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Home My WebLink About187-079MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-07 KUPARUK RIV UNIT 3H-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-07 50-103-20079-00-00 187-079-0 W SPT 5789 1870790 3000 2285 2288 2288 2286 720 980 980 980 REQVAR P Austin McLeod 6/1/2025 Two year to MAIP. AIO 2C.016. 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 3H-07 Inspection Date: Tubing OA Packer Depth 840 3300 3180 3160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602190822 BBL Pumped:4.2 BBL Returned:4 Thursday, July 24, 2025 Page 1 of 1            elevated OA pressure; already has TxIA communication (AIO 2C.016) -- jbr MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-07 KUPARUK RIV UNIT 3H-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3H-07 50-103-20079-00-00 187-079-0 W SPT 5789 1870790 3000 2541 2543 2542 2542 670 920 920 920 REQVAR P Brian Bixby 6/6/2023 MIT-IA as per AIO 2C.016 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 3H-07 Inspection Date: Tubing OA Packer Depth 900 3300 3190 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607094044 BBL Pumped:3.9 BBL Returned:3.8 Wednesday, July 26, 2023 Page 1 of 1           MEMORANDUM TO: JiM Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3H-07 KUPARUK RN UNIT 3H-07 Src: Inspector Reviewed By P.I. Supry -j4`' Comm Well Name KUPARUK RIV UNIT 31-1-07 API Well Number 50-103-20079-00-00 Inspector Name: Austin McLeod Permit Number: 187-079-0 Inspection Date: 11/28/2021 Insp Num: mitSAM21 L129092610 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-07 'Type Inj r w TVD 5789 Tubing 1691 - 1695 1693 1693 PTD 1870790 Type Test SPT' Test psi 3000 IA 770 3300 3140 3120 - BBL Pumped: 4 BBL Returned: 4 OA 440 _ 670 - 670 670 Interval REQvAR PIF P Notes: 2 year MITIA to MAIP. AIO 2C.016 v1 Monday, December 13, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, July 1, 2019 �p� �7I P.I. Supervisor .1\s-ry {l y/l SUBJECT: Mechanical Integrity Tests l l `l 1 ConocoPhillips Alaska, Inc. 311-07 FROM: Brian Bixby KUPARUK RIV UNIT 311-07 Petroleum Inspector See: Inspector Reviewed By: P.I. Supry IT-31L— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 31-1-07 Insp Num: mitBDB190619115025 Rel Insp Num: API Well Number 50-103-20079-00-00 Inspector Name: Brian Bixby Permit Number: 187-079-0 Inspection Date: 6/16/2019 ' Packer Depth Well 3x07 1Type lnj W1TV� - Tubing PTD 1370790 TYPe Testi sPT (Test psi 3000 IA BBL Pumped. 3? rBL Returned: 3.3 -. OA Interval REQVAR — _ 1P/ P Notes: MITIA to maximum anticipated injection pressure per A10 2C.016 ' Pretest Initial 15 Min 30 Min A5 Min 60 Min 97U '_90 I--0 31-0 040 '40 ^10 7710 Monday, July 1, 2019 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg6/ P.I.Supervisor el 4 t 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-07 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-07 Petroleum Inspector Src: Inspector Reviewed By: PP.I.5upry J „ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-07 API Well Number 50-103-20079-00-00 Inspector Name: Chuck Scheve Permit Number: 187-079-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605170327 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-07 - Type Inj W'TVD 5789 - Tubing 2827 2826 • 2827• 2827 PTD 1870790 Type Test SPT Test psi 3000 . IA 825 3470 , 3340 • 3310- BBL Pumped: 4 - BBL Returned: 4.1 - OA 400 440 440• 440 - Interval REQVAR P/F P ✓ Notes: Tested per AIO 2C.016 iG HI: Thursday,June 15,2017 Page 1 of 1 • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,September 28,2016 Jim Rpgg �e1 t71 13 J Co P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-07 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 5g-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-07 API Well Number 50-103-20079-00-00 Inspector Name: Chuck Scheve Permit Number: 187-079-0 Inspection Date: 9/26/2016 Insp Num: mitCS160927134743 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type InJ TVD 5789 Tubing 2709 -I 2737 - 2730 - 2724 — PTD 1870790 ;TypeSPT3000 IA Test Test psi 1140 3300 - 3200 - 3190 - Interval REQVAR 'P/F P OA 310 - 340 340 - 340 Notes: Tested per A1O 2C.016 SCANNED jS► 0 r 2G17 Wednesday,September 28,2016 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, February 16, 2015 7:33 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: FW: Kuparuk injector 3H-07 (PTD 187-079) Update 2/16/14 Attachments: image001.png; 3H-07 90 Day TIO plot.JPG; 3H-07.pdf Chris, The diagnostic monitor period on Kuparuk injector 3H-07 (PTD# 187-079) is coming to an end. The tubing and IA have maintained a substantial differential pressure and are showing no indicators of tubing by IA communication. At this point in time the well will be shut in for due to possible influence on an upcoming rig work over on a neighboring well. CPAI intends to apply for an AA for water injection only due to TxIA communication while injecting gas. The well will remain shut in until the AA process and the rig work over on the neighboring well has been completed. Please let me know if you have any questions or disagree with the plan. Attached are a 90 day T/I/O plot and a well bore schematic. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 AWELLS TEAM ConoociPhillips From: NSK Problem Well Supv nt: Sunday, June 29, 2014 8:43 AM To: a Chris D (DOA) Subject: RE: aruk injector 3H-07 (PTD 187-079) Update 6/29/14 Chris, Since the previous report on Kuparuk in • tor 3H-07 (PTD 187-079)the IA pressure has continued to increase and is suspected to be TxIA communication rather t : thermal. The well was shut in and freeze protected on 6/27/14, DHD then performed a passing MIT-IA on the following .. 6/28/14(see attached form). The plan forward would be to WAG the well to water with the •-lief that the well is experiencing TxIA on MI injection only. Unfortunately at the present time the water injection system . H pad is down for maintenance, with a startup date tentatively scheduled for September of 2014. Once 3H pad has wat- 'njection capabilities back online, CPAI intends to bring 3H-07 online, on water injection for a 30 day monitor/diagnos • eriod with the intent to apply for an AA for water injection only. The well will remain shut in until it is able to be brough nline on water injection. Attached are the MIT form and 90 day TIO trend. Please let Dusty or myself know if you have any questions or disagree with this plan. W W Ul 00 (n CI ri N w w a _ U _ U) O O W ,ll a I`-- N O. c p ur o 0 N et Q ,,,- .±- ti a v t a) z y W m 0 O O W O O tr N N- a tr U, w _ko t 0 0 W CV N M LE; od I^ ai L] J1 N- J O O }W } rn C) Ai6 op co0CO u 0 0 N0. o.;12u, I I I I W 71 a i l u, Lelu W d R ll \ L......___3 V) O u, u" a7 Sf-CP' 0 w m 0 7 E E O U R m 3 ' o C Z c a h . ,rci 0 x-- r-.. O O C C N > L L » = ao01Lc, M 1- I N 0. a f- `soy ea eu cu Z_ N M N N u, o ad le 13i011 07 -, es C uSd s, cn 0 W a KUP INJ 3H-07 ConocoPhiMips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) -Act Mint(ftKB) r r..,rdnawp, 501032007900 KUPARUK RIVER UNIT INJ 53.93 6,000.00 8,620.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3H-07.10/11/20143:44:06 PM SSSV:Locked Out Last WO: 42.40 10/3/1987 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,319.0 10/2/2014 Rev Reason:TAG lehallf 10/1/2014 .............................. HANGER,31 0 Casing Strings Casing Description OD(in) ID tel Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len p...Grade Top Thread r CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.2 3,572.2 3,032.6 36.00 J-55 BTC Casing Description -OD(in) ID(in) 'Top(ftKB) 'Set Depth(ft(B) Set Depth(TVD)...'VA/Len It...Grads Top Thread PRODUCTION 7 6276 35.0 8,609.9 6,199.9 26.00 J-55 BTC Tubing Strings - Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt)lhItt) Grade Top Connection CONDUCTOR,38.0-115.0- TUBING 1String 31/21 2.9921 31.01 8.05741 5837.7 9.30 J-55 I EUE8rdABMOD Completion Details Nominal ID Top(18K(B) Top(TVD((111(8) Top Incl(°) Item Des Com (in) 31.0 31.0 0.11 HANGER FMC GEN 4 HANGER 3.500 SAFETY VLV;1,703.2 1,7932 1,763.2 27.61 SAFETY VLV OTIS SERIES 10 SAFETY VALVE-LOCKED OUT 2.813 5/27/99 7,970.5 5,780.8 49.01 PBR BAKER PBR 2.992 7,984.2 5,789.8 49.00 PACKER BAKER FHL PACKER 2.992 GAS LIFT;2,701.2 8,023.6 5,815.7 49.15 NIPPLE CAMCO D NIPPLE NO GO 2.750 8.056.6 5.837.2 49 36 SOS CAMCO SHEAR OUT SUB 2.937 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (NOB) (3 Des i Com Run Date ID(in) 8,300.0 5,996.1 48.93 FISH FISH Flapper seat from surface line check valve- 12/17/1999 possibly lost downhole Perforations&Slots Shot SURFACE:35.24,572.2-A . Dons Top(TVD) Dim(TVD) (shots/1 Top(ftKB) Bite(MB) (ftKB) (lIMB) Zone Date t) Type Com 8,136.0 8,208.0 5,888.8 5,935.8 UNIT D,C-4, 5/10/1988 12.0 IPERF 60 deg.phasing;SQZD GAS LIFT;5,423.6 C-3,3H-07 &Cleaned Out;2 1/8" EnerJet 8219.0 8,239.0 5,943.0 5,956.1 A-2,3H-07 6/15/1997 4.0 RPERF 0 deg.phasing;2 1/8" EnerJet DP GAS LIFT:7.299 4 8219.0 8,239.0 5,943.0 5,956.1 A-2,3H-07 5/10/1988 8.0 IPERF 60 deg.phasing;2 1/8" EnerJet DP 8,270.0 8,290.0 5,976.4 5,989.6 A-1,3H-07 12/10/1987 1.0 APERF 120 deg.phasing;2 1/8" EnerJet DP 8,270.0 8,290.0 5,976.4 5,989.61 A-1,3H-07 6/15/1997 4.0 RPERF 0 deg.phasing;2 1/8" GAS LIFT:7.921.9 EnerJet DP Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Blm(kKB) (ftKB) (1100) Des I Start Date Com 8.136.0 8.208.0 5.888.8 5.935.8 CMT SQZ 2/8/1997 Mandrel Inserts FOR;7,970.5 ,a tl r*. on PACKER;7,084.2 N Top(TVD) Valve Latch Pon Size TRO Run ie Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn 1' 2,701.2 2,463.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/10/1987 2 5,423.6 4,192.2 CAMCO KBUG 1'GAS LIFT DMY BK 0.000 0.0-12/10/1987 NIPPLE;8.023.6 3 7,299.4 5,342.9 CAMCO KBUG 1 GAS LIFT 'DMY BK 0.000 0.0 12/10/1987 4 7,921.9 5,749.0 OTIS LBX 1 12'GAS LIFT 'DMY RM 0.000 0.0 12/21/1987 SOS;8,056.6 Notes:General&Safety • • End Date Annotation 91;2010 NOTE:View Schematic w/Alaska Schematic9.0 -- (PERF:8,130.04,208.0 RPERF;8,219.0-8,239.0 (PERF:8,219.0-0,239.0 RPERF;8,270.04,290.0, APERF;8,270.0-0,290.0 FISH;8,3000 PRODUCTION;35.04,609.9 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,January 16, 2015 4:12 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: Kuparuk injector 3H-07 (PTD 187-079) 1/16/15 Update of approved 30 day monitor period Attachments: image001.png; 3H-07 90 Day TIO plot.JPG; 3H-07 Schematic.pdf Chris, This email is to inform you that Kuparuk injector 3H-07 (PTD# 187-079)will be brought online to complete a 30 day monitor period while on water injection. The well was brought on water injection the 10th of September to start an approved 30 day monitor period but was shut in 15 days later due to operations request as a precaution to prepare for an upcoming rig work over on a nearby well. Because the original monitor period was cut short, CPAI was unable to prove or disprove integrity between the tubing and inner annulus while injecting water. It is CPAI's intentions to bring 3H-07 back on water injection and complete a 30 day monitor period with intent to apply for administrative approval for water injection only if TxIA integrity is proven. If at any time during the monitor period TxIA communication is confirmed the well will be shut in and a plan for corrective action will be formulated. Please inform us if you have any questions or disagree with this plan. Attached is a 90 day TIO plot and well bore schematic Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 illiWELLS TEAM SCANNED JAN 2 01:5 From: NSK Problem Well Supv Sent: Sunday, June 29, 2014 8:43 AM To: Wallace, Chris D (DOA) Subject: RE: Kuparuk injector 3H-07 (PTD 187-079) Update 6/29/14 Chris, Since the previous report on Kuparuk injector 3H-07 (PTD 187-079)the IA pressure has continued to increase and is suspected to be TxIA communication rather than thermal. The well was shut in and freeze protected on 6/27/14, DHD then performed a passing MIT-IA on the following day 6/28/14 (see attached form). The plan forward would be to WAG the well to water with the belief that the well is experiencing TxIA on MI injection only. Unfortunately at the present time the water injection system at 3H pad is down for maintenance, with a startup date tentatively scheduled for September of 2014. Once 3H pad has water injection capabilities back online, CPAI intends to bring 3H-07 online, on water injection for a 30 day monitor/diagnostic period with the intent to apply for an AA for water injection only. The well will remain shut in until it is able to be brought online on water injection. Attached are the MIT form and 90 day TIO trend. 1 Please let Dusty or myself know if you have any questions or disagree with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 From: NSK Problem Well Supv Sent: Wednesday, June 25, 2014 7:03 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Kuparuk injector 3H-07 (PTD 187-079) Chris, Kuparuk injector 3H-07 (PTD 187-079) is displaying an increase in IA and OA pressures, with multiple IA bleeds needed to stay within CPAI's Well Operating Guidelines. The well was brought on MI injection on 6/2/14 after being shut in for an extended period of 19 months. At this point in time the pressure increases are believed to be thermally induced, with some delayed thermal responses due to the cold-soaked well. However if communication does become suspected at a later date,these delayed thermal responses could be interpreted as signs of communication in retrospect. This pre-emptive report serves as communication that CPAI intends to monitor the well under heightened scrutiny for 30 days. If communication becomes suspected during this monitor period,we will inform the AOGCC at that time. When the well has stabilized, a State Witnessed MIT-IA will be scheduled as necessary. A follow up email will be provided at the end of the 30 day monitor period. Attached are the wellbore schematic and 90 day TIO trend. Please let Dusty or myself know if you have questions or disagree with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7126 Pager(907) 659-7000 pgr. 123 2 (uJ S + cc =- W - N U) c., a ui I11 Q U N O W s- 1:t N a LL o p N O a v o o x V W m N O W O ix n- a a t— in O W N F 61 O_ 1 J O J . f'i ., w t_ w A 6„5 P ., M fv — u. o c 0 0 0 0 0 0 0 0 t' I 1 I I 1 1 I t t _�% IL 11- L C v. • sr- - c a A 0 C R C CO - d - d iv C 7 E E O U ea a «. c 11 Q ar O 0 r C - 1 O N O N = OD /T cD 4 s f a. 0.1— 1Ot I ' E " ""d m tI d as 16 RI A o o 0 0 0 0 0 ., ., Vr." N _ 0 O O O O O O r o v0 a tr, o V, Odle vas _CP CO 5 M N N !Sd �} U) 0 uJ KUP INJ 3H-07 Conoc Phillips r' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(.) MO(ftKB) Act Btm(ftKB) r r.n..w1„Ilrp. 501032007900 KUPARUK RIVER UNIT INJ 53.93 6,000.00 8,620.0 ... Comment H25(ppm) Date Annotation End Date KB-Ord(B) -Rig Release Data 3H-07 10/11/20143:44:06 PM SSSV:Locked Out Last WO. 42.40 10/3/1987 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Data Last Tag:SLM 8,319.0 10/2/2014 Rev Reason:TAG lehallf 10/1/2014 HANGER.3/ �` = Casing Strings Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.2 3.572.2 3.032.6 36.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WILen(I...Grade Top Thread PRODUCTION 7 6.276 35.0 8,609.9 6,199.9 26.00 J-55 ETC M,,,._Tubing Strings Tubing Description !String Mu...lID(in) I Top(ftKB) !Set Depth(ft..f Set Depth(TVD)(...I Wt(11y/ft) (Grade Top Connection CONDUCTOR;38.0.115.0 ' TUBING 31/2 2.992 31.0 8.05741 5.837.7 9.30 J-55 I EUE8rdABMOD Completion Details 'Nominal ID Top(ftKB) Top(TVD)(MB) Top not(") Item Das Can (in) 31.0 31.0 0.11 HANGER FMC GEN 4 HANGER 3.500 SAFETY VLV;1,703.2 T 1.793.2 1,763.2 27.61 SAFETY VLV OTIS SERIES 10 SAFETY VALVE-LOCKED OUT 5/27/99 2.813 7,970.5 5,780.8 49.01 PBR BAKER PBR ' 2.992 7,984.2 5,789.8 49.00 PACKER BAKER FHL PACKER 2.992 GAS LIFT;2,701.2 8,023.6 5,815.7 49.15 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,056.6 5,837.2 49.36 SOS CAMCO SHEAR OUT SUB 2.937 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) I') Des Com Run Date ID(in) 8.300.0' 5,996.1 48.93 FISH FISH Flapper seat from surface line check valve- 12/17/1999 possibly lost downhole Perforations&Slots Shot SURFACE;35.24.572.2-• • Dens Top(TVD) Ben(TVD) (ahotsx Top(ftKB) Btm((KB) ((1KB) (ftKB) Zona Date ti Type Com 8,136.0 8,208.0 5,888.8 5,935.8 UNIT D,C-4, 5/10/1988 12.0 IPERF 60 deg.phasing;SCUD GAS LIFT;6,423.0 C-3,3H-07 8 Cleaned Out;2 1/8" EnerJet 8219.0 8,239.0 5,943.0 5,956.1 A-2,3H-07 6/15/1997 4.0 RPERF 0 deg.phasing;2 1/8" EnerJet DP GAS LIFT. zee a 8,219.0 8,239.0 5,943.0 5,956.1 A-2,3H-07 5/10/1988 8.0 IPERF 60 deg.phasing;2 1/8" GAS LIFT/.7.9,v EnerJet DP 8,270.0 8,290.0 5,976.4 5,989.6 A-1,3H-07 12/10/1987 1.0 APERF 120 deg.phasing;2 1/8" EnerJet DP . 8,270.0 8,290.0 5,976.4 5,989.6 A-1,3H-07 6/15/1997 4.0 RPERF 0 deg.phasing;21/8" EnerJet DP Cement Squeezes Top(ND) Blm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 8.136.0 8.208.0 5,888.8 5,935.8 CMT SQZ 2/8/1997 • r --• Mandrel Inserts PBR;7070.5 _- St ati s on Top(TVD) Valve Latch Port Size TRO Run PACKER;7,684.2 N Top(ftKB) (ftKB) Make Medal OD Sarn T lint Type type (in) (psi) Run Date Corn 1' 2,701.2 2,463.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/10/1987 2 5,423.6 4,192.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/10/1987 NIPPLE;8,023 8 3 7,299.4 5,342.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/10/1987 4 7,921.9 5,749.0 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 12/21/1987 SOS;8,0588 Notes:General&Safety End Date Annotation 9/1/2010 NOTE:View Schematic wl Alaska Schematic9.0 (PERF;8,138.0-0,208.0-p RPERF;8.219.0-8,239.0 • (PERF;8,219.0.8,239. RPERF;8,270.0-0,260.0 APERF:8:RF .- FISH;0,300.0tilb PRODUCTION,35.0-8,609 9 ~ ConocoP ' ' h~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~ i ~.$~ ; ~~ ~ ,;~ F~ `'~' %' ~~ j'~ .., .. ~..°~ Dear Mr. Maunder: ~ ~~~-~`~9 ~~~ 07 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treahnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~" ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 3G 3H 3K & 3Q Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n!a 17" n/a 5.52 8/8l2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 818/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.82 8/9J2009 3H-15 50103200820000 1871030 19" n/a 19" , n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" Na 1.27 8!9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" Na 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 ~ MEMORANDUM To: Jim Regg ~~~~ 7~~~(Q~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska A(aska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 5UBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-07 KUPARUK RN LTNIT 3H-07 Src: Inspector NON-CONFIDENTIAL Reviewed By~. P.I. Suprv ~2- Comm Well Name: KUPARUK RIV L1NIT 3H-07 Insp Num: mitCS090608145034 Rel Insp Num: API Well Number: 50-103-20079-00-00 Permit Number: 187-079-0 Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~ ~,e~j T sx-o~ Type Inj. N TVD s~s9 IA iooo zi6o ~ zioo T zioo ~ P.T.D~ 1870790 TypeTest SPT Test psi I500 QA 400 420 420 420 Interval a~TST p~ r ' Tubing i2oo i2oo i2oo izoo NOtes' Pretest pressures observed and found stable. Injection shut in recently, well still in warm condition. ~ 4~"di`~~-, ;~, ii r~t4l~; . .. . . . _. ~ Wednesday, June 1Q 2009 Page 1 of 1 MEMORANDUM TO: Jim ReggD ~I I P.I. Supervisor !'-.é¿f1- . ~·tt~: ,(:)(; i. '. FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV UNIT 3H-07 Insp Num: mitJCr060613123158 Rei Insp Num Packer -----------...-r=-------..,-... I ---.. Well 1_ 3H-07 ¡Type Inj. i W , TVD ~!.:__~~~0790..ITypeTest i SPT.! Test psi Interval 4~TST P/F P Notes 1.5 bbl's pumped for test. Wednesday, June 14,2006 ') State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA. INC 3H-07 KUPARUK RIV UNIT 3H-07 Src: Inspector NON-CONFIDENTIAL API Well Number 50-103-20079-00-00 Permit Number: 187-079-0 Depth 5790 1500 "\, ö1Q \~ , Reviewed By: P.I. Suprv ...J15.íZ- Comm Inspector Name: John Crisp Inspection Date: 6/10/2006 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. r---..-,---=-=----r----..--··-,----···-·'··------,--·-..--------¡------- , IA I 550 ; 1730 I 1690 1690 i I : OA 1--\õO----: 100 I 100 T-·--ïõo--¡-·---f----- TUbing! _ 22oo~_I---~2200 T2200¡~ 2200 ~~.-- +.~--- SCi\NNED .JUN 2 l1' 2D06 Page 1 of 1 Schlumberger ¡. ,~' ~ ~,1:;_ ~ l Schlumberger -DCS 2525 Gambell Street, Suite 40~ \_ Anchorage, AK 99503-2~t'"rX\~f~!':J ATTN: Beth Well 1B-17 IQ4-045" 1 E-36 198-r:21.~ 3H-07 IB7- 07'/ 3H-07 ,I /, 2A-09 fPJIo-ml 1A-10 /8/- /ÚJO 2M-14 Jéì,;}- /JI(J~ 1E-05 19f"r/)5P. 2H-12 /PfS-:J{¡;':J. 1 C-21 3G-18 /q()- / /)S' 1 E-119 2U-13 /64-;l't& 1 Y -09 18.~- f"h1 1 E-1 05 2C-08 /B-:z,-oc¡~ 2C-02 ¡R7¡- 093 1 C-25 / qq -031 2C-141f34·';¡rD 2C-10 1!!3.f-:J/t 1A-18 1%- 5.~ 2C-01 IB!;- DB? 10-32 !J()()-/7.;:l., 2C-12 /84-,x(o 2C-15 184· ~3 1J-154 1 E-1 04 Job # 11216283 11216282 11217023 11166757 11154126 11213710 11154127 11166747 11154128 11154131 11154129 11217025 11166753 11213128 11162832 11141255 11213129 11144074 11166759 11144067 11144070 11213709 11141252 11141260 11141254 NIA 11217024 c~ [-7' t. l FEB 22 2006 ~ "'''' ,.Ivìl~. v,)liHH1:>SIOI, ?JlcOOf~e Log Description SBHP SURVEY SBHP SURVEY LDL STATIC SURVEY PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT/GHOST PRODUCTION PROFILE WIDEFT INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE MEMORY INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE GLS PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION LOG WITRACTOR INJECTION PROFILE 02/21/06 NO. 3691 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk e Date BL Color CD 02/18/06 1 02/18/06 1 02/11/06 1 01/20/06 1 02/09/06 1 02/08/06 1 02/10/06 1 12/25/05 1 02/11/06 1 02/14/06 1 02/12/06 1 02/13/06 1 01/14/06 1 02/06/06 1 01/28/06 1 e 01/28/06 1 02/07/06 1 02/02/06 1 01/25/06 1 01/26/06 1 01/29/06 1 02/07/06 1 01/25/06 1 02/02/06 1 01127106 1 02/05/06 1 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address orfax to'(907) 561-8317. Thank you. ~~ Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN' Beth NO. 2967 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 O9/25/O3 Field: Kuparuk Well Job # Log Description Date BL Color CD 2X-14 '1.~/~' i ~ PROD PROFILE/DEFT 09/01/03 2A-24 !q~- I £~-'~ PROD PROFILE 09/02/03 3F-15 1.<~:~--~ "~ INJECTION PROFILE 09/05103 ~s-~ I,~ ~~ ~.~c~'o" ~.o~,~ o~o~o~ 3S-09 ~ ~,~~ INJECTION PROFILE 08/02/03 3H-07 ~ ~ ~-~'~ INJECTION PROFILE 08/06/03 su.v ~D-~03 ~ %~ ~NJECT~ON P.OF~L~ 0S/~0/03 ~C-~7~ .~3-~~ ~NJECT~ON P.OF~LE 08/~3/03 ~B-~02 ~G~- 23~32 'US~T 0S/~/03 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~ ~ DATE: June 27, 2002 Chair -,~? SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska Inc. P.I. Supervisor''~' "'l I \~G'~~ '~ 3H multiple FROM: John H. Spaulding KRU Petroleum Inspector Kupamk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WeilI 3H-02 I Typelnj. i N I T:V.D.'I 5759 I Tub,'ngl 750 i oo"'1 ~00 i ~00 I lntervall 4" .P.:r.D~I 1871070,TYi~etesti . Pi'.' IT,estpsil' 144,.0 .i C, as~in011. ~22'~',1 2100'1 20751 2075 '1 PIE '1 P' i ~otes,: Well is currently shUt in ...................... i we,,! 3H~ I Type,nj.I G I T.V.D.I ~ JTubingl145° I 1350 j1350 j1350 I,nte~va, J 4 i,,,P'.T.D.I 187078o ITypetes'tl 'P ITestPsil, 1449 i,ca~ia.~'I '1,0,25 i ,2~50 i '2050 i 2025'1 'PiE I _P Notes: .. W.e"! 3H-07 I mype~nJ.'l G I T.V'.D. ! 57901Tubingl 31501 ~i551 3150' I' 3150 'l~;;terVa~l 4 ..p.m.D.I 1870790 I.fYpe{estl P ITestPsil' 1448 I casingI 2~50I 19501 19501 l'bSb I 'P/F I -P Notes: Draw down was performed versus pressure build up ' We, l' 3H-0J)"lT'yPe~nj.'l' "~S' I T.V. Di I ~72'~ 'l Tubing]' 36001 3600'! 3600 'l 3600 ]~nterval] 4 P.T.DiI 187~120 I.,TYpetestl P ITes.tPsi'!''' ~3.~",! ,C~.~,ngl' .~55 I ~so .j.'2750 I ;~750 I PiF'l _P Notes: ', ~ve, I ~,-~ I~ype~.i.! 'G' I~.V.D. I SS~S I%~'~"gi 3'~00 I"~00 I ~00 I ~oO I~hterv~;~I 4" ..... P:.T'D-I '~871290 I~rypetestl''', . . P'. IT'eStpSil ~470"1 ~:aSing I '~850', I',. 3300., 1'3300 I :~275 I P/F'I _P Notes: Type INJ. Fluid Codes F = FRESH WATER 1NJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 1 of 3 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 Vadance 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: 3 hrs. CC: none MIT report form 5/12/00 L.G. mit(l) kru 3h 6-27-02js.xls 7/16/2002 STATE OF ALASKA AL/-,~,~,A OIL AND GAS CONSERVATION COMMI,~,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well 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 X 4. Location of well at surface 1397' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1229' FSL, 1400' FWL, Sec. 12, T12N, R8E, UM At effective depth 1013' FSL, 1202' FWL, Sec. 12, T12N, R8E, UM At total depth 959' FSL, 1153' FWL, Sec. 12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 862O 6206 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-07 9. Permit number/approval number 87-? -7 10. APl number 50 - 103-20079-00 1 1. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 8 5 2 3 true vertical 61 42 feet Junk (measured) None feet Casing Length Structural Conductor 8 0' Surface 3 5 3 4' Intermediate Production 8575' Liner Perforation depth: measured 8136'-8208', true vertical 5888'-5935', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 8057' Packers and SSSV (type and measured depth) Pkr: Size 16" 9-5/8" 7" Cemented Measured depth 228 Sx AS I 1 1 5' 1100 Sx AS III & 3572' 500 Sx Class G, Top Job 60 Sx AS I 300 Sx Class G & 8 61 0' 175 Sx CS I 8270'-8290' 5976'-5989' 8219'-8239', 5942'-5955', ,Baker "FH" @ 7984'; SSSV: Otis Series 10 @ 1793' True vertical depth 115' 3023' 6199' RECEIVED 13. 14. Stimulation or cement squeeze summary Reperforate "A" sands on 6/15/97. Intervals treated (measured) 0RI$1NA 8219'-8239', 8270'-8290' Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns w/ DP charges at 4 SPF, fp was 1600 psi. NOV 24 199i LNaska 011 & Gas Cons, Commission Anchorage Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 5522 325 2666 Subsequent to operation 0 0 5858 325 27OO 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service 17. I hereby,~tify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Wells Superintendent Form 1Of0~ I~'v ~6/15/8~,) Date /f-'Z~' ~'~ ~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. .UPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3H-07(W4-6)) WELL JOB SCOPE JOB NUMBER 3H-07 PERFORATE, PERF SUPPORT 0614971910.4 DATE DAILY WORK UNIT NUMBER 06/15/97 PERFORATE, PERF SUPPORT 8345 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O No (~ Yes (~ No SWS-YON JORDAN FIELD AFC# CC~ DAILY COST ACCUM COST Signed ESTIMATE KAWWRK 230DS36H L $14,563 $14,563 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1600 PSI 1600 PSI 0 PSI 0 PSII 325 PSII 325 PSI DALLY SUMMARY I REPERFORATED A SAND' INTERVALS 8219"8239' & 8270"8290' ' 2 1/8" ENERJET DP - 4 JSPF' 0 PHASING ' 0 DEG FROM LOW ISIDE TIME LOG ENTRY 08:00 MIRU SWS UNIT #8345 - C. YON - PT BOP & LUBRICATOR 3500 PSI - O.K. 11:00 RIH W/20' 2 1/8" ENERJET-MPD-CCL - 4 JSPF DP TO 8350' TIED-IN TO SCHLUMBERGER PL LOG - SHOT INT. 8270'-8290' 0 DEG FROM LOW SIDE POOH - ON SURFACE ALL SHOTS CONFIRMED FIRED 14:40 RIH W/20'2 1/8" ENERJET-MPD-CCL - 4 JSPF DP TO 8350' FOR 2ND GUN RUN HUNG UP MOMENTARILY @ 8219'-8239' - TIE-IN - SHOT POOH - ON SURFACE MISFIRE CONFIRMED - DET CORD DAMAGED 17:40 RIH W/20' 2 1/8" ENERJET-MPD-CCL - 4JSPF DP TO 8350' FOR 3RD GUN RUN TIED-IN TO SHORT JOINTS @ 8284'-8304'- SHOT POOH - ON SURFACE ALL SHOTS CONFIRMED FIRED. 21:00 RDMO SWS - RETURN WELL TO INJECTION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $500.00 $500.00 SCHLUMBERGER $14,064.00 $14,064.00 TOTAL FIELD ESTIMATE $1 4,564.00 $1 4,564.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS0 Stimulate Plugging Perforate 1. Type of Request: Pull tubing Operation Shutdown Alter casing Repair well Pull tubing _ Other X to WI 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 5. Type of Well: Development _ Exploratory _ Stratigraphic _ 99510 Service X W I 1397' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1229' FSL, 1400' FWL, Sec. 11, T12N, R8E, UM At effective depth 1014' FSL, 1202' FWL, Sec. 11, T12N, R8E, UM At total depth 959' FSL, 1153' FWL, Sec. 11, T12N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 8620' feet 6 2 0 6' feet 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-07 9.. Permit number/approval number ~8-724 10. ~API number feet so-103-20079 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Cement: 8523'-8620 Effective depth: measured 8 5 2 3' true vertical 6142' feet feet Junk (measured) None Casing Length Structural Conductor 80' Surface 3537' Intermediate Production 8 5 7 5' Liner Perforation depth: measured 8136'-8208° 12 SPF 8270'-8290' 1 SPF true vertical Size Cemented 1 6" 9 5/8" ,, Measured depth True vertical depth 228 Sx AS I 1 15' 1100 Sx AS III & 3572' 500 Sx Class G top Job w/60 Sx AS I 300 Sx Class "G" 7 6 6 8' 175 Sx CS I 60 degree phasing, 8219'-8239' 120 degree phasing 5888'-5935', 5942'-5955', 5976'-5989' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55, set at 8057' Packers and SSSV (type and measured depth) Baker FHL Packer @ 7984', Otis Series 10 SSSV @ 1793' 13. Stimulation or cement squeeze summary 115' 3032' 6198' Intervals treated (measured) 8 SPF 60 degree phasing RECEIVED Alaska .Oil & Gas Cons. C0mm/ssi0r~ Well was converted from oil producer to water injector. Producer and MIT record are attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1050 2800 0 440 psi 160 psi Subsequent to operation 0 0 - 8 3 6 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil __ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 600 psi 1860 psi Service Water Injector ~qCO Alaska, . SuDsidiary of Atlantic Richfield Corn 3/C/_ 7 iPBDT CONTRACTOR ,4.?C -' REMARKS tFIELD - DISTRICT, STATE OPERATION AT REPORT TIME WELL SERVICE REPOF IDAYS ? DATE ,//-/,~- /3o0 ECE,I FED Gas Cons. c,~,,._. [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ] Temp. °F Chill FactoraFlJ~ Visibility miles llWind Vel, knots REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision ANC Pre-Job Safety Meeting TOTAL FIELD ESTIMATE Signed !1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program,~ Pull tubing _ Variance 2. Name of Operator '~15. Type of Well: I Development X ARCO Alaska, In(;. I Exploratory _ 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 I Service 4. Location of well at surface 1397' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1229' FSL, 1400' FWL, Sec. 11, T12N, R8E, UM At effective depth 1014' FSL, 1202' FWL, Sec. 11, T12N, R8E, UM At total depth 959' FSL, 1153' FWL, Sec. 11, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-7 9. Permit number 87-79 10. APl number ,~0-103-2007~) feet 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8620' feet Plugs (measured) 6206' feet Cement: 8523'-8620' Effective depth: measured true vertical 8523' feet Junk (measured) 614 2' feet None Casing Structural RlJrfn~ Intermediate Produotio~ Liner Perforation depth: 8136'-8208' 8270'-8290' Length 80' 3537' 8575' measured 12 SPF 1 SPF true vertical Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 228 Sx AS I 1 15' 1100SxAS III & 3572' 500 Sx Class G Top Job w/60 Sx AS I 300 Sx Class G & 7 6 6 8' 175 Sx CS I 60 degree phasing, 8219'-8239' 120 degree phasing 5888'-5935', 5942'-5955', Tubing (size, grade, and measured depth 3 1/2", J-55, set at 8057' Packers and SSSV (type and measured depth) Baker FHL Packer @ 7984', Otis Series 10 SSSV @ 1793' 115' 3O32' 6198' 8 SPF 5976'-5989' 60 degree phasing TVD 13. Attachments Description summary of proposal Convert well from oil producer to water injector. 14. Estimated date for commencing operation Sept~mbf~r, 1988 16. If proposal was verbally approved Name of approver Date approved _ Detailed operation program ..X. (Wellbore schematic attached). 15. Status of well classification as: Oil Gas BOP sketch Service Water Iniector Suspended 17. I hereby ce_..rtify that the foregoing ~s true and correct to the best of my knowledge. Signed (.~%/v-~ Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test w Location clearance Mechanical Integrity Test ~ ..Subsequent,~form require 10- Approved by the order of the Commissioner,... "/'~,~...,~....? [, f..,~ Commissioner For ~./ / xj m 10-403 Rev 06/15/88 ' , .~pproved Copy ~/~, turned IApprov,~ No..~ . / Date ¢ '- "Z -'7__ ~ b"g SUBMIT IN TRIPLICATE Well 3H-07 Conversion to Water Injection 1. The proposed procedure is attached. , No BOPE will be necessary to convert the well to water injection service. , The static bottomhole pressure will be acquired by taking a WHP/FL prior to the well's conversion. The reservoir pressure is estimated to be 2700 psi based on the producing GOR. 4. No workover fluid will be used. 3H WATERFLOOD CONVERSIONS GENERAL PROCEDURE , . . . Obtain final 12 hour well test. Check to insure that the sundry notice for converting the well to water injection has been approved by the State (Erin: ext. 6523). SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2" meter runs, and calibrate instrumentation. Notify the State of the upcoming Mechanical Integrity Test. After 72 hour shut in, contact Engineering (ext. 7525) to record wellhead pressure and shoot tubing fluid level. Conduct MIT. Packer depths and required 7" annular pressures are shown in the table below. Bleed the annulus to 500 psi after completing the test. Send a copy of the WSR and the State's MIT form to S. Twiggs at ATO 1130. WELL 3H-07 3H-09 3H-12 3H-22 DEPTH (TVD) OF PACKER 5789' 5727' 5877' 595 O' REQUIRED CSG PRESSURE FOR MIT (PSI) 2084 2062 2115 2142 . The targeted injection rates and estimated set pressures are summarized below. After the initial trial, modify the injection set pressure to more closely match the desired rates (+/- 500 BPD is fine). WELL 3H-07 3H-09 3H-12 31-1-22 DESIRED INITIAL INJECTION RATE (BWPD) 5000 7000 5000 3000 ESTIMATED SET PRESSURE (PSI) 1 200 1 200 1500 1 500 . The above set pressures and rates will apply only until the STP begins winter time operation. Then the injection rates will be increased. ARCO Alaska Inc, is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A WELL 3H-07 SURFACE LOCATION' 1397'FNL, 281'FWL, SEC 12, T12N, R8E, UM TREE: FMC 3-1/8" 5000 PSI APl #: 5010320079 DEPTHS: REFERENCED TO 0' RKB REVISION: 9/9/88 TUBING SPOOL ELEV: 31' RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3572' PBR: BAKER 2.992" ID @ 7970' PKR: BAKER FHL 2.992" ID @ 7984' NOGO: CAMCO 'D' NIPPLE 2.75" ID @ 8024' SHEAR OUT: 2.937" ID @ 8056' C A2 A1 7": 26# J-55 @ 8610' L SSSV · OTIS SERIES 10 ID 2.813" @1793' GLMI: 2701' / 1.0" GLM2: 5424' / 1.0" GLM3: 7299' / 1.0" GLM4: 7922' / 1.5" MAX HOLE ANGLE = 54° AT 6100' MD HOLE ANGLE ACROSS KUPARUK = 49° 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 8057' 8136' 12 SPF 8208' 8219' 8 SPF 8239' 827O' 1 SPF 829O' FILL @ 8461' (171' RATHOLE) PBTD: 8522' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-79 .... 3. Address 8. APl Number P. O. Box 100360~ Anchorage, AK 99510 50- 103-20079 4. Location of well at surface 9. Unit or Lease Name 1397' FNL, 281' FWL, Sec.12, T12N, R8E, UM .... Kuparuk River Unil; At Top Producing Interval 10. Well Number 1229' FSL, 1400' FWL, Sec. 11, T12N, R8E, UM 3H-7 At Total Depth 11. Field and Pool 959' FSL~ 1153' FWL, Sec. 11, T12N, R8E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool ADL 25531 ALK 2657 76' RKB 14 Date Comp. Susp orAh~-d. I15. Water Depth, if offshore i l6. No. of ComPletions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ' I 20. Depth where SSSV set I 21. Thickness of Permafrost I 8620'MD/6206'TVD 8523'MD/6142'TVD YESx[~] NO [] I 1793 feet MD I 1600' 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR/FDC/CNL: CBL. Gyro 23. '-' CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1R" 67.~,# FI-Z~rl Surf !!5' 2~.'' 228 sx AS ! Top job w/60 sx AS I 7" ?F,.O# .I-5~ R,,rf RRIC)' 8-1/2" 300 sx Class G & !75 sx CS ! 24. Perforations open to Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/12 sPf, 120° phasi n(l..S..IZE DEPTH SET (MD) PACKER SET (MD) 8136' -8208 'MD/5888 ' -5935 'TVD ' 3-1/2" 8057' 7984' Perforated w/8 spf, 60° phasing 26. ACID, FRACTURE CEMENT'SQUEEZE, 8219 ' -8239 'MD/5942 ' -5955 'TVD , ETC. Perforated w/1 spf, 120° phasing ....DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL'USED .. 8270 ' -8290 'MD/5976' -5989'TVD "' see attached Adden¢ um, dated 5/25/88, ,,. for Fracture data. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKES'IzE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.a~ OIL-BBL GAS-MCF WATER-DBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SubmJ~,~,o None RECEIVED Alaska 011 .& Gas Cons. Commissloll ' :..: Anchorage -," * NOTE: Drilled RE 10/3/87. Tubing ran & perforated well 12/10/87. Fractured well 4/13/88. Perforations adde¢ 5/10/88, / Form 10-407 TEMP3/WC100 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 recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 81:34 ' 5887 ' N/A Base Kuparuk C 8208' 5935' Top Kuparuk A 8208' 5935' Base Kuparuk A 8327' 6013' 31. LIST OF ATTACHMENTS Addendums (dated 12/29/87, 5/24/88 & 5/25/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~) _~_/7'~/~(~ .~~jLC-A-~' Title Associate En§ineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21.: Indicate.whether from ground level (GL)or other elevation (DF, KB, etc.). Item. 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and.the location of the cementing tool. ..... ~: -:;i ...,' Item 27!: IVjethod of.Operation'. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jeCti0n, ~'a~.!njeCt.ion',"Sh~t:in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL' 3H-7 11/28/87 RU and RIH GR/JB to 8522' WLM. RU and RIH with CBL from 8516' to 6000'. TOC at 7940'. Ran gyro from 0-8500'. ~r~l 1 i ng S~Visor ADDENDUM 4/13/88 3H-7 Frac Kuparuk "A" sand perfs 8270'-8290' in three stages per procedure dated 4/8/88 as follows: Pmp 830 bbls gelled diese! pad @ 20 BPM, 1600-4247 psi. Stage 1: 60 bbls gelled diesel, 4 ppg, 20 BI~M, 3990-4033 psi Stage 2: 50 bbls gelled diesel, 6 ppg @ 20 BI~], 4045-4015 psi Stage 3: 54 bbls gelled diesel, 8 ppg @ 20 BFM, 4930-7555 psi Screed out w/27 bbls, 6 ppg into perfs. Fluid to Recover: Sand in Zone: Sand in Csg/Tbg: 1111 bbls 13,895# 17,873# RECEIVED Alaska Oil & Gas Cons. Con]mis$1Orl ADDENDUM 5/10/88 3H-07 RUGearhart. Tst lubr. RIH, perf in 11 rns as follows: 8239'-8219' & 8239'-8219' @ 4 SPF, 30° phasing left and right. Perf 8208'-8186', 8208'-8186', 8186'-8164', 8186'-8164', 8164'-8142', 8164'-8142', 8142'-8136', 8142'-8136' & 8142'-8136' @ 6 SPF, 30° right and left phasing. Release well to Production. Supe rvi ~ December 21, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70105 Well: ~ Field- k · Kuparu survey Date: November 28, 1987 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry.$un/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARCO ALASKA., INC. 3H-7 ( SEE: 12 T 12N RO::-":E ) I<UF'ARLIK ALAL:.;KA ANCHORAGE ALASI<A DATE OF: ~=,URVEY NOVEMBER ' '::!:i .:: :..: :.::S: COMPLt~AT ION EL(~.L ...... ' ""-":' D E C E M B E R o. 1 ;, .1. '::'..: ,::,'-' -'/ ,..I 0 B I',1U FI B E R A I< - B 0 - 701 ('~..~_ COLLR'_'::;;E DOG-LEG I]I R E C T I 0 N S E V E R I "F Y D E G R E E '._:..; Ii E G / 100 M E A F;111:7 F 0 t ....... ,"-. ..... ............ ,.' E.I ', t T F':AL..VERT I CAL INCL.. I NAT I ON DEF'TH D E:_' F:" T I"-! DEPTH I]E;G I"t 11'4 Kt:Z L L Y BUSI..-t I NG E-"t_1:'.7. V. = '76, ,, 00 F'"F., OF:'E R A ]"0 R--' H A F;:G E F:;: ::': ::::::::::::::::::::::::::::::::::: ;:. ::'::i TOTAL REL-:TANGLIL. AF~ E:(]ORD I NA]"ES VERT i CAi .... N Ci R TH / S 0 I...t T I-.I E A S T / W E S T S E C T i 0 u 0.0 (') .... '7,':.,. 0 () C, 1 O0 10 ()~ ()() 24, (:;'C;, 200 20 () ,, () (:.~ 124. (':,(") 3 () 0 2 S" '.:.;'. i;:' i;:'22 ::-:: ,. ':".;' 9 () 4. 0 (3 ....":: '::;'.. ':-}... ':>.. ':'}.. :}.: :2:3 . '::'... '::"... 0 I;;," .' .... ~ .~ ("~ 4 ':;':;' ':;' :;' Zl. 23 ';;' S' ("~, 22 N :t8, 0 W (),:2:8 0,:2:2 lq 22 N ''"'''''' 69 W (). 07 (] "-'" 1 N .~. C, ,, .......................... . . .. -"N £;:' .,:: ..... N :.7:(;;),. 60 W (), ()E: 1 ,, 55 N :28 Iq 16. 1 i.:¢ W 0. ,:} 6 :2. :2:0 N 2:B 1'4 '7, 6'.:.> g C,. ()'7 :2:..'1. 2 N 0. O0 0.1¢) W (').:36 W 0.65 W 0.'?0 W 1. ()7 W 600 7()0 0 (q -() ,, 09' -.::.Q ,,._j:_z .1,_ .......... .... (), 3:2 -0,5 ..... O. :iii: :3 .... i. :3:3 - 1.94 'F.;' 0 () .t. (} 0 0 I 1 O0 1800 1900 17 6 S,', 21 16 S'3, 21 .... c .... 1 7 79,, ,_,,..':'.'=;, 0 :31 BI 8, 6() 0 :30 iq i (). 6(7) !;! .._;3'4: .............. !y .... () ::ii',() N ';irO, 19 0 2,S N t:[, () 2 J :B :::;f:::;4. :>".: () ...... 6 2 "7 j. C) ,. :l. :3 :21 ~;.,:,,,, J 9 W .1. 7 4 L:i;60. :BO W ";' i -z,-":, '._;E, i (") W :;!:4 1 ':) S 62 :::'-T~ W · ' .... ~ ~ . x. / F, 1 c- 6R '-":." :2:2 0 S 6,3. :2:0 W 2000 2 :I. 0 () 22 () ("~ 2:300 :2400 250 () :2 6 (;) 2 '70 1 9 41, ':;..-,.":' 3 8 2 r.'-~ 17. E:"7 42 2 091. ',i'i:,:.) 42 2 i ,..':., 5,, E, 9 42 zt ':7 42 ":1. Zl. ..;. ~. ..fi ') 2 :_31:3 ,, ,S (:, "'> "Z, ,2:: Z. "' .2 4 !:':i '7. d:, 0 1'2 S 64.:30 W 20 S /-, 7. !50 ! 1 ::; /-, 7. 2:3 '.F;6,7.6 E, '.i.:.'; d-,5,. ',.:.'i:S' 1.3 '.:ii; ,'35, ;!.'i;:' ~ ':::d:, 4. ,. 39 · . ~.. i .41 S W 2.90 154. E: 9 L--; W :2:.45 180.70 S W 0, 1. ~-.': ............. '_,..-...'. 06,. '? 6 =Ei W 0, 27 2:2:2,9 6, S AN ~.HORAUE ALASKA ARC:O ALASKA., iNC. · .:~.H - 7 ( ..-., E _. 12 T' 12 hi R 0 8 E ) I<IJPARI_IK AL. ASKA DATE OF .~=.,URVE F NOV'EMBER Z:::,, 1 !787 "- ' ' ! " ' I!,' '"":"' .... t'~ '~"";l'-'f'"l tF'" ' t-' ~! I ' :::::::::::::::::::::: ........... ::: ': ! i.~JMF LITA'T ~.l~ ........ .... _~ .-..., YR .-,, .. ,. ~ ,. , R~E~..:... ........ ....... :-~:~-,:A'~.,, '~. · ~' ':'" '~ ~ .... ,,, , .... "~ ~- ' ..... DECEMBER 01, 1'.-.-,'87 ,.JOB NLIMBER i.~l<-BCf-.70105 KE L. L Y BI.iS I---I ! N Ci E'_" L. E V. = 7~,. ('-,~ () I:::' T,, 0 F:'E R A T i."_'l R-H A R iii [:' F;.' j:x .,::7::?:.:?: ..:.~..,: :.:.:..: .... . .:, ,:::- "i'F;~tJE M E A S LI R E I!i '- V E: RT :i:' (}-A I.. [) E P '1" H D E F' T H :2: c:, c:,,::~, 3100 3200 3:3¢)0 :34-O0 35C:,0 360() 3'70C) 3 '.=.;' 0 ¢.', 4000 4 .i. 0 0 V E R T I C A L ]: N C L. i N A T ! 0 lq D i R E: C T I 0 lq D E F' T H D E G M I N D E G R E E S D 0 G- L. E G T 0 T A L S EVE R ! T Y R E C T A N Gl_IL... AR C n OtR D I I',IA'!"E S D E G / .1 o 0 N (] R T H / S 0 LIT H E A S T / W E S T' · . '-,'"', ... ' .....,, , ,5;= 9'48.71 W '27..:,..:,, F) 8 2,:':, 57 08 51 0 S /=, 1 50 W 1 ....., 440.29' S 4:200 4. 30 C, 440(2) 4500 46, 00 470O 4800 4 ':7,,' 0 C~, 50 (:~, 0 510 0 5200 5300 :3:300 ,, 22 3724..,::.'-' .,::'-' :386:3. :_-":5 :3787, :::5 :392,,'=,, :=:'2 :2:85 C,, 82 3 '? '.:.;' 0.4:3 :2:'? J. 4 ,, 4-:2: 4 C', 54, 17 :::':.-, 7 :~:. 1 '7 · '.1. ]. ]. 6 ,, 9'(:: 4. 04. 0. '.-.-,' C', 540(:) 4.177.71 4101. '7 t 5500 42:_::7.67 4161.6,7 5 t 46 S 6 (). 69 W 0, 24 :348, 90 S 1 ,'_-.97, '74 W 1:3 ::=': 4. ("):':: 51 51 S 60 E:() W 0 12 :=:87,':'(' ,, ...... :, S 1766. :_--', 1 W t '::',"- 2 4 i =" ": ._~...~k.,..50._ ~ ............ 0,., 2,"-, ':,'""= '-"-' ':' _1'8:.~~ ~ ......... ~.<-]:.C:' '7':::' :,.,,.! _:L-z ..................... ; .,:-,J,. ,::,~ .-, ...... -- .. 5.1. 45 F; 60./.':,'F..' W 0.16 9,'64.3 L=: ::-.-; 1 ':.-,' 0:3.24 W "L:' ]. 1 i..:: ,, 1' 51 2,'-, S 5'?. 8'F,' W o. '70 100 :z:. 2 C, S 1 'F..;' 71.2, 0 W "::: t. '? 7. :3 C, 5'--". 69' W 0. :30 10, 42, 46 S .... 203:3.76 Jd_ ";' 2'7 .':~ '-' '-' 5 ! 10 , :=: :, r . ::. :: ::. ." .....",. ":' '" 50 59 '='-' 59":50 W:: 0"24 -, ','-, - o-:,~.:, 10.81.~4 S 21C)~.~::7 W .,,. .... .,..91 50 42 ~- 2'? ._, (_) 5 0 3 0 !5 0 18 51 5 8 2:.-'.': 1:3. & t ANCHORAGE AI_A:SKA ARCO ALASKA., INC. 31--I-7 ( SEC 12 T KUPARUI< ALASKA __ . M E A S I...I t:? E Ii .ELATE' OF SUIRVE¥ NOVEl'fl~:~:8:...:28.~ t9:3'7 ~'- "', " .'",. " ' - ~'~--, -' ?~ - J-' -~ - '* --' ~7-.' ' .:' ..~.:: :'ii!!::" I]ECEMBER 01, 19E:7 JOB NIJMBER AI<-BO-70105 I<ELI....Y BI...tSHIN(3 EL..EV, = 76.C:,0 i:::'T. ......... 0 P E R A "F 0 F~i::: (} E R :,..:+-.:,, ,:: ........ '-':1 I" ' .... _ ..................... .. T'RLtE ..... ~~) ......... F':Ot IRSE CFII. JRSE DO(3-LE~G .... ~L VE:F?T l CAL.. VERT 112AL. i NCt.... I NAT' I (iN D l RECT i ON SEVER l TY RECTANGI_ILAR COORD i NATES VERT ]: CAi .... D E P T I---t 0 E; F::' T' I---t 61 ()0 6:20 0 6, :3 (),:.-.:, 64-() ,'_':, 5 C, C) 66()0 6700 6:300 ,':..'-:,'P C:, C: 7C.)0C'~ 71 C:,O 7200 7:300 74 C),:.'.:, .. 750 / (:, V ~--.~ 770 0 7800 7?00 :_::00C~ 8100 82C) C', 830,:::, ,'_::400 L::SC, O 860 C) E-:,S 2 C) 489 :iii:. 48 4 i;:'6 (). 4. 8 5 C:,:23.09 5 :I. 50 ,, :2'7 5 ::2 :t./t. ::30 .. 5 2 7',3.5 4 5407.4. 2 56. ,_,z 8.4:3 57 :B 3. 'F':B 57'P9.51 5864.69 5 929. :30 6061. 16, ,S 1 '--76. ':> :E: ,'.':, 1 ? :2.6. 0 !:il 4 E, 2. ,:} 4 5527. 1. 4 =.'--;92 4:3 5657. 'P'3 _..-!./ ~_:.? .._. Pi 1. 5 7',-_-i:E:. ,'.':,'P E..-- .,--~ r':'* · .j,c,.j-.:,, 4.'? 9' S 46. :3'? W O. 68 2:31. :'::. ] 8 S 4 i;;' :2,:':, S 4- 5 ,, 6, 0 W 0.6, 7 :2365.85 S 49. 1: '.-:" E; 45, :2:(3. W 0. ....":'.=, . 2419.10 S 49 8 S 4,_,. 0 W 0 30 ,':.,a~-'_~ .=;2 S 49 1 S 44.50 W 0. :F.:9 '25:--::6. 18 S EP.? ....... 0 ........ S_44. i '~W ......... j. 23 2580.16 ,4-9 :'3 E:. ~'~ S 43.39 W O. 8'.? 26 :-q 4. ';? 0 S 4 '.:;' .=;_ c...., 42 . F:_ ("~ W 0 .72 2 A_ '-.-?. 0 . :31 c.._, c, ,z,.-:,--:, (") (') 3 ;E: '7 6,. !::; 3 :2: ':.-' :3 0 . 6 :_--: _.la. 40:B 7.5'2 W 4.147:.78 W 4194.64 W ]'FIE: CALF:UI...A'T']:Cff',I F:'F;.:OCE.'i]I. IF~E:S AF;.:liii: BASED (iN "I"HIFL' L.I'.E;E OF 'I"FIIREE I]IMENSIONAL.. RADILIS OF' CLIRVATURE' ARCO. ALASKA, INC. 3H.~-7 (SEC' 12 T t 2N ROSE ) KUPARUK AL.A:::KA ANCHORAGE ALAoF..F.~ DATE OF '=' ' ' ] ........ ' "" 987 ~L!RVEY NLVEMBER.~,:::, I : :::::::::::::::::::::::::::::::::: COMPUI'AT I ON DEC:EMBI~[R 01, 1987 ,JOB NUMBER AK-BO-'70105 KEL. LY BUSHING ELEV. = 76.00 F'"I'. 0 P E R A T (] R - H A R G E R INT~RROLAT'EL'~ VAL..LtE'.B F'OF( EVEN M E A ~.:.'; U i::,: f.::: !::i V E R T I C A I... DE F:"I"H '0 Iii!' F:'T FI 1000 FEET OF MEASLtRED DEF'TH V E R T I C: A L C 0 R R E C't" I 0 N () () ,, ()0 10 0,:'} 'il;"? 9 ,. '.:.;' 7 :2:0 0 () i 'ii:: 3 :.'.:.'~ ,, 6 4 :2: ()0 (':) 2 6 6 '.::::, 31 4 0 () 0 :L:', :::"', 0 2, ,, :3 :I. ?:';(')(")(') ":":;'"':'/- :~', 2 ~, t:') C') 0 /~ =:' "'" '= . .. -r ...... ::,._,. 1 1 7000 5 _t. 5 0.2 7 8 0 (2)0 5 7'!..-/'iF,'. !51 8 6 2 0 ,.".:., 2 0 5.7 ARCO ALASKA~ INC. 3H-7(SF'C12 T12N R)oE) KL~F'ARUK ALASKA MEASURED DE:.F'TH ANCHORAGE ALASKA ':~:~ii?::'. ;:::.':":~::;,?;:::_!.: ................. COMPUTAT ION DA]~_~_. lie C E MB E R () 1 :, 1 '.-7,'87 DATE' OF .=,JRVEY NOVEMBER 2F-:, t987 ' ' ::::::::::::::::::::::::::::::::::: , i:: :-.:: ?" ' "] '" .:,L B'"".::,E~ DEF'TH I NTE:RRO[.:'.~TE-D VAL..UES F L F',, EVEN t 00 FEET OF "" t '"' ~ : . -' :T:RLi['~ SLIB-SE:A 'r'o"rr".', L ',,,'F.': F;: T I ('.::Al .... VERT I CAl... REC TANE-iL.II...AR C Cl t:.'i F,' L] I N A T I!:. '..z_'; MD--TUD DEt:::"f'H DEF:"T'H NORTH / :L:;OLI]"H E:.AE;]" / NE:F.;T J[:~ I FF'F:i:RENCE ,..lOB I',iL.IMBER AK-BO-70105 KELLY BUF;HING ELEV, = 76.0(-) F"T'. nF~R~,ffOF;.:-HARGER :.'.:v' ..:.:,x.:..,: :.:,:.:..,'.:. -: VER"f' I CAL. (": 0 R R E C: T I 0 N / C, 176 276, '""76, 47/_-, 576 6_:-,76, '776, 8 7 ,-'.:, 0.0 C:, .... 76,, c:,("l 0,00 0,0 (] 0 ,, 00 76.()0 0.00 0. :16 N A.(')5 W ().C~c) 1 76,. (),:.::, :;ii: 76, () 0 :376, ()0 47 c'-,, 00 5'76,. ()0 676, 00 "7'7,'_-,, 00 8'76. ()0 O. C:,c) 10 (). 0(") O. 78 N (). :2_"il;' W O. C)(] 0. (")() 2()(),. 0 () 1. :3L-..: N 0 ,, 58 W (). C, .1. (). ()(.) 2, (':,,:]~, c:,(") '2..t 1. N ("~, ::.:) Zl. t,4 ('~. () t 0 ,. 0 c) '"" ]" ,7 z] ........................ .,:: .... :,?.~: ......................... :%, .....,~. %. ...... :: '-. ............................ - - /.I-C:,C~. C:'(":, 2. 'F'2 I".1 1.04 W O. 01 0. ()0 !5,.'":,,::) C":.':' "'" . . ...... :,. '77 N I ()'i'.".' W O. C) 1 0. C:, () 6 (} 0,. () 0 4,67 N 0. '.74. W (), 02: 0, (]0 7 (] O. 0 () 5..."56, N 0.80 W 0.0:2 0. C) O 800., () () 6.51 N 0 ,, ,':,.5 W C:,. (:):2: (), ()0 1 1176 1277 ? 76, 9 "76 ,, 00 9 (} 0.00 076, 1 (:) 76, ,, 00 .!. 000, 00 1:3 7 8 14 :{: ';:: 1 ._,,:, 7 1 1 '76.0C) 1 t O0. OC) 127/-, O0 12C)C) (')C) .......... t '_'_.? : ........... r::-~'---::: Y--_....~-.. -""- 1:2: 7.""-, ,. ()0 1 :L:: C)0. C)0 1476. OC) 14. C')C:,. 00 1576. OC:, 1500. C) 0 '7. :.3:3 N (). :'-]8 W O. 0:3 0 · O0 7.20 N 3.73 N 3.63._,':' 1:3.84 '._--; 26. 'P4 S 4:':: .'-5':' S · 1696 loC 7 16,76. O0 1600. O0 1776. O0 1700. O0 63.24 S 84.58 S t.20 W 0.04 0.01 6.00 W 0.24 0.20 _.1. 6.._/;.-., 7__W 1.1 O 0.86 :':::3. 1:2: W 2. '? 7 1. :3 7 .... , 45 W 6 28 :3 :_::2 F:4.8:_:: ~ { .11,., :~:7 :5., 12'I:'74'W' ' 20.27::~': ' 8,40 1 ~/_-,. O0 gl 31.71 11.45 SPERRY-SUN WELl_ SURVEYING COMPAIqY ARCO. ALASKA, INC. oH-7 ( ;:,EL. 1_~_ ~". !._ ~N..N___R_"O:_ _=,LI~_)_ ~.ii" ":.::.': ....... ;: ....... KUPARLtK ALASKA MEASL~RIED DEF'T'H ANCHORAGE ALASKA .... ~J~iU.TA TI oN. DATE_ DECEMBER 01, 1987 I NTERRD~"~'~ED VALLtES FL R']=' EVEN TRUE SUB-SE A TO"FAt... DATE: !:!F .,URVE¥ NOVEMBER: ~,:,, 1 ./o/ ,JOB NUMBER AK-.BO-7010,5 i<EL L Y BUSH I NG EL E V. = 76.. ,2,() F:"T' ,, _iF ERA FUR-HARL~ER 100 FEET OF oLB-.=,EA DEPTH V F:'i: R T I C A I .... I:) E F::' '1" FI , . VERT I CAL_ RECTANGULAR !]E F'-r' H NOR TH/SOLITH CCl I:1R D I N A T E S M D'- T V D V E R 'T I C A I_ E A :=; '1" / W E: S 'ir. .r.'i I F F: E:. Fi: E N C E C 0 R R E C T I 0 N . 192:B 2 () 4 ~:. 21 "7,:'.-., 2:..=: 1 244 `5, · ':., =~ c, 2 71 2:5:60 :B c3 :/ "-" J./_":, E: :3 :B 2 7 :3 4 E: :B :2:64 :379 :'2, 5;' 5 ,'.'.:., 4117 4278 4440 4/-, 01 1:3'76,. 00 1 9 7 "- 0 2 07 6 ,, C:, 0 21 '7/:,. () () · 7,-'::,'?' z. (") (') :2:2:'76. () 0 :2,.1. '76.00 2 57 ~. 0 () ::ii: 6 "7 ;::,. ,.'.'.:, 0 '277,:':. ~ () () :'7::i.:::'7 (!:,. C, 0 ....... 2-'976.0() 30 7,'5,. C) 0 :.31 7 E,. ,:'J) O :7:2 '7 ~:,. ~..'.:, 0 :::3 3'? 6.0 () :3 4'7 6.0 0 :5:5 7 6.0 0 :7:6'7 ,'L-,. (')0 i :iF: ()O. 0 C:, 11 ':), 44. S 21 'iF..'. 1:2: W 4'7. '.:::' 0 16. 1 2. 00 (')_ ,, (3_ '.'") 174 ,, 43 :iii; .=,._,,:, .'-' '='''' .,: ..., ''"' '= N 1. 00. ~.]) ::.i: .,_"::"::>.. .32 21 () () ,, 00 209.87:5; 441.86, W 1:35. 1 () :B 5. ()9 .220 () ,, (30 244 ,, 5' 2 :L:; N';;' F,. (") (") W '[ 7 ("~. 41 :=: 5. ::', '[ :....'.~:...~.-~ ..... ~..:' ................... = ...... ,4: ....... ~ .,'= ..,-, 23 ('). 0.. ().. C). '279 .4 (').. E; 610 , O. 2. W .."::' 0 :=~... F;i.. C)_ ..-.,'"' ..., '= , 0.. o.. 2-/.I-C, 0. OC:, :316.48 S /=,'F.'6. ,"i.'i.:', 1,4 2zt. 2.82 ::.47. :3:2 .... , "::'r-" 5:5 ::: 4 Z[ " .... ,-,- · ,-, .-,,-, r.:.-, Z .~:...., Jo nn ..... F:?.Z, z-:.,,_=.,. W ......... -~,__~_~.......=!::_, .................. ..... .. ::.. . .:? '?/-,("i ~') ,:"),:':, 4-07 ::',"z '.ii!; :=:8'7 6,'.::, W :7:: :34 '"' '= . ..................... · . .... 49 2 7 ()C;. 0,:) 4 6 5.6, 4 :.:.i; 'P'.:.:' 5. :3 4 W :2:9 '_:-:_'. 2 7 5 7.91 - ~:: ~:. ,_-=- '2 ::::: ,:") (') ('),:") '~"::'/t. '74 :i-'-'; :/1 C.~:--': 7 .... W 4 .... 1 l .... :iii::iii: .......... u . . -...*.. u .... . . u 2'?o0 O0 ~-5':'i ':'/- S 1210 1i W .=,07 92' 5/- -'-' ::::0 (') O. C:,(] 6:3'7. ':'/:::: :i::; 1:316. :3 0 W "' . .......... _ .:, o 4 20 5 6.2'F, :3 i 00.. 00_. /-, '-.":' .=,, }'::! E_. ;5._; .......... j._ ~ 2__.'_:_:._ ¢2 ',..?.j_ ~ ............ &_~ I. :34. .. _..'::~ _7..,,_1=~__ ................ 3200,, ()0 75:'.1.. ,'3'2 :2 1 .'--"q:31 · 07 W 6:30.02 :.'='::300. O0 ~:::: 16.9'.:.:' S 1,5.,41.1.4. W 741 · 2'.=¢ 61.26 :34,:::,,n. 00 879.21 S 1751 · 84 N =5= 02 ,. 9.1. .... 6 :=: S c:, ,F:'_ . .. oO '.-.-,'41 . -_-=;':'-.., L-; I,"::A2_ _ · ._.'=;°,=, 1,4 864 .6,1 61 . 7(:, :.-_4,5, O,t:~. ,:::, 0 10' 0 :z:. 9' A:5; 197 :.2.51 1,4 925.79 61 · 17 M E A S U R E .0 l]E P T H ANL, HORAL',E AL. ASKA cOMP!~N,, DECEMBER O1: :I'?L:.:7 : ii ' "'' ' '-' '"'' .., 'F'87 DATE OF sURVEY I',I~,VEMBER~.~¢,. 1 JOB NUMBER AK-BO--7C) 105 KEL L Y BU:-2;H I NG EL E V. = 76.0(::, Ic T. 0 P E R A 'T' 0 R - H A R O E R IN IEBF~.~LAil:.~:EI.I VALLf[:.:, FLR EVEN 100 FEET OF SUB-SEA OEP'TH., , :.. :'1:: R U E s u B- s E A ............... T 0 T A L V E F:~ T :t; F:Ai ........... .... VERT I C:AL R E C T A N G IJ L.. A F:;: F: Fd"i R FI l N A'T E E; Id._" R - "F 'v' D- V ER'T' I CAI .... 4 '7 E, :1. :37 '7 (:-,, ('.) 0 491 '? :}.': 876. C)() 50 '7 '7 :}.", ? 76. () 0 :2, i.;' ,:'_':, (). 00 .._, ~: .:,.:]. .407,'.':, ,, () C, 4 () ()C) ,, 00 5 :L::'iD '? 4:1 "2' 6. C) () 4:1. ,::;:, 0 ,, 0 () 12: lZ;' ' ' ...... ,e,.q 4276. C)() zl. 2()O. 00 .. / ..:, 1 4 :;ii:'76. C) (") 4:2', 00 0 5'.-T~C)C.) 44'7./:, ~ ()('.) 440C) ,, C:,() 6 C) 6 i;' 4 ."::;'7 ,.:!:,. 9 ()45 C:, 0. () 0 62:2:6 .-.':t ,":, -.? 6. C)() zt 60,:.'.~. ()C') 640 C) 47 '7,'S. ,:'2)0 47 ('-:, 0. C)0 656:_--: 67:2:4 6F:,'_--:3 7504 76.58 48'76 ....... C) C) 4 :i:O() 00 i 84 C) (')4 S.:,z"""' ~'/-'/ 67. W t ~=,o7'", 60 o.:,,"-' 1/-,_ 4'? 76 (') (') 4900.00 1919 6, 0 S '"""";' ' ...... :,..:,, o 1 W 1748 'P5 6 !. :3~] ]=~c)76.00 50()0,00 19':>8..~()... S ...... ~47~.,80 W _ ~8o7. ,63 ..... ._c, · 517(::,. C,() 5100.00 2077.27 S 3561.'75 W 1864.2C) 56.56 52'76. C)0 .... Y;2(")C) . ('"")_.._ ~";' 1 ?;/-,_ _.. ,_,=/-':' S :'::Z-,P; 1 .... . :::A_ _ W 1 'F, 20 . C)5 ._=;='.._, 8/-,. _ ='-"- ' 7._ S · _,..:, / o (') 0 R 9, (')(') c) (') 22:3/-, ' P; :~ 7 & 0 ~ 0 ~ W 197 ~. ~::~{ .:,.-,: . -"- . ..... . - . -- m ,.,, ,,,., ,, ..... , .~ ~ ...... . .... ~ ........... ,- , 5476.00 5400.00 2315.71 S o,:,~4.66 .W. ~. =;%76 (")(') ~(')C) (')(':, 2:396 R9 :~ '::':¢0::: 18 W 2082:36 ~':' 51 : ARC:O ALASKA:, INC, : ;S::H,-7 ( fi;EC t T .t :2N t",, J, oE ) KUPARUK AL. ASKA AN_:HLIRAL',E I-.~LAot-,.A :: :: COMPI_=~' ! ON. :DALf'E D E C:E M B E R () 1 :, :t. '.-::'8 7 DATE OF ;SL1RVEY NOVEMBER 28., ::::::::::::::::::::::::::::::::: ,_10 B N U M B E R A K- B 0- 7 01 _~._, KEL. LY BI..,IF:;HING ELEV, = (] F' E:: R A T 0 R - H A R G E IR i 987 76. ()() F'"!" ,, IN'. TER:::~TEE:~ :'"P;~'~:¥:~ ~: :"'] VALUES' FOR EVEN i00 FEET r]F' '"'.:,LB-oEAI ,' ..... DEPTH "j" [:;: I...I [ii: S U B- S E:. A T Cf T a J .... M E i::~ :).'i; t,..I R EL] V E F.: T I C A t ....V E R T I C: A L R [.:.': C "l" a Ri (ii I...I [... A J::~ I]: rf.i 0 R L] I hi A "1' IE '.!.:; M D ...- T V L] D E P T I--.1 D E I:::' T' I.-.1 :[) E I::' T H N L')I::;.: "1" t--I / t.:.'i; L'] I...I T FI E A :.:]; T / W E S ]" ]]I F: F' [ii: IR E hi C: E V E R "r I C A L C 0 R i::;: E C ]" I 0 N ,:::, .t. 1 7'.:.764 .t. ! 7 2 7 0 z[ "2 "2 5 '7 d, 20 Tt--t E i",itZ A R !E S"I" 20 F:'O(:)"I' P'i:('-I ( I:::' t::;: 0 h'l I::;..'A D I t..tS 01:: ('_:I._ItR VA Tt...tiRE ) F'O t hi T S · ANC:I.,.IE~I:?AGEAL¢..~.:,I"..~,""": '""" ARF:O ..... At.Z::~SI<A~, I I',,tC: · [lATE OF' S;LIRVEY :NOVEt~BER .z~o""'-', 1 '.:.:-'E:7 : :3H- 7 (",:,EL. ...... i .,~ '') T 12N ROSE .'~ :.i :::: I<LIPAF~LIK AL.A::;KA .................................................................................................. ~d"tF'UT'A:T t ON ~~ ...... ~' ;['T~F:.:CEMBER ,:}.1.., 1 9:_::7 JOB NUMBE:R AK-.BC~-7C) 105 K E..'. L L Y B U'.:._:;Ft I N G E L. E V, = 76.00 t:::T ,, r"~F'ERATOR-HARGED _ ..: S Li B- S E A "1' O T A L. VERT I C:At... RECTANGLIL. AR C(]E~RD I NATE'.E; 1 D EF'.'f?:! ........ t~! (i! t? T[),:,i? !~!!7!.1.._.,!,'J7 I-! ....... ji~:?.-:.ii 7[: ./.~ ~-_.': '-ii:; T ........... H.(.). F,~!:,:j I,F::,?.!~ ~ :::: '? (") ,,::~ ~:::' ,..-, .-. ~:::. ............... ~ '::. :: ...... ':} 4 8 2 0 C:.~ 5 9:3 !5.0 4 E::32:7 e, () i :3. :!. 2 :-'.-'i: 5 0 0 ,:':.. 12 6 ,, 9:3 ,:::,...,.~:...:, 6 :t. 42 ,, ():3 8620 6 :'2:05.7:3 .., ..-, :I :!,:.'; 4160. ?i9 .,::. (:,...,..: ....... W T l-IR KI..IF'A R I..IK C =;'"'='-' 04 26'.:;'4.75 E; 41'F'E:. 75 W BASE I':.'.'UF'ARLIK' C !'::;::::: !::; 9 ,:.) 4 2,'.!:, 94 '":'::" S 4 9 :i::. "~' 5 . ,, . / ..... :1. / ..,N T t'.] F' K i..IF'A RI..II-::: A ...... .:7. 12 .'776, C) 71 '::' 42F:P:.) ,'}.,E', W BASE Ki...IF'ARUK ....... · - ,-.,. ',,'.., ,, :iii: 2 :iii; , ' ....... "' ...... 6 C) 6 c", ,, 0 :,":',' 2 ~-: 6 'i'}. ,./-., ? F:; 4 ~; 5'? ,, 2':T' W F' L. I..lt'_'i B A C K 'l" 6:t'2'?. 7:3 292:3,,'!77 ::.:.'; 44()',~i:.:34 W ]"OTAL DE:F'TH DRILLER ~.~F,L,U ALASI<A, IN(":. · :3H--7 (,-:,EL. 1 ~: T 12N ROSE) . ::.: .:.. DER_tVED USING DII_ DEPTHS AI",ID F;PERF,'Y SI_IN SURVEY DATA ...................... :. ....... _.UORD INA ~ ~:..::, :!: ::::::::::::::::::::::::::::::::::::: :/::::::::::::::::::::::::::::::::::::::::::::::::::::::::: · 7 ::'i! ::::,~!~:. ?:!':::?,i i:: ' BKB BKB F;~ ......... ~B....-~:;EA VERT I CAL ( aR I ;'~ ~ N- i73~F.,~[~::::I .,~:o'-"~' t FWL. ) ::: ,..,EL._. 1,:: :~::~::~:~ ::~: R'L,::,E ::1) FROM LINEAR EXTRAF'OLATIFIN BELOW DEEPEL::T STATION. ':: ' 2) F:OMF'I~TER PROGRAM - SPERRY '.5;I.JN THREE DIMENSIONAL RADIUS OF L.'L!RVATL~RE DATA CA!~J3LJ!.-:AT ]: QN AND I N.TEEtF'C?!:..AT !l-)_hJ__B_Y RAD I LIS OF CI_IRVATLIRE CCtMF'UTATION DATE T~ECEMBER 01) 1987 DATE OF SLIRVEY NOVEMBER 2:::, i?:37 JL-IB N~~K-BO-70105 I-:::ELLY:i':BUiSHINr-~ ELEV. = 76.00 F T. SPERRY -SUN SCALE :- 1 INCH TO 500.00 / 500.0 KUPRRUK ARCO ALASKA, INC. 3H-?[SEC12 T12N ROBE) NOVEMBER 28, 1987 AK-BO-?0105 -45~0.00 -4o6o. oo oo '~5bo. oo "2°bo. oo -~5'1~0. oo -:01~0. oo -501~. oo --500.00 --1000.00 --1500. O0 --2000.00 0.00 1500.00 3000.00 4500.00 7500.00 ~ SPERRY -SUN 5CRLE :- 1 INCH TO 1500.00 KUPRRUK 3H-?[SEC12 T12N ROSE] 9K-80-?0105 I 1500,00 3000.00 6205.73. · ;~,:~i~v~.e~ 28. ~: r: ~.. . INC. 1987 ~862Q 4500.00 6000.00 VERTICAL PROJECTION ARCO Alaska, Inc, Date: April 20, 1988 Transmittal #: 7146 RETURN TO: ARCO Alaska, Inc. ' Attn' Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. copy of this transmittal. Please acknowledge receipt and return one signed -"-' 1G-16 '--~1G-09 -----~1G-09 1G-09 ~L%~ 2C.04 "~3H-05 3H 02 ~ ':i Y' 1 4 Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Post-Frac Report Post-Frac Report Post-Frac Report Treatment Report Pulse Test 2 - 8 - 8 8 Static 'C' Sand 2 - 3 - 8 8 'A' Sand 2 - 3 - 8 8 Static 'C' Sand 2 - 3 - 8 8 Static Both Sands 1 2 - 1 3 - 8 7 'A' Sand 4 - 6 - 8 8 Allo Frac 10 4-6-88 AIIo Frac 10 4-6-88 AIIo Frac 10 4-13-88 3 - 1 1 - 8 8 'A' & 'C' Sands ......... Anchorage Receipt Acknowledged' DISTRIBUTION: D & M ~'of?Alask-~::;~,~:.:~?~??~..~:~!,~:,~., !'~Ii Date' Chevron Mobil SAPC Unocal Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1988 Transmittal # 7056 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please ackmowledge receipt and return one signed copy of this transmittal. ~"~'~2V-4 Cement Evaluation Log 12-29-87 5987-7253 ~ '"~3H-6 Cement Bond Log 11-27-87 5300-7866 -'~ ~~ Cement Bond Log 11-28-87 6000-8516 -.o ~'~3H-5 Cement Bond Log 11-25-87 4900-7020 ~3H-8 Cement Bond Log 12-3-87 4600-6756 "~'~3H-10 Cement. Bond Log 12-9-87 5128-6633 ~ "~3H-1 Cement Bond Log 12-3-87 5700-7978 ~'~ x'~3H-2 Cement Bond Log 11-23-87 6100-8184 "~ x'~3H-4 Pulse Echo Log 11-25-87 5600-7986 x'z "~3H-9 Cement Bond Log 12-8-87 5550-7162 '"~'"~3H-3 Pulse Echo Log 11-26-87 4400-9354 o~ Receipt Acknowledged: DISTRIBUTION: Date: Alaska 0ii &'Gas Cons. Anchorage NSK Drilling State of Alaska (+sepia) ARCO Alaska. inc. is a Subsicliary of AtlanticRichfielciCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 11, 1988 Transmittal # 7061 RETURN TO: ARCO Alaska, Inc. Attn: 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-4 BHP Data Worksheet 12-17-87 Camco 3H-5 Kuparuk Well Pressure Report 12-18-87 Static Otis 3H-5 Kupaurk Well Pressure Report 12-18-87 Static Otis 3H-6 Kuparuk Well Pressure Report 12-19-87 ~ Kuparuk Well Pressure Report Static 3H-8 Kuparuk Well Pressure Report 12-23-87 Static Otis 3H-8 Kuparuk Well Pressure Report 12-21-87 Static Camco ' 3H-9 Kuparuk Well Pressure Report 12-22-87 Static 'C' Sand Otis 3H-10 Kuparuk Well Pressure Report 12-22-87 Otis Receipt Acknowledged: DISTRIBUTION: D&M BPAE Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ""'" STATE OF ALASKA .... ALASI... OIL AND GAS CONSERVATION COMN. .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other Stimulate [] Plugging [] Perforate~3 Pull tubing COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1397' FNL, 281' FWL, Seco12, T12N, R8E, UN At top of productive interval 1229' FSL, 1400' FWL, $ec.11, T12N, R8E, UN At effective depth 1013' FSL, 1202' FWL, Sec.11, T12N, R8E, UN At total depth 959' FSL~ 1153' FWL~ Sec.11~ T12N~ R8E~ UN 5. Datum elevation (DF or KB) RKB 76 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-7 8. Approval number 7-837 9. APl number 50-- 103-20079 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 8620'MD true vertical 6206 ' TVD Effective depth: measured 8523 'MD true vertical 6142'TVD Casing Length Size Conductor 80 ' 16" Surface 3537 ' 9-5/8" Producti on 8575 ' 7" Perforation depth: measured true vertical 8270 ' -8290 'MD feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 228 sx AS I ll5'MD 1100 sx AS III & 3572 'MD 500 sx Class G Top job w/60 sx AS I 300 sx Class G & 8610'MD 175 sx CS I 5976'-5989'TVD Feet True Vertical depth 115'TVD 3032 ' TVD 6200 'TVD 12. Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 8057' Packers and SSSV (type and measured depth) FHL pkr ~ 7984' & Otis SSSV @ 1793' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~E~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~. /~ Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) SW03/29 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 are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no, AK2505 ICounty. parish or borough NORTH ST.OP;. Lease or Unit ADL: 25531 Title COMPT.;..T TON J Stat~tK 3H-7 JWell no. API: 50-103-20079 IDate I Hour 12/10/87 0230 Complete record for each day reported NORD?C I Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 12/10/87 ( TD: 8620 PB: 8523 SUPV:SS/DJ IARCO w.I. 56.0000 Prior status if a W,O. GIH WITH PERF GUN MW:10.0 NaCl/NaBr MOVED RIG TO 3H-7. ACCEPTED RIG @ 0230 HRS, 12/10/87. ND TREE. NU BOPE & TESTED TO 3000 PSI. RU GEARHART. GIH WITH PERF GUN (LOADED WITH 1SPF, 120 DEGREE PHASING, 20 GR DENSIJET 720 CHARGES) DAILY:S40,715 CUM:$40,715 ETD:S40,715 EFC:$777,000 The above is correct For form prel~ation and distribution, see Procedur~tll~_Manual, Section 10, Drilling, Pages 86 and 87. Title Associate Engineer 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. I Accounting cost center code District County or Parish ~ State i ARCO Alaska, Inc. NORTH SLOPE I AK Field KUPARUK RIVER UNIT Auth. or W.O. no. AK2505 Lease or Unit I Well no. I ADL: 25531 3H-7 Title CO[V~T,ETTON Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 12/11/87 ( . TD: 8620 ?B: 8523 SUPV:SS/DJ API: 50-103-20079 IA.R.Co. W.I. ~otal number of wells (active or inactive) on thisI ~ost center prior to plugging and 56,0000 ~bandonment of this well IDate12/10/87 / H°ur 0230 IPri°r status If a W'O' Complete record for each day reposed NORDIC i RIG RELEASED MW: 6.9 DIESEL PERF F/ 8270' - 8290', W/ 1 SPF. RUN 3-1/2" COMPLETION. SET PKR AT 7984'. TEST TBG. OK. SHEAR PBR. TEST ANNULUS TO 2500 PSI. TEST SSSV. OK. SHEAR BALL. ND BOPE. NU TREE AND TEST SAME. OK. DISPLACE WELL TO DIESEL. SET CPV. RIG RELEASED @ 2315 HRS 12/10/87. (SSSV @ 1793', TAIL @ 8057') DAILY:S132,001 CUM:$172,716 ETD:S172,716 EFC:$777,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data INew TD PB Depth Date I K nd of rig Type completion (single, dual, etc.) IOfficia reservoir 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 Signature/~ ~ ~//~ '~/'~( '~ IDate /~ '?~'~"~:~7 ITitle For form preparj~ion and distribution, see Proceduresi/~lanual, Section 10, Drilling, Pages 86 and 87. Associate Engineer ARCO Alaska, Inc. Date: Subject: December 22, 1987 Incorrect API Number Internal Correspo~nd~ence Ft~ecode: Well File' 3H-7 From/Location: Telephone: To/Location: S. A. McKnuckles 265-6835 Distribution AT0/1119 The API number Schlumberger printed on the Well 3H-7 log headers is incor- rect. Please change from "50-029-20079" to "50-103-20079". Thank you for your assistance. ~o/~,.~, .?,..~? .... ~<~/i~',-~'c~ ~ ~~,""~ ~.~/'i /-s/~ ~L~?~ Please contact me at the above number if you have any questions. Kuparuk Records Clerk SAM'pg-0176 cc' M. L. Hagood E. M. Oba G. K. Phillips AT0/1120 AT0/1156 AT0/1170 ~o ~ Distribution D. M. Franzen L. Johnston Alaska Oil & Gas Commission DeGloyer and MacNaughton ATO Central Files Drilling Department Files NSK Central Files PRC/E-202 ANO/879E Anchorage Dallas Vault AT0/1479 NSK ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6001-B STATE OF ALASKA ALA,..,,A OIL AND GAS CONSERVATION CON,,,,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation ShutdownS' Re-enter suspended well [] Alter casing !Z Time extension [] Change approved program [] Plugging [] Stimulate D Pull tubing [] Amend order ~ Perforate ~: Other 2. Name of Operator ARCO Alaska~ Inc 3. Address P. Oo Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1397I FNL, 281I FWL, Seco12, T12N, R8E, UM At top of productive interval 1.358I FSL, 1383I FWL, Sec.11, T12N, R8E, UPI (approx) At effective depth 1094! FSL, 1156I FWL, Sec.11, T12N, R8E, UPI (approx) At total depth 10411 FSL, 1105I FWL, Sec.11, T12N~ R8E~ UM (approx) 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 80I 3537I Casing Conductor Surface Production 8575' 8620'MD feet 6197'TVD feet 8523'MD 6133'TVD Size 1 6" 9-5/8" 7I1 . 6. Ku 7. 3H Datum elevation (DF or KB) D ?§ ' feet Unit or Property name paruk River Unit Well number -7 8. Permit number 87-7cj g. APl number 50-- 103-20f)79 10. Pool Kuparuk River Oil Pool Plugs (measured) None Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None feet Junk (measured) None feet Cemented Measured depth True Vertical depth 228 sx AS I 115'MD 115'TVD 1100 sx AS I11 & 3572'MD 3031'TVD 500 sx Class G Top job w/60 sx AS I 300 sx Class G 8610'MD 6190'TVD 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge TitleAssoc i at;e Epoineer Signed ~/lf~/~( J ,~¢L/I~..A ~, _ Commission Use Only (Dani) SA2/1 1 9 Conditions of approval Approved by Date Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ?- C~O'..~¢ Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date/~) °'~,~87 Submit in triplicately// ARCO Oil and Gas Company Well History - Initial Report - Daily Inatruotione: Prepare and submit the "Initial Report" on the first Wednesday efta; a well is spudded or workover operations ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK2505 Doyon 14 Operator ARCO Alaska, Inc. ICounty, parish or borough North Slope Borough Lease or Unit ADL 25531 Title Drill API 50-103-20079 Date 9/25/87 IH°ur State Alaska IWell no. 3H-7 ARCO W.I. Prior status If a W.O, Spudded or W.O. begun Spudded Date and depth es of 8:00 a.m. 9/26/87 thru 9/28/87 9/29/87 9/30/87 10/01/87 Complete record for each day reported 0330 hrs. 56.24% 16" @ 115'/9-5/8" @ 3572' 3602', (3487'), Rn'g 9,5/8" csg Wt. 9.1, PV 13, YP 11, PH 9, WL 9, Sol 5 Accept rig @ 2000 hfs, 9/25/87. NU diverter sys. Spud well @ 0330 hfs, 9/26/87. Drl & surv to 3602'. Make cond'g rn. RU & rn 90 its, 9-5/8", 36#, J-55 BTC csg to 3572'. 1003', 0.4°, N46.9E, 1002.98 TVD, -2.80 VS, N 5.66, W 0.15 1568', 19.7°, S62.3W, 1558.05 TVD, 78.36 VS, S 31.22, W72.70 2123', 39.0°, S62.3W, 2039.03 TVD, 348.18 VS, S148.69, W316.97 2706', 44.4°, S68.0W, 2471.34 TVD, 734.17 VS, S296.56, W678.62 9-5/8" @ 3572' 3903', (301'), Drlg ahead Wt. 8.5, PV 4, YP 2, PH 9.5, WL --, Sol 1 Cmt 9-5/8" w/ll00 sx AS III & 500 sx C1 "G" w/2% S-1 & .2% D-46. Bump plug & tst cs§. ND diverter. Perform 60 sx AS I top job. RIH w/8½" BHA & DO cmt & flt equip. Perform LOT to 12.5 ppg EMW. Drl & surv to 3903'. 2990', 49.9°, S63.7W, 2664.41TVD, 940.71VS, 381.69S, 868.49W 3724', 50.7°, S63.7W, 3126.71TVD, 1509.09 VS, 638.12S, 1377.64W (NOTE: Ran 90 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 3454', FS @ 3572') 9-5/8" @ 3572' 7035', (3132'), Drlg ahead Wt. 9.5+, PV 4, YP 1, PH 9, WL 8.8, Sol 9 Drl to 7035' . 4072', 51.9°, S60.9W, 3344.29TVD, 1780.16VS, 764.55S, 1618.08W 5339', 50.8°, S59.5W, 4130.38TVD, 2772.80VS, 1242.23S, 2489.11W 6635', 51.9°, S52.5W, 4910.68TVD, 3806.05VS, 1805.58S, 3355.94W 9-5/8" @ 3572' 8538', (1503'), RU Schl Wt. 10, PV 11, YP 6, PH 9.0, WL 4.8, Sol 11 Drl to 8538', short trip, CBU, POOH. RU Schl f/OHL. 7107', 50.0°, S46.9W, 5208.02TVD, 4167.78VS, 2042.56S, 3635.37W 8453', 48.8°, S43.4W, 6087.17TVD, 5161.04VS, 2750.76S, 4367.91W The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date [ Title I Drilling Superintendent 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 o~ficial 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 Lease or Parish Alaska County Field or Unit Kuparuk River Auth. or w.o.A~gnO. AK2505 T t e Doyon 14 North Slope Borough Accounting cost center code State Alaska ADL 25531 JWell no. 3H-7 Drill API 50-103-20079 Operator ARCO Alaska, Inc. Spudded or W,O. begun Spudded A.R.Co. W.I. 56.24% Date 9/25/87 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 0 I Prlor status if a W.O, 330 hrs. I Date and depth as of 8:00 a.m. 10/02/87 10/03/87 Complete record for each day reported 9-5/8" @ 3572' 8620', (82'), LD BHA Wt. 10.1, PV 9, YP 5, PH 9.5, WL 5.4, Sol 12 RU Schl, log DIL/SFL/SP/CAL/GR/FDC/CNL f/8552'-7900' WLM; cont w/GR to 1000'. Log DIL/SFL f/8552'-3570'. RD Schl. RIH, drl 8538'-8620', circ, POOH, LD DP. 7" @ 8610' 8620', (0'), RR 10.0 ppg Brine RU & rn 206 its, 7", 26#, J-55 BTC csg w/FC @ 8523', FS @ 8610'. Cmt w/lO0 sx POzz "G" cmt w/4% D-20, .5% D-65 & .2% D-46 & 200 sx Cl "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ w/lO.O ppg brine, bump plug. ND BOPE, NU tbg head & tst to 3000 psi. RR @ 0300 hrs, 10/03/87. Old TD New TD PB Depth 8620' TD 8523' PBTD Released rig Date Kind of rig 0300 hrs. Classifications (oil, gas, etc,) 0il Producing method Flowing 10/03/87 Type completion (single, dual, etc.) Single IOfficial reservoir name(s) Kuparuk Sands Rotary Potential test data 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 TP. C.P. Water % GOR Gravity Allowable Effective date corrected I The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date: ARCO Alaska, Inc~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ,. October 20, 1987 Transmittal # 6094 RETURN TO ~ ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and retukn one signed coPy of this transmittal. "~3H-7 Colville 2" and 5" Raw Data and Porosity FDC . 10-1-87 ~ 3H-6 Colville 2" and 5" Raw Data and Porosity FDC 9-23-87 3576-4100 3527-3900 Receipt Acknowledged: DISTRIBUTION: ' ~'~" ":; .& Gas Cons. Cornrnissfor~ Anchorage NSK Drilling Geology D & M Plano BPAE(+sepia) SAPC (+sepias) · Unocal (+sepia) State of Alaska (+sepia) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Vault (film) ARCO Alaska, Inl Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 20, 1987 Transmittal #6086 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and retu~rn one signed copy of thistransmittal. 3H-7 OH Lis Tape 10-1-87 3H-17 OE Lis Tape 10-9-87 Receipt Acknowledged: DISTRIBUTION: Anchorag-~ 'i~mi~lotl M. Stanford state :of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ARCO Alaska, Im Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 12, 1987 Transmittal #: 6080 RETURN TO: ARCO Alaska, Inc. Attn: 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-7 ' 2" Dual Induction 10-1-87 3576-8546 3H-7 ~5" Raw FDC 10-1-87 3576-8546 3H-7 ~2" Raw FDC 10-1-87 3576-8546 3H-7 -- 5" Porosity FDC 10-1-87 3576-8546 3H-7 ~2" Porosity FDC 10-1-87 3576-8546 3H-7 ~..~-~yberlook 10-1-87 3H-7 ~ 5" Dual Induction 10-1-87 3576-8546 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M L. Johnston(vendor package) Vault(film) ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 5, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 RECEIVED Enclosure Alaska 0il & Gas Cons. C0mmissi0n Anchorage ARCO Alaska. Inc. is a Subsidiary o! AllanticRichfteldCompany I II. "II I YICINITY MAP~ SCALE I"a 2MILES ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. NOTES I. ALL COORDINATES ARE AS.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-67.19,$5-44 ~ L-~7-11, 29-$2. 5. O.G. ELEVATIONS FROM CED-RlXX- $471~ A 6. HORIZONTAL POSITION BASEDON SH CONTROL ASPs 'X' LATITUDE LONGITUDE J Dill' E N. L. 6,000,110.7:5 6,000,135.51 6,000, 160. 57 6,000, 18.5.28 6,000,210.66 000, 235.50 000,260.34 6,000,285.82 6,000,310.30 6,000, 335.43 6,000,42 5.37 6,000,450.51 6,000,475.46 6,000,500.41 6,000, 52.5.44 6,000, 550.46 6,000,575.45 6,000,600.44 6,000,650.45 6,000,675.40 6,000,700A2 4cJ,8,655.4 4 498,655.43 498,65559 49 8,6 55.43 498,655.47 498,655.40 498,655.41 498,655.44 498,6.55.45 498,655.44 498,655.44 498,655.38 498,655.42 498,655.45 498,655.41 498,655.47 498,655. 55 498,655.59 498,655.49 498,655.65 49 8,655.75 70o 24'41.531'' 70° 24'41. 775" 7 0° 24'42.022" ?o" :,4:42 26~" 70° 24 42.514" 70° 24 45.003 TO° 24,43.494 70°24 43.741" ?ooz4'qq.6Lm" 70024'44.873.' ?oo24. 45.119" ?0°24'45.$ _64.~' ?0°~4' 45.610 ?0024'45.856" 70°24'46. IC~" 70o24'46348' 70024'46. e4.0" 70°24'47.08 5" 70024'47. 53,1" I ~o 0o' 39.416"i 150000' $9.417' 150° 00'3~9.418" 15 O° 00', 39.417:: 150° O0 39.416 I5O° oo: 150° O0 39.418' 150° 00' 39.417" 150° 00', :59.417" 150° 00 39417" 150o00'39.418" 150o 00'39.42d' 150o 00':59.419" 150° 00'39. 150° 00' 39.419 150000' :59.417" 1 50o00'39.415" 150ooo'99.4~' 150o00':59.418'' 150o00'$9.413'' 150°00'39.410"I i ~a~ka Oil 1522' 149 7,' 1472, 1446 1422', 1:597 1:571' 1:547' 1:522' 1232' 1207' 1182' 1107' 10~2' 1057' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. OF.A/. , , ~ee,eeeeee..e .....~ee,eee ~ 1007' 982' 957' 281' 281' 281' 28 I' 281' 281' 281', 281 281' 282' 282' 282' 282' 282' 33.6' 33.6', 33.6 33.?' 33.8' :53.6' :53.6', $3.~ 33.8' 33.8' 33.8' 33.9' 33.9' 33.9' Pod Elev. 38.8' 38.7' :56.6' $e.e', $8.9 3,6.6, $8.6 36.7' 36.8' :58.8' $8.?; 38.7 , 36.7 38.6' 3,6.9' $8.7' 38.6' 3 8.6' ' ' 'KU~kUX ~,~o,~ct ---- D.S. 3H WELL CONDUCTOR AS-BUILT ' PREPARED LOUNSBURY Associates ANCHORAGE ALASKA D. WN BY: PJW J CHK BY: JWT , _ , . _ - July 31, 1987 J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Telecopy No. (907) 276-7542 Re: Kuparuk ]liver Unit 3H- 7 ARCO Alaska, Inc. Permit No. 87-79 Sur. Loc. 139.7'FNL, 281'FWL, Sec. 12, T12N, R8E, UM. Btmhole ]hoc. 1202'FSL, l124'FWL, Sec. 11, T12N, RSE, UM. Dear Mr. Kewim: Enclosed is t]he approved appliCation for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental 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. Ve__r=A truly~.~°tlrs, ~ Chairman Alaska Oil and Gas Conservation Co~mm_ission BY ORDER OF THE COMMISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Douglas L. Lowery -*--,,, STATE OF ALASKA ~-~- ALASKA _ AND GAS CONSERVATION CC ¢IISSlON PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill,~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test Lq Development Oil Re-Entry [] DeepenI-qI 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 76' PAD 39' feet Kuparuk River Field · ~ Kuparuk River Oil Pool 3. Address 6. Property Designation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1397'FNL, 281'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nurpber Number 1358'FSL, 1383'FWL, Sec.ll, T12N, RSE, UM 3H-7 //8088-26-27 At total depth 9. Approximate spud date Amount 1202'FSL, 1124'FWL, 5ec.11, T12N, R8E, UM 09/02/87 $500,000 12. Distance to nearest 13. ~)~_t~nce to nearest well 14. Number of acres in prOperty 15. Pro.posed depth(MD and TVD) 8486'MD property line 1124'~ TD feet 25' ~ Surface feet 2560 (6121'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff deptl~ 050 feet Maximum hole angle 51 0 Maximum surface 1 862 psig At total depth (TVD) 2998 18. Casing program Settin~l 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 3693' 35' 35' 3728 3146' 1100 sx AS I II & HF-EF[W 500 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8452' 34' 34' 8486 6121' 200 sx Class G(minimurr HF-EF',W TOC 5)0' abov; top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. 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 Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~r_ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~¢-Time vs depth plot .~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements c~//rt?r~-t'hlat the foregoin~q.j,s/,~ / true....a, nd correct, to the best of my knowledge . 21.1 hereby Si"ned / X .,f~,,¥c¢/.' '~' /? n er Dat~/7~,~~~- ~-' ~', Title Regional Drilling Engi e ~ \ / .¢'~..//~,-~¢i ,/~,' ;¢,~ ~. (. ~.'-¢--~'/ ~ ~- b' ~"/ '" Commission Use Only (JLQ) PD2/39 Permit Num/j~!~r__ / I AP, number . .. I Approval date / See cover letter ?-- ,..¢ [ 50-, .... o I 0 7 ^ / 3+,~1 / Q 7,,__vi. for other requirements Conditions of approval Samples required [] Yes ~. No Mud log required ,_; fe~ No Hydrogen sulfide measures ~ Yes ~ No DirectiOnal survey required ~ Yes ~ No Required worki~j;~,~~__~ 5M; ~ 10M; ~ 15M Other: by order of Approved by ~ '.. ,/- %~._~///~~h,/ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in/ .~ate · I ARCO ALASKA. INC. PAD 3H. WELL NO, 7 HROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA 0 . SURFAOE ! 000 _ 2000 _ 3000 _ 4000 _ 5000. 6000 _ ?000 KOP TVD-1050 TMD-1050 DEP-O 3 BUILD 3 DEe 9 PER 100 FT I$ B/ PERMAFROST TVDml5gl TMD-159g DEP-?8 21 T/ UGNU SNDS TVD-l?76 TMD'1795 DEP-143 35 45 EOC TVD-2540 TMD-2760' DEP-716 St T/ W SAK SNDS TVD-2556 TMD-2785 DEP-?35 K-12 TVD-2946 TMD-~40B DEP-1222 9 5/8' CSG PT TVDm3146 TMD-3728 DEP-1471 AVERAGE ANGLE 51 DEG 18 HIN K-5 TVD-4326 TMD-5615 DEP-2944 T/ ZONE D TVD=S876 TMD=8094 DEP=4878 T/ ZONE C TVD=S879 TMD=8099 DEP=4882 T/ ZONE A TVD-5906 TMD=8142 DEP-4915 TARGET CNTR TVD=59~8 TMD=8193 DEP=4955 B/ KUP SNDS TVD~5996 TMD=8286 DEP=5028 TD (LOG PT) TVD~6121 TMD~8486 DEP~S184 I I ~ I 1 000 2000 :3000 4000 VERTICAL SECT[ON I 5000 I 6000 I HOP I ZONT AL PROJECT I ON SCALE 1 IN. = 1000 FEET z o TD LOCATION, 1202' FSL. l!24' FWL SEC. !!, T12N. RSE ARCO ALASKA, PAD 3H. WELL NO' 7' PROPOSED KUPARUK FIELD, NORTH SLOPE. ALASKA 1000 1000 _ 2000 _ 3000 _ 6000 5000 4000 ! ,, ! TARGET CENTER TVD=5938 TRI0=8193 DEP-4955 SOUTH 2563 WEST 4241 WEST-EAST 3000 2000 1 000 0 I I, I I '~ SURFACE / SEC. II. TI2N. RSE S 58 DE(; 51 MIN W 4955' (TO TARGET) 1 000 SL~FACE LOCATION, 1397' FNL, 281' FWL SEC. 12. TI2N. RSE 1 O0 1 50 200 250 300 350 400 450 500 I I I I I I I I I 1 25O 1 300 1350 1 400 1450 1500 1550 i ,, ~,~500 ~ ~" 1 ~00~ ~ /' 1400 ~ ~' :' ~ ~ ~ -- -- ~To~O- : T~O0--~ 400 :~~~F- 500 koF~ ~so //1 600 KoP~ ~o ' / .J~ 500 700 //1000 11 200 1 200 ~.~0_o ~ I I I I 200 250 300 350 400 ¢1900 -"" 1800 I 100 ! 150 I 450 1 250 1300 1 350 1400 1450 1 500 1550 i 5OO KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC DESCRIPTION 1. 16" C0elDUCTC~ 2. FMC SLIP-ON WILD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH T~VO 2-1 / 16" 2000 PSI BALL VALVES 4. 20' 2000 PSi DRILLIN~ SPOOL W/10' OUTLETS :5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SII~LE VALVE OPENS AUT01qATICALLY UPON CLOSUI~ 0~ ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLE0 TO ACHIEVE 0OWNWINO DIVERSION. e,. 20' 2000 PS1 ANNULAR PI:~.VENTER 4 ARCO ALASKA, INC., REQUESTS API::~OVAL OF THIS OlVERTER SYSTEH AS A VARIANCE FROM 20AAC2S.035(b) MAtNTEN ,ANCE ~ OPERATION -o-L i 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, 2. CLOSE ANNULAR PREVENTER AND BLO~ AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DCN/NWIND DIVERSION. O0 NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 m i L 6 < > ,,h ~ DIAGRAM #1 13-5 _' 5000 PSI RSRRA BCP STACX -- A~TCR C. APACITY TEST I. (3.E~ ll~ FILL NI1AU.ATCR gEI)ERVOIR TO PR(IP~ LEVEL glTH ~C FLUID, Z. ~ THAT ~Tt:IR ~ I8 ~ I~1 I~TH I___~1_ I~1 ~ (lr TI~ RIgA.AT(IR. 3. ~ TZII~.,,, ~ CL(~E: AiL UI~T8 4. RE:CCI~ C~N NN3C I;~:PQ~, TIE N:]:EPT.I~LE L(3~I LZMZT IS 45 SE~ CI,.O~ll~ TI]~ AI~ I~00 P~% ~ININ~ 5 4 I:D-5/8' BC~ STACK TEb~ I. FILL BI~ 8'tN3( N~) CHI3~ ~O.D WTTH ~"1'IC ~Y LZ~ V~V~ 4. ~~~ TO 0 ~]. L[~ V~. ~T~ P[~ ~ ~~ V~ 6. ~ TO ~] ~ ~~Z ~ [N~ 4. WZ~ A ~~ L~~~Z HZ~ ~ ~ IN 8. 10. ~U[D. ~ ~ V~ [N ~[~ ~[T[~ 12. ~ST ST~I~ V~, ~Y, ~ly ~S, ~I~ PI~ 3~ ~I. 13. ~ ~ I~TI~ ~ ~~ ~ TEST F~, 5I~, ~ ~ TO ~I~I~ ~I~. 14. P~~ ~Y ~ ~I~Y ~TE ~ ~ILY, I '" 51C~84001 REV. MAY 1.5o 19,8 GENERAL DRILLING PP, OCE'DUIIE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. In~tall Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8%" hole to logging point according co directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole co provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement ?" casing. Pressure test co 3500 psig. II. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xnm8 tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow ouC preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and tes~ packer. 18. Nipple down blow ouc preventer 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. , , SHALE SHAKER~'- I"IUD '~ LEANER H ~ STI STIR _ R TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 ~eight 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 AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators 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 (Kuparuk average) 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. LWK5/ih wing valve 'reserve Pit lino~ swab valve master valve pad center [Plan-Viewi actuator valve g. I. valve I line psi gauge ,.,,.w.I. adaptor swab valve wing valve--- flow'cross actuator valve r Kuparuk Well-head Orientation ARCO ALASKA, INC. VR plug-. master valve well line valve View from Pad Center ii ARCO Alaska, Inc:~-'~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 16, 1987 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built (Wells 1-18) Location Plat- 3H Pad Dear Mr. Chatterton: Enclosed is an as-built you have any questions, location plat for the subject wells. If please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany II I ell ALL WELLS LOCATED IN SEC. 12, . .~.~ T. 12 N., R.8 E., UMIAT MERIDIAN.,'~' ' Ye 2 ! 4 7 8 9 lC II 12 13 14 15 16 17 18 'Y' ASPs 'X' 6,000,110.73 6,000,135.51 6,000, 160. 57 6,000,185.28 6,000, 210.66 6,000,235. 50 6,000, 260.34 6,000, 2:85.82 6,000,310.30 6,000, 335.43 6,000,425.3? 6, 000,45051 6,000,475.46 6,000, 500.41 6,000, 525.44 6,000,550.46 6,000,575.45 6,000,600.44 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 98,655.40 98,655.41 498,655.44 498,655.45 498,655.44 498,655.44 498,655.38 498,655.42 498,655.43 498,655.41 498,655.47 498,655.55 498,655.$9 LATITUDE 70° 24'41.531" 70°2:4'41. 775" 7' 0° 24,' 42.07 ~", 24 42.514' 70° Z4:4Z. 758:: ?00 24 43.005 70o 70° Z4,43.494 700Z4 43.741" ?0° Z4'44.6Z6" 70024'44.873'' 70024' 45.119" 70°24: 45.3__6~." 70°24 45.610 70024'45.856" 70o24'46.102'' 70024. 46.$48' LONGITUDE 150° 00' 39.416" 150°00',39.417, oo, 150° 00, 39.417 150° O0 39.416" ° 09: 150° O0 39.418 150e 00' 39.417" 150° 00; 39.417'; 150°00 39.417' 150000' 39.418" 150° 00'39.42d' 150° 00'39.419" 1so° 0o:39. 150° O0 39.419 150°00' 39.417' 150000. 39.415" 150o00'39,414- I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTSA LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. ¥1ClNITY MAP SCALE I"' 2 MIL[-$ NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19,35-441L-87-11, 8. O.G. ELEVATIONS FROM CED-RlXX- $471~ 6. HORIZONTAL POSITION BASEl)ON 3H CONTROL MONUMENTS PER LOUNSBURYS, Assoc. O{~tl F, N. L. 1546' ' 1522' 149 1472, 1446 1422' 1397' 1322 1232' 1207' 1182' 1107' 1082' 1057' IDist F.W.L. 281' 281' 281' 281' 281' 281: 281 281', 281, 281 281° 281' 26( 261', 261 281' 28 2' 282' O.G. El $4.0' 34.0' 33.9: 33.8 33.7' 33.7', 33.6 33.6' 33.6' 33.6' 33.7' 33.8' 33.8' 33.6', 33.8 33.8' 33.8' 33.8' er. Pod Elev. 38.8' 38.8' 38.7' 38.7' 38.8' 38.8: 38.9 38.7', 38.6, 38.6 38.7' 38.8' 38.8' 38.7; 38.7 38.7' 38.8' 36.g' ARCO Alaska Inc. PROJECT D.S. 3H WELL CONDUCTOR AS-BUIlT LOUNSBURY Associates ANCHORAGE ALASKA OWN BY: PJW CHKBY: JWT DATE: 6/9/87 NSK 6.308-d5 '(14 ~ 22) 28) .: (6) UIMER '(29 'ubru 31) 2. Is w~ll to be located im a a~ined pool ............................. i~ ~ loeat:ed proper rtSsr, ance ~xa otb~ wells .. ~ ................. Is operator tha only affected parry ................................. 8. Can pe=mit be approved before fi~een-day wait ...................... 9. Does operator have a bond in force .................................. 10 Is a conservation order needed 11 Is adminisu=ativ~ appr~-needed 12. Is the lease ~rnher app~~Ue ................ .,..~ , 14. Is conduator string providad ........................................ //~ 15 Will surface casing protect fresh water zones .... · eeeeeeeee eeeeeeeeeeeeee ~ 16. IS enough cement used to ci=culate on c~nchcuor and st=face ......... .~w ,, 17. Will cement ~ie im surface and intermediate or produation st:rings ... .~ 18. Will cement cover all known produa=ive h~rizorm ..................... ~ 19. Will all casing give adequate safety in collapse, tension and burst...~, " 20. Is this well to be kicked off frcm an exis~ we!lbore ............ : .f~ 21. Is old we!lbore abar~= procedure inc!udad on 10-403 ............ 22 Is adequate w~llbore separation proposed ~/- ' 24. Is the dm-~J_img fluid program schematic and ~-~t of equ/p~ t adequate 25. A=e necessaz~ d~gr~ and aesc=iptions of dive:~er and BOPE atzached. 26. Does BOPE have suffimienu presm:e ratiug - Test to 3 OOo psig .. 27. Does the choke m~n~*old ca:ply w/API tt9-53 (May 84) .................. 28 Is the presence of H2S gas probable ..... For exploratory and Strat~hic w~lls: 29. Are data presented om potential overp~~ zones? ................. 30. Are se_ism~c analysis data presented on shallow gas mmms .... , ....... 31. If an offs~e loc., are survey results of seabed condi=b=ns presented _ ,,, , (6) Add: Geolo~F: rev: 01/28/87 6,011 E Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infOrmation. VP O10,H02 VERIFICATION LISTING PAGE $ REEL H£ADER ERVICE NAME :EDIT ATE RIGIN : EEb NAME 172458 ONTINUATION # REVXO~IS REEL O~MENTS ILIS TAPE, ARCO ALASKA, INC, 3H'7, API 50-029'20079 * TAPE HEADER ** ERVICE NA~E IEDIT ATE 187/10/13 RIGIN IFSlA APE NAME ONTINUATION ~ :01 REVIOUS TAPE O~MENTS ILlS TAPE, ARCO ALASKA, INC, 3H-7, API 50-029-20079 EOF * FILE HEADER XLE NAME IEDIT ,00! ERVICE NA~E ER$ION # ATE ~ AXI~U~ LENGTH I 1024 XbE TYPE RE¥1OUS FILE INFORMATION RECORDS ** NE~ CONTENTS ~* COMMENTS ** UNXT TYPE CATE SIZE CODE o ? ooo ooo ooI 000 000 002 0 000 000 004 065 000 000 002 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 ;P 010,H02 VERIFICATION bISTING PAGB 2 $CHbUMBBRGBR AEASKA COMPUTING CENTER DMPANY m ARCO AbASKA, INC, ELb = 3H'7 IEbD m KUPARUK OUNTY = NORTH SbOPE BOROUGH TATE m ALASKA OB NUMBER AT AKCCI 72458 UN #1, DATE bOGGEDI 01 OCT 87 DPl dim KOHRING ASZNG · 9.625" ~3576'(bOGGER) " BIT SIZE = 8,5" TO B552'(bOGGER) YPE FLUID · bSND ENS'TY ' 10.0 bB/G R' - 4.22 $ 70 DF '8C0 SITY = 39.0 $ RMF m 4,23 $ 71 DF H m 9,0 RMC w 3.49$ 66 DF LUID LOSS · 4,8 C3 RM AT BHT m 2,11 ~ {47 DF IE~D REMARKSI .:5 STANDOFF USED ON OIL $ONDEi MATRIX DENSITY m SAND; BHS -OPENt HC s CAbIPERI L.DENS, m !,O; MUDCAKE BALSING ON FDC SKIDi THREE EXTRA PASSES REQUIRED TO VP OlO,H02 VERIFICATION LISTING , LEAN OFF TOOL; MAIN PASS LOGGED FROM 8475' TO AVDID ~UCK ON BOTTOM. OOL TYPES/~)U~OERS: DIS 1457 DIC 1308 PGS 508 CNC 1238 SGC 3533 PAGE THiS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE <SEE FILE EDIT,002 FOR 1,2" SAMPLED DENSITY D~TA> DUAL INDUCTION SPHERICALLY FOCUSED LOG FIRST TO LAST READINGI ~544' TO 3576' OIL REPEAT (8544' TO ~462') MERGED TO OIL LOG (8462 T9 3576') SP R~PEAT (8544' TO 84"40 ) MERGED :0 SP LOG (B44o' TO GR(DIb) REPEAT (8544' TO 8420' MERGED ?0 GR LOG (8420' TO 357 ') FORMATION DENSITY COMPENSATED bOG (F~N) FIRST TO bAST READINGI 8520 TO 725t' VP 030,H02 VERIFICATION LISTING PAGE 4 TO FDC ~OG (8436" TO786~") * AND GR LOG (7451' TO 7251 )' , * CNL REPEAT C8505 TO 84.30 ERGED * TO CN~ ~OG (8430" TO 7868') * AND CN~ LOG (7~51" TO 7~51'~ * GR(FDN) REPEAT (8521- TO 8442 ) ~RGED * 'TO GR bOG (8442~ TO 7868") * A~D GR bOG (7451' TO 7251") * GAMMA RAY IN CASING ~CH~) * FIRST TO hAST READING{ 3611~ TO 983 * DATA FORMAT RECORD NTRYBLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 8 4 73 60 16 VP 010.H02 VERIFICATION LISTING PAGE 5 0 1 66 0 ATUM SPECIFICATION BLOCKS NEN SERVICE SERVICE UNIT API API API APl FILE SIZE SPb REPR ORDER # CODE PROCESS 0000000 ID FLU DIb LD P DIL R ENS R FDN HOB FDN RHO FDN PHI FDN PHI FDN A FDN CNL FDN CNL FDN ENS FDN R CHL ENS CML LOG TYPE CLASS MOD NO, FT O0 000 O0 0 0 OHMM O0 2 0 OHMS O0 I 0 OHM~ O0 ~20 MV O0 10 GAPI O0 3 0 LB O0 GAP! O0 310 G/C3 O0 350 G/C3 O0 356 PU O0 890 IN O0 28O PU O0 890 O0 42O O0 000 CPS O0 330 CPS O0 3 0 bB O0 6]5 OiPI O0 310 LB O0 635 4 01 0 0 4 46 0 0 4 44 0 0 4 01 0 0 4 Ol 0 0 4 21 0 0 4 O1 0 0 4 O2 0 0 4 Ol 0 0 4 O0 0 0 4 01 0 0 4 O0 0 0 4 01 0 0 4 O0 0 0 4 31 0 0 4 30 0 0 4 21 0 0 4 O1 0 0 4 21 0 0 4 1 68 0000000 I ~8 00000000000000 8 00000000000000 I 68 00000000000000 I 68 00000000000000 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 8 00000000000000 ! ~8 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 68 00000000000000 ~ 68 O000000000000O t 68 0000000000000~ 8 000000000000 68 O00000000000gO 68 00000000000000 1 68 00000000000000 DATA EPT P HOB CNL 8572 5000 SFbU '1~ 000 453~ GR DRHO 50 1953 NRAT 444 2500 TENS 3 3 2920 725t ILD 3,6~ IbM 4 NRA 0000 GR -999,2500 TENS 55),t !/i°ooo EPT P {'lOB PHI CNL 2 45 512 000 SFbU 625 'Ga i629 DRHO 660 NRAT 000 TENS 542~ 343 375 TENS 273 DPH! 6230 RNRA 0000 GR 542~ -99~ 3400 CALX TENS )0 EPT P HOB PHI CNL 8400 0000 SFLU -36:0000 GR 31,3730 DRHO ,8164 NRAT 730,0000 TENS 0 3 5332 ZLD TENS DPH! 3 ':332 442 Ibl~ 000 GR · 8 0 CALl TENS ~000 '~500 EPT P HOB PHI 33 634 0000 SFLU DRHO 5449 NRAT 5000 TENS 9 8O 0 2 5232 8797 ZLD 6t2 TENS 00495 DPHI 9648 RNRA 0000 GR 7 5232 8364 IbM 0000 GR 7850 CALl 891 ~CNL 500 TENS 7 8O -999 ~EPT P 8200,0000 SFLU -42,5000 GR 16,4821 IbM 5280,0000 GR VP 010.H02 YERIFICATiON LISTING HOB PHI CNL EPT P HOB Pi-II P HOB PHI CNb EPT P HOB CNb EPT P HOB CNb gPT HOB b EPT 'HOB ~EPT :HOB ~PH I !HOB ~PHI 'CNb 2,5527 DRHO 37,7441 NRAT 626,5000 TENS 8100 0000 SFLU -38 5000 GR 2 3203 DRHO 55 0781 NRAT 397 7500 TENS 8000 0000 SFbU -57 5000 GR 2 4063 DRHO 50 8789 NRAT 428 5000 TENS ~ 5000 GR ~.~340 DR.O 4 , 492 NRAT 412,2500 TENS 7800 0000 SFLU -50 000o GR -999 2500 DRHO -999 2500 NRAT -999 2500 TENS 7700 0000 SFLU -6] 5000 GR -999 2500 DRHO -999 2500 NRAT -999 2500 TENS 7600 0000 SFLU -62 0000 GR -999 2500 DRHO -999 2500 NRAT -999 2500 TENS 7500 0000 &.FLU -57 5000 GR -999 2500 DRHO -999 1500 NRAT -999 500 TENS 7400 0000 ,bFLU -61 5000 GR I 3945 DRHO 3 2285 NRAT 583 5000 TENS 7.30 ,0000 S~bU 580,0000 G 0 0093 DPHI 3i1973 RNRA 5280 0000 GR :8256 12 4375 TENS ~!0249DPHI 1406 RNRA 519 0000 GR 1t4 0 3 5300 04 I XLD 37~0 TENS 0063 DPHX 9102 RNRA 0000 Ge 3 128 0 3 4984 3744 ILD 8750 TENS 0234 DPHI 7500 RNRA 0000 GR 1 4367 ILD 399 0000 TENS -999 2500 DPHI -999 2500 RNRA -999 2500 GR 5 ~59 ILO O0 TENS -999 500 GR 4 0387 ILD 105 6250 TENS -999 225500 DPHI -999 O0 RNRA -999 2500 GR 4 126 '999 -999 ,,999 160 ILD 43751 TENS 2500 DPHI · 2500 RNRA 2500 GR 9 86 0 456~ ILD 6§40 0098 · 0000 GR 3 0260 ILD 128:0000 TENS 5,8949 CALI 3,4668 NCNb -999,2500 TENS 4 -999 8200 IbM 0000 GR 9811 CALX 1797 NCNb 2500 TENS 5300 1 -gg ,6904 ~'RbM ,0000 ,7727 CAb! ,7734 NCNb ,2500 TENS , I:o ooo 19, NCNb ""999,2500 TENS -999 '999 -999 0 NCNb 500 TENS 3 4844 '999 -999 -999 9712 IbM 0000 GR 2500 CALl 2500 NCNb 2500 TENS 486~ '999 '99.9 '999 650 IbM 000 GR 2500 CALX 2500 NCNb 2500 TENS '999 -999 2500 CAbl 2500 NCNb 2500 TENS . GR , ~ NCNb '999, 5 TENS 3.0805 ~LM 4548,0000 GR PAGE 8,4375 2172,0000 ,,999,2500 1,9105 1664,0000 ",999,2500 8,3672 ~707;0000 9~9,~500 ::g oo '"' tho "999 O0 . ~,9919 OO " 'tloo -999;2500 -999,2500 -999 .,999, -999, ',999, '999, iO0 1283~ VP OlO,MOR VERIFICATION LISTING PAGE 7 HOB 2,4512 ORHO 0,07742 DPHI CNL 478,0000 TENS 4548 000 GE EPT 7200,0000 SFbU P -59,5000 GR HOB -999'2500 DRHO PHI --999,2500 NEAT CNL --999,2500 TENS 6250 TENS .999,2500 DPHI 999,2500 RNRA '999'2500 GR EPT 7100,0000 SFLU 4 P "89,0000 GR 98 HOB ".999,2500 DRHO -999 PHI --999,2500 NEAT ".999 CN5 -999,2500 TENS ".999 02 3 IUD 68~5 TENS 500 DPHI 500 RNRA 2500 GR EPT P HOB PHI CNL 7000 0000 SFbU -08 5000 GR -999 2500 DRHO ".999 2500 NEAT -999 2500 TENS 3 8405 ILD 105 5000 TENS -999 2500 DPH! -999 2500 RNRA ".999 2500 GR EPT P HOB PHI tnb 6900 ".30 -999 ".999 ".999 0000 o00o G 2500 DRHO 500 NEAT 500 TENS 4 103 ".999 '999 "999 0387 ILO 4375 TENS 2500 DPH! 2500 RNEA 2500 GR EPT NOB PHI CNL 6800 0000 SFLU -43 0000 GR -999 2500 DEMO -999 2500 NEAT -999 2500 TENS -999 -999 "..999 79020 ILO 75 0 TENS ~2~o0 DPHI 2~00 RNRA O0 GE EPT P HOB PHI CNL 6700,0000 SFLU 3.,97~3 IbD -26,5000 GR 87,i3 5 TENS '999,2500 DRHO '999, 500 DPH! 500 RNRA ".999,2500 ~RAT '999'~500 GR ".999,2500 TENS '999, EPT P HOB PHI -999 -999 ".999 2500 DRHO 2500 NEAT 2500 TENS '999 '999 500 DPH! 500 RNRA 500 GR ~EPT P HOB PHI CNL 6500,0000 SFLU -20,5000 GE -999,2500 DRHO -999'2500 NEAT -999,2500 TENS 3 03 -~99 -999 -999 8882 8125 TENS 2500 DPH! 2500 RNRA 2500 GR 'EPT P 6400,0000 SFbU -16,0000 GR 12,0502 CAbI "9 2500 TENS 3,91!7 ibm '4540,0000 GR --999,2500 CAbl ;2500 Nb ,2500 TENS 450~,2374 lb~ ,0000 GR "999,2500 CAb! -999,2500 NCNb -999,2500 TENS 4 1553 IbM 4404 0000 OR -999 2500 CAUl -999 2500 NCNb -999 2500 TENS "'999 -999 -999 500 CAbI 500 NCNb 500 TENS 6 4384 -999 -999 -999 500 CALl 500 NCNb 2500 TENS 41284 *o999 '999 ".999 0000 2500 2500 NCNb 2500 TENS -999 500 CALl 500 NCNb 2500 TENS 4 2340 IbM 402~ 0000 GR , 0 9 2.500 TENS 8,703! 1864,0000 -999,2500 "999, o -999,3500 4,3t65 -999,3500 "999,;~500 .,999~,2500 -999.2500 -999: -999,{,900 -999,;~500 -999.2500 -99'9 .,,, -999 6,8086 -999,~500 oo "999*2500 -99~le fllp '99! 4 "999 O0 O0 O0 ,6386 ILD 0679 IbM ,~ g~,3750 TENS 418~4' -9994, ,0000 GR VP O!O,H02 VERIFICATION hISTING PAGE 8 PHI 99,2500 NRAT CNL -999,2500 TENS PT 6300,0000 SFLU "33,0000 GR HOB -999,2500 DRHO PHI -999.2500 NRAT CNb -999.2500 TENS EPT 6200,0000 SFbO P .'33,5000 GR HOB 999,2500 DRHO PH! '999.2500 NRAT CHh -999,2500 TENS EP? 6~00,0000 SFbU . ]4,0000 GR ~OB 999,2500 ORHO PH:! -999,2500 NRAT CNb -999,2500 T£NS EPT 6000,0000 $FLU P -42,0000 GR HOB -999,2500 DRHO ~Hl!' -999,2500 NRAT '" -999~2500 TENS EPT 5900 P HOB 999 PHI -999 C~L -999 0000 SFbU 0000 GR 2500 DRHO O0 TENS 5800 -999 -999 -999 0000 ~LU 5000 ~ 2500 DRHO 2500 NRAT 2500 TENS HOB -999 P~! -999 C .L -999 0000 0000 500 D~HO 500 500 EPT 5600 P -37 HOB -999 PH! -999 CNL -999 0000 ~FLU 0000 ;R 500 DRHO 500 NRAT 2500 TENS EPT P -999,2500 DPHI -999.2500 RNRA '999,2500 GR 3 7748 '00 8125 '"~}99 2500 '999 2500 '999 2500 3 9319 98 6250 -,999 2500 -999 500 -999 ~500 500 -999 2500 -999 2500 -999 2500 3 3106 100 9375 -999 2500 -999 2500 -999 2500 i 5838 I~ 6875 -9 2500 -999 2500 -999 2500 3 5687 100 ~,250 -999 2500 -999 2500 -999 2500 II.,D TENS DPH! RNRA GR TENS DPHI RNRA GR TENS DPH! RNRA GR TENS DPH! RNRA GR bD DPH! RNRA GR TENS DPH! RNRA GR 2266 IbD 99,2500 RNRA -999,2500 GR 11~ 9306 3125 '99 '99~ 2500 2500 -99§ 2500 · . ooo TENS DPHI RNRA GR TENS -999 2500 CAbl -999:2500 NCNb -999,2500 TENS 4,0379 IbM ,0000 ~910 999,2500 C~b/ '999,2500 NCNb '999.2500 TEN~ 38 ~,3729 ibm ,0000 GR -9 9,2500 CAb! ,2500 TENS 4,2545 IbM 36 ,2500 CAbI .9~'0000 Ge -999,2500 NCNb ,,,999,2500 TENS 37103 5572 0000 -999 2500 -99~ 2500 -99 2500 3 7791 3614 0000 -999 2500 -ggg 2500 -999 2500 .35303 87 oo o o :9,, ! oo 999 O0 -999 O0 000 -999 2500 -999 O0 3 1729 3430 0000 ~500 '999 500 CAb! TENS IbM GR CAbI NCNb TENS R CAbI NCNb TENS CkbI NCNb TENS, IbM GR CAb! NCNL TENS . 4066 IbM 330 .0000 GR -999,2500 -999 ~ 2500 -999,2500 4,0t44 -999;3~00 -999~00 ~999~2500 '""]{oo -999~2500 ~999~ 29 -III - ~$00 -999 2500 .9, ., , ILo -~9 ~5oo .,,} -,,, '999 '999 250~ ~9 -999 VH 010,H02 VERIFICATION LISTING PAGE 9 HOB -999,2500 DRHO PHI -999,2500 NRAT CNb -999,2500 TENS -999.2500 DPHI '999,2500 RNRA "999.2500 GR EPT PHI CNI., 5400 0000 SFbU -58 7500 GR -99 2500 NRAT -99~ 2500 DRHO -999 2500 TENS 4375 TENS 999,2500 DPH! -999,2500 RNRA -999,2500 G{~ EPT P HOB PHI CNt, 5300 0000 SFbU -63 5000 GR -Egg 2500 DRHO -999 ~500 NRAT -999 500 TENS 0 TENS -Egg 500 DPHX -999 500 RNRA ,,.Egg 500 GR P HOB CN~, 5200 0000 SFbU -45 0000 OR -999 ~500 DRHO -999 500 NRAT -Egg 2500 TENS 1 141 -999 -999 -999 0 XLD 8 ~0 TENS 500 DPHX 2500 RNRA 2500 GR PT HOB 5100 -999 -999 -999 0000 SFbU SO00 GR 2500 DRHO 500 NRAT ~500 TENS 10~ T NS -gE 2500 DPHI -gE9 2500 RNRA -999 2500 GR EPT P HOB I:,HX CNL, 5000 0000 SFLU - 2500 DRHO -999 2500 NRAT -999 2500 TENS 4 0006 lbo 144 1250 TENS -Egg 2500 DPHX -999 2500 RNRA -999 2500 GR EPT ~p HOB 4900 -54 -999 -999 -999 000 SFbU 500 GR 2500 DRHO 500 NRAT 500 TENS Egg -999 -999~ 0 DPHI 500 RNRA 500 GR SFLU GR DRHO NRAT TENS -999, O0 DPHX '999. O0 RNRA '999,' O0 GR ~EPT :HOB }PHI 'CNL '999 -999 -999 000 SFLU 50O OR NRA. T 2500 TENS -999 -999 TI~NS RNRA 500 GR ~EPT 4~00,0000 SFbU 58,0000 GR 9375 ~ENS -999,2500 CALX -999,2500 NCNb -999,2500 TENS 5 33B0 -999 -999 -999 OiOi IbM 0000 GR 500 CAb! 500 NCNb 500 TENS -999 -999 -999 408], ~ oooo 2500 CALX 2500 NCNB 2500 TENS -999 -999 -999 9144 0000 GR 2500 CAbI 2500 NCNb 2500 TENS -999 -999 ,,999 500 CALX 500 NCNB 500 TENS 0 GR 500 CAbI O0 TENS 0000 2500 CALl 2500 NCNb 2500 TENS · 99~ 0000 2500 CAL, X 2500 NCNb 2500 TENS R NCNb -999,2500 TENS 000 , -999,2500 -Egg,2500 '999.3500 -999. O0 -999; O0 -99~, O0 -999,{S00 -990, -999. '9990 : ,Z$O0 ,'00 O0 -9! -' i'O0 VP OIO.H02 VERIFICATION LISTING PAGE HOB -999 2500 DRHO PHI -999[2500 NRAT CNL -999 2500 TENS EPT 4500,0000 SFbt.! -58,2500 GR ~OB -999,2500 DRHO PHI -999,2500 NRAT CNL -999,2500 TENS EPT 4400,0000 SFbU P -56,0000 GR HOB -999;2500 DRHO PHI -999,2500 NRAT CHh -999,2500 Tgt)$ EPT 4300.0000 SFLU P -61,2500 GR HOB '999,2500 DRHO PHI -999,2500 NRAT CNL -999,2500 TENS EPT 4200 P -60 HOB -999 PHI '999 CNL -999 0000 SFLU 7500 GR 25O0 DRHO ilO0 NRAT O0 TENS EPT HOB NL 4100,0000 '61;i500 '999, 500 -999,500 SFLU GR DRHO NRAT TENS HOB 4OO0 - 2 0000 SFbU 25OO 2500 GDRRHO 2500 NRAT 25OO TENS HOB '{PHI ~C N L 3900 -999 -999 -999 0000 ~R~bU 75OO 25OO DRHO 2500 NRAT 2500 TENS 'EPT HOB 3800 -999 -999 -999 0000 SFLU 500o GR 2500 DRHO 25OO NRAT 2500 TENS 'EPT ;p 3100.0000 SFLU 65,7500 GR -999,2500 DPHI -999.2500 RNRA -999,2500 GR ! -999;2500 DPHI -999;225500 RNRA '999, O0 GR 104, 0 TENS '999,2500 DPHI '999,i~00 RNRA '999, O0 GR 3 2850 111 0000 -999 2500 -999 2500 -999 2500 3 2724 0000 ,-999 2500 ,,,999 2500 -999 2500 3 2977 102 5625 -999 25O0 -999 2500 -999 2500 3 1899 2500 -999 2500 -999 2500 "999 2500 -999 2500 -999 2500 ?3O8 8 7500 -9999 2500 -99 2500 -999 2500 TENS DPHI RNRA GR lbD TENS DPHI RNRA GR TENS DPHI RNRA GR ILD TENS DPHI RNRA GR IUD TENS DPHI RNRA GR '999,2500 '999,2500 '999,2500 3,7542 2900,0000 '999,2500 "999,2500 '999,2500 4 0317 3084 0000 -999 2500 -999 2500 -999 2500 3 7455 2780 0000 ,,,o 2741 6439 0000 -999 2500 -9 . gg 2500 3 7975 oooo 99 2500 -999 2500 -999 2500 4 0837 270 ..999~ 0000 .,o 295~ 8474 0000 ...999 2500 "9999 2500 '99 2500 CAbI NCNb TENS GR CALl NCNb TENS -999,2500 0999 ~ 2500 '999"2500 7.7550 !LD 5.7824 IbM ) 60.5938 TENS 2294,0000 GR .'99 : ILD 6,5286 ILM 6 6 32 TENS 2520,0000 GE -9991 5 ~00 DPHI -999,2500 CAbI -999,, ~0 RNRA -999,2500 NCNb -99! }00 GR -999,2500 TENS -99! ~00 GR ",999,, NCNb -999, TENS '999, GR CAb -999,i 06 NCNb -999~:;~500 TENS ~999~2500 IbM . OR 999,2$00 CAbI ,,999,2500 NCNb -999,2'{00 TENS m999,.2500 GR CAb! -9! NCNb -9! ~0. TENS -99! ~0 GR CAb! "9! iO0 NCNb -9! iO0 TENS -9! )0 VP OlO,H02 VERIFICATION LISTING PAGE 11 HOB -999,2500 DRHO PHI -999,2500 NRAT CNL -999,2500 TENS EPT HOB CNb 'EPT HOB 'EPT !PHI ~CNL ~p :HOB CNL [HOB EPT 'CNb ;P iHOB IPfiI :CNb ~P ~HOB EPT P 3600 0000 -75 0000 -999 2500 -999 2500 SFbU DRHO NRAT -999 ~500,0000 .999.2500 999,2500 '999,2500 -999,2500 ~400,0000 999,2500 -999,2500 '999,2500 -999,2500 3300,0000 -999,2500 -999,2500 '999,t~00 -999, O0 oooo 99 2500 -999 2500 -999 2500 -999 2500 2500 TENS GR DRMO NRAT TENS SFLU GR DRHO NRAT TENS SFbU GR DRHO ?E DRHO NRAT TENS oooo 2500 -999 2500 DRHO -999 2500 NRAT -999 2500 TENS aoo '999 -999 -999 0000 ~RFbU 2500 2500 DRI,IO 2500 NRAT 2500 TENS 2900 0000 -999 2500 -999 2500 -999 2500 -999 2500 GR DRHO NRAT TENS ,0000 SFLU -289~ ,2500 GR :~99,2500 DPHI 99,2500 RNRA '999,2500 GR 3 1311 ILO 84 0000 TENS -999 2500 OPHI -999 2500 RNRA -999 2500 GR -999~ 2500 lbo -999 2500 TENS -999 2500 DPHI '999 2500 RNRA '999 2500 GR -999 2500 lbo -999 2500 TENS -999 2500 DPH! -999 2500 RNRA -999 2500 GR -999 -999 *'999 *'99~ "99 t500 lbo 500 TENS 2500 DPHI 2500 RNRA 2500 GR -999 -999 -999 -999 -999 2500 lbD 2500 TENS 2500 DPHI 500 RNRA 500 GR -999 '999 *'999 *"999 '999 i500 500 TENS 500 DPH! 500 RNRA {500 GR ,2500 ~ENS "999,2500 DPHI -999,2500 RNRA *'999,2500 GR '999 "99~ -99 2500 2500 2500 DPHI 2500 RNRA 2500 GR -999,2500 lbD -999,2500 TENS -999 2500 CAb! '999~2500 NCNb '999,2500 TENS 3 5163 ibm 2410 0000 GR -999 2500 CAb! -9992500 NCNb 90 2500 TENS -999,2500 ~bM '999,2500 GR -999,~2500 CAbZ -999,2500 NCNb 56,8125 TENS -999,2500 IbM '999.2500 GR -999,2500 CAb! '999.2500 NCNb 50,1250 TENS -999,i500 IbM -999 500 GR 40 O0 TENS -999 -999 .'999 -999 500 IbM 500 GR 500 CALl 500 NCNb 500 TENS -999 -999 '999 ..999 46 i500 IbM 500 GR 500 CAb! 500 NCNb 125 TENS R CAbl NCNb TENS CAb! NCNb TENS *'999, O0 -999, -999,2500 3,{488 '999~{500 '999e~500 -999,~500 2334,0000 -9 9, 0 ~999~S00 2404,0000 *'999, *'999, 2300,0000 °999 .00 ii!! 2144 '99~ "999 2204 )0 ~0 2~94 ~00~ '9! ~0 O0 O0 m~ 0 - 2O VP 0!0.H02 VERIFICATION LISTING PAGE 12 HOB -999 2500 DRHO P~! -999~2500 NRAT CNL -999.2500 TENS -999,~500 DPHI 99.2500 GR EPT P HOB PHI CNL 2700 0000 SFLU -999 2500 GR -999 2500 DRHO -999 2500 NRAT '999 2500 TENS -999 2500 -999 2500 TENS -999 2500 DPH! -999 2500 RNRA -999 2500 00,0000 BFLU -999 ~PT . 2~99,2500 GR '999 HOB '999,2500 DRHO '999 PHI "999,2500 NRAT '999 CNb -999,2500 TENS -999 O0 IbD ~00 TENS 2500 DPHI O0 RNRA EPT P HOB PHI 2500 0000 SFLU · .999 2500 OR -999 2500 DRHO -999 2500 NRAT -999 2500 TENS -999 -999 -999 -999 -999 -999.2500 CALl -999.2500 NCNL 42.5000 TENS .PT HOB 40 0000 GS[LU 99092500 -999 2500 DRHO '999 TENS -999 -999 -999 -999 -999 -999,2500 IbM '999.2500 GR ggg, 0 NCNb 47,9062 TENS 2300.0000 SFbU '999,2500 GR -999.2500 DRHO -999.2500 NRAT -999,2500 TENS -999 '999 -999 -ggg 55 EPT P HOB PHI ~200 0000 SFbU 999 ~500 GR -999 500 DRHO -999 2500 NRAT -999 2500 TENS 500 500 GR 500 CAb] 2500 NCNb 5000 TENS P NOB PHI 'CNL .2100 ggg '999 999 500 TENS 500 IbD -999.2500 IbM 500 TENS -999,2500 GR O0 RNRA -999.2500 NCNb 2500 OR 39,4063 TENS bD ~500500 500 ~00 500 GR EPT P HOB PHI CNb .2oo0 999 -999 ,,,,999 -999 0000 SFLU 2500 G~ 500 DRHO §00 NRAT 2500 rE~.S -999 2500 -999 2500 TENS -999 2500 DPHI -999 ~500 RNRA -999 500 GR ~EPT ,p 1900.~000 SFLU 999. 500 GR -9992500 -gg9 2500 TENS -999 25,00 DPHI -999 2500 RNRA -9992500 OR -999 -999 -999 -999 -999 TENS 25500 DPHI 2 O0 RNRA 2500 GR -999 2500 IbD -999 2500 TENS -gg9 2500 DPH! -999 2500 RNRA -9992500 GR -ggg,2500 -999.2500 TENS -999 -999 -9gg -999 500 IbM 500 GR 2500 CAbI 2500 NCNb 9062 TENS -999.2500 IbM '999.2500 GR "999,2500 CibI -999,2500 NCNb 27,6406 TENS -999 ..999 -999 -999 30 ,oo° 2500 CibI TENS -999 '9gg ,2500 2104,0000 ~00 '99~ '0 -" {'00 I )00 ,,,,999.{500 -999;2500 -99~,250o 1995,0000 9 -999.2500 '999,,t500 940 e 000 -999,2500 -999,2500 -999~2500 "999~.2500 1830;0000 .,999"' 0 -99g,{$00 0999'2500 1735.0000 NCNb .,9.99. 10000 2500 TENS 1655 0000 -999 2500 IbM -999 2500 GR -999 2500 CAb! '999 2500 NCNb 50 2813 TENS '999,2500 IbM '999.2500 GR "" -999 1695 0000 ,,,999.2500 -,999.2500 VP 010,MO2 VERIFICATION LISTING PAGE 13 HOB -999 2500 DRMO PHI -999:2500 NRAT CNb -999,2500 TENS EPT 1800,0000 SFLU -999,2500 GR ~OB -999.2500 DRHO PHI -999,2500 NRAT CNb -999,2500 TENS EPT 1700,0000 SFbU P -999,2500 GR HOB -999,2500 DRHO PHI m999,2500 NRAT CNb -999,2500 TENS £PT P HOB PHI EDT HOB HOB EPT ~EPT :HOB 1600 0000 -999 2500 -999 ~500 -999 500 -999 2500 GR DRHO NRAT TENS 1500,0000 ~FLU -999,2500 R -999,2500 DRMO -999,2500 NRAT -999,2500 TENS 1.400,0000 SFbU 999,2500 GR :999,25oo NRA 999,2500 TENS 1.300,0000 ~t,U .999;2500 : 999,' 2500 DRHO .999,2500 NRAT '999;2500 TENS 1.200,0000 999,2500 GR -999 ,,2,500 DRMO :999 2500 NRAT 999'2500 ~I00,0000 SFbt) 999,2500 GR -999,2500 DRHO -999,2500 NRAT -999,2500 TENS !000,0000 8FLU 999,2500 GR '999,2500 DPHI '999,2500 RNRA '999,2500 GR -999 2500 -,999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250O -999 2500 2500 2500 -999 2500 -999 2500 -99 O0 · -999 2500 -999 2500 -999 25O0 -999 25OO -999 2500 -999 2500 -999 2500 -999 25OO -999 5OO -999 ~500 -999 2500 -999 ~500 -999 500 99 250O o 25O -999 2500 -999 2500 -999 2500 -999 2500 -999 25OO -999 -999 -999 40 .2500 ,2500 ,4063 IbD '999,2500 TENS '999.2500 DPHI '999,2500 RNRA -999,2500 GR 28,8281 IbD -999,2500 TENS '999,2500 DPHI '999,2500 RNRA '999,2500 GR 31,1562 lbO ~999. TENS :999, DPHI 999, RNRA '999, GR 31, tD -999 EN$ -999 DPHI '999 RNRA -999 GR 24 IbD "999 TENS '999 DPH! -999 RNRA '999 GR 33 ILD '999 TENS -999 DPHI -999 RNRA '999 GR 45 IbD -999 TENS -999 DPHI ~999 RNRA '999 GR 43 5OO 5OO 5OO 50O 906 500 500 844 2500 2500 2500 2500 6875 500 500 soo 25OO 0313 2500 2500 2500 2500 7t88 ILD -999,2500 TENS -999,2500 DPM! -999,2500 RNRA -999'~500 GR 48,7188 -9999,~§00 IbD "'999,2500 '99 , TENS "999.2500 CAbI NCNb TENS GR CAb! NCNb TENS GR CAb! NCNb TENS GR NCNb NCNb TENS IbM GR CALl NCNb TENS N'CNL, TENS IbM GR CAbI NCNb TENS GR CAb! NCNb TENS -999,2500 -999,2500 1625,0000 -999,2500 -999,~500 -999.2500 -999,2500 1600,0000 -999,2500 -999,2509 -999.2500 1540;0000 -999,2500 -999,2500 - 9 , 500 1465,0000 '"' -999 1405 :999 .00 .999 ~', O0 -99~ 2500 130 0000 ~999 -99~ ~0 125 000 "9' '999 ~999 ~000 -999 '999 :500 0 0 1081 ~0 '""t Sg -999, VP OlO,H02 VERIFICATION LISTING HOB -9992500 DRHO -999.2500 OPHI 9992500 CAbI PHI -999:2500 NRAT -999'2500 RNRA -'999 :2500 NCNb CNL ..999,2500 TENS -999,2500 GR 25,0]1) TENS EPT 980,5000 SFbU P -999,2500 GR HOB -999,2500 DRHO PH! -g99,2500 NRAT CNL -999,2500 TENS -999,2500 IbD -999 500 TENS -999 500 DPH! -999 2500 R~RA -9992500 GR * FILE TRAILER ILE NAmE :EDIT ,00! ERVICE NAME ATE : AXiMU~ LENGTH : ~024 I~E TYP~ EXT FILE NAME : EOF ********** [I* bE HEADER IL NAME :EDIT ,002 ERVICE NAME : ERSiON # : AXIMUM LENGTH : 1024 XLE TYPE : REVIOUS FILE COMMENTS -999,2500 IbM '999,2500 GR '999,2500 CAL! '999,2500 NCNb 26'B437 TENS PAGE 14 -999,2500 -999;2500 1040,0000 -999,2500 -999, O0 .,9,.tloo lull:: 0000 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLA¥~ FIELD PRINTS VP O10,N02 VERIFICATION blSTING , PAGE 15 SCHLUMBERGER bOGS INCLUDED WITH THIS FILE FILE EDIT,OOX FOR 6" SAMPLED DIb/FDC/CNb/GR FORNATION DENSITY COMPENSATED hOG (F~H) FIRST TO LAST READING= 8520' TO 7890' COMPENSATED NEUTRON bOG (FDM) FIRST TO LAST READING= 8505' TO 7890' GAMMA RAY LOG (FDH) FIRST TO LAST READING= 8496' TO 7890' DATA FORMAT RECORD ** NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 1~ 9 4 65 .XIN 16 ~ 66 1 0 ! 66 0 ATU~ SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT AP1 AP1 APl API FILE ID ORDER # LOG TYPE CLASS MOD NO, FT O0 000 O0 0 0 i PT FDH GAPI O0 310 O1 0 0 HOB FDH G/C3 O0 350 02 0 O ~R'HO FDH G/C3 O0 356 01 0 0 [PHI FDH PU O0 890 00 0 0 AL! FDH IN 00 280 O! 0 0 ~PHI FDH PU O0 890 O0 0 0 RAT FDH O0 420 01 0 0 ,NRA FDH O0 000 O0 0 0 SIZE SPb REPR PROCESS CODE (OCTAb) 4 I 68 000000000OO000 4 1 68 00000000000000 4 I 68 00000000000000 4 I 68 00000000000000 i t 68 00000000000000 1 68 00000000000000 4 1 68 00000000000000 4 I 68 00000000000000 4 I 68 00000000000000 ,. <, VP 010,H02 VERIFICATION LISTING CNL FHH CPS 00 330 CNb FDH CPS 00 330 EN$ F{)H LB 00 635 31 0 0 4 3O 0 0 4 21 0 0 4 DATA EPT PHI NRA 85~,4004 GR ,~680 CALl 3, 336 NCNb 8500,1992 GR 31,1733 ClhI ,3750 NCNb 8400,1992 GR 13,4422 CALl ,9141 NCNb 8)00,1992 GR i7~2585 CAbI 2,9023 NCNb 8200,1992 GR NCNb 8100,2998 GR 18,5790 CAbI 3.7363 NCNb 8000,2998 GR 13.2339 ~AbI 4,1875 CNb 7900.2998 Ga 1~t6259 CAbI ,5781 NCNb 7889.70~ GR 18,20 CAbI 4,0000 NCNb £PT PHI EPT PHi NRA EPT PHI NRA EPT pH! NRA EPT PHI EPT PHI NRA EPT PH'! NRA PT I0~.6875 RHOB ,5430 NPH! 1829.0000 FCNL 108,8 25 RHOB 0000 5~.7500 RHOB ,7461 NPHI 2450,0000 FCNL 78,1875 RHOB ?,9609 NPHI 2142.0000 FCNL 6~,0938 RHOB ,9102 NPH! 2254.0000 FCNb 0000 ~HOB .o.oooo 8750 RHOB 1604, FCNL 11~,7500 RHOB 1658,4219 NPH! ,0000 FCNL 131 .~!0 RHOB '60 ~ NPH! 176 , FCNL $ FI.bE TRAILER XLE NAME I~DIT .002 ERVICE NAM~ ERSION # ATE { AXZMUM LENGTH I 1024 !bE TYPE EXT FILE NAME PAGE 16 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ,705~ DRHO o 464 TENS 43 NRAT 574~ 000 TENS 203457 DRHO 32,5684 NRAT 840.5000 TENS 3{0)652 DRHO ,7168 NRAT 738,0000 , 68 DRHO 605,000 , NRA? 452, 500 TENS 2.4346 DRHO 54,~3 7 NRAT 383, 000 463,2 TENS ' A NRAT 441, TENS -~,06{0 0000 5461!0093 2,8496 $412.0000 0,032! 2.902 5288;0000 !' 0,0464 554~ '1055 eO000 ~P 010,H02 VERIFICATION LISTING PAG£ ~? * TAPE TRAIhER ** ERVIC£ NAME :EDI? ATE APE NAME ONTINUATION # EXT TAPK NAME DM~ENT$ Ibis TAPE, ARCO A6ASKA, INC, 3H-7, API 50-029-2'0079 $ REEb TRAI6ER ERVICE NA~E tEDIT ATE RIGIN I EE6 NAME t72458 ONTIMUATION # ~0~ EXT RE£6 NAME ; OMMENT$ ~6I$ TAPE, ARCO A~ASKA, INC, EOF