vertical 6196' feet feet Junk (measured) Casing Length Size Structural Conductor 1 08' 1 6" Surface 330 6' 9 - 5 / 8" Intermediate Production 8027' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Cemented 25O 88O 63O 25O 275 7609', 7612', 5917', 5920', 3 1/2", J-55, @ 7520' Sx C.S. II Sx A.S. III & Sx Class "G" Sx A.S. 1 & Sx Class "G" 7698'-7709', 5989'-5998', Packers and SSSV (type and measured depth) RRH @ 7488'& OLP @ 1786'. Measured depth 108' 3306' 8027' 7720'-7756', 6008'-6037', True ve~ical depth 108' 2776' 6264' 7798'-7806' MD 6072'-6080' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0il & Gas Cons. Corn, rnissio,r · .,~,.., gnchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1931 9OO 1538 5099 800 2163 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Water Injection :17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~.7,~'~ / ,~'~/~ ~ Title .~,t. ¢,~ ,"--J Form 10-404 R~v 06/15/88 SUBMIT IN DUPLICATE' ,---~-'- STATE OF ALASKA ~-~-',, ALAL . OIL AND GAS CONSERVATION COM. SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program D Plugging ~ Stimulate © Pull tubing ~ Amend order ~ Perforate ,~ Other 2. Name of Operator ARCO Ala.~ka- Inc. 3. Address P.O. Box 100360~ Anchorage, Alaska 99510 4. Location of well at surface 577' FSL, 1856' FEL, Sec. 28, T11N, R9E, UN At top of productive interval 1546' FNL, 1207' FWL, Sec. 27, T11N, R9E, UM At effective depth 1402' FNL, 1327' FWL, Sec. 27, T11N At total depth 1348' FNL, 1373' FWL~ Sec. 27, T11N 11. Present well condition summary 8075' Total depth: measured 6305' feet true vertical feet Effective depth: measured 7945' feet true vertical 6196' feet Casing Length Size Structural Conductor 108 ' 16" Surface 3306' 9-5/8" Intermediate Production 8027 ' 7" Liner 7698' -7709' Perforation depth: measured , R9E, UM , R9E, UM Plugs (measured) 5. Datum elevation (DF or KB) 127' RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well number ~,,t,~'.z.,~,: 2F-03 8. Pe~/.m?~ number "-- /$'7 9. APl number Junk (measured) 50-- 10. Pool 02921062 Kuparuk River Oil Pool Cemented Measured depth 250 Sx C.S. II 880 Sx A.S. III & 630 Sx Class "G" 250 Sx A.S. I & 275 Sx Class "G" , 7720' -7756' True Vertical depth true vertical 5989'-5998' 6008'-6037' Tubing (size, grade and measured depth) 3 1/2" Packers and SSSV (type and measured depth) RRH @ 7488' & QLP @ 1786'. , J-55, @ 7520' 108' 108' 3306' 2776' 8027' 6264' , 7798' -7806' MD , 6072' -6080' TVD 12.Attachments Description summary of proposal ~ Detailed operations program Perforate C Sand with single shots at 7609' and 7612' MD-RKB. 13. Estimated date for commencing operation 03/07/88 BOP sketch 14. If proposal was verbally approved Name of approver ~, ~ ]~"~ i ?/~1 Date approved 15. I hereby certify that the foregoing is true and correct to the_best of my knowledge Signed ,/(~ . .~¢,~ Title ~.~._~ ~,' ~- ~ Commission Use O~ly of approval Notify commission so representative may witness ~ Approval No. Conditions I Approved by Plug integrity ~.O.~.~NtE C. SMITH BOP Test © Location clearance Approved CoPY Returned - '~ Commissioner by order of the commission Datec~-//,~'---- Submit in triplicate Form 10-403 Rev 12-1-85 Kuparuk Well 2F-03 C Sand Perforation Procedure The 'C' Sand will be perforated with 2 shots only to provide pressure support to offset 'C' Sand producers. A 2-1/8' E-Un, through-tubing perforating gun will be used. . If the well is currently on gas injection, convert to water injection. After conversion, inject water at maximum rate for a minimum of one week before perforating the 'C' Sand. 2. MIRU E.Line Unit. 3. RIH w/CCL, perf guns, magnetic decentralizer. 4. Tie-in to depth using the following logs: Schlumberger DIL/SFL 1 ~22~84 Gearhart CCL/CBL 311 318 4 5. Perforate the following locations with a single shot using a 2-1/8' strip gun. DIL/SFL CCl./CBL Shot De~3th (MD-RKB) Deoth ~MD-RKB~ I 7610' 7609' 2 7613' 7612' Perforating gun specifications: Any of the following service company guns will be acceptable. However, it should be noted that the Schlumberger Enerjet Gun has performed the best in field use and in perforating studies. Schlumberger 2-1/8" Enerjet Dresser 2-1/8" Silverjet Gearhart 2-1/8" E.Jet II . , RD E-Un, Unit. Continue water injection at the maximum header pressure or meter limit. The well will not be switched to a gas injection cycle until a 5% HPV water slug has been established in the 'C' Sand. ~chorage Kuparuk Well 2F-03 Well 2F-03 is currently utilized for 'A' Sand-only water alternating gas injection. Perforation of the 'C' Sand will allow injection into. the 'C' Sand and provide pressure support to the offset °C' Sand producers. A copy of the proposed program to allow conversion of the subject well is attached. The perforating will be performed with 2-1/8" through-tubing guns. A 5000 psi BOP and lubricator will be employed during all stages of the downhole work. Surface pressure falloff analysis indicates an average reservoir pressure of 3200 psig in the 'A' Sand, and the 'C' Sand pressure is estimated from offset wells at 2700 psig. WELL ARCO Alaska, Inc. NTRACTOR REMARKS WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company [PBDT ,'--'~~-FIELD- DISTRICT-STATE . $~,,~ I c ,~__.~_,~_~ ,,,0'7" 5 5 o o~b' I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report oF OF miles knotl .. REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING .- FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision - Pre-Job Safety Meeting AFE I TOTAL FIELD ESTIMATE // ~; ~'~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefimte or appreciable length of time. On workovers when an o~icial test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used Ior reporting the entire operation it space is available. Accounting cost center code District ICounty or Parish Slate [ Alaska North Slope Borough Alaska Field Lease or Unit Well no. Kuparuk River ADL 25657 2F-3 AFE AK1916 -Completion API 50-029-21062 Nordic 1 cost center prior to plugging and ARCO Alaska, Inc. 56.24% abandonment of this well Spudded or W.O. begun Date Hour Prier status if a W.O. /~C.- Complete 2/2/87 0945 hrs. Date and depth as o! 8:00 a.m. 2/03/87 2/04/87 Complete record for each day reported 7" @ 8027' 7945' PBTD, POH, Chg out couplings 10.0 ppg brine Accept ri~ @ 0945 hrs, 2/2/87. Displ well w/brine; well dead. ND tree, NU & tst BOPE to 3000 psi. RIH w/RTTS & set @ 60'. ND BOPE, chg tbg head to 5M, Gan 3, tst packoff to 3000 psi NU & tst BOPE to 3000 psi. Pull RTTS. RIH, tag pkr @ 7500', POH w/3½" compl & chg out couplings to AB Mod. LD SSSV. 7" @ 8027' 7945' PBTD, RR 6.8 ppg diesel Fin POH. RU & rn 234 jts, 3½", 9.3#, J-55 8RD AB Mod tbg w/SSSV @ 1786', Pkr @ 7488', TT @ 7520' Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/diesel. RR @ 2330 hrs, 2/03/87. Old TD New TO ..' i , PB. Deplh Released rig Date Kind o! rig 2330 hrs. 2/03/87 Classifications (oil, gas, etc.) Type completion (single. dual, etc.) Oil Single Producing method OHicial reservoir name(s) Flowing Kuparuk Sands Potential test data 7945' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correCt ,,,,, Sig ~) 0 ~p JO Drilling Supervisor For form preparl~and distributio ,d'~'~ see Procedures Manual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively 8s they are prepared for each well. iPage no. Dlvll~on ol AtlantlcRichfleldCompa~y · '-"-, STATE OF ALASKA ~ "-"~ ALAS. OIL AND GAS CONSERVATION COM, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate __J Pull tubing Alter Casing [] Other ~i~ WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorac~e~ AK 99510-0360 4. Location of well at surface 577' FSL, 18561 FEL, 5ec.28, T11N, R9E, UM At top of productive interval 1546' FNL, 1207' FWL, Sec. 27, TllN, R9E, UM At effective depth 1402' FNL, 1327' FWL, 5ec.27, TllN, RgE, UM At total depth 1348' FNL, 13731 FWL, 5ec.27, T11N, R9E, UM 5. Datum elevation (DF or KB) RKB 127'. 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-3 8. Approval number 7-24 9. APl number 50-- 029-21062 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 108' Surface 3306' Production 8027' Perforation depth: measured true vertical 8075 ' MD 6305 ' TVD 7945 ' MD 6196 ' TVD Size 16" 9-5/8" 7!1 feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 250 sx CS II 108'MD 880 sx AS Ill & 3306 'MD 630 sx Class G 250 sx AS I & 8027'MD 275 sx Class G 7698'-7709', 7720'-7756', 7798'-7806' 5989'-5998' 6008'-6037', 6072'-6080' True Vertical depth 108 'TVD 2776'TVD 6264 ' TVD 12. Tubing (size, grade and measured depth) 3-1/2", J-55 tbg w/tail ~ 7520' Packers and SSSV (type and measured depth) RRH pkr ~ 7488' & QLP SSSV ~ 1786' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Iniection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations [~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge /- Signed Form 10-404 Rev. 12-1-85~ Title Associ ate Engineer Date (DANI) SW02/020 Submit in Duplicate STATE OF ALASKA '~ ~'~ ALASKA ulL AND GAS CONSERVATION CC,,vIMISSION WFLL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well Z 1. Status of Well Water Injector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-187 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21062 4. Location of well at surface 9. Unit or Lease Name 577' FSL, 1856' FEL, Sec.28, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1546' FNL, 1207' FWL, Sec.27, T11N, R9E, UM 2F-3 At Total Depth 11. Field and Pool 1348' FNL, 1373' FWL, Sec.27, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool 127' RKBI ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/16/84 01/22/84 03/31/84'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21.Thickness of Permafrost 8075'MD,6305'TVD 7945'MD,6196'TVD YES []( NO [] 1786 feetMD 1400' (approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/SP/GR/Cal, GR/CBL/CCL, Gyro, CCL/"2em._o. T.og '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#/47.0i~ J-55/L-8( Surf 3306' 12-1/4" 880 sx AS Ill & 630 ~x ;lass G 7" 26.0# J-55 Surf 8027' 8-1/2'" 275 sx Class G & 250 sx 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) 7698' - 7709'MD 3-1/~'! 7520' 7488' 7720' - 7756'MD 7798' - 7806'MD w/4 spf,90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 5989 ' -5998 'TVD See attached Adden :lum, dated 10/13/84: 6008'-6037'TVD for Fracture data. 6072'-6080'TVD 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED 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. ., .: -, , -; i' L'~-, ~ ~ .~'~ ; . .. . · ~ , '-~ i ".;;: :)' ?' !:.,./! ?., ::. '~ :., :'.-.: .~';z,...~ '~' ' . : ~-: · NOTE: DRilled RR 01/24/84, Perforated well & ran tubing 03/31/84. Well worked over 02/03/87, Form 10~07 WC2/O55/DAN I Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicat~// NAME - :~ '; I~clu~d~ interv, ai tested, pre§sure data, all fluid~ recovered and gravity, " :' ': MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. . . ~.. Top Upper Sand 7607 ~ 5915 ~ N/A Base Upper Sand 7618 ~ 592z~ ' Top Lower Sand ': - . ':7685' 5979' . Base Lower Sand 7865' 6129' '- ' .'i .~" ., _ . . . L' -- .. 31. LIST OF ATTACHMENTS Addendum (dated 10/11/8~). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .. Signed & ~ ~j,])C/L~ " Title Assoc~ ate Engineer Date // INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately 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 STATE OF ALASKA ~-'~ ALASK,. OIL AND GAS CONSERVATION COMb, .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend '.~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program I~ Plugging ~ Stimulate F;.. Pull tubing ~,~,,.Amend order ~ Perforate- Other- 2. N a Ar~ 00 fA ~)aPsekraa~ o [ n c, 3. Ad~lr.~)s..SBox 100360 Anchorage, AK 99510-0360 4. Location of well at surface 577' FSL, 1856' FEL, Sec.28, T11N, R9E, UM At top of productive interval 1546' FNL, 1207' FWL, 5ec.27, TllN, RgE, UN At effective depth 1402' FNL, 1327' FWL, Sec.27, T11N, RgE, UN At total depth 1348' FNL, 1373' FWL, Sec.27, T11N, R9E, UM 5. Datum elevation (DF or KB) RKB 127' 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-3 8. Permit number 83-187 9. APl number 50-- 029-21062 10. Pool l(uparuk River Oil Pool feet 11. Present well-condition summary Total depth: measured true vertical 8075 ' MD 6305 ' TVD feet feet Plugs (measured) None Effective depth: measured 7945 'MD true vertical 6196'TVD Casing Length Size Conductor 108' 16" Surface 3306 ' 9-5/8" Production 8027' 7" feet feet Junk(measured) None Cemented Measured depth 250 sx CS II 108'MD 880 sx AS III & 3306'MD 630 sx CI'G' 250 sx A5 I & 8027'MD 275 sx CI'G' True Vertical depth 108 'TVD 2776 ' TVD 6264 ' TVD Perforation depth: measured 7698 '-7709', 7720 ' -7756 ', 7798 ' -7806 ' true vertical 5989'-5998', 6008'-6037, 6072'-6080' Tubing (size, grade and measured depth) 3-1/2", J-55, @ 7532' Packers and SSSV (type and measured depth) RRH @ 7500' & QLP ~ 1962' 12.Attachments Description summary of proposal ~ Detailed operations program % BOP sketch 13. Estimated date for commencing operation January 28~ 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 ~~ ~~6/L~ Title. Associate Engineer Commission Use Only (JLQ)SA/200 Date Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Commissioner Approved by Form 10-403 Rev 12-1-85 Approval No. ~ .... ~(~ by order of the commission Date 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 ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAMS TUBIN6 HEAD 2 t. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. ?-1/16" - 5000 PSI PIPE PAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 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. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2. 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, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES, 8. 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. 9. OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO ZiO00 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10, OPEN BLIND RAMS AND RECOVER TEST PLUG, HAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO :3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, 1:3. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. I4. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. ,::. .~ ~ -~ ',:-. ~J 'dO dULY 28, 1986 NORDIC RIG 9-5/8") ADDENDUM WELL: 2F-3 1/24/84 Arctic Pak w/41 bbls AS I, followed by 58 bbls Arctic Pak. 3/14184 Rn GR/CBL/CCL, tag btm @ 7863' WLM, P0H logging· Rn gyro f/surf-7945'. 9/11/84 Rn temp log f/7850'-7400'. 9/16/84 Start Frac at: 1214 hrs, 9/16/84 Pmp 40 bbls, 120° diesel @ 12.5 BPM/4675 psi; 45 bbls Ho0/gel pad @ 15 BPM/3950 psi; 25 bbls Hg0/gel @ 1 ppg of 100 mesh (1000#) @ 15 BPM/3850 psi; 25 b~ls gel/Ho0 w/1 ppg, 12-20 sand (1000#). Pmp'd @ 10 BPM/3150 psi% Pmp 30 bbls 6 ppg 12-20 sand @ 10 BPM, press inc'd steadily f/3150-4100 psi. Stopped pmp'g 31 bbls ahead of schedule w/total sand pmp'd = 7560 psi. Flush w/75 bbls diesel/gel @ 10 BPM. Press went f/4400 psi down to 3700 psi. Complete frac@ 1236 hrs, 9/16/84. Rn CCL/temp log. 9/21/84 Ck sand fill inside tubing "A" sand perf's: 7298'-7709' and 7798'-7806' RIH w/sinker bars, tag fill @ 7694' POOH, RD Well SI 9/22/84 "A" sand perf's: 7298'-7709', 7720'-7756' and 7798'-7806' RU CTU, tst BOPE & tbg to 4000 psi. RIH w/CTU, start circ @ 7050' w/40# gelled diesel, CO to 7892'. Calc top of sand @ ~7690'. Moderate sand ret's. Circ cln w/132 bbls gelled diesel @ 1.6 bbls/min. Well kicked off flowing while on btm w/CTU. Start diesel flush, cln'd CTU w/15 bbls diesel; stopped pmp; SI well @ wing vlv, POOH w/CTU. Rec'd all fluid pmp'd & made 162 bbls mx'd diesel crude & LW. RD CTU. 9/23/84 "A" sand perf's: 7298'-7709', 7720'-7756' and 7798'-7806' RU S/L, tst BOPE & lub to 2500 psi. RIH w/sinker bars, tag fill @ 7830' (24' ratehole), RD S/L. Well rel'd to Production. Drilling Superintendent Dante z . , 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 Cas 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-6 213-8 2.13-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 2F-15 2F-16 2D-10 2D-16 Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers on i)n' · on · on · on · on · on · on · on · on · on 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 11/5/85 1115185 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 11/6/85 . ~'i .. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . . STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] V COMPLETED WELL i-]'~ OTHER [] 2. Nam~~r~AS~n' INC. 3. Add~s. O. BOX 100360, ANCHORAGE, ALASKA 99510 4'L°c~~~E LOCATION: 577' FSL, 1856' FEL, SEC. 28, TI!N, R9E, UM 7. Permit No. 83-187 8. APl Number 50- 029-21062 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2F-3 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER OIL ADL 25657 ALK 2583 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] 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-3 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 ,-. ., -C. ic.c' . . Alaska 0il & Gas Cons. Anch0ra~e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,j,/~/.~ The space below for Commission use Conditions of Approval, if any: Title KUPARUK Date OPERATIONS COORDINATOR 12/04/85 Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 ~, 7.1 ~q(% Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~'~-'' Post Office Box 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 dri!lsite 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 EP_,2 0 o,~ ~ ~s Cons, Commission AnChor~le ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~-... STATE OF ALASKA ~... ALASK/ IL AND GAS CONSERVATION C '4MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well COMPLETED WELL OTHER [] N/A . . 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF,etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 P001 N/A I see attached 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). /4) Pursuant to form 10-403, it is proposed that the attached list otU^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. SEP 2 o 19B5 Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~~ ~~ -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. -/-1-80 Approved Copy ,R®turrmd / · .... 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: 0092 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 25658 I! 25658 I! 25657 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 .';, , ECEIV ~.laSk8 Oil & G~s Crms Gommissior~ f- ARCO Alaska, 10~._' ~... Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P. O. ~' 100360 ~orage, AK 99510 ' . ~ ~f__= --~--- -/T~z~nsmittedAherewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OTIS PBU SURVEYS' ., 2W-8~<' 1/08/85 1B-7 "~_.12/14/84 2F-12 1/06/85 27-5 ~ 1/02/85 2W-§/'~. 1/07/85 W-6 -' 1/07/85 w-7 1/07/85 i lA-1'~' 12/31/84 1A-I--~ 12/15/84 lA-1 ...... 12/23/84 G-5.~- 12/25/84 2F-3~ -12/31/84 2V-8A~ 12/16/84 2B-10 ' 12/17/84 1Y-9-~ 12/20/84 -~-IC-..;A,~ 12/10/84 2F-2'~ 12/29/84 2F-15 ..... 1/05/85 2F-14- 1/04/85 2F-9 ~ 1/02/85 2~-8~ 1/01/85 API 029-21228 '029-2D616 029-21097 029-21073 029-21220' 029-05900 -- 029-20908 02~-21178. 029-21084 029-21 063 02 9-21048 029-2~ 090 029-21077 _ CAMCO PBU SURVEYS 1E-12-' 12/14, 16/84 /cat Receipt Acknowledged: DISTRIBUTION .... rlll$,..,.C,, Anchoracc B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Op$. J. Rathmell Well Files ARCO Aleska, Inc. i~ · subsidiary ol AtlantlcRichlieidComl:)any ARCO Alaska, In~--'' Post Offic~ ,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2F-3 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, Gruber Associate Engineer JG' tw GRU7/LIO Enclosure RECEIVED APR 2 4 ] 1t4 ~,Iaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 2F-3 COMPLETION SUMMARY RU Gearhart. Ran GR/CBL/CCL. Ran Gyro. RD Gearhart. Secured well. Accepted rig @ 1000 hrs, 03/30/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran gauge ring/JB to 7847' WLM. Perforated the following intervals w/4 spf, 90° phasing- 7798 7746 7736 7726 7720 7699 - 7806 - 7756 - 7746 - 7736 - 7726 - 7709 7698 - 7699 Ran 3½" completion assy w/tail @ 7532', pkr @ 7500', & SSSV 1962'. 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 @ 1630 hrs, 03/31/84. GRU7/CS03 RECEIVED APR 2 ]904 Ataska Oil & Gas Cons. Commission Anchorage 2F-3 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0045 hrs, 01/16/84. Drld 12-1/4" hole to 3320'. Ran 76 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3306'. Cmtd 9-5/8" csg w/880 sxs AS III & 630 sxs class "G". Bumped plug w/1500 psi - floats held - ok. Perform top job using 100 sxs AS I. ND 20" hydril and diverter. Instld 9-5/8" packoff and tstd ok. NU BOPE & tstd.ok. Witnessed by Ed Sipple AOGCC state rep. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10 new form. Tstd form to 11.5 ppg - EMW - ok. Drlg 8½" hole to 8060. Ran logs DIL/SFL/SP/GR/FDC/CNL/CAL f/8044' 3306'. Cont drlg 8½" hole to 8075 TD as of 1/22/84. Ran 185 its 7" 26# J-55 BTC csg w/shoe @ 8027. Cmtd 7" csg w/275 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. Secured well and released rig @ 0700 hrs on 01/24/84. DH81 2/09/84 ih APR 2 4 g84 A~aska 0i~ & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK' ,ILAND GAS CONSERVATION C '~MISSION w =LL C_ MPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL d(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-187 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21062 4. Location of well at surface 9. Unit or Lease Name 577' FSL, 1856' FEL, Sec.28, T11N, RgE, UM Kuparuk River Unit f YE~IRE. D f 10. WellNum~er At Top Producing Interval ! '-:.,,¢ 15/+6' FNL, 1207' FWL, Sec.27, T11N, RgE, UH ~5-'ur.. ~ ' 2F-3 i ?. L~ /~ 11 Field and Pool At Total Depth 13/+8' FNL, 1373' FWL, Sec.27, T11N, RgE, UN ...................... 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' EKEI ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/16/8/+ 01/22/8/+ 03/31/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8075'MD,6305'TVD 7945'MD,6196'TVD YES ~3. NO []I 1962 feet MD 1400' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/SP/GR/Cal, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE 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#/47.~# J-55/L-E0 Surf 3306' 12-1/4" 880 sx AS Ill & 630 sx Class G 7'-' 26.0# J-55 Surf 8027' 8-1/2" 275 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) 7798' - 7806' 3-1/2" 7532' 7500' 7720' - 7756' 7698' - 7709' w/4 spf,90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure :CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None. RECEIVED 2 4 J984 Alaska Oil & Gas 0~$. Commission Anchorage Form 10407 Rev. 7-1-80 GRU7/WC03 Submit in duplicate CONTINUED ON REVERSE SIDE ........ = ¢ ,. ~.',.. -, . ~ . ~-~. ,.'~, .. . , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · .. Top Upper Sand 7607?- 5915' ~ .. Base Upper Sand 7618' . -5924' · . . . Top Lower Sand 7685' 5979' N/A .:~..:. Base Lower Sand 7865' 6129' _ . . . . , _ 31. LIST OF ATTACHMENTS ' Drilling History, Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby ce~('ify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drillin,q Engr. Date '/-2'-///- /", ' 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 (G L) or other elevation (DF, KB, etc.). Item 23~ At~aC~hbd-supplemental records for this well should show the details of any m~ltiple stage cement- ing and the location of the cementing tool. Item 27' Method of 0p. eration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ...... jection,,Ga~ I~djection, Shut-in, Other-explain. · . Item 28: If no cores taken, indicate "none". Form 10-407 ,J CI]['~ N 0: i~ C) 3:3 ~ Z (:) 2 Zl~ ~::1... F'ARI..Ik: F I EL...El', NOIRTH F-;LOI::'E, AI_AE;I.:::A ' (_ 7.. 4 ..... HD, " ' .'r'f , : ' , ,-,z '.!ii; I (:! I'¢IA.-~.6;YRO ', ")-.-- ,::l ~ '.:.~;I..IRVF]:Yf_'IR: F' EFFERf ..... RN/._IAI'4N, DATE RI_IN 14-1'1AR-'-',:, .I- .....'::' ]: G P'I ~ :'::_ (:) ('). N I".1 -" ':7 4 C"., F' R O B E I',10 ." ."5 E; % I:::r"ii::;:E~:S :[ OFIT: N '.-T; 37 N :i:i; I.l.I I::;~ "/E Y "[' (.~ I'::: E: N F' R 0 Pi [,J E L.. L H E A ][:f ' ~J Whipstock A PETROLANE COMPANY REC:OR[I OF .'-:I_IRVEY RClrl]:l_lS OF L-:LIRVCITURE I"IETHOD '..]RCO AI..ASI::.~., I I'qC:. ='AD ':?.1='-'., WELL NO -' :':~ !':; I GHA-'GVI"-~FI <.L.II:..'AI..(I..II.::. 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F'I hi A 12-- C:[O'..T; ORE- '----DIRECT I"0I~: D I '.:; T A N C: E: N'T._-,'--EIEGLS'-'~._,~--T'Ff'F~._~'7 SEF:S E '4/.~= ¢~-, FEET '"l._ ._1 m .. -- ~liF ;~:~r Eastman ~ A PETROLANE COMPANY ,JOB I',lf]l: A('):_'-':84. Z ()24(') F::'AGE I",10,, .' 1 ,, ............................. M A R K E: R ................... T R LIE S LIB S E. A .............................. L.%i[fE .............. FI...~: A~r]REtT~ E'R T I c: A L: ......... '-- "" ............. ' I'"- I" '"' I--' ' ..................... NAME ................[ [".F TI-I [ EF I H D I FI'-- £ E:I- ] H C 0 0 R D I N A 'r E F.; ][] I STANCE D I I:REC]" I ON TH I CI<IqlE'.BS FEET FEET . FEET FEET FEET F' F E.".'T' [) P'l . I~..~ i- "lC~' .1~1' ,-i ~ .-i I; ;" .'#l I~_~_.~ TOF:' I..IF::'F'I!::R. SAIxlD 7607 ,, 00. .. .::, ~ 15 . (..)._, 1 67~2 .0 .,=~'""~'.,/,:,c,. 05 .:,'-' 1.,. 7. :34 N .::, L) 6 .= . ...., ..:, 4:37/8 .6:3 N 44 8 E BA'.~;E I..II:::'F'ER SANB 7618,, 00 57~24.. 07 16S/:3. S/ 57$)7.07 3162,, 15 N 3066.5? E 4404. ?~0 N 44. 7 E T_.F I_LIWER .::,~iqD ~ .......,. 0[~ ~~~~ ~~._, .:,I .. 1~~0.. ~ ..... L 444 ...... ~ N~ ..., E.. .... ' -- 1 ....... 20 E 4~42.03 N 44 0 E ' :{ ...... "~ ¢'/'=; 00 6129.26 1" '-' =' '-"-' ' EA.:.I::. LOWER SAND ~,::,:: ...... 7.:,,..,,7 6002,2(~ :,,:.67, ~:::: N 3 ~'~ .... Eastman Wht' stOcl A PETROIANE COMPANY Suggested form to be inserted in each "Active" well folder to d~,eck for timely compliance with our regulations. Operator, ~11 name and ' Number Reports and Materials to be received by: Date Required Date Received Remarks i Completion Report Yes .z,/. ?~,,,~ ~...~ ,~L7/ (,,~ ,/~ '. Well History Yes / " ;<, Core Chips - "' "' "~ · ...¢>:"./ Core Description :.;'/.~ .~,"~'b '"----"-"-'~" .,Registered Survey Plat :,C.--.~.-'~ .~'V . Inclination Survey ,..51~.%..?' . C,>,~ _Directional Survey '/~'~'/ Drill Stem Test Reports , ,~_ ~_- · Prcddcti0n Test Reports ~.~ · , · · ARCO Alaska, inc Post Office boY, 100360 · Anchorage, Alaska 99510 Telephone 907 276 1215 ~pril 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 APR I '2 Alaska Oil & Gas O.:ns, A ' ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~, ALASK¢ ,IL AND GAS CONSERVATIONC ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2, Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 COMPLETED WELL I~X OTHER [] 4. Location of Well Surface:' 577' FSL, 1856' FEL, 5ec.28, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 7. Permit No. 83-187 8. APl Number 50- 029-21062 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate I [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) ~. Altering Casing [] Abandonment [] Other 13. 'Describe Proposed or Completed Operations (Clearly state ali 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. Ran Gyro. RD Gearhart. Secured well. Accepted rig ~ 1000 hfs, 03/30/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran gauge ring/JB to 7847'WLN. Perforated the following intervals w/4 spf, 90° phasing: 7798' - 7806' 7746' - 7756 7736' - 7746 7726' - 7736 7720' - 7726 7699' - 7709 7698' - 7699 Ran 3-1/2" completion assy w/tail ~ 7532', pkr ~ 7500', & SSSV ~ 1962'. ND BOPE. ok. Disp well w/30 bbls diesel & crude oi-1. Dropped ball & set pkr. Opened SSSV. released rig ~ 1630 hfs, 03/31/84. NU tree & tstd to 3000 psi!- Set BPV. Secured well ~ 14. I hereby certi,fpAthat the foregoing is true and correct to the best of my knowledge. Signed /~ ,~.~~ Title Area Dril ling Engineer The space f ssign use Conditions/Of APprov~, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU6/SN39 Submit "Intentions" in Triplicate and "Subsequent Reports': in Duplicate KUPARUK ENGINEERING Well Name: .~4~ ~~/ Log Date Run ~L / DISTRIBUTION NSK Operat ions Dr il 1 lng ~te of AK- Blueline Bluel ine Blueline & ~ Sign &/~jeturn the attached..~ copy/~s. / recei~ %~R,.f~ d~a.~ ':::: L/eteturnto: ARCO' 'ALASKA, ::~INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING Well Name: Transmittal Date Run ¢' DISTRIBUTION NSK Operation Blueline Dr ill ing Bluel ine Geology Bi/Se/Film R&D Bluel ine D&M ...... -- ~' Bluel~ine -Sta~e ....................... B1ZS_F~~? F.G. Baker Blueline D.B. Schaf er Blueline & returnm~. ~. ?a~t,a¢ ed Sign . ~" ;,~' ~ copy a~ rece~n~-o~f~ge:~p --~ -, Alaska0il&~asCorm. Commjss[o~ Return ~o: ARCO~At;A'§~,'-'--' INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING TRAHSMITTAI_ = '~ ~/~ TO' FROM' D. Fay Allison WELL NAME' see below Transmitted herewith are 'the following' pLEASE NOTE. BL - BLUELINE, S - SEPIA, F - FILM~TAPE, PC - PHOTOCOPY Well Des cript ion Date Run R ~-~-PT ACkNOJLEDu~D' EASE RETURN RECEIPT TO' - ARCO ALASKA, IHC. c,--.'-, e','." - ATTH D. FAY ALLISON ATO/11'15"B ..... ' - ,.. · ' '"" P. O. BOX 100360 AHCHORAGE, AK. 99510 ARCO Alaska, In' Post Office ,.,oX 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-1 2V-6 WSP #3 2F-2 2V-7 WSP #13 2F-3 2V-8 Hemi Spring St #1 2F-4 2B-5 Thank you. Sincerely, Drilling Engineer JBK/SHi:ih ARCO Aiaska. Inc. is a subsidiary of AtlanticRichlieldCompany -. ' " ' ,~--., STATE OF ALASKA ,_, ALASKA L AND GAS CONSERVATION CZ .'MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Per~_l~87 ARCO Alaska, Tnc. 3. Address 8. APl N~l~r_21062 P. O. Box 100360, Anchorage, AK 99510 50- 9. Uni, t,,o,r.,L-eRsl~ Name ~u~lver Unit 577' FSL,1856' FEL, Sec.28, TllN, R9E, UM 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 ALK2583 10. W~__°3 11. Field and Pool KPU River Field KPK River Oil Pool Obj. January 84 For the Month of. ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0045 hrs, 01/16/84. Drld 12¼" hole to 3320'. Ran, cmtd & tstd 9-5~8" csg. Performed top job. Cont drlg 8½" hole to 8060'. Ran logs. Cont drlg 8½" ~ole to 8075'TD. Ran, cmtd and tstd 7" csg. Displ brine from top of well. Secured well and released rig @ 0700 hrs. on 1/24/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# 3-55 HFERW BTC csg w/shoe @ 3306'. class "G". Cmtd w/880 sxs Arctic Set III and 630 sxs 7" 26# J-55 HFERW BTC csg w/shoe @ 8027'. Cmtd w/275 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DTL/SFT~/FDC/CNT,/S? / C-R/CAT~ / f/8044 ' -3306' 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo~ or~'thi~f~'m is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~ssion by the 15th of the succeeding month, unless otherwise directed. F°J~r~9.-4/~l~ 102 Submit in duplicate 2F-3 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0045 hrs, 01/16/84. Drld 12-1/4" hole to 3320'. Ran 76 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3306'. Cmtd 9-5/8" csg w/880 sxs AS III & 630 sxs class "G". Bumped plug w/1500 psi - floats held - ok. Perform top job using 100 sxs AS I. ND 20" hydril and diverter. Instld 9-5/8" packoff and tstd ok. NU BOPE & tstd ok. Witnessed by Ed Sipple AOGCC state rep. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10 new form. Tstd form to 11.5 ppg - EMW - ok. Drlg 8½" hole to 8060. Ran logs DIL/SFL/SP/GR/FDC/CNL/CAL f/8044' 3306'. Cont drlg 8½" hole to 8075 TD as of 1/22/84. Ran 185 jts 7" 26# J-55 BTC csg w/shoe @ 8027. Cmtd 7" csg w/275 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. Secured well and released rig @ 0700 hrs on 01/24/84. DH81 2/09/84 ih THRU: FROM: M EMORAN DUM State of Alaska ALASKA~_.OIL AND GAS CONSERVATION COmmISSION TO: C. t~rton DATE: January 24, 1984 Cha~ . ~ ~" ~~' FILE NO: 51.5 Lonnie C. Smith Co~is s loner TELEPHO N E NO: Edgar:~w. Sipple, Jr /- SUBJECT: Witness BOPE Test on Petrole~ InspeCtor ARCO's Kuparuk 2F-3, Sec. 28, TllN,R9E,~{, Pemit No. 83-187, Parker Rig 141. Tuesday, January 17, 1984: I traveled this date via Alaska Airlines t°"prudhoe Bay to witness a BOPE test on ARCO's Kuparuk 2F-3 Well. Parker's Rig 141 was in the process of drilling the surface hOle. Wednesday, Januar, y 18, 1984: The BOPE test commenced at 10:30 am Ahd was ~onh%uded at '12:'10 pm. There were no failures. I filled out the A.O.G.C.C. BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 2F-3, Parker Rig 141. Attachment. 02-00IA(Rev. 10/79) ,4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COHblISSION B.O.P.E. Inspection Report Date /-"/d~::' '''''' ~'~ ¢ Location: Sec ~ Drilling Contractor Representative Permit" F3'-- ~g/~ Casing Set @_3~ O~ ft. Representative. ~ ~/~&~,~A/' Location, General ~ ._ ACCUHULATOR S'YSTEH Well Sign tgi' Full Charge Pressure 3~00 ps.ig · General Housekeeping ~)~_ Pressure After Closure /~ psig Reserve pit ~ 200 psig Above Precharge Attained: / Pin OO sec 'Rig - ~ Full Charge Pressure Attained: ~ miring sec Controls: Master Remote ~ ~ Blinds switch ............. BOPE Stack Test Pres~re Kelly and Floor Safe~y Valves - ~¢ / ¢~ / ~OO Upper Kelly~ e~Test Pressure Annul¢r Preventer Pipe Rams ¢~ ~OOO Lower Kell~ / CWTest Pressure Blind R~ ¢~ ~¢¢ _ Ball Type ¢¢~est Pressure ¢~ ~ ~~Test Pressure Choke Line Valves O~ ~o~ Inside BOP H.C.R.~alve O~ ~o om Choke Manifold ~ ~ Test Pressure Kill Line Varves ~ O~o · . Chegk V~ve ~ ~~ No. f~nges ~ ~ '' Adjustable Chokes I- O~ ~ ~(~ llydrauically operated choke ~-o~ Repair or Replacement of failed' equipment to be made within ~ days and'~ ~ Inspector/Commission office notified. · Distribution orig.' - AO&GCC cc - Operator cc - Supervisor. ARCO Alaska, Inc. ?"'"' Post Office B~... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-3 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 1, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU5L85- tw EnclosUres ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _AND GAS CONSERVATION Ct 'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-187 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21062 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well Surface: 577' FSL, 1856' FEL, Sec.28,'TllN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 12. I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 10. Well Number 2F-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate ~J Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~[' Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) (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 1, 1984 Subsequent Work Reported on Form No./'(~- q~-'~ Dated .~_/~_~/~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' ' ' ' Signed ~~~~ Title A~ea DPJ,]Jng EngJ.ee~ Date The space ssion use APproval, any: Condition~of Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10403 GRU5/SN47 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate December 21, 1983 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Res Kuparuk River Unit 2F-3 ARCO Alaska, Inc. Permit No. 83-187 Sur. Loc. 577'FSL, 1856'FEL, Sec. 28, TllN,-RqE, Btmhole Loc. 4134'FSL, 1485'FWL, Sec. 27, TllN, RqE, Dear Mr. Kewin, 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 survey is required as per 20 AAC 25.050(b)(5). If available, a gape containing the digitized log information shall be submitted on all logs for.copyxng 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 promulgated thereunder (Title 5, Alas~m Administrative Code). Prior to commencing operations you may be contacted by the-Habitat Coordinator's Office, Department of Fish and Game. Pollution ol 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, please notify ghis office 24 hour~ prior to commencing installation of tile blowout preven- tion equipment so tb~t a representative of the Commission may '\'Jeffrey B. K "-~ Kuparuk River Uni~ ~_ - 3 -2- ~-~L, ember 21, 1983 be present to witness testing of the equipment before the' surface casing shoe is drilled. Wq~ere a diverter ~ystem is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~misslon may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, plea~a give thi. notification so that we may have a office adequate advance ~ ~ "· witness presager. Very truly yours, C. V. Chatterton Chairman of BY A!a~ka Oil and Gas Cons~rvation Co~ission Enclosure cc., Department of Fish & G~e, Habitat section w/o encl, Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 'l $0 Anchorage, Alaska 99510 Telephone 907 276 1215 December 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2F-3 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 2F-3, 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 o Diagrams and description of the BOP equipment Since we estimate spudding this well on January 19, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Si ncerely, / Area~Drilling Engineer JBK/GRU5/L67 Attachments ARCO Alaska, !nc. is a Subsidiary of AtlanticRichfieldCompany PHASE I AS BUILT CONDUCTORS I- 8 94.3 94.4 94.5 09 160 010 150 011 140 O~ 1:50 28 27 34 BASIS OF ,PAD ELEV. IS T.B.M. 8:~-25-49.' O.G. ELEV. s INTERPOLATED FROM DWG. SR. 8 F- i 2 - ;~0:50 REV. I RENUMBER ALL WELLS PER NSK 4 DRILLING 12,/2/83. ( IBOOROTATiON OF NUMBERING) ; REV. 2 CHANGE ALL ELEVATIONS LOCATED IN PROTRACTED SECTION TOWNSHIP II N. tRANGE 9 E.,UMIAT 28 MER. ,BASIS OF LOCATION IS MONUMENTS C.E.F..2 N.E. & 2'C MIDDLE PER LND ASSOCIATES. DElL .SITE AS BUILT Z,F CONDUCTORS LOCATIONS WELL I WELL 2 WELL WELL 4 WELL 5 WELL 6 WELL 7 WELL 8' Y= 5~949, $41.83 Y= 5,949,400.93 .X= 517,382.34 518' FS L Y= 5,949,460.06 Xm 517,372.18 577' FSL Y" 5,949, 51 9.07 FSL Y'5,949,566. $9 X" 517,658.11 683' FS L 'Ye ~949, 507. 09 X" 517,648.17 62 4' FSL Y= 5~949,448.14 X= 5,17,658. $ I 565' FSL Y = 5,949,389.02 X · 517,668.3:5 506' FS L L~t. 70° 16'21.9780" Long. 149 1857' FEL I. at, 70e 16'22.5595" Lea9, 149e51'33.896'' 1847' FEL Let, 70 Lon~, !4~e51~34. 161" 1856' FEL Lat. 70016'25.7219'' Lo nc]. 1,49°51 '34.451 1866' FEL~ Let.'?O° 16' 24. 18 I1" Lor~. 1,49°51'26.410" 1590' FE L' Lot 70° 16'23.5977" LO ag. 1.49°51 '26.12 I" 1580' FEL Let. ?Oe 16'2~. 0176" ~ 1,49°51'25.851'' 1570 FEL' L~t.70e 1~'22.4:55 7"' Le~. 149e51' 25.543" 1561' FEL · DAVID FILUCCI 527( :50 e 32 THIS 33 31 ~ SURVEY _. 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 ~ DIRECT SUPERVISION ANO THAT ALL. DETAILS ARE CORRECT AS OF NOV.'5,1983. !BSSOI], ARCO Alaska, Inc. Kuperuk I~'oj~t North Slope Drtlllml DRILL SITE E.F CONDUCTOR AS'BUILT LOCATIONS date* II · 9,8 3 acele' I"= 400' "'--"-- STATE OF ALASKA ALASKA OIL ..,4D GAS CONSERVATION COMrv,..SlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 577' FSL, 1856' FEL, Se¢.28, T11N, RgE, UH At top of proposed producing interval 3885' FSL, 1250' FWL, Sec. 27, T11N, RgE, UH At total depth 4134' FSL, 1485' FWL, Sec. 27, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 127' PAD 98' ADL 25657 ALK 2583 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 8210' ND, 6311' TVD feet 14. Distance to nearest property or lease line 1146' ~ TD feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 20. Anticipated pressures 9. Unit or lease name Kuparuk River Unit ~-'~. 10. Well number 2F-3 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 2F-2 well 60' @ surface feet 18. Approximate spud date 01/19/84 2865 psig@ 80°F ..Surface feet. MAXIMUM HOLE ANGLE 44 o I (see 20 AAC 25.035 (c) (2) 3216 psig@ 6311 ft. TD (TVD) SIZE Hole Casing F4" I16" ~2-1/4" I 9-5/8" ~-112" / 7" / Weight 65.5# 36.0# 26# Proposed Casing, 22. Describe proposed program: CASING AND LINER Grade I Coupling Length H-40 / Weld J-55 HF'IRW BTCI J-55 / BTCI 8182' HF-ERW / I _iner and Cementing Program SETTING DEPTH MD TOP TVD 80' 3269' 29' 29' I 29' I 29' I I 28' I 28' I MD BOTTOM TVD 109'1 109' 3298' 2783' I 8210'16311' QUANTITY OF CEMENT (include stage data) ± 200 cf 880 sx AS Ill & 630 sx Class G 250 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8210' MD (6311' 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 3298' MD(2783' TVD). A 1~-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 2865 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-55, 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~that the foregoing is true and correct to the best of my knowledge Th e space ~vv~f~~l~sion US' Samples required I I~YES ~qXI O Permit number [ Form 10401 '~ff~/Pl~24 ~ TITLE Area Dri 11 i ng Engi neet DATE Mud log required DYES ~LNo Approval date ~ 92-91 /R~ ,COMM ISSI O N ER DATE by order of the Commission Submit in triplicate CONDITIONS OF APPROVAL I D irectional Survey required [ APl number ~YES []NO 50- L2 SEE COVER LETTER FOR OTHER REQUIREMENTS I PERMIT TO DRILL 2F-3 installed and tested upon completion of the job. 2F-3 will be 60' away from 2F-2 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7218'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. _ PAD: 2F, t~EI:L. NO, ?':-.:~ PR'OPOSED ...... .... : , - : - . --~ ...... : ' - ~ ...... ~~ ..... i ..... ; '~ _ ~ ...... ~ ....... - EASTMAN,- WHIPSTOCK~ INC ...... } ........ ~ : : ::.2~_':-:: :S:::_. :.:._: :':~_:-. _ .-; ....... + .... - : .... :. : :_:: :__ ::-::::~::_: _ :.: :: :_ _-:_. :::.:: :_: :;_: ::_::.:: '. :-.._:::._ ~ .:.:_::~:"-::_:: :-:-:_::::::"~'::::'::":':~ .............. ....... ~T:--. .. _ .... - ............................ ...... : ........ .....[[ .... : .... ~ -:--:2~_~: :: 2~ ::¥/~ ~:: =========================== -:--~.: ........ ~ .....~ ........ ~ .......... ~ ....... ~--~ ..... : - .................. -!-- : : i ...... ' ....... i ..........~ ......... = ........ ~ ..... ~ .... --~ .... t .... - - '~ ......... ~--~' :::::::::::::::::::::::: :/--:' ........ ~ ......... ~ ............... ~ ........... ~-.-~~--~ -- ~ -_:~- ~-- -E~D=~OE:~DES~~E:~2~_ .... ~_ ~--~ ...... ~.~--~-i ...... I ' ..... ..... : ............. . ........ : ....... 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' : ' ' ~:_~2 : ..-_::: :. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: --:--:: _ - ....... : ~ -:_'._.' :- - ::- ':: I __- :__ _ : ........ : ........................ ...... ............... .................. ..... ......... ,?.--, . - ~ .... ~ ........................ s ........ ~ ....... '. .... ~='? .... ~-i~ ..... h~ ........ ~ I . ~ .~: ~ ; · = ~ ~ . : ' . I ~ · ~ ' : ~ .... ~ , . ~---, .~' ' ~ , ·:~- ~-' ' ..... ' ...........~-"-~-~- -?~- ' i ~ : i : : ; ~ ~ ~ ~ '= ~ -.. : : ' ' ~- .... ~---~~:~-~---'~~:~ :I',:'-~~-~---~ .... ~ .......... i '--'! '- - ~ . ~~- ...... :- -- ~ - . : , ~ · ~ . ~ : . , _ } : ~_~ ........ _.~~-- > : .................. i __._._~_._. _______._. _~__._ ~ __4 ..... >.___~-~--~--T~---~ : : :-~ .... _j ........ ~__. ~_ . ~_ _ ~-~:~-:'~::~~-~-'-. - ~ - _ ; ~ .... i. , ~ - . - . . ~_:::::::::::::::::::::::: ..... ~ ............... ~ ....... ~ ...... T .... i . . ~ . , ..... ~_: ................... - .................... : ..... ~___~--- - T '! ......... ; ..... ~ ' -~. . __:::_.~o°o_ :.... :: :.: ..... ::::.:.~:::_:::~::_::::::::::::::::::::::::::::::: ~---:~ ~ ~_ . ~ :. [ , ~:. ~__ . ~ :' ._ _ '_: .... .... : ..................... ....... ~ ................. · ............... :-- ::-::-~'::----: ........... ....... : - ........ . ::::::::::::::::::::::_%:2~___:.:'_:::-:2_%:._:;:~:~-~L..: L_:_~ ....... : .... ~ ..... ~-~-~---~ ..... ?'~ ~ ' '' i' ; : - ':'-'~'~ :TOP:-:-UPpE ~DS--~ :;'~-: : :.: 1--':' 2 ~: TAReET:;CNT~:;-::TV~6~-- T~=~8~~~~-,~ ~-~~-~~,~:-:-: ,~ ' I ' ' _ ' ! ' ' ' ~ - - ' - ~-~ .... : '~'"' ~- '~ ~ ' ~ I ' ..... ~ .............BASE-KUP:S~--:-TV D=6 ]/~_~T~I-~:~_~?~ .... : ..... /~__:~ ........ : ......... ~ ....... ............................................ ~-- ,: ...... ~ ............... ~ ~ , i . O: '- : _ - .'-1:000 ::2';:-7: : ................. ~ ....... ~ ........ : ........ : ......... : ...... : ........ ~ .......... ........ ~ ...... - .... ~ ................ _ . . .... : ...... ~ · ...... ~ ....... : ' ._ -: ...... ~ ...... : ....... : .............. ? ....... - . . ... __~ . : ................ : ........ ~ .... .............. ~ .......... · ........ _ _ . ........... : ............ ~ ................. ~ .... ._ ..~ ....... ~ ....... ~ ~ . . _ - : ........................................... ~ ............ ~ ......... ?..-:-~ .... ....... ARCO-AL&$K&.- INC- '-~ ....... - i ..... ~ - PAD 2F; WELL- _NO, _ -~__~PROPOSED'_ ~';L:- '... i ....... ~ ......~ .......... - ....... ~ ....... ~ ........ ~ ....... ~ ....... L; ~' ' : ___2 __~' ........... .... ;_; ........ , ......... : ..... : ........ ~ ....... ~ ......... ; : _: ................... ........ ' ~ ....................... ~ .... ~ ~ .........__...:._L ...... ................. ............ ' ' : __~ ........ ~ ......... ............. ~ ............ ~ : ; ' ' ; . ' ; ~ , , , I : : , : ..... ;% ............. -:* ~~-: P~-; I ; ; ~ i ~ : :!~, : ~ ~--~-';-f~-'~~~'- .... ~ ......~ .... ~-i' ~, - ....... ~ ........ ~ .................. : - ~ '- =~ ' : ~ ' '~~t~-~ _. ,~ ..... ; .......................... ~ .~ ~ - .... ~__ : ~__ - . . __ _~ ....... ~ .......~ ......... ~ ............ f -~ .. _: ........................ ~ , . ....... ;~ ........... ; : : --~ ..... ' ......... ~_~ .... ' ~ L. , : : __~ ....... ~ .... : ...... ~ ...... ', .... i'-' ' ' ; , i ,. .......... ~ ............. ~ ....... I''~:-- ..................................... _ .. . _. , . . : : · : ~: . m I. 2. 3. 4. . Surface Diverter S~,stem 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/10" lines to resem~e pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. . Maintenance & Opera.tion Upon initial inslallation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event.that gas or fluid flow to surface is detactad. If necessary, manual ly override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor I I ANNULAR PREVENTER BLIND RANIS PIPE RAMS 7. [JDRILLING ! t -PIPE RAMS ) s C t CSG HD . 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 11" - 3000 psi casing head 3, 11" - 3000 psi x 13-5/8" - $000 psi spacer spool ¢. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drtlllng spool 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling-spool w/choke and ktll 1 tnas 7. 13-5/8" - 5000 psi pipe rams 8, 13-5/8" - 5000 psi blind rams 13-5/8" - 5000 psi annular ACClJNULATOR CAPACITY TEST 1. OIECK ANO FILL ACCU/dULATOR RESERVOIR TO PROPER LEVEL glTH HYDRAULIC FLUID. 2; AS~RE TNAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI IXIgNSTREAM OF THE REGULATOR. 3. OBSERVE TINE, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIHE AND PRESSURE REI~IAINING AFTER. ALL UNITS ARE CLOSED I/ITH CHARGING PU~P .OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOgER LIHIT IS 45 SECONDS CLOSING TIHE AND 1200 PSI REHAINING PRESSURE. 13"518" BOP STACK TEST 1. FILL BOP STACK AND HANIFOLD WITH ARCTIC DIESEL. 2. .CHE~K THAT ALL HOLD OOgN SCRE]dS ARE FULLY RETRACT- ED.. PREDETERNINE DEPTH THAT TEST PLUG gILL SEAT AND SEAT IN I/ELLHEAD. RUN IN LOCK DOgN SCREMS IN HEAD. 3. CLOSE ANNULAR PREVEtfl'ER AND CHOKES AND BYPASS VALVES ON HANIFOLD. 4. TEST ALL COHPONENTS TO 250 PSI AND HOLD FOR 10 #ZNUTES. $. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 #ZNUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 HINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES. BLEED DOgNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAZNZN6 UNTESTED HANIFOLD VALVES, IF ANY, IJZTH 3000 PSI UPSTREAH OF VALVE AND ZERO PSI DOgNSTREAH. BLEED SYSTEH TO ZERO PST. 9. OPEN TOP SET OF PIPE RAJ~ AND CLOSE BOTTOH SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 #INUTES BLEED TO ZERO PSI. 11. OPEN BOTTOH SET OF PIPE RAHS. BACK OFF RUNNING ,JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PS! FOR 10 HINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAHS AND RECOVER TEST PLUG. HAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET ZN DRILLING POSITION. 13. TEST STAI~)PZPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP'TO 3000 PSI WITH KO~EY PUMP. ' 15. RECORD TEST INFOR~TION ON BLOWOUT PREVENTER TEST FORM SIR MID SEND TO DRILLING SUPERVISOR. 16. PERFORH COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. t j- · ANNULAR PREVENTER 11 m ) . BLIND RAMS '. ~.' { .. t PIPE RAMS ¢ ~D' ~IpOL!ILN~ - PIPE ) 7 HD C_~G D IAGRN4 #2 13-5/8' 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head Z. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7-1/16' - 3000 psi x 11' - 3000 psi double studded adapter $. Il' - 3000 psi x 15-$/8' - $000 psi spacer spool $. 13-$/8' - 5000 psi x 13-$/8# - $000 psi drilling spool 7. 13-5/8' - 5000 psi pipe runs 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-6/8' - 5000 psi pipe rams 10. 13-5/8' - 5000 psi blind rams 11. 13-5/8' - 5000 psi annular ACCH~LATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Z. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI 90WNSTREAN OF THE REGULATOR. 3. OBSERV/ TINE THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TINE AND PRESSURE RE)4AINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUNP OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT - IS 45 SECONDS CLOSING TIME AND i200 PSI REMAINING PRESSURE. 13-5/8' BOP STACK TEST, 1. FILL BOP STACK AND HANIFOLD WITH ARCTI.C DIESEL. Z. CHECK THAT' ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDET~INE DEPTH THAT TEST PLUG WILL SEAT Am) SEAT Z. WEU.HE~. RUN ZN LOCK OOWN SCREWS HEAO. 3. CLOSE ANNULAR PREVENTER ANO .. CHOKES ANO BYPASS VALVES ON 4. TEST ALL CONPONENTS TO 250 PSI ANO HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PS! ANO HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER Atto CLOSE TOP SET OF PIPE 7. INCREASE PRESSURE TO 3000 PSI ANO HI)LO FOR 10 MZNUTES. 8. CLOSE VALVES OZRECTLY UPSTREAM OF CHOKES. BLEEO OOWNSTRE~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTEO MANIFOLO VALVES, IF ANY, WITH 3000 PS! UPSTREAM OF VALVE ANO ZERO PSI OOWNSTREAH. BLEED SYSTEN TO ZERO PSI. 9. OPEN TOP SET OF PIPE PANS ANO CLOSE BOTTOM SET OF PIPE RAPS. 10. INCREASE PRESSURE TO 3000 PSI ANO HOLO FOR 10 MINUTES BLEEO TO ZERO PSI. 11. OPEN 801TOM SET OF PZPE RAHS. BACK OFF RUNNING JOINT ANO PULL OUT OF HOLE. CLOSE BLINO RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI o 12. OPEN BLINO RAMS ANO RECOVER TEST PLUG. MAKE SURE MANIFOLO ANO LINES ARE FULL OF ARCTIC OZESEL ALL VALVES ARE SET IN ORZLLING POSITION. 13. TEST STANOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND ZNSIOE BOP TO 3000 PSI WZTH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANO SEND TO ORILLZNG SUPERVZSOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (8) (3) Admin (9' thru 11) (10 and 11) (4) Casg , Ig~- -'~.4,~, ,~,~_~ (~2 't~'ru 20) (21 thru 24) (6) Add: YES NO 1 Is the permit fee attached ........................... " ,';:?'z 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. ~"- ....__ 8. Can permit be approved before ten-day wait .......................... ~½~- .... 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. REMARKS 21. 22. 23. 24. 25. Does operator have a bond in force .................................. ,',,,,%,,. .... Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface . 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 ....................................... flJff Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~;?i~'~ psig .. ,~I~'" Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o Geo logy: Engin_ezer~ing: HWK Jz~. LCS ~~EW ~--' WVAt~__ JKT~HJH ~'-~.~ JAL ,. MTM-~-' rev~ 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE z~ ~ .o.: ~ '~ ~2 (~ '~; ..... ~ .... 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. 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