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188-077
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-07 KUPARUK RIV UNIT 3O-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-07 50-029-21840-00-00 188-077-0 W SPT 6502 1880770 3000 2350 2350 2350 2350 60 60 60 60 REQVAR P Adam Earl 6/24/2025 MIT-IA per AIO 2C.032 to max.ant.inj.psi 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 3O-07 Inspection Date: Tubing OA Packer Depth 320 3325 3125 3100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625081342 BBL Pumped:3.9 BBL Returned:3.8 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-07 KUPARUK RIV UNIT 3O-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3O-07 50-029-21840-00-00 188-077-0 W SPT 6502 1880770 3000 2650 2660 2650 2650 70 80 80 80 REQVAR P Austin McLeod 6/16/2023 Two year to MAIP. AIO 2C.032. 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 3O-07 Inspection Date: Tubing OA Packer Depth 700 3500 3300 3260IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230617185015 BBL Pumped:3.6 BBL Returned:3.4 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 Two year to MAIP. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:20:31 -08'00' MEMORANDUM TO: Jim Regg E'fG� (p/ l(I r -O P.I. Supervisor llll Z. FROM: Adam Earl Petroleum Inspector Well Name KUPARUK RIV UNIT 30-07 Insp Num: mitAGE210607103747 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConowPhillips Alaska, Inc. 30-07 KUPARUK RIV UNIT 30-07 Src Inspector Reviewed By: P.I. Suprv��L Comm API Well Number 50-029-21840-00-00 Inspector Name: Adam earl Permit Number: 188-077-0 Inspection Date: 6/3/2021 Packer Depth Well 30-07 Type Inj w 'TVD 6502 PTD 1880770. " Type Test sPr- Test psi 3000 BBL Pumped: 37 ' BBL Returned: 3.2 Interval RFQVAR P/F P Notes- MIT IA tested as per AIO 20.032 to Max Ant Inj- Psi / Tuesday, June 8, 2021 Page I of 1 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2450 � 2410 1 2450. 2450 -- _ - IA 660 3310 3140 - 3100 -r OA 140 160 - 160 I 160 - Tuesday, June 8, 2021 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July I, 2019 TO:Jim Regg P.I. Supervisor t EG -] =j tq / I SUBJECT: Mechanical Integrity Tests // ConocoPhillips Alaska, Inc. 30-07 FROM: Brian Bixby KUPARUK RIV UNIT 30-07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -miz— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-07 Insp Num: mitBDB190619115509 Rel Insp Num: API Well Number 50-029-21840-00-00 Inspector Name: Brian Bixby Permit Number: 188-077-0 Inspection Date: 6/16/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-07 Type Inj WITVD6502 Tubing' 2215 ' 2225 2225- 2225 . PTD 1880770 Type Test SP Test psi 3000 IA 1060 3290 - 3160 - 3135 - BBL Pumped: 3.3 ' BBL Returned: 3.1 OA 380 580 - 580. 580 - Interval REQVAR P/F P Notes- MITLA to maximum anticipated injection pressure per AIO 2C.032 ✓ Monday, July I, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim ReggtR / P.I.Supervisor e c `9,2 (67 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-07 FROM: Chuck Scheve KUPARUK RIV UNIT 30-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry —rte NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-07 API Well Number 50-029-21840-00-00 Inspector Name: Chuck Scheve Permit Number: 188-077-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605172544 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-07 ' Type Inj W "TVD 6502 ' Tubing 2775 • 2775 - 2775 - 2775 - PTD 1880770 - Type Test SPT Test psi 3000 - IA 760 3400 - 3220 - 3200 - BBL Pumped: 4.4 BBL Returned: 4.4 - OA 520 760 - 770 770 Interval REQVAR P/F P V Notes: Tested Per A1O 2C.032 V SCAMMED AUG 3 0 2017, Thursday,June 15,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 15,2016 TO: Jim Regg l P.I.Supervisor 1-47/r/1�l �l 1�(�1P SUBJECT: Mechanical Integrity Tests /" CONOCOPHILLIPS ALASKA INC 30-07 FROM: Guy Cook KUPARUK RIV UNIT 30-07 Petroleum Inspector Src: Inspector Reviewed BJ.1 � P.I.Supry`J U"- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-07 API Well Number 50-029-21840-00-00 Inspector Name: Guy Cook Permit Number: 188-077-0 Inspection Date: 3/14/2016 Insp Num: mitGDC160314134056 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-07 - Type Inj W TVD 6502 - Tubing 1900 - 1900- 1900 - 1900 PTD 1880770 Type Test SPT Test psi 1626 - IA 965 3300 - 3225 - 3210 - Interval OTHER " P/F P ✓' OA 460 560 - 560 - 560 - Notes: Test for an AA prep for water injection. 3.5 bbls of diesel were pumped for testing. SCANNED SEP 2 6 2016 Tuesday,March 15,2016 Page I of I S • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, March 11, 2016 3:30 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: KRU 30-07 (PTD 188-077) Update Attachments: 30-07 90 day TIO 3-11-16.JPG Chris, 30-07 (PTD 188-077) is coming to the end of the 30 day water injection monitor period. The well has exhibited no signs of TxIA communication and it is CPAI's intention to apply for an AA to allow for water injection only. In order to remain in compliance and to align the MITIA test date of 30-07 to the UIC MIT permanent 4 year scheduled pad testing (July 2017)for 30 pad CPAI has requested a witnessed MITIA to be performed on 3/14/16. Once the witnessed MITIA is complete the 10-426 will be attached to the AA application and sent in. The well will be left online for the MITIA and while the AA is being processed. Attached is a 90 day TIO plot. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager (907) 659-7000 pgr. 123 SCANNED APR 0 a 2016 ittWELLS TEAM ConocoPhillips From: NSK Problem Well Supv Sent: Monday, January 26, 2015 3:16 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Kuparuk injector 30-07 (PTD 188-077) 30 Day gas monitor period results Chris- Kuparuk injector 30-07 (PTD#188-077)was Bing monitored for a 30 day gas injection trial period. The IA continues to show a pressure increase while on gas injection so the well was shut in and freeze protected earlier today. Because the well passed initial diagnostic tests of an MIT-IA, IA draw d i n test and tubing and inner casing pack off tests it is suspected that the TxIA communication being observed is a sma only leak. Due to the water injection line being de- rated CPAI intends to leave the well shut in until a well line upgrade has en completed. At that point in time the well will be brought on water injection for a 30 day monitor period with intent to ue an AA for water injection only due to TxIA communication while injecting gas. Please let us know if you have any questi s or disagree with the plan. Attached are a wellbore schematic and a 90 day T/I/0 plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. 1 W • o7 a ca Ec y w a U _ !1J G W Q cc M Ct. T L"' p al 0 W 0 a L 8 y w m y G W O cc u Or r 0 W N co Pcu rn J J 9 0 LP LP - iia J _ '011. al, c.) c co CO by 11-0 RS O OSV C 3 co C t c en U c, < vi a> 7 EL C Z C a ul0 I's C'S s O N p N Y Mti NM C d r r- =a Q S I I u, x y 55�� �{ Dc 112 n o CD o o . o 0 oz I § § Y § b § .§ § # °' z Cl w ow o W a , w ad le hi0Y1 t+ y .1 •1 , r, N 1',1 a, as0c Isd N O w Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, January 26, 2015 3:16 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Kuparuk injector 30-07 (PTD 188-077) 30 Day gas monitor period results Attachments: image001.png; 30-07.pdf; 30-07 90 Day TIO plot.JPG Chris- Kuparuk injector 30-07 (PTD#188-077) was being monitored for a 30 day gas injection trial period. The IA continues to show a pressure increase while on gas injection so the well was shut in and freeze protected earlier today. Because the well passed initial diagnostic tests of an MIT-IA, IA draw down test and tubing and inner casing pack off tests it is suspected that the TxIA communication being observed is a small gas only leak. Due to the water injection line being de- rated CPAI intends to leave the well shut in until a well line upgrade has been completed. At that point in time the well will be brought on water injection for a 30 day monitor period with intent to pursue an AA for water injection only due to TxIA communication while injecting gas. Please let us know if you have any questions or disagree with the plan. Attached are a wellbore schematic and a 90 day T/I/0 plot. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) .J 943-0450y WELLS TEAM SCANNED JAN '2 .Luo omocoPb imps From: NSK Problem Well Supv Se • Friday, December 26, 2014 4:35 PM To: Walla • Chris D (DOA) Cc: Senden, R. ' er; NSK Problem Well Supv Subject: RE: Kupar ' jector 30-07 (PTD 188-077) report of IA pressure increase Chris- Kuparuk injector 30-07 (PTD# 188-0 was originally reported for an unexplained IA pressure increase. The initial diagnostics,consisting of an MIT-IA, IA dr. down test, and tubing and inner casing pack off tests, all passed. The well was left shut in with a differential pressure be -en the tubing and IA. The IA has shown no substantial pressure increase since the pressure differential was establis -d. It is CPAI's intention to bring the well back online for a 30 day gas injection period. At this point in time a well line upg ..e is scheduled during the 2nd quarter of 2015 on the water injection line. Therefore, if at any point during the 30 day gas 'Vection period tubing by inner annulus communication is confirmed the well will be shut in and freeze protected. Please let now if you have any questions or you disagree with this plan. Attached are a well bore schematic, 90 day T/I/0 plot and a test form from the dia:Bostic testing performed. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 1 W • z4- Z Z C7 C7 C7 C7 m WWW W Q L L Z Z a Z Z Z Z O O O O 14.1 O CD CC) CD CC (D CN T Cll. o a '', a p in O O O O W O I.- O O 0,1 CC Cfl ,I. CC) r Ea N O O O O W O CO (C7 (D d N e") ('i N li 1- el H (I) kr) ,'S C O O O O W 5.7.4. N CV N m C) ((C) - CCi H r N r T- r r CI J M1 1• 1• 1` ..I O O O O T 0000 f`-1 (y.l (V) 01 S o o o ��0P < o N o its I I I I I* .: __7 .,I I 1 I I 'AO in a ° 41) V IIIIea 7 it •I• 'V cp C 0 Ca C.) u 7.50 0 '_ 11. G Q I O U ...."‹. ,:ii ..„ cso C Z C a 41. O o r r ti O o00 � � € fin M N N a r a U. I CD I d LI 1 N Q Q V V c.t ZC Ca 0 c 0 0 0 0 o 0 o 0 0 oU7 rn Y N V1 ' M 0 N N - - ad le won 7NRI C 0 W iSd a • KU P 30-07 ConocoPhillips 0t, Well Attributes Max Angle&MD TD Aleskts.I: Wellbore API/UWI Field Name Well Status Incl CI MD(ftKB) Act Btm(ftKB) t.orncoi4ellips 500292184000 KUPARUK RIVER UNIT INJ 41.62 4,000.00 8,148.0 Comment H2O(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date WSII Confw:-30A7.8/14201°732:53 AM SSSV:TRDP Last WO: 3/2/1990 33.98 7/27/1988 _-_- Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 7,831.0 8/10/2008 I Rev Reason:FORMAT UPDATE 9.0 I Imosbor 18/142010 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 11 155555.33 -- CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED '.; Casing Description String 0... String ID...Top(ftKB) Sot Depth(L..Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 95/8 8.921 35.0 4,556.8 4,105.7 36.00 J-55 BTC -`, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.151 35.0 8,128.3 6,928.9 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING(QC) 2 7/8 2.441 I 33.0 I 7,668.5 I 6,559.3 6.50 J- 55 EUEABMOD I Completion Details Top Depth (THD) Top Incl Nomi... Top(ftKB) (ftKB) C) Item Description Comment ID(in) CONDUCTOR. _ j 33.0 33.0 0.77 HANGER CIW GEN I HANGER 2.875 1° 1,812.5 1,812.3 -0.86 SAFETY VLV OTIS FMX SAFETY VALVE 2.313 7,581.7 6,490.0 37.15 LOCATOR AVA LOCATOR w/11.56'SEALS STABBED INTO ORGINIAL 2.441 ICOMPLETION PBR SAFETY VLV, 17,583.0 6,491.0 37.14 PBR AVA PBR 2.374 1.812 7,597.1 6,502.3 37.08 PACKER AVA RHS RETRIEVABLE PACKER 2.374 7,633.9 6,531.7 36.93 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,668.0• 6,559.0 36.78 SOS AVA BALL SEAT SHEAR OUT SUB.***TTL ELMD 7647'w/SWS 2.441 IPROF 10202006"' GAS LIFT. IR Other In Hole I ireline retrievable plugs,valves,pumps,fish,etc.) 9,110 Top Depth i IND) Top Incl Top(ftKB) (ftKB) C) Description Comment Run Date ID lin)_ 7,877 6,726.7 36.50 FISH 1 1/2"GLV Left in Rathole 3/5/1990 3/5/1990 Perforations&Slots Shot J Top(TVD) Btln(TVD) Dorm Top(kK8) Bkn(kK8) MB) (ftKB) Zona Date (sh--- Type Comment SURFACE, 7,748• 7,758• 6,623.1 6,631.2 G1,30-07 330/1990 12.0 APERF 60 deg.ph;21/8"Dyna Strip 354,557 7,810 7,822 6,672.9 6,682.5 A-3,30-07 3/30/1990 12.0 APERF 60 deg.ph;2 1/8"Dyna Strip ille GAS UFT, 7,832 7,856 6,690.6 6,709.9 A-2,30-07 3/30/1990 12.0 APERF 60 deg.ph;21/8"Dyna Strip 5,423 7,872 7,892 6,722.7 6,738.8 A-1,30-07 9/23/1988 8.0 IPERF 45 deg.phasing;4.5"HSD Csg Gun Cement Squeezes GAS LIFT,_ Top Depth Btm Depth 9,691 (TVD) ITVD) Top(ftKB)Bim(ftKB) (ftKB) (ftKB) Description _Start Date _ Comment 7,748.0 7,758,0 6,623.1 6,631.2 Cement Squeeze 8/27/2006 SQUEEZED C SAND PERFS FROM 7748'TO 7758'. TOTAL OF 23 BBLS BEHIND PIPE.3000 PSI GAS LIFT, = SQUEEZE PRESSURE FOR ONE HOUR.JETTED 7.530 t1 OUT EXCESS CEMENT TO 6778' Notes:General&Safety End Date Annotation LOCA'O5R,82 10/20/2006 NOTE:!PROF SHOWED RESTRICTIONS TO 2.5"ID @7715'&7777'-DUE TO CEMENT SQUEEZE? 7/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR,7,583 PACKER,7,597 I NIPPLE,7,634 , II SOS.7,8158 APERF, 7,748-7,758 CEMENT SQUEEZE, - - 7,748 APERF, 7,810.7,822 PERF, _ • 7,83A2-7.856 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Sia TRO Run Stn Top(ftKB) MKS) (°) Make Model (in) fiery Type Type lin) (psl) Run Date Com... a) 1 3,115.5 3,007.7 41.52 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1992 FISH,7,877 -- { 2 5,422.8 4,801.5 38.05 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1992 IPERF, 7,8727.892 3 6,691.0 5,787.7 38.54 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1992 4 7,539.3 6,456.3 37.33 MERLA TGPD 1 12 GAS LIFT DMY RK 0.000 0.0 1/9/1992 PRODUCTION. 35-8,128 5 a ' TD,8,148 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. I ~(~- ~ q r'/ Well History File Identifier organization (done> RESCAN DIGITAL DATA X Color items: [] Diskettes, No. n Grayscale items: [] Other, No/Type [] Poor Quality Originals: Other: TOTAL PAGES: l~)~ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps:. rn Other items scannable by large scanner .OVERSIZED (Non-Scannable) [3 Logs of various kinds Other DATE: Isl Project Proofing .[3 By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl Scanned (done) PAGES: (0~· (at the time of scanning)~ SCANNED BY: BEVERLY BREN ~IN~;ENT)SHERYL MARIA LOWELL RESCANNED BY: ~REN VINCENT SHERYL MARIA LOWELL General Notes or Comments abOut this file: Quality Checked (done) RevlNOTScanned.wpd • MEMORANDUM To: Jim Regg ~ P.L Supervisor ~~~,5~ ']~Z-Z ~~~ C FROM: Chuck Scheve Petroteum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July Ol, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-07 KUPARUK RIV UNIT 30-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: RL Suprv ~.1~'/'~-- Comm Well Name: KUPARUK RIV LJNIT 30-07 Insp Num: mitCS090626190348 Rel Insp Num: API Well Number: 50-029-21840-00-00 Permit Number: 188-077-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/26/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wejl 3O-~~ Type Inj. G 'j'~ 6502 jA 450 2440 2350 2350 P.T.D 1880770 TypeTest SPT TQSt pSl 1625.5 QA 60 60 60 60 Interval 4~TST P~` P ~ Tubing 3675 3675 3675 3675 NOtes: Pretest pressures observed and found stable . ~. A. ~< , ir~~ t~ +~r~(Yt~ '. .. ~~~;. k. a.; u ~. _, I`v ~.".. Wednesday, July O1, 2009 Page 1 of 1 • ~. ~~~ ~ a ~ ~ ~ Alaska P,O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501. ~~ NC1~ ~ ~ 20D~ • ~~.o°fT Dear Mr. Maunder: Enclosed please find a spreadsheet.with.a Gist 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 a corrosion inhibitor, engineered to prevent water from entering the annular space.. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on October 19, 2007 and the corrosion inhibitor/sealant was pumped on October 28, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~ ~ i r' ~°"~. Perry Ike ConocoPhillips Well Integrity Projects Supervisor Aa~cl~~ar ,~~; • • Surface Casing by C®nduct®r Annulus Cement, C®~r®si®n inhibit®r, Sealant T®p-®ff Report of Sundry Operations (10-404J Date Kuparuk Field 10/28/2007 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 3©-7 188-077 26' 42 t0" 10/19!2007 3 10{28/2007 30-17 188-029 49'8" 7 16" 10/1912007 5 10/28/2007 1D-11 199-072 4'1" n/a 4'1" n/a 16.5 10/28/2007 1. Operations Performed: . . RECEIVED STATE OF ALASKA NOV 2 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TION8sl<a Oil & Gas Cons. Commission Other nc Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Opera!. ShutdownD Plug Perforations 0 Stimulate 0 Waiver 0 Time Extension o o Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 58' Re-enter Suspended Well 5. Permit to Drill Number: 188-077 I 6. API Number: 50-029-21840-00 Exploratory Service D o 9. Well Name and Number: 30-07 8. Property Designation: ADL 25513 11. Present Well Condition Summary: Total Depth Effective Depth Casiñg Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool measured 8148' feet true vertical 6945' feet measured 8031' feet true vertical 6851' feet Length Size MD 110' 16" 110' 4499' 9-5/8" 4557' 8070' 7" 8128' Plugs (measured) Junk (measured) TVD Burst Collapser .110' 4106' 6929' .' Measured depth: 7748' - 7892' '¡(. . .~. "t.;. ..)~;t~ ~!::sf..::L true vertical depth: 6623' - 6739' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7668' MD. Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 7597' SSSV= SSSV SSSV= 1812' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 2175 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oilD GasD WAG 0 ,GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if c.o. Exempt: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 1576 1230 250 Casin Pressure Tubin Pressure 2263 3716 Daily Report of Well Operations_X Contact WDSPL 0 Printed Name Signature Production Engineering Technician Date II/z.r/()t 1 3 2006 If. '5,,~ Submi~ilìal Only ./ ~/[ r.?/f//Cl.ft:7 Title Phone 659-7535 Form 1 0-404 Revised 04/2004 . 30-07 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 11/19/06 Commenced Water Alternating Gas (WAG) Injection / -'~-~i:";o ~~.~,- ..~."".>;."-'-"",,,,"-"-- - Ç) 11/10/06 Sc~lIIRblPgep NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV 1 3 Z006 G~ C'.QfI¡:;, QjffimissiOO ^\1çOO~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UT ~ 1~1J -()'9-? Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K,28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kr27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . Gary Eller Wells Group Engineer Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phooe;ËëË\'J£O St.? 2 "1 l\j\JS . Comm\SSIOI\ .\ &. Gas COI\S. Mas\!.a 0\ r.,l\c\\Ofage September 26, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 30-07 (APD # 188-077) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation on the Kuparuk well 30-07. If you have any questions regarding this matter, please contact me at 263-4172. ~CANNEÆ) SfP 2 ~ 2006 -. --""--"-'-' JGE/skad A..._L Ion 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 - Stimulate 0 Other au Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 188-077 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21840-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 58' 30-07 8. Property Designation: 10. Field/Pool(s): ADL 25513 ' Kuparuk River Field 1 Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 8148' , feet true vertical 6945' . feet Plugs (measured) Effective Depth measured 7872' feet Junk (measured) 7877' true vertical 6723' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 4499' 9-5/8" 4557' 4106' PROD. CASING 8070' 7" 8128' 6929' Perforation depth: Measured depth: 7748'-7758' (sqz'd), 7810'-7822', 7832'-7856', 7872'-7892' true vertical depth: 6623'-6631',6673'-6683',6691'-6710',6723'-6739' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7668' MD. Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 7597' Otis 'FMX' SSSV= 1812' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7748'-7758' RBDMS 8Ft SEP 2 8 2006 Treatment descriptions including volumes used and final pressure: 23 bbls behind pipe 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation SI . Subsequent to operation na na 1654 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0' Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ0' WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact ~~r@~ 3-4172 Printed Name ry Eller ~~ Title Wells Group Engineer ~ \G\o \ ()~ Signature Phone Date '-.....l ,)..k \. ( ,.. Prenared bv Sharon AI/sun-Drake 263-4612 Form 10-404 Revised 04/20~ ~ ~ 9·z,?,O' Submit riginal On' t<~CE/VED SEP 2 7 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & G REPORT OF SUNDRY WELL OPERATIONS as Cons. Commiss' . STATE OF ALASKA . OR\G\NAL 6% A ~;k ~ SSSV (1812-1813, 00:2.875) Gas Lift landreVOummy Valve 1 (3115-3116, 00:4.750) Gas Lift landreVOummy Valve 2 (5423-5424, 00:4.750) Gas Lift landreVOummy Valve 3 (6691-6692, 00:4.750) Gas Lift landreVOummy Valve 4 (7539-7540, 00:5.460) PBR (7583-7584, 00:2.875) PKR (7597-7598, 00:6.151) ConocoPhllllps ~laska. Inc. 1- NIP (7634-7635, 00:2.875) TUBING (0-7668, 00:2.875, 10:2.441) TTL (7668-7669, 00:2.875) Perf I I - f--- (7810-7822) - f--- = Þ= Perf - f--- (7832-7856) - f--- - f--- - r---- - f--- - f--- 11/2'GLV - ~ r---- (7877-7880, - f--- 00:1.500) - f--- Perf - f--- (7872-7892) - f--- - r---- - f--- - r---- - f--- . 30-07 KRU = API: 500292184000 Well TVPe: INJ SSSV TVDe: TRDP Oria Completion: 7/27/1988 Annular Fluid: LastW/O: 3/2/1990 Reference Loa: Ref Loa Date: Last Taa: 7872' RKB TD: 8148 ftKB . . DescriDtion Size TOD Bottom TVD Wt Grade PROD. CASING 7.000 0 8128 6929 26.00 J-55 CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 4557 4106 36.00 J-55 Tubina Strina - TUBING Size I TOD I Bottom I TVD I Wt I Grade I Thread 2.875 I 0 I 7668 I 6559 I 6.50 I J-55 I EUE AB MOD Perforations SummarY = Interval TVD Zone Status Ft SPF Date Tv De Comment 7748 - 7758 6623 - 6631 C-1 C 10 0 8/27/2006 Saz 7810 - 7822 6673 - 6683 A-3 12 12 3/30/1990 APERF 7832 - 7856 6691 - 6710 A-2 24 12 3/30/1990 APERF 7872 - 7892 6723 - 6739 A-1 20 8 9/23/1988 ¡PERF 30..07 AnQle (1j¡ TS: 37 deQ (1j¡ 7724 Anole @ TD: 36 deo @ 8148 Rev Reason: PERF SQUEEZE Last Update: 9/26/2006 Thread Stimulations & Treatments Interval Date TVDe 7748 - 7758 8/27/2006 CEMENT SQUEEZE 60 dea. ph' 2 1/8" Dvna Strip 60 dee. ph' 2 1/8" Dyna Strip 45 deg. phasing: 4.5" HSD Csg Gun Comment SQUEEZED C SAND PERFS FROM 7748' TO 7758'. TOTAL OF 23 BBLS BEHIND PIPE. 3000 PSI SQUEEZE PRESSURE FOR ONE HOUR. JETTED OUT EXCESS CEMENT TO 6778'. V Type V OD Latch Port TRO Date Run Vlv Cmnt Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 1 3115 3007 MMH FMHO 2 5423 4802 MMH FMHO 3 6691 5788 MMH FMHO 4 7539 6456 Merla TGPD Other pluas, eQuip., etc.) - COMPLETION DeDth TVD TVDe 1812 1812 SSSV 7583 6491 PBR 7597 6502 PKR 7634 6532 NIP 7668 6559 SOS 7668 6559 TTL Fish - FISH DeDth I 7877 11 1/2" GLV DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.5 RK 0.000 0 DescriDtion 1/9/1992 1/9/1992 1/9/1992 1/9/1992 ID 2.313 2.374 2.374 2.250 2.441 2.441 Otis 'FMX' AVA AVA'RHS' Cameo 'D' Nipple NO GO AVA I I Left in Rathole 3/5/1990 Comment DescriDtion Well History (2 year) 30-07 5.2184000 Date 08/29/2006 08/28/2006 08/27/2006 08/24/2006 08/23/2006 08/23/2006 08/20/2006 08/16/2006 08/13/2006 CoI1oc6Phillips Well History (2 year) 30-07: 500292184000 : 9/14/2006 Page 1 of 1 . Event TAGGED FILL @ 7872' RKB (EST. 20' OF FILL). OBTAINED SAMPLE OF WHAT APPEARS TO BE FRAC / FORMATION SAND. JOB COMPLETE. MILLED 3' CEMENT AT 7784' WITH 5 3/4" UNDERREAMER. CLEANED SAND TO HARD TAG @ 7870' CTMD WITH SSW AND BIO SWEEPS. BETTER THAN 1:1 RETURNS. SQUEEZED C SAND PERFS FROM 7748' TO 7758'. TOTAL OF 23 BBLS BEHIND PIPE. 3000 PSI SQUEEZE PRESSURE FOR ONE HOUR. JETTED OUT EXCESS CEMENT TO 6778'. UNABLE TO JET THROUGH TO SAND PLUG. SHUT DOWN FOR NIGHT WITH 2000 PSI LEFT ON WELL. DUMP BAILED SLUGGITS @ 7760' SLM. DRIFTED TBG WITH 2.02" CENT, TAGGED @ 7786' RKB. DRIFTED TBG WITH 1.75" SAMPLE BAILER. TAGGED SAND TOP @ 7793' RKB. DUMP BAILED SLUGGITS @ 7770' SLM. IN PROGRESS. FULLBORE SAND PLUG, 800 LBS. SAND. FP WELL WITH 20 BBLS DIESEL. TAGGED FIRM SAND TOP @ 7819' RKB. TOOLS DRAGGED THRU APPARENT HEAVY FLUID OR SLURRY TO 7787' RKB. TAGGED SAND TOP @7816' RKB, EST. 21' BELOW TARGET WINDOW. Pumped Full Bore Sand Plug using 2200 lbs of #20/40 silica sand. Estimate top of sand plug @ 7785' RKB fully covering the A sand perfs. Freeze protected the tubing with diesel down to 2500' RKB. Well is to remain shut in for further well work. 9 records retrieved for Well History (2 year) http://biz.ak, ppCO .com/webbert/W ell/Report/rpt Well T able,aspx?REPO R T=., %2f.. %2fU ser.,. 9/14/2006 · , RECEIVED e STATE OF ALASKA e 2 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION JUN REPORT OF SUNDRY WELL OPERA TIOM:i\a Oil & Gas Cons. COfMlÎssion 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 OtherAncho~e Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill NUl)1ber: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 188-0771 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21840-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 58' 30-07 8. Property Designation: Kuparuk River Unit ¡Aþt, ¡.;Ç/3 ~.~.,. fÞv 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth measured 8148' 6945' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size MD TVD Burst Collapse 7" 110' 4557' 8128' 110' 4499' 8070' 16" 9-5/8" '·_i Perforation depth: Measured depth: 7748-7758,7810-7822,7832-7856,7872-7892 true vertical depth: 6623-6631,6673-6683,6691-6710,6723-6739 Tubing (size, grade, and measured depth) 2-7/8", J-55, 7668' MD. Packers & SSSV (type & measured depth) pkr= AVA 'RHS' pkr= 7597' SSSV= SSSV SSSV= 1812' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A NA NA Subsequent to operation N/A N/A N/A NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG0' GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Printed Name Signature Marie McConnell / Perry Klein Marie McConnell .. ... U::;~.. .... Title /1 . œ~~ .. Phone Y' ;-7"::/ ~..... -- .. o R \ G \ N A L; Problem Well Supervisor 659-7224 6/25/2006 Form 10-404 Revised 04/2004 .Þ ,.~.o'"' SU:~ig7iW~ e 30-07 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 6/3/2006IsET 2.25" C-A2 BLANKING @ 7634' RKB 6/23/2006 BH seal weld - N2 purge. T/I/O=O/O/O. Rigged up N2 purge across lA, OA, and conductor for 3 pass BH seal weld and cooper heat. Final T/I/O=O/O/O. 6/24/2006IMITOA passed (post BH seal weld). See attached form. 6/25/2006 Pulled C-A2 Blanking @ 7634' RKB. MECHANICAL 4trEGRITY TEST (MIT) FORM e WELL NO.: 130-07 I DATE: 16-24-06 ISWI I i,e,: Prod, ProdNL, MI, SWI, PWI MIT TEST TYPE: IMITOA I i.e., Tbg, IA 19-5/8", OA 113-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel . .~ WELL TYPE: Record all Wellhead P T START TIME: 111 00 E S T ressures before and durina Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** 000 0 000 0 o 1800 1740 1730 TUBING IA OA 1 Post Bradenhead weld MITOA T START TIME: E S TUBING T IA OA 2 COMMENTS: T START TIME: E S TUBING T IA OA 3 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** PASS OR FAIL PASS PASS OR FAIL PASS OR FAIL r'SC COMMENTS * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: 10. Sauvageau 1 B. Rogers cc: PWS I 6/3/00 MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '0 " P.I. Supervisor /",,;'f/I 11' -;J;. ¡ '''',/ tt !..".-/! I,,) :',.:..) DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA mc 30-07 KUPARUK RIV UNIT 30-07 FROM: John Crisp Petroleum Inspector Src: Inspector l %ß'" ó17 Reviewed By: P.l. Suprv,~TBf2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-07 Insp N urn: mitJCr060613131823 Rei Insp Num API Well Number 50-029-21840-00-00 Permit Number: 188-077-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well"i 30-07 ¡Type Inj.1 N I ~VD._L~~02 J'-~-'! _ ~_l.,,1960 ¡---;S9õ-f18'7-or'-=-"---¡--=--= P.T. 11880770 ITypeTest I SPT I Test psi I 1625,5 i OA I 20 ¡ 30 ! 30 I 30 I 'I -Ï~;~-;:I 4YRTST '_p;-'_~-;---O'_"___' TUbingi--ö.-rO.-¡--....O..--lo---i- -------- _n______ .__.________ ..__..__,__....._..,____.._---L___...__...~.,_. _L___,__...._ Notes 6.5 bbl's pumped for test. Short term shut in for braiden head weld, SSV & SSSV was pumped open for test. Tubing was on vacuum. Tubing tail plug set for wellhead repair. SCANNED JUN 2 7 2006 Wednesday, June 14,2006 Page I of 1 Schlumbergep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /fl:C41 2U-12 ß::J 122. 2B-02 /;1'3 -67130-07 1~.i-OJ¿2V-15 2oif_OC;,¡1E-112 "'<"J b if 2P-427 ,t..ú... 4 , I 0 10942844 10922542 10922549 10922543 10922552 10922545 SIGNED: Log Description PROD PROFILE/DEFT PROD PROFILE/DEFT INJECTION PROFILE PROD PROFILE/DEFT INJECTION PROFILE SCMT ~ý{P fJ 5- Date 02/15105 02/26/05 03/05105 02/27/05 03/08/05 03/01/05 "" ~. <" P. r~) On r: SCA,NNEG p.. pn 1 0 L I U~¡ Ig~-077 6·o~f)1 03/15/05 NO. 3365 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ BL Color CD 1 1 1 1 1 1 .-- .// í ~-;x;~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: June 28, 2002 THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests PAl 3O multiple KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 30-05 I Typelnj.[ G I T.V.D, I 6514 I Tubing[ 3750 I 3750 I 3750 I 3750 I lntervall 4 P.T.D.J 1880760 JTypetestI P ITestpsiJ 1629 J CasingJ 1425 I 2080 I 2040I2040 J p/F I --P Notes: 'WellI 30-06 Type lnj.I G I T.V.D, 16415 I Tubing 13675 13675 13675 13675I,nte va, I4 P.T.D.I 1880600 Type testI P I TestpsiI 1604 I Casingl 2600 I 3000 I 2980 I 2980 I" P/F I -P Notes: WellI 30-07 I Typelnj. I S I T.~/.D. I 6502 I Tubingl 1500 I 1500 I 1500 J 1500 J lntervalJ 4 P.T.D.I 1880770 Type testI P I Testpsil 1626 ICasingI 950 I 2250 I 2240 I 2240 I P/F I P Notes: Well[ 30-10 I Typelnj. I G I T.V.D. I 6360 I Tubing I 3000 I 3600 I 3600 I 3600 I lntervall 4 P.T.D.I 1880590 Type testI P I Testpsil 1590 I Casingl 2550 I 3000 I 2980 I 2970 I P/F I P Notes: WellJ 30-12 I Typelnj. J (3 I T.V:D. J 6404 J Tubing I 3650 I 3650 I 3650 I 3650 I lntervalJ 4 P.T.D.I 1880410 ITypetestl P ITestpsil 1601 I Casingl 760 1205012050120001 P/FI P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 1 of 2 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 5 Attachments: none Number of Failures: 0 Total Time during tests: 4 hrs cc: none MIT report form 5/12/00 L.G. mit(l) kru 3o 6-28-02js.xls 7/16/2002 ~"~ STATE OF ALASKA .... Oh ALASKA OIL AND GAS CONSERVATION CZ31VlMk.~SION / ?"//~ REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate /V./~ Alter casin~'-; ~ Repair. well Oth"-~r X '~'~' 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory _ Stratigraphic Service .~. 4. Location of well at surface 854' FNL, 1917' FWL, SEC.22, T13N, R9E, UM 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-07 feet At top of productive interval 1187' FSL, 747' FEL, SEC.15, T13N, At effective depth 1316' FSL, 601' FEL, SEC.15, T13N, At total depth 1357' FSL~ 556' FELr SEC.15r T13N~ 12. Present well condition summary Total Depth: measured true vertical R9E, UM R9E, UM R9E~ UM 81 4 8' feet 6944' feet Plugs (measured) 9. Permit number/approval number S8-77 / 10. APl number 50-029-2184000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8045' feet Junk (measured) 6861 ' feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 4522' 1 6" 9-5/8" 8093' 7" Cemented Measured depth True vertical depth 211 SXAS I 110' 110' 1100 SX AS III & 4557' 4106' 350 SX CLASS G - TOP JOB 85 SX AS 1 200 SX CLASS G & 8128' 6928' 175 SX AS I measured 7748'-7758', 7810'-7822', 7832'-7856' 7872'-7892' 8 SPF true vertical 6622'-6630', 6672'-6681', 6689'-6709' 6722'-6739 Tubing (size, grade, and measured depth) 2-7/8" J-55 @ 7668' Packers and SSSV (type and measured depth) AVA 'RHS' PKR @ 7597', OTIS 'FMX' SSSV @ 1812' Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL Intervals treated (measured) 12 SPF Alaska Oil & Gas Cons. Anch0ra.qe 14. Treatment description including volumes used and final pressure Representative Daily Averaae Production or Iniection Data -- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1102 483 0 2730 155 Subsec]uent to operation 0 0 3260 1851 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector _X 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 09/12/90 Title Petroleum Engineer Date 3/~/? ~ SUBMIT IN DUPLIC,~TE APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _X_ Pull tubing _ Variance _ 2. Name of Operator 5. Type of Well: Development X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 854' FNL, 1917' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1187' FSL, 747' FEL, Sec. 15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec. 15, T13N, R9E, UM At total depth 1357' FSL~ 556' FELr Sec. 15~ T13N~ R9Er UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured 8 0 4 5' true vertical 6 8 61 ' Casing Length Size Structural Conductor 8 0' 1 6" Surface 4 5 2 2' 9 5/8" Intermediate Production 8 0 9 3' 7" Liner Perforation depth: measured Operation Shutdown _ Re-enter suspended well_ Plugging _ Time extension_ Stimulate . Perforate _ Other 8148' feet Plugs (measured) 6944' feet None 6. Datum elevation (DF or KB) RKB 59 7. Unit or Property name Kuparuk River Unit feet 7748'-7758, 7872'-7892' true vertical 6622'-6630', 6672'-6681', 6722'-6739' Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 7668' Packers and SSSV (type and measured depth) AVA 'RHS' pkr (~) 7597', Otis 'FMX' SSSV ~ 1812' Attachments Description summary of proposal _~. feet Junk (measured) feet None Cemented 8. Well number 30-07 9. Permit number 88-77 10. APl number 50-029-21 840 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 211 SxASl 110' 1100 Sx AS III & 4557' 350 Sx Class G - TOP JOB 85 sx AS I 200 Sx Class G & 81 2 8' 175 Sx AS I Measured depth True vertical depth 110' 4106' 6928' 7810'-7822', 7832'-7856' 12 SPF 8 SPF 13. Convert well from oil producer to water injector. 14. Estimated date for commencing operation December 23. 1991 16. If 9,roposal w~ verbe~lly approved Name of approver Date approved 6689'-6709', RECEIVED Alaska 0il & 6as Cons. Commissioo Anchorape Detailed operation program_ BOP sketch -- 15. Status of well classification as: Oil Gas Suspended Service Water Iniector 17. I hereby certify that the foregoing Si~ned C'..(.AJo ~ is true and correct to the best of my knowledge. Title Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ B_OP Test_ Location clearance__ Mechanical Integrity TestX Subsequent form require Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL S!GNED BY LONNIE c. SMITH IApproval 10-~o~,,~d CoPY J ~;~/ ._No~_f.__- Commissioner Date /~ '~,3'-?/ SUBMIT IN TRIPLICATE Well 30-07 Conversion to Water Injection ARCO Alaska requests approval to convert Well 30-07 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7700' and 7940'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. KUPARUK WELL 30-07 APl #: 500292184000 SPUD DATE: 07/20/88 ADL LEASE: 25513 PERMIT #: 88-77 COMPLETION DATE: 09/23/88 WORKOVER DATE: 03/03/90 ORIGINAL RKB: SURFACE LOCATION: 854'FNL, 1917'FWL, SECPP,T13N,R9E TOP OF KUPARUK: 1187'FSL,747'FEL,SEC15,T13N,RgE TD LOCATION: 1357'FSL,556'FEL,SEC15,T13N,RgE Ail deplhs are MD-RKB to top of equipment unless othen~ noted 58 TUBING SPOOL: 33 PAD ELEVATION: WELLTYPE: PRODUCER CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5~ H-40 110 9.625" 36# J-55 4557 7' 26# J-55 8128 2.875' 6.5~ J-55 ABM 7668 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV OTIS FMX 2.313' 1812 · SBR AVA PBR 7583 PKR AVA RHS 7597 NOGO CAMCO 'D' NIPPLE 2.25' 7634 SHROUT AVA 7667 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 41 HOLE ANGLE THRU KUP: 36 LAST TAG DATE: 03/05/90 RATHOLE: -15 FISH/OBSTRUCTION: PBTO: PBTDSS: DEPTH 2ooo 7877 7877 1-1/2' GL'V 8031 6378 :,:.:.:.:,:,:.;.:.:,;+;+:.:.:.;.:.:.;,:,:,:.:.;+;.;+:,:.:.: ,:+:.:.:.:.;.:.:,:.:.:+:,;.;.:,;.;.:.:,:.:.:.:.:.;.:.:.:.;.;.:. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,:,:.:.:.:.;.;.:.:,:.;,:,:.;.;,:.:.;.:.;.:,:,:.:.;.:.:.:,:.:.:,;.:. ...,.....,.........,...,...v.....v.............,...,.v...,.,. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 24 / L GAS UFT and FLOW INFORMATION VALVE STN DEPTH MANDREL 1 3116 MCMURRY 2 5423 MCMURRY 3 6691 MCMURRY ~11 4 7539 MERLA TGPD PERFORATION DATA SIZE 1' 1' 1' 1.5" PORT SIZE 0.1875 0.1875 0.25 0.3125 INTERVAL ZONE FT SPF PHASE 7748-7758 C 10 12 30 7810-7822 A3 12 12 60V 7832-7856 A2. 24 12 60V 7872-7892 A1 20 8 45 COMMENTS HLS 2.15" TT HLS 2.15" TT HLS 2.15' TT SOS 4.5' CSG REVISION DATE: 04/20/90 REASON: ARCO Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 20, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. W E L L ACTION 30-07 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /\1{;~1~ ~/)(/;~ C Pull tubing __ Alter casing __ Repair well ~;" Name of Operator ~ 5. Type of Well: DevelOpment ~; ARCO Alaska. Iris, Exploratory _ 3. Address Stratigraphic _ P..: O. Box 100360, An, chorage, AK 99510 Service , _ 4. Location of well at surface 854' FNL, 1917' FWL, Sec. 22, T13N, RgE, UM At top of productive interval 1187' FSL, 747' FEL, Sec. 15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec. 15, T13N, R9E, UM At total depth 1357' FSL, 556' FEL, Sec. 15, T13N, RgE, UM At"-"vA, OILAND GAS CONSERVATION COMP' 'ION REPON i' OF SUNDRY WELL OPEI-[ATIONS' Type of Request: Operation Shutdown '.._ Stimulate _ Plugging __ Perforate Pull tubing ~ Other _ 6. Datum elevation (DF or KB) 59' RKB feet 7. Unit or Property name 12. Present well condition summary Total Depth: measured 81 48' feet true vertical 6944' feet Ku,paruk River Unit 8. Well number 30-7 9. Permit number/approval number 88-77/90-147 10. APl number 50-029-21840 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 8045' feet true vertical 6861' feet Junk (measured) Casing Length Size Structural 8 0' 1 6" Conductor Surface 4522' 9- 5/8" Intermediate Production 8093' 7" Liner Cemented Measured depth 211 SxAS II 110' 1100 Sx AS III & 4557' 350 sx Class G- Top job w/85 sx AS I 200 Sx Class G & 8128' 175 Sx AS I True vertical depth 110' 4106' 6928' 13. Perforation depth: measured 7872'-7892', true vertical 6722'-6739', 7832'-7856', 6691'-6710', Tubing (size, grade, and measured depth) 2 7/8" J-55, tbg w/ tail @ 7668' Packers and SSSV (type and measured depth) · AVA 'RHS' Pkr @ 7597', Otis 'FMX' $SSV @ 1812' Stimulation or cement squeeze summar 7810-7822', 6673-6683', 7748-7758' APR 5 1990 Intervals treated (measured) Prior to well operation (producing) Subsequent to operation (producing) 15. Attachments Copies of Logs and Surveys run _ Treatment descriptiOn including volumes used and final pressure 14. Re0resentative Dai!v Averaoe Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 634 135 -0- 1 150 956 385 -0- 1 150 16. Status of well classification as: Water Injector Daily Report of Well Operations X Oil x Gas Suspended _ Service 17. I herelpy certify.that t~e/~,i~g is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE Tubing Pressur, 115 115 ARCO Alaska, inc--,~ · Subsidiary of Atlantic ~ichfietcl Compar,, : ~EL..~ O '7 PBDT JFIELD-DISTRICT-STATE -.b.',-~c-,-o,=, 18 08 ~AUJ~O~7"cZ/4 ~9'0¢,,~/~...~/'~VtCz.¢' /If, ~-F.7.~. IOPERATION AT REPORT TIME WELL SERVICE REPORT REMARKS tDAYS DATE ~ ~ i S l3e /eo .... · ' so ~74~ 1-3 78~o 78zz ~ A z .7~3z-3~ a~ 951990 ~ CHHCK TH{S BLOCK {~ SUMMARY CONT{NUHD ON BACK w..,,.,~l,.-,.,_ .~ c-~.-Iv,.,~,,,,,.~ ,..Iw-v.'. ! D: KRU,'% I./NU/DR ~ LL I NG ,. · , , ! ,I V!CINITY MAP Al.I. WELLS lOCATED IN SEC, 82 T. !$ N., R. 9 E., UMIAT MERIDIAN. NOTE:$ I, N.[ COORDINATES ARE A,$.P., ZONE 4. 2. Al./. DISTANCES ~HOWN ARE TRUE. 3. ELEVATIONS &RE B.P.M.~.L. 4. REFER. FIELD IKX)K 5. O.G. ELEVATIONS FROM CED-RIXX-$365& 6. HORIZONTAl,. I~O~ITION BASED ON ~:100N'/'ROf. MONUMENTS PF,.R I,,OUN~IIURY ........................ o,s~, DIST. "am '-P~-' Well Y AsPs,, , X LATITUDE LONGITUDE: FNL ,EYRE £1ev. ~lev_ I 6,02 2,095.27 585,478.27 ?Oe28' 17.$38" 149° 47' $0.$97" 724' 1842' 17,5' 2;~,9' 2 6,022,075. 89 525,490.94 70028. 17.126" 149° 47 '$0.526'' 745' 1855' t7.71 3 6,022,052.1~ 525,~.67 ~' 1691~". . 149°47~30.1~ 76Y 1667' t?.9 4 6,022,030, ~ 525,515.5a ~2a* I~ 149°47, Z9.8~. 18~ 1879~ 18.0~ 2~7', 5 6,02Z,~8,~ 525~528.38 7~8: " 149°47,29.4~. 81 I, 1898, 18. I l&Z~. 149e47, ~,071. 83Z, 19~; 18. I', ? 6,021 ~965. ~ .5~5,55~.~ !~9 14¢47 28,6~. ~; 1~17, lC.Z, 2~1 I49 47,~8.~. ~ 6,0~1 ~. I~ 5~ ~57e. Z7 15,632 149° 47 27,974 ~gT 1941 18.4 I0 6,08 t ,84~ ~ 525,683.6l ~28' 14.~3" 149°47'26.6~'' 975' t986' 18.?' 11 6,021,822.~ 525,6~5,71 ~' 14.651" 1490 4T'Z6.295" ~7' ~98' tm.o' la 6,02I ,8~.87 525,668.~ 7~28', 14.4~7" 149°4T',~.9~ 10~9' 201/' 18.8' i3 6,OZl ~779. t6 525 766t ,20 ~e~, 14. Z~3'" 149°47 25.5~, 1041'. Z024', la.9', ~.0, 14 6,0ZI ,~7. ~ 5Z5,6~.~ ~o~, 14.010 '~ ' 149~47',85,~,, t0~ 80~, 19.0; 88.8, 15 6,021,735.76 525,~6.12 ~O~ IS.~5 149 47 24,8~ 108~ 2048, 19.0, ~.~, 16 6~021~?14. 15 525,6~. 17 ~e28' 13.~$" 149e47'~4.4~" ll~ 20~, 19.1 17 6,0ZI ~69~ 525,710.85 ~* 13, S69" 149o47' Z4.0~' 112~ 2073 19.0' 18 6,02 1,670.97 525 ~7~,~ ~25' t3. 157" 149047'23,7~3" 1149' 2085' 19.0' 23.5' Alaska Inc D.S. 3.0 WELL coNDUCTOR ~:BUILT UNSBURY 6 sociates RAGE ............ ..I ~ASKA .. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well X Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 854' FNL, 1917' FEL, Sec. 22, T13N, R9E, UM At top of productive interval 1187' FSL, 747' FEL, Sec. 15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec. 15, T13N, R9E, UM At total depth 1357' FSL, 556' FEL, Sec. 15, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8148' 6944' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 59' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-7 9. Permit number/approval number 88-77/90-015 10. APl number 5o-029-21840 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8045' true vertical 6861 ' feet Junk (measured) feet Casing Length Size Structural 8 0' 1 6" Conductor Surface 4 5 2 2 9 - 5 / 8" Intermediate Production 8 0 9 3' 7" Liner Perforation depth: measured 7872'-7892' true vertical 6722'-6739' Cemented Measured depth 211 Sx AS II 110°md 1100 sx AS III & 4557'md 350 sx Class G- Top job w/85 Sx AS I 200 sx Class G & 81 28'md 175 sx AS I Tubing (size, grade, and measured depth) 2-7/8 .... , J-55 tbg W/ tail @ 7668' Packers and SSSV (type and measured depth) AVA 'RHS' Pkr @ 7597', Otis 'FMX' SSSV @ 1812' True vertical depth 11 0'tvd 41 06'tvd 6928'tvd 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ..X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 05/17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO O,, rind Gas Company Well History - Initial Report - Daily Inet~'uctlons: Prepare and submit the "Initial RIIN~rV' on the first Wednesday after a well is spudded or workover operations are starled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough ARCO ALASKA INC. I NORTH SLOPE BOROUGH Field Lease or Unit KOPARUK I ADL: 25650 Auth. or W.O. no. ITitle AK4621 I WORKOVER A~State KRU 30-7 IWell no. Operator ARCO Spudded or W.O. begun IDate IHour W.O. I 2/28/90 F0:00 Date and depth as of 8:00 a.m. 03/01/90 ( TD: 0 PB: 8045 SUPV:DB 03/02/90 ( TD: 0 PB: 8045 SUPV:DB Complete record for each day reporied NORDIC ~1 IARCO W.I. 55.0000 Prior status if a W.O. SET BPV, ND TREE 7"@ 8128' MW: 8.5 SW PULL BPV. RU HARDLINE TO TANK AND FLOWLINE. BLED GAS OFF TBG TO FLOWLINE. PUMP 54 BBL SEAWATER DOWN TBG. PRESSURED UP TO 3500 PSI WHEN SW HIT FORMATION SHUTDOWN PUMP AND LOST 200 PSI IN 10 MIN. OPENED ANNULUS TO FLOWLINE AND CIRC SYSTEM VOLUME THRU OPEN GLM AT 7540'. OVERDISPLACED 50 BBLS AND SI WELL. FREEZE PROTECT FLOWLINE WITH 30 BBL DIESEL. MONITOR WELL, NO PRESSURE. SET BPV. DAILY:S32,761 CUM:$32,761 ETD:SO EFC:$192,761 STAB SEALS ONTO PBR 7"@ 8128' MW: 8.5 SW ND TREE, NU BOPE, PULL BPV. TEST BOPS. BOLDS, PULL HGR, HGR DAMAGED AND SENT IN FOR REDRESS, REPLACE WITH NEW HGR. CIRC BU AND POOH WITH 2-7/8" COMP ASSY. BOTTOM 7 JTS OF TBG REPLACED DUE TO BUCKLING, THE BOTTOM JT JUST ABOVE THE AVA SEAL UNIT WAS SEVERELY BUCKLED AND THE OTHER 6 JTS ONLY SLIGHTLY BUCKLED. RIH WITH COMP ASSY INCL 7 NEW JTS AND NEW GLMS AND SSSV. TEST SSSV CONTROL LINE TO 5000 PSI OK. STAB ONTO AVA PBR @ 7583' AND PREP FOR SPACE OUT @ 0600. DAILY:S34,378 CUM:$67,139 ETD:SO EFC:$227,139 The above la, correct see Prooedures MaChOtel. Section 10, Drilling. Pages 86 and 87. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO ,land Gas Company Daily Well History-Final Report Instructions: Prepare and submit the ',Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and represelltative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ARCO ALASKA INC. AK State Field KUPARUK Count~Qr Parish NORTH SLOPE BOROUGH IL .... ~bZn!t 25 650 ITitle WORKOVER KRU 30-7 Well no. Auth. or w.,~:~o621 Operator ARCO Spudded OW .Wd~; begun Date and depth as of 8:00 a.m. 03/03/90 ( TD: 0 PB: 8045 SUPV:DB Old TO Released rig A'"'~sW. 6000 Date 2/28/90 Completel~)c~If~- e~.h day reported Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well O~%: 00 IPrlor status if a W.O. I RIG RELEASED 2000 3/2/90 7"@ 8128' MW: 8.0 DIESEL LAND TBG, SPACE OUT, MU TBG HGR, TEST CONTROL LINE, RELAND TBG, RILDS, RU SLICKLINE, SET SV IN D NIPPLE, TEST TBG TO 2500 PSI, TEST ANNULUS TO 2500 PSI, TEST SSSV, RIH W/SLICKLINE, PULL SV, RD SLICKLINE, SET BPV, ND BOPE, NU TREE, TEST PACKOFF TO 5000 PSI, PULL BPV, SET TP, TEST TREE TO 5000 PSI, OPEN SSSV, PULL TP, REVERSE CIRC. WELL TO DIESEL, SET BPV, RELEASE RIG DAILY:S62,624 CUM:$129,763 ETD:SO EFC:$289,763 New TD PB Depth Date Kind of r g Type completion (single, dual, etc.) Officia reservoir name(s) Classifications (oil, gas, etc.) Producing method Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII 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 Signature Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no, DlvlNon of AtlsntlcRIchfleldCompany ^...o"^ o,. co ,ss,o. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS [~ SUSPENDED I---] ABANDONED F'-I SERVICE [--"1 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-77 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21840 4 Location of well at surface 9 Unit or Lease Name 854' FNL, 1917' FWL, SEC 22, T13N, RgE UM ....... ~ ~ LC~'~; ?!'~'~:'~ ~ KUPARUK RIVER UNIT AtTop Producing Interval ~'~' ~;~: i' I Vt~;~I~F~'~ .l 10 Well Number At Total Depth -!~/.-./~. 11 Field and Pool 1357' FSL, 556' FEL, SEC 15, T13N, RgE UM ....... ~ ..... -~'"'~;~'~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 59' ADL: 25513 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions JULY20 1988 JULY25 1988 ~I NA feet USLI' 1 , 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 8148' MD & 6944' TVD 8031' MD & 6849' TVD YES [~ NO ~']I 1812' feet MDI 1700' (approximate) 22 Type Electric or Other Logs Run . DIL,SFL,GR,CAL,SP,FDC,CN L, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 110' 24" 211 SX AS III 95/8" 36# J-55 SURF 4557' 12-1/4" 1100 SX AS III & 350 SX CLASS G 7" 26# J-55 SURF 8128' 8-1/2" 200 SX CLASS G & 175 SX AS 1 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) 7872'-7892' MD, 4-1/2" W/8 SPF 6722' - 6739' TVD 2-7/8", J-55 7668' 7597' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7872'- 7892' 45,727 lbs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD FIowTubing 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. RECEIVED 16 1990 *FIRST COMPLETED 9/23/88, RE-COMPLETED 3/2/90 I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . !. ~ ~ ~,~. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 7718' 6598' NA BO'I-i'OM KUPARUK C 7761' 6633' TOP KUPARUK A 7797' 6662' BOTTOM KUPARUK A 7934' 6772' , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P~r~ ,.~~ Title /1~ ~:),,.~ ,~,~,/ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 pedinent 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 ADDENDUM WELL 30-7 5/14/89 Frac Kuparuk "A" sand perfs 7872'-7892' in seven stages as follows. Stage Stage Stage Stage Stage Stage Stage 1: Pmp 150 bbls Gel water @ 20 bpm 5228-5500 psi 2: Pmp 445 bbls Gel water pad @ 20 bpm 5830-5570 psi 2A: Pmp 305 bbls Gel Water pad @ 20 bpm 6100-5550 psi 3:44 bbls Gel Water w/.1-2 ppg 16/20 Carbolite. @ 20.5 bbm 5640-5583 psi 4:57 bbls Gel Water w/2-4 ppg 16/20 Carbolite @ 19.5 bpm 5583-6312 psi 5:58 bbls Gel Water w/4-6 ppg 16/20 Carbolite @ 16.5 bpm 6312-5966 psi 6 75 bbls Gel Water w/6-8 ppg 16/20 Carbolite @ 16 bpm 5966-6446 psi Stage 7 84 bbls Gel Water w/8-10 ppg 16/20 Carbolite @ 16 bpm 6293-7731 psi Screen out w/approx 13 bbls 10 ppg in perfs leaving approx 52 bbls 10 ppg in tbg. All fluid BJRXL-4 Gel Water w/5% Diesel - Breakdown and pad contained 40 ppt Silica flour & 8 hr break. Fluid to recover: 1600 bbls Sand in zone: 45727 lbs Sand in csg: 14798 lbs Avg pressure: 5800 psi Drilling ~upervisor Date Reservoir Fluid Study ARCO OIL AND GAS COMPANY 30-7 Well Kuparuk Field North Slope, Alaska RFL 890010 Western Atlas International A Litton/Dresser Company CORE LABORATORIES January 27, 1989 ARCO Oil and Gas Company 2300 W. Plano Parkway PRC E-407 Plano, TX 75075 Attention' Mr. Jerry Haley Subject- Reservoir Fluid Study 30-7 Well Kuparuk Field North Slope, Alaska RFL 890010 Gentlemen' A subsurface sample was collected from the subject well and submitted to our laboratory in Irving, Texas for use in a reservoir fluid study. The results of this study are presented on the following pages. Thank you for the opportunity to perform this study for ARCO Oil and Gas Company. Should any questions arise or if we may be of further service in any way, please do not hesitate to contact us. Sincerely, ames R. Fortner Area Manager Reservoir Fluid Analysis JRF:DK'vlw 17 cc' Addressee 1300 East Rochelle Boulevard, Irving, Texas 75062-3963, P.O. Box 152053, Irving, Texas 75015-2053, (214) 541-2673, (800) 248-CORE Western Atlas International A Litton/Dresser Company CORE LABORATORIES LABORATORY PROCEDURES ARCO Oil and Gas Company Reservoir Fluid Study 30-7 Well Kuparuk Field North Slope, Alaska RFL 890010 The composition of the reservoir fluid was determined through hexanes with a heptanes plus residual fraction by low temperature fractional distillation, along with gas chromatography. An extended analysis was then performed on the heptanes plus fraction by capillary chromatography. The results, in terms of both mole percent and weight percent, are presented on pages three through five. A small quantity of the reservoir fluid was charged to a high pressure windowed cell and thermally expanded to the reservoir temperature of 161°F. During a constant composition expansion at this temperature, the fluid was found to have a bubblepoint pressure at 2314 psig. When subjected to differential pressure depletion at the reservoir temperature, the fluid evolved a total of 340 cubic feet of gas at 14.65 psia and 60°F per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.188 barrels of saturated fluid per barrel of residual oil at 60°F. The viscosity of the reservoir fluid was measured over a wide range of pressures at 161°F in a rolling ball viscosimeter. The viscosity of the fluid was found to vary from a minimum of 3.29 centipoises at the saturation pressure to a maximum of 11.38 centipoises at atmospheric pressure. Three separator tests, (one on the original reservoir fluid and two on DV prepared oils) were performed at specified conditions. The results of these separator tests are tabulated on pages 13 through 15. The data from the reservoir fluid separator test were then used in conjunction with the data from the pressure-volume relations and differential vaporization tests to calculate the solution gas/oil ratio and oil formation volume factor data that will be necessary to perform material balance calculation under primary pressure depletion. These combination flash- differential data are presented on page 16; the formulae used to derive the data are given on page 17. Western Atlas International A Litton/Dresser Company Company Well Field CORE k 'BORATORIES ARCO Oil and Gas Company 30-7 Kuparuk File RFL 890010 County North Slope State Alaska TABLE OF CONTENTS Laboratory Procedures Table of Contents Well Information Summary of Reservoir Fluid Data Reservoir Fluid Composition Pressure-Volume Relations Compressibility Differential Vaporization Viscosity Separator Tests Adjusted Differential Vaporization Data Nomenclature and Equations Paqe i ii 1 2 3-5 6 7 8-10 11-12 13-15 16 17 ii The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made The nterpretations or opinions expressed represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. Page File Well I of 17 RFL 890010 30-7 WELL INFORPIATION FORMATION CHARACTERISTICS Formation Datum Date First Well Completed Original Reservoir Pressure Original Produced Gas/Liquid Ratio Production Rate Separator Conditions Stock Tank Liquid Gravity ft ss ,psig @ ft scf/bbl B/D psig and~° F °API@ 60°F Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Reservoir Conditions: Pressure Date Temperature Status of Well Water Cut WELL CHARACTERISTICS ft ft ft in. to ft B/D/psi @ B/D psig @ ft 161 °F @ ft percent Depth Sampled Status of Well Tubing Pressure Bottomhol e Pressure Sampl ed By Date Sampl ed SAMPLING CONDITIONS ft psig psig @ ft Page. 2 of File RFL 890010 Well 30-7 17 SUMMARY OF RESERVOIR FLUID DATA Vol umetric Data - Bubblepoint pressure (Pb) = 2314 psig at 161°F Thermal expansion at 5000 psig = V at 161°F = 1.04194 V at 70 °F Differential Vaporization.(DV) Data Solution gas/oil ratio {Rsdb) at bubblepoint 340 standard cubic feet of gas per barrel of residual oil at 60°~ Relative oil volume (Bodb) at bubblepoint = 1.188 barrels of oil per barrel of residual oil at 60°F Density of reservoir fluid at bubblepoint : 0.8176 gm/cc Viscosity Data Viscosity of reservoir fluid at bubblepoint = 3.29 centipoises Separator Test Data Separator Conditions 250 psig at 150°F to 0 psig at 180°F Bofb(1) Rsfb(2) Tank Oil Gravity, °API at 60°F 1.187 336 22.5 Standard conditions = 14.65 psia and 60°F (1) Formation volume factor, barrels of oil at bubblepoint per barrel of stock tank oil at 60°F. {2) Solution gas/oil ratio at bubblepoint, total standard cubic feet of gas per barrel of stock tank oil at 60°F. Page 3 of File RFL 890010 Well 30-7 17 Cylinder Number 454030 Component RESERVOIR FLUID COMPOSITION Mole Weight Molecular Percent Percent Wei_qht(1) Hydrogen Sulfide 0.00 0.00 Carbon Dioxide 0.63 0.16 Nitrogen 0.23 0.04 Methane 36.24 3.42 Ethane 2.79 0.49 Propane 2.25 0.58 iso-Butane 0.70 0.24 n-Butane 1.34 0.46 iso-Pentane 0.54 0.23 n-Pentane 0.85 0.36 Hexanes 1.66 0.82 Heptanes plus 52.77 93.20 100.00 100.00 34.080 44.010 28.013 16.043 30.070 44.097 58.123 58.123 72.150 72.150 84 300(2) Density, gm/cc at 60°F(1) 0.80064 0.81720 0.80860 0.29970 0.35584 0.50648 0.56231 0.58343 0.62408 0.63049 0.685 0.9243(2) Sample Molecular Weight = 169.88 (1) Assigned properties taken from literature. (2) Measured properties adjusted for CG_ found analyzed by capillary chromatograph. in low temperature distillation residue as Page 4 of File RFL 890010 Wel 1 30- 7 HEPTANES PLUS FRACTION Mole Weight Component Percent Percent Heptanes 3.96 1.27 Octanes 6.33 2.26 Nonanes 5.89 2.38 Decanes 5.79 2.59 Undecanes 5.30 2.60 Dodecanes 5.00 2.69 Tridecanes 5.39 3.15 Tetradecanes 4.63 2.94 Pentadecanes 4.39 3.02 Hexadecanes 4.65 3.45 Heptadecanes 3.37 2.67 Octadecanes 3.50 2.93 Nonadecanes 3.21 2.82 Eicosanes 2.77 2.54 Heneicosanes 2.51 2.44 Docosanes 2.26 2.30 Tricosanes 2.03 2.16 Tetracosanes 1.77 1.96 Pentacosanes 1.68 1.94 Hexacosanes 1.47 1.76 Heptacosanes 1.27 1.58 Octacosanes 1.17 1.52 Nonacosanes 1.14 1.53 Triacontanes 1.07 1.48 Hentriacontanes 0.79 1.14 Dotriacontanes 0.81 1.20 Tritriacontanes 0.68 1.04 Tetratriacontanes 0.63 1.00 Pentatriacontanes 0.54 0.87 Hexatriacontanes plus 16.00 38.77 100.00 100.00 Molecular Weiqht¢l) 96 107 121 134 147 161 175 190 206 222 237 251 263 275 291 305 318 331 345 359 374 388 402 416 430 444 458 472 486 726.12(2) Densi at Calculated mole wt. = 300 gm/mol Calculated density = 0.9243 gm/cc @ 60°F Heptanes plus Undecanes pl us Pentadecanes pl us Eicosanes plus Hexatriacontanes plus 100. O0 100. O0 78.03 91.50 57.71 80.12 38.59 65.23 16.00 38.77 300 351 416 506 726 (1) Assigned properties taken from literature. {2) Calculated by material balance. 17 ty, gm/cc 60°F(1) 0.722 0.745 0.764 0.778 0.789 0.800 0.811 0.822 0.832 0.839 0.847 0.852 0.857 0.862 0.867 0.872 0.877 0.881 0.885 0.889 0.893 0.896 0.899 0.902 0.906 0.909 0.912 0.914 0.917 1.096(2) 0.9243 0.9438 0.9672 1.0003 1.0956 Page 5 of File RFL 890010 Wel 1 30- 7 LOW TEMPERATURE DISTILLATION RESIDUE FRACTION 17 Component Mole Weight Molecular Density, gm/cc Percent Percent Wei_qht(ll at 60°F(~) N-Butane 0.10 0.02 58.12 Iso-Pentane 0.12 0.03 72.15 N-Pentane 0.12 0.03 72.15 Hexanes 0.78 0.22 84 Heptanes 3.93 1.27 96 Octanes 6.25 2.25 107 Nonanes 5.82 2.37 121 Decanes 5.72 2.58 134 Undecanes 5.23 2.59 147 Dodecanes 4.94 2.68 161 Tridecanes 5.33 3.14 175 Tetradecanes 4.58 2.93 190 Pentadecanes 4.34 3.01 206 Hexadecanes 4.60 3.44 222 Heptadecanes 3.33 2.66 237 Octadecanes 3.47 2.93 251 Nonadecanes 3.17 2.81 263 Eicosanes 2.74 2.54 275 Heneicosanes 2.48 2.43 291 Docosanes 2.24 2.30 305 Tricosanes 2.02 2.16 318 Tetracosanes 1.75 1.95 331 Pentacosanes 1.66 1.93 345 Hexacosanes 1.45 1.75 359 Heptacosanes 1.25 1.57 374 Octacosanes 1.16 1.52 388 Nonacosanes 1.13 1.53 402 Triacontanes 1.06 1.48 416 Hentriacontanes 0.79 1.14 430 Dotriacontanes 0.80 1.20 444 Tritriacones 0.67 1.04 458 Tetratriacontanes 0.63 1.00 472 Pentatriacontanes 0.53 0.87 486 Hexatriacontanes plus 15.81 38.63 726.12(2) 100.00 Benzene (wt %) : Trace Measured mole wt. : 297 gm/mole Measured density = 0.9232 (1) Asigned properties taken from literature. (2) Calculated by material balance. 100.00 0.583 0.624 O.63O O. 685 0.722 0.745 0.764 0.778 O. 789 0.800 0.811 0.822 0.832 0.839 0.847 0.852 0.857 0.862 0.867 0.872 0.877 0.881 0.885 0.889 0.893 0.896 0.899 0.902 0.906 0.909 0.912 0.914 0.917 1.096(2) Page 6 of File RFL 890010 Well 30-7 17 PRESSURE-VOLUME RELATIONS AT 161'F (Constant Composition Expansion) Pressure, Relative Y Density, psi q Vol ume(1) Functi onl2) qm/cc 5000 0.9818 4500 0.9848 4000 0.9879 3500 0.9912 3000 0.9947 2800 0.9961 2700 0.9968 2600 0.9976 2500 0.9984 2400 0.9993 2314 Pb 1.0000 2293 1.0020 2275 1.0037 2253 1.0059 2152 1.0165 1979 1.0382 4.394 1719 1.0818 4.195 1453 1.1473 3.983 1174 1.2553 3.756 922 1.4182 3.552 738 1.6150 3.403 642 1.7656 3.324 445 2.2850 3.162 334 2.8480 3.070 222 3.9661 2.976 Thermal expansion at 5000 psig = V @ 161°F = 1.04194 V @ 70°F (1) Volume at indicated pressure per volume at bubblepoint. (2) Y Function : (Pb - P)/[(Pabs)(RV - 1)]. 0.8328 0.8302 0.8276 0.8249 0.8220 0.8208 O.8202 0.8196 0.8189 0.8182 0.8176 Page 7 of File RFL 890010 We 11 30- 7 17 COIqPRESSIBILITY M 161'F From 5000 psig to 4500 psig : 6.09 x 10-6 V/V/psi From 4500 psig to 4000 psig = 6.32 x 10-6 V/V/psi From 4000 psig to 3500 psig = 6.59 x 10-6 V/V/psi From 3500 psig to 3000 psig : 6.97 x 10-6 V/V/psi From 3000 psig to 2314 psig = 7.79 x 10-6 V/V/psi Page 8 of File .......... RFL 800010 Well . 30-7 17 DIFFERENTIAL VAPORIZATION AT 16]'F Solution Pressure, Gas/Oil psig Ratio, Rsd(1) 2314 Pb 340 2050 305 1800 274 1550 239 1300 205 1050 171 800 136 550 102 300 64 0 0 Rel at i ve Oi 1 Devi at ion Oil Volume, Density, Factor Bod(2) gm/cc Z 1.188 0.8176 1.176 0.8221 0.856 1.164 0.8266 0.862 1.152 0.8311 0.870 1.140 0.8357 0.880 1.128 0.8406 0.893 1.115 0.8456 0.908 1.103 0.8508 0.927 1.089 0.8564 0.952 1.042 0.8814 @ 60°F : 1.000 @ 60°F : 0.9182 Gas Formation Vo 1 ume Factor(3) 0.00725 0.00831 0.00973 0.01171 0.01467 0.01949 0.02870 0.05288 Incremental Gas Gravity 0.641 0.639 0.638 0.638 0.639 0.642 0.656 O.694 1.013 Gravity of residual oil = 22.5 °API@ 60°F Standard conditions = 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of residual oil at 60°F. (2) Barrels of oil at indicated pressure per barrel of residual oil at 60°F. (3) Cubic feet of gas at indicated pressure per standard cubic foot. Page 9 of t7 File RM- 8900i0 Well 30-7 500 SOLUTION GAS/OIL RATIO DURING DIFFERENTIAL VAPORIZATION 450 400 35O 30o 250 zoo 5O 0 0 500 iO00 1500 2000 2500 3000 PRESSURE, PSIG 1,30 I. 25 i. 10 i.O0 RELATIVE OIL VOLUME DURING DIFFERENTIAL VAPORIZATION 0 500 lO00 i500 2000 2500 3000 PRESSURE, PSIG Page 11 of File RFL 890010 Well 30-7 17 VISCOSII~' Al 161'F Pressure, psi§ 5000 4500 4000 3500 3000 2500 2314 Pb 2050 1800 1550 1300 1050 800 550 300 0 Oil Viscosity, centipoise 4.41 4.20 3.99 3.78 3.57 3.36 3.29 3.61 3.92 4.25 4.62 5.06 5.57 6.27 7.13 11.38 Calculated Gas Viscosity, centipoise 0.0170 0.0162 0.0155 0.0148 0.0142 0.0137 0.0132 0.0127 Oil/Gas Viscosity Ratio 212.4 242.O 274.2 312.2 356.3 .406.6 475.0 561.4 Page i2 of File RFL 8900i0 WeZl 30-7 i2.0 iO. 0 8,0 4,0 0 VISCOSITY OF RESERVOIR FLUID LEGEND 1000 2000 3000 4000 5000 PRESSURE, PSIG Page 13 of File RFL 890010 Well 30-7 17 Separator Conditions psig °F 250 150 to 0 180 SEPARATOR TEST - RESERVOIR FLUID Stock Tank Formation Liquid Volume Separator Gas/Liquid Ratio Gravity, Factor Volume Gas (1) (2) °API at 60°F Bofb(3) Factor(4) Gravity 257 276 1.073 0.640 57 60 22.5 1.187 1.050 1.162 Rsfb = 336 Standard conditions : 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. (2) Standard cubic feet of gas per barrel of stock tank liquid at 60°F. (3) Barrels of liquid at bubblepoint per barrel of stock tank liquid at 60°F. (4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at 60°F. Page 14 of File RFL 890010 Well 30-7 17 Separator Conditions psig °F 250 150 to 0 180 SEPARATOR TEST - 2000 PSIG DV OIL Stock Tank Formation Liquid Volume Separator Gas/Liquid Ratio Gravity, Factor Volume Gas (1) (2) °API at 60°F Bofb(3) Factor(4) Gravity 229 245 1.075 0.641 60 63 22.4 1.177 1.050 1.181 Rsfb = 308 Standard conditions : ]4.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. (2) Standard cubic feet of gas per barrel of stock tank liquid at B0°F. {3) Barrels of liquid at bubblepoint {2000 psig} per barrel of stock tank liquid at 60°F. {4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at 60°F. Page 15 of File RFL 890010 Well 30-7 17 Separator Conditions psig °F SEPARATOR TEST - !000 PSIG DV OIL Stock Tank Formation Liquid Volume Separator Gas/Liquid Ratio Gravity, Factor Volume Gas (1) (2) °API at 60°F Bofb(3) Factor(4) Gravity 250 150 99 107 1.078 0.652 to 0 180 63 66 22.4 1. 130 1.050 1. 199 Rsfb : 173 Standard conditions : 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. {2) Standard cubic feet of gas per barrel of stock tank liquid at 60°F. {3} Barrels of liquid at bubblepoint {1000 psig} per barrel of stock tank liquid at 60°F. (4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at 60°F. Page 16 of 17 File RFL 890010 Wel 1 30- 7 DIFFERENTIAL VAPORIZATION AT 161°F ADJUSTED TO SEPARATOR CONDITIONS Formati on Gas Gas/Oil Volume Oil Formation Oil/Gas Pressure, Ratio, Factor, Density, Volume Viscosity psi g Rs (1) Bo(2) gm/cc Factor(3) Rat i o 5000 336 1.165 0.8328 4500 336 1.169 0.8302 4000 336 1.173 0.8276 3500 336 1.177 0.8249 3000 336 1.181 0.8220 2800 336 1.182 0.8208 2600 336 1.184 0.8196 2314 Pb 336 1.187 0.8176 2050 301 1.175 0.8221 0.00725 1800 270 1.163 0.8266 0.00831 1550 235 1.151 0.8311 0.00973 1300 201 1.139 0.8357 0.01171 1050 167 1.127 0.8406 0.01467 800 132 1.114 0.8456 0.01949 550 98 1.102 0.8508 0.02870 300 60 1.088 0.8564 0.05288 0 0.8814 212.4 242.0 274.2 312.2 356.3 406.6 475.0 561.4 Separator Conditions: Primary Separator 250 psig at 150°F Stock Tank 0 psig at 180°F Standard conditions : 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of stock tank liquid at 60°F. (2) Barrels of oil per barrel of stock tank liquid at 60°F. (3) Cubic feet of gas at indicated pressure per standard cubic foot. Page 17 of File RFL 890010 17 Well 30-7 Symbol s Bo Bod Bodb Bofb Bt Btd Pres Pb Rs Rsd Rsdb Rsfb RV NOMENCLATURE AND EQUATIONS Barrels at reservoir conditions per barrel of stock tank oil. Relative oil volume from differential vaporization test. Bod at bubblepoint pressure. Formation volume factor from separator test. Total (two-phase) formation volume factor. Total formation volume factor from differential vaporization test. Reservoir pressure. Bubblepoint pressure. Standard cubic feet of gas per barrel of stock tank oil. Solution gas/oil ratio from differential vaporization test. Rsd at bubblepoint pressure. Sum of separator and stock tank gas/oil ratios from separator test. Relative volume from pressure-volume test. Equations For Bo at and above the bubblepoint pressure: Bo = (RV)(Bofb) For Bo below the bubblepoint pressure: Bo = (Bod)(Bofb/Bodb) For Rs: Rs : Rsfb - [(Rsdb - Rsd)(Bofb/Bodb)] For Bt: Bt : (Btd) (Bofb/Bodb) OR Ii A L August 18, 1988 Mr. Randy Ruedrich ARCO AlaSka, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80079 Well: 3-o-7 Field: Kuparuk Survey Date: August 2, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you~for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry. Sun/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA 3-0-7 KUPARLIK ALA._KA I NC:. SF'ERRY-:_:;UN WELL SURVEyIN~ ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, · ~,~,~ COMPUTATION DATE ALIGLIST 5, 1" '-"~' ~o,:. ._lOB NUMBER AK-BO-80079 KELLY BUSHING ELEV. - ='=' 00 FT VERTICAL SECTION ,-:ALCLIL~'TED-"'ALONG CLf"ISLIRE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN 0 0.00 -58.00 0 0 100 100.00 42.00 0 45 200 199.99 141.99 0 43 300 299.98 241.98 0 39 400 399.97 341.97 0 37 500 499.97 441.97 0 33 600 599.96 541.96 0 34 700 699.96 641.96 0 37 800 799.95 741.95 0 41 900 899.94 841.94 0 42 1000 999.94 941.94 0 37 1100 1099.93 1041.93 0 42 1200 1199.92 1141.92 0 45 1300 1299.91 1241.91 0 44 1400 1399.91 1341.91 0 31 1500 1499.90 1441.90 0 32 1600 1599.90 1541.90 0 36 1700 1699.89 1641.89 0 30 1800 1799.89 1741.89 0 43 1900 1899.87 1841.87 I 7 1950 1949.85 1891.85 2 15 2000 1999.78 1941.78 3 47 2050 2049.61 1991.61 5 23 2100 2099.30 2041.30 7 18 2150 2148.79 2090.79 8 55 2200 2198.07 2140.07 10 28 2250 2247.11 2189.11 12 0 2300 2295.82 2237.82 13 55 2350 2344.16 2286.16 15 40 2400 2392.11 2334.11 17 10 L:OLIR.=,E DOG-LEG D I REIE:T I ON SEVER I TY DEGREES DEG/1 O0 0. 0 E 0.00 41.50 E 0.75 40.89 E 0.03 47.39 E 0.11 ='-' /-,':~ E 0 08 ,_1 ..=l, _ oo . 81. :30 E 0.45 75.1':..? E 0.07 75.19 E ~ 0.07 58.50 E 0.20 65. 0 E 0.08 65.30 E 0.08 46.69 E 0, 23 4'B'?. 19E 0.06 51.60 E 0.04 67.39 E 68. 69 E 73. OE TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST o: Oo o. GO 0.49o'" 0.43 E 1 46 S 1 '="- ,:..:,S '=' 12 E m .~:.. - 3. ]'-~' '.~ 97 E (..:, S ~-. 3.28 S . :~_, 88 E ~ 4.84 E Z.~:I S 5. -'= - - ~,_, E 2.:~6 '" ... 6,90 E 1.78 S 7.97 E 1.29 S 9.0:3 E 0.22 N 10..93 E 1.05 N 11..93 E . C)_. 27 ...... 1~ 6='~. bi ............ 1~.:~ .E. 0.03 1..97 N 13.7:3 E 0.08 2.30 N 14.68 E VERTICAL SECT I C" O. O0 0.04 O, ~0 0.22 0.46 2.86 5.16 6.30 8,72 10.02 12. ( 12. N 73.'3';' E o. 1i 2 58 N N 67.80 E 0.24 2.95 N N 60.80 N 54.39 N 47.19 N 47.50 N 50.89 N 54.19 N 56.60 N 59.19 N 59.30 N 58.80 N 57.89 E E E 3.17 E 3.22 E ........... ~,_~;9 .. 16.61 E 0.41 3.66 N 18.06 E . ~, :_'? ................ 4.47__.~ ........ 1.9.28 E . . 6.17 N 21.29 E 8.88 N 24.24 E ...... 1 ~ .4.8.._N ............ 2F~..4.4._ E E 3.37 16.75 N 34.06 E E 3.20 21.53 N 41.00 E E ........... ~,20 26,.69 N ........ 49,26 E E 3,86 32.42 N 58..90 E E 3.51 39.00 N 69,86 E E 3.04 46.4~ N .... ~1.~,? E.. , ~() - L,~6~___ E .............. 1~ '-._~ ...... 14.87 16.45 17._?1 . 20.54 24.54 . .~0.. 06 37.12 45.53 ~. 21 66.33 79. O1 '?~: · 06 ARCO ALA. KA, INC 3-0-7 KLIF'ARUK ALASKA SPERRY-.=.UN WELL ._~LRVEYING COMPANY PAGE ~... ANL. HuRAb E ALASKA DATE OF SURVEY AUGLI.ST L-:OMF'UTAT I ON DATE ~C!$~...OYR...C!S_'C_:L:LFLI_ ~Cj__S_!-J~V_~Y__ ................... -' °-' 17.%c, ._lOB NUMBER AK-BL-I-80079 A U o LI._-, T 5 · '- '-' '~-' KELLY BUSHING ELEV. = ='-' ;_,o. 00 FT. FIPERATOR-MCGU I RE vERTICAL SECTION C:ALc:UL~TE£i"ALoNG CLOSURE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN 2450 2439.66 2381.66 18 49 2500 2486.71 2428.71 20 43 2600 2579.17 2521.17 24 1 2650 2624.49 2566.49 25 53 2700 2669.05 2611.05 28 2 2750 2712.86 2654.86 29 3:4 2800 2755.96 2697.96 31 19 2850 2798.22 2740.22 33 13 2900 2839.53 2781.53 35 19 2950 2879.93 2821.93 36 51 3000 2919.45 2861.45 38 41 3050 2958.01 2900.01 40 21 3100 2995.83 2937.83 41 19 3150 3033.36 2975.36 41 25 3200 3070.89 3012.89 41 17 3250 3108.47 3050.47 41 14 3300 3146.07 3088.07 41 13 3350 3183.66 3125.66 41 17 3400 3221.20 3163.20 41 23 3500 3296.46 3238.46 40 58 3600 3371.83 3313.83 41 11 3700 3446.~4 3388.94 41 25 3800 3521.88 3463.88 41 30 3900 3596.78 3538.78 41 29 4000 3671.61 3613.61 41 37 4100 3747.29 3689.29 40 0 4150 3785.85 3727.85 39 5 4200 3824.77 3766.77 38 40 4300 3902.81 3844.81 :3:3 4:3 4400 3981.26 3923.26 37 55 COLIRSE DOG-LEO DIREC'¥ION SEVERITY DEGREES DEG/IO0 N 56.19 E N 54.89 E N 53.10 E N 53.69 E N 54.19 E N ._4.;_,c E N 55.69 E N 56.69 E N 56.10 E N 54.89 E N 53.89 E N 53. 0 E N 53. (] E Iq .5:3. 0 E N 52. :_::'.~ E N 53.19 E N 53.60 E N 54.19 E N 54.10 E N 54.80 E N 55.50 E N 56. 0 E N 57.10 E N 57.89 E N 58.19 E N 55.1.9 E N 53.19 E N 52.60 E N 52.60 E N 52.60 E TOTAL ........................ REI.:TANOULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SEC:T I r-' ') 3.44 54 '-"-~' · .o~ N 94.8~ E 108 44 3.90 64.40 N 108.79 E 125.31 ---~ -- I-- . ......... . . ~ :-~6, 8 ! N .1:39,.~ E 163:34 3.75 99.38 N 156.49 E 184.43 · _~= 112.72 N 174. c,.-, E 207.08 ~. ,~ E ~.~l,.1~ .=,. 07 126.7~. N !94 ~"- .... z~,6.44 · _,. 72 141.25 N 215.1:~ E '-"~ :_4.'- 95 156.10 N 237.37 E z~,.=,'-"="='. 06 4.23 171.68 N 260.8! E 31 · -' :~:9 188 36 N '-"-'~ 08 E .~mI '~ 'q'~' 2C~A '-' ' ......._ o ~0 N :~(')'P_... 98 E :371 .10 ': 51 22~ 15 N ~¢~, ....... d ....... '~'~'~ 54 E 402, 9 . . 4._-z,. 59 i i ~- '-J ~ 244 83 N 361 65 E 0.20 264.71 N ~88.04 E O, 29 2~4.62. N ......... 414.._~ 1. E 0.41 :304.44 N 440 76 E 0.5:3 324.09 N 467.22 E 567.5 0.26 362.86 N 520.63 E 0.63 401.15 N 574.20 E 0.5.1_ ........_4.'38_._7Q N ........ 62~, _1:~. E. . 0.40 475.85 N 682.70 E O. 73 0.24 2.54 .... . ....... ~_,.. 13 1.11 O. 04 O. 79 512.35 N 737.95 E · 54Z,.75 N ......... Z?;~, 83 E 58:3.05 N 850.11 E 618.8.9 N 904.73 E 633.52 699.30 830.76 896.74 ?62.67 637. ?,1 N 656.44 N 694.41 N 732, 08 N 1028.60 1093.68 ?~Q.~.~5 E 1.!2~,48 955.58 E 1156.87 1005.25 E 1219.38 10~4.~1E 1~81.~? ARCO ALASKA 3-0-7 · KUPARUK ALASKA INC. VERTICAL SECTION C:ALCULATED''~ ALONG CLOSURE .:,FERRY-.:,UN WELL .:,LRVEY.I.N!j...!j~..JM..PAN¥_ ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1.988 COMPLITATION DATE , '~A'-' dOB NUMBER AK-BO-8o07'~ AUGUST 5 1 ...~.:, _ . . KELLY BUSHING ELEV. -- ~':'z,o. 00 FT. TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN 4500 4060.28 4002.28 37 39 4600 4139.93 4081.93 36 43 4700 4220.18 4162.18 36 31 4800 4300.72 4242.72 36 10 4900 4381.57 4323.57 35 55 5000 4462.63 4404.63 35 45 5100 4543.68 4485.68 35 56 5200 4624.45 4566.45 36 19 5300 4704.29 4646.29 37 42 5400 4783.22 4725.22 38 3 5500 4861.75 4803.95 38 4 5600 4~40.44 4882.44 38 29 5700 5017.89 4959.89 39 59 5800 5094.29 5036.29 40 22 5900 5170.57 5112.57 40 12 6000 5246.~1 5188.91 40 15 6100 5324.26 5266.26 :38 22 6200 5402.66 5344.66 38 21 6300 5481.07 5423.07 38 21 6400 5559.50 5501.50 38 19 6500 5637.85 557~.85 38 30 6600 5716.02 5658.02 38 38 6700 5794.18 5736.18 38 32 6800 5872.76 5814.76 37 52 6900 5951.74 5893.74 37 47 7000 6030.64 5972.64 38 1 7100 6109.28 6051.28 38 17 7200 6187.78 6129.78 38 15 7300 6266.:34 6208.34 38 11 7400 6345.18 6287.18 37 44 C:OURSE D I RECT I ON DEGREES N 52.89 E N 52.80 E N 52.30 E N 51.89 E N .51.39 E N 51. 0 E N 50.80 E N 49.80 E N 46.69 E N 46.30 E N 46.30 E N 46.50 E N 4'.-.?. 10 E N 4'P. 19 E N 49.19 E N 48.89 N 51.60 N 51.50 N 51.39 N 51.19 N 50.89 N 50.80 N 50.60 N 50.19 N 49.80 N 50. 0 N 50. 0 N 50. 0 N 50. 10 N 49.69 DOG-LEG . TOTAL ................................ SEVERITY RECTANGULAR COORDINATES VERTICAL DEG/100 NORTH/SOUTH EAST/WEST SECT 0.:33 769.17 N 11"-' '-' 0._-,. oO E 1342.66 ~ 805.68 N 1151.48 E 1403.10 0.36 841.96 N 11 '='- ~. :~ E 1462.76 0.43 '~ ~ '~' ~,:,. 37 N 1'-'~4~, =. ~'-' E 1 ~,~'~'"'.~.:,]'-' 0. '-"-' oo 914· ,=,'=":',=, N 1291 . 77 E 1580 . ,_,,=, 0 ' '-'9 9= ..... 6* Y, 4:~ ~. ; ._, 1,57. N ~ ~:37,..4C) E 1 '-"- 0 '2'~ ,~o,:, ~o,:,-~ o6 ..,~o. 51 N '-' E Iz*'='o., o. O0 0.70 1026.18 N 14zo.~3 E 17._,:.. 2.33 1066,27 N 147:3.10 E 181Z, O1 0.42 11 '~' oo.54 N 1517.64 E 1878.15 0.02 1151 13 N 1= '~' . _. . ._,6z. 22 E 19:-.~. 52 O, 43 ! 19~, 86.~N ...... 16OZ, 08. E 2C¥)1 · 21 ~ 23 1'~''-c ~c, E 2064 . z3o. 32 N 165:-~_.. '= = .~ 0.38 1278.52 N 1702.75 E 2128.74 E 0.20 1363.11 N 1800.49 E E 2 54 1403 63 N 1849 16 E . . . ~._~1. E 0.06 1480.91 N 1~46.31 E 2445.31 E O. 13 1519.70 N 1994.73 E ~c,07.35 E 0.15 1598.13 N 2091.42 E 2631.84 E 0.17 1637.64 N '~' '~':~. . zl._~ 69 E 2694 21 E ...... 0,..7; ..... ~,7~6 N .... 2.~Z. Z~ E '-' ~ . E 0 '~' '-"~'- . ~6 1716.49 N ~t~4.3:3 E 2817.34 E 0.26 1756.06 N 2281.32 E 2878.74 E 0 03 1'-''-'~ 5~ N 2376.10 E 3002.40 I ,~._~ ._1 l E 0.09 187S.32 N 2~23. S:3 E 306~.25 E 0. ~ 1 191 ~. 9~ N . ~70, ~ ~ :~: 1 ~.5, 7:~: ARCO ALASKA, INC. 3-0-7 KUPARUK ALASKA VERTICAL SECTION CALCLIEATED ALONG CLOSLIRE ERR Y-.:.LN WELL ._URVEYINu C:OMPANY ............................... PAGE ANL. HORAUE ALASKA DATE OF SURVEY AUGUST.., '":' AUGUST 5 1'- '~'''' , ;~oc, dOB NUMBER AK-BO-8007~] KELLY BUSHING ELEV. = ~8.00 FT. TRUE MEASURED VERT I CAL DEPTH DEF'TH 7500 6424.41 7600 6503.99 7700 6583.79 7800 6664.23 7900 6744.57 8000 6825.01 8100 6905.46 8148 6944.0? SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULA~' 'Ci~i0RD iNA¥-Ei~ ............ VERTICAL DEPTH DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTI']-.t 6366.41 :'::7 27 N 47..:..)'-'r E 0 37 1'75~ 57 N 251/_J~' y:~, E ..... .~ ,-, . . ._- 1 o6.70 :.44._,. 99. . 37 4 N 47.10 E O. 40 1774.14 N ~._,_-~. oz E 3247.20 ~:. ~S z '~' ._, = . '~ 9 '='.:, 6 '-' ':~ 48 '" P '~' '~' = '- · ._,,~ N .:,oL}7 1 ~60o. 04 E '-"-" ... ................... 6606.~._.'-":' 36 36 N 48 .69 E 0 .05 2072. '~6 N ~o._'"' ~'~'~. 87 E 3366.71 ~ - - , . - .~, . '~ .-, 6686...7 36 Z:d N 48:30 E 0 27 Z ll~. 42 N 2697.46 E ._,4z6.15 6767.01 36 · . ~,~.06 N 2741.73 E ~.- ................ o~ ~,, 45 6847.46 36 ~, . 0 E 0 00 2191 79 N 2785.86 E ..... ,44.71 6.:,.:,6.0? 36 '?~ '~,5~--, ~.- N 48 0 E 0 O0 '~"-' ' . z~10.87 N 2807.04 E HORIZONTAL DI:--;PLACEMENT = ._-,._ 7.:,. 15 FEET AT NORTH._15 DEG. 46 MIN. EA._T¢; AT MD = 8148 THE CALCLILATION F'ROCEDLIRES ARE BASE[; ON ]'~., U~::E OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, 3-0-7 KUPARUK ALASKA MEASURED DEPTH I NC:. J ._-,FERRY-~.,i_N WELL SLIRVEYINO C:OM~/.JS, IN.¥~ ANCHORAGE ALASKA DATE OF SURVEY AUGUST COMPLITATION DATE AIJG~::;T 5, 1~.=,,:, ,JOB NUMBER AK-BO-80079 KELLY BUSHING ELEV. = 58.00 FT. INTERPOLATED VALJEo FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH TOTAL RECTANGULAR C:00RD I NATES NORTH/::.OUTH EAST/WEST MD-TVD VERTICAL r', I FFERENCE C:ORREC:TI ON 0 0.00 -58.00 1000 999.94 941.94 2000 1999.78 1941.78 3000 2919.45 2861.45 4000 3671.61 3613.61 5000 4462.63 4404.63 6000 5246.91 5188.91 7000 6030.64 5972.64 8000 6825.01 6767.01 8148 6944.09 6886.09 0.00 0.00 1.29 S 9.03 E 6.17 N 21.29 E 206.20 N 309.98 E 583.05 N 850.11E 951.57 N 1337.40 E 1363.11N 1800.49 E 1756.06 N 2281.32 E 2152.06 N 2741.73 E 2210.87 N 2807.04 E THE CALCLILATION PROC:EDLIRES ARE BASED ON THE USE OF THREE 0. O0 O. C_~: O. 06 ................ 0...-~.":"-' 0.16 80.55 80.33 :328. ~':] ~47,.~ 537 37 · .,:.,.=,. '~8 753.09 215, 73 1174 '.g':~ '-' '.'=:. ..... ~.0.- 64 120:3.91 ..o'-"-'. ;",'2- - DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA 3-0-7 KUPARUK ALASKA MEASURED DEPTH 0 58 158 258 358 458 558 658 758 858 958 1058 1158 1258 1358 1458 1558 1658 1758 INC. ::,FERRY-.=,JN WELL SURVgY !N.(~, ,!::OJ~..~(~[.Y. Ei~E ....~ ....... ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1988 COMPUTATION DATE AUGUST 5, 1 '-~ ,--, c,'="=' ,_lOB NUMBER AK-BO-80079 KELLY BUSHING ELEV. = 58.00 FT. ....... O?_ERATOR-MCGU I RE .................. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RERTANGULAR L. UL RD I NATE.=. ~ ~-'i- NORTH/._, iLlTH EAST/WEST MD-TVD VERT I CAL D I FFERENCE !]:ORR _E~:~_! ON ......... Om 58. 158. 258. 358. 458. 558. 658. 758. 858. 958. 1058. 1158. 1258. 1358. 1458. 1558. 1658. 1758. O0 00 O0 O0 O0 O0 O0 O0 O0 O0 00 O0 00 O0 00 00 O0 O0 O0 -58. O. 100. 200· 300. 400. 500. 600· 700. 800. 900. 1000. 1100. 1200. 1300. 1400. 1500. 1600. 1700. O0 0.00 0.00 O0 0.09 S 0·08 O0 1.06 S 0.93 O0 2.00 S 1.77 00 2.76 S 2.61 O0 3.33 S 3.49 00 3.19 S 4.43 00 2.93 S 5.41 00 2·62 S 6.46 00 2·00 S 7.50 00 1.48 S 8.61 O0 0.99 S 9.60 00 0.14 S 10·51 00 0·71N 11·51 00 1·47 N 12.50 00 1·83 N 13.36 O0 2.17 N 14..~ 00 2.48 N 15.25 O0 2.75 N 16.12 0.00 E O, O0 . O, O0 E 0.01 0.01 E 0.02 0.01 E .0, 02 0,. C.!.1 ................ E 0.03 0.01 E 0.03 0.00 E O, 04 ....... (~..._P.! ....... E 0.05 0.01 E 0.05 0·01 E .0. O~ ..... ~]_, 01 ............ E 0.07 0.01 E 0.07 0.01 E O. (_~ ....... 0,01 E 0.09 0 · 01 E 0.10 0.00 E ....................... _Q.i~ .... 9._o0 ............................................. E O. 11 0.01 E O. 11 0.00 ARCO ALASKA 3-0-7 KLIPARUK ALASKA · MEASURED DEPTH 1858 1758 2058 2157 2261 2364 246:.? 2576 2687 2802 2922 304:-? 3182 3315 344:.? 3581 3714 3848 3981 INC. · =,F ERRY-.:,.IN WELL '-' '" . - · :,URVEY I N~ J:iOMF]ANY ....................... E'AGE ANCHORAGE ALASKA DATE OF SURVEY ALIGUST~," 1988 L. uMF i_ TAT I ON DATE .... AUGUST 5, 17:::8 ,_lOB NUMBER AK-BO-80079 KELLY BUc. H INeJ ELEV. = 58.00 FT. OPES~qTOE=I~CGU I~F ~ INTERPOLATED VALLEo FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH .:,UB-oEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOLITH EAST/WEST MD-TVD VERTICAL DIFFERENC~ CORRECTION 1858.00 1758.00 2058.00 2158.00 2258.00 2358.00 2458.00 2558.00 2658.00 ~'~M'-' 00 2858.00 2?58.00 3058.00 3158.00 3'258.00 3358.00 3458.00 3558.00 3658.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3.27 N 17.35 E 4.66 N 17.54 E ?.42 N 24.82 E 17.60 N 35.23 E 27.88 N 51.26 E 41.03 N 73.20 E 58.37 N 100.10 E 81.28 N 132.13 E 107.28 N 170.05 E 141.75 N 216.20 E 179.0:3 N 271.71E 225.14 N 335.53 E 277.79 N 405.38 E 330.2? N 475.63 E 381.83 N 546.89 E 431.84 N 481.31N 52?.68 N 576.68 N 618.15 E 69o, 8Q ..~ ............ 764.80 E o._-.~ · 84 E 0.12 0.01 0.16 Q,~ ........... 0.43 0.27 1.3:2 0.90 3.14 I ~'~ ,~ ...... 6.38 3.24 11.40 5.02 18.90 7,50.. ~'~Y. 48 10.~='~ 44.3? 14.71 64 67 20,'-'- ........ ~ 91.99 27.32 124.85 32.86 1~7.86 ...... ~.01 ......... 191.03 33.17 223.62 32.59 290.23 33.48 323.79 33.56 ARCO ALASKA, 3-0-7 KUPARUK ALASKA MEASURED DEPTH 4113 4242 4370 4497 4622 4747 4870 4994 5117 5241 5367 5494 5622 5752 5883 6014 6143 6270 6398 I NC;. SPERRY-SUN WELL :-=;URVEYIN~ C!;!ME'BNY ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1.988 COMPLITATION DATE ALII,~LI,:.T 5, 1'-''":''~' ._II_-IB NUMBER AK-BO-8007.9 KELLY BUSHING ELEV. = 58.00 FT. _OPE_R~ T ~R :M_~i~!_-I_! ~_E_ .................... INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ]'RUE VERTI,-:AL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR L.u_RDINATEo MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I CAL C:C!RRE~!;~T I C!,N ....... 3758.00 3858.00 3.958.00 4058.00 4158.00 4258.00 4358.00 4458.00 4558.00 4658.00 4758.00 4858.00 4958.00 5058.00 5158.00 5258.00 5358.00 5458.00 5558.00 3700.00 624.02 N 912.11E 3800.00 672.60 N .976.72 E 3900.00 721.07 N 1040.12 E 4000.00 768.11N 1101.89 E 4100.00 813.83 N 1162.22 E 4200.00 859.08 N 1220.98 E 4300.00 904.22 N 1278.42 E 4400.00 949.47 N 1334.81E 4500.00 995.07 N 1390.91E 4600.00 1042.14 N 1447.07 E 4700.00 1094.90 N 1503.37 E 4800.00 114.9.00 N 155.9.98 E 4900.00 1203.47 N 1617.21E 5000.00 1258.38 N 167.9.42 E 5100.00 1313.83 N 1743.66 E 5200.00 1369.28 N 1807.57 5300.00 1420.23 N 1870.!~ 5400.00 1469.51N 1932.04 5500.00 1518.95 N 1993.80 ._",._l._l m ' ' ._'i i.', -r. 412 =':' 43.9.12 464, = 4 ~"-" 05 I~__ -'~'i · F_,~6. ~.,.~.,.9.6~-~ ='-"'=' 66 ._, ,~ ..=i. 609. ?8 6~6.98 664.43 6.94.39 725.54 32.1'~ .~.~ ....... 27.94 26.61 25, 42 24.50 23.84 23.40 ':>":' 39 ...-.,..it l 'T.~ '-J ..=.o. 9:-=: . .~6, .'_32 ........ 27. O1 27.45 . 29.96. :31.15 E 756.54 31. O0 E ............... Z~ ,.Q 4 ....................... ;2,'.3~ ._50 E. 812.57 27.53 E 840.08 27.51 ARCO ALASKA, 3-0-7 KUPARUK ALASKA INC. SF'ERRY-SUN WELL SLIRVEYIN~ Cg~PANY ......................................................... RA~ ........ ~ ..... ' ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1988 COMPUTATION DATE AUGUST = · _,, 1988 .lOB NUMBER AK-BO-80079 KELLY BUSHING ELEV - ='~ 00 FT INTERPOLATED VALUES FOR EVEN 100 FEET-OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERT I CAL VERT I CAL DEPTH DEF'TH DEPTH TOTAL RECTANGULAR COORDINATES NJRTH/SOUTH EAST/WEST MD-TVD VERT I CAL D I FFERENCE CO..RRECT I .(iN ,! 6525 5658.00 5600.00 1568.87 N 2055.50 E 6653 5758.00 5700.00 1619.35 N 2117.41E 6781 5858.00 5800.00 1669.72 N 2178.53 E 6907 5958.00 5900.00 1719.62 N 22S8.03 E 7034 6058.00 6000.00 1769.81N 2297.70 E 7162 6158.00 6100.00 1820.49 N 2358.10 E 728~ 6258.00 6200.00 1871.11N 2418.50 E 7416 6358.00 6300.00 1921.36 N 2478.16 E 7542 6458.00 6400.00 1971.35 N 2536.49 E 7667 6558.00 6500.00 2020.81N 2593.51E 7792 ~'" ~ ...... '?A4'~ :39 E 6~._,,:,.00 6600.00 '='(')A9 9(~) ~ .... . 7916 6758,00 6700.00 2119.02 r~ 2704.88 E 8041 6858.00 6800.00 2168.35 i, 275~.82 E 8148 6944.09 6886.09 2210.87 N 2807.04 E 867.75 27.67 :~'.~5.74 27.9,.~ 923.30 27.57 949.92 26.61 976.72 1004. 07 27. ~._,'--'= 1 ~..---, 1..a~x 27.32 1058.2 ! 2~,. 82 . (.)84 31 26.10 1109.61 25.29 11:34.23 ......... 24. ~:~ 1158.70 24.46 1183.00 24.31 THE CALC:LILATION F'ROC:EDURES ~ '-' d.:,E A LINEAR INTERPOLATION BETWEEN _ _ THE NEAREST 20 FOOT MD (FROM RADI~ '-' I.:, OF C:URVATURE) F'QII~IT_~ ............ ARCO ALASKA· INC. 3-0-7 KUPARUK : ALA---~KA · SPERRY-SLIN WELL SURVEYIN~ COM.PAN_Y ...................................................................... ~...A.~]~.' ] .1.~". .... ' ANCHORAGE ALASKA DATE OF SURVEY AUGUST,-, '~ 1988 r:OMPLITATION DATE ........................ Al IGI I::;T = ..... ,, l'.-.-,e:8 KELLY BUSHING ELEV. = ='---' ..,L'~. 00 FT. .............. L]PERATOR-MCGU I RE _. INTERPOLATED VALIIES FOR oFEL. IAL oURVEY POINTS TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL ° I~' I" ' RE _.TAN _~LIL AR C:OORD I NATES NORTH/'-'-I .:,U JTH EAST/WEST MARKER 7718 6598.43 6540.43 2040.67 N 2616.11E TOP KUPARUK C 7761 6632.93 6574.93 2057.61N 2635.40 E BASE KUPARUK C 7797 6661.82 6603.82 2071.78 N 2651.52 E TOP KUPARUK A 7934 6771.91 6713.91 2125.86 N 2712.56 E BASE KUPARUK A 8000 6825.01 6767.01 2152.06 N 2741.73 E SURVEY DEPTH 8045 6861.21 6803.21 2169.94 N 2761.58 E PBTD 8148 y' 6944.09j 6886.09 2210.87 N~ 2807.04 E~- TD ARCO ALASKA~ INC. 3-0-7 STRAT I GRAPH IC E:UMMARY DERIVED USING DIL DEPTHS~ AND SPERRY SUN SURVEY DATA MARKER ....... MEA:SURED [EFTH BKB TOP KUPARUK C 7718 BASE KUPARUK C 7761 TOP KUPARUK A 7797 BASE'KUF'ARUK A 7934 PBTD 8045 TD 8148 TVD BKB SUB-SEA 6598.43 6540.43 6632.93 6574.93 6661.82 6603.82 6771.91 6713.91 6861.21 6803.21 6944.09 6886.09 ~OR!l! NATES THICKNESS WITH REF' TO WELLHEAD VERT I CAL ( OR I G I N- 854FNL 1917FWL ) ........ ~EU _.~..~ ...... ]Cl~lxl_ ...... Po., E 2040.67N 2071.78N 2125.86N 21.6~.~4N 2210.87N 2616 I~-' 2651.52E 2712.56E ~7oI.~ 2807.04E 1) FROM LINEAR EXTRAPOLATION BELOW DEEF'EST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA CALCULATION AND INTERPOLATION BY RADIUS OF CLIRVATURE ............................. COMPUTATION DATE AUtUoT 5 DATE OF ~Jl~..V_EY AU~!~T ~, 1.~88 dOB NUMBER AK-BO-80079 KELLY.B_~I~I.NG ~L£V. = ~'~.00 FT. TRdE NSRTH SCALE ;- t INCH ~8 500.00 / 500.0 KUPRRUK ARCO flL. ASKR, INC. 3-0-? RUGU5~ 2. ~988 AK-88-80079 -2000.00 F1500. O0 8t48 I -500. O0 , , L-sac. co I t OGO. CO '[ I I I 5C0. CO. 2~3OO. O0 2500. O0 SPERRY -SUN 0.00 SCALE ;- 1 INCH TO t500. O0 / 1500.0 KUPABUK ARCO ALASKR, INC. 3-~-7 AUGUST 2. 1988 RK-80-80079 1500.00 6000.00 ?5O0.00 -~944, 09 I \ ~8~48 I 45C0. CC VERT ~ C,qL PRO JE C-i-- ~ 0t'i ARCO Alaska, In/'''''~' Post Office _ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 13, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 30-7 Perforate March 15, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA I, ,SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X 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 4. Location of well at surface 854' FNL, 1917' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1187' FSL, 747' FEL, Sec. 15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec.15, T13N, R9E, UM At total depth 1357' FSL, 556' FEL, Sec. 15, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 81 48' feet Plugs (measured) 6 94 4' feet None 6. Datum elevation (DF or KB) RKB 59 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-7 9. Permit number 8{~-77/8-6~9 10. APl number 50-029-21 840 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8045' feet Junk (measured) 6 861 ' feet None Casing Length Structural Conductor 8 O' Surface 452 2' Intermediate Production 8093' Liner Perforation depth: measured 7872'-7892' true vertical 6722'-6739' Size 16" 9 5/8" 7" Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail at 7668" Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 7597', Otis 'FMX' SSSV @ 1812' 13. Attachments Description summary of proposal X Add perforations to A-2, A-3 & C Sand Lobes Cemented Measured depth True vertical depth 211 SxASI 110' 110' 1100 Sx AS III & 4557' 4106' 350 Sx Class G - Top Job w/85 sx AS I 200 Sx Class G & 81 2 8 6 9 28' 175 Sx AS I Detailed operation program _ BOP sketch 14. Estimated date for commencing operation M~r(;h 15, 1990 16. If proposal was verbally approved Name of approver LO~¢~;~, 5¢v'-~,~ Date approved 15. Status of well classification as: Oil X Gas _ Service Suspended 17. I herel::ll~ certify/'tthat,.,the foregoing is true and correct to the best of my knowledge. Signed . ~tJ ~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Location clearance Subsequent form Plug integrity _ BOP Test Mechanical Integrity Test_ ORIGINAL SIGNED BY LONNIE 0, SMITH Approved by the order of the Commission require. ,o.~~ Commissioner IApproval ~(~_ [ ~_.~ I Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kupamk River Unit Well 30-07 Additional Perforations Well 30-07 is currently perforated in the A-1 Sand Lobe, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to add perforations in the A-2, A-3, and C Sand Lobes in this producing well. A Wireline BOPE will be used during the perforating procedure. Static Bottom-Hole Pressure is expected to be 2600 psi in this well. No workover fluid will be used during the perforating procedure. Zone Proposed Perf Depths Length C 7748-7758' 10' A-3 7810-7822' 12' A-2 7832-7856' 24' AL ,A OILAND GAS CONSERVATION COMk ION ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ X Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 854' FNL, 1917' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1187' FSL, 747' FEL, Sec. 15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec. 15, T13N, R9E, UM At total depth 1357' FSL, 556' FEL, Sec. 15, T13N, R9E, UM 12. Present well condition summary Total Depth: RKB 59 7. Unit or Property name Kuparuk River Unit f~t 8. Well number 30-7 9. Permit number 88-77/8-629 10. APl number 50-029-21 840 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured true vertical 81 48' feet Plugs (measured) 6 9 4 4' feet None Effective depth: measured true vertical 8045' feet Junk (measured) 6 8 61 ' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 4522' I 6" 9 5/8" 8093' 7" measured 7872'-7892' true vertical 6722'-6739' Tubing (size, grade, and measured depth 2-7/8" J-55 tbg w/ tail @ 7668' Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 7597', Otis 'FMX' SSSV @ 1797' Cemented Measured depth True vertical depth 211 SxASII 110' 1100 Sx AS III & 4557 350 Sx Class G - Top Job w/85 sx AS I 200 Sx Class G & 81 2 8' 175 Sx AS I 110' 4106' 6928' 13. Attachments Description summary of proposal X Proposed workover will repair buckled tubing. 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch 15. Status of well classification as: Oil X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed P~ ~ ~ Title 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 ~,pproved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED IApproval No~ q _~o,~ed C,o~¥ ' SUBMIT IN TRIPLICATE KUPARUK RIVER UNIT 30-7 Workover Procedure SUMMARY: Kuparuk Well 30-7 will be worked over to repair buckled tubing. The corkscrewed tubing will not allow perforations to be added in the "A" and "C" sands. The tubing above the retrievable packer will be pulled and inspected. Necessary replacements will be made and the tubing will be rerun with the well returning to gas lift production. PROCEDURE: 1. Move in and rig up Nordic #1. 2. Displace tubing and annulus with seawater. 3. Nipple down tree and nipple up BOPE. Test same. . Pull out of hole with tubing. Inspect and replace tubing as necessary before rerunning. o Run in hole with completion string. Displace annulus with diesel before locating into top of retrievable packer. 6. Pressure test annulus to 2,500 psi. 7. Nipple down BOPE and install tree. 8. Secure well and release rig. After workover is complete, additional perforations in the "A" and "C" sands will be proposed. 5000 .PSI BOP S ACK 5 1. 9 5/8" CASING HEAD 11" - 3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6' - 3000 PSI TUBING HEAD 3. 7 1/6' - 3000 PSI X 11' - 5000 PSI CROSS~3VER AND SPOOL 4. 11' - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11' - 5000 PSI ANNULAR 11. 12. 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. ~RVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS 4. RE(:X:)RD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINF- CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. 2. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WEM.PEAD. RUN IN LOCJ(-I:X3WN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOlD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOlD FOR 10 MINUTES. 7. 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 I:X:)WNS~. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLU~ MAKE SURE MANIFOLD AND UNES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITI(:~. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 1 3. RECOFID TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRIMJNG SUPERVlSOI:~ 1 5. PERFORM (X3MPt.ETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 KUPARUK WELL 30-07 APl #: SPUD DATE: ORIGINAL RKB: 5(XI2921~IOiX) ADL LEASE: 25513 PERMIT 07~ COITION DATE: 09/23/88 WOFIKOVER DATE: SURFACE LOCATION: ~4'FNLlglTFWL,~Tl~,~ TOP OF KUPARUK: 118TFSL,74TFEL~Cl~,T13N,ROE TO LOCATION: 1357FSI.,Ia6'FEL,~ECIB, TlaN, RgE Al del:e~ am MO-I:IKB m t:~ ef equlpmem ~ ~ mini 58 TUBING SPOOL: a3 PAD ELEVATION: WELLTYPE: PRODUCER CASING arid TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.51t H-40 110 9.625" 3~ J-M 45~7 7' 20~ J,-55 8128 2.875' 6.~ J..56 ABM ?668 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV OTIS FMX 2.313' 1797 SBR AVA PIeR 7583 PKR AVA RI'IS 7597 NOGO CAMCO 'O 2.25" 7634 SHROUT AVA 7668 L 24 GA~ UFT Ind FLOW INFORMATION VALVE STN DEPTH MANOREL S~.E 1 ~ MCMUI:I:W 1' 2 4~ MCMURRY 1 · 3 5~01 MCUURRY 1' 4 ~ MCMUI:IRY 1' $ 7O47 MC. J4UI:a:IY 1" 8 7540 MERLA 1.5" PERFORATION DATA INTERVAL ZONE FT SPF PHASE 7872-7802 A1 20 8 45 PORT SIZE 0.1875 0.1875 .DV 0.25 .0V 03125 COMMENTS sos4. scsG MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 41 HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: ft FISH/OBSTRUCTION: 7560 CORKSCREWED 'EiIV · 8031 ~378 DEPTH REVISION DATE: REASON: ARCO Alaska, Inc. Date: March 9, 1989 Transmittal #: 7443 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 0 7 Resevoir Fluid Study 1 - 2 7 - 8 9 # 8 9 0 0 1 0 Receipt Acknowledged' DISTRIBUTION: Drilling- .--~ .. Franzen Alasi~a Oii & .',~n,~ Co.~:~ Com.~lissioa ' Anchorag~ D&M State of Alaska Kuparuk Resevoir SAPC Chevron Mobil Unocal ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn' Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 I Sub-Surface Pressure Survey I 0 - 0 6 - 8 8 3 H - 1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8 3 O- 0 7 Kuparuk Well Pressure Report I 2- 2 0 - 8 8 3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7 3 F- 1 6 Kuparuk Well Pressure Report 8 o 1 7- 8 7 3 F- 1 1 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F- 0 5 Kuparuk Well Pressure Report 1 2 - 1 2 - 8 8 3 F- 1 3 Kuparuk Well Pressure Report I 2 - 3 1 - 8 8 3 N - 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7 3 N- 10 Kuparuk Well Pressure Report 6 - 11 - 87 3 N - 04 Kuparuk Well Pressure Report 9 - 01 - 87 3 N - 09 Kuapruk Fluid Level Report 5 - 04 - 87 30-14 Kuparuk Fluid Level Report 2- 13-89 30-14 Kuparuk Fluid Level Report 2 - 10 - 89 3 M o I 8 Kuparuk Fluid Level Report 2 - 10 - 89 3 F - 16 Kuparuk Fluid Level Report 6 - 05 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 09 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 18 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 16 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 21 - 87 3 F- 08 Kuparuk Fluid Level Report 5 - 08 - 87 3 F- 16 Kuparuk Fluid Level Report 8 - 18 - 87 3 F- 16 Kuparuk Fluid Level Report 8 - 24 - 87 3 F - 13 Kuparuk Fluid Level Report 6 - 05 - 87 3 F- 16 Kuparuk Fluid Level Report 6 - 2 / 3 - 87 3 F- 16 Kuparuk Fluid Level Report 8 - 5 - 87 3 F- 16 Kuparuk Fluid Level Report 6 - 5 - 87 3 F- 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing CommJssjo~ Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N -05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku ~aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku3aruk Fluid Ku~3aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku 3aruk Fluid Ku ~aruk Fluid Ku~3aruk Fluid Ku 3aruk Fluid Ku~3aruk Fluid AcknoWledged· Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report 9 - 1 I - 87 Report I 2 - 06 - 86 Report 9- 1 I -87 Report I 0 - 1 I - 87 Report 9 - 1 6 - 87 Report 4 - 1 I - 88 Report 4 - 08 - 88 Report 4 - 01 - 88 Report 3 - 26 - 88 Report I - 30 - 88 Report I 0 - 1 2 - 87 Report I 0 - 15 - 87 Report I 0 - 2-8 - 87 Report 10 - 28 - 87 Report I 0 - 28 - 87 Report 10 - 28 - 87 Report 3 - 1 9 - 87 Report 9- 1 2- 87 Report 9 - 1 0 - 98 Report 9 - 1 0 - 87 Report 9 - 1 0 - 87 Report 9- 1 2-87 Report 9 - 08 - 87 Report 9 - 01 - 87 Report 9 - 01 - 87 Report 9 - 06 - 87 Report 9 - 06 - 87 Report 9 - 06 - 87 Report 9 - 06 - 87 Report 6 - 01 - 87 Report 5 - 31 - 87 Report 6 - 03 - 87 Report 6 - 06 - 87 Report o 6 - 08 - 87 Report 6 - 09 - 87 Report 6 - 25 - 87 Report 4 - 1 7 - 87 Report 4 - 1 8 - 87 Report 6 - 1 7 - 87 Report 6 - 20 - 87 Report 5 - 07 - 87 Report 8 - 24 - 87 ........................... Date: casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & G3s Cone. CcmmJssJoi,~ ....... ¢t~Orage DISTRIBUTION: D&M State of Alaska i- Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-1 4 ~3H-15 ~3H-17 e3M-19 ,~3H-06 e3H-09 ,3H-21 e3K-06 ~,3H-21 .1Y-06 30-07 Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aurk Fluid Ku 3aruk Fluid Ku 3aruk Fluid BHP Report Level Report ~1 2- 1 0 - 8 8 Level Report I 2- 0 9 - 8 8 Level Report I 2 - 0 9 - 8 8 Level Report 1 2 - 0 9 - 8 8 Level Report I 2 - 0 8 - 8 8 Level Report 1 2- 1 3 - 8 8 Level Report 1 2 - 1 3 - 8 8 Level Report 1 2- 1 2 - 8 8 Level Report 1 2- 1 2 - 8 8 Level Report 1 2- 1 2 - 8 8 I I-27-88 Casing Tubing Casing Casing Tubing Casing Casing Casing Casing Casing Receipt Acknowledged: Alaska ........................... Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil ,:. ARCO Alaska, Inc. Date: December 23, 1988 Transmittal #: 7382 RETURN TO: ARCO Alaska, Inc. Attn' Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 30-07 FID Flowing BHP Log &'/... o,.,/ '1 Please acknowledge receipt and return 1 1-27-88 7500-8024 Receipt Acknowledged' Anchorage DISTRIBUTION; __ D&M State of Alaska Unocal SAPC Chevron Mobil "'"'" STATE OF ALASKA ALA .... A OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ~' Pull tubing __ Alter casing m Repair well m Pull tubing Other % COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 854' FNL, 1917' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1187' FSL, 747' FEL, Sec.15, T13N, R9E, UM At effective depth 1316' FSL, 601' FEL, Sec.15, T13N, R9E, UM At total depth 1357' FSL, 556' FEL, Sec.15, T13N, R9E, UM 5. Type of Well: Development .~_ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) RKB 59 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-7 9. Permit number/approval number 88-77/8-629 -- 10. APl number 50-- 029-21840 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8148 ' MD 6944 ' TVD feet Plugs (measured) feet None Effective depth: measured 8045 'MD true vertical 6861 ' TVD feet Junk (measured) None feet Casing Length Size Structural Conductor 80 ' 16" Surface 4522 ' 9-5/8" Intermediate Production 8093 ' 7" Liner Perforation depth: measured 7872 ' -7892 'MD true vertical 6722'-6739'TVD Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 211 sx AS II 1lO'MD 1100 sx AS III & 4557'MD 350 sx Class G - Top Job w/85 sx AS I 200 sx Class G & 8128'MD 175 sx AS I 2-7/8", J-55, tbg w/tail ~ 7668' Packersand SSSV(typeand measured depth) AVA 'RHS' pkr @ 7597' & Otis 'FMX' SSSV ~ 1797' 110'TVD 4106'TVD 6928 ' TVD 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run~v GYro 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. Signed ~ Title Area Dri 11 i ng Engi neet Form 10-404 Rev 06/15/88 / (Dani) SW03/047 *NOTE: Completion Well History SUBMIT IN DUPLICATE ARCO Oil and Gas Company ~ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations ere started, District Field Auth. or W.O. no. ARCO Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. NORTH SLOPE - ~PARUK l County, pari'sh Or borough I Lease ~'r Unit ~2998 ______j__ COMP_LETE I Title J_ API: 5 0-0 2 g-2 ~ 8_~_~L~_ '~ ' IWell no. Operator ACCEPT 09/22/8__8~ Spudded or W,O. begun N~Date Date and depth as of 8:00 a,m09/23/88 ( PB: 8045 SUPV:MD Complete record for each day reposed 8) RUNNING COMPLETION 7" ' ' ~ ACCEPT RIG AT 2345 HRS, 9/22/88. PERFORATE 7872'-7892' W/ 8 SPF, 45 DEGREE. RIH WITH 2-7/8" COMPLETION ASSEMBLY. DAILY: $6,650 CUM: $721,057 ETD:S721,057 EFC:$1, 290, 000 The above~ o. 6) ~/ / _____-- ~)~,~, iPn ~°, C~ ad~eres'8 6 and · ' ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold· "Final Report" should be submitted also when operations are suspended for an Indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District lCounty or Parish NORTH SLOPE - KUPARUK ~ or Uni'------~-- ~ N:)L= 25513 Title CO['~LETE Field I Accounting cost center code Sta~K 3~x~.CO Alaska, Inc. KUPARUK RIVER FIELD 30-7 [Well no. Auth. or W.O. no. AK2998 Operatbr ~co Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 09/24/88 ( TD: 8148 PB: 8045 SUPV:MD APl: 50-029-21840 A.R.Co. W,I. total number of walls (active or inactive) on this '" 56. 0000 cost center prior to plugging and I abandonment of this well I oate 09/22/88 Hour2345 ['IRS ]Prior status if a w,o, Complete record for each day reported NORDIC i RIG RELEASED 7"e 8128' MW:10.0 NACL FIN RNG 2-7/8" COMPL. SET PKR, REL PBR, TEST TBG, ANN, AND SSSV - OK. ND BOPE, NU TREE AND TEST SAME. DISPL WELL W/DIESEL. RR @ 2030 HRS, 9-23-88. DAILY:S141,797 CUM:$862,854 ETD:S862,854 EFC:$1,290,000 NOTE: OTIS 'FMX' SSSV ~ 1797', AVA 'RHS' PKR ~ 7597', & TT @ 7668'. Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data Well no. Date Reservoir K~iBnDepth tType completion (single, dual, etc,) Test time Producing Interval Pump size, SPM X length ~ size ~ Water % Gravity corrected · see Procedures Ma , Drilling, Pages 86 a 87. Production Oil on test Gas per day Allowable Effective date ARCO Alaska, Inc. Date' August 26, 1988 Transmittal #: 7276 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-06 Cement Bond Log 8-02-88 51 87-8052 30-08 Cement Bond Log 8-01 -88 3085-7648 3 O- 04 Cement Bond Log 8 - 0 3 - 8 8 6 9 8 0 - 8 8 6 6 3 O- 0 7 Cement Bond Log 8 - 0 2 - 8 8 64 5 7 - 8 0 2 4 Receipt "Acknowledged: DISTRIBUTION; NSK Drilling Chevron(+sepia) State of Alaska(+sepia) SAPC(+sepia) Unocal(+sepia) Mobil(+sepia) STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 59' 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location 854' At top of 1320' At effective depth 1381 ' FSL, 646' At total depth 1423' FSL, 601 ' of wellatsurface FNL, 1917' FWL, Sec. 22, T13N, R9E, UM productiveinterval FSL, 792' FEL, Sec. 15, T13N, R9E, UM (approx) FEL, Sec. 15, T13N, RgE, UM (approx) FEL, Sec. 15, T13N, RgE UM (approx) 7. Well number 30-7 8. Permit number 88-77 9. APl number 50-- 029-21 840 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 8148'MD feet 6939'TVD feet Casing Conductor Surface measured 8045 ' MD true vertical 6855 ' TVD Length Size 80 ' 1 6" 4522 ' 9-5/8" Producti on 8093 ' 7" feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth Rue Verticaldepth 211 sx AS il 110'MD 110'TVD 1100 sx AS III 4557'MD 4106'TVD & 350 sx Class G Top job w/85 sx AS I 200 sx Class G 8128'MD 6923'TVD Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None None 12.Attachments Description summary of proposal [] Detailed operations program [] ~/FI I N I ~TngV 13. Estimated date for commencing operation September, 1988 14. If proposal was verbally approved Name of approver Date approved BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢o ~,J')/t./~L-- ~.~¢.Jt_. Title Associate Engineer ~ Commission Use Only (SA3/0026) Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI , Approved by (Dani) No. Approved Copy ORIGINAL SIGNED BY Returned LONNIE C. SMITH ~~7 by order of Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate ~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2998 ICounty, parish or borough NORTH SLOPE - KUPARUK Lease or Unit ADL: 25513 Title DRILL IState 30-7 lWell no. API: 50-029-21840 Operator ARCO Spudded or W,O. begun ARCO W.I. J 56.0000 Hour JPrior status if a W.O. 1430 HRS I SPUD J Date 07/20/88 Date and depth as of 8:00 a.m. 07/20/88 ( TD: 0'( SUPV: 07/21/88 ( TD: 2077' ( 2 SUPV: 07/22/88 ( TD: 4231'( 2 SUPV: - 07/23/88 ( TD: 4577'( SUPV:DL 07/24/88 ( TD: 6372'( 1 SUPV:DL 07/25/88 ( TD: 8033'( 1 SUPV:DL 07/26/88 ( TD: 8148'( SUPV:DL Complete record for each day reposed DOYON 14 ) MOVE RIG TO 30-7 MW: 0.0 VIS: 0) ) ;77) DAILY: $ 0 CUM: $ 0 ETD: $ 0 EFC: $1,290, 000 :) .54) DRILLING 16"@ 110' MW: 9.4 VIS: 78 FINISH MOVING RIG. ACCEPT RIG 0930 HRS, 7/20/88. NU DIVERTER AND FUNCTION TEST SAME. PU BHA. DRILL OUT ICE IN CONDUCTOR. SPUD @ 1430 HRS, 7/20/88. ROTARY DRILL 110'-1887' ORIENT AND NAVI-DRILL 1887'-2077' DAILY:S54,959 CUM:$54,959 ETD:S54,959 EFC:$1,290,000 ~) 46) DRILLING 16"@ 110' MW: 9.2 VIS: 57 FINISH DRILLING KICKOFF 2077'-2713'. DRILL 2713'-4155'. POH FOR WASHOUT. DRAIN PLUG WASHED OUT OF MOTOR. CHANGE OUT AND ORIENT NAVI-DRILL, PU BIT, TIH. DRILL 4155'-4231'. DAILY:S44,331 CUM:$99,290 ETD:S99,290 EFC:$1,290,000 ) ~95) TEST BOPE 9-5/8"@ 4557' MW: 9.5 VIS: 48 DRILL 12-1/4" HOLE 4231'-4577' CIRC & COND MUD, DROP SURVEY POH. LD BHA. RU AND RUN 115 JTS 9-5/8, J-55, BUTT CASING. SHOE @ 4557', COLLAR @ 4477'. CIRC & COND MUD AND CEMENT W/80 BBL WATER SPACER, 1100 SX AS III AND 350 SX CLASS G, DISP W/346 BBLS WATER. LOST RETURNS AFTER 190 BBLS. BUMPED PLUG TO 2000 PSI OK. FLOATS HELD OK. RD CEMENTERS, ND DIVERTER AND PERFORM TOP JOB W/85 SX AS I. MU SPEED HEAD, INSTALL BOPE AND BEGIN TESTING SAME. DAILY:S186,752 CUM:$286,042 ETD:S286,042 EFC:$1,290,000 ;) ;61) DRILLING 9-5/8"@ 4557' MW: 9.3 VIS: 32 INSTALL WEAR RING, PU BHA, INSTALL NL MWD SOURCE, RIH, CUT DRILL LINE. DRILL OUT COLLAR AND CEMENT. TEST CASING TO 2000 Psz OK. DRILL OUT SHOE, 10' OF NEW HOLE AND pERFOrm' L.O.T. TO 12.5 PPG EMW, OK. DRILL AND SURVEY 4587'-6372'. DAILY:S42,413 CUM:$328,455 ETD:S328,455 EFC:$1,290,000 DRILLING 9-5/8"@ 4557' MW:10.1 VIS: 49 DRILL AND SURVEY 6372'-8033'. .... : ~,, ! , . DAILY:S48,876 CUM:$377,331 ETD:S377,331 EFC:$1,290,000 ;) 15) The above is correct r)ATT,Y-_ $63, ~3R2 Signature (~ {~/)")J¥~ ,<~,.(./~_. JDat. For form preparat¥'~J and distribution, see Procedures MJ~ual, Section 10, Drilling, Pages 86 and 87. POH LDDP 9-5/8"@ 4557' MW:10.1 VIS: 46 FINISH DRILLING 8032'-8148' CIRC AND SHORT TRIP, REAM AND WASH TO BOTTOM. CIRC AND CONDITION MUD, DROP SURVEY AND TOH. REMOVE NL SOURCE, LD BHA. RU SCHLUMBERGER, LOG DIL/SFL/CAL/SP 8140' -4550', FDC/CNL 8140' -740' 0, GR 8140' -1000', RD SCHL. MU BHA AND TIH, CIRC AND CONDITION HOLE, SPOT PILL AND POH LDDP. o.[]M: $440:413 ETD. $440.. 413 V. FC_- ~1. 290: OOO J Title ~'~/f:,/~ A,~CIATE ENGINL:~R ARCO Oil and Gas Company Daily Well History-Final Report District Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code County or Parish State ARCO Alaska, Inc. I NORTH SLOPE - KUPARUK AK ! Field iJLease or Unit I Well no. KUPARUK RIVER FIELD I ADL: 25513 30-7 Auth. or W.O. no. JTitle AK2998 I DRILL Operator I A.R.Co. W.I. ARCO ] 56. 0000 Spudded or W.O. begun JDate SPUD J 07/20/88 Date and depth Complete record ~'or each day reported as of 8:00 a.m. DOYON 14 Old TO Released rig 07/27/88 ( TD: 8148 PB: SUPV:DL ClassificatiOns (oil, gas, etc.) Producing method Potential test data 50-029-21840 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. 1430 HRS RIG RELEASED 7"@ 8128' MW: 0.0 NACL FINISH POOH. LDDP. RIH W/ 7" CSG W/ FS AT 8128'. CMT W/ 200 SX OF CLASS G CMT. BUMPED PLUG W/ 3500 PSI. CIP AT 2030 HRS, 7/27/88. ND BO?E. SET SLIPS. CUT OFF CSG. NU TBG HEAD AND TEST TO 3000 PSI. RIG RELEASED AT 0200 HRS 7/27/88. DAILY:S273,994 CUM:$714,407 ETD:S714,407 EFC:$1,290,000 tNew TD J PB Depth Date Kind of rig Type completion (si~ngle, dual, etc.) IOfficial reservo r name(s) 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 _ For form preparati~and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: August 5, 1988 Transmittal #: 7248 RETURN TO: ARCO Alaska, Inc. Atln: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. "" 3 O- 08 OH LIS Tape and Listing 7 - 2 9 - 8 8 # 72 8 5 5 "' 30-08 LSS Waveform Tape and Listing 7-27-88 #72855 -' - 30-07 OH LIS Tape and Listing 8-03-88 #72860 Receipt Acknowledged: DISTRIBUTION; State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: August 5, 1988 Transmittal #: 7245 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 30-O7 30-07 30-07 30-07 30-07 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return 5" Dual Induction 2" Dual Induction 2" & 5" Raw FDC 2" & 5" Porosity FDC Cyberlook 7-25-88 4552-8134 7-25-88 4552-8134 7-25-88 4552-8118 7-25-88 4552-8118 7-25-88 Receipt Acknowledged: ............ DISTRIBUTION: NSK Franzen Drilling L. Johnston(vendor package) D&M .State of Alaska(+sepia) M EMORAN DUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C. Smith Commissioner DATE: July 29, 1988 FILENO: D.BDF. 002 T~U: Richael T. Rinder ¢-~¢''?('/~¢' Sr. Petroleum Engineer Petroleum Inspector TELEPHONE NO: SUBJEC~ BOP Test AAI KRU 30-7 Permit No. 88-77 Kuparuk Rv Field ~a~.~..M,:~.July 23, 1988: The test began at 5:00 a.m., and was concluded at 6:30 a.m. As the attached BOP Test Report shows, there were no failures. In summary, I witnessed the BOP Test on ARCO's 30-7. Attachment 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator f~/ Wen ©- .'.' Location: Sec Location, General ,~----~ Well Signa--''~ General Housekeeping~ Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Test Pressure Annular Preventer Pipe Ra, ms Blind Rams ~.3 Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures ACCUMULATOR SYSTEM Charge Pressure ~O psiR Full Pressure After Closure /~0(~ psig Pump incr. clos. pres. 200 psig --- min~, sec. Full Charge Pressure Attained: ~ min/2-sec. Controls: Master RemOte~]~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold No, Valves No. flanges Repair or Replacement of failed equipment to be made within -- Commission office notified. Adjustable Chokes / Hydrauically operated choke / Test Time //~,~ hrs. day~ and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor July 18, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 ' k Re: Kuparu River Unit 30--7 ARCO Alaska, Inc. Permit No. 88-77 Sur. Loc. 854'F~L, 1917'FWL, Sec. 22, T13N, RgE, UM. Btn~ole Loc. 1430'FSL, 661'FEL, Sec. 15, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above q d 11 re~erence we . The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior 'to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify.this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chai~an of Alaska Oil and Gas Conservation Comission BY ORDER OF THE COI,~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA '~" ALASKA U,,_ AND GAS CONSERVATION CO,.,MISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test FJ Development Oil Re-Entry [] DeepenEZ]I Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513~ ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 854'FNL,1917'FWL,Sec.22,T13N,RgE,UM Kuparuk River Unit Statewide At top of productive interval(L~ target) 8. Well nu,mber Number 1 320' FSL, 792 ' FEL, Sec .1 5,T1 3N, RgE, UM 30-7 #8088-26-27 At total depth 9. Approximate spud date Amount 1430'FSL,661 ' FEL,Sec. 15,T13N,RgE,UM 07/20/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line DS 30-6, DS 30-8 8131 'MD 661' ¢TD feet g`5' ¢ surface feet 2560 6897'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2000 feet Maximum hole angle 400 Maximum surface 2426 psig At total depth (TVD) 3239 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 115 115' +200 # cf 12-1/4" 9-5/8" 36.0# J-55 BTC 4438 35 35 4473 4099' 1100 sx AS Ill & F-ERW 350 sx AS II 8-1/2" 7" 26.0# J-55 BTC ~(~,~'~ 34 34 8131 6897' 100 ~,X ,50/,50 Poz Lea. ~F-ERW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~Ou~arfukO G 500' above Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate Production .t~!N ~ 7 Liner Perforation depth: measured AI~S~ 0it & Gas COOS. Commission A~c~0rage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] DiverterSketch [] Drilling program F~ Drilling fluid program ~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements 21. I hereby.certify that the,, foregoing is true and correct to the best of my knowledge Signed ~;~/¢~/~/ ~/~¢4~"' ~E .,~l~~ Title ........ ,,~, _..'.'nee. / v.,[' .... '-/~ ~ ~ ~.eg~..on.a~,_ur~ ~ ~ ~..~ ~'"g " Date // L;ommission use unIy~l.~...Cy~ (TEM) PD 1003 ( Permit Number I APl number I Approval date See cover letter ~¢~8-77J 50--O2-9 - ;~;18~oJ 07/18/88 for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required L-J Yes '~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required ~Yes [] No Required working.,p~ssur~j~for~,~2M; ~ 3M; [] 5M; [] 10M; [] 15M Other: ~~~(~~/~~~~,~..~,.~...-..'""~' ~~/~ by order of Approved by Commissioner the commission Date Fnrm 10-401R~v_ 124-R5 StJbml riDlicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. .. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin~~ Pressure test to 3500 psig. 11) Downsqueeze Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cas.ed hole logs. 15) Move in Workover rig, NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER RECEIVED ]t.!N 2 7 1988 /kl~sk~ Oil & Gas 18ohs. Oommission Anchorage SHALE ~ ST SHAKERSI STIR MUD CLEANER STIR CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 Drillin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge . - Degasser -. Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators 9-12 RECEIVED ..iL.IN ?. ? 1.988 Alaska Oil & Gas Cons. Commission An¢!torage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. TherefOre, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWXS/ih .....KUPARUK RIVER UNIT · 20' DIVERTER SCHEHATIC I I II DESCRIPTION 1. 16' C(3qlIX,~TC~'. 2. Fl'lC SI,,IP,-4:N ~ STARTIN~ ~ 3. FI'lC OlVERTTR AS3~qBLY MTN ~ 2-I/16' 2000 PSI 8ALL VN,,VES 4. 20' 2000 I~J101tl4J~ ~ rtl0' ~ $. 10' HCR 6NJ. VkkVllW/10' ~ I. IN~, A SlNeI~ VAI,VE ~ ~TICAI~Y ~ DIVERSI(~N. e. 20- 2000 ~ ~~ 4 AKO ALA~I~, INC., REGLIEST~ APegOVM. OF THIS DIVERTER SY~TEI'I AS A VARIANCE. FR0rt 20AAC2"J.035(b) RECEIVED ,~U ? 7 1988 A~as~a 0it & Gas Gons. Commission k 2 I I.' I MAI NTENANCE & OPERATION UPON INITIAL [NSTALLATION. CLOSE I~VENTER ~ vERIFY THAT VALVE OPENS PI~Y. 2. CLOSE ANNULAR I:)REVENT~R AI~ ~l, Okt AIR THROUGt DIVERTER LINES EVERY 12 H01JR~. 3. CLOSE ANNULAR PI~EVENI"ER IN THE EVENT THAT ,~N iNFLUX OF WELL8ORE FLUI0$ OR 6AS I$ 0ETECTECI. OPEN APPlqopRIATE VALVE TO ACHIEVE OOWN~NO DIVERSION. DO NOT SHUT IN WELL -- UNDER ANy CIRCUMSTANC£1S < <, L nI, 7 6 5 ii > > DIN3RAM #1 13.5/8' 5000 P~I RSRRA BOP STACK i. 16' - 2000 PS! TAI~CO b"TAR'rIM) lEAD 2. I1' - 3000 PS! CASIN~ I-[AD 3. II' - 3000 PSI X 1~-5/'8" - 5000 PSI SPACER 4. 1~--5/8" - 5000 PSI PIPE 5. 15-5/8" - 5000 PSI DRILLII~ SPOCL W/Q.4CKE KILL 6, 15-5/8" - 5000 PS[ C%:M~E RAM I~VPIPE RN~ ON TOP, ?, [;5-5/87 - 5000 PSI A~ATOR C,J~mACITY TEST I. Q-ECl( ~ FILL N:OJM. I.ATCR RESERVOIR TO PROPER LEVEL WITH HYDRAIJ..IC FLUID, 2. ASStJRE THAT AC~ATOR PRESSURE IS ~X30 PSI WITH 1500 PSI DON~TREAM CF THE REGL.1ATOR. 3. CI~SE~ TII~F_, TI-I~i CLClsE ALL UN]TS SIMLITAI~OUSLY AN3 RECORD THE TIM[ AN3 ~ REI~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLM3 CFF. 4. RECORD ON NN3C REPORT, THE ACCEPTABLE LOI~R LIMIT IS 45 SECON3S CLOSINS Tlbl~ AI~ 1200 PSI RE~ININ~ 4 3 2 15. 13---5/8' BOP STACK .TEST i. FILL BCP STACK AND CHOKE IvINIIF(].D WITH ARCTIC DIESEL. 2. Q-ECK THAT ALL LO0( DOW SCRE~ IN Y~[LLkF_/~ ARE FULLY RETP. AC'TED, SEAT TEST PLUG TN V~[I..L~D WITH ~ING JT AI~ ~ IN L~ SCRE~ 3. CLOSE ~ P~ENTER AIq) ~ KILL ~D ~ LIllE VALVES ADJN:E. NT TO BCP STN:X. ALL OTI-ER VALVES AM) CliO(ES SHOJ.D BE OPEN. 4. PRESStRE UP TO 250 PSI ~ HOLD FOR I0 MIN. IN- CREASE PRESSLRE TO 5000 PSI ~ H~LD FOR I0 MIN. _m_FED PRESSLRE TO 0 PSI. 5. OPEN ~ PREVENTER ~ ~ KILL mN) CHO<E LIllE VALVES. CLOSE TCP PIPE RAMS AN) HCR VALVES CN KILL ~ CHOKE LINES. 6. TEST TO 250 PSI ~ 5(II) PSI AS IN STEP 4. 7. ~INJi TESTING ALL VALVES. LIliES, ~ ~S WITH I 250 PSI LOW ~ ~)00 PSI HIGH. TEST AS IN STEP 4. DO NDT PRF~QE TI~&'T AN~ ~ TI-~T IR hOT A FULL CLOSING POSITIVE SEAL CHOKE. CN.Y ~IIUN IESI Q-EKES THAI DO NDI FULLY CLOSE. 8. OPEN TOP PIPE R/~B ~ CLOSE BOTT(~I PIPE RAM~. TEST BOTTOM PIPE RAM~ TO 250 PSI ~ 5000 PSI. 9. OPEN BOTTOM PIPE ~ BA(X OUT EUN~NG JT mM) PULL CIJT CF HOLE. 10. CLOSE BLIhD ~ N~D TEST TO 250 PSI ~ ~ PSI. II. OPEN BLII~D RAtS ~ RETRIEVE TEST PLU~ MaJ(E SURE Me~IIFCLD ~ LIliES ~ FLI.L OF NO~HrREEZING FLUID. SET ALL VALVES IN DRILLING POSITICtt 12. TEST STAI~PIPE VALVES, KELLY, KELLY CCX](S. DRILL PIPE SAFETY VALYEo /~D INSIDE BOP TO 250 PSI ~ ~XX) PSI. RECCRD TEST IhFCRt~TION ON BLOKIJT PREVENTER TEST FORbl, SIGN, ~ SF.J~D TO DRILLING StPERVI~. VEEKLY THEREAFTER FtlqCTI~LY OPERATE BCPE DAILY. Alaska Oil & Gas Cons. Commission I oo8__4oo ARCO ALASKA, Ino. Ped 30. Well No, 7 Propoeed Kuperuk Field, North Slope, Aleeke 0. . RIG} ELEVAT[ON~ $9' I 000 _ 2000. 4000 B/ PERHAFROST' TVD-1719 . KOP~ TVD"2000 THD-2Ooo.DEP-O 3 BUI:LD ,3 DEG' PER I00 FT 2! T/ UGNU SNDS TVD-2709 THD'"'2726 DEP-136 27' 39 EOC TVD-3230 TMD-333Z DEP-449 T/ W SAK SNDS TVD=3524 THD=3721 DEP=696 K-12 TVD=3899 THD=4211 DEP=1012 9 5/8' CSG PT TVD-4099 THD=4473 DEP-1181 5( AVERAGE ANGLE 40 DE(; 7 MI N RECEIVED ,i[,~N 2 7 ].988 Alaska Oil & 13as Cons. Commission Anct,,~,.ue 6000 7O00 1000 2000 VERTICALi SECT[ON K-5 TVD-5894 THD-6820 DEP-2693 T~ ZONE D TVD-6509 THD-7624 DEP-3211 T~ ZONE C TVD-6596 THD-7738 DEP-3284 T/ ZONE A TVD-6643 THD-7799 DEP-3324 ~'ARGET CNTR TVD-6694 THD-7866 DEP-3367 B/ KUP SNDS TVD-6744 THD-7931 DEP-3409 IG PT) TVD-6897 THD-8131 DEP-3538 3000 4OOO HORIZON; L PROJECT I ON SCALE 1 IN. = 1000 FEET ARCO ALASKA. ! no. Pad 30. Well No, Z Proposed Kupsruk Field. North Slope. Alaska 4000 ~000 _ 2000. _ 1000 m 1 000. _ WEST-EAST 1 000 0 1000 2000 I I I :SO00 I TARGET CENTER TVD,,6694 TI'ID-?8~,~ DEpm~.~' NORTH* 217'4 EAST 257'1 TD LOCATI ON' 1430' FSI.. ~,~1' FEL SEC- 15. TI,3N. RGE ARGET LOCAT ! ON, 1320' FSL. ?e2' FEL C, 15. T13N. RgE SURFACE LOCAT ! ON, 854' FILL. 1917" Fk'L SEC, 22. TI3N. RgE 49 DEG 47 MI N E 367' (TO TARGET) RECEIVED Alaska Oil & Gas Con~. Commission Anchorage 1750 1800 1850 1900 lg~0 2000 800 85O 900 _ ~ 1,,1 O0 ! 700I ° 500 ~ 11 O0 5qo '" kSO0 ~ ! 900 ~'' 500 %'1.300 ~"' 500 950 _ 1000 _ I I' I I I ~ 4100 I I ~ 5OO / / / '"'2500 I I I RECEIVED Alaska Oil & Gas Bons. Commission / /'"'2700 2050 I L600 _ 65O _ 700 75C _ 85( 90C 95( _ 10( I I I i I i 750 1 800 1 850 1 go0 1 950 2000 2050 _ 80C CHECK LIST FOR NEW WELL PERMITS Company /~0 Lease & Well No. ITEM APPROVE DATE ' ' YES NO (1) Fee ~ ~/Z~(~ 1. Is the permit fee attached .......................................... j~_ REMARKS (2 thru 8) (8) (3) Admin ~P~m~ g [C9/~ 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) OPE (23 thru 28) 2. Is well to be located in a defined pool ............................. ~3g 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 wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~._ Does the well have a unique name and number ......................... ~_ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 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 wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ,, Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: ~~. ~-.~.~,,~ · Geology: Engine~in ~: 7~m~BEW ~ ~rm ,.~ rev: 02/17/88 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .......... ,./ 31. If an offshore loc., are survey results of seabed conditions pres~d 32. Additional requirements ............................................. INITIAL GEO. UN IT ' ON / OFF POOL CLASS STATUS AREA NO. SHORE f/9©lOO fP~-/ O~ra. 8,~o ~, (6o ©~ Additional Remarks: 0 ~Z 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. "' AL,~$Kt COMPUTINg CENTER ;~ SCHLUMBERGER IS TAPE VERIFICATION LISTING 'HLUMGERGER ALASKA CGMPUTIN8 CENTER 3-~UG-1958 lZ~: 32 PAGE: SERVICE NAME :EOIT DATE : 85/08/ '3. ORIGIN : FL'lC REEL NAmE : 72860 CONTINUATION .~ : PREVIOUS REEL : COMMEN'T : LIS TAPE.~ ~RCO KUPARUK 3 0-?:~ &PI #50-029-21840 SERVICE NAME DATE : 8810,31 3 ORIGIN :' ~LIC TAPE NA~E : 72~60 CONTINU~TION e : PREVIOUS TAPE COMMENT : L~S T~PE~, ~RCO KUPARUK 3 0-7, API ~50-029-21840 · C'-~ FILE HEADER ~ ~-' ~ ~-' FILE NAME : EDIT ,,00! SERVICE : ~LIC VERSION : O01A02 DATE : ~8/0~/ 3 MAX REC SIZE : 1024 FILE 'TYPE ..'. LO LAST FILE : SCHLUMGERGER ~,LASKA COMPU'T~NG CENTER JOB NUM3ER AT AKCC: 72850 RUN ,~1~ D~TE LOGGED: 25-JUL-B9 LOP: J. KDHRING DATE COMPUTED: D3-AUG-8$ CASING TYPE FLUI3 DENSITY VISCOSITY PH FLUID LOSS : 9.525" @4552'(LOGGER) - BIT SIZE = 8.5" TO 8140'{LOGGER) '= WEIGHTED POLYMER = !0.1 LB/G RM : 3.25 ,@ 66 DF = &4-O S ~MF = 3.60 @ 62 O~ = 9.5 RMC = 2.98 @ 61 DF = 4.0 C3 RM AT ~HT = 1.531 @ 148 DF FIELD REMARKS: 1 1/2" STANDOF¢S USED ~N OIL; MATRIX DENSITY = SAND (2.65); HOLE CORRECTION = CALZmE~; BHS = OPEN. TnOL TYPES/NU~CRS' DIS 1131 DIC 6!7 SET 3'3 CNC 1~49 SGC 24'79 IS TAPE VE~,IFIC~.TION LISTING 'HLUMBERGER ~L~SKA "OM'PUT'iNG C:cNTER ]-AUG-!988 PAGE: '"'"~'"'"""'-,-,-,--,--,--,- THIS DATA HAS NOT B=EN. .... DEPTH SHIFT[D - OVERLAYS FIELD PRINTS ..,-'"'~'"'"'"'.,--,-..,,-.,- -,- SCHLU'M~RGE~ LOGS INCLUOE9 WITH THIS FILE ('_OI 001): · ~ <SeE ~ILE EOI'T.O02 ~0~ 1.2" SAMPLED FDC/CNL TA> '~ ILLY. ~- OUAL IND!JCT]ON SPHERIC FOCUSSD LOG ~' [ 8134~ TO 455'4 ~- FRST TO L~ST R.EtOING, ~ ~g'RM~T~ON O~NS!TY COMP~NS~Eg LOG ~- FIRST TO LAST REA NG. 8118' TD 7388' ~ rOMPSNSATED NEUTRON LO~ (.,~NL) · ' FIRST TO :LAST R~SA.ING. 8103" 'TO -,- GAMM:~ ~AY IN CASING (.CHL) - FI T TO LAST REA3ING 4554' TD 990' TABLE TYPE : CONS CN FN WN NATI STAT C DUN SECT TOWN RANG LATI LONG OPER SON APIN TUNI va LU ARCO ALASKa, INC. K UP AR UK 3 0-7 U.S.A. ~L~SK~ NOR'TH SLOPE 22 1 ~ N 9-- $5¢' FNL 1917' FWL MaLLARY 5'~085S 50-029-21840 DEFI COMPANY NAME FIELD NAME WELL N,~ME NATION STATE OR PROVINCE COUNTY SECTION TOWNSHIP R~NGE L&TITUDE LONGITUDE OPERATOR'S CODE SERVICE ORDER NUMBER API SERIAL NUMBER TABLE TYPE : CU~V DE:I DEPT TENS SFLU ILM ILD DEPTH C'HANN~L N~ME TENSION S=L UNAVEqAGEO IL-MEglUM R~SISTIV!TY IL-OEEP RESISTIVITY IS TAPE VER'IFIC~TION LIST 'HLUMBERG~R ~L.&SK,~ COMPUTING CENTER 3-AUG-19B8 14:32 PA~E: 9EFI SP S~ONT~NEOUS POTEN'TI ~L GR GAMMA R kY T~ENS TENSION OPHI DENSITY POROSITY DRHO DELT~ qHO RHOB SULK DENSITY CALl C~LZPER GR G~MMA R&Y TENS TENSION NPHI NEUTRON P!]ROS!TY T~RA CALIBRATED THERM&L NEUTRON RATIO RTNR R~W THE~M,~L ~:,~UTRnN,~ RATIO RCF'T RCFT RCNT RCN'T CFTC CFT'C CNTC CNTC CAL[ CALIPER G~ G~MMfl R~Y TENS TENSION GR GAM~A R~Y IIlIll I,I It Ii ! I II i I JI II DATA FORMAT SPEC..IFIC~.TZON R~CORD ~ TYPE R,EPR CODE V,~LUE I 66 0 Z 66 0 3 73 100 4 66 1 8 68 0.5 '9 55 FT 11 ~ 10 13 66 0 1~ 65 ~T 15 66 6B 16 66 1 O 66 0 ........... ,m SET TYPE - CH~N ~-~ NAME SE~V UHIT SERVICE ~Pi ~PI API ~P! FILE NUMB NUMB SIZE REOR ID ORDER ~ LDO TYPE CLASS MOO NUMB S~MP ELEM CODE DEPT FT 5'3085:5 1 1 1 4 68 TENS DIL LB 530855 I I I 4 68 SFLU 21L OH~M 53~855 1 I 1 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 IS TAPE VERIFZCATION LISTING ]HLUM~ERGER ALASK~ COMPUTZN'G CENTER 3-&UG-1988 14:132 N,~ME SERV UNIT SERVICE ADZ ID ORDER ~ LOG ILM DIL OHMM 530855 ILD OIL OHMM 530855 SP OIL MV 530.855 GR OIL G~.PI 530855 TENS FDC L8 530855 DPHI FDC PU 530855 DRHD :DC G/C~ 5'B0855 RHOB FDC G/C] 530855 CALZ FDC IN 530855 GR FDC G~PI 530855 T~NS CNL L~ 539855 NPHI CNL PU 530855 TNRa CNL 530855 RTNR CNL 530855 RCFT CNL CPS 5308S5 RCNT CNL COS 530855 CFTC CNL CPS 530855 CNTC CNL CPS 5308~5 C,~LI :CNL IN 5~0855 GR CNL GAPI 530855 TENS CHL LB 530855 GR CHL GAPI 5308S5 ~PI ADI a, PI ~ILE NUNB NUMB TYPE CLASS MOO NUMB SAMP ELEM SIZE 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 1 1 t 1 1 1 1 1 I ! 1 1 1 1 1 1 1 1 1 1 I 1 ! 1 1 1 1 1 1 ! 1 1 1 I I 1 1 1 1 1 ! 1 1 I 1 1 1 1 1 1 I I 1 I I 1 1 I I REPR CODE 68 68 6B 68 68 68 68 68 68 68 68 68 63 68 68 68 68 68 68 68 PROCESS (HEX) 0000000000' O000000OO0 0000000000 OOOO000000 0000000000 0000000000 0000000000 0000000000 O0000000OO 9000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOOOO00OO DO00000000 O00000OO00 DEPT. 815 7. 000 ILO .OIL 2.501 D~H!. FDC 9. 225 G~ .FDC 85.375 RTNR.CNL 2.g68 CNTC.CNL 1973.196 GR . CHL -999.250 DEPT. 8100.000 ILO .OIL 2.671 DPHI.FDC 13.542 GR .FDC 89.313 RTNR.CNL 3.006 CNTC.CNL 2036.627 GR .CHL -'999.]50 DEPT. 8000.000 ILD .OIL Z.656 DPHI.FDC 14.768 GR .mDC 95.Z50 RTNR.CNL 3.380 CNTC.CNL 1924. 060 GR .5HL -999.250 TEN'S.DIL SD .OIL DRHO.FDC TENS.CNL RCFT.CNL CALZ.CNL TENS.DIL SP .DIL DRHO.FDC TENS.CNL RCFT.CNL C4LI.CNL T6NS.OiL SP .OIL DqHg. FDC TENS.CNL PCFT.CNL CALI.CNL 4829.000 -65.000 0.146 4820.000 630.73Z ~.250 6832.000 -1~.328 9.055 6~32.000 641.693 8.438 6712.000 -1.5.531 0.047 6712.000 523. 568 9.375 SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL G:R .DIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NDHI.CNL RCNT.CNL GR .CNL 2.773 85.375 Z.51~ 32.340 1895.001 85.375 3.351 89.313 2.425 33.122 2013.570 89.313 2.889 96.250 2.406 42.355 1882.846 96.259 ILM .DIL TENS.FDC CALI. FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALl.mDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALl. FDC TNRA .CNL CFTC.CNL TENS.CHL Z.425 4820.000 8.250 2.875 698.230 -999.,Z50 Z. 779 6832.000 8.438 2.942 693. 889 -999.250 2.746 6712.000 8.375 3. 443 569.235 -999. ZEO IS *TAPE VER'IFI:CATION LISTING 'HLUMSERGER ALASKA COMPUTING CENTER 3-~U'~3-:1988 14:32 PAGE: DEPT. 7900.000 TENS.OIL ILO .OIL 8.924 S~ .OIL D'PHI.~FDC 3.7.79.4 DRHO.FDC GR .FDC 72.813 T~NS.CNL RTNR.CNL 2.838 RCFT.CNL CNTC.CNL 2:537.806 CALZ..CNL GR .CHL -999o!50 DEPT. 7800.000 TENS.OIL ILD .OIL 3.,¢46 SP DPHI.FDC 10.392 DRHg. FOC GR . FDC 87.06'3 TENS.CNL RTNR.CNL 3.357 RCFT.CNL CNTC.CNL 2159.352 CALI.CNL GR .CHL -999.250 DEPT. 7700.000 TENS.OIL ILD .DIL 3.176 SP .OIL DPHI. FDC 5. 036 DRHO. FDC G'R .FDC 11,3.063 TENS.CNL RTNR.CNL 3.035 RCFT.CNL CNTC.CNL 2280.594 CAL'I.CNL GR .CHL -99'9.250 DEPT. 7500.000 TENS.DIL ILD .OIL 2.546 SP .OIL D~HI.:DC 15.140 DRHO.mDC GR .FDC 112.938 TENS.CNL RTNR.CNL 3.627 RCFT.CNL CNTC.,CNL 1913.942 C&LI,CN[ GR .CML -999.250 DEPT. 7500.000 TENS.OIL ILO .DIL 1.603 SO .OIL DPHI.FDC 26.115 DRHO.FDC GR .~DC 117.938 TENS.CNL RTNR.CNL 3.560 RCFT.CNL CNTC.CNL 1,694.262 C~LI.CNL GR .CHL -999. ZSO DEPT. 7'~00.000 TENS.OIL ILD .DIL 2.4~. 3 SP .OIL DPHI.FDC ~T.SZO ~HO.FDC GR .FDC 110.438 TENS.CNL RTNR.CNL 3.455 RCFT.CNL CNTC.CNL 1837.749 C~L'I.CNL GR .CHL -99q.250 DEPT. 7300. 900 TSNS.DIL ILD.~n'L 3.-474 Sm, ..mil DPHI.FDC -999.250 DRHO.~DC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.25 O RCFT. CNL CNTC.CNL -999.250 C~LI.CNL 648¢. OCO -32.09~+ 0.004 648.4. 000 805.006 8,297 6752.000 -23.047 0.035 675 2. 000 569.279 8.414 6:620. 000 -34.125 0.076 6520. 000 70 9. 136 8. 6520.000 -21.625 0.048 6520.000 467.827 '9.008 6292.000 -8.836 0.013 6292. 000 616.377 8.336 622a.00o -17.391 o.0o9 6224.000 ~75.292 3.953 6284.000 -20.073 -999.250 -999.250 -399.Z50 -999.250 SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHO~.FDC NPHI.CNL RCNT.CNL GR .'CNL SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHO~.FDC NPHI.CNL RCNT.CNL GR .CNL S~LU.OIL GR .OIL RHDB.FDC NPHI.CNL RCNT.CNL GR .CNL 13.020 72.813 2.355 31.8:35 2~93.879 72.813 3.088 87.063 2.479 39.T37 2004.940 87.063 3. 083 113.063 2.550 32.387 2220.388 113. 063 2.40~ 112.938 2.400 40.518 1811.567 11!.938 1.697 117.938 2.252 46.168 1697.174 117.938 Z.617 110.438 2.361 41.291 1770.625 110.438 4.103 185.250 -999.250 -999.250 -999.250 -999.250 ILM .OIL TENS.FDC C ALI. FO C TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CAL,!.FOC TNRA.CNL CFTC.CNL' TENS.CHL ILM .OIL TENS .~OC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA .CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.mDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CaLI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TSNS.FDC CALI.FDC 'TNR~.CNL CFTC.CNL TENS.CHL 9. 497 648~.000 8.297 2.846 90 '7.318 -999.250 3.511 6752.000 8.416 3.304 681.626 -999.250 3.357 6620. 000 8.828 2.925 794.077 -999.250 :2.320 6520.000 9.008 3.395 545.530 -999.250 1.641 6292.000 8.336 3.648 467.712 -999.250 2.367 6226.000 8.953 3.433 532.454 -999.250 3.434 -999.Z50 -999.250 -999.250 -999.250 -999.250 IS TAP~ VERIFT .~C A'T ION LIST[NO 'HLUNBE~GER ALASKA COMPUTING 'CENTER GR .CHL -999.250 OEPT. T200.O00 TENS.OIL ILO .DIL 1.369 SP .OIL DPHI.~DC -999.250 ORHO..=DC GR .FDC -999.250 T=_NS. CNL RTNR.CNL --999.250 RCFT.CNL CNTC.CNL -999.250 C~LT.CNL GR .CHL -999.250 DEPT. 7100.000 TiENS.DIL ILD .DIL 2.228 SP .OIL DPHI.FDC '-999.Z50 DRHg. FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL -99'9.250 DEPT. TO00.O00 T~NS.DIL ILD .DIL 2.24'7 SP .OIL DPHI.~DC -999.250 D~HO.FOC GR .FDC -999.250 T~NS.CNL RTN~.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL -999.250 D~PT. 6900.000 TENS.OIL ILO .OIL 2-573 SP .OIL DPHI.FDC -999.250 DRHO.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C&LI.CNL GR .CHL -999.250 DEPT. 6800.000 TENS.D!L ILO .OIL 2.759 SP .DIL DPHI.~DC --999.250 DRHO.FDC GR .~DC -999.250 TENS.CNL RTNR.CNL -999.25'0 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL -999.250 DEPT. 6?Og. OOO TENS.OIL ILD .DIL 2.978 SP .git DPHI.FD£ -999.250 DRHO.~DC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CML -999.250 DEP'T. 6600. 000 TENS. git ILD .OIL 2.599 SP .Dlt DPHI FOC 'gq9 ~:;O DRHO ~O"' GR .FDC -99~.250 T'ENS.CNL RTNR.CNL -999. 353 RCFT.CNL '3-tU~-1988 14:]3,2 6600 .gOO -0.904 -999.250 -999.250 -99 '9.250 -999.250 SFLU .OIL GR .OIL RHOE.~DC NPHI.CNL RCNT .CNL G~ .CNL 6248.000 -10.336 -999.250 -999.250 -999.250 -'999.250 SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL G~ .CNL 6120.900 -15.438 -999.250 -999.250 -999.250 -999.250 SFLU.DIL GR .DIL RHOB. FDC NPHI .CNL RCNT .CNL G~ .CNL 6088.000 -20.625 -999.250 -999.250 -999.250 -999.250 SFLU.OIL GR .DIL RHOS.FDC NPHI.CNL RCNT .CNL GR .CNL 6208.000 -22.641 -999.250 -999.250 -999.250 -999.25 O SFLU.DIL GR .Oil RHOB.FOC NPHI .CNL RCNT.CNL GR .CNL -30.547 -999.250 -999.250 -~99.250 -999.250 SFLU.DIL GR .OIL RHOB.FOC NPHI.CNL RCNT.CNL GR .CNL 5672.000 -12.250 -999.250 '- ~99. 250 -999.250 SFLU.OIL GR .OIL RHO8.~DC NPHI.CNL RCNT.CNL 1.409 201.000 -999.250 -999.250 -999.250 -999.,250 2.199 96.313 -999.250 -999.250 -999.250 -999.250 2.329 97.8'75 -999.250 -999.250 - 999. ,Z 50 -999. 250 2.512 111-063 -999.350 -999.Z50 -999.250 -999.250 2.595 102.250 -999. 250 -999.250 -999. 250 -999.250 3.965 8¢.938 -999.250 -999.250 -999.250 -999.250 2.540 94.813 -999.250 -999.250 -999.250 ILM .OIL TENS.FDC C~LI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC C~LI.FDC 'TNR~ .CNL CFTC.CNL TENS .CML ILM .DIL TENS.FDC CaLI.FDC TNR~.CNL CFTr CNL TENS.CHL ILM .OIL TENS.FDC CALI.FOC TNR&.CNL C~TC.CNL TENS.CHL ILM .OIL TENS.~DC CALI.FDC TNRa .CNL C~TC.CNL TENS .CHL ILM .OIL TENS.FOC CALI. FDC TNRA.CNL C.cTC.CNL TENS.CHL ILM .OIL TENS.FDC C&LI.~DC TNR~.CNL C~TC .CNL P~GE: 1.507 -999.250 -999.250 -999.350 -999.250 -999.250 2. 268 -999.25:0 · -999. 250 -999.250 -99'9. 250 '-999.250 2.274 -999.250 -999.250 -999.250 -999.250 -999.250 2.524 -999.Z50 -999.250 -999.250 -999.250 -999.250 2.691 -999.250 -999.250 -999.250 -999.250 -999.250 3.008 -999.250 -999.250 -999.250 -999.250 -999.250 2.621 -999.250 -999.250 -999.250 -999.250 'S TAPE VER!~ICflTTON LISTING ~HLUMBERG~R ALASKA COMPUTINS CENTER 3-~UG-1988 14:32 PAGE: CNTC.CNL -999.250 C~LI.CNL GR .CHL -999.250 OEPT. 6500.000 TENS.OIL ILO .OIL 2.905 SP .OIL DPHI.FDC -999.250 DRHg. FDC GR .FgC -999.250 T~NS.CNL RTNR.CNL -!999.250 RCF'T.CNL CNTC. CNL -~9 g.]250 C ~L Z. CNL GR .CHL -999.250 DEPT. 6400.000 TENS.OIL ILO .DIL 2.954 SP .OIL DPHI.FDC -999.250 D~HO.~OC GR .~DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTCoCNL -~99.2SO CALZ.CNL GR .CHL DEPT. 6300.000 TENS.~IL ILO .~IL 2.659 SP .OIL DPHZ.FDC -999.250 gRHO.FDC GR .FD'C -999.250 T!ENS.CNL RTNR.CNL -999.250 RCFT.!CNL CNTC.CNL -999.~50 CAL!.CNL GR .CML -999.250 DEPT. 6ZO0.OOO TENS.DIL ILO .OIL Z..~8.¢ SP .OIL OPHI.FDC -99'9.250 DRHO. ~D,C GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL -999.250 DEPT. 6t00.000 TENS.OIL ILD .DIL 2.514 SD .OIL DPHI.FDC -999.250 DRHD.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -~99.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR.~rHL -999. 250 DEPT. 6000.000 TENS.OIL ILD .OIL 3.058 SD .DIL D~Hi =DC -999 ~50 DRHg CDr GR .FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~L~.CNL GR .CHL -999.250 DEPT. 5900.000 TSNS.DIL ILD .OIL 3.OB1 SD .Oil DPHI. FDC -.~9 9. Z50 D2HC. :DC 6~ .FDC -99~.250 TENS.CNL -999.250 56 ¢ 8.000 -19. ! 8'8 -999.250 -999,,,250 -99'9.250 -999.250 5564.000 -8.398 -'999.250 -999.250 -999.250 -999.250 5500.000 -12.633 -999.250 -999.250 -999.250 -999.250 5~6~.000 -10.055 -999.250 -999.250 -999.250 -999.250 -27.500 -999.250 -999.250 -999.250 -999.250 -15. 102 -999.250 -999.250 -999.~50 -999.250 5240.000 -21.766 -999.250 -999.250 GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHZ.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.~DC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.CDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NDHi.CNL RCNT.CNL GR .CNL S~LU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL .OIL RHOB.FDC NPHI.CNL -999. 250 2.360 109.313 -999.250 -999.250 -999.Z50 '-999.250 2.996 108.93~ -999. 250 --999.250 -999. 250 -999.250 2.978 101.063 -999.250 -999.250 -999.250 -99'9.250 2.581 93.688 -999.250 .-999.250 -999.250 -999.250 Z. 5lB 105.500 -999.250 -999. 250 -999. 250 -999. 250 z.gT8 Tg.375 -999.Z50 -999.250 -999.Z50 -999.250 3.096 BB.6B8 -999.250 -999.250 TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.CDC CALI.FOC TNRA.CNL CFTC.CNL TENS.CHL ILM .git TENS.FDC CALI.FDC TNR&.CNL CFTC.CNL TENS.CHL ItM .OIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL T~NS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.mDC CALI.FDC TNR&.CNL -999.250 2.842 -999.250 -999.250 -999.250 -'999.250 -999.250 2.964 -999.250 -999. 250 -9'99. 250 -999.250 - 9 9 9.2 5 0 2.656 -999..250 -999.250 -999.250 -999. Z50 -9gg. 250 2.~90 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 2.529 -999.Z50 -999.250 -999.250 -999.250 -999.250 3.042 -999.250 -999.250 -999.250 -999.Z50 -999.250 3.043 -999.Z50 -999.250 -999.250 IS TAPE VSRIFIC~TIgN LISTING ~HLUM~ERGER AL~.SKA COMPUTING CENTSR 3-AUG-1958 14:32 RTNR.CNL '-999.250 RCFT.CNL CNTC.CNL -999.250 CALI.CNL GR .CHL -999.250 DEPT. 5BOO.gOO TENS.gIL ILD .gl[ 2.867 SP .gll DPHI.FDC -999.2,50 D~HD.FDC GR .FDC -999.250 T'ENS.CNL RTNR.CNL -'999. 250 RCFT.CN[ CNTC.CNL -999.250 CILZ.CNL GR .CHL -999.250 DEPT. 5709.000 Ti~NS.OIL ILD .OIL ~-. ??.~ S? .gl[ DPHZ.FDC -999.2]5'0 GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C,a, kI. CNL GR .CHL -999.250 DEPT. 5600.000 TENS.OIL ILD .DIL 2.994 SP .OIL DOHI.FDC -999.250 g~HO.FDC GR .FDC -999.250 T~NS.CNL RTN~.CNL -'999.250 RCF'T.CNL CNTC.CNL -999.250 C~LI.CNL GR .CH[ -999.250 DEPT. 5500.000 TENS.DIL ILD .DIL 2.921 S~ .OIL DPHI.FDC -999.250 O~HO.:OC GR .FOC -999.~50 'T=_NS.CNL RTN~..CNL -"~99.,~50 RCFT.rNL CNTC.CNL -999,250 CALI.CN[ GR .CH[ -999.250 DEPT. 5400. 000 TENS.OIL ILD .DIL Z. ~'T 5 S° .DIL DPHI.FDC -999.259 9RHO.FDC GR .FDC -999.250 TENS.CNL RTN~.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 CAL~.CNL GR .CHL -999.Z~0 DEPT. 5300.000 TENS.DIL ILO .DIL 2.901 S? .OIL D'PH Z. FDC -999. 250 ORH9. FDC GR .FDC -999,250 T~NS,CNL RTN~,.CNL -999.250 ~CFT.CNL CNTC.CNL -999.250 C~LZ.CNL GR ,CHL -999.250 -999.250 -999.250 5220.000 -19.031 -999.250 -999.250 '-999.250 -999.250 5060. 000 -9.797 -999. 250 -~999.250 -999.250 -999.250 4880.000 -? .~88 -999.250 -999.250 -999.250 -99'9. 250 4TgZ.o00 -10.055 -999.Z50 -999.259 -999.250 -999.250 4~72.000 -2.777 -999.250 -999.250 -999.250 -999.250 4520.000 -5.266 -999.250 -999.250 -999.250 -999.250 RCNT .CNL GR .CNL SFLU.OIL GR .OIL RHO;B.FDC NPHI.CNL RCNT.CNL OR .CNL SFLU.DIL GR .git RHOB. FDC N~HI .CNL RCNT.CNL GR .CNL SFLU.OIL GR .DIL RHOB.~DC NPHI.CNL RCNToCNL GR .CN[ SFLU.OIL GR .OIL RHDB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .DIL RHOB.~DC NPH!.CNt qCNT.CNL GR .CNL -999.250 -999.250. 2.853 97.688 -999.250 -999. 250 -999.250 -999.250 2.426 85.375 -999.250 -999.250 -999.250 -999.250 3.116 93.813 -999.250 -999.250 -999.250 -999.250 3.882 100.938 -999.250 -999.250 -999.250 -999.259 2.958 90.813 -999.250 -999.250 -999.250 -999.250 2.733 80.313 -999.250 -999.250 -999.250 -999.250 CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNR~.CNL CFTCoCNL TENS.CH[ ILM .git TENS.FDC CALI.FDC TN~,A.CNL CFTC.CNL TENS,CHL ILM .OIL TENS,FDC ~CALI.FDC TNRA.CNL CFTC.CNL TENSoCHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL C~TC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC C~LI.mDC TNRAoCNL CFTC.CNL TENS.CHL -999.250 -999.250 2.830 -999.250 -999.250 -999.Z50 -999.250 -999.250 2.734 -999.250 -999.250 - 999.250 -999. 250 -999. 250 2.988 -999.250 -999.250 -999.250 -999.250 -999.250 2.858 -999.250 -999.250 -999.250 -999.250 -999.250 2.802 -999.250 -999.250 -999.350 -999.250 -999.250 2.828 -999.250 -999.250 -999.250 -999.250 -999.250 S TAPE VERIFIC,&TION LISTING HLUMBEDG ~R., ~LA SK,~, COMPUTItan'. ,~, ~, C~. NT ER,_ DEPT. ILO .OIL DPHI .FDC GR .FDC RTNR.CNL CNTC.CNL GR .CHL 5:~00.000 T~NS.DIL 3. IlO SP .OIL -999,259 DRHD,FDC -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 C,.~L,I,CNL .-999.250 OEP'T. ILD .OIL DPHI.FDC GR .FDC RTNR.CNL C N T C. C N L GR .CHh 5100.000 TENS.OIL 2.58:1 SP .OIL -999.250 DRHO.FDC -999.Z50 TENS.CNL -999.250 RCFT,CNL -99g, 250 C.~LZ, CNL -999.250 DEPT. ILO .OIL DPH!.FDC GR .FDC RTNR.CNL CNTC.CNL G R . C H L 5000.000 T~ENS.OIL Z. 985 SP .OIL -'999.250 DRHg.=gC -9'99. 250 TENS. CN1 -999.250 RCFT.CNL -999.250 CALI.CNL -999.250 DEPT. ILD .OIL DPHI .FDC GR .FDC RTNR.CNL CNTC.CNL GR . CHL 4900.000 T~NS.g~L 0.934 SP .OIL -999.250 DRHD.mDC -999.250 TENS.CNL -99'9.!50 RCFT.CNL -999.250 C~LI.CNL -'999.25 g DEPT. ILD .OIL DPHI.. FO"' GR .FOC R 'T N R. C N L CNTC.CNL GR .CHL 4300,000 TENS.OIL 2. ~01 SP .OIL -999.250 DRHO.FDC -'~99.250 TENS.CNL -~99.250 RCFT.CNL -99~ 2~0 C~LZ '~'N~ -999.250 DEPT. ILC .OIL DPHI.~OC GR .FDC RTNR .CNL CNTC.CNL GR .CHL 4700.000 TENS.OIL 3.224 SP .OIL - 99 9.250 DP, Hr]. FDC -9~9.~50 TENS.CNL -999.250 RC~T.CNL -~99.~_50 C~LI.CNL -999.250 DEPT. ILD .DIL DPHI.FDC GR .FDC RTNR.CNL CNTC.CNL GR .CHL 4600. 000 TENS. OIL 1.3e7 SP .91t -999.250 D~HO.FDC -999.250 TENS.CNL -999. 250 RCFT.CNL -999.250 C~LI.CNL -99 9.250 3-AUG-1988 1~:32 4504.000 -.6. 801 -999.250 -'99 9.25 O -999.250 -999.250 SFLU.DIL GR .OIL RHOB .FDC NPHI .CNL RCN'T.CNL GR .CNL 4392. 000 -6.~65 -999.250 -999.250 -999.250 -999.~50 SFLU.DIL GR .DIL RHDB.FDC NPHI .CNL RCNT.CNL GR .CNL -9.953 -999.25,9 -99 9. Z 50 -999.250 - 99 9 · 250 SFLU .OIL GR .OIL RHOB.FOC NPHI .CNL RCNT.CNL GR .CNL 4204.000 -6.816 -999.250 -999.250 -999.250 '-999.250 S~LU.OIL ~GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL 414~.000 0.282 -999.250 -999.250 -999.250 -999.250 S=LU.DIL GR .OIL RHOB.~DC NPHI .CNL RCNT .CNL GR .CNL 4144.000 -4.82~ -999.250 -:)99.250 -999.250 -999.250 SFLU.DIL GR .D'!L RHOB.FOC NPHI.CNL RCNT.CNL GR .CNL 3970.000 -0.106 -999.250 -~99.250 -999.259 -999.250 S~LU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL 3.108 86.000 -999.250 -999.250 -999.250 -999.250 2.431 88.18~ -999.250 -999.250 '-999.250 -999.250 2.893 90. 875 -999. 250 - 99 9. Z 50 -999.150 -999. 250 0.812 84.813 -999.250 -999.250 -999.250 -999.250 2.581 92.313 -999.250 -999.250 -999.250 -999.250 2.667 84.688 -999.259 -999.250 -999.250 -999.250 1.434 92.125 -99'9.250 -999.250 -999. 250 -999. 250 ILM .OIL TENS.FDC C~LI:.FOC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC C AL1. FDC TNRA.CNL CFTC.CNL T~NS.CHL ILM .OIL TENS.~DC CALI. FDC TNR~.CNL CFTC .CNL TENS.CHL ILM .OIL TENS.MDC CALI.FOC TNR~ .CNL CFTC.CNL TENS .CHL ILM .DIL TENS.FDC CALI.FDC TNR~ .CNL C~TC.CNL TENS .CHL ILM .OIL TENS.FDC CALI.FDC TNR&.CNL C~TC.CNL TENS.CHL ILM .OIL TENS.FDC C&L!.FDC 'TNRA,CNL CFTC.CNL TENS.CHL PAGE: 3.104 -999.250 -999.250 -999.250 -999.250 -999.25'0 2.504 -999.250 -999.250 -999.250 -999.250 -999.250 2.893 -999.250 -999.250 -999.250 -999.250 -999.250 0.920 -999.250 -999.250 -999.250 -999.250 -999.250 2.780 -999.250 -999.250 -999.250 -999.250 -999.250 2.878 -999.250 -999.250 -999.250 -999.250 -999.250 1.515 -999.Z50 -999.250 -999.250 -999.250 -999.250 ES TAPE V=RI~IC~T'ION,~ ~ LISTING, :HLUM~ERG~R ~LASK~ CfMPUTING CENTER 3-~UG-1988 14:32 PAGE: 10 DEPT. 4500.000 TENS.OIL ILO .OIL -999.250 SP .OIL DPHI.FDC -999.250 DRHO.~DC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT..CNL CNTC.CNL -999.250 CALZ.CNL GR .CHL 67.938 DEPT. 4,~00.000 TENS.OIL ILO .gIL -999.250 SP .OIL DPHI.~DC -999.750 DRHO.FDC GR .FDC -999.25:0 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL G~ .CHL 59.531 DEPT. 4300.000 TENS.OIL ILD .OIL -999.250 SP .OIL DPHI.FDC -999.250 DRHO.FDC GR .~DC -999.250 TENS.CNL RTN~.CNL '-'999.25;0 ~,CF'T. CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 47.,~13 DEPT. 4200.000 TENS.OIL ILD .OIL -999.250 SP .OIL DPHI.FDC -999.250 D~HO.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -99'9.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 4~.469 DEPT. 4100.000 TENS.OIL ILO .OIL -999.250 SP .OIL DPHI.FDC -999.250 DRHO.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 53.000 DEPT. 4000.009 TENS.OIL ILD .OIL -999.250 SP .OIL DPHI .FDC -999.~50 DRHO.FDC GR .FDC -999.~50 T~NS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~aLI.CNL GR .CHi 51.469 DEPT. 3900.000 TENS.Oil ILD git -999 250 SP DPHI.FDC -999.250 DRHO.FDC GR .FgC -999.~50 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.259 CALZ.CNL -999.250 -999.259 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 -999.250 -999.250 -999. 250 -999. ZED -999.250 -999.250 -999.250 -999. ,250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999. 250 -999.250 -999.~50 -999.250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOS.FDC NPHI.CNL RCNT,CNL GR -CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI .CNL RCNT.CNL GR .CNL SFLU .OIL GR .DIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. Z 50 -999.250 --999.250 -999.250 -999.259 -999.259 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ILM .DIL 'TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TfNS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL !LM .OIL TENS .FDC C~LI.FDC TNR~.CNL CFTC.CNL TENS.CHL !LM .OIL TENS.FDC CALI.FDC TNR~..CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL CcTC .CNL TENS .CHL ILM .DIL TENS.FDC CALI.FDC TNR~ .CNL CFTC.CNL TENS .CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL -999.250 -999.250 - 999.25:0 -999.250 -999. 250 3834.000 -999.250 -999.250 -999.250 -999.250 -999.250 3790.000 -999.250 -999.250 -'999.250 -999.250 -999.250 3700.000 -999.250 -999.250 -999.250 -999.250 -999.250 3610.000 -999.250 -999.250 -999.250 -999.250 -999.250 35B0.000 -999.250 -999.250 -999.250 -999.250 -999.~50 3484.000 -999.25D -999.250 -999.250 -999.250 -999.250 3414.000 IS T~PE V~ERIFIC~TION LISTING HLUM~ERGER ~LASKA ~MPUTING ,C~NTFR 3-~Ur~-1988 14:32 PAGE: II GR .CHL 5!5.87:5 DEPT. 3800.g00 TENS.OIL ILO .OIL -999.250 SP .OIL DPHI.FOC -999.250 O,OHg. FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RC~'T.CNL CNTC.CNL -999.250 CALI.CNL GR .CHL 54.188 DEPT. 3700.000 T~NS.DIL ILO .git -999.250 SP .OIL DPHI.FDC -'999.250 DRHQ.FDC GR .FDC -999.2.50 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 CALI.CNL GR .CHL 62.406 DEPT. 3600.000 TEN.S.DIL ILO .OIL -999.250 SP .OIL DPHi. FDC -'999.250 gRHO.FDC GR .FDC -999.250 TENS.CNL RTN'R.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 4.5.905 DEPT. 3500.000 TENS.OIL ILO .OIL -999.250 SP .OIL DPHI.FDC -999.250 ORHg. FDC GR .FDC -999.250 TENS.CNt RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.!50 C~LI.CNL GR .CHL 50.281 DEPT. 3400.000 TENS.OIL ILO .OIL -999.250 SP .OIL DPHi.FDC -999.250 DRHg. FDC GR .~DC -99~.250 TENS.CNL RTNR.CNL -999.250 RCF'T.CNL CNTC.CNL -999.250 CALI.CNL GR .CHL 47.963 DEPT. 3309.000 TENS.OIL ILD .OIL -990.250 SP .OIL DPHI.FDC -999.250 DRHO.~DC GR .FDC -q99.250 TEMS.CNL RTNR.CNL -)99.250 RCFT.CNL CNTC.CNL -9'99.250 CALI.CNL GR .CHL 54.469 DEPT. 3200.009 TENS.OIL ILO .git -)99.250 SP .OIL DPHI.FDC -999.250 gRHO.~gC GR .,..=DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -399.250 -999.250 -999.250 -999.~_50 -999.250 -999.250 -999.150 -999.250 -999.250 -999.250 -999.250 -999.250 SFL1J.DIL GP .DIL RHOB.FOC NPHI.CNL RCNT.CNL GR .CNL S'FLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NOHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHO5.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC NmHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHOB.FDC N~HI.CNL RCNT.CNL -999.250 -999.25'9 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 --999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 --993.250 -999.250 -999.250 -999.250 -999.250 -'999.250 -999.250 ILM .DIL TENS.FDC CALI.FDC ~TNRA,.CNL CFTC.CNL TENS.CHL ILM .OIL 'TENS.FDC C~LI.FDC TNRA .CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNRa.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.~DC C~LI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC C~LI.FgC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL -999.250 -999.250 -999.250 -999.250 -999.250 331~.000 -999.250 -999.250 -999.250 -999.250 -999.250 3244.000 -999.250 -999.250 -999.250 -999.250 -999.250 3224.000 -999.250 -999.250 -999.250 -999.250 -999.250 3170.000 -999.250 -999.250 -999.250 -999.250 -999.250 3044.000 -999.250 -999.250 -999.250 --999.250 -999.250 3010.000 -999.250 -999.250 -999.250 -999.250 -999.250 [.S TAPE VERIFIC~TT. gN LISTING "'HLUNBERGER ALASK~ COMPUTING CENTER 3-~UG-1988 lz,: 32 12 · CNTC.CNL -999.250 C&LI.CNL G~ .CHL 32.875 DEPT. 3100.000 TENS.OIL ILO .OIL -999.1250 SP .OIL DPHi.~DC -999.250 gRHD.FDC GR .FDC -999.250 TENS.CNL R'TN~. CNL -999.'9_50 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL g~ . CHL 42.719 DEPT. 300g. OOg TENS.OIL ILO .OIL -999. 250 S~' .DIL DPHI.FDC -999.250 DRHO.FDC GR .~DC -999.ZS0 TENS.CNL R'TNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LZ.CNL GR .CHL 37.219 DEP'T. Z900.OOg TENS.OIL ILD .DIL -999.250 SP .OIL DPH[oFDC -999.25'0 D~HO.FDC GR .FDC -999.250 TiENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 55.125 DEPT. Z80D.OO0 TENS.OIL ILD .OIL -999.250 SP .OIL DPHZoFDC -999.250 ORHO.FDC GR .FDC -999.250 T~NS.CNL RTNR.CNL -999.~50 RCFT.CNL CNTC.CNL -g99.250 C~LZ.CNL GR .CHL 40.719 DEPT. 2700.000 TENS.OiL ILD .OIL -'999.250 SP .31L DPHI.FDC -999.250 DRHO.FDC GR .~DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHi 31.391 DEPT. 2600.003 TENS.DIL ILO .OIL -99~.Z50 SP .OIL DPHI.~DC -99'9.250 DRHO.~DC GR .FDC -99~.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 32.$75 DEPT. 2500.000 TENS.OIL ILO .'OIL -999.250 SP .OIL DPHI.FOC -999.259 DRHO.=DC GR .FDC -~99.250 TENS.CNL -999.250 -999,250 -999.25D -999.250 -999,250 '-999.25O -99~.~5D -999.250 -999.250 -999.250 -'999. 250 -999,250 -'~9~. 250 -'999.250 -999,250 -999.250 '-999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. ZSO -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -99~. 250 -999.250 -999.250 -999.250 -999.250 -999.250 G~ .CNL SFLU.OIL GR .OIL RH05.~OC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR ..OIL RHO~.FDC NPHI .CNL RCNT.CNL G~ .CNL SFLU.DIL GR .OIL RHOS.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.DIL GR .OIL RHO~.FDC NPHI.CNL RCNT.CNL Gq .CNL SFLU.DIL G~ .DIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL - 999. Z 50 -999.250 -999,250 -999,250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.,250 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -~99.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.259 -999.250 -999.250 TENS .CHL ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC C~LI.FDC TNR~.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC C~LI.FDC TNRA.CNL CFTC.CNL T~NS.CHL ILM .OIL TENS.FDC CALI.FDC TNR~.CNL 2930.000 -999.250 -999.250 -999,250 -999.250 '-999,250 Z894,000 -999,250 -999.250 -999,250 -999.250 285~+. 000 -999.250 -999.250 -999,250 -999.25:0 -999,250 2794.000 -999,250 -999.250 -999.250 -999,250 -999.250 270¢.000 -999.250 -999.250 -999.250 -999.250 -999.250 267¢.000 -999.250 -999.250 -999.250 -999.250 -999.250 2670.000 -999.250 -999.250 -999,250 -999.250 TAPE VERZFIC&TZON LISTING 'HLUM~ERGER AL~SK:~ COMPUTING CENTER RTNR.CNL -999.259 RCFT.CNL CNTC.CNL -999.250 CALI.CNL G~ .CHL 35.594 DEPT,, 2400.000 TENS.OIL ILO .D!L -999.250 S° .glL DPHI.FDC -999.250 DRHD.FDC GR .FDC -999.]50 TENS.CN[ RTNR.CN[ -999.250 RCFT.CNL CNTC.CNL -999.250 CALI,.CNL GR .CHL ~6.0:00 DEPT. 2300.000 TENS.OIL ILO .OIL '-999,. 250 S:m .OIL DPHI.FDC -999.250 DRHO.:DC GR .FDC -999.~50 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 CALZ.CNL GR .CHL 37.250 DEPT. 2200.000 T!ENS.DIL ILD .OIL -'999.250 SP .DIL DPHI.FDC -999.250 DRHO.~DC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 CALI.CNL GR .CHL 40.938 DEPT. 2100.000 TENS.OIL ILO .OIL -999.250 SP .OIL DPHI.FDC '-999.250 DRHO.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFToCNL CNTCoCNL -999.250 C~Lt. CNL GR .CHL 32.531 DEPT. 2000.000 T~NS.DIL ILO .OIL -999.Z5~ S° .OIL gPHI.mDC -999.250 DRHO.FDC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.259 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 4Z.906 DEPT. 1900.g00 TY~NS.OIL ILO .OIL -999.250 S~ .OIL DPHI.FDC -999.]50 DRHO.~DC GR .=DC -999.~50 T~NS.CNL RT NR. CNL --999 . 250 RCFT. C NL CNTC.CNL -999.250 C~L'I.CNL GR oCHL 47.-525 3-AUG-ID88 14:32 -'999. 250 -999.250 RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 SFLU.DIL GR .OIL NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999. 250 -999.250 -999.259 SFLU.OIL GR .DIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 .-999.250 -999.250 -999.250 -999.250 .-999.250 S~LU.DIL GR .OIL RHOB.mDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -99 9.25 O -999.250 -999.250 -999.250 S:LU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -999.259 -999.250 SFLU.OIL GR .OIL RHOS.mDC NPHI.CNL RCNT.CNL GR .CNL -99'9. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999. 250 -999. 250 -999.250 -999.250 -999. 250 -999. 250 -999. 250 -999.250 -999.250 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999. 250 -999.250 -999.250 C F:'TC. C NL TENS.CHL !tM .OIL TENS .FDC C ALI. FDC TNR ~. C NL C~TC.CNL TENS .CHL ILM .DIL TENS. FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL !tM .OIL TENS.FDC C~LI.FDC TNRA.CNL CFTC.CNL TENSoCHL ILM .git TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL PAGE: .-999.Z50 ,2494.000 -999.250 -999.250 -999.250 -999.Z50 -999.250 2440.000 -999.250 -999.250 -999.250 -999.250 -999.250 2364.000 -'999.250 -999.250 -999.250 -999.250 -999.250 2280.000 -999.250 -999.250 -999.250 -999.250 -999.250 2174.000 -999.250 -999.250 -999.250 -999.250 -999.250 2100.000 -999.250 -999.250 -999.250 -999.250 -999.250 2015.000 13 £S TAPE VERIFICATION LISTING 'HLUM~ERGER AL~SK~ COMPUTING ,CENTER DEPT. 1800.000 T~NS.DIL ILO .OIL -999.250 SP .OIL OPH~.~OC -999.250 D:RHO. FDiC GR .FDC -999. 250 T~NS.CN[ RTN~.CN[ -999.250 RCFT.CNt CNTC.CNE -999.250 C~LI.CNL GR .CHL 42.906 DEPT. 1'700.000 TEN S.gI[ ILD .OIL -:~99. 250 SP .OIL DPHI.~DC --999.250 DRHO'~DC GR .FDC -999.250 T~NS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999,250 C~LZ.CNL GR .CHL 31.500 DEP'T. 1600.000 TENS.OIL ILO .git -999.250 SP .OIL DPHI.FDC -999.2.50 DP, HO. FDC GR .~FDC -999.250 TENS.CNL RTNR.CNL --999.250 RCFT.CNL CNTC.CNL -999.250 C&LI.CNL GR .CHL 4~.938 D EP'T. 1500. 000 T~NS.OIL ILO .OIL -999.250 SP .OIL DPHI.~DC --999.250 DRHO.:DC GR .FDC -99'~.250 TENS.CNL RTNR.CNL -999. 250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR .CHL 3¢.219 DEPT. 1~00.000 TENS.OIL ILO .OIL -'999.250 SP .OIL DPHI.FDC -999.250 DRHO.:DC GR .FDC -99c~.250 T~NS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.259 C~LI.CNL GR .CML 37.156 DEPT. 1300.000 TENS.OIL ILO .OIL -999.250 SP .OIL D~HI.FDC -999.250 DRHO.~DC GR .FDC -999.250 TENS.CNL RTNR.CNL -999.259 RCFT.CNL CNTC.CNL -999.250 C~[I.CNL GR .CHL 45.~3B DEFT. 1200.000 TENS.OIL ILO .OIL -999.250 Sm .OIL DPHI.FDC -999.250 ORHO.FDC GR .~DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.259 'C~LI.CNL GR .CHL 4~.656 3-~UG-~988 14:32 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 SFLU.OIL GR .OIL RHOE.FDC NPHZ.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 '-999.250 -99'9.250 -99'9.250 SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -99'9,259 -999.250 -999.250 SFLU.DIL GR .OIL RHOS.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SFLU.OIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 SFLU.DIL GR .OIL RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -999.250 -999.250 -999. 250 -999.250 -999.~50 -999.250 SFLU.DIL GR .OIL RHOB .FDC NPHI.CNL RCNT .CNL GR .CNL -99 9. 250 -999.250 -999.250 -999.250 -999. 250 -999.250 SFLU.OIL GR .Oil RHOB.FDC NPHI.CNL RCNT.CNL GR .CNL -'999.250 -999.250 -999.250 -999.25'0 -999.250 -999.250 -999.250 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999. 250 -999.250 '-999.250 -99'9.2.50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 "-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ILM .OIL TENS.FDC CALI.FDC TNRA.CNL C FTC. CN t TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA .CNL CFTC.CNL TENS.CHL ILM .OIL TENS.mDC CALI.FDC TNRA.CNL ~CFTC.CNL TENS.CHL ILM .DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL T:NS.CHL. ILM .OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL ILM .OIL TENS.FDC CALI.FDC TNR& .CNL C~TC.CNL TENS.CHL PAGE': --r999' 25,0 -999.250 -999.250 -999.250 -999.250 1965.000 -999.250 -99'9.250 -999.250 -999.250 -999.250 1900.000 -999.25'0 -999.250 -999.250 -999.250 -999.25'0 1860.000 -999.250 -999.250 -999.250 -999.250 -999.250 1800.000 -999.250 -999.250 -999.250 -999.250 -999.250 1735.000 -999.250 -999.250 -999.250 -999.250 -999.250 1690.000 -999.250 -999.250 -999.250 -999.250 -999.250 1625.000 14. ~S 'TAPE VERZFIC.~TION L'ISTZNG 'HLUMBERGER ALASKA COMPUTING CENTER 3-AUG-1988 14:32 PAGE: 15 DE P'T. 1100.000 TENS.OIL -999.250 SFEU.OIL -999.250 ILM .OIL ILD .OIL -999.250 S~ .OIL -999.250 GR .OIL -999.250 TENS.FDC DPHI-FDC -999.250 DRHO.~DC -999.250 RHOS.FDC -999.250 CALI.,~DC GR .FDC -999.250 T'ENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCF~T.CNL -999.250 RCNT.CNL ,-999.250 CFTC.CNL CNTC.CNL -999.250 CALZ.CNL -999.250 GR .CNL -999.250 TENS.CHL GR . CHL 50. DEPT. 1000.000 TENS.OIL -999.250 SFLU.DIL .-999. ~50 ILM .OIL ILO .DZL -999.250 SP .OIL -999.250 GR .OIL -999.250 TENS.FDC DPHI.FDC -:999.250 ORHO. ~DC -999.250 RHOB.FDC -999. 250 CALI.FDC GR .FDC -999.250 T!ENS.CNL -999. ID0 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -99'9.250 RCFT.CNL -999.250 RCNT.CNL -999.2.50 CFTC.CNL CNTC.CNL -999.250 C~LI.CNL -999.250 GR .CNL -999.250 TENS.CML GR .CHL 51.000 DEPT. 989.000 T!ENS.DIL -999.250 SFLU.gIL -999.250 ILM .OIL ILD .OIL -999.250 SP .OIL -999.250 GR .OIL -999.250 TENS.~DC DPHI.=DC -999.Z50 D~HO.~DC -999.250 RHOB.FDC -999.250 CALI.FDC GR .~DC -999.259 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.259 RCFT.CNL -999.250 RCNT.CNL -999-250 CFTC.CNL CNTC.CNL -999.250 CALI.CNL -999.250 GR .CNL '-999.250 TENS.CHL GR .CHL 5~..125 -999.250 -999.250 -999.Z5'0 -999.250 -999.250 1570.000 -999.250 -999.250 -999.250 -999.250 -999.250 1520.000 -999.250 -999.250 -999.250 -999.250 -999.250 1505.000 ~--~.-.- FZL=._ TR~ ~L=~- , ""~'*.----,- FILE NAME : EDIT -001 S;RVI'"E ' ,:LIC VERSION : 00~02 D,~TE : '~8/03/ 3 M~X REC SIZE ' 1024 FILE TYPE : LO LAST =ILE '""'"'-" FZ~ ~- H~DCR -'-"-""'" FILE NA~E : EDIT .OOZ SERVICE : ~=LIC VERSION : OOlAO2 DATE : '~J8/0,$/ _'3 MAX RFC SIZE : 10Z4 FILE TYPE : LO LAST FILE : ~-'"-'"" ~ H ! - - -,-.,.-.-~ T S D~TA Ha.S NOT B=EN DEPTH SHIFTED DVERLAYS FIELD PRINTS **~: IS TAPE VERIFICA'T!ON LISTING ~HLUMBERGER ALASKA COMPUTING CENTER 16 SCHLUMBERS~ER 'LOGS INCLUDED WITH THIS FILE (ED!'T.OO2): .... FDIT.OOl FOR. 6" S,&MPLEg DIL/FDC/CNL/GR DA'TA> ~Oq~e, TION DENSITY COMPENSATEO LOG (.F:DH) FIRST TO LAST R:ADING: 8118' TO 7]96' COMPENSATEO NEUTRON LOG (.CNH) FIRST Tg L~ST R:AOING'.. . ,9103' TO 7396' TABLE TYPE ' 'CONS TUNI CN FN WN N,~TI STAT COUN SECT TOWN RANg LAT'! LONG OPER SON ~IN 'VALU A~Cg .ALASKA~ INCo KUP~RUK 3 ~-7 U.S.A. ~LASK& NOR'TH SLOPE 2~ ! 3N 9E 8541 FNL 1917~ FWL M~LLARY 530B55 50-029-Z18~0 DEFI COMPANY N~ME FIELD N~M'E WELL NA~4E NATION STATE OR P~OVINCE C OU NT ¥ SECTION TOWNSHIP R,ANGE LATITUDE LDNGI TU~E OPE'R~TOR'S CODE SERVICE ORDER NUMBER ~PI SERIAL NUMBER TABLE TYPE : CURV DEFI DEPT 9E~TH CHANNEL N,~ME TENS D PHi DRHO RHC~ CALi GR TENS NPHi TNRA R 'T NR RCFT TENSION DENSITY POROSITY DELTA RHO BULK OENSITY CALIPER G~M~A R~Y TENSION NEUTRON POR']SITY C~LIB~,~TED THERMAL NEUTRON R4TID RAW TH~RM~,L N~U'TRON R~T~O RCFT 'S TAPE VERIFICATION'LISTiNG 'HLU~49, ERGiER ALASKA COMPU~TING CENTER 3-~UG-1988 I4:']2 17 OE~I RCNT RCNT CFTC CF:TC CNTC CNTC GR GAMMA RAY ,,-'~ DATA FORNAT SPEC'r~:IC AT'ION,,.. RECORD-"'"~-.~- SET 'TYPE - 6~.EB TYPE REPR CDgE V,~LUE I 66 0 2 66 0 3 73 64 4 ,66 1 8 ,68 O. 099 9 65 ~T 11 66 16 1 '3 66 0 1,4 6 5 ~ T 1 5 66 ,58 16 66 0 6.6 1 -~-,- SET TYPE - CHAN '~'~- NAME SERV UNIT SERVICE AP1 aP1 ~ml API mILE NUMB NUMB .SIZE REPR 19 ORDER ~ LOG TYPE CLASS MOD NUMB S&MP ELEM CODE DEP'T FT 530855 TENS FDH L~ 530855 DPHI :DH PU 530855 DRHD FDH G/C3 530855 RHOB FDH G/C3 530855 CALI FDH IN 530855 GR FDH G~PI 530855 TENS CNH LB 530855 NDHI CNH PU 530855 TNRA CNH 539855 R'TNR CNH 530855 RCFT CNH CPS 530955 RCNT CNH CPS CFTC CNH CPS 53~855 CNTC CNH CPS 530855 GR CNH g~PI 530855 PROCESS 2 1 I 4 68 2 1 1 4 68 2 1 I 4 6 8 2 1 I ,~ 6 8 2 I 1 4 68 2 1 I 4 68 2 1 1 4 68 2 1 1 4 68 2 1 1 4 68 2 1 1 4 68 2 1 1 4 68 2 1 1 4 68 2 1 1 4 6 8 2 1 1 4 68 2 1 1 4 68 2 1 1 4 6~ (HEX) 0000000000 O000OO0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TAPE VER'iF!C~,TZON LiS'TING 'HLUM3ERGER ALASKA COMPUTING CENTER DEPT. 8152.899 TENS.FDH RHOB.FDH 2.509 C~LI.FDH NPHI.CNH 45.672 TNRA.CNH RCNT.CNH 2065.668 CFTC.CNH DEPT. 8100.000 TENS.FDH RHO~.FDH 2.433 C~LI.FDH NPHI.CNH 3¢.~30 TNRA.CNH RCNT.CNH 1927.630 CFTC.CNH DEPT. 8000.000 TENS.=DH RHOB.mDH Z.402 CALI.~DH NPHI.CNH 47.001 TNRA.CNH RCNT.CNH 173'3.900 CFTC.CNH DEPT. 7900.000 TENS.~DH RHOS.FDH 2.352 CALI.=DH NPHI.CNH 30.701 TNRA.CNH RCNT.CNH 2498.~.66 CFTC.CNH DEPT. 7800.000 TENS.~OH RHOB.FDH 2.487 CALI.=OH NPHI.CNH 42.530 TNR~.CNH RCNT.CNH 2095.53~ CFTC.CNH DEPT. 7'700.000 TENS.:DH RHOB.FDH 2.495 C~LI.~DH NPHI.CNH 35.412 TNR~.CNH RCNT.CNH 1984.181 CFTC.CNH DEP'T. 7600.000 TENS.FDH RHOB.:DH 2.373 C~LI.FDH NPH~.CNH 39.870 TNR~.CNH RCNT.CNH 1909.$52 CFTC.CNH DEPT. 7500.000 TENS.FDH RHOB.FDH Z.ZT9 C~LI.FDH NPHI.CNH 47.I91 TNR&.CNH RCNT.CNH 1677.567 CFT'C.CNH DEPT. 7400.000 TENS.FDH RHOB.FDH 2.42~ C~LI.FDH NPHi.CNH 42.905 TNR~.CNH RCNT.CNH 1342.944 C;TC.CNH DEPT. 7395.800 TENS.~DH RHOB.FDH 2.315 CALI.FDH NPHI.CNH 4~.933 TNR~.CNH RCNT.CNH I~77.567 CFTC.CNH 3-AUG-1988 14:132 4.824.00'0 ;3.242 3.66~ 594. 901 ,673 2. O00 B. 445 3.038 589.773 672;B.000 8.289 3.690 552.243 6340.000 ~.195 ~,. 761 935.151 6660. DOD 8. 602 3. ~71 624.611 6644.00D 8.742 3.094 765.965 636~.000 8.930 3.353 633.972 6~6~.000 8.305 3.702 · %6 ~. 347 615~.000 ~.789 3.507 579.615 6224.900 ~. 703 :3. 611 473.963 DPHI.FDH GR .FDH RTNR.CNH 'CNTC.CNH OPHI.FDH Gq .FDH RTNR.CNH CNTC.CNH DPHI.FDH GR .FDH RTN~ .CNH CNTC.CNH OPHI.FDH GR .FDH RTNR.CNH CNTC.CNH DPHI.FOH GR .FDH RTNR.CNH CNTC.CNH DPHI.FDH GR .FDH RTNR.CNH CNTC.CNH DPHI.FDH GR .FDH RTN~.CNH CNTC.CNH DPHI.FDH GR .FDH RTNR.CNH CNTC.CNH D~HI.mDH GR .mDH RTNR.CNH CNTC.CNH DPHI.¢DH GR .mDH R'TNR.CNH CNTC.CNH 8.552 95.125 3.787 2150.905 13.143 94.188 3.179 2050.948 15.006 96.18:8 3.314 1906.000 18.0,49 74.688 2.872 2545.616 9.870 91.188 3.317 2060.562 9.391 115.125 2199. 231 16.815 106.750 3.671 2013.004 22.462 110.438 3.900 1726.09 ? 13.435 94.063 3.925 1'947.429 20.245 125.875 3.478 1749.815 D~HO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.~DH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR .CNH ORHO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.~DH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCF'T.CNH GR .CNH PAGE: 0.149 4824.000 537.392 95.125 0.035 6732.000 581.763 9,4.188 0.091 6728.000 534-623 96.188 0.031 6340.000 841.339 74.688 -0.033 6660.000 596.017 91.188 0.105 6444.000 703.288 115.125 0.061 6368.000 574.594 106.750 0.015 6268.000 401.440 110.433 0.067 5152.000 531.777 94.063 0.011 6224.000 446.267 126.875 18 END OF DATA TAPE VERIFICATION LISTING 'HLUM~,E~GER AL~.SK~ COMPUTIN~.S CENTER 3-AUG-1988 14:32 PA~E: 19 ~,~-~- FIL FILE NAME : EDIT .002 VERSION : 001A02 D~,TE : MAX REC SIZE : 1024 FILE 'TYPE : LO LAST FILE SERVICE NAM= ' :DI'T DATE : ~8/08! ORIGIN : ~t. IC TAPE NAME : C~gNTINU~TISN ~ : 1 PREVIOUS 'TAPE COMMENT : LIS TAPE, ARCO KUP~RUK 3 0-7~ API .~50-029-.21840 SERVICE NAME : EDIT DATE : 8~/08/ 3 ORIGIN : '~LIC R:EL NAME ' 72e60 CONTINUATION ~ : PREVIOUS ~EEL : COMMENT : LIS TAPE, .~RCD KUP~RUK ~ D-T~ API ~50-029-21B40
