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Home My WebLink About198-101 STATE OF ALASKA AL, _,:A OIL AND GAS CONSERVATION CON. _SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate "' Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:�{/\A-O se.472 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-101 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-22887-00 7.Property Designation(Lease Number): 8.Well Name and Number: 'R1'( //� ADL 025639 WSAK 1 H-401 S#144A U-444 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 4,yZ. 15 11. Present Well Condition Summary: Total Depth measured 5511 feet Plugs(measured) None true vertical 3199 feet Junk(measured) None Effective Depth measured 5145 feet Packer(measured) 3350, 3388, 3432, 3599 true vertical 3197 feet (true vertical) 2909, 2938, 2972, 3087 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 121 121 0 0 SURFACE 3941 13 3982 3205 0 0 LINER 1620 7 5187 3197 0 0 ' 1.:A,N IEL�I SEP 1 -Ins' 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 3693-4161,4182-4682,4702-5144 RECEIVED True Vertical Depth: 3137-3210,3210-3186,3189-3197 V JUN 152015 Tubing(size,grade,MD,and TVD) 4.5, L-80, 3463 MD, 2995 TVD AOGCC Packers&SSSV(type,MD,and TVD) PUMP-4 1/2 REDA PCP PUMP ON 3.812 XX-LOCK(38'4.75"OAL)IN X NIPPLE @ 3350 MD and 2909 TVD TUBING ADAPTER @ 3388 MD and 2938 TVD MOTOR-REDA 540 SERIES MOTOR, 7OHP,42 AMP @ 3432 MD and 2972 TVD WLEG-WIRELINE RE-ENTRY GUIDE @ 3599 MD and 3087 TVD SSSV=None @ 0 MD and 0 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 96 3 24 230 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Fr- Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email n1139(a�conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone:659-7535 Date 60 . /Z • /5 Form 10-404 Revised 5/2015 vii- of 3// de f/, '(5"--- Su It Original Only RBDMS s\ JUN 16 2015 1H-401 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/22/15 PULLED 3.812 XX LOCK&4-1/2" REDA PUMP @ 3350' RKB. SET NEW 3.81 XX LOCK&4- 1/2" REDA PUMP (OAL 38' 3.75"). COMPLETE. 05/24/15 Well returned to production KUP PROD 1H-401 ConoccPI IiI IIps - Well Attributes Max Angle&MD TD Alaska,Inc. welroere APuuW Field Name Wellbore Status Inc!(') MD(ftKB) Act Btm(ftKB) (r..,,,',,-,ip, 500292288700 WEST SAK PROD 98.94 4,361.94 5511.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1H-401,2/18/20157.59.08 AM SSSV:NONE 7/20/2007 Last WO: 11/3/1998 45.00 6/20/1998 Vertical schematic(actual) Annotation - Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,670.0 3/26/2013 Rev Reason:GLV C/O hipshkf 2/27/2015 iCasing Strings HANGER;38.0 j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �l _' CONDUCTOR 20 19.000 41.0 121.0 121.0 WELDED I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 10.050 40.9 3,982.0 3,205.0 40.50 J-55 BTC I `r f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1, 4- LINER 7 6.276 3,567.9 5,187.4 3,197.1 26.00 L-80 BTC 1 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 3,567.9 3,067.7 50.62 PACKER BAKER ZXP PACKER w/8'TIE BACK EXTENSION 6.276 CONDUCTOR,41.0-121.0--i lk 3,586.8 3,079.5 52.38 OVERSHOT BAKER OVERSHOT w/HI-PRESSURE PACK OFF 6.276 HEAT TRACE;0.0 € , Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/fp Grade Top Connection CIRCULATION 1 2 7/8 2.4411 38.0 3,600.2 3,087.5 6.501L-80 HYD 511 TUBING Completion Details Nominal ID Top(RKB) Top(ND)(ftKB) Top Incl(1 Item Des Com I (inl 3,598.9 3,086.8 Ir 53.50 WLEG WIRELINE RE-ENTRY GUIDE 2.441 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(INH) Grade Top Connection TUBING WO I 4 1/21 3.9581 38.01 3,463.71 2,99521 12.601 L-80 IMOD BTC Completion Details Nominal ID ESP MANDREL,2,668.6 g Top(MKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) _ 38.0 38.0 0.00 HANGER FMC DUAL ESP HANGER 4.500 3,387.0 2,937.8 40.90 NIPPLE OTIS X LANDING NIPPLE w/3.813 PROFILE 3.813 3,388.7 2,939.1 40.93 Pump Canister PUMP CANISTER EXTENSION 0.000 EXT 3,401.0 2,948.4 41.16 Pump Canister PUMP CANISTER&THREADED JT 0.000 PUMP:3,350.0 1 I i, 3,412.0 2,956.7 41.37 GEARBOX REDA GEARBOX w/INTAKE:4:1 RATIO 3.813 `t�,I;: 3,423.0 2,964.9 41.58 PROTECTOR REDA 540 SERIES PROTECTOR 0.000 NIPPLE,3,387 I0 1p�) 3,432.0 2,971.6 41.75 MOTOR REDA 540 SERIES MOTOR,70HP,42 AMP 0.000 L/ 3,458.7 2,991.5 42.25 SENSOR REDA PRESSURE&TEMP SENSOR 0.000 TUBING ADAPTER;3,387.9 ' II°{ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Pump Canister EXT.3.388.7ill Top(ND) Top Incl Top(ftKB) (ftKB) r) Des Corn Run Date ID(in) Pump Canister:3,401.0 0.0 0.0 0.00 HEAT TRACE 4.5"TUBING HEAT TRACE 11/4/1998 0.000 GEARBOX,3,412.0 3,350.0 2,909.5 38.84 PUMP 4 1/2 REDA PCP PUMP ON 3.812 XX-LOCK(38' 6/17/2013 0.000 4.75"OAL)IN X NIPPLE PROTECTOR',3,423.0 ai 5,200.0 3,197.4 88.70 FISH CABLE BANDS 5 CABLE BANDS LOST BELOW 1/1/1998 0.000 MOTOR',3,432.0 n; 4.5"TUBING 1/1/1998 SENSOR 3,458.7 �a Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/, _ ___ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 3,693.0 4,161.0 3,136.5 3,210.1 Ugnu B,1H- 9/6/1998 32.0 SLOTS SLOTTED LINER - ,mx' 401 I. Al 4,182.0 4,682.0 3,210.1 3,186.4 Ugnu B,1H- 9/6/1998 32.0 SLOTS SLOTTED LINER I fII 401 4,702.0 5,144.0 3,186.8 3,196.6 Ugnu B,1H- 9/6/1998 32.0 SLOTS SLOTTED LINER WLEG,3,598.9 401 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,668.6 2,296.9 CAMCO KBG-2- 1 ESP SOV BTM 0.000 2,000.0 2/6/2015 LS Notes:General&Safety End Date Annotation �. 11/3/1998 NOTE:Dual String 4.5x2.875",6.5 LB L-80,0'-3600'RKB;2 875"Slotted Liner 3598'-3282' SLOTS:3,6930-4,161.0-. 9/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;4093.9820- I :VI- SLOTS;4,1820-4,682.0 SLOTS;4,702.0.5,144.0I- LINER 3567.95187.4 FISH,5,2000 Wallace, Chris D (DOA) From: Martin, Kenneth Lloyd <K.L.Martin@conocophillips.com> Sent: Friday, May 22, 2015 4:39 PM To: Regg,James B (DOA);Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: 1H-UGNU-01 (PTD# 198-101) Attachments: image001.png We have confirmed that problem with the well is in the pumping system. We are going to change the pump out beginning today and within a few days bring the pump on line to see if a new pump solves the problem and allows us to return 1H-Ugnu-01 to production. If you have any questions please let me know, Kenneth Lloyd Kenneth Lloyd Martin Production Engineering Regional Advisor ConocoPhillips Alaska S ES MAY 2 8 Z015 Office: (907) 659-7525 F • : NSK Problem Well Supv Sent: ' . day, October 30, 2014 10:22 AM To: Regg, Jam- : (DOA); Wallace, Chris D (DOA) Cc: Senden, R. Tyler, ‘,.rtin, Kenneth Lloyd; NSK Problem Well Supv Subject: 1H-UGNU-01 (P i _ 98-101) Jim and Chris, This email is to inform you that 1H-UGNU-01 #198-101) has been shut in due to a suspected system failure. The well stopped pumping and was shut in for pressure su 'Hance. The failure mechanism has not been identified at this point in time. It is CPAI's intentions to monitor the pressure ild up for an unknown amount of time and re-attempt to start the pump. If the re-start is successful the well will remain on oduction. If the re-start is unsuccessful intervention work will be scheduled as needed to replace the pump. Th roper notifications for continued production or pump replacement will be submitted depending on the outcome of the su ' lance period and attempted re- start. Please let me know if you disagree with this plan. If you have any questions or concerns please contact Jan Byrne or myself at 659-7126 \ N Attached are a well bore schematic and a 90 day TIO plot. N\ Dusty Freeborn/Jan Byrne Problem Wells Supervisor \ ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 \ ilptWELLS TEAM conocchlps 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~f/~) I File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: /~, ~ ~ ~ ~ [] Poor Quality Odginal - Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED [~ Logs of various kinds [] Other COMMENTS: Scanned by~ildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Oamth~ Is~ - STATE OF ALASKA ALAS _ .OIL AND GAS CONSERVATION COMMI:._,ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: AbandonRepair well RugPerforationsPerforateReturn to Service r p r r r Other Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p. Exploratory r - 198-101 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 • 50-029-22887-00 7 Property Designation-(Lease-Number) — 8-Well Name-and-Number: -- --1 H-40-1 ADL025639 ` ' 1HUGNU01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 1 Kuparuk River Field/UGNU Undiefined Oil Pool 11. Present Well Condition Summary: Total Depth measured .. 5511 feet Plugs(measured) None true vertical 3199 feet Junk(measured) None Effective Depth measured _ 5145,, feet Packer(measured) •;,_, 3568 true vertical 3197 feet (true vertical) . 3067 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 121 121 SURFACE 3941 10.75 3982 3205 I LINER 1620 7 5187 3197 SGAHNED J U L 1 0 2014D iAN 0 7 'O'4 Ei� Perforation depth: Measured depth: 3693'-4161';4182'-4682';4702'-5144' True Vertical Depth: 3137'-3210';3210'-3186';3189'-3197' AOGCC Tubing(size,grade,MD,and ND) 4.5, L-80,3464 MD, 3087 TVD Packers&SSSV(type,MD,and ND) PKR=Baker ZXP w/8'tieback extention, 3568 md, 3067'tvd SSSV=None 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM6431 MAY 16 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 250 311 Subsequent to operation 46 1 0 100 206 14.Attachments 15.Well Class after work: � Copies of Logs and Surveys run Exploratory r Development 1T..+' Service r Stratigraphic r 16.Well Status after work: ' Oil p-, • Gas r VVDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell H,prttphrey Email n1139(a�conocophillips.com Printed Nam,/ Bog ,ehristes �n Title NSK Production Engineering Specialist Signature , ----Z7,------t----/-_.___ Phone:659-7535 Date At}AK'NX / V/c-I vi-r- 5/zi 1 i4 Form 10-404 Revised 10/2012 �/2,/� Submit Original Only 1H-401 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/26/13 KILL WELL WITH 50 BBLS 10 PPG BRINE, RIH TO TAG AT 5119' CTMD, PUH TO LANDING DEPTH OF 5100'CTMD, SET HEATER STRING PER PROCEDURE AT 5100' CTMD, HAVE AES DRY WATCH FOR THE NIGHT AS THE EPDXY FOR PENTAIR WIRES CURE, JOB IN PROGRESS. 10/27/13 INSTALL FMC WELLHEAD AND CONNECT TOP FLANGE, SEAL PENATRATING TUBES, NIPPLE UP SPACER SPOOL ON 4 1/2"COMPLETION SIDE, P/T CONNECTION TO 250/3000 PSI, PUMP 6 BBLS OF SLICK DIESEL INTO TBG TAKING RETURNS UP THE IA TO TIGER TANK, INSTALL"DO NOT OPERATE" SIGN ON MASTER VALVE ON 2 7/8" TBG, JOB COMPLETE 12/12/13 Return to Service KUP 1H-401 a COfOCO✓Phillips - Well Attributes Max, e&MD ,To Alaska IIX Wellbore APIIUInd(' WI Field Name Well Status In ) MD(RKB) Act BM)(ftKB) 500292288700 WEST SAK PROD 98.94 4,361.94 5,511.0 Comment H2S(ppm) Date Annotation End Date KB-Gfd(ft) Rig Release Date •-• Well Confg:-IH-407,62720136:34:09 AM SSSV:NONE 7/29/2007 Last WO: 11/3/1998 45.00 6/20/1998 Schematm-Actual Annotation !Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 3,670.0 3/26/2013 Rev Reason:TAG,GLV C/O,Re-Set Pump haggea 6/26/2013 Casing Strings , I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd -CONDUCTOR 20 19.000 41.0 121.0 _ 121.0 WELDED HANGER,38 .� m Casing Decalption String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd AR SURFACE 103/4 10.050 40.9 3,982.0 3,205.2 40.50 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd P LINER 7 6.276 3,568.0 5,187.4 3,197.4 26.00 L-80 BTC Liner Details Top Depth (ND) Top Incl Nomi... Top(RKB) ( B) (°) Item Description Comment ID(in) 3,568.0 3,066.8 50.53 PACKER BAKER ZXP PACKER w/8'TIE BACK EXTENSION 6.276 3,586.8 3,079.3 52.33 OVERSHOT BAKER OVERSHOT w/HI-PRESSURE PACK OFF 6.276 CONDUCTOR, I 41-127 Tubing Strings HEAT TRACE, - i Tubing Description String 0.. String ID..Top(RKB) Set Depth(t...Set Depth(ND)..String Wt...String... String Top Thrd o ,111CIRCULATION 2 7/8 2.441 38.0 3,600.2 3,087.5 6.50 L-80 HYD 511 TUBING Completion Details ' Top Depth (TVD) Top Incl Nomi... Top(RKB) (RKB) (°) Item Description Comment ID(in) 3,598.9 3,086.7 53.49 WLEG WIRELINE RE-ENTRY GUIDE 2.441 i Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING WO 4 1/2 3.958 38.0 3,463.7 2,994.7 12.60 L-80 MOD BTC )M pompletion Details II Top Depth ..- j. (ND) Top Incl - Nomi... Top(RKB) PUB (°) Rem Description Comment ID(in) MANDREL - :- 38.0 38.0 -0.90 HANGER FMC DUAL ESP HANGER 4.500 2,669 3,387.0 2,928.8 33.21 NIPPLE OTIS X LANDING NIPPLE w/3.813 PROFILE 3.813 3,388.7 2,930.3 33.37 PUMP 4 1/2 REDA PCP PUMP ON 3.812 XX-LOCK(38'4.75"OAL)IN X 0.000 ,l NIPPLE 6/17/13 lIJ 3,401.0 2,941.6 34.56 PUMP PUMP CANISTER EXT 8 TREADED JT 0.000 3,412.0 2,951.4 35.62 GEARBOX REDA GEARBOX w/INTAKE:4:1 RATIO 3.813 'f II° 3,423.0 2,961.1 36.68 PROTECTOR -REDA 540 SERIES PROTECTOR 0.000 - 3,432.0 2,968.8 37.55 MOTOR REDA 540 SERIES MOTOR,70HP,42 AMP 0.000 NIPPLE.3,387 ---- 3,458.7 2,990.7 40.13 SENSOR REDA PRESSURE 8 TEMP SENSOR 0.000 TUBING ADAPTER, - - Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) 3.38e Top Depth PUMP,3,389 It ./ (ND) Top Incl Top(RKB) (RKB) (1 Description Comment _ Run Date ID(in) PUMP.3,401 0.0 0.0 0.00 HEAT TRACE 4.5"TUBING HEAT TRACE _ 11/3/1998 0.000 GFARBox, 5,200.0 3,197.4 88.84 FISH CABLE BANDS 5 CABLE BANDS LOST BELOW 4.5" 1/1/1998 0.000 3,472 � TUBING 1/1/1998 PROTECTOR, 3,423 ser. Perforations&Slots : a Shot MOTOR,3,432 : t. Top(TVD) Btm(TVD) Dena W SENSOR, k �% Top(RKB)BIm(RKB) (RKB) (RKB) Zone Date (Oh- Type Comment 3,693.0 4,161.0 3,136.5 3,210.2 Ugnu B,1H-401 9/6/1998 32.0 SLOTS SLOTTED LINER 3,459 t i 4,182.0 4,682.0 3,209.6 3,186.3 Ugnu B,1H-401 9/6/1998 32.0 SLOTS SLOTTED LINER 4,702.0--5,144.0 3,186.8 3,196.6 Ugnu B,1H-401 19/6/1998 132.0ISLOTS SLOTTED LINER 1 ' likes::General&Safety . End Date Annotation .rr,..,. 11/3/1998 NOTE:Dual String 4.5x2.875",6.5 LB L-80,0'-3600'RKB;2 875"Slotted Liner 3598'3282' 9/282010 NOTE:View Schematic w/Alaska Schematic9.0 WLEG,3,599 -..--- I t,(j Ohilla SLOTS. 3.693-4 161 SURFACE 1. i I I 41-3,982 ' SLOTS, a ■ 4,102-4,682 (Y a a _ 1 Mandrel Details Iii - Top Depth Top Port g„. (ND) Incl OD Valve Latch Size TRO Run N...Top(RKB) (RKB) (°) Make Model (in) Sew Type Type (in) (psi) Run Date Com... 1 2,668.6 2,297.0 26.47 CAMCO KBG 1 ESP SOV BTM 0.000 2,000.0 6/162013 SLOTS, i a � 4.102-5.144 e Ia LINER, J 3,568-5,187 FISH,5,200 1 TD,5,511 FW: Tract Operation Status fW-UgnU-01 (PTD 198-101) Page 1 of2 . Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, August 25,20075:02 AM To: Maunder, Thomas E (DOA) . ~ "-'~~-............. Subject: FW: Tract Operation Status for 1 H-Ugnu-01 (PTD 198-101) .. .*- \ S ~-- \D \ ~CANNfD AUG 2" 820D7 From: Martin, K L Sent: Monday, August 20,200711:04 PM To: NSK Problem Well Supv Cc: Rodgers, James T¡ Roberts, Bowen E Subject: Tract Operation Status for 1H·Ugnu-01 (PTD 198-101) ... (. Ii- ..__...,'..,--~..."."".....,...,. .\ .. .".f '···-·'....................A Prob Well Supv--Please forward the following note to Tom Maunder. Dear Tom, I'm pleased to report that we finally have good news regarding the operations of 1 H-Ugnu-01. The current status of the well is shut in, but this time the shut in is intentional while we design a new string to improve production. Chronology We brought the well on line in April with the new smaller pump at our slowest possible rate in order to keep the bottom hole pressure high (for better PVT samples). The well produced for a bit more than three days before the pump stopped surfacing fluids. We circulated the well out to diesel via the shearout valve. We believe the problem to be that the fluid in the tubing is so viscous that the pump has insufficient head to pump it. We succeeded in getting one short test of the well by itself during this period, with 73 BLPD, of which we estimate 40 BLPD was coming from the formation and the rest diesel from the annulus. We brought the well back on line from May 5 to May 16 and this time tried to keep a steady mixture of diesel (as a diluent) mixing with the crude at the pump intake. We again tried to keep the pump speed as low as possible to minimize gas breakout from the formation. After 11 days, a period of low diluent rate occurred, and the pump stopped moving fluids again, and we circulated diesel down the tubing again. We also had one test during which we estimated at 78 BLPD from the formation, approximately 24% of which was diesel, and we estimated the formation water cut at 17% from a shakeout. Pumping resumed from May 27 to June 4. We tested the well by itself for nearly 36 hours at varying rates. We have used these tests to estimate the efficiency of our positive displacement pump (ESPCP) and determine the inflow performance curve so that we could improve our allocation of fluids produced. Rates on these tests were as high as 145 BLPD, and we measured GOR's mostly in the range of 20-25 scf/stb. These GOR's are consistent with the observed GOR's during sampling, but it is not known if they have been artificially depressed by the long shut in between production attempts in 1998 and 2002 or by gas breakout in the formation. We pumped hot diesel down the annulus of the well more frequently during this period, but about midnight on June 4, the well stopped producing again. This time diagnostics showed that the tubing had frozen (surface production temperature was running about 28 to 30°F at this time). On June 25, we cleaned the ice plug out of the tubing, and on June 26 attempted a restart which failed to produce oil because during the pumping operations the shearout valve had sheared. After changing out the shearout valve the well was brought on line July 20 and produced until it was shut 8/27/2007 FW: Tract Üperation Status fW-UgnU-01 (PTD 198-101) Page 2 of2 . down on August 8 in preparation for the CPF1 shutdown. This time rates were increased on the pump in order to keep the well warmer, and more diesel was pumped to keep the viscosity down. No tests were completed during this period because the 1 H test facility was down for its inspection and its startup was delayed until after the pump was shut down. Rates are allocated based on the bottomhole pressures and ESPCP rates. Rates averaged around 65 BLPD from the formation and 35 BPO of diluent, grab samples continued to show very low GORis and formation water cuts ranging from 25-35%. We believe that some of this water is water left in the well during drilling and workover operations based on compositional analysis. On August 1 st, we ran coiled tubing into the 2-7/8" service (bypass) tubing string of the well and gathered fluid samples from the liner. We hope that these samples will be near enough to reservoir conditions to allow PVT analysis of the Ugnu oil in this area of the pool. Having completed the first step in the 1998 operations plan, we are now anxiously awaiting a design which will allow us to add heat to the well downhole so that we can return the well to production without having to use diesel as a diluent. You can expect to hear from us when we know how that string will be deployed, hopefully around year end. The well may be brought on again prior to that time if any of the samples we gathered we insufficient in size or unexpectedly contaminated with diesel. If you have any questions, please give me or the Ugnu Coordinator Bowen Roberts (265-6040) a call. 1.(ßnnetli £foyá Kenneth Lloyd Martin Production Engineering Regional Advisor ConocoPhillips Alaska Kuparuk: (907) 659-7525 Home: (907) 248-7223 8/27/2007 . . RECEIVED MAY 0 1 2007 Conoc6Phillips"'Ska Oil & :n~h~::~ Commission April 30, 2007 To: Torn Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. ih Ave. Ste. 100 Anchorage,AJC 99501 Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 . \ CQw"\D \0\ ~JUN 1420D7 Subject: Report of Sundry Well Operations. ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operé;lti.gµfor Ugnu well1U-Ugnu-01 (lH-401). ./ If you have any questions regarding this matter, please contact me or Robert Buchholz at 659-7535. ?i'" .!j¿. ,. / , '/ ... ì 1/ I ~L-<- ËD 6/,> ,_- st;-- Robert D. Christensen Attachments: 10-404 Form . 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other l.:J Retum to Service Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConöcoPhillips Alaska, Inc. Development 0 Exploratory 0 198-1011 , 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22887-00 ,.. 7. KB Elevation (ft): 9. Well Name and Number: 1 U-Ugnu-01 RKB 95' / 1 H-401 ('/ 8. Property Designation: ß>~.~.l>'1 10. Field/Pool(s): Kuparuk River Unit ¡41>c... t-S'"(¡.~ Kuparuk River Field 1 West Sak Oil Pool ,,.- 11. Present Well Condition Summary: . / Total Depth measured 5511' feet true vertical 3199' £" feet' Plugs (measured) Effective Depth measured 5145 feet Junk (measured) true vertical 3197 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 20" 121' 121' SURFACE 3887' 10-3/4" 3982' 3205' Slotted liner 1619' 7" 5187' 3197' Perforation depth: Measured depth: 3693' - 5144' true vertical depth: 3136' - 3197' :¡' Tubing (size, grade, and measured depth) 7", L-80, 5144' MD. Packers & SSSV (type & measured depth) PKR = "ZXP" PACKER W/8' TIE BACK EXTENSION PKR = 3567' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 250 197 Subsequent to operation 63 / 103 250 219 14. Attachments 15. Well Class after proposed work: 0 / 0 Copies of Logs and Surveys run _ Exploratory Development o Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil 0 / Gas 0 WAG 0 GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Bob Christensen / Bob Buchholz Printed Name ~J¡JZtensen /' Title Production Engineering Technician , Signature ~ /.. ' . /1 i >::)I' Phone 659-7535 Date i ~ o:¡'- L ' / . . RECe\VED STATE OF ALASKA MAY 0 1 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION,' ..... ' . . sian REPORT OF SUNDRY WELL OPERATION&kè 0\" a,s Cans. Coml1\lS ,/ Form 10-404 Revised 04/2004 OR\G\NAL RBDMS 8ft JUN 1 1 2007 ~~t1~fi~~$'ß1 . . 1 H-401 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/25/07 DRIFTED TBG AND TAGGED @ 3421' RKB. SET 4-1/2 REDA PCP PUMP ON 3.813 X- LOCK (38.15' OAL) IN X-NIPPLE @ 3388' RKB. RAN 4-1/2 CHECK SET, CONFIRMED LOCK SET. 04/25/07IWell Returned to Service for production testing. Re: FW: Informal Notification to AOGCC Regarding wellIH-Ugnu-OI e e Good luck Perry. lC\~\O \ NSK Problem Well Supv wrote, On 4/6/20072:54 PM: Tom, We are going to make another attempt to produce from 1 H-Ugnu-01, PTD # 198-101, with a new pump design. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCAJt\1NED APR 1 7 2007 'II '-, ,,",' From: Martin, K L Sent: Friday, April 06,200711:30 AM To: NSK Problem Well Supv Cc: Rodgers, James T; NSK Prod Engr Tech; Hollar, Eric Andrew; CPFl Prod Engr Subject: Informal Notification to AOGCC Regarding well lH-Ugnu-Ol Please send a note to Tom Maunder informing him that we are scheduling a job to rerun the pump on weIl1H-Ugnu-01 (PTD 98-101). This will be the same pump we attempted last fall with an extended rotor and greater intake opening in one more attempt to actually move this viscous oil. If all goes well we should start the job before the end of April. Thanks, Kenneth Lloyd Kenneth Lloyd Martin Production Engineering Regional Advisor ConocoPhillips Alaska work: (907) 659-7525 home: (907) 248-7223 I of I 4/17/2007 9:09 AM . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 ?vIr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5CANNED JAN 1 6 2007 06,\0\ ,0\ Dear ?vIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28,2006 for lD-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cO~ Jerry Dethlefs ConocoPhillips Problem "VeIls Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14' 6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197 -206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 10-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . Conoc6Phillips Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk: Unit, NSK-69 POBox 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 To: R£CË/VËD AUG 3 1 2006' Alaska Oil & G as Cons. C . Anchorage ortlrnfssion August 29,2006 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage,AJe 99501 Subject: Report of Sundry Well Operations. ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operation for Ugnu well 1 U-Ugnu-O 1 (lH-401). If you have any questions regarding this matter, please contact me or Robert Buchholz at 659-7535. Attachments: 10-404 Form SCANNED AUG 312006 ¡qir-IO\ 1. Operations Performed: . RECEIVED STATE OF ALASKA . AUG 3 1 ,006 ALASKA OIL AND GAS CONSERVATION COMMISSION . & G C emission REPORT OF SUNDRY WELL OPERA Tlð~ Od as ons. om 0~t Time Extension D \X=>~__ Re-enter Suspended Well D m<6; Abandon D Alter Casing D Repair Well Pull Tubing D Operat. ShutdownD Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 95' 8. Property Designation: ADL 25639, ALK 464 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE Slotted Liner Perforation depth: measured 5511' feet true vertical 3199' feet measured 5145 feet true vertical 3197 feet Length Size MD 121' 20" 121' 3887' 10-3/4" 3982' 1619' 7" 5187' Measured depth: N/A true vertical depth: N/A Tubing (size, grade, and measured depth) 7", L-80, 5144' MD. Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Stimulate D Waiver D Other Exploratory D Service D 5. Permit to Drill Number: 198-101/ 6. API Number: 50-029-22887-00 9. Well Name and Number: 1 H-401 1 U-Ugnu-01 10. Field/Pool(s): ti. I1J,(. t/.K.Jd, Kuparuk River Field / Oil Pool ft~, 3(·0 Plugs (measured) Junk (measured) TVD Collapse Burst 121' 3205' 3197' Packers & sssv (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Casin Pressure 250 250 Tubin Pressure 173 175 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GlNJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Daily Report of Well Operations _X Contact Printed Name Signature Form 10-404 Revised 04/2~ R \ G \ N A L WDSPL D Title Phone 659-7535 8-3I.c¿ RBDMS BFl SEP 0 1 2006 k ~\ ~ \ Submit Original Only . 1 H-401 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 08/19/06 SET REDA ESP ON 3.81" X LOCK (OAL 37' 9-1/2"). TOP OF PUMP @ 3353' WLM. CHECK SET SHOWS GOOD SET. PULLED & REPLACED SOV @ 2670' RKB; BTM LATCH, 2000 PSI TBG SHEAR. 08/20106 Attempted to produce the well. Unable to Surace any fluids or build tubing pressure. Job suspended 08/21/06 PULLED 4-1/2" REDA PUMP (37' 9-1/2" OAL) @ 3352' WLM. INDICATIONS ARE PUMP WAS SEATED. ..f.: . ;¡:, t"II\¡, '....j' '-') ) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 11 2005 REPORT OF SUNDRY WELL OPERA TIONSAlaska Oil & Gas Cons. Commisslor f operations:Perlormed:: ',Ab;ando:rïD ' ,Hepair:Well:, [], '. PlugPerforatio~s D ,Stinï~late 0 ,.other, A~ij!sge, " 'Àlte,r'c~~i~'g' D ' ,'Pull tÚbi~9" 0 :,'perforate~~~lPo,ÒI 0 ' ' W¿:¡iver D , ' ,t'ime Extensio~ I=:L ~, : _ , ,Change Approved Program, D' 'opèrat. ShufdownD, ," P'è~~ratè " 0 Re':e'nter Suspended Well' ,0,," ' 2. Operator Name: , -4'. .current Well Status:: , 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 'Development ' 0 Exploratory 0 , 198-101 3. Address: Stratigraphic ' 0 ' S~rVice' D' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22887-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 H-401 1 U-Ugnu-01 8. Property Designation: 10. Field/Pool(s): Kuparuuk River Unit Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE Slotted Liner Perforation depth: measured 5511' feet true vertical 3199' feet measured 5145' feet true vertical 3197' feet Length Size MD 121' 20" 121' 3887' 10-314" 3982' 1619' 7" 5187' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3205' 3197' Measured depth: N/A ~J\NNEL NO\Þ {) 8 2.005 true vertical depth: N/A Tubing (size, grade, and measured depth) 7", L-80, 5144' MD. RBDMS 8Ft 0 CT 1 1 2005 Packers & SSSV (type & measured depth) 10-3/4" x 7" Baker ZXP Pkr 3568' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: 2 Well Class after proposed work: Exploratory D Development 0 Seryice D '16. Well Status after proposed work: OH~' ;....¡Ga'sD WAßD,;, Ç3INJO VV1,NJ..D·· ,,:,.VlJDSPL[] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Prior to well operation Subsequent to operation Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinq Pressure 166 340 Casinq Pressure 290 1 113 47 ~~~~~åW;D~ ;~I~::' ~\,' - . . ',,_'.,' ,:', " "...',' -:',. .,' ',' ''"'"'' , .:., , .' "". ',,_. ',...." ',', .co' ~d~~\1~i~~*gijeerb~t~t~~i,,'\ ""c' ..~'" F) I ('\ ~ ['tAL ~, i ..-ç II. . ."..~ ~i f. '-. \. ~ I \ ¡ \,.,;. l ~ \I Form 10-404 Revised 04/2004 Submit Original Only ') 1 H-401 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 9/1S/200sISet Wireline retrivable ESP-PC Pump on 3.81" X lock @ 3388' WLM. 9/17/200s1Well brought on production. FW: IH-Ugnu-OI News ) ) Subject: FW: IH-Ugnu-Ol News From: "Spencer, Jeffrey An <Jeffrey.A.Spencer@conocophillips.com> Date: Thu,22 Sep 2005 09:39:13 -0800 Tc): tom_mauncier@adrrÜn·.state.ak.us·" .!:." .. "' """ """"".. Cç: CPFl Prod Engr <n1269@conocophiHips.com>, "Rodgers, James.T."" . <James. T .Rodgers@conocophillips.com>, "Martin, K LtI <:K.L.Martin@conocophillips.com> · ,". . . .' ". Tom, ('\. '15-- \ 0 \ This is the latest update from the 1 H-401 Ugnu well. We'll keep you posted. Thanks again for your help and have a terrific day! Jeffrey A. Spencer Su pervisor GKA Heavy Oil Development ConocoPhillips Alaska, Inc. 907 -263-4171 Jeffrey.A.Spencer@conocophillips.com , f'rn o! Ç)\ tnÍ\~1 I) ...) l:' If".' rr...:~ ,f-,} .oO \..l "- \oJ -----Original Message----- From: Martin, K L Sent: Tuesday, September 20, 2005 1:07 PM To: Rodgers, James T; CPF1 Prod Supv; Dubuisson, E. Paul; Fox, Matt; Lineberger, C. Van; Werner, Michael; CPF1 DS Lead Techs; CPF1 Prod Engr; Martin, K L; Patterson, John C; Redman, R.Scott; Spenceley, Neil; Spencer, Jeffrey A Cc: CPAI Wells Coord Supv; Fitzpatrick, Charles J; Senden, R.tyler; Downey, Allison; Harmon, Stephen M Subject: 1H-Ugnu-01 News The well continues to produce, the motor drive running at 15Hz, which should still equate to about 160 BLPD. The suction pressure is down to 720 psi as of noon today (about 615 psi of drawdown) and the pressure continues to decrease, though at a slightly slower rate of about 3 psi/hr today. Yesterday's lab sample was 32.30/0 water cut. Assuming the diesel in the backside contributed about 20 BBLS the formation would be contributing about 90 BOPD. The source of the water may be annular fluids pumped in 1998, drilling fluids, or the formation, this is being investigated. If you have any questions, please feel free to contact me today, or the CPF1 Engineer (Mike Timmcke) after tomorrow. Thanks, Kenneth Lloyd 1(ennetfi LCoyá :Martin Lead CPF1 Production Engineer Office: (907) 659-7525 (or CPF1 PE @ -7493) 9/22/2005 11: 15 AM FW: 1H·UGNU-01 (pTD (1.101) . Page 1 of 1 Maunder, Thomas E (DOA) \~ \s--\() \ From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Sunday, September 04, 2005 8:04 AM To: Thomas Maunder Subject: FW: 1H-UGNU-01 (PTD (198-101) Tom, FYI, Conocophillips is going to attempt another production test on 1 H-401 (1 H-UGNU-01; PTD 198-101) mid to late Septmember. Let me know if you have any questions regarding the well or the production test. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 .- SGA..~NEIJ AUG 28 Z007 "--'Original Message····· From: Martin, K L Sent: Saturday, September 03,20054:28 PM To: NSK Problem Well Supv Cc: Spenceley, Neil Subject: IH·UGNU-Ql MJ, In the course of your normal correspondence with the AOGCC, could you inform them that it is our intention to reattempt production of 1 H-UGNU-01 (API 500292288700) sometime in September. The last time we showed an attempted day of production it was flagged in their computer, so I want them to know in advance. No sundry required work has been completed (or is anticipated), we are simply rerunning the wireline retrievable PCP and turning it back on. Thanks, Kenneth Lloyd '1(¡mnetli £ÚJyá :Martin Lead CPF1 Production Engineer Office: (907) 659-7525 (or CPF1 PE @ -7493) Home: (907) 248-7223 '~~~ v.<:'\~~ ~c'C"d 8/27/2007 . . Page 1 of3 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder@admin.state.ak.us] Sent: Wednesday, June 09,2004 1:52 PM To: NSK Problem Well Supv Subject: Re: 1HUGNU01 (198-101) \ ~~ \0 \ Sometimes our inquiring natures deliver us more information than we really would like to know. Thanks Jerry, issue closed. NSK Problem Well Supv wrote: Tom: The well is displayed on the Setcim computer system as 1 H-401 (I don't know why that was chosen, but is the only well at 1 H with a "400" series). Our "official" database of permitted names shows the same name you have--1 HUGNU01. The change was probably made just to make it easier for the operators. I would think if we submitted reports on this well it could come up either way, depending on if the reports were automatically generated from Setcim or compiled by a human. I don't know of any problems yet, but if you find some let me know and I will pass along. Jerry -----Original Message----- From: Thomas Maunder Lm-ªilto:tom_maunder@admin.stªte.ªI<.I.I~] Sent: Wednesday, June 09, 2004 11:06 AM To: NSK Problem Well Supv Subject: Re: IHUGNUOl (198-101) SGANNED AUG 2 82007 Jerry , You know that I do try to read what comes through here!!! Is the 401 designation how you all have that internally?? The official well name as I see it in our records is 1HUGNU01. Tom NSK Problem Well Supv wrote: Tom: I am not surprised that caught your eye. The naming of this well Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 ----Original Message----- From: mas Maunder [æªi ~maunder@admin.state.ak.us] Sent: Wedne June 09, 2004 10:27 AM To: NSK Problem e upv Subject: Re: 1HUGNUOl ( I Jerry, A quick question, in your message thought the 400 series wells were ~~~~~ ç,.,~~ 8/27/2007 . . From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, June 14, 2004 9:50 AM To: Thomas Maunder Subject: RE: FW: IHUGNU01 (198-101) Tom: I passed your comments on and íf anything comes up I will get back to you on it. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 14, 20048:48 AM To: NSK Problem Well Supv Subject: Re: FW: IHUGNU01 (198-101) Thanks Jerry. Interesting. The only observation I have is that this nomenclature sequencing looks to work well. I would not recommend mixing U gnu and West Sak with the same 100 series designation. They are separate pools and likely will have different operating requirements and allowed injeciton fluids. You don't want to have the Milne Point situation where by well name you can't readily determine if a well is Kuparuk, Schrader or Sag River. I agree that there are likely to be few U gnu wells for the time being, but the naming convention is something that needs to be kept in mind as one looks out in the future. I suspect that the fact that there already was ONE 400 series well out there slipped through the cracks as Meltwater came into being. Call if you would like to discuss. Tom NSK Problem Well Supv wrote: Tom: I thought you may be interested in the in-workings of our company. See what your email generated-- Jerry -----Original Message----- From: Werner, Michael Sent: Monday, June 14, 2004 7:49 AM To: Rodgers, James T¡ Leveille, Greg P.¡ Hand, Jim Cc: NSK Problem Well SUpV¡ Schwartz, Dede Subject: RE: 1HUGNU01 (198-101) . . The 400 series numbers were adopted for Ugnu wells in 1998, building on the West Sak (100) Tabasco (200) and Tarn (300) precedent. I guess recognition that there would be very few Ugnu wells for a while lead Meltwater to start using 400 in their naming scheme. Dede, Do you have any additional insight on this? Michael Werner Staff Geologist ConocoPhillips Alaska, Inc. (907) 265-6191 f1:~C:;Ì1~~~_:~~E~~E~~c:;g!:::<::Jc:;gpþ.::~):~:bE!?:~<::J!!! -----Original Message----- From: Rodgers, James T Sent: Wednesday, June 09, 2004 5:15 PM To: Leveille, Greg P.; Werner, Michael; Hand, Jim Cc: NSK Problem Well Supv Subject: RE: 1HUGNU01 (198-101) Have any of you thought about well naming nomenclature for Ugnu wells? There may not be many for a while, but do we want to start a new number sequence or treat it like a WS well? James T. Rodgers Greater Kuparuk Area Production Engineering Supervisor j9:!:!1~?:~_::r.::<::Jªg_'?.E!?~C:;<?.!:::<::J.c:;gE.~_~11~P?:C:;<::J~ NSK 69; 907-659-7226 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, June 09, 2004 10:41 AM To: Rogers, James E. Subject: FW: 1HUGNU01 (198-101) James: Do we have a problem brewing with the naming of this Ugnu well? Is this something that should be addressed in town by someone? Jerry -----Original Message----- From: Thomas Maunder [~9:\}:~g::t::<::J¡T.J_r:r:t¿:¡~0<:J'?E~9:ª~:i:1!:?_tate. ak .L1§.] Sent: Wednesday, June 09, 2004 10:27 AM To: NSK Problem Well Supv Subject: Re: 1HUGNU01 (198-101) Jerry, A quick question, in your message you refer to the well as 1H- 401. I . . thought the 400 series wells were at Meltwater. Also, do you know of any "published" document regarding the naming convention for the pools at Kuparuk and Alpine?? Following is my understanding of the protocols in use. Kuparuk Pool--"zero or null" series West Sak--100 series Tabasco--200 series Tarn--300 series Melt--400 series As far as I know, an Ugnu series has not been designated. Alpine--"zero or null" series Nanuq--200 series At Prudhoe the protocol has evolved to Ivishak--"zero or null" series Kuparuk pools--100 series Schrader pools--200 series Lisburne--300 series Ugnu--400 series Call and we can discuss. Thanks, Tom Martin, K L wrote: been no production It is n have been having me anical problems with the mp installation and have not succeed in surfacing any fluid (except ated in and out during a fill further details y se feel free to conta like on The pump (this is received word about a have to change plans be delayed again. Kenneth Kennet Lloyd Martin Lead PFl production Engineer Off'ce: (907) 659-7525 (or CPFl PE @ -7493) (907) 248-7223 Kt',: It1U\Jl~UUl ~l~ð-lUl) r-"\ /""\ Subject: RE: lHUGNUOI (198-101) From: "Martin, K L" <K.L.Martin@conocophillips.com> Date: Wed, 09 Jun 2004 10: 15 :21 -0800 To: tom - maunder@admin.state.akus CC: NSK Problem Well Supv <n1617@conocophillips.com>, CPFI Prod Engr <n1269@conocophillips.com>, "Seitz, Brian" <Brian.Seitz@conocophillips.com>, "Rodgers, James T" <James.T.Rodgers@conocophillips.com>, "Billings, Jason W" <j ason.w .billings@conocophillips.com> Tom, There has been no production from 1H-UGNU-01. It is not entirely from lack of trying. We have been having mechanical problems with the pump installation, and have not succeeded in surfacing any fluid (except that which we circulated in and out during a fill clean out). The pump was sent back to Canada for modifications (this is a wireline retrievable PCP by REDA) , and I received word about a week ago that we are going to have to change plans on the modification, so it will be delayed again. If there are any further details you would like on this well, please feel free to contact me. Kenneth Lloyd Kenneth Lloyd Martin Lead CPF1 Production Engineer Office: (907) 659-7525 (or CPF1 PE @ -7493) Home: (907) 248-7223 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, June 09, 2004 9:12 AM To: CPF1 Prod Engr¡ Seitz, Brian Cc: NSK Problem Well Supv Subject: FW: 1HUGNU01 (198-101) Please see note from Maunder about 1H-401. Can either of you respond with an answer? Either cc me or send it to me to forward. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:to~ maunder@admin.state.ak.us] Sent: Wednesday, June Õ-§ ~- - 2-ÖO4-- 8 -;-2-9--ÃM -- --- ------ - -- - ------. To: NSK Problem Well Supv Subject: 1HUGNUOl (198-101) Jerry, I was looking through our listing and ran across this one. There are a series of sundries in the file about shutting down operations. Last item was in 2001 regarding commingling test production. I don't show any production in our report. lof2 6/9/2004 11 :06 AM Kh: IHUUNUUl (11.)15-101) 2 of2 ~ Has the well been in production?? Thanks, Tom Maunder, PE AOGCC ~ What are the plans if any?? 6/9/2004 11 :06 AM ALAS OIL AND GAS CONSERYATION COM I SSIO June 29, 2001 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Bross GKA Satellites Supervisor PHILLIPS Alaska, Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Subject: Sundry Application - Tract Production Test - Well 1H-Ugnu-01 File: Kuparuk River Unit Ugnu Undefined Pool Dear Mr. Bross: The AOGCC has received your Sundry Application to commingle test production from 1H-Ugnu-01 well with fluids from the Kuparuk Oil Pool. The well test and evaluation is expected to last one year during which time the reservoir performance will be evaluated for potential development. Allocation of tract production from 1H-Ugnu-01 shall be based on a minimum of two well tests per month and surveillance of typical production parameters to estimate daily and monthly producti°n. Point to point allocation has been adopted as a standard method of individual well production based on tests. Allocation methodology may be subject to additional requirements of the Department of Revenue and Division of Oil and Gas. Production will need to be reported monthly electronically and AOGCC Form 10-405. The new pool for reporting purposes will be Ugnu Undefined, pool number 490170. We understand that production from 1H-Ugnu-01 will be reported as regular production and will not be held confidential. During the evaluation period, gas-oil ratio will need to be monitored and a variance requested if necessary. A variance will be considered based evaluation of reservoir performance and impact of depletion without pressure support on ultimate recovery. I f there are any questions contact our staff at 279-1433. ~,~ ,-- Cammy Oechsli Taylor Chair Attachment Copy: Mark Myers, Director DOG D.E. Dickinson, DOR Oil & Gas Audit KRUUgnu 1 H-01TractOperations.doc State of Alaska DEPARTM]~NT OF NATURAL RESOURCES DIVISION OF OIL AND GAS LEASB 550 West 7 Avenue, Suite 806 Anchorage, Alaska 99501-3560 (907)269-8fl 14 phone (907)269-8943 fax FAX TRANSMITTAL DEIZV'ER TO: FAX NI_rM~2: .n ?¢- ?$,,t.-x. 7 TOTAL PAGBS (including u-ansmktal sheet): JUN 19 2001 Fax Charge $4.00 plus copies x .25. ~chora~ Please remit this amount to% Department of Natural Resources Division of Management 550 West 7~h Avenue, Suite 1410 Anchorage, AK 99501-3561 Make check payable to: Department of Revenue. you experience any problems receiving this fax, please call (907) 269-8814 immediately. lift ¥Og ~6~ 69~ i06 l'V~ ~I'¢I I00g/61/90 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Dora I. Sori~ Land Department, ATO 1360 Phone (907) 26.5.6297 Fax: (907) 263-4966 October 13, 1999 State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, At( 99501 Attention: Mr. Kenneth A. Boyd CERn- .~D MAIL 200! Status Report Tract Operation 1 H-401 Ugnu Test Well Kuparuk River Unit, Tract 34 Your ADL-025639 Our ALK 464 RECEI_V_ED OCT 14 1999 DIV, OF OIL & GAS DIRECTOR'S OF_F_[CE, Dear Mr. Boyd' ~ in accordance with the requirements set forth in your Tract Operation approval letter dated October 16, 1998, ARCO Alaska;'lnc. ("ARCO") acknowledges that the one-year approval period for the Tract Operation will expire on October 16, 1999; and hereby provides you with an update on the suspended Ugnu pr?duction test. As noted in the Six Month Status Report dated April 13, 1999, the test well was suspended and isolated from the production system. There have been no additional well activities since the April report with the exception of limited equipment relocations. Kill weight brine fills the well and a back pressure valve is installed in the tubing hanger. A copy of the approved well Sundry is attached. Only trace amounts of oil were ever produced from the well and down hole samples were not obtained. There are currently no plans to re-initiate the test in 1999. However, further testing is currently being evaluated for year 2000. If future operations are contemplated, ARCO will request a new Tract Operation approval. If you have any questions regarding the operation please contact Steve Bross at 265- 6083. Very truly yours, Dora I. Soda Senior Landman Mike Kotowski Dan Dickinson Jack Hartz Stephen Bross Jordan Wiess Central Files DRN DOR AOGCC ATO - 1126 ATO - 1146 February 26, 1998 ~F-f¢.4 ~T' CT Tnn~./~T/nn ARCO AIIteka, Int.. Yala,o,~ ¢,,n ~. I~' 3?8 February 23, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Oas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RECEIVED JUN i9 2001 Subject: Request for Shutdown of Well Operations for IH-Ugnu-Ol Dea~ Blair, Per the attached sundry, 6RCO Alaska, Mc. would like to apply for Shutdown of Well Operations status on 1H-Ugnu-0 l, The well, an Ugnu heavy oil test producer, was completed as a single zone horizontal well in late 1998. The completion incorporated a progressive cavity ESP wi& heat trace, and the well had produced completion water for a period of a few weeks. Recently, it was discovered that the ESP has failed, and the wkeline retricvabIe pump component of the ESP was pulled from the well. Due to the difficult economic conditions wl~ich now exist, heavy oil projects on the North Slope are being sca/ed back, The 1H-Ugnu-01 well is included in this reduction in activity and cost constraint. Thus, the wireline retreivable ESP pump component needed in this well will not be replaced in the foreseeable future. Instead, the well will be temporarily suspended untiI well service capital is available. The well will be left shut in with kill weight brine and a back pressure valve installed in the tubing hanger. As you know, the well is not capable of flow without artificial lift. ARCO Alaska. Inc. proposes to leave 1H-Ugnu-01 in the Shutdown of Well Operations mode until capital permits a pump replacement. Tentatively this work would likely occur in the year 2000. A Form 10404 will follow this letter when the suspension request is approved, and the field work to suspend the well has been completed. Thomas W. McKay Shallow Sands Drilling Team'Leader Kuparuk Drilling Department ARCO Alaska, Attachments: Form 10403 Well Schematic 1H-Ugnu-01 Tubing Detail -~^ ~ ~a~n~ ~ cv~ ~ qTn .4n 4Tfl Vfl~ ~fl~ Bile £06 ~-Xrg~ ~T'~I T00~/61/90 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Dora I. $oria Land Department. ATO 1360 Phone (007) 26S-$297 Fax: (g07) 263-4966 RECEtVED JUN 19 _. Nas~ 0ii & Gas Cons. Anch0rag. e April 13, 1999 CERTIFIED MAIL Mt'. Kenneth A..Boyd, Director Division of Oil and Gas Department of Natural Resources 550 W, 7th Ave., Suite 802 Anchorage, AK 99501 Six Monfl~ Status Report Tract Operation 1H-401 Test Well Formerly 1H-Ugnu-01 Test Well Kupamk River Unit,. Tract 34 ADL-025639/ALK 464 DIVISION OF OIL & GAS Dear Mr. Boyd: Reference is made to that certain letter dated September 22, 1998, submitted to you by ARCO Alaska, Inc. ("ARCO';). Therein ARCO requested the approval of a tract operation to evaluate the potential of the Ugnu formation .under.Track 34 which is covered by ADL-025639 (the ~'Tract Operation"), namely the testing of a tract well, the 1H401 (the "Well"). Further reference is made to your Tract Operation approval letter dated October 16, 1998. In accordance with the requirement set out in such letter with respect to an interim report at six months, the following shall describe rite operations conducted on the.--W-ell-to date. - DNrR permission for the Ugnu Tract Operation was granted October 16, I99g_ Following commissioning and during the subsequent initial de-watering, the electric submersible pump ("ESP") used for artificial lift experienced a downhole electrical failure (after only 18 hours of mn-time). ARCO notified you of such failure by letter dated November 2, 1998. Although the pump itself was wireline retrievable, work to the drive section or power cable required a rig. Nordic 2 was diverted to drillsite 1H for a four-day workover of the Well on October 29, 1998. The workover to replace the failed ESP motor was successful. The well was returned to production at approximately 35 BWPD with 50 PSI draw~down. Low rate de-watering was expected to continue for over 30 days until bottom hole oil samples were obtained. The draw down pressure was limited to allow for accurate determination of reservoir pressure and gas content. Following the sampling, the wireline retrievable pump was to be upgraded to a larger ESP and the Well's flow potential tested. ^~^ ~ ~ ~ o~q m ~Tn 4n ~T~ vn~ e~a~ Rfl~ ].fir RECEIVFD "'-~ STATE ^LXSKA JUN I c) 2001 ALA$1 A OIL AND GAS CONSERVATION COMI I$$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abmnclon Suspen-d'~.~_~. Operalion Shutdown Aller--~asin9 Repair wall1-_ Plugging Change approved program __ Puli tubing-__ 2. Name at operator ,5. Type et waiL' t Development X ARCO Alaska, Inc. E~plaratary 37 Address ..... ', Stra~graphic ~ ' P. O. Box 100360, Anchorage, AK 99510 Sen/ica I -- 4. L~6'atmn of wail'fit surface 469' FNL, 804' FEL, Sec. 33, T12N, P, 10E, UM At top of productive interval 509' FSL, 1050' FEL, Sec, 28, T12N, R10E. UM At effective depth At total depth 984' FNL, 1989' FEL, Sec. 33, T12N, R10E, UM T'2_-Preseht we~l condition summary ~ Re-enter suspended well Ti-me extension Stimulate -- Variance__ Pe-'~o~te__ ~ Other ~. , ~_ Datum electron (DF O~ KB) 41' RKB f~t : 7?~ni[o~o~6~ name ~ ~mk River Unit ; 6~11 number 1H.Ugnu;~ ~ 9. Pe~t number ~ 10. APl ~ ~-029-22887 I 11, Fiel~Pool ~ Kuparuk River Field Total Depth: measured 5511 feet Plugs (measured) (approx) true vertical 3199 feet Effe[;tive depth: measure~l 5144 ~eet Junk (measured) (approx) tn~e vertical 3197 feet Casing Length Size Cemented Structural Conductor 80' . 20" S u rfa r.~ 3941" 10.75" Intermediate Praductl013 1619' 7' Liner --PYrf~rabon depth: measured MeaSured depth 10 cu yds High Eddy 121' 514 sx AS III LW & 3982' 618 sx Class G & 60 sx AS I slotted liner 356B'-5187' True'vertical depth 121' 3205' 1923-3197' NIA DUPLICATE Tubing (size. grade, and m~asured depth) 4.§". 12.6~, L-hO @ 3385' bo~om of ESP ~ 34~', 2.875' 6.~ L~0 Hyd511 Pa~em and S$~V (~pe and measured depth] 10.75' x 7" Baker ~P P~ ~ 13. Attachments Description summary of proposal. X Conta~ Tom M~ Kay at 265-6890 with any questions. t . 14. EsUmated date for ~mmencing operation Detailed operation program__ 15. StatUS of Well classification as.' JOil February 28. 1999 1(~. If proposal was verbally approved Name of approver Date approved · ~tm S~ailow Sands Team Eeader ~ ~ FOR~UMM~ION USE ONLY JC~nditions ef appraval: No~ Gemmissian so lep~as~lmll~ ~ay J Plug Jnt~g~ BOP Tasl L~II~ J Mechani~l In~ Test_ ~~~ 10-~O,~ Gas ~ Suspended ~ Form 10-403 Rev 0§11 Date Commissioner Date SUBMIT IN TRIPLICATE ~ ~ ~Tn ~n AT~ vnn ,. ~t~R~ 6gZ £06 WA ~T'~I IOOZ/61/90 After thc workover, the Well continued to produce for approxin~ly 30 days un~ the low production rates (35 BWPD) resulted in the fommtion of an sppsrent ice plug in nhe tubing. The subsequent failure of the downhole shearont valve resuJted in pump damage. A decision was raade in February to defer the pump ~eplacement and temporarily suspend the test. Only trace amom~ts of oil were ever produced and down hole samples were not obtained. On February 23, 1999, a sundry was filed with the AOGCC for the Shutdown of Well Operations on the Well. Low crude oil prices and capital limitations were the main drivers of the suspension. As economic conditions improve, the test may be completed. If you have any questions regarding the operation please contact Steve Bross at 265-6083. Very truly yours, Dora I. Sofia Senior Landman JUN 19 2001 DIS (wex) ce: Steve Bross ATO Larry Gipson ATO PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 S. Bross Phone (907) 265-6083 Fax: (907) 265-6224 June 13,2001 Ms. Camille Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1H-Ugnu-01 Application for Sundry Approval Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached application for sundry to test the 1H-Ugnu-01 well. ~. you~hay~_any questions regarding this matter, please contact me at 265-6083 dr Mavriky Kalugin at 263-4440. " ..................... Sincerely, S. Bross GKA Satellites Supervisor Kuparuk Satellites SB/skad RECEIVED JUN 1 ~ 29.,01 Alaska Oil & Gas Cons. Commission Anchora~ STATE OF ALASKA ALA~, OIL AND GAS CONSERVATION coM'~ISSION APPLICATION FOR SUNDRY APPROVALS 10-403 1. Type of request: Abandon _ Suspend _ Operational shutdown_ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ,/,, .,(' ,/" 469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 509' FSL, 1050' FEL, Sec. 28, T12N, R10E, UM At effective depth At total depth 984' FNL, 1989' FEL, Sec. 33, T12N, R10E, UM Re-enter suspended wellx Time extension _ Stimulate _ Other_X Vadance _ Perforate _ Test 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-Ugnu-01 9. Permit number / approval number 98-101 10. APl number 50-029-22887-00 11. Field/Pool Kuparuk River Field/Ku~Pool 12. Present well condition summary Total depth: measured 5511' true vertical 3199 Effective depth: measured 5144' true vertical 3197' Casing Length Size Conductor 80' 20" Surface 3941' 10.75" Intermediate 1619' 7" Production Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented 10 cu. Yds High Eady 514 sx AS III LW & 618 sx Class G & 60 sxAS I Measured Depth True vertical Depth 121' 121' 3982' 3205' 3568'-5187' 1923'-3197' RECEIVED JUN i zl 2001 N/A Alaska 0il & Gas Cons, Commission Anchorage 4.5", 12.6#, L-80 @ 3385' bottom of ESP @ 3464' & 2.875", 6.5#, L-80 Hyd511 @ 3600' (slotted 3282'-3600') 10.75" x 7" Baker ZXP Pkr @ 3568' 13. Attachments Description summary of proposal __X_ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation May 1, 2001 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil $ Gas Service __'~4~~ 17. I hereby certify that thee foregoing.is true and correct to the best of my knowledge. /;,' // ~gnea :/~;:'~: -,: ,/,.~4-,~.~¢ Title: Engineering Supervisor Steve Dross Suspended Questions? Carl Mavdky Kalugin 263-4440 Date ~ ~ ~ i Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test__ Location clearance__ Mechanical Integrity Test '~"3~CSubsequent form required 10- ORI'GINAL SIGNED BY Approved by order of the Commission 13 Tny'r~r Seamount Commissioner Date t~~~/ ...... / / ORiSi ' AL 1H-Ugnu-01 (1H-401) Program Summary . o The test scope involves downhole sampling to determine live oil, in-situ fluid properties and measuring reservoir performance both with and without formation solids production. An extended test period of up to 12 months may be required due to the following: 1. Downhole sampling requires low drawdown production, resulting in low rates. This will require a number of weeks to condition the well for sampling. Several hundred barrels of completion brines will need to be recovered which also extend the sampling conditioning period. A larger capacity pump will be installed following the sampling activities for higher drawdown production performance testing. Based on similar Canadian heavy oil development experience, several months may be required to establish stabilized reservoir performance. Once stabilized conditions are established, perforating will be done to encourage formation solids production to achieve a stimulated wellbore. Several months may again be necessary to establish stabilized reservoir performance. All produced fluids will be commingled with Kuparuk production at DS 1H through the existing manifolding system. The well will be tested at least twice per month using the drill 'site test separator and all Ugnu volumes will be designated an allocation factor of one. Due · ,to the low initial rates associated with low drawdown, wellbore conditioning work (<50 ~ BOPD), there will likely be some variability in the initial flow rates measured through the drill site separator. The unfamiliar heavy oil production testing method using Kuparuk's testing facilities will be optimized as testing progresses. The participating tract owners will pay all related royalties and taxes based on the allocated test volumes. · A copy of the directional survey and wellbore schematic are attached. Log data across the Ugnu formation, derived from KPA well logs, provided excellent control for placing a horizontal wellbore in the Ugnu target beneath the existing DS 1H pad location. Since the target required little departure from the pad, the well path starts to the north and then tums back south to achieve a horizontal section in the target area. The completion design includes two separate tubing strings. The production tubing is a 4.5" string with an electric submergible downhole pump. The second string is a 2.875" open ended circulation string, which provides access to the horizontal section without removing the artificial lift equipment. The second string also allows us to run downhole-sampling equipment during normal production operations. The horizontal sectionis completed with a 7" slotted liner, which was appropriately sized to provide sand control. Wellbore Survey for Ugnu's 1H-401 Horizontal Producer 1H-40 i 1 H-401 Surv Dpth Md Surv Dpth Tvd 0 0 121 121 196.78 196.78 282.78 282.76 372.77 372.63 456.31 455.87 553.06 551.78 645.17 641.83 731.36 724.17 826.74 813.08 916.68 895.09 1,006.07 974.38 1,096.77 1,052.21 1,186.82 1,127.03 1,282.35 1,203.77 1,377.36 1,278.32 1,471.36 1.351.38 1,565.35 1,423.85 1,663.14 1,498.73 1,757.23 1,570.30 1,853.23 1,643.86 1,948.50 1,717.78 2,043.72 1,791.49 2,139.38 1,865.11 2,235.80 1,939.83 2.329.85 2,014.24 2,429.98 2,094.38 2,461.01 2,119.39 2,493.05 2,145.47 2,524.05 2,171.13 2,556.18 2.198.34 2,587.41 2,225.28 2,618.22 2,252.24 2,649.25 2,279.68 2,681.28 2,308.31 2,712.39 2,336.56 2,744.52 2,366.28 2,775.84 2,395.68 2,807.18 2,425.35 2,839.40 2,455.97 2,871.55 2,486.57 2,902.30 2.515.91 2,934.55 2.546.61 2,966.81 2,577.05 2,998.93 2,607.01 3,030.91 2,636.44 3,063.01 2.665.61 1H-401 Surv Dpth Ss 95 -26 -101.78 -187.76 -277.63 -360.87 -456.78 -546.83 -629.17 -718.08 -800.09 -879.38 -957.21 -1.032.03 -1,108.77 -1,183.32 -1.256.38 -1,328.85 - 1,403.73 -1.475.30 -1.548.86 -1.622.78 - 1.696.49 - 1.770.11 -1.844.83 - 1.919.24 - 1.999.38 -2.024.39 -2,050.47 -2.076.13 -2.103.34 -2.130.28 -2,157.24 -2.184.68 -2.213.31 -2.241.56 -2,271.28 -2.300.68 -2,330.35 -2,360.97 -2,391.57 -2,420.91 -2.451.61 -2,482.05 -2.512.01 -2,541.44 -2,570.61 1H-401 IH-401 1H-401 1H-401 1H-401 1H-401 Dog Leg Incline Radius Azimuth Map Dx Map Dy 0 0 0 0 0 0 0 0 0 0 0 0 1.08 0.82 0.54 54.62 0.44 0.31 2.1 1.96 2.19 347.76 0.62 2.1 2.09 3.8 6.58 355.69 0.04 6.58 2.52 5.81 13.56 3.24 0.02 13.56 3.56 9.21 26.17 7.35 1.21 26.14 6.11 14.83 45.32 6.13 3.28 45.2 5.34 19.43 70.7 5.5 5.66 70.47 3.81 22.97 105.16 7.75 9.47 104.73 3.25 25.49 141.98 11.38 15.42 141.15 4.48 29.47 183.08 12.35 23.65 181.55 3.22 32.31 229.56 11.03 32.76 227.21 3.35 35.29 279.6 11.83 42.37 276.37 2.74 37.8 336.44 10.61 53.05 332.23 1.09 38.82 395.33 10.32 63.37 390.22 0.58 39.16 454.47 9.64 73.24 448.53 1.44 39.95 514.32 7.91 81.96 507.74 0.32 40.11 577.2 8.33 90.43 570.07 0.8 40.85 638.26 8.1 98.76 630.58 2.23 39.11 699.89 6.16 106.03 691.82 0.52 39.11 759.9 5.37 111.67 751.64 1.53 39.45 820.13 7.61 118.1 811.58 0.52 39.91 881.19 7.3 125.61 872.19 1.66 38.49 942.12 8.48 133.58 932.6 1.71 36.92 999.64 7.92 0.21 36.75 1,059.66 7.7 4.02 35.85 1,078.03 9.16 2.67 35.17 1,096.64 8.27 7.02 33.1 1.114.03 7.07 6.76 31.15 1,131.10 5.27 6.16 29.59 1,146.84 3.04 5.7 28.32 1,161.66 0.53 7.17 27.36 1,175.93 356.23 6.26 25.89 1,189.89 353.19 9.28 23.64 1,202.36 348.87 9.85 21.01 1,213.75 344.22 8.9 19.35 1,223.42 337.72 8.98 18.33 1,231.84 329.59 8.29 18.04 1,239.34 321.07 8.07 17.7 1.245.70 312.68 9.11 17.17 1,250.54 303.49 8.39 18.49 1,254.48 295.76 9.34 20.23 1,257.50 288.33 9.89 22.11 1.259.44 281.23 9.97 23.97 1.260.17 274.6 8.3 25.4 1.259.70 269.21 141.41 989.59 149.18 1,049.11 151.74 1,067.30 154.44 1,085.71 156.66 1,102.96 158.39 1,119.95 159.43 1,135.70 159.8 1,150.61 159.31 1,165.09 157.9 1,179.37 155.81 1,192.23 152.92 1.204.08 149.36 1.214.26 144.84 1.223.29 139.09 1.231.51 132.32 1.238.65 125.06 1.244.27 116.45 1.249.07 106.53 1,252.98 95.31 1.255.83 82.92 1,257.44 69.52 1.257.78 1H-401 X Loc 549.54O.85 549,540.85 549.541.29 549,541.47 549,540.89 549,540.87 549,542.06 549.544.13 549.546.51 549.550.32 549.556.27 549.564,50 549.573.61 549.583.22 549.593.90 549.604.22 549,614.09 549,622.81 549,631.28 549,639.61 549,646.88 549,652.52 549.658.95 549,666.46 549,674.43 549,682.26 549,690.03 549,692.59 549,695.29 549,697.51 549,699.24 549,700.28 549,700.65 549,700.16 549.698.75 549.696.66 549.693.77 549.690.21 549.685.69 549.679.94 549.673.17 549.665.91 549.657.30 549,647.38 549,636.16 549,623.77 549,610.37 1H-401 Y Loc 5.980.234.18 5.980.234.18 5.980.234.49 5.980.236.28 5.980.240.76 5,980.247.74 5.980.260.32 5,980.279.38 5,980.304.65 5,980,338.91 5,980.375.33 5,980,415.73 5,980.461.39 5,980.510.55 5,980,566.41 5,980.624.40 5,980.682.71 5,980.741.92 5,980.804.25 5,980.864.76 5,980,926 5,980,985.82 5,981,045.76 5,981,106.37 5,981,166.78 5.981,223.77 5,981,283.29 5,981 301.48 5.981.319.89 5,981.337.14 5,981.354.13 5,981.369.88 5,981.384.79 5,981.399.27 5,981.413.55 5,981.426.41 5,981.438.26 5.981,448.44 5.981,457.47 5,981.465.69 5.981,472.83 5.981.478.45 5.981,483.25 5.981.487.16 5.981,490.01 5.981,491.62 5.981,491.96 1H-401 1H401 Surv Dx Surv Dy 0 0 0 0 0.44 0.31 0.63 2.1 0.08 6.58 0.11 13.56 1.38 26.13 3.58 45.18 6.13 70.43 10.16 104.67 16.35 141.04 24.85 181.39 34.26 226.99 44.2 276.08 55.25 331.87 65.95 389.79 76.2 448.04 85.32 507.19 94.2 569.46 102.93 629.91 110.6 691.1 116.64 750.89 123.46 810.78 131.38 871.34 139.74 931.7 147.95 988.63 156.11 1,048.10 158.8 1,066.27 161.62 1.084.66 163.95 1.101.90 165.79 1.118.88 166.94 1.134.62 167.41 1.149.53 167.01 1.164.01 165.7 1.178.30 163.69 1.191.17 160.88 1.203.04 157.39 1.213.25 152.93 1.222.31 147.23 1.230.56 140.51 1.237.75 133.29 1.243.42 124.71 1.248.27 114.81 1.252.25 103.61 1255.17 91.23 1,256.86 77.84 1,257.29 1H-401 Wellbore Survey (continued) 3.093.10 3,125.03 3,157.08 3,189.01 3,220.44 3,251.81 3,283.92 3,316.26 3,347.47 3,379.05 3,486.05 3,557.72 3,604.37 3,652.77 3,700.28 3,748 3,794.76 3,841.99 3,889.74 3 930 59 ¢/-.-~,999.99 4,072.50 4,110.10 4,142.14 4,174.01 4,204.74 4,235.92 4,267.76 4,299.75 4,330.59 4,361.93 4,393.69 4,426.35 4,452.41 4,485.03 4,519.87 4,550.27 4,5~1.41 4.612.08 4,64531 4.671.26 4,702.03 4,798.21 4,826.89 4,859.57 4,890.74 2.692.64 2.720.95 2,748.96 2,776.47 2.803.18 2,829.55 2,856.19 2,882.63 2,907.48 2 931.77 30l 1.59 3 061.15 3 089.97 3 116.80 3 139.77 3 159.35 3 175.07 3,187.39 3,196.40 3,201.26 3,205.97 3,208.22 3,209.81 3,210.51 3,210.28 3,210.05 3,210.06 3,209.76 3,208.38 3,205.83 3,202.42 3,198 3,193.17 3,189 3,186.68 3,184.92 3,184.04 3,184.05 3,184.91 3,185.98 3,186.41 3,186.36 3,186.77 3,187.64 3,188.63 3,189.71 3,190.64 3,191.43 3,191.88 -2,597.64 10.1 26.74 -2.625.95 10.27 28.42 -2,653.96 9.57 29.74 -2,681.47 10.54 31.33 -2,708.18 9.08 32.33 -2,734.55 10.88 33.33 -2,761.19 8.8 34.59 -2,787.63 8 35.77 -2,812.48 9.7 38.67 -2,836.77 6.93 40.75 -2,916.59 1.9 42.76 -2,966.15 9.65 49.67 -2,994.97 9.45 54.01 -3,021.80 9.58 58.64 -3,044.77 10.37 63.52 -3,064.35 9.53 68.01 -3,080.07 10.53 72.69 -3,092.39 9.23 77.05 -3,101.40 8.8 81.2 -3,106.26 9.66 85.12 -3,110.97 3.2 87.1 -3,113.22 2.39 86.53 -3,114.81 4.22 87.78 -3,115.51 9.11 90.09 -3,115.28 3.08 90.72 -3,115.05 2.35 90.12 -3,115.06 3.54 89.83 -3,114.76 5.63 91.26 -3.113.38 7.69 93.71 -3,110.83 5.72 95.42 -3,107.42 7.19 97.27 -3,103 8.24 98.94 -3,098.17 4.84 98.57 -3,094 8.72 96.11 -3.091.68 9.44 94.09 -3,089.92 6.19 92.09 -3,089.04 9.32 90.82 -3,089.05 7.56 89.16 -3,089.91 5.23 87.67 -3,090.98 2.65 88.34 -3,091.41 6.14 90.19 -3,091.36 2.74 90.02 -3,091.77 6.14 88.47 -3,092.64 0.42 88.41 -3,093.63 1.34 88 -3,094.71 0.95 88.2 -3,095.64 2.58 88.08 -3,096.43 3.35 89.16 -3,096.88 0.84 89.18 1.258.04 1,254.78 1,249.99 1,243.64 1,235.92 1.226.75 1,215.90 1,203.71 1,190.86 1,176.98 1,129.20 1,096.45 1,073.98 1,050.04 1,026.23 1,002.07 978.17 954.39 931.85 914.22 887.28 873.65 864.37 854.25 845.94 838.48 831.99 825.96 820.7 816.46 813.03 809.87 806.91 804.28 803.12 803.15 803.67 804.98 807.76 811.35 816.16 820.47 826.73 834.68 843.66 854.15 864.13 876.28 888.72 263 56.36 1,256.78 256.91 41.85 1,254.08 251.21 26.92 1,249.70 245.37 11.91 1,243.59 240.3 -2.77 1,235.92 234.28 -17 1,226.63 229.75 -31.05 1,215.50 225.75 -44.75 1,202.88 224.31 -58.01 1,189.44 223.24 -71.86 1,174.78 223.7 -120.54 1,122.75 224.15 -156.17 1,085.27 223.17 -181.3 1,058.56 223.45 -208.73 1,029.08 222.67 -236.91 998.52 221.87 -265.96 966.13 220.25 -294.65 932.74 220.24 -323.86 897.76 220.9 -354.12 861.95 221.37 -380.6 831.23 220.36 -425.55 778.57 221.14 -451.7 747.82 221.66 -472.73 723.65 219.13 -496.9 694.86 218.37 -516.78 669.74 217.92 -536.29 644.55 216.87 -554.79 620.01 215.85 -573.11 594.78 215.83 -591.56 568.87 215.18 -609.9 542.79 213.95 -627.13 517.43 211.96 -643.83 491.29 210.45 -659.92 464.34 209 -675.79 436.1 210.41 -688.5 413.48 210.14 -704.73 385.24 207.15 -721.22 354.57 208.74 -735.29 327.62 208.08 -749.92 300.15 207.62 -764.06 272.95 206.76 -779.05 243.3 206.07 -790.43 219.99 207.15 -804.03 192.39 207.27 -818.43 163.91 207.17 -832.67 135.78 207.41 -847.46 106.63 206.68 -860.32 81.01 206.5 -874.75 51.71 206.24 -888.41 23.7 549,597.21 549,582.70 549,567.77 549,552.76 549,538.08 549,523.85 549,5O9.80 549,496.10 549,482.84 549,468.99 549,420.31 549,384.68 549,359.55 549,332.12 549,303.94 549,274.89 549,246.20 549,216.99 549,186.73 549,160.25 549,115.30 549,089.15 549,068.12 549,043.95 549,024.07 549,004.56 548,986.06 548,967.74 548,949.29 548,930.95 548,913.72 548,897.02 548,880.93 548,865.06 548,852.35 548,836.12 548,819.63 548,805.56 548,790.93 548,776.79 548,761.80 548,750.42 548,736.82 548,722.42 548,708.18 548,693.39 548,680.53 548,666.10 548,652.44 5,981,490.96 5,981,488.26 5,981,483.88 5,981,477.77 5,981,470.10 5,981 460.81 5,981 449.68 5,981 437.06 5,981423.62 5,981 408.96 5,981 356.93 5,981,319.45 5,981,292.74 5,981,263.26 5,981,232.70 5,981,200.31 5,981,166.92 5,981,131.94 5,981,096.13 5,981,065.41 5,981,012.75 5,980,982 5,980,957.83 5,980,929.04 5,980,903.92 5,980,878.73 5,980,854.19 5,980,828.96 5,980,803.05 5,980,776.97 5,980,751.61 5,980,725.47 5,980.698.52 5,980,670.28 5,980,647.66 5,980,619.42 5,980,588.75 5,980,561.80 5,980,534.33 5,980,507.13 5,980,477.48 5,980,454.17 5,980,426.57 5,980,398.09 5,980,369.96 5,980,340.81 5,980,315.19 5,980,285.89 5,980,257.88 64.67 1.256.38 50.14 1,253.78 35.18 1,249.49 20.13 1,243.48 5.4 1,235.91 -8.89 1,226.72 -23.01 1,215.68 -36.79 1,203.15 -50.14 1,189.80 -64.09 1,175.23 -113.11 1,123.52 -148.99 1,086.28 -174.3 1,059.74 -201.92 1,030.44 -230.3 1,000.06 -259.56 967.87 -288.47 934.67 -317.92 899.88 -348.41 864.27 -375.09 833.73 -420.39 781.37 -446.74 750.79 -467.93 726.76 -492.29 698.13 -512.34 673.14 -532.02 648.08 -550.68 623.67 -569.16 598.56 -587.78 572.77 -606.3 546.81 -623.69 521.57 -640.57 495.54 -656.83 468.69 -672.89 440.56 -685.75 418.02 -702.17 389.89 -718.86 359.33 -733.11 332.48 -747.92 305.1 -762.24 278 -777.42 248.45 -788.96 225.21 -802.74 197.7 -817.33 169.32 -831.75 141.28 -846.74 112.23 -859.77 86.7 -874.39 57.49 -888.23 29.57 4.924.35 4,953.94 4.985.90 5.019.98 5,050.32 5.082.87 5,112.12 5,143.21 5,177 5,212.43 5,242.79 5,273.29 5,305.25 5,335.60 5,367.66 5,398.96 5,432. ! 3 5,448.77 5,511 1H-401 Wellbore Survey (continued) 3.192.38 -3,097.38 0.51 89.1 3.193.04 -3,098.04 4.49 88.34 3.194.02 -3,099.02 1.61 88.13 3.194.86 -3,099.86 3.06 89.04 3,195.30 -3,100.30 0.82 89.29 3.195.80 -3,100.80 3.1 88.95 3.196.27 -3,101.27 0.98 89.22 3,196.62 -3,101.62 2.07 89.5 3,196.95 -3,101.95 1.93 89.37 3,197.66 -3,102.66 3.14 88.34 3,198.86 -3,103.86 4.09 87.12 3~200.32 -3,105.32 0.98 87.39 3,201.08 -3,106.08 7.86 89.9 3.200.81 -3,105.81 4.66 91.11 3,200.13 -3,105.13 0.87 91.33 3,199.53 -3,104.53 8.06 90.87 3,199.12 -3,104.12 1.47 90.54 3,198.99 -3,103.99 8.11 90.38 3,198.58 -3,103.58 0 90.38 903.13 916.93 933.02 951.31 968.44 987.73 1,005.81 1,025.45 1,047.45 1,071.22 1,092.04 1,113.41 1,136.25 1,158.50 1,182.54 1,205.97 1,230.79 1,243.55 1,292.48 206.39 -903.11 -6.52 207.48 -916.33 -32.98 207.95 -931 -61.36 208.46 -946.91 -91.48 208.46 -961.19 -118.25 209.41 -976.75 -146.83 209.31 -990.92 -172.42 208.73 -1,005.82 -199.7 209.37 -1,022.04 -229.34 208.95 -1,039.09 -260.39 209.18 -1,053.65 -287 209.05 -1,068.30 -313.72 209.12 -1,083.64 -341.74 209.85 -1,098.41 -368.26 210.02 -1,114.21 -396.15 207.54 -1,129.10 -423.68 207.9 -1,144.34 -453.14 209.24 -1,152.20 -467.8 209.24 -1,182.24 -522.3 548.637.74 548 624.52 548.609.85 548.593.94 548.579.66 548.564.10 548.549.93 548.535.03 548.518.81 548.501.76 548.487.20 548.472.55 548.457.21 548.442.44 548.426.64 548.411.75 548,396.51 548,388.65 548.358.61 5.980.227.66 5.980.201.20 5.980.172.82 5,980.142.70 5,980.115.93 5,980.087.35 5,980.061.76 5,980.034.48 5.980.004.84 5,979,973.79 5.979.947.18 5.979.920.46 5,979.892.44 5.979.865.92 5.979.838.03 5,979.810.50 5,979,781.04 -1.147.31 5,979,766.38 -1.155.27 5,979,711.88 -1.185.67 -903.13 -O.55 -916.53 -26.92 -931.39 -55.2 -947.49 -85.22 -961.95 -111.89 -977.7 -140.37 -992.04 -165.86 -1.007.12 -193.04 -1.023.53 -222.58 -1.040.79 -253.51 -1.055.53 -280.03 -1.070.35 -306.65 -1.085.88 -334.57 -1.100.82 -360.99 -1.116.81 -388.77 -1.131.88 -416.2 -445.56 -460.17 -514.47 * End of 1H-401 Wellbore Survey* H-UGNU-01 Production Well Current Well Status (2/10/99) 5K FMC ESP Wellhead 2,265' of Raychem Heat Trace attached to 4-112" Tubing 4-112" x 1" Camco KGB-2-LS GLM ~ 2,669' MD 4-112" 12.6# L-80 BTC Mod Tubing as required from 3,385' to surface. 4-112" Otis X-Nipple ~ 3,387' MD Top of ESP Assy ~ 3,388' MD Bottom of ESP Assy ~ 3,464' MD Future plans are to freeze protect wi diesel and install BPV's in the top of the 4-112" and 2-718" tubing strings for temporary suspension of operations.. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Directional KOP = 300' Max Angle = 99° ~ +4,362' MD completion interval = 90° Tubuiars 20" 166.4~ X-56 ~ 121' MD 10-314" 40.5~ L-80 ~ 3510' 10-314" 45.5~ L-80 ~ 3633' t0-314" 40.5# L-80 ~ 3982' 7" 26# L-80 Slotted liner ~ 5187' 4-112" 12.6# L-80 Mod BTC 2-718" 6.5~ HYD 511 2-718" 6.5~ HYD 511 Slotted Tubing -Top ~ 3,282' MD Baker ZXP Packer - Top ~ 3,568' MD 2-718'° 6.5~ HYD 511 Tubing - Tail ~ 3,600' MD 10-314" CSG @ 3,982' MD 7" 26~ L-80 Slotted Liner PBTD ~ 5144' MD 7" Shoe ~ 5187' MD TD ~ 5511' MD MAC 2/10/99 Well ComPlian e Report File on Left side of folder 198-101-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 05511 TVD 03199 Completion Date: 1HUGNU01 50- 029-22887-00 PHILLmS ALASKAINC Start Stop 9/10/98 Completed Status: 1-OIL Current: Name D 8459 1-5 Interval SPERRY MPT/GR/EWR4 Sent Received T/C/D · OH 7/1/98 7/1/98 L DGR/EWR4-MD FINAL 133-5511 OH 7/22/98 7/22/98 L DGR/EWR4-TVD FINAL 12103199 OH 7/22/98 7/22/98 R SRVY CALC BHI 0-5511. OH 10/5/98 10/7/98 R SRVY RPT Daily WelIOps .... - __ Was the well cored? yes no Comments: SPERRY 0-5511. OH 7/13/98 7/22/98 Are Dry Ditch Samples Required? yes ~q,o~) And Received? yes no Analysis Description Received? yes/tiff) Sample Set # Wednesday, November 08, 2000 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 23, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Request for Shutdown of Well Operations for 1H-Ugnu-01 Dear Blair, Per the attached sundry, ARCO Alaska, Inc. would like to apply for Shutdown of Well Operations status on 1H-Ugnu-01. The well, an Ugnu heavy oil test producer, was completed as a single zone horizontal well in late 1998. The completion incorporated a progressive cavity ESP with heat trace, and the well had produced completion water for a period of a few weeks. Recently, it was discovered that the ESP has failed, and the wireline retrievable pump component of the ESP was pulled from the well. Due to the difficult economic conditions which now exist, heavy oil projects on the North Slope are being scaled back. The 1H-Ugnu-01 well is included in this reduction in activity and cost constraint. Thus, the wireline retreivable ESP pump component needed in this well will not be replaced in the foreseeable future. Instead, the well will be temporarily suspended until well service capital is available. The well will be left shut in with kill weight brine and a back pressure valve installed in the tubing hanger. As you know, the well is not capable of flow without artificial lift. ARCO Alaska, Inc. proposes to leave 1H-Ugnu-01 in the Shutdown of Well Operations mode until capital permits a pump replacement. Tentatively this work would likely occur in the year 2000. A Form 10-404 will follow this letter when the suspension request is approved, and the field work to suspend the well has been completed. Please call me at 265-6890 ifyouJ)ave any questions regarding this request. Thomas W. McKay ~,( Shallow Sands Drilling Team'Leader Kuparuk Drilling Department ARCO Alaska, Inc. Attachments: Form 10-403 Well Schematic 1H-Ugnu-01 Tubing Detail STATE OF ALASKA ALAS,_ ~.,.)IL AND GAS CONSERVATION COMM,_~51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend g Alter casing Repair~e~r Change appr-5-ved program -- Operation Shutdown Plugging Pull tubing__ Re-enter suspended well Time extension Stimulate Variance Peq:f-orate __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 509' FSL, 1050' FEL, Sec. 28, T12N, R10F, UM At effective depth At total depth 984' FNL, 1989' FEL, Sec. 33, T12N, R10E, UM 5. Type of Well: Development X Exploratory Stratigraphic-- Service -- 6. Datum elevation (DF or KB) 41' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-Ugnu-01 9. Permit number 98-101 10. APl number 50-029-22887 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total Depth: measured 5511 (approx) true vertical 3199 Effective depth: measured 5144 (approx) true vertical 3197 Casing Length Size Structural Conductor 80' 20" Surface 3941' 10.75" Intermediate Production 1619' 7" Liner feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth 10 cu yds High Early 121' 514 sx AS III LW & 3982' 618 sx Class G & 60 sx AS I slotted liner 3568'-5187' True vertical depth 121' 3205' 1923-3197' Perforation depth: measured N/A tl~l~~vertical 0RIGINAL Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ 3385' bottom of ESP @ 3464', 2.875" 6.5# L-80 Hyd511 @ 3600' (slotted 3282'-3600') Packers and SSSV (type and measured depth) 10.75" x 7" Baker ZXP Pkr @ 3568' 13. Attachments Description summary of proposal X Contact Tom Mc Kay at 265-6890 with any questions. Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: February 28, 1999 Oil Gas 16. If proposal was verbally approved Name of approver Date approved Service__ Signed17' I~~h_a_t t~o,ng ig'true,nd correct to the best of mY knowled_qe/~ Title ..... Feaaer . ', _.:7Z.,¢i",/ · ~,,,'¢"'~ Sl~allow Sands Team Date .~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance__ Mechanical In~grityTest_ Subseque~form require 10- ./J'a¢l..~ ORIGINAL SIGNED-BY Approved by the order of the Commission Robert N. Chdstenson Commissioner Suspended X IlAppr°val NoJ ~/./_ ~/, Date ~'" I -c>)q Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE _ ,e6 0o¢ N99'~ uT.,O,(o.e6 ..~ Date: 12/3/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iH-UGNU-01 WELL ID: 999144 TYPE: -- AFC: 999144 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/05/98 START COMP:09/02/98 RIG:NORDIC % 2 WI: 0% SECURITY:0 API NUMBER: 50-029-22887-00 BLOCK: FINAL:09/ll/98 10/30/98 (C32) TD: 5511' PB: 5511' 10/31/98 (C33) TD: 5511' PB: 5511' 11/01/98 (C34) TD: 5511' PB: 5511' 11/02/98 (C35) TD: 5511' PB: 5511' 11/03/98 (C36) TD: 5511' PB: 5511' 11/04/98 (C37) TD: 5511' PB: 5511' RIG UP TO CIRC. WELL. SUPV:M.C. HEIM Move rig and camp from 1Y-15A to 1H-01. MW: 0.0 UNKN TESTING BOPE. MW: 9.0 BRINE SUPV:M.C. HEIM Circ down 4.5" tubing w/brine. N/D tree and N/U BOPE. RIH W/ REVERSE BASKET & 3 MW: 9.0 BRINE SUPV:M.C. HEIM N/U BOPE and test BOPE to 350/3500%. Pull 4.5" tubing. RUNNING COMPLETION=ii STD MW: 9.0 SUPV:M.C. HEIM RIH w/4.5" tubing. RIH w/completion equipment. BRINE TEST CONDUCTIVITY OF BOTH SUPV:M.C. HEIM Continued to RIH w/completion. MW: 9.0 BRINE INSTALLING STACK IN CELLA MW: 9.0 BRINE SUPV:RICK OVERSTREET N/D BOPE. Test packoff to 500 psi. Freeze protect well. Release rig @ 2200 hrs. 11/4/98. ARCO Alaska, Inc. - .... Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 12, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1H-Ugnu-01 (Permit No. 98-101/398-289) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 1H-Ugnu-01. If there are any questions, please call 265-6120. Sincerely, Graham C. Alvord Kuparuk Drilling Team Leader AAI Drilling GCA/skad RECEIVED ! 2 1999 Alaska 0il & Gas Cons. ~missi°t~ Anch0ra~e STATE OF ALASKA ALAS: ..... OIL AND GAS CONSERVATION COMrv,._~¢lON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Pull tubing X Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 509' FSL, 1050' FEL, Sec. 28, T12N, R10E, UM At effective depth At total depth 984' FNL, 1989' FEL, Sec. 33, T12N, R10E, UM 12. Present well condition summary Plugging Perforate -- __ Repair well __ Other X 5. Type of Well: Development X Exploratory Stratigraphic q Service -- Repair Tubing 6. Datum elevation (DF or KB) RKB 41' 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-Ugnu-01 9. Permit number/approval number 98-101/398-289 10. APl number 50-029-22887-- O O 11. Field/Pool · Kuparuk River feet Total Depth: measured 5511' true vertical 3199' Effective depth: measured 5145' true vertical 3197' feet feet feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 80' 20" Surface 3941' 10.75" Intermediate Production 1619' 7" Liner Perforation depth: measured N/A Cemented Measured depth 10 CY High Early 121' 514 sx AS III LW & 3982' 618 sx Class G & 60 sx ASl slotted liner 3568'-5187' true vertical N/A Tubing (size, grade, and measured depth) 4.5", 12.6¢~, L-80 @ 3385' bottom of ESP @ 3464', 2.875", 6.5~, L-80 Hyd 511 @ 3600' (slotted 3282'-3600') Packers and SSSV (type and measured depth) 10.75"x 7" Baker ZXP Pkr @ 3568' True vertical depth 121' 3205' 1923'-3197' 0RiGii'qkL RECEIVED 13. Stimulation or cement squeeze summary jAN !2 1999 14. Intervals treated (measured) Treatment description including volumes used and final pressure A]~[$~3. 0ii & ~8.~ CONS, O0~ffti~S Anchorage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Water Injector__ Daily Report of Well Operations -X : Oil X Gas -- 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Suspended __ Service __ Signed ~~_,., ~(~,.~(~H4,~L-./~f,_~,'~itle Kuparuk Drilling Engineer Form 10~404 Rev 05/17/89 - - Date SUBMIT IN DUPLICATE 1H-UGN Curre (2/10/99) uction Well ! Status ARCO Alaska, Inc. 5K FMC ESP Wellhead 2,265' of Raychem Heat Trace attached to 4-1/2" Tubing 4-1/2" x 1" Camco KGB-2-LS GLM @ 2,669' MD 4-1/2" 12.6# L-80 BTC Mod Tubing as required from 3,385' to surface. 4-1/2" Otis X-Nipple @ 3,387' MD Top of ESP Assy @ 3,388' MD Bottom of ESP Assy @ 3,464' MD Future plans are to freeze protect w/diesel and install BPV's in the top of the 4-1/2" and 2-7/8" tubing strings for temporary suspension of operations.. Directional KOP = 300' Max Angle = 99° @ ±4,362' MD completion interval = 90° Tubulars 20" 166.4# X-56 @ 121' MD 10-3/4" 40.5# L-80 @ 3510' 10-3/4" 45.5# L-80 @ 3633' 10-3/4" 40.5# L-80 @ 3982' 7" 26# L-80 Slotted liner @ 5187' 4-1/2" 12.6# L-80 Mod BTC 2-7/8" 6.5# HYD 511 2-7/8" 6.5# HYD 511 Slotted Tubing - Top @ 3,282' MD Baker ZXP Packer- Top @ 3,568' MD 2-7/8" 6.5# HYD 511 Tubing - Tail @ 3,600' MD 10-3/4" CSG @ 3,982' MD 7" 26# L-80 Slotted Liner PBTD @ 5144' MD 7" Shoe @ 5187' MD TD @ 5511' MD MAC 2/10/99 CASING / TUBING / LINER DETAIL 10-3/4" Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Kuparuk Field WELL: 1H-Ugnu-01 DATE: 6/8/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 44 Jts Joint 'B' Joint 'A' 32 Jts X, Y, Z' 5 Jts 1 Jt 2 Jts RKB to Landing Ring - Parker Rig #245 FMC Fluted Mandrel Casing Hanger & 45.5#, NT-80 pup 10-3/4", 40.5#, J-55, BTC Casing (Jts #41 thru #84) 10-3/4", 40.5#, J-55, BTC Casing - Baker Locked Gemoco '751E' Stage Cementing Tool 10-3/4", 40.5#, J-55, BTC Casing - Baker Locked 10-3/4", 40.5#, J-55, BTC Casing (Jts #9 thru #40) 10-3/4", 45.5#, L-80, BTC Casing, 9-7/8" Special Drift, Jts 'X', 'Y', '2 10-3/4", 40.5#, J-55, BTC CaSing (Jts #4 thru #8) Gemoco Insert Shut-Oft Baffle 10-3/4", 40.5#, J-55, BTC Casing (Jt #3) Gemoco Float Collar 10-3/4", 40.5#, J-55, BTC Casing (Jts #1 & #2) Gemoco Float Shoe 40.91 1.80 1976.05 40.91 42.71 41.15 2018.76 2.84 2059.91 46.24 1401.13 122,49 213.50 43.00 1.53 89.52 1.81 Bo-Il'om of Shoe ==>> I TD = 3997' MD (~ 15' Rathole) I Baker Lock thru Insert Shut-Off Baffle, plus Sta~te Collar to Joints 'A' & 'B' Install Insert Shut-Off Baffle on Top of Joint #3 Run 45.5# Joints 'X', 'Y', & 'Z' on Top of Joint #. Run Sta~te Collar & Baker Locked Jts 'A' & 'B' on Top of Jt #4~ Run FMC Han~ler on Top of Joint #84 3 Bow Sprin~1 Centralizers: Install on a stop rin~l in the middle of Jolts # I, #2, & #3 10 Solid Strai~tht Blade Centralizers: slip on next 10 joints, Jts #4 thru # 10 + X, Y,2 2062.75 2108.99 3510.12 3632.61 3846.11 3846.11 3889.11 3890.64 3980.16 3981.97 25 Bow Sprin~l Centralizers: every 3rd joint to surface, plus on on stop rin~t on Joints 'A' & 'B i Leave OUT 16 Joints: #85 thru #10~2 Remarks: String Weights with Blocks: K# Up, K# Dn, 75K# Blocks. Ran ?? joints of casing. Drifted casing with 9.875" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou~ on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. (?? Joints of 40.5# + 3 Joints of 45.5#)- Parker Rig #245 Drilling Supervisor: Don E. Breeden CASING / TUBING / LINER DETAIL ARCO ALASKA / Subsidiary of Atlantic Richfield WELL: 1H-Ugnu-01 DATE: 9/6/98 PAGE: 1 of 1 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 7" Slotted Liner TOPS Parker RKB to 13 5/8" 5M Wellhead Flange 38.00 Baker ZXP Pkr w/8' Tie Back Extension W X- 18.88 3567.95 Baker 9-5/8" Overshot W/Hi-Pressure Pack off 5.24' total 1.00 3586.83 7" 26# L-80 BTC PIN X Cut off 19.32 3587183 1 Jts 7" 26# L-80 BTC Blank Liner 43.05 3607.15 7" 26# L-80 BTC Marker Jt 42.70 3650.20 11 Jts 7,, 26# L-80 BTC Slotted Liner 468.15. 3692.90 7" 26# L-80 BTC Marker Jt 20.98 4161.05 12 Jts 7" 26# L-80 BTC Slotted Liner 499.78 4182.03 7" 26# L-80 BTC Marker Jt 21.18 4681.81 11 Jts 7" 26# L-80 BTC Slotted Liner 441.18 4702.99 7" 26# L-80 BTC Blank Liner w/insert packoff bushing and flapper 42.32 5144.17 7" Shoe 0.92 5186.49 TD 5187.41 * Packoff bushing installed in top of joint ,85 down f/cpl.. . RIG SUPERVISOR: Donald Lutrick . TUBING 4-1/2" REDA ESP of Dual Completion 1H-UGNU-01 ARCO Alaska, Inc. DATE: 11/03/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Parker 245 RKB to 13-5/8" 5M well head flange 38.00 FMC Dual 4.5" & 2.875" ESP Hanger 1.02 38.00 Jt# HGR 4-1/2" 12.6# L-80 8 Eue rd Mod tubing 30.82 39.02 4-1/2" Space out pup 8 rd box X Bu~ress pin 3.85 69.84 Jt# 23-103 4-1/2" 12.6# L-80 Mod BTC tubing 2589.15 73.69 4-1/2" 12.6# L-80 Mod BTC tubing PUP 5.73 2662~84 GLM 4-1/2" x 1" Camco KGB-2-LS Mandril 3.909" ID 5.985" OD 7.53 2668,57 4-1/2" 12.6# L-80 Mod BTC tubing PUP 5.73 2676.10 Jt#1-22 4-1/2" 12.6# L-80 Mod BTC tubing 702.69 2681.83 4-1/2" 12.6# L-80 Mod BTC tubing PUP BTC Box X 8rd pin ??? 2.50 3384.52 4-1/2" Otis 'X' landing nipple w/3.813" Profile .85 3387,02 4-1/2" Tbg adapter 4-1/2" 8rd-5.13 V thread lock plate .81 3387.87 Pump canister extension, Measured weld to weld 12.33 3388.68 Pump canister threaded joint .81 3401.01 Pump canister 10.22 3401.82 REDA Gearbox w/intake: 4:1 Ratio, Output sPeed 425 RPM @ 60 H 11.00 3412.04 REDA 540 Series Protector: BSBSB-PC Type 9.00 3423.04 REDA 540 Series Motor: 70 HP. 1535 Volt, 42 Amp, 60Hz, 1700 RPM 26.70 3432.04 3 Phase, 4 Pole, Upper Tandem 3458.74 REDA Downhole pressure & Temperture Sensor:0-5000 PSIA, 5.00 3458.74 3463.74 Heat trace 2265' Long Start Heat trace @ pin end of Joint #34 Tangent Section 3379' -3486" 1 Heat Trace End Shoe 6' REDA: 614 Flat bands 341 Heat Trace Flat Guards 6' 150 - 6' guard., 30Heat Trace Flat Guards 4' 27 Heat Trace Flat Guards 3' 1164 Flat Bands 103 jts. 4-1/2" 12.6# L-80 BTC tubing 1 jt of 4-1/2" 12,6# L~80 Eue 8 rd Mod tubing 104 jts total Remarks: String Weights with Blocks: 80K# Up, 50K# Dn, 6K# Blocks. Ran 103 oints of tubing. Drifted tubing, GLMs, & hanger with 3.78" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-cOated. Nordic Rig #1 Drilling Supervisor: Donald L. Wester TUBING 2-7/8" Tubing of Dual Completion 1 H-UGNU-01 ARCO Alaska, Inc. DATE: 11/4/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Parker 245 RKB to 13-5/8" 5M well head flange 38.00 ' jt#11-118 2-7/8" 6.5# L-80 HYD 511 tubing 3244.16 38.00 jt#1-10 2-7/8" 6.5# L-80 HYD 511 Slotted tubing 316.75 3282.16 2-7/8" OD Wireline re-entry guide 1.26 3598.91 3600.17 Remarks: String Weights with Blocks: ??K# Up, ??K# Dn, 6K# Blocks. Ran ??? ioints of tubing. Drifted tubing, GLMs, & hanger with 2.867" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-coated. Nordic Rig #1 Drilling Supervisor: Donald L. Wester 1 H-UGNU- roduction Well Curt ell Status (2/10/99) 2,265' of Raychem Heat Trace attached to 4-1/2" Tubing 4-1/2" x 1" Camco KGB-2-LS GLM @ 2,669' MD 4-1/2" 12.6# L-80 BTC Mod Tubing as required from 3,385' to surface. 4-1/2" Otis X-Nipple @ 3,387' MD Top of ESP Assy @ 3,388' MD Bottom of ESP Assy @ 3,464' MD 5K FMC ESP Wellhead ARCO Alaska, Inc. Future plans are to freeze protect w/diesel and install BPV's in the top of the 4-1/2" and 2-7/8" tubing strings for temporary suspension of operations.. Directional KOP = 300' Max Angle = 99° @ ±4,362' MD completion interval = 90° Tubulars 20" 166.4# X-56 @ 121' MD 10-3/4" 40.5# L-80 @ 3510' 10-3/4" 45.5# L-80 @ 3633' 10-3/4" 40.5# L-80 @ 3982' 7" 26# L-80 Slotted iiner @ 5187' 4-1/2" 12.6# L-80 Mod BTC 2-7/8" 6.5# HYD 511 2-7/8" 6.5# HYD 511 Slotted Tubing - Top @ 3,282' MD Baker ZXP Packer - Top @ 3,568' MD 2-7/8" 6.5# HYD 511 Tubing - Tail @ 3,600' MD ~-- 10-3/4" CSG @ 3,982' MD 7" 26# L-80 Slotted Liner PBTD @ 5144' MD 7" Shoe @ 5187' MD TD @ 5511' MD ~IAC 2/10/99 FROM: ~RCO RLflSKA FAM HO. : 9072656096 10-50-98 12:54P P.04 CASING / TUBING / LINER DETAIL ARCO Alaska, Inc. Subsidiary of Attantic Richfield Company Kuporuk Field WELL: 1H-Ugnu-01 DATE: 6/8/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 44 Jts Joint 'B' Joint 'A' 32 Jfs X, Y, Z' 5 Jts 1 Jt 2 Jts RKB to Landing Ring Parker Ri,c] #245 FMC Fluted Manarel Casing Hanger & 45,5#, NT-80 pup 10-3/4", 40,5#, J-55, BTC Casing (,Jts #41 thru #84) !.0.-3/4", 40.$#, J-55, BTC Casing - Baker Locked Gemoco '7,~11E' Stage Cementing Too~ 10-3/4", 40,5#, J-55, BTC Casinq - Baker Locked 10-3/4", 40.5#, J-55, BTC Casing (Jts #9 thru #40]) 10-3/4", 45.511, L-80, BTC Casing, 9-7/8" Special Drift, Jts 'X', 'Y', '2 10-3/4", 40,5#, J-55, BTC Casing (~J.t.s #4_thr..u...~8,~ Gemoco Insert Shut-Off Baffle 10-3/4". 40.5#, J-55, BTC Casinc~ (,Jr #3) Gemoco Float Collar 10-3/4", 40.5#, J-55, BTC Casing (Jts ~1 & #2) Gemo¢o Float Shoe 40.91 1.80 1976.05 41.15 2,84 40.24 1401.13 122,49 213,50 43.00 1.53 89.52 40.91 42.71 2018.76 2059,91 2062.75 2'.'.08,99 3510.12 3632,61 3846.11 3846,11 3889.11 3890,64 3980.16 1,81 Bot-'rom of Shoe ==>> 3981.97 ! TD: 3997' MD (~ 15' Ralhale) 1 Baker Lock thru Insert Shut-Off Battle, plus Stage Collar to Joints 'A ' & 'B' Install Insert Shut-Off Baffle on Top of Joint 113 Run 45.5# Joints 'X', 'Y', & 'Z' on Top of Joint # . .R_un sta~le Collar & Baker Locked JIS 'A' & 'B' on TO~ of Jt #4~ Run FMC Hon~ler on Tol~ of Joint #84 3 Bow Spring Centralizers: Instoll on a sto~. rin~ in the middle of Jolts #I, 1t2, & 1t3 I0 5olid Straigl~t Blade Centralizers: slip.._.o_.n next..1.0 joints, Jts.#4, r.t.~U.....#_l ~.+____X__: Y_.?. 25 Bow Sprin~l Centralizers: e very 3rd joint to surface, plus on on stop rin~ on Joints 'A ' & 'B i Leave OUT 16 Joints: #85 thru #1 O0 Remarks: String Weights with Blocks: K# Up, KIt Dn, 75K~_Blocks. Ran ?? joints of casing. Drifted casing with 9.875" plastic rabbit. Used Arctic Grade AP! Modified No Lead thread comp._..o__.Uj on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. (,?? Joints of 40.5# + 3 Joints af 45.5#~) Parker Rig #245 ~fllling S_uP_erviso,q' Don E. Breeden FROM: ~RCO ALRSKR FR× NO.: 90?2656096 10-30-98 12:54P P.05 CA'SING /TUBING / LINER DETAIL - ARCO ALASKA / Subs/diary of Atlantic Richfield WELL: 1H-Ugnu-01 DATE: 9/6/98 PAGE: 1 of 1 ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ,. .,,., ,,,. ... 7" Slotted Liner TOPS Parker RKB to 13 5/8",,5M Wellhead Flan~,,e 38.00 ,,, Baker ZXP Pkr w/8' Tie Back Extension W X- 18.88 3567,95 Baker 9-5/8" Overshot W/Hi-Pressure Pack off 5,24' total 1.00 3586.83 7" 26# L-80 BTC PIN X Cut off 19,32 3587.83 1 dts 17" 26# L-80 BTC Blank Liner 43.05 3607.15 7" 26# L-80 BTC Marker Jt 42,70 31550.20 11 Jts 7" 26# L-80 BTC Slotted Liner 468.15- 3692,90 7" 26# L-80 BTC Marker Jt 20,98 4161.05 12 Jts 7" 26# L-80 BTC Slotted Liner z99.78 4182,03 , ...... ,,,, 7" 26# L-go BTC Marker Jt 21.18 4681.81 11 Jts 7" 26# L-80 BTC Slotted Liner 441.18 4702.99 7" 26# L-g0 BTC Blank Liner w/insert packoff bushing and flapper! 42.32 514~.1 7 7" Shoe 0.92 5186.49 TD! 5187.41 * Packoff bus. h,!.ng instalJed.!n top of joint.,,85 down f/cplg. ,, ,, PKR AND lINER ARE NOT SET , . _ RIG SUPERVISOR: Donald Lutrick FROM: aRCO PLASK~ FP× NO. : 90?2656096 10-30-98 12:55P P.06 . _J' TUBING ,jE_1Z2" REDA ESP o_LO_~o~n 1H-UGNU-01 ARCO Alaska, Inc. DATE: 9/8/98 Subsidiary of Aflanfi~ Richfi=~ld C:ornpanv 1 OF 1 PAGES # ITEMS co'MpLETE DESCRIPTION oF-E'QulPMENT RUN .....LENGTH ...... ~EPTH TOPS Pa'EEer 245 RKB ta 13-5/8" 5M weli"i'~ead flan~e.,' 38.00 FM.,,,C Dual 4.5" & 2,875" ESP Hang?r 1.02 , 38,00 Jr# HGR 4-1/2" 12,,,,6# L-80 Mod BTC tubing_..., 30.82 :.~_.9..,..0..2 4-1/2" Spac .e,,,out pup 8 rd box X Buttress ,Din. .... 3,85 69.84 Jr# 4-!,03 4-1/2" 12,6# L-80 Mod B.T._,C tubing ...... 3196,20 ?3,69 . 4-1/2" 12.6# L-80 Mod 8TC tubing PUP 5,73 3269,89 GLM 4-1/2"x 1.-Camco K~'_2_~ Mandril 3.g0~,'ID 5.985"O[~ ........ 7,53 3275.62 4-1/2" 12,6# L-80 Mod BTC,tubing PUP 5.73 3283,15 Jr#l-3 .... ~ ,4~1/2" 12,6# L-80 Mod BTC tubing. ..... 95.64 3,,2.88,88 4-_1/2" 12.6# L-80,..M,, od BTC tubing PUP BTC Box X 8rd loin ?,,? 2,50 3384,52 4-1/2" Otis 'X' landin~,,nipple w/3,813" Pro~ile .... ..,,85 3387.02 4-1/2" Tbg adapter 4-1/2" 8rd-5.13.¥ thread lock plate .81 3387..8,7 Pump canister extension. Measured weld to weld ...... 12.33 3388,68 Pump canister threaded, ioint ,.,.,., .$1 3401.01 Pump canister 10.22 3401.82 ,,, REDA Gearbox w/intak, e.i 4:1 Ratio, Output speed 425 RPM @ 60 H 11,00 3412,04 !REDA 540 Series Protector: BSBSB-PC Type ,9,,;0_0 3423,04 REDA 540 Series Motor: 70 HP, 1,535 Volt, 42 Amp, 60Hz, 1700 RPM 26.70 3432,04 3 Phase, 4 Po,,!,.e,. Upper Tandem , 3458,74 ~REDA Downhole pre,s.s..u, re. & Temperture Sensor:0-5000 PSIA, 5.00 3458:,.7,,,,4 3463.74 .. Heat trace 2265' Lon,q .......... Start Heat trace @ pin end of Joint #34 .. . . Tangent.~.ection 3379' - 3486: . ...... 1 Heat Trace End Shoe 6' 345 Heat Trace Flat Guards 6' 30 Heat Trace Flat Guards 4' 23Heat Trace Flat Guards 3' 1154 Flat Bands ............................... 104 total i~'.~'i"4-i/2" 12.6# L-8,..,0 BTC tubing .. Remark,~: String We ¢jhts with Blocks: 80K# IJp. 50K# Dn, 6K# Blocks. Ran 103 oints of tubing. Drifted tubing. GLMs. & hanger with 3,78" plastic rabbit, Used Arctic Grade APl Modified No Lead thread compound on all connections, Tubing is non-coated, Nordic Rig #I Drilling Supervisor: Donald L. Wester .PROM: ~RCO ALRSK~ FR× NO. : 9072656096 10-30-98 12:55P P,O? TUBING 2-7/8" Tubing of Du~J_C_o_mp~etj_o~ I H- UGN U-01 ARCO AlaskQ, Inc. DATE: 9/7/g8 Subsidiary of Atl(~nl~c R~chfield ComDony 1 OF I PAGES _~_!.TEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Parker 245 RK,B,,,to 13-5/8" 5M ,,veil head fiancee ..... 38,00 jt#11-118 2-7/8"6.5,~ ,L-80HYD511 tubing 3244,16 138.00 .... ,i.?,1-10 2-7/8" 6,5# L-80 [dYE) 511 SI,,o,,tted tubing 316.75 ~- 3282.16 2-7/8" OD Wir_~lino r~-~n,fryv ... cduide ~.26, 3,598.91 .............. 3600. ! 7 . . ,, Remarks; String Weights with Blocks: ??K# Up, ??Kit Dh, 6K# Blocks. Ran ??? ,oints of tubing. Drifted tubing:_ GL_MS.,& h_.a...n, ger with 2,867" plastic rabbil', Used Arctic Grade APl Modified No Leac thread compound on all connections. Tubing is non-coated. Nordic Ri~] #? Drilling Supervisor; Donald L. Wester F'ROM: ARCO ALASKA FlzlX NO. : 9072656896 STATE OF ALASKA ALAGKA OIL AND GAS CONSERVATION COM"~fi~SSION APPLICATION FOR SUNDRY APPROVALS 18-38-98 12:53P P .01 1. Type of Request: Abandon_ Suspend _ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging__ Time e~tension_ Stimulate _ Pull tubing X Variance__ Perforate__ Other__ 2. Name of Operator ARC~Q ,Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 ' $. Type of Well: Development X Exploratory _ Stratigraphic _ Service G. Datum elevation (DF or KBI 41' RKB. 54' Pad elevation 7. Unit or Property name Kuparuk River Unit f'J_et .......... 4, Location of well at surface 469' FNL, 804' FEL, Sec. 33. T12N, R10E, UM At top of productive interval 509' FSL, 1050' FEL, Sec. 28, TI:~N, R10E, UM At effective depth At total depth 984' FNL, 1989' FEL, Sec, 33, T12N, RIOE, UM 8. Well numoer 9. Permit number 98-101 10. APl number 50-029-22887 11. Field/Pool Kuparuk River 12, Present well condition summary Total Depth: measured 5511' (approx) true vertical 3199' Effective depth: measured 5145' (approx) true vertical 3197' Casing Length Size Structural Conductor 80' 20" Sudace 3941' 10.75" Intermediate Production 5146' 7" Liner feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth True vertical deplh 10 cu. Yds. High Early 121' 121' 514 sx AS Ill LW 3982' 3205' & 618 sx Class G & 60 sx AS I slotted liner 5187' 3197' Perforation depth: measured true vertical N/A N/A Tubing (size, gra. de. and measured depth) 4.5", 12.6#, L-80 G 3404', 2.875", 6.S~, L-80 @ 3600' Packers and SSSV (type and measured depthl N/A ORIGINAL 13. Attachments Description summary o! proposal ~ Contact Mark Chambers at ;~65-1619 with any questions. 14, Estimated d~te for commencing operation Q_c. lP_bC_L3 ~, 16. If proposal was verbally approved Name of approver Date approved Detailed operation program BOP sketch 15. Stalus of well c~assification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledcle. Signed~¢14~~,~,~.., ~"o~. C~',? ~;f~v~ Title Kuparuk Drilli¢g Team Leader , ,¢u FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness _ BOP T~=t ule~r~nc~ Plug integrity ~ ~ Luc~tion Mechanical Integrity Test_ Subsequent form require 10~ Orlginat S; ....... Approved by the o,der of the Commission I:)~vid W." Commissioner Form !0.403 Rev 06/15/88 SUBMIT IN TRIPLICATE =~OM: ~RCO ~L~SK~ ~AX HO. : 9072656096 !0-30-9~ 12:54P P.02 1H-UGNU-01 '- ' GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1, RU wireline unit. RIH and drift 4-1/2" tubing. RIH and tag top of wireline retrievable pump. RIH and pull shear circulating valve from GLM leaving open pocket. 2, Set BPV i.q tubing. 3. Remove flow riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: o , MIRU Nordic Rig. L~zy hard-line to tree. Pull BPV, Load pits w/sea water, Displace tubing and annulu~ w/ sea water, SI well and determine kill wt fluid required. Load pits w/kill weight filtered 3% KCL Brine (expected kill weight = 9.0 ppg). Circulate well to brine. Ensure well is dead. Set BPV. ND tree. NU and test BOPE. Screw in landing joint. POOH w/4-1/2" x 2.7/8" dual ESP oompletion standing back tubing for re-run. Repair ESP. RIH w/4-1/2" x 2-7/8" dual ESP completion as per attached schematic. MU ESP cable penetrator system, Test wellhead penetrators and cable conductivity's as required. Land tubing. ND BOPE. NU and test tree. Freeze protect well with diesel. Lower Limit: 4.0 days Expected Case: 4.0 days Upper Limit: 5,0 days NO problems pulling or re-running completion Difficulties encountered pulling or re-running ESP completion. MAC 10/30/98 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Dora I. Soria Land Department, ATO 1360 Phone (907) 265-6297 Fax: (907) 263-4966 October 13, 1999 ~ CERTIFIED MAIL State of Alaska Department of Natural Resources Division of Oil and Gas \ 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 / Attention: Mr. Kenneth A. Boyd Re: Status Report ~ _-. --~ati°n ~ RECEIVED ~---4_1~401 Ugnu Test Well~ ~'" Kuparuk River Unit, Tract 34 Your ADL-025639 Our ALK 464 Dear Mr. Boyd: 0 CT 15' 1999 AJaS~ Oil & g~ Cons. Commission Anchorage In accordance with the requirements set forth in your Tract Operation approval letter dated October 16, 1998, ARCO Alaska, Inc. ("ARCO") acknowledges that the one-year approval period for the Tract Operation will expire on October 16, 1999, and hereby provides you with an update on the suspended Ugnu production test. - As noted in the Six Month Status Report dated April 13, 1999, the test well was suspended and isolated from the production system. There have been no additional well activities since the April report with the exception of limited equipment relocations. Kill weight brine fills the well and a back pressure valve is installed in the tubing hanger. A copy of the approved well Sundry is attached. Only trace amounts of oil were ever produced from the well and down hole samples were not obtained. There are currently no plans to re-initiate the test in 1999. However, further testing is currently being evaluated for year 2000. If future operations are contemplated, ARCO will request a new Tract Operation approval. Page 2 Status Report October 13, 1999 If you have any questions regarding the operation please contact Steve Bross at 265- 6083. Very truly yours, Dora I. Soria Senior Landman CC: Mike Kotowski Dan Dickinson Jack Hartz Stephen Bross Jordan Wiess Central Files DRN DOR AOGCC ATO - 1126 ATO - 1146 February 26, 1998 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1H-Ugnu-01 (Permit No. 98-101) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1H-Ugnu-01. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Shallow Sands Drilling Team Leader TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well O~L [] GAS I---1 SUSPENDED I--I AB^NDONE© SERWCE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-101 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22887 At Top Producing Interval469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM ~~ ,~-{~--~ J,~i c i ~:;J [~/"!; i~ Kuparuk River Unit 509' FSL, 1050' FEL, Sec. 28, T12N, R10E, UM i ...... -" i 1H-Ugnu-01 984' FNL, 1989' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk Oil Pool RKB 41', Pad 54' ADL 25639 ALK 464 12 Date05.Jun.98Spudded 13 13-Jun-98Date T.D. Reached 14 10-Sep-98Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 5511' MD & 3199' TVD 5145' MD & 3197' TVD YES ~ NO U NA feet MD 1817 APPROX 22 Type Electdc or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE w-r GRADE TOP BTM HOLE SIZE CEMENT RECORD 20' 91.5# H-40 SURF. 121' 30' 10 cu. yds High Eady 10.75' 40.5# J-55 SURF. 3982' ]3.75" 514 sx ASIIILW, 618 sx Class G, 60 sx ASI 7' 26# L-80 3568' 5187' 9.875' slotted liner 24 Per[orations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE (dual string) DEPTH SET (MD) PACKER SET (MD) 4.5' 3464' N/A N/A 2.875' 3600' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE J GAS-OIL RATIO I TEST PERIOI · Flow Tubing Casing Pressure CALCULATED OiL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. gr~ci~rag[ Form 10-407 Submit in duplicate Rev. 7-]-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. Ugnu B 3732' 5550' Annulus left open - freeze protected with diesel. 31. LIST OF A1-FACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge.. ~",Z/,~/,~ ~,,j ,.~.~ ,~ ) Signed Title '~'-~h~,/...~_/f~'~c~(: DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/5/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iH-UGNU-01 WELL_ID: 999144 TYPE: AFC: 999144 STATE:ALASKA 22887-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/05/98 START COMP:09/02/98 RIG:NORDIC # 2 BLOCK: FINAL:09/ll/98 WI: 0% SECURITY:0 API NUMBER: 50-029- 06/01/98 (D1) TD: 121' (121) SUPV:DEB 06/02/98 (D2) TD: 121'( SUPV:DEB o) 06/03/98 (D3) TD: 121'( SUPV:DEB o) 06/04/98 (D4) TD: 121'( SUPV:DEB o) 06/05/98 (D5) TD: 1478'(1357) SUPV:DEB 06/06/98 (D6) TD: 2782' (1304) SUPV:DEB 06/07/98 (D7) TD: 3997'(1215) SUPV:DEB MW: 0.0 VISC: Moving rig 0 PV/YP: 0/ 0 APIWL: 0.0 Move drilling and utility modules off well and from 3K pad to IH pad. MW: 0.0 VISC: Moving rig 0 PV/YP: 0/ 0 Continue to move rig from 3K pad to IH pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 Moving drilling module over well Move drilling modules to 1H-Ugnu. MW: 0.0 VISC: Prepare to spud 0 PV/YP: 0/ 0 APIWL: 0.0 APIWL: 0.0 APIWL: 0.0 NU diverter and function test. Spud and drill from 121' to 351'. MWD not working properly. Found a nozzle blown out of bit. Drill to 1478'. Got gas cut from 10.4 ppg to 9.6 ppg. Circulate out gas cut and finish weight up to 10.6 ppg. MW: 10.6 VISC: 85 PV/YP: 31/30 Drilling @ 3200' MD APIWL: 5.6 Drill from 1478' to 2356' MD. Mud gas cut to 9.7 ppg. Drill to 2688' MD. Not getting enough dogleg for drop and turn. Pump slug. Drill to 2782' MD. MW: 10.5 VISC: 75 PV/YP: 29/32 Opening hole to 13.75" @ 440' MD APIWL: 5.6 Drill from 2782' to 3997' MD. Build angle to near horizontal. MW: 10.4 VISC: 85 PV/YP: 27/34 CBU @ 2299' APIWL: 7.4 Move rig modules to iH pad. Accept rig @ 1200 hrs. 6/4/98. NU diverter stack. Date: 10/5/98 ARCO ALASKA INC. WELL SLrMMARY REPORT Page: 2 06/08/98 (D8) TD: 3997'( SUPV:DEB 06/09/98 (D9) TD: 3997'( SUPV:DCL 0) 0) 06/10/98 (D10) TD: 3997' ( 0) SUPV:DCL 06/11/98 (Dll) TD: 4017'( 20) SUPV:DCL 06/12/98 (D12) TD: 4323'(306) SUPV:DCL 06/13/98 (D13) TD: 5511'(1188) SUPV:DCL 06/14/98 (D14) TD: 5511' ( 0) SUPV:DCL 06/15/98 (D15) TD: 5511'( 0) SUPV:DCL MW: 10.5 VISC: 90 PV/YP: 38/35 APIWL: 4.0 Opening hole to 13.75" at 3821' Open hole to 13.75" from 121' to 3196' MW: 10.5 VISC: 72 PV/YP: 32/25 APIWL: 4.2 Circ and condition mud for cement Open hole from 9-7/8" to 13.75" from 3196' to 3997' Ream from 2509' to 2588' Tight hole 2474', 2188', 1903', 896' Work through tight spot, OK. RIH w/ 10.75" casing. MW: 10.4 VISC: 62 PV/YP: 30/23 APIWL: 4.2 Test casing after drill out stage tool Wash and push casing from 2127' to 2442' Pump cement. ND diverter, NU BOPE and test to 300/3000 psi. MW: 9.2 VISC: 85 PV/YP: 28/29 APIWL: 4.4 Mix sweeps Drill out cement and stage tool. Drill out cement to 3836' Drill out float equipment and 20' new formation to 4017' Performed LOT, 12.1 EMW. MW: 9.3 VISC: 57 PV/YP: 20/18 APIWL: 3.5 Drilling at 4580' Mix Baroid drill in fluid. Pump dry job. Drill from 4017' to 4323' MW: 9.3 VISC: 62 PV/YP: 20/26 APIWL: 3.2 Wiper trip Drill from 4323' to 5511' MW: 9.3 VISC: 64 PV/YP: 19/25 APIWL: 3.6 Clean pits for filtered brine Circ hole clean at shoe while rotate and reciprocate pipe. Continue to clean pits. MW: 9.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Prep to displace well w/clean brine Clean pits. Filter brine into suction pits. Reciprocate and displace hole with zanvis sweep and brine. Date: 10/5/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/16/98 (D16) TD: 5511'( 0) SUPV:DCL 06/17/98 (D17) TD: 55~1' ( 0) SUPV:DCL 06/18/98 (D18) TD: 5511' ( 0) SUPV:DCL 06/19/98 (D19) TD: 5511' ( 0) SUPV:DCL 06/20/98 (D20) TD: 5511' ( 0) SUPV:DCL MW: 9.3 VISC: prep to run liner 0 PV/YP: 0/ 0 APIWL: 0.0 Standby for MI to mix brine. Pump zanvis sweep. Pump caustic wash. MW: 9.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LD DP Finish circ caustic wash. RIH to TD. Had minor tight hole from 5200' to 5511'. Rotate drill string. No problems. No drag. RIH w/7" slotted liner. RIH and space out 2-7/8" wash string. RIH w/liner on 4" DP. Liner stopped at 5184' Attempt to work liner down. Worked to 5189' Spotted zanvis pill. No success. Pipe no longer free moving up. MW: 9.3 VISC: Circ hot brine 0 PV/YP: 0/ 0 APIWL: 0.0 LD Baker setting tool. LD 2-7/8" wash pipe. Run 20 stds 4" DP. POH LD same. Monitor well. Fluid loss. ND stack. NU tubing head. Moved camp to iD pad. ND BOPE, NU BOP. Test all BOPE to 300/3000 psi. RIH w/2-7/8" wash assembly. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOP RIH w/2-7/8" tubing and 4" DP. Circ well w/brine. Losses increased. Pump 10% acetic acid. MW: 0.0 VISC: Rig released 0 PV/YP: 0/ 0 APIWL: 0.0 Freeze protect well. ND BOPE. NU 13-5/8" x 7-1/16" DSA and valve. Released rig at 12:00 6/20/98. Date: 10/5/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 REMEDIAL AND COMPLETION OPERATIONS WELL:iH-UGNU-01 WELL_ID: 999144 TYPE: AFC: 999144 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER I/NIT SPUD:06/05/98 START COMP:09/02/98 RIG:NORDIC # 2 WI: 0% SECURITY:0 API NUMBER: 50-029-22887-00 BLOCK: FINAL:09/ll/98 09/02/98 (C21) TD: 0' PB: 0' 09/03/98 (C22) TD: 5511' PB: 5511' 09/04/98 (C23) TD: 5511' PB: 5511' 09/05/98 (C24) TD: 5511' PB: 5511' 09/06/98 (C25) TD: 5511' PB: 5511' 09/07/98 (C26) TD: 5511' PB: 5511' 09/08/98 (C27) TD: 5511' PB: 5511' 09/09/98 (C28) TD: 5511' PB: 5511' CONTINUE TURN KEY RIG MOV MW: 0.0 DOIL SUPV:DONALD L. WESTER Turn key rig move from 2C to iH pad. Lay rig mats down. STUCK RIG IN FRONT OF iH- MW: 0.0 DOIL SUPV:DONALD L. WESTER Accept rig due to road condition @ 0001 hrs. 9/3/98. Continue rig move from 2C to iH pad. Stuck rig 3/4 mile from iH pad. Lay out all rig mats. Stuck rig in front of 1H-Ugnu-O1 backing over well. TESTED BOPE, RELEASED HOW MW: 9.3 BRINE SUPV:DONALD L. WESTER Spot rig over well. N/D dry hole valve. N/U 13-5/8" 5M double gate. Install rams and function test. Test BOPE 250/3500 psi. CONTINUE RIH W/ BHA #1 5. MW: 9.3 BRINE SUPV:DONALD L. WESTER POOH 4" drill pipe. Run 5.5" chemical cutter to 3580'. Cut 7" liner. CIRCULATE AND FILTER BRIN MW: 9.3 BRINE SUPV:DONALD L. WESTER RIN with 5-7/8" spear and latch into liner top packer @ 3260'. POOH w/fish. Run Baker ZXP packer. POOH W/ 2.875" TBG STAND SUPV:DONALD L. WESTER RIH with 2-7/8" tubing. MW: 9.3 BRINE R/U DUAL EQUIPMENT, PICK SUPV:DONALD L. WESTER RIH with 4.5" tubing. MW: 9.3 BRINE SPACING OUT 4-1/2" WITH H SUPV:DONALD L. WESTER & RICK OVERST RIH w/ESP equipment. MW: 9.3 BRINE Date: 10/5/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 09/10/98 (C29) TD: 5511' PB: 5511' 09/11/98 (C30) TD: 5511' PB: 5511' 09/12/98 (C31) TD: 5511' PB: 5511' FINISHED PUMPING FREEZE P MW: 9.3 BRINE SUPV:RICK OVERSTREET Continue to RIH with 2-7/8"x 4.5" tubing, ESP and heat trace. ND BOPE, NU tree and test to 250/5000 psi. MOVING RIG FROM iH TO 3B MW: 9.3 BRINE SUPV:RICK OVERSTREET Freeze protect well. RDMO to 3B-14. Release well @ 0500 hrs. 9/11/98 MOVING RIG FROM 1H-01 TO SUPV:RICK OVERSTREET Move rig. MW: 0.0 nl ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No. Page 1 of 5 · ~ [![~ ~ I :(---'~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD - WELL DATA Target TVD (ET) Target Coord. N/S Slot Coord. N/S -469,00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS0 Target Description Target Coord, E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ftr~ 30m~] 10m0 Vert, Sec. Azim. 220.43 Magn. to Map Corr. 27,630 Map North to: OTHER suRvEY DATA " ' Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / $(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F-r) (DO) (DD) (FT) (FT) (F'D (F-T) Per 100 F'D Drop (-) Left (-) 0.00 0.00 0.00 0,00 0.00 0.00 0,00 TIE IN POINT 05-JUN-98 MWD 121.00 0.00 0,00 121.00 121.00 0,00 0.00 0.00 0.00 0.00 8" M1C 1,6 DEG AKO 05-JU N-98 MWD 196.78 0.82 54.62 75.78 196.78 -0.53 0.31 0.44 1.08 1,08 05-J U N-98 MWD 282.78 1.96 347.76 86.00 282.75 -2.01 2.11 0.63 2.10 1.33 05-JUN-98 MWD 372.77 3.80 355.69 89.99 372,63 -5.07 6.59 0.08 2.09 2.04 05-JUN-98 MWD 456.31 5.81 3.24 83.54 455.87 -10.40 13.57 0.11 2.52 2.41 9.04 -, 05-JU N-98 MWD 553.06 9.21 7.35 96.75 551.78 -20.79 26.14 1.38 3.56 3.51 4.25 05-JUN-98 MWD 645.17 14.83 6.13 92.11 641,83 -36.72 45,19 3.58 6.11 6.10 -1.32 05-J U N-98 MWD 731.36 19.43 5.50 86.19 724.18 -57.60 70,44 6.14 5.34 5.34 -0.73 05-JUN-98 MWD 826.74 22.97 7.75 95.38 813.09 -86.28 104.68 10.17 3.81 3.71 2.36 _, 05-JUN-98 MWD 916.68 25.49 11.38 89.94 895.10 -117.97 141.05 16.36 3.25 2.80 4.04 ... · 05-JUN-98 MWD 1006.07 29.47 12.35 89.39 974.39 -154.20 181.40 24.86 4.48 4.45 1.09 _. 05-JUN-98 MWD 1096.77 32.31 11.03 90.70 1052.22 -195.02 227.00 34.27 3.22 3.13 -1.46 05-JUN-98 MWD 1186.62 35.29 11.83 89.85 1126.88 -238.73 275,98 44.19 3.35 3.32 0.89 05-JUN-98 MWD 1282.35 37.80 10.61 95.73 1203.78 -288.47 331.89 55.26 2.73 2.62 -1.27 06-J UN-98 MWD 1377.36 38.82 10.32 95.01 1278,33 -339.50 389.81 65.95 1.09 1.07 -0.31 06-JUN-98 MWD 1471.36 39.16 9.64 94.00 1351,39 -390.48 448.06 76.20 0.58 0.36 -0.72 06-J UN-98 MWD 1565.35 39.95 7.91 9§.99 1423.86 -441.42 507.21 85.33 1.44 0.84 -1.84 06-J U N-98 MWD 1663.14 40.11 8.33 97.79 1498,74 -494.58 569.47 94.21 0.32 0.16 0.43 06-JUN-98 MWD 1757.23 40.85 8.10 94.09 1570,31 -546.26 629,93 102.94 0.80 0,79 -0.24 06-J U N-98 MWD 1853.23 39.11 6.16 96.00 1643.87 -597.81 691.12 110.61 2.23 -1.81 -2.02 06-J U N-98 MWD 1948.50 39.11 5.37 95.27 1717.79 -647.24 750,91 116.65 0.52 0,00 -0.83 -0'~'~ ~'~ ~--~'8--M-WD ..... '~':~i~ ...... 3~)i~5'-' 7.61 95.22 1791.50 -697.25 81o.8o 123.46 1.53 0.36 2.35 06-J U N-98 MWD 2139.38 39.91 7.30 95.66 1865,12 -748.49 871.37 131.39 0.52 0,48 -0.32 _ · i iii i ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No. Page 2 of 5 · -' [~ = I ::~-1 Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Dessription Target Coord, E/W Slot Coord, E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft~ 30mi'-] 10m~ Vert. Sec. Azim. 220.4~3 Magn. to Map Corr. 27.630 Map North to: OTHER i i iii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FI') (FT) (F'l') , (FT) (Per 100 F'r)Drop (-) Left (-) 06-JU N-98 MWD 2235.80 38,49 8.48 96.42 1939.84 -799.86 931.73 139.74 1.66 -1.47 1,22 06-JUN-98 MWD 2329.65 36.92 7.92 93.85 2014.09 -848.41 988.54 147.94 1.71 -1.67 -0.60 06-JUN-98 MWD 2429.98 36.75 7.70 100.33 2094.39 -899.07 1048.13 156.11 0.21 -0.17 -0.22 06-J U N-98 MWD 2461.01 35.85 9.16 31.03 2119.40 -914.65 1066,30 158.80 4.02 -2.90 4.71 06-JUN-98 MWD 2493.05 35.17 8.27 32.04 2145.48 -930.48 1084.69 161.62 2.67 -2.12 -2.78 06-JUN-98 MWD 2524.05 33.10 7.07 31.00 2171.14 -945.11 1101.93 163.95 7.02 -6.68 -3.87 06-JU N-98 MWD 2556.18 31.15 5.27 32.13 2198.35 -959.23 1118.91 165.79 6.76 -6.07 -5.60 ..... 06-JU N-98 MWD 2587.41 29.59 3.04 31.23 2225.30 -971.96 1134.66 166.94 6.16 -5.00 -7.14 06-J U N-98 MWD 2618.22 28.32 0.53 30.81 2252.25 -983.62 1149.56 167.41 5.70 -4.12 -8.15 06-J UN-98 MWD 2649.25 27.36 356.23 31.03 2279.70 -994.38 1164.04 167.01 7.17 -3.09 -13.86 06-JUN-98 MWD 2681.28 25.89 353.19 32.03 2308.33 -1004.40 1178.33 165.70 6.26 -4.59 -9.49 8" M1C 2 DEG AKO -, 07-JUN-98 MWD 2712.39 23.60 348.87 31.11 2336.58 -1012.89 1191.19 163.69 "9.37 -7.36 -13.89 07-JUN-98 MWD 2744.52 21.01 344.22 32.13 2366.31 -1020.09 1203.04 160.88 9.75 -8.06 -14.47 07-JU N-98 MWD 2775.84 19.35 337.72 31.32 2395.71 -1025.59 1213.25 157.39 8.90 -5.30 -20.75 ,'_ 07-JUN-98 MWD 2807.18 18.33 329.59 31.34 2425.38 -1029.59 1222.30 152.92 8.98 -3.25 -25.94 07-JU N-98 MWD 2839.40 18.'04 321.07 32.22 2455.99 -1032.17 1230.56 147.22 8.29 -0.90 -26.44 -- 07-J U N-98 MWD 2871.55 17.70 312.68 32.15 2486.60 -1033.29 1237.74 140.50 8.07 -1.06 -26.10 07-JUN-98 MWD 2902.30 17.17 303.49 3~).75 2515.94 -1032.92 1243.42 133.28 9.11 -1.72 -29.89 07-JU N-98 MWD 2934.55 18.49 295.76 32.25 2546.64 -1031.05 1248.27 124.70 8.39 4.09 -23.97 07-J U N-98 MWD 2966.81 20.23 288.33 32.26 2577.08 -1027.66 1252.25 114.80 9.34 5.39 -23.03 07-J U N-98 MWD 2998.93 22.11 281.23 32.12 2607.04 -1022.62 1255.17 103.59 9.89 5.85 -22.10 -- 07-J U N-98 MWD 3030.91 23.97 274.60 31.98 2636.47 -1015.88 1256.86 91.21 9.97 5.82 -20.73 07-J U N-98 MWD 3063.01 25.40 269.21 32.10 2665.64 -1007.52 1257.29 77.82 8.30 4.45 -16.79 07-JU N-98 MWD 3093.10 26.74 263.00 30.09 2692.67 -998.28 1256.38 64.65 1 O. 10 4.45 -20.64 i ii SURVEY CALCULATION AND FIELD WORKSHEET Jo No. 0450-98229 Sidetrack No, Page 3 of 5 _1~ :ll['lr~_"l :/t--~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co.- #245 Field KUPARUK RIVER UNIT I-- Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A. HARSTAD WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[-] SS~ Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 220.43 Magn. to Map Corr. 27.630 Map North to: OTHER I SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F~ (DD) (DD) (FT) (FT) (FT) (FT) (Per mO F'r)IDrop (-) Left (-) 07-J U N-98 MWD 3125.03 28.42 256.91 31.93 2720.98 -986.88 1253.78 50.12 10.27 5.26 -19.07 07-J U N-98 MWD 3157.09 29.74 251.21 32.06 2749.00 -973.91 1249.49 35.15 9.57 4.12 -17.78 07-J U N-98 MWD 3189.01 31.33 245.37 31.92 2776.50 -959.58 1243.48 20.11 10.54 4.98 -18.30 -- 07-J U N-98 MWD 3220.44 32.33 240.30 31.43 2803.21 -944.26 1235.91 5.38 9;08 3.18 -16.13 07-JUN-98 MWD 3251.81 33.33 234.28 31.37 2829.58 -928.00 1226.72 -8.91 10.88 3.19 -19.19 07-J U N-98 MWD 3283.92 34.59 229.75 32.11 2856.21 -910.44 1215.68 -23.03 8.80 3.92 -14.11 -- 07-JUN-98 MWD 3316.26 35.77 225.75 32.34 2882.65 -891.96 1203.15 -36.81 8.00 3.65 -12.37 07-j UN-98 MWD 3347.47 38.67 224.31 31.21 2907.50 -873.15 1189.80 -50.16 9.70 9.29 -4.61 07-JU N-98 MWD 3379.05 40.75 223.24 31.58 2931.79 -853.01 1175.23 -64.11 6.93 6.59 -3.39 07-J UN-98 MWD 3486.05 42.76 223.70 107.00 3011.61 -781.86 1123.53 -113.14 1.90 1.88 0.43 07-JUN-98 MWD 3557.72 49.67 224.15 71.67 3061.17 -730.24 1086.29 -149.02 9.65 9.64 0.63 , 07-JUN-98 MWD 3604.37 54.01 223.17 46.65 3089.99 -693.63 1059.75 -174.33 9.45 9.30 -2.10 07-J UN-98 MWD 3652.77 58.64 223.45 48.40 3116.82 -653.41 1030.46 -201.95 9.58 9.57 0.58 07-JU N-98 MWD 3700.28 63.52 222.67 47.51 3139.79 -611.89 1000.08 -230.33 10.37 10.27 -1.64 07-j UN-98 MWD 3748.00 68.01 221.87 47.72 3159.37 -568.41 967.88 -259.59 9.53 9.41 -1.68 07-J U N-98 MWD 3794.76 72.69 220.25 46.76 3175.09 -524.38 934.68 -288.50 10.53 10.01 -3.46 07-J UN-98 MWD 3841.99 77.05 220.24 47.23 3187.42 -478.80 899.89 -317.94 9.23 9.23 -0.02 07-JUN-98 MWD 3889.74 81.20 220.90 4~.75 3196.42 -431.92 864.28 -348.44 8.80 8.69 1.38 07-JUN-98 MWD 3930.59 85.12 221.37 40.85 3201.29 -391.37 833.74 -375.11 9.66 9.60 1.15 12-JUN-98 MWD 3999.99 87.10 220.36 69.40 3206.00 -322.14 781.38 -420.41 3.20 2.85 -1.46 8' M1C 1.6 DEG AKO 12-J UN-98 MWD 4040.42 86.53 221.14 40.43 3208.24 -281.77 750.80 -446.76 2.39 -1.41 1.93 12-J UN-98 MWD 4072.50 87.78 221.66 32.08 3209.84 -249.74 726.76 -467.95 4.22 3.90 1.62 -- 12-J UN-98 MWD 4110.10 90.09 219.13 37.60 3210.53 -212.15 698.14 -492.31 9.11 6.14 -6.73 12-J UN-98 MWD 4142.14 90.72 218.37 32.04 3210.31 -180.12 673.15 -512.36 3.08 1.97 -2.37 i i SURVEY CALCULATION AND FIELD ------------WORKSHEET Job No, 0450-98229 Sidetrack No. Page 4 of 5 I Field KUPARUK RIVER UNIT ! rl~ -' I ::(---'~Ja Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co.- #245 [! Well Name & No, PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep, ROBBY BARNARD/A,HARSTAD ' WELL DATA Target TVD (F-r) Target Coord, N/S Slot Coord, N/S -469.00 Grid Correction 0,000 Depths Measured From: RKB ~] MSLr-J SS[~ Target Description Target Coord. E/W Slot Coord, E/W -804,00 Magn, Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft[~ 30m[~ 10m0 Vert. Sec, Azim, 220,43 Magn. to Map Corr. 27.630 Map North to: OTHER i ii su'RvEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl, Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / $(-) E(+) / W(-) DL Type (F'ri (DD) (DD) (FT) (FT) (FT) ..... (FT) (Per 100 FT) Drop (-) Left (-) 12-J U N-98 MWD 4174,01 90,12 217.92 31.87 3210.07 -148.28 648.09 -532.05 2,35 -1.88 -1.41 12-JUN-98 MWD 4204,74 89,83 216,87 30,73 3210,09 -117,60 623,67 -550,71 3,54 -0,94 -3,42 12-J U N-98 MWD 4235,92 91,26 215,85 31,18 3209,79 -86,50 598,57 -569,19 5,63 4,59 -3.27 13-JU N-98 MWD 4267,76 93,71 215,83 31,84 3208,41 -54,79 572,78 -587,82 7,70 7,69 -0,06 13-JUN-98 MWD 4299,75 95,42 215,18 31,99 3205,86 -23,02 546.82 -606,34 5,72 5,35 -2,03 ~I 13 - ,JUN - 98 MWD 4330,59 97,27 213.95 30,84 3202.46 7,47 521,58 -623,72 7,19 6,00 -3,99 ..... 13-JUN-98 MWD 4361,93 98,94 211,96 31,34 3198,04 38,23 495,55 -640.60 8,24 5.33 -6,35 .. 13-JUN-98 MWD 4393,69 98.57 210,45 31,76 3193,20 69,21 468,70 -656,86 4,84 -1,16 -4,75 13-JUN-98 MWD 4426,35 96,11 209,00 32,66 3189,03 101,04 440,58 -672,92 8,72 -7,53 -4.44 13-JUN-98 MWD 4452,41 94,09 210.41 26.06 3186.71 126,54 418.03 -685,78 9,44 -7,75 5.41 13-JUN-98 MWD 4485,03 92,09 210,14 32,62 3184,96 158,60 389.90 -702.21 6,19 -6.13 -0,83 . 13-JUN-98 MWD 4519.87 90,82 207.15 34,84 3184,07 192.69 359,34 -718,90 9,32 -3,65 -8,58 , 13-J UN-98 MWD 4550,27 89.16 208.74 . 30.40 3184,08 222,37 332,49 -733,14 7,56 -5,46 5.23 13-JU N-98 MWD 4581.41 87,67 208,08 31,14 3184,94 252.81 305,11 -747,95 5.23 -4,78 -2.12 ,-- 13-JUN-98 MWD 4612.08 88,34 207.62 30,67 3186.00 282.73 278.01 -762,27 2,65 2.18 -1.50 13-J UN-98 MWD 4645,31 90,19 206,76 33,23 3186,43 315,07 248,46 -777.46 6,14 5.57 -2,59 -. 13-J UN-98 MWD 4671,26 90,02 206.07 25,95 3186.38 340.25 225,22 -789.00 2.74 -0.66 -2.66 13-J UN-98 MWD 4702,03 88.47 207.15 3{),77 3186,79 370,12 197.71 -802,78 6.14 -5,04 3.51 13-JU N-98 MWD 4733.95 88.41 207.27 31,92 3187,66 401.18 169.33 -817,37 0,42 -0,19 0.38 13-J U N-98 MWD 4765.50 88.00 207.17 31.55 3188.65 431.88 141.29 -831,79 1.34 -1.30 -0,32 13-J U N-98 MWD 4798.21 88.20 207.41 32.71 3189.73 463.72 112.24 -846.78 0.95 0.61 0.73 13-JU N-98 MWD 4826,89 88.06 206,68 28.68 3190.67 491.61 86.71 -859.82 2.59 -0.49 -2.55 13-J U N-98 MWD 4859.57 89.16 206.50 32.68 3191.46 523.33 57.49 -874.44 3.41 3,37 -0.55 .... 13-J U N-98 MWD 4890.74 89.18 206.24 31.17 3191.91 553.56 29.57 -888.28 0.84 0.06 -0.83 i ii ii SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No. Page 5 of 5 · = [w[~; I :~-'~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD II I WELL DATA Target TVD (F-T) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL[~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ff~ 30m~ 10m~ reft. Sec. Azim. 220.43 Magn. to Map Corr. 27.630 Map North to: OTHER SURVEY DATA , , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (OD) (DD) (F'r) (FI') (F-r) (F-r) (Per 100 FT) Drop (-) Left (-) 13-JUN-98 MWD 4924.35 89.10 206.39 33.61 3192.41 586.15 -0.56 -903.18 0.51 -0.24 0.45 13-JUN-98 MWD 4953.94 88.34 207.48 29.59 3193.08 614.92 -26.93 -916.58 4.49 -2.57 3.68 13-JU N-98 MWD 4985.90 88.13 207.95 31.96 3194.06 646.08 -55.21 -931.44 1.61 -0.66 1.47 .... 13-JUN-98 MWD 5019.98 89.04 208,46 34.08 3194.90 679.38 ' -85;23 -947.54 3.06 2.67 1.50 13-JUN-98 MWD 5050.32 89.29 208.46 30.34 3195.34 709.05 -111.90 -962.00 0.82 0.82 0,00 i 3-JUN-98 MWD 5082.87 88,95 209.41 32.55 3195.84 740.95 -140.39 -977.74 3.10 -1.04 2,92 13-JUN-98 MWD 5112.12 89.22 209.31 29.25 3196.31 769.65 -165.88 -992.08 0.98 0.92 -0.34 ~3-JUN-98 MWD 5143.21 89.50 208.73 31.09 3196,66 800.12 -193.06 -1007.16 2.07 0.90 -1.87 , , 13-JUN-98 MWD 5177.00 89.37 209.37 33.79 3196.99 833.25 -222.60 -1023.57 1.93 -0.38 1.89 13-JUN-98 MWD 5212.43 88.34 208.95 35.43 3197.70 867.98 -253.53 -1040.83 3.14 -2.91 -1.19 13-JUN-98 MWD 5242.79 87.12 209.18 30.36 3198.90 897.73 -280.05 -1055.57 4.09 -4.02 0.76 . 13-JUN-98 MWD 5273.29 87.39 209.05 30.50 3200.36 927.60 -306.66 -1070.39 0.98 0.89 -0.43 13-JUN-98 MWD 5305.25 89.90 209.12 31.96 3201.12 958.92 -334.58 -1085.92 7.86 7.85 0.22 13-J UN-98 MWD 5335.60 91.11 209.85 30.35 3200.85 988.72 -361.00 -1100.86 4.66 3.99 2.41 13-J U N-98 MWD 5367.66 91.33 210.02 32.06 3200.17 1020.24 -388.78 -1116.85 0.87 0.69 0.53 13-JU N-98 MWD 5398.96 90.87 207.54 31.30 3199.57 1050.88 -416.20 -1131.92 8,06 -1.47 -7.92 13-JU N-98 MWD 5432.13 90.54 207.90 33.17 3199.16 1083.24 -445.56 -1147.34 1,47 -0.99 1.09 13-JU N-98 MWD 5448.77 90.39 209.24 16.64 3199.02 1099.52 -460.18 ' -1155.30 8.10 -0.90 8.05 13-JUN-98 MWD 5511.00 90.38 209.24 62.23 3198.61 1160.57 -514.48 -1185,70 0.02 -0.02 0.00 Projected Data - NO SURVEY _-- _. -- iii i i ii i i i i iii i i i i ii i l,lllll,l 111 i i llll ' I ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98220 Sidetrack No,Page1 of 5 · ~ [![~'- I ::/c--'~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT ~ m=m-m,m~mm, Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD ii iii i i ii i ii ii i ~ · WELL DATA ,, Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL0 SS~-] Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mb~ lom~ Vert. Sec. Azim. 220.43 Uagn. to Map Corr. 27.630 Map North to: O__T_THER " suRVEY DAT/~, ............. ,, Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F-r) (DO) (DO) (FT) ........ (FT) (FT) (F-r) (Per lO0 F'D: Drop (-) Left (-) 0.00 0.00 0,00 0.00 .... 0.00 0.00 0.00 TIE IN POINT '\./ 05-JUN-98 MWD 121.00 0.00 0,00 121.00 121,00 0.00 0.00 0.00 0,00 0.00 8' M1C 1.6 DEC AKO ,. 05-JUN-98 MWD 196.78 0.82 54.62 75.78 196,78 -0.53 0.31 0.44 1,08 1,08 , 05-JUN-98 MWD 282.78 1.96 347.76 86,00 282.75 -2.01 2.11 0,63 2.10 1.33 ..... 05-JUN-98 MWD 372,77 3.80 355.69 89,99 372,63 -5.07 6.59 0.08 2.09 2.04 05-JUN-98 MWD 456,31 5.81 3.24 83,54 455,87 -10.40 13.57 0.11 2.52 2.41 9,04 05-JU N-98 MWD 553.06 9,21 7,35 96,75 551.78 -20,79 26,14 1.38 3,56 3.51 4.25 ., 05-JU N-98 MWD 645,17 14.83 6,13 92.11 641.83 -36.72 45.19 3,58 6.11 6.10 -1,32 05-JUN-98 MWD 731.36 19.43 5,50 86.19 724,18 -57.60 70,44 6.14 5,34 5,34 -0.73 05-JUN-98 MWD 826,74 22.97 7,75 95,38 813,09 -86,28 104.68 10.17 3,81 3,71 2.36 ,., 05-JUN-98 MWD 916,68 25.49 11.38 89.94 895.10 -117.97 141.05 16.36 3.25 2.80 4.04 , 05-JUN-98 MWD 1006.07 29.47 12.35 89.39 974,39 -154.20 181,40 24.86 4.48 4,45 1,09 , ..... 05-JUN-98 MWD 1096.77 32,31 11,03 90.70 1052.22 -195.02 227.00 34.27 3.22 3.13 -1.46 ill 05-JUN-98 MWD 1186.62 35.29 11.83 89.85 1126.88 -238.73 275.98 44.19 3.35 3,32 0.89 05-JUN-98 MWD 1282.35 37.80 10.61 95.73 1203.78 -288.47 331,89 55.26 2,73 2,62 -1,27 06-JUN-98 MWD 1377.36 38.82 10,32 95.01 1278.33 -339.50 389.81 65,95 1,09 1.07 -0.31 08-J UN-98 MWD 1471.36 39.16 9.64 94,00 1351.39 -390,48 448.06 76.20 0.58 0,36 -0.72 06-JUN-98 MWD 1565.35 39.95 7.91 95.99 1423.86 -441,42 507,21 85.33 1.44 0.84 -1.84 06-JU N-98 MWD 1663,14 40.11 8.33 97.79 1498.74 -494.58 569.47 94.21 0.32 0,16 0.43 -- 06-J U N-98 MWD 1757.23 40.85 8.10 94.09 1570.31 -546.26 629,93 102.94 0.80 0,79 -0.24 -- 06-JUN-98 MWD 1853.23 39.11 6,16 96,00 1643,87 -597,81 691.12 110,61 2.23 -1.81 -2,02 -- 06-JUN-98 MWD 1948.50 39.11 5.37 95.27 1717.79 -647.24 750.91 116.65 0.52 0,00 -0.83 06-J U N-98 MWD 2043.72 39.45 7.61 95.22 1791.50 -697,25 810.80 123,46 1.53 0.36 2.35 06-J U N-98 MWD 2139.38 39.91 7.30 95.66 1865,12 -748,49 871.37 131.39 0.52 0,48 -0.32 i i ii i i i ii ! i I i i i i i ii i i i i i ii i i i,iii r ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No.Page2 of 5 · ~ [11~1~ ~ ~.....~ Company ARCO ALASKA, lNG. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Sun/ey BHI Rep. ROBBY BARNARD/A.HARSTAD WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSc Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (oD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 220.4~3 Magn. to Map Corr. 27.630 Map North to: OTHER ........ SURVEy DAT~,-, .............. _ -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) "E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FI') (FT) (FT) (Fi') (Per m0 FTI Drop (-) Left (-) 06-JUN-98 MWD 2235.80 38.49 8.48 96.42 1939.84 -799.86 931.73 139.74 1.66 -1.47 1.22 06-JUN-98 MWD 2329.65 36.92 7.92 93.85 2014.09 -848,41 988.54 147.94 1.71 -1.67 -0.60 .,, 06-JUN-98 MWD 2429.98 36.75 7.70 100,33 2094.39 -899.07 1048.13 156,11 0.21 -0.17 -0.22 06-J UN-98 MWD 2461.01 35.85 9.16 31.03 2119.40 -914.65 1066,30 158,80 4.02 -2,90 4.71 06-JUN-98 MWD 2493.05 35.17 8.27 32.04 2145.48 -930.48 1084.69 161.62 2.67 -2.12 -2.78 06-J UN-98 MWD 2524.05 33.10 7,07 31.00 2171.14 -945.11 1101.93 163.95 7.02 -6.68 -3.87 ..... 06-JUN-98 MWD 2556.18 31.15 5,27 32.13 2198.35 -959.23 1118.91 165.79 6.76 -6.07 -5,60 06-JUN-98 MWD 2587.41 29.59 3.04 31.23 2225.30 -971.96 1134.66 166.94 6.16 -5.00 -7.14 06-JU N-98 MWD 2618.22 28.32 0.53 30.81 2252.25 -983.62 1149.56 167.41 5.70 -4.12 -8.15 06-J UN-98 MWD 2649.25 27.36 356.23 31,03 2279.70 -994.38 1164.04 167.01 7.17 -3.09 -13.86 ,, 06-JUN-98 MWD 2681.28 25.89 353.19 32.03 2308.33 -1004.40 1178.33 165.70 6.26 -4.59 -9.49 8" M1C 2 DEC AKO 07-JUN-98 MWD 2712.39 23.60 348.87 31.11 2336.58 -1012.89 1191.19 163.69 9.37 -7.36 -13.89 07-J UN-98 MWD 2744.52 21.01 344,22 32.13 2366.31 -1020.09 1203.04 160.88 9.75 -8.06 -14.47 07-JU N-98 MWD 2775.84 19.35 337.72 31.32 2395.71 -1025.59 1213.25 157.39 8.90 -5.30 -20.75 .,, 07-J U N-98 MWD 2807.18 18.33 329.59 31,34 2425.38 -1029.59 1222,30 152,92 8.98 -3.25 -25.94 ., 07-JUN-98 MWD 2839.40 18.04 321.07 32.22 2455.99 -1032.17 1230.56 147.22 8.29 -0,90 -26.44 07-JUN-98 MWD 2871,55 17.70 312,68 32,15 2486.60 -1033,29 1237,74 140.50 8.07 -1,06 -26.10 07-J U N-98 MVVD 2902.30 17.17 303.49 3~.75 2515.94 -1032.92 1243,42 133.28 9.11 -1.72 -29.89 07-JU N-98 MWD 2934.55 18.49 295,76 32.25 2546.64 -1031.05 1248.27 124.70 8.39 4.09 -23,97 07-J U N-98 MWD 2966,81 20.23 288,33 32,26 2577.08 -1027.66 1252.25 114.80 9,34 5.39 -23.03 07-J UN-98 MWD 2998.93 22.11 281.23 32.12 2607.04 -1022.62 1255.17 103.59 9.89 5.85 -22.10 07-JUN-98 MWD 3030.91 23.97 274.60 31.98 2636.47 -1015.88 1256.86 91.21 9.97 5.82 -20.73 07-J U N-98 MWD 3063,01 25.40 269,21 32,10 2665.64 -1007,52 1257.29 77.82 8.30 4.45 -16.79 07-J U N-98 MWD 3093.10 26.74 263.00 30.09 2692.67 -998,28 1256.38 64.65 10,10 4.45 -20.64 i i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No. Page 3 of 5 · "_ [I [~-]; 1 ::/t--I Company ARCO ALAgKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT i~ i=i=ii~=i. Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD i i ii i ii ii i i i i WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/VV -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10m~ Vert. Sec. Azim. 220.43 Magn. to Map Corr. 27.630 Map North to: OTHER ' suR~/~Y ...... DATA ....... -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) ' E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (1~) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 07-JU N-98 MWD 3125.03 28.42 256.91 31.93 2720.98 -986.88 1253.78 50.12 10.27 5.26 -19.07 07-JU N-98 MWD 3157,09 29.74 251.21 32.06 2749.00 -973.91 1249.49 35,15 9.57 4.12 -17.78 07-J U N-98 MWD 3189,01 31.33 245.37 31.92 2776.50 -959.58 1243.48 20.11 10.54 4.98 -18.30 .... 07-JU N-98 MWD 3220.44 32.33 240.30 31.43 2803.21 -944.26 1235,91 5.38 9.08 3.18 -16.13 ...... 07-JUN-98 MWD 3251.81 33.33 234.28 31.37 2829.58 -928.00 1226.72 -8.91 10.88 3.19 -19.19 ......... 07-JUN-98 MWD 3:283.92 34.59 229.75 32.11 2856.21 -910.44 1215.68 -23.03 8.80 3.92 -14.11 07-JUN-98 MWD 3316.26 35,77 225.75 32.34 2882.65 -891.96 1203.15 -36.81 8.00 3.65 -12.37 ,, 07-J U N-98 MWD 3347.47 38.67 224.31 31.21 2907.50 -873.15 1189.80 -50.16 9.70 9,29 -4.61 ..........., 07-JU N-98 MWD 3379.05 40.75 223.24 31.58 2931.79 -853.01 1175.23 -64.11 6.93 6.59 -3,39 .. , 07-J UN-98 MWD 3486,05 42.76 223.70 107.00 3011.61 -781.86 1123.53 -113,14 1.90 1,88 0,43 07-JUN-98 MWD 3557.72 49,67 224.15 71,67 3061.17 -730,24 1086.29 -149,02 9.65 9.64 0.63 07-JU N-98 MWD 3604.37 54.01 223.17 46,65 3089,99 -693,63 1059.75 -174,33 9,45 9.30 -2.10 -, 07-JUN-98 MWD 3652.77 58.64 223.45 48,40 3116.82 -653.41 1030.46 -201.95 9.58 9.57 0,58 07-JUN-98 MWD 3700.28 63,52 222.67 47.51 3139.79 -611.89 1000.O8 -230.33 10.37 10.27 -1.64 07-JUN-98 MWD 3748.00 68.01 221.87 47.72 3159,37 -568,41 967.88 -259.59 9.53 9.41 -1.68 07-J UN-98 MWD 3794,76 72,69 220.25 46.76 3175.09 -524,38 934.68 -288,50 10.53 10.01 -3.46 07-JUN-98 MWD 3841,99 77.05 220.24 47,23 3187.42 -478.80 899.89 -317,94 9,23 9.23 -0.02 07-JUN-98 MWD 3889.74 81.20 220.90 4'~,75 3196.42 -431.92 864.28 -348.44 8.80 8.69 1.38 07-JUN-98 MWD 3930.59 85,12 2::)1,37 40.85 3201,29 -391.37 833,74 -375.11 9.66 9.60 1.15 12-JUN-98 MWD 3999.99 87.10 220.36 69,40 3206.00 -322.14 781.38 -420.41 3.20 2,85 -1.46 8' M1C 1.6 DEG AKO _ -- 12-JUN-98 MWD 4040.42 86.53 221.1 4 40,43 3208.24 -281.77 750.80 -446.76 2,39 -1.41 1.93 12-JUN-98 MWD 4072.50 87.78 221.66 32,08 3209.84 -249.74 726.76 -467.95 4.22 3.90 1.62 ___ 12-JUN-98 MWD 4110.10 90,09 219,13 37.60 3210.53 -212.15 698.14 -492.31 9.11 6.14 -6.73 12-JUN-98 MWD 4142,14 90.72 218.37 32.04 3210.31 -180.12 673.15 -512.36 3.08 1.97 -2,37 i i i i iii i i i " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-08229 Sidetrack No. Page 4 of 5 Company ._A_..R_~_O___A_L/~_S___~__,..!~.C- ........................................... Rig Contractor & No. Parker Drilllng Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD ,, i i ! i ii ii i ii i Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB J~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m[-] 10m~ Vert. Sec. Azim. 220.43 Magn. to Map Corr. 27.630 Map North to: OTHER .....SU RVEY 'DATi ........... .,, Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment · Type (FI') (DD) (OD) (FT) (FT) (FT) (FT) (Per lO0 FT) Drop (-) Left (-) 12-J UN-98 MWD 4174.01 90,12 217.92 31.87 3210,07 -148.28 648,09 -532.05 2,35 -1.88 -1,41 12-JU N-98 MWD 4204.74 89.83 216.87 30.73 3210.09 -117,60 623.67 -550.71 3.54 -0.94 -3.42 ......... 12-JUN-98 MWD 4235.92' 91,26 215.85 31,18 3209.79 -86.50 598.57 -569,19 5.63 4,59 -3,27 ............ 13-JU N-98 MWD 4267.76 93.71 215,83 31,84 3208,41 -54.79 572.78 -587,82 7,70 7.69 -0,06 13-JUN-98 MWD 4299,75 95,42 215.18 31,99 3205.86 -23,02 546.82 -606.34 5.72 5.35 -2.03 ....... 13-J UN-98 MWD 4330,59 97.27 213.95 30,84 3202.46 7,47 521.58 -623,72 7.19 6,00 -3.99 - 13-JUN-98 MWD 4361.93 98.94 211.96 31.34 3198,04 38.23 495.55 -640,60 8,24 5.33 -6.35 ........ 13-J U N-98 MWD 4393.69 98.57 210.45 31,76 3193.20 69.21 468,70 -656,86 4,84 -1.1 6 -4.75 13-JU N-98 MWD 4426.35 96.11 209,00 32.66 3189,03 101.04 440.58 -672.92 8.72 -7.53 -4,44 13-JUN-98 MWD 445~.41 94.09 210.41 26.06 3186.71 126.54 418.03 -685.78 9,44 -7,75 5,41 13-JUN-98 MWD 4485.03 92,09 210.14 32.62 3184.96 158.60 389.90 -702,21 6,19 -6.13 -0,83 ,. 13-JUN-98 MWD 4519.87 90.82 207.15 34.84 3184.07 192,69 359.34 -718.90 9.32 -3,65 -8.58 _ 13-J U N-98 MWD 4550.27 89.16 208.74 30.40 3184.08 222.37 332.49 -733.14 7.56 -5.46 5.23 13-J UN-98 MWD 4581.41 87.67 208.08 31,14 3184.94 252.81 305.11 -747.95 5.23 -4.78 -2.12 ... 13-J U N-98 MWD 4612.08 88.34 207.62 30.67 3186.00 282.73 278.01 -762,27 2,65 2.18 -1,50 13-J U N-98 MWD 4645.31 90.19 206,76 33,23 3186.43 315.07 248.46 -777.46 6.14 5.57 -2.59 ., 13-J UN-98 MWD 4671,26 90.02 206,07 25.95 3186.38 340.25 225.22 -789.00 2.74 -0.66 ~2.66 ., ... 13-JUN-98 MWD 4702.03 88.47 207.15 30.77 3186.79 370.12 197,71 -802.78 6.14 -5,04 3.51 ,. 13-J U N-98 MWD 4733.95 88.41 207.27 31,92 3187.66 401.18 169.33 -817,37 0,42 -0,19 0.38 13-JUN-98 MWD 4765,50 88.00 207.17 31.55 3188,65 431.88 141.29 -831,79 1.34 -1,30 -0,32 .= 13-J U N-98 MWD 4798.21 88.20 207.41 32.71 3189.73 463.72 112,24 -846.78 0,95 0.61 0.73 13-JUN-98 MWD 4826.89 88.06 206.68 28.68 3190.67 491.61 86.71 -859.82 2.59 -0.49 -2.55 13*JUN-98 MWD 4859.57 89.16 206,50 32.68 3191.46 523.33 57.49 -874.44 3.41 3.37 -0,55 13-J U N-98 MWD 4890.74 89.18 206.24 31.17 3191.91 553.56 29.57 -888.28 0.84 0.06 -0.83 · i iii i i i ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98229 Sidetrack No. Page 5 of 5 I [ll['r~l-; [-:~-'~- Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1H/UGNU-01 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD/A.HARSTAD jrN'r~l~ ....... WELL DATA ........ TVD (FT) Target Coord. N/S Slot Coord. N/S -469.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Target Description Target Coord. E/W Slot Coord. E/W -804.00 Magn. Declination 27.630 Calculation Method MINIMUM CURVATURE Target Direction (DD) __ Build\Walk\DL per: 100ft[~ 30m0 10m~ reft, Sec. Azim. 220.43 Magn. to Map Corr. 27,630 Map North to: OTHER .............. SURVEY DATA .......... ,, Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+)'/S(-) .... E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (PO) (FT) (1~. (F'r) (FT) (Per l00 ET) Drop (-) _Left (-) 13-JUN-98 MWD 4924.35 89,10 206.39 33,61 3192.41 586.15 -0.56 -903.18 0.51 -0.24 0.45 13-JUN-98 MWD 4953.94 88.34 207.48 29.59 3193.08 614.92 -26.93 -916.58 4.49 -2.57 3.68 13-JUN-98 MWD 4985.90 88.13 207.95 31.96 3194.06 646.08 -55.21 -931,44 1,61 -0.66 1.47 13-JU N-98 MWD 5019.98 89.04 208.46 34.08 3194.90 679.38 -85.23 -947.54 3.06 2.67 1.50 13-JUN-98 MWD 5050.32 89.29 208.46 30.34 3195.34 709.05 -111.90 -962.00 0.82 0.82 0.00 13-JUN-98 MWD 5082.87 88.95 209.41 32.55 3195,84 740.95 -140.39 -977.74 3.10 -1.04 2.92 13-JUN-98 MWD 5112.12 89.22 209.31 29.25 3196.31 769.65 -165.88 -992.08 0.98 0.92 -0.34 13-JUN-98 MWD 5143.21 89.50 208.73 31.09 3196,66 800.12 -193.06 -1007.16 2.07 0.90 -1.87 ...... 13-J UN-98 MWD 5177.00 89.37 209.37 33.79 3196.99 833.25 -222.60 -1023.57 1.93 -0.38 1.89 ..... 13-JUN-98 MWD 5212.43 88.34 208.95 35.43 3197,70 867.98 -253.53 -1040.83 3.14 -2,91 -1.19 13-JUN-98 MWD 5242.79 87.12 209.18 30.36 3198.90 897.73 -280.05 -1055.57 4.09 -4.02 0.76 -- 13-J UN-98 MWD 5273.29 87.39 209.05 30.50 3200.36 927.60 -306.66 -1070,39 0.98 0.89 -0.43 13-JUN-98 MWD 5305.25 89.90 209.12 31.96 3201.12 958.92 -334.58 -1085.92 7.86 7.85 0.22 .... ,, 13-JUN-98 MWD 5335.60 91.11 209.85 30,35 3200.85 988.72 -361.00 -1100.86 4.66 3.99 2.41 13-J UN-98 MWD 5367.66 91.33 210.02 32.06 3200.17 1020.24 -388.78 -1116.85 0.87 0.69 0.53 13-JU N-98 MWD 5398.96 90.87 207.54 31.30 3199.57 1050.88 -416.20 -1131.92 8,06 -1.47 -7.92 13-JU N-98 MWD 5432.13 90.54 207.90 33.17 3199.16 1083.24 -445.56 -1147.34 1.47 -0.99 1.09 13-JU N-98 MWD 5448.77 90.39 209.24 16.64 3199.02 1099.52 -460.18 -1155.30 8.10 -0.90 8.05 13-JUN-98 MWD 5511.00 90.38 209.24 62.23 3198.61 1160.57 -514.48 -1185.70 0.02 -0.02 0.00 Projected Data - NO SURVEY -- ___ i i i i i ii i ii i1~1 Kuparuk Unit Kuparuk 1H 1H-Ugnu-01 S UR VEY REPORT 8 July, 1998 Your Reft API-500292288700 Last Survey Date 13.June.98 Job# AKMMS0248 KBE- 95.0' DRILLING SERVICES ORtGI, NAL RECEIVED JUN ? 2 1'::)98 Oil & Gm'~. Commi,~ion Anchorage Survey Ref: svy36 Sperry-Sun Drifting Services Survey Report for 1H-Ugnu-O1 Your Ref: API-500292288700 Kuparuk Unit Measured Depth (ft) Incl, 0.00 121.00 196.78 282.78 372.77 456.31 553.06 645.17 731.36 826.74 916.68 1 OO6.O7 1096.77 1186.82 1282.35 1377.36 1471.36 1565.35 1663.14 1757.23 1853.23 1948.50 2043.72 2139.38 2235.80 2329.85 2429.98 2461.01 2493.O5 2524.05 0.000 0.000 0.820 1.960 3.800 5.810 9.210 14.830 19.430 22.970 25.490 29.470 32.310 35.290 37.800 38.820 39.160 39.950 40.110 40.850 39.110 39.110 39.450 39.910 38.490 36.920 36.750 35.850 35.17O 33.100 Azim, 0.000 0.000 54.620 347.760 355.690 3.240 7.350 6.130 5.500 7.750 11.380 12.350 11.030 11.830 10.610 10.320 9.640 7.910 8.330 8.100 6.160 5.370 7.610 7.300 8.480 7.920 7.700 9.160 8.270 7.070 Sub-Sea Depth (ft) -95.00 26.00 101.78 187.75 277.63 360.87 456.78 546.83 629.18 718.09 800.10 879.39 957.22 1032.04 1108.78 1183.33 1256.40 1328.87 1403.75 1475.31 1548.87 1622.80 1696.51 1770.13 1844.85 1919.26 1999.40 2024.41 2050.49 2076.14 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) -95.00 263.01 N 346.77 E 26.00 263.01 N 346.77 E 101.78 263.32 N 347.22 E 187.75 265.12 N 347.41 E 277.63 269.59 N 346.86 E 360.87 276.58 N 346.89 E 456.78 289.15 N 348.15 E 546.83 308.20 N 350.36 E 629.18 333.45 N 352.91 E 718.09 367.69 N 356.94 E 800.10 404.06 N 363.12 E 879.39 444.41 N 371.62 E 957.22 490.01 N 381.03 E 1032.04 539.10 N 390.97 E 1108.78 594.90 N 402.02 E 1183.33 652.81 N 412.71 E 1256.40 711.06 N 422.96 E 1328.87 770.21 N 432.08 E 1403.75 832.48 N 440.96 E 1475.31 892.93 N 449.68 E 1548.87 954.13 N 457.35 E 1622.80 1013.92 N 463.39 E 1696.51 1073.81 N 470.20 E 1770.13 1134.37 N 478.12 E 1844.85 1194.73 N 486.47 E 1919.26 1251.66 N 494.68 E 1999.40 1311.14 N 502.83 E 2024.41 1329.31 N 505.52 E 2050.49 1347.70 N 508.34 E 2076.14 1364.94 N 510.67 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 5980234.12 N 549542.20 E 0.00 5980234.12 N 549542.20 E 0.000 0.00 5980234.44 N 549542.64 E 1.082 -0.53 5980236.23 N 549542.82 E 2.096 -2.01 5980240.71 N 549542.24 E 2.087 -5.07 5980247.69 N 549542.22 E 2.517 -10.40 5980260.27 N 549543.41 E 3.556 -20.79 5980279.33 N 549545.48 E 6.107 -36.72 5980304.60 N 549547.87 E 5.341 -57.60 5980338.87 N 549551.68 E 3.808 -86.28 5980375.28 N 549557.62 E 3.254 -117.97 5980415.68 N 549565.86 E 4.480 -154.20 5980461.34 N 549574.97 E 3.219 -195.02 5980510.50 N 549584.58 E 3.346 -238.83 5980566.36 N 549595.26 E 2.735 -288.47 5980624.35 N 549605.57 E 1.090 -339.49 5980682.66 N 549615.44 E 0.581 -390.47 5980741.87 N 549624.17 E 1.442 -441.41 5980804.20 N 549632.64 E 0.321 -494.57 5980864.71 N 549640.97 E 0.802 -546.25 5980925.95 N 549648.24 E 2.229 -597.81 5980985.78 N 549653.88 E 0.523 -647.24 5981045.72 N 549660.30 E 1.531 -697.25 5981106.33 N 549667.82 E 0.523 -748.48 5981166.74 N 549675.78 E 1.663 -799.85 5981223.73 N 549683.61 E 1.709 -848.51 5981283.25 N 549691.37 E 0.215 -899.07 5981301.44 N 549693.94 E 4.021 -914.64 5981319.85 N 549696.64 E 2.666 -930.48 5981337.10 N 549698.86 E 7.022 -945.11 Comment Kuparuk 1 H Continued... 8 July, 1998 - 14:22 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1H-Ugnu-01 Your Ref: API-500292288700 Kuparuk Unit Measured Depth (ft) Incl, 2556.18 2587.41 2618.22 2649.25 2681.28 2712.39 2744.52 2775.84 2807.18 2839.40 2871.55 2902.30 2934.55 2966.81 2998.93 3030.91 3063.01 3093.10 3125.03 3157.08 3189.01 3220.44 3251.81 3283.92 3316.26 3347.47 3379.05 3486.05 3557.72 3604.37 31.150 29.590 28.320 27.360 25.890 23.640 21.010 19.350 18.330 18.040 17.700 17.170 18.490 20.230 22.110 23.970 25.400 26.740 28.420 29.740 31.330 32.330 33.330 34.590 35.770 38.670 40.750 42.760 49.670 54.010 5.270 3.040 0.530 356.230 353.190 348.870 344.220 337.720 329.590 321.070 312.680 303.490 295.760 288.330 281.230 274.600 269.210 263.000 256.910 251.210 245.370 240.3OO 234.280 229.750 225.750 224.310 223.240 223.700 224.150 223.170 Sub-Sea Depth (ft) 2103.35 2130.30 2157.26 2184.70 2213.33 2241.58 2271.30 2300.70 2330.37 2360.99 2391.59 242O.93 2451.64 2482.08 2512.03 2541.47 2570.64 2597.67 2625.97 2653.99 2681.50 2708.20 2734.57 2761.21 2787.64 2812.49 2836.79 2916.61 2966.17 2994.99 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2103.35 2130.30 2157.26 2184.70 2213.33 2241.58 2271.30 2300.70 2330.37 236O.99 2391.59 2420.93 2451.64 2482.08 2512.03 2541.47 2570.64 2597.67 2625.97 2653.99 2681.50 2708.20 2734.57 2761.21 2787.64 2812.49 2836.79 2916.61 2966.17 2994.99 1381.92 N 512.51E 1397.67 N 513.66 E 1412.57 N 514.13 E 1427.05 N 513.73 E 1441.34 N 512.42 E 1454.21N 510.41E 1466.07 N 507.60 E 1476.28 N 504.10 E 1485.33 N 499.64 E 1493.59 N 493.94 E 1500.77 N 487.21E 1506.45 N 479.99 E 1511.30 N 471.41E 1515.27 N 461.51 E 1518.20 N 450.30 E 1519.89 N 437.92 E 1520.32 N 424.54 E 1519.40 N 411.36 E 1516.81 N 396.83 E 1512.52 N 381.87 E 1506.50 N 366.82 E 1498.93 N 352.09 E 1489.74 N 337.80 E 1478.70 N 323.68 E 1466.17 N 309.91 E 1452.82 N 296.56 E 1438.25 N 282.60 E 1386.54N 233.58 E 1349.31 N 197.70 E 1322.77 N 172.40 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 5981354.10 N 549700.59 E 6.760 -959.23 5981369.85 N 549701.63 E 6.162 -971.96 5981384.76 N 549702.01E 5.704 -983.61 5981399.23 N 549701.51 E 7.171 -994.37 5981413.51 N 549700.10 E 6.256 -1004.40 5981426.37 N 549698.01 E 9.277 -1012.89 5981438.21N 549695.12 E 9.854 -1020.10 5981448.40 N 549691.55 E 8.900 -1025.60 5981457.42 N 549687.03 E 8.979 -1029.60 5981465.64 N 549681.28 E 8.294 -1032.18 5981472.78 N 549674.51 E 8.071 -1033.29 5981478.41 N 549667.25 E 9.109 -1032.93 5981483.20 N 549658.64 E 8.395 -1031.06 5981487.11 N 549648.71 E 9.338 -1027.66 5981489.96 N 549637.48 E 9.889 -1022.62 5981491.57 N 549625.09 E 9.975 -1015.88 5981491.91N 549611.70 E 8.304 -1007.53 5981490.91 N 549598.54 E 10.098 -998.29 5981488.22 N 549584.02 E 10.273 -986.89 5981483.83 N 549569.09 E 9.571 -973.92 5981477.72 N 549554.08 E 10.537 -959.59 5981470.05 N 549539.40 E 9.080 -944.27 5981460.77 N 549525.17 E 10.877 -928.01 5981449.63 N 549511.13 E 8.801 -910.44 5981437.01 N 549497.43 E 8.004 -891.97 5981423.58 N 549484.17 E 9.701 -873.16 5981408.92 N 549470.31 E 6.933 -853.02 5981356.89 N 549421.63 E 1.900 -781.86 5981319.42 N 549386.00 E 9.652 -730.25 5981292.71 N 549360.86 E 9.449 -693.64 Comment Kuparuk 1H Continued... 8 July, 1998 - 14:22 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for lH-Ugnu.01 Your Ref: API-500292288700 Kuparuk Unit Measured Depth (ft) Incl. 3652.77 3700.28 3748.00 3794.76 3841.99 3889.74 3930.59 3999.99 4040.42 4072.50 4110.10 4142.14 4174.01 4204.74 4235.92 4267.76 4299.75 4330.59 4361.93 4393.69 4426.35 4452.41 4485.03 4519.87 4550.27 4581.41 4612.08 4645.31 4671.26 4702.03 58.640 63,520 68.010 72.690 77.050 81,200 85.120 87.100 86.530 87.780 90.090 90.720 90.120 89.830 91.260 93.710 95,420 97.270 98.940 98.570 96.110 94,090 92,090 90,820 89.160 87.670 88.340 90.190 90.020 88.470 Azim. 223.450 222.670 221,870 220,250 220.240 220.900 221.370 220.360 221.140 221.660 219.130 218.370 217.920 216.870 215,850 215.830 215.180 213.950 211.960 210.450 209.000 210,410 210.140 207.150 208.740 208.080 207.620 206.760 206.070 207.150 Sub-Sea Depth (ft) 3021.81 3044.78 3O64.37 3080.09 3092.41 3101.42 3106.28 3110.99 3113.24 3114.83 3115.53 3115.30 3115.07 3115.08 3114.79 3113.41 3110.86 3107.45 3103.03 3098.20 3094.03 3091.71 3089.95 3O89.O7 3O89.O7 3089.93 3091.00 3091.43 3091.38 3091.78 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 3021.81 3044.78 3064.37 3080.09 3092.41 3101.42 3106.28 3110.99 3113.24 3114.83 3115.53 3115.30 3115.07 3115.08 3114.79 3113.41 3110.86 3107.45 3103.03 3098.20 3O94.03 3091.71 3089.95 3O89.O7 3089.07 3089.93 3091.00 3091.43 3091.38 3091.78 1293.47 N 144.77 E 1263.09 N 116.40 E 1230.89 N 87.14 E 1197.69 N 58.23 E 1162.90 N 28.79 E 1127.29 N 1.71W 1096.74 N 28.38W 1044.38 N 73.68W 1013.80 N 100.03W 989.76 N 121.21W 961.14 N 145.57W 936.15 N 165.62W 911.08 N 185.31W 886.67 N 203.97W 861.56 N 222.45W 835.78 N 241.07W 809.82 N 259.59W 784.58 N 276.98W 758.54 N 293.85W 731.70 N 310.12W 703.57 N 326.17W 681.02 N 339.03W 652.89 N 355.45W 622.33 N 372.15W 595.48 N 386.39W 568.10 N 401.20W 541.00 N 415.52W 511.44N 430.70W 488.20 N 442.24W 460.69 N 456.02W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 5981263.23 N 549333.44 E 9.578 -653.42 5981232.67 N 549305.26 E 10.371 -611.89 5981200.28 N 549276.21E 9,532 -568.41 5981166.89 N 549247.53 E 10.527 -524.39 5981131.90 N 549218.31E 9.231 -478.81 5981096.09 N 549188.05 E 8.796 -431.93 5981065.37 N 549161.58 E 9.664 -391.38 5981012.71N 549116.63 E 3.201 -322.15 5980981.96 N 549090.48 E 2.387 -281.78 5980957.79 N 549069.45 E 4.219 -249.75 5980929.00 N 549045.28 E 9.110 -212.16 5980903.88 N 549025.39 E 3.081 -180.13 5980878.69 N 549005.88 E 2.353 -148.29 5980854.15 N 548987,37 E 3.545 -117.60 5980828.92 N 548969.06 E 5.633 -86.50 5980803.01N 548950.60 E 7.695 -54.80 5980776.93 N 548932.26 E 5.716 -23.03 5980751.58 N 548915.04 E 7,190 7.46 5980725.44 N 548898.33 E 8.241 38.22 5980698.48 N 548882:25 E 4.841 69.20 5980670.25 N 548866.37 E 8.725 101.03 5980647.62 N 548853.66 E 9.441 126.53 5980619.39 N 548837.43 E 6.187 158.59 5980588.71N 548820.94E 9.321 192.68 5980561.77 N 548806.87 E 7.561 222.36 5980534.29 N 548792.24 E 5.233 252.80 5980507.10 N 548778.10 E 2.649 282.72 5980477.44 N 548763.11E 6.139 315.06 5980454.13 N 548751.72 E 2.738 340.24 5980426.53 N 548738.13 E 6.139 370.11 Comment Kuparuk 1H Continued... 8 July, 1998 - 14:22 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1H-Ugnu-01 Your Ref: API-500292288700 Kuparuk Unit Measured Depth (ft) Incl. 4733.95 4765.50 4798.21 4826.89 4859.57 4890.74 4924.35 4953.94 4985.9O 5019.98 5050.32 5082.87 5112.12 5143.21 5177.00 5212.43 5242.79 5273.29 5305.25 5335.60 5367.66 5398.96 5432.13 5448.77 5511.00 88.410 88.000 88.200 88.080 89.160 89.180 89.100 88.340 88.130 89.040 89.290 88.950 89.220 89.500 89.37O 88.340 87.120 87.39O 89.900 91.110 91.330 90.870 90.540 90.380 90.380 207.270 207.170 207.410 206.680 206.500 206.240 206.390 207.48O 2O7.95O 2O8.46O 2O8.46O 209.410 209.310 208.730 209.370 208.950 209.180 209.050 209.120 209.850 210.020 207.540 207.900 209.240 209.240 Sub-Sea Depth (ft) 3092.65 3O93.64 3O94.73 3095.66 3096.44 3096.90 3097.40 3098.06 3099.04 3099.89 3100.33 3100.83 3101.30 3101.64 3101.98 3102.68 3103.89 3105.35 3106.10 3105.84 3105.15 3104.55 3104.14 3104.01 3103.60 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 3092.65 3093.64 3O94.73 3095.66 3O96.44 3096.90 3O97.4O 3098.06 3099.04 3099.89 3100.33 3100.83 3101.30 3101.64 3101.98 3102.68 3103.89 3105.35 3106.10 3105.84 3105.15 3104.55 3104.14 3104.01 3103.60 432.32 N 470.61W 404.27 N 485.03W 375.22 N 500.02W 349.69 N 513.05W 320.47 N 527.67W 292.55 N 541.51W 262.42 N 556.41W 236.05 N 569.81W 207.77 N 584.66W 177.75 N 600.77W 151.07 N 615.22W 122.59 N 630.97W 97.10 N 645.30W 69.91N 660.38W 40.38 N 676.79W 9.44 N 694.05W 17.07 S 708.78W 43.69 S 723.61W 71.61S 739.13W 98.03 S 754.07W 125.81 S 770.06W 153.23 S 785.13W 182.59 S 800.55W 197.21S 808.51W 251.51S 838.91W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (rt) 5980398.06 N 548723.72 E 0.420 401.18 5980369.92 N 548709.49 E 1.338 431.88 5980340.77 N 548694.69 E 0.955 463.71 5980315.15 N 548681.82 E 2.578 491.60 5980285.84 N 548667.39 E 3.350 523.32 5980257.83 N 548653.74 E 0.837 553.55 5980227.60 N 548639.04 E 0.506 586.15 5980201.14 N 548625.81 E 4.490 614.91 5980172.77 N 548611.14 E 1.610 646.07 5980142.64 N 548595.24 E 3.061 679.37 5980115.87 N 548580.96 E 0.824 709.05 5980087.28 N 548565.40 E 3.100 740.94 5980061.70 N 548551.23 E 0.984 769.64 5980034.42 N 548536.33 E 2.071 800.11 5980004.77 N 548520.12 E 1.933 833.24 5979973.72 N 548503.07 E 3.139 867.98 5979947.11 N 548488.50 E 4.089 897.72 5979920.40 N 548473.86 E 0.982 927.59 5979892.38 N 548458.51 E 7.857 958.92 5979865.86 N 548443.75 E 4.656 988.71 5979837.98 N 548427.94 E 0.867 1020.23 5979810.45 N 548413.06 E 8.057 1050.87 5979780.99 N 548397.82 E 1.472 1083.23 5979766.33 N 548389.96 E 8.110 1099.51 5979711.83 N 548359.92 E 0.000 1160.56 Comment Projected Survey Kuparuk 1H Continued... 8 July, 1998 - 14:22 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1H-Ugnu-01 Your Ref: API-500292288700 Kuparuk Unit Kuparuk 1H All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Structure. Northings and Eastings are relative to Structure. 'i~The Dogleg Severity is in Degrees per 100ft. ..... Vertical Section is from Well and calculated along an Azimuth of 220.430° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5511.00ft., The Bottom Hole Displacement is 1292.50ft., in the Direction of 246.545° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 -95.00 263.01 N 346.77 E Tie-on Survey at surface 5511.00 3103.60 251.51 S 838.91 W Projected Survey 8 July, 1998 - 14:23 - 6 - DrillQuest spenr -sum- mi:IlL-I--lNG S J=: F! U'II- I= c: 13-Jul-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1H-Ugnu-01 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 0.00' MD Window / Kickoff Sun:e,/: 5,511.00' MD Projected Survey: ~*~'" ~ (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED A~k~ 0~ & G~ ¢on~. Oommi~bn k~ch0rage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 8. 1998 ' tot 1H-UGNU-01, AK-~MM-80248 1 LDWG formatted Disc with verification listing. API#: 50-029-22887-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TItE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service At-tn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSMITTAL To: State of Alaska July 22, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1H-UGNU-01, AK-MM-80248 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' _~i Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1H-UGNU-01: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22887-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22887-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, SuiTe G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Max, 21. 1998 Tom McKav Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-Ugnu-01 ARCO Alaska, Inc. Permit No.: 98-101 Sur. Loc.: 469'FNL, 804'FEL, Sec. 33, T12N, R10E. UM Btmhole Loc: 874'FNL, 2153'FEL, Sec. 33, T12N, R10E, UM Dear Mr. McKay: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the B OPE test performed before drilling beloxv the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson Commissioner BY ORDER OF THE COMMISSION dlf/enclosures CC: Department of Fish & Game, Habitat Section xxJo encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~i2,A OIL AND GAS CONSERVATION COMMI~SSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill [~ lb TypeofWell Exploratory [--' StratigraphicTest E Development Oil X Re-Entry ~ Deepen ~' Service ~'; Development Gas [-' SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 280' FSL, 1170' FEL, Sec. 28, T12N, R10E, UM 1H-Ugnu-01 #U-630610 At total depth 9. Approximate spud date Amount 874' FNL, 2153' FEL, Sec. 33, T12N, R10E, UM 5/26/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1H-14 5490' MD 2153 @ TD feet 29' @ 300' feet 2560 3196' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 40.6° Maximum surface 1690 psig At total depth (TVD) 2002 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 94.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 13.5" 10.75" 40.5# J-55 BTC 3933' 41' 41' 3974' 3183' 828 Sx Arcticset III & 60 Sx Class G 9.875" 7" 26.0# L-80 BTC 1666' 3824' 3152' 5490' 3196' Slotted Liner 19. To be completed for Reddll, 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 LPirn°edrU ct'° n DUPLICATE Pedoration depth: measured true vertical 20. Attachments Filing fee X Property plat [~ BOP Sketch X DiverterSketch X Ddlling program X Ddlling fluid program X Time vs depth plot ~ Refraction analysis r'- Seabed report r-~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true .and corr.ecJ~o th .et)est of my knowledge Signed'~"~~ ~/,' .~'~~ Title Drilling Team Leader ~ ~ ' /f \ Commission Use Only Perm.i.t Number I APl number _ ( ~,) I Approval date ~---~ ,, .~¢ ~,~ J See cover letter for ~'~'-//4::~,// I 50- ~ .2---~'~- 2-,~""= ~"~'' ~' I ,..)~O~-[ ~I other requirements Conditions ~f approval Samples required F' Yes ~' No Mud loglrequi~ed F' Yes .~ No Hydrogen sulfidemeasures r'- Yes '~ No Directional survey required ~ Yes [~ No Required working pressure for DOPE I-- 3M E IZ I-- Other:. ORIGINAL SIGNED BY Robert N. Chnstenson byorderof Approved by Commissioner the commission Date . . . Form 10-401 Rev. 7-24-89 mit in triplicate STATE OF ALASKA COMMISSION ALASK~ OIL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill [-' lb TypeofWell Exploratory r' StratigraphicTest [~ Development Oil X Re-Entry r~ Deepen E~ Service E Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 469' FNL, 804' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 280' FSL, 1170' FEL, Sec. 28, T12N, R10E, UM 1H-Ugnu-01 #U-630610 At total depth 9. Approximate spud date Amount 874' FNL, 2153' FEL, Sec. 33, T12N, R10E, UM 5/26/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1H-14 5490' MD 2153 @ TD feet 29' @ 300' feet 2560 3196' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 40.6° Maximum surface 1690 psig At total depth (TVD) 2002 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 94.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 13.5" 10.75" 40.5# J-55 BTC 3933' 41' 41' 3974' 3183' 828 Sx Arcticset III & 60 Sx Class G 9.875" 7" 26.0# L-80 BTC 1666' 3824' 3152' 5490' 3196' Slotted Liner 19. To be completed for Reddll, 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 ~.ru .e_, Vertical depth Structural (~, ~'~ ~ sC Conductor Surface Intermediate Production ).'! ~'' ',/ '~ .".'? ..,,., i.;'.., ::: Perforation depth: measured f~ ~ \ [ [*,~ ' ;.~_~,.~,i~ true vertical 20. Attachments Filing fee X Property plat F~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~' Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true .and corr,ec, t~o th,eft)est of my knowledge ;""~"~- /?Jr/, /i/~,X Title Drillino Team Leader Date S'~'/Z~ CZ Signeo /' ~.,/~ I ! v ' ! ~' ,~ ~ / v ~ ""/ ! ~' ~, Commission Use Only Permit Number I APl number ~ ~/ I Approval date ~-~ ,, ,\r,.~, See I cover letter for I 0-oz¢- I I other requirements Conditions of ~.ppro~/al Samples required F; Yes [~ No Mud Iogtrequi~ed ~' Yes .,~ No Hydrogen sulfidemeasures F~ Yes '~ No Directional surveyrequired ~ Yes ~ No Required working pressure for BOPE ~ 2M E~ aM E~ 5M E 10M [~ 15M Other: Approved by ORIGINAl SIGNFD BY commissioner the commission Date Form 10-401 Rev. 7-24-89 R,{;;)~l't N, Christenson ~. ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor May 12, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill 1H-Ugnu-01 Ugnu Test Well, Kuparuk River Unit Dear Sirs' ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Ugnu interval from 1H Pad in the Kuparuk River Unit ("KRU"). The well is designed to test the production potential of the Ugnu interval in the vicinity of 1H Pad. Completion plans call for setting a horizontal slotted liner through the Ugnu interval and then running a dual completion string consisting of a progressive cavity ESP on 4-1/2" tubing and a 2-7/8" tubing guide string. Sand production is expected in this unconsolidated formation and it is planned to produce this sand through the slotted liner and ESP. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Ugnu sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Ugnu sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 1H-Ugnu-01, such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is May 26, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Thomas A. Brockway Operations Drilling Engineer ,~k~ Attachments: CC: 1H-Ugnu-01 Well File Tom McKay ATO-1202 Larry Gipson ATO-1262 Drew Hembling ATO-1278 Lewis Ledlow ATO-1282 GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD 1H-Ugnu-01 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 10-3/4" surface casing point (+/3974' MD) according to directional plan. 4. Pick up hole opener and open hole to 13-1/2". 5. Run and cement 10-3/4" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and using light weight lead permafrost cement. 6. Install and test BOPE to 3000 psi. Test casing to 2000 psi for 30 min. per AOGCC regulations. 7. Drill out cement and 20' of new hole. Perform formation integrity test, taken to a maximum of 12.5 ppg EMW. 8. Drill 9-7/8" horizontal hole to proposed well TD (+/- 5490' MD) according to directional plan, running LWD logging equipment as needed. 9. Displace well from drill-in fluid to kill weight completion fluid as required. POOH 10. Run 7" slotted liner. Set liner lap a minimum of +/- 150' inside the 10-3/4" surface casing. Set liner top hanger and packer. Circulate well to kill weight completion fluid. 10. ND BOPE. NU production tree. Secure and freeze protect well. Release drilling rig. 11. Move in and rig up Nordic 2 12. ND production tree. NU BOPE and pressure test to 3000 psi. Pull back pressure valve. 13. RIH with scraper assembly and a bit with no jets. RIH to liner top packer. Reverse out if fill is present. 14. Pick up dual completion string. One string will have a Reda ESP pump on 4-1/2" production tubing, the second will be a 2-7/8" production tubing guide string. 15. Run in well with ESP pump string and guide string run in tandem. ESP pump string will have power cable and information wire attached to tubing. 16. Attach heat trace cable to the 4-1/2" tubing at pre-determined depth to position bottom of heat trace below permafrost. Space out heat trace cable to avoid surface splicing. 17. Position ESP and guide string at desired depth, set dual tubing hanger, and run electrical penetrators through same. 18. Make surface electrical connections as required and set back pressure valve in tubing hanger. 19. Nipple down BOPE. Nipple up dual tubinghead, master valve and production tree. 20. Secure well and release rig. 1H-Ugnu-01 TAB,05/12/98, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1H-Ugnu-01 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 10-3/4" Surface Casing 9.0-10.4 20-26 15-25 50-80* 10-15 15-40 7-8 9.5-10 _+10% Surface Casing To TD 9.4-10.4 10-18 15-25 35-45 4-8 6-10 4-5 7.5-8.5 <12% Drillin_q Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1690 psi. The leak off EMW was chosen based on an FIT on 1H-14 taken to 12.5 ppg at 4315' TVD (0.65 psi/fi) and held for 15 minutes. It can be expected that testing in the shallower Ugnu formation will result in lower leakoff values of between 11.5 ppg and 12.0 ppg. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (2860 ft)(0.70 - 0.11) = 1690 psi Based on offset well data, reservoir pressures in the Ugnu sands in the vicinity of 1H pad are expected to be +/- 1300 psi (0.45 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 2860' at the top of the formation. Well Proximity Risks: The nearest existing well to 1H-Ugnu-01 is KRU 1 H-14. As designed, the minimum distance between the two wells would be 29' at 300' MD. 1 H-Ugnu-01 TAB,05/12/98,v.2 Drilling Area Risks: Risks in the 1H-Ugnu-01 drilling area include lost circulation, shallow gas and hydrates below the permafrost, and potential borehole instability in the Ugnu formation. Shallow gas will be controlled by increasing the mud weight while lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 1H drilling results, 9.4 ppg mud should be adequate to control the Ugnu formation pressures without resulting in lost circulation. The 10-3/4" casing shoe will be tested to a maximum equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. ARCO Alaska, Inc. has drilled through the Ugnu formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 ACC 25.033 (e) and 20 ACC 25.601 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of 1H- Ugnu-01. Annular Pumpin_cl Operations: /,J ~)Jr' Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 1H Pad. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1H-Ugnu-01 10-3/4" casing and tubing annuli will be filled with kill weight brine and diesel prior to the drilling rig moving off of the well. 1 H-U gnu-01 TAB,05/12/98,v.2 I v c,,0t,~b,~,~,~ For: T. Brockway oofe plaited ; 5-M~y-98 PIo~ Reference ~s U~nu-01 Version Co~d;notes ore in feet reference slot ~U~nu-01. r~e Vertical Oepths ore reference ~8 (Porker ~245 2OO 200 4OO 600 800 1000 1200 400 1600 1800 2000 220O 2400 2600 28O0 3000 3200 3400 1400 ARCO Alaska, Inc. Structure : Pad 1H Well : Ugnu-01 Field : Kuparuk River Unit Location : North Slope, Alaska 1400 1200 1000 <- West (feet) 800 600 400 200 I I I I 1 I I I RKB ELEVATION: 95" K0P TVD=300 TMD=300 DEP=0 TARGET LOCATION: 280' FSL, 1170' TEL SEC. 28, T12N, RIOE 0.00 KOP 4,00 8.00 12.00 TARGET TVD=3183 TMD=3974 0EP=-333 NORTH 749 WEST 366 Top Ugnu C Sand Begin Tangent Section Begin Final Build Top Ugnu B Sand 0 2O0 & Turn TARGET - Casing Pt Base Permafrost DLS: 4.00 dog per 100 fi, 0 16.00 20.00 24.00 8.00 O0 0 O0 TD LOCATION' EOC TVD=1232 TMD=lS15 DEP=-291 / 40.00 874, FNL 215Y. FELI I SEC. $3, Y12N, RIO~E I AVERAGEANGLE~ TD 7 Slotted Liner 40. 62 D E C ///B/PERMAFROSTTVD=1613 TMD=1817 0EP=-567 SuRFEA~T~MLA;cEADTioN: /~/ I 469' FNL, 804' FEL ........ I SEC. 33, T12N, RIOE 38.15 /BEGIN 0ReP & TURN TVD=2109 TM0=2471 DEP=-926 29.96 ~ 220.43 AZIMUTH 12~2~ ~ -333' (TO TARGET) 13.32 t DLS: 9.00 deB per 100 fl t ***Plane of Propose*** 15.98 ~ 22.19~ 29.81 k ~U U_ C S_.AND__TVD=_2860_TMD_--_3300 OEP=-894 ............ ~~~-O~NU~T~/D'2~2~8-~9 TMD=3324 DEP=-879 'I'AtqL+E'I' Al'qUbE "% BEGIN FINAL BUILD TV0=2956 TM0=3424 DEP=-815 55'861.84~-.~ T/UGNU B SAND TV0=3129 TM0=3715 0EP=584 .... ~nn . ~ .._~TD - CSG PT TVD=3196 OLS' 9 O0 de9 per 100 f~ .... ._~ · ' oz.o'+ ~ TMD=5490 DEP=ll83 TARGET - CSG PT/EOB TVD=3183 TMD=3974 DEP=-333 i i i i i i I I I I I II i I II I I I II I I i I I i i I i 200 i 000 800 600 400 200 0 200 400 600 800 1000 1200 1400 i 600 Verffcal Section (feet) -> Azimuth 220.43 with reference 0.00 N, 0.00 E from slot #Ugnu-01 1400 1200 1000 800 6OO 400 200 20O 400 60O A Z O 300 28O 260 240 22O 200 i80 16O I ~ 1¢0 -i-- 120 0 lO0 Z 8O 6O 4O 2O 2O 4O 6O Cteoted by Wkhoels~n For: T. Brockway Dote protted : 5-Mcy-§8 Plot Reference is U§nu-O1 Version Co~dlnotes ore in ~eet refe~nce slot ~U~nu-01, T~e VeH[col Dapths Ore reference ~8 (PorRer ARCO Alaska, Inc. Sfrucfure : Pad 1H Well : Ugnu-01 Field : Kuporuk River Unif Location : North Slope, Alaska <- Wesf (feel) · Eosf (feel) 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 100 i20 140 60 I I I I I I I I I I I I I I I I I I ~ I I I I I I I I I 3O0 260 / /~2oo A 140 Z j ~oo / o 120 3100 gOO 300 3000 ? 7oo/ ~oo [ ~ 29O0 ; / 1 O0 ] ~ 28oo 2o 400~/27°° ~00 o ~oo gOO 40 i i i i i i i i i i i i i i i i i i i i 60 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 1320 1260 1200 1140 1080 1020 960 Oeo~ed by ~;c~cers~ For: T, Brockway Dote plotted : 5-Mcy-98 Plot Reference is U§nu-01 Version J~lO. Coordinates ore in feet reference slot ~/Ugnu-01. rr~e Vert[ccl Depths ore reference RKB (Parker ARCO Alaska, nc. Structure : Pod 1H Well : Ugnu-01 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 360 300 240 180 120 60 0 60 20 180 240 300 360 420 480 540 I I I I I I I I I I I I I I I I I I I I I I I I I I 5800 5700 2400 5600 3100 5500 2300 3000 5400 2200 2900 · 3OOO./ / / 3100./ ? / 900 2800 ,-'" / '~1 O0 840 780 "~ 720 0 Z 20O0 1900 660 600 540 1800 480 420 360 1700 1600 1500 1400 300 240 ,/ 280~" 2900/ ,,- # / ...... ~2500 270/0./" "~ 2400 o 2300 2200 ¢, 2100 ; i 2000 / ~ 1 900 , ; 1I ¢ 1 soo -,' ~7oo i lSOO ! ~ 1400 1300 200 5500 5800 4OO0 3200 1800 4100 1900 43OO 3500 4400 O0 I I I I I I I I i I i i I I I I I I I I 560 300 240 180 120 60 0 60 120 180 240 300 360 420 480 540 East (feet) -> 1320 1260 1200 1140 1080 1020 96O 900 840 0 78O 720 660 600 540 48O 420 360 300 24O A CO Alaska, Inc. Structure: Pad 1H Well : Ugnu-01 Field : Kuparuk River Unit Location : North Slope, Alaska c~ted w ~c~e,o~ For: T. Brockway Dote p~otted: 5-k~oy-98 Plot Reference is Ugnu-01 Version ~10. Ceord;notes ore ~n feet reference slot ~U§nu-01. rru¢ Vcrtio31 Oepths ere reference RKB (Perker ~245 110o 1000 9OO 800 70O 600 500 400 300 200 100 1 O0 200 300 400 5OO <- West (feet) 1500 1400 1500 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 f I I I I I I I I I I I I I I I I I I I t I I I I t I I I 600 \ ~ soooIP/ 5oo 3600 .ff,,.////,,,~ 0 0 440C 1600 3400 3200 ../'"'/ 160 )0 3000 ,,//'" ~ 4200 '1400 ~ 2800 /'" ~ 4000 1200 - .,' 1400~ ,,,,,,, 2400 1200k 500 8OO 22OO ..." 1004 600 " 20OO /' " 1800 ,1200 1600 1400 2200 1400 2400 1200 26O0 1100 1000 9O0 800 7O0 600 500 400 I z 0 200 ('D 3200 100 100 20o 400 1000 8O0 300 1200 1aa0 340( 2800 I I I I I I I I I I I I I t I I I I I I I I I I I I I 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 <- West (feet) 400 5OO A~CO Alaska, Inc. Pad 1H Ugnu-01 slot #U~nu-01 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : Ugnu-01 Version #10 Our ref : prop2896 License : Date printed : 5-May-98 Date created : 20-Mar-98 Last revised : 5-May-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 21 29.028,w149 35 28.07 Slot location is nT0 21 24.415,w149 35 51.574 Slot Grid coordinates are N 5980233.800, E 549540.918 Slot local coordinates are 469.00 S 804.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARJ%NCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath GMS <0-6750'>,,6,Pad 1H PGMS <0-8086'>,,4,Pad 1H GMS <0-8740'>,,8,Pad 1H GMS <0-8155'>,,3,Pad 1H GMS <0-8300'>,,7,Pad 1K PGMS <0-10332'>,,15,Pad 1H PGMS <0-10172'>,,12,Pad 1H PGMS <0-9774'>,,il,Pad 1H PGMS <0-11653'>,,9,Pad 1K PGMS <0-11172'>,,13,Pad 1H PGMS <0-7880'>,,1,Pad 1K PGMS <0-10300'>,,20,Pad 1H PGMS <0-8455'>,,17,Pad 1H PGMS <0-7510'>,,16,Pad 1H MSS <0-10840'>,,5,Pad 1H PGMS <0-8990'>,,19,Pad 1H PGMS <0-8670'>,,18,Pad 1H PGMS <0-8090'>,,2,Pad iH PGMS <0-8315'>,,21,Pad 1H PGMS <0-7561'>,,10,Pad 1H PGMS <0-10228'>,,14,Pad 1H PGMS <0-7440'>,,22,Pad 1H Closest approach with 3-D Minimum Distance method Last revised Distance 21-Aug-91 177.7 8- Jan- 93 21-Aug- 91 21 -Aug- 91 21-Aug-91 17 -May- 93 17 -May- 93 17 -May- 93 17 -May- 93 24 -Jun- 93 5 -May- 93 18-Feb-93 22-Feb-93 17 -May- 93 21 -Aug- 91 18-Feb- 93 17 -May- 93 17 -May- 93 24 -Ju~- 93 17 -May- 93 24-Jtln- 93 23-Jun- 93 554 2 417 8 270 7 298 0 419 0 90 1 118 8 269.3 240.1 435.4 368.1 222.7 404.8 59.0 372.9 330.1 452.6 210.3 149.7 29.0 381.8 M.D. Diverging from M.D. 300.0 4500.0 300.0 5100.0 300.0 5489.6 4900.0 4900.0 300.0 3840.0 300.0 4500.0 0.0 0.0 300.0 4400.0 200.0 4300.0 200.0 4100.0 0.0 5000.0 600.0 2940.0 3660.0 3660.0 325.0 4600.0 300.0 300.0 300.0 4100.0 300.0 4500.0 0.0 4900.0 0.0 4200.0 300.0 4400.0 300.0 4100.0 0.0 4700.0 2-7/8" Guide String 20" Conductor Casing 1H-Ugnu-01 Wellbore Schematic Heat Trace 4-1/2" Production Tubing with ESP Power Cable 10-3/4" Surface/Production Casing Progressive Cavity ESP w/Wireline & CT Retrievable Pump 7" Slotted Liner w/0.02" Slots 2-7/8" Slotted Tubing TAB, 5/12/98, v.2 J ' Tg 20 21 2 5. COORDINATES SHOWN ARE A $ P ZONE 4 N.A D. 27. . . . , . %,, 34 4. LOCATED WITHIN PROTRACTED SECTION $$. TWP. /2 N.. ~_~ / ~SLR~Y ROE. I0 E., UMIAT MERIDIAN, ALASKA. ~ ~ ~ , 5. DATE OF SURVEY IS APRIL 25, 1998. ~CINITY MAP SC~ 1"= 2 28~ 7 ~T~F ~ ~ j uSNU- ~ 20. ~ .5 17o 06 ~ 16o j 2' 7118 ~ LEGEND 4' [[ 0 NEW CONDUCTOR LOCATION b SECTION 33, TO~SH'IP 12 NONTH, RANGE !0 EAST ~o. Y x ~ ~ / ~uo~ o / ~. ~o. ~s~. o ~. ~. s ~o~ 2, z~. ~z REvl BY CK DATE DESCRIPTION ~ LOUNSBURY CI~ a AssOCiAteS, ~c. ~ DRILL SI~ 1-H A CO Alaska, Ino. u uu-o Subsidiory of Atlontic ~ichfield Compony ~S-SIAK[D CADD FILE NO. ] ~ DRAWING NO:I PAOE: iREv: LK650D4 4/27/98NSK 6.50-d4 ~og ~ 0 ....~;UPARUK R!VER Ufi~ 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER --AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPEFIATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. 2 ARCO ALASKA. INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSi BALL VALVE. 4. 20' - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 6 5 4 2 13 5/8" -5000BOP STACK ACCUMUI. ATOR CAPACITY T~;T 1. CHECK AND FILL ACCUMULATOR.RESERVOIR TO PROPER LEVEL WITH HYDRAUEC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS - ARE CLOSED WITH CHARGING PUMP OFF. 4.RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER lIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PS! AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 51:X)0 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TESTTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. LINES, AND CHOKES WITH A250 PSI LOWAND 5000 PSI HIGH. TESTAS IN STEP 4. OD NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PS! FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE, CLOSE BUND RAMS AND TESTTOS000 PS! FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 17_ TEST KELLY COCKS AND INSIDE BOP TO 5000 PS! WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PS! STARTING HEAD ?- 11' - 3000 PS! CASING HEAD 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SP(:X~L 4. 13-5/8' - 5000 PSI VARIABLE PIPE I:::LAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TESTAND THE PRIOR ONE WILL BE TESTED TO 250 PS! LOW AND 5000 PSI HIGH GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD 1H-Ugnu-01 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 10-3/4" surface casing point (+/3974' MD) according to directional plan. 4. Pick up hole opener and open hole to 13-1/2". 5. Run and cement 10-3/4" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and using light weight lead permafrost cement. 6. Install and test BOPE to 3000 psi. Test casing to 2000 psi for 30 min. per AOGCC regulations. 7. Drill out cement and 20' of new hole. Perform formation integrity test, taken to a maximum of 12.5 ppg EMW. 8. Drill 9-7/8" horizontal hole to proposed well TD (+/- 5490' MD) according to directional plan, running LWD logging equipment as needed. 9. Displace well from drill-in fluid to kill weight completion fluid as required. POOH 10. Run 7" slotted liner. Set liner lap a minimum of +/- 150' inside the 10-3/4" surface casing. Set liner top hanger and packer. Circulate well to kill weight completion fluid. 10. ND BOPE. NU production tree. Secure and freeze protect well. Release drilling rig. 11. Move in and rig up Nordic 2 12. ND production tree. NU BOPE and pressure test to 3000 psi. Pull back pressure valve. 13. RIH with scraper assembly and a bit with no jets. RIH to liner top packer. Reverse out if fill is present. 14. Pick up dual completion string. One string will have a Reda ESP pump on 4-1/2" production tubing, the second will be a 2-7/8" production tubing guide string. 15. Run in well with ESP pump string and guide string run in tandem. ESP pump string will have power cable and information wire attached to tubing. 16. Attach heat trace cable to the 4-1/2" tubing at pre-determined depth to position bottom of heat trace below permafrost. Space out heat trace cable to avoid surface splicing. 17. Position ESP and guide string at desired depth, set dual tubing hanger, and run electrical penetrators through same. 18. Make surface electrical connections as required and set back pressure valve in tubing hanger. 19. Nipple down BOPE. Nipple up dual tubinghead, master valve and production tree. 20. Secure well and release rig. 1H-Ugnu-01 TAB,05/12/98, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1H-Ugnu-01 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 10-3/4" Surface Casin~ 9.0-10.4 20-26 15-25 50-80* 10-15 15-40 7-8 9.5-10 _+10% Surface Casing To TD 9.4-10.4 10-18 15-25 35-45 4-8 6-10 4-5 7.5-8.5 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1690 psi. The leak off EMW was chosen based on an FIT on 1H-14 taken to 12.5 ppg at 4315' TVD (0.65 psi/ft) and held for 15 minutes. It can be expected that testing in the shallower Ugnu formation will result in lower leakoff values of between 11.5 ppg and 12.0 ppg. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (2860 ft)(0.70 - 0.11) = 1690 psi Based on offset well data, reservoir pressures in the Ugnu sands in the vicinity of 1H pad are expected to be +/- 1300 psi (0.45 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 2860' at the top of the formation. Well Proximity Risks: The nearest existing well to 1H-Ugnu-01 is KRU 1 H-14. As designed, the minimum distance between the two wells would be 29' at 300' MD. 1 H-U gnu-01 TAB,05/12/98,v.2 Drillin,cl Area Risks: Risks in the 1H-Ugnu-01 drilling area include lost circulation, shallow gas and hydrates below the permafrost, and potential borehole instability in the Ugnu formation. Shallow gas will be controlled by increasing the mud weight while lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 1H drilling results, 9.4 ppg mud should be adequate to control the Ugnu formation pressures without resulting in lost circulation. The 10-3/4" casing shoe will be tested to a maximum equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. ARCO Alaska, Inc. has drilled through the Ugnu formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 ACC 25.033 (e) and 20 ACC 25.601 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of 1H- Ugnu-01. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 1H Pad. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1H-Ugnu-01 10-3/4" casing and tubing annuli will be filled with kill weight brine and diesel prior to the drilling rig moving off of the well. 1H-U gn u-01 TAB,05/12/98,v.2 I ¢~,o,.~ ~, ~, .... For: T. Brockway Date olatted: 5-Uay-98 Plot Reference is U~nu-01 Version ~10. Ca~dinales ore in ~eet reference slot jUgnu--01. Tree Vertical OepLhS are reference ~B (Perker ,ARCO Alaska, Inc.! Structure : Pod 1H Well : Ugnu-O1 I Field : Kuporuk River Unif Locofion: North $1ope, Alosko <- West (feet) 400 1200 '.' 000 800 600 400 200 0 I I ~ ~ I I I I I i ! I I I 200 I 1400 -3 2OO 200 400 6OO 8OO 1000 1200 1400 1600 i800 2000 22OO 2400 2600 2800 3000 3200 3400 t I Top Ugnu C Sand TARGET LOCATION: Begin Tangent Section 280' FSL, !170' FEL Begin Final Build SEC. 28, Ti2N, R1OE RKB ELEVATION: 95' & Turn TARGET Top Ugnu B Sand 0.00 TVD=3185 TMD=3974 DEP=-333 NORTH 749 TARGET - Casing Pt KOP TVD:300 TMD:300 DEP:0 KOP WEST 365 Base Permafrost 4.00 ~ 8.00 12.00 DLS: 4.00 deg per 100 ft ~6,oo 4 ~~ / EGG o.oo 40 aa [- ~o~& o · ] EOC WD=1232 TMD=1315 DEP=-291__ / ~ 874' FNL 2153"F~-L AVERAGE ANGLE~ 40.62 DEG ¢B/PERUA[ROSTTVD:1613 TMD=la17 DEP:-=,67 ' ESTIMATED SURFACE LOCATION: , 469' FNL, 804' FEL .1 ] SEC. 33, T12N, RIOE ~ 29,96 320.43 AZIMUTH ~6.o8 -333' TO TARGET i I ***Plane of Proposal*** 13.32 DLS: 9.O0 deg per 100 ft · ~7.99'X_ T/UGNU C SAND TVD=2860 TMD=3300 0EP=-894 ] ..... %x flEGIN TANGENT SECTION WD:287§ TMD=Z324 DEP=-879 TARGET ANGLE J 'X. BEGIN FINAL BUILD 1~,D:2958 TMD=3424 DEP:-815 , ~.8,~% 89.51 DEG 55.84 I -"'-~ ~ ~ TD - CSG PT TVD=3196 -I DLS: 9.00 deg per 100 ft 82.84--~ --~ TMD=5490 DEP=1183 ~ TARGET - CSG PT/EOB TVD=3183 J TMD:3974 DEP=-333 1400 1200 i 000 800 600 400 200 0 200 400 600 800 1000 1200 ! 400 1600 Vertical Section (feet) -> Azimuth 220.43 with reference 0.00 N, 0.00 E from slot #Ugnu-01 1200 lOO0 8OO 600 400 2OO 2OO 400 6OO Z O c,..., w .~..~.~ For: T. Brockway Date platted : 5-tday-g8 Plot Reference is Ugnu-01 Version Co~di~tes ore in feet refe~nce slot ~Ugnu-01. T~e Ve~t[col Depths ore reference ~D (Porker 300 280 26O 240 22O 200 180 ARCO Alaska, Inc. 160 140 120 lOO ~ I ! 8O Structure : Pod iH Well : Ugnu-01 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) · Eosf (feet) -> 60 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 ! 1100 lOOO ~ 900 ! ! , ~ 800 , i7oo 2900 ! 600 i / 28o0 5oo¢ 400(~ 2700 3300 2500 32OO O0 300 3OOO ~_oo lOO o0o 28O 26O 240 220 200 180 160 140 12o 1 O0 8O 6O 4O 2O 2° I , , } 60 60 I i , i , i , i , i i [ i i i 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 I O0 120 140 160 <- West (feet)' East (feet)-> A Z 0 1520 1260 1200 1140 1080 1020 96O gOO 840 ,+_ 780 '~ 720 0 z 660 60O 540 480 420 360 300 24O o,~*.~ ~ s~,ce,.~For: T. Brockway oate platted : 5-l~y-98 PlOt Reference is Uqnu-01 Version ~10, Ca~di~tes or~ in Ce~ ~fe~nce llOt ~nu-01. IT~e Ve~icel Oepths~~ ~B (Porker ~245). ARCO Alaska, ....... Inc.[ Sfrucfure: Pod 1H Well : Ugnu-01 Field : Kuporul< River Unit Location : North Slope, Aloskol East (feet) -> if i 5800 360 300 240 180 120 60 0 60 120 180 240 300 360 420 480 540 I I I ~ I i I I I I I I I I I I I t 57OO 5600 3100 5500 5000 5400 2900 2800 240O ....... .. 2500 2700./' "~ 2400 280~"' ~ 2300 2900.,/ 12200 2500 / ,/ 3000./ · · · · // 2200 ,,," 3100/ ,/ ,, /- I ~ I I I o 4300 '~'1 O0 2OOO 1900 1800 1700 1600 1500 1400 L I i i i 360 300 2,I, 0 i 80 ! 20 60 0 60 120 180 240 300 360 420 480 540 East (fee'l') -> 1320 1260 1200 1140 i 2100 / ¢ ~ ~oo I ~37 O0 / ~600 ( /100 420 /1500 / , k300 ~oo / I '~l 1080 1020 /X I Z o AI CO Alaska, Inc.[ Structure : Pod 1H Well : Ugnu-01 Alaska Field : Kuporuk River Unit Location : North Slope, c**~,,d ~ ,~ For: T. Brockway O~te pW~ted: 5-Moy-98 ~[ot Ref~ence is Oqnu-OI Ve~slo~ Ca~inates a~ in fe~ ref~nce ~o[ ~nu-01. T~e Vertical Oe~s are ref~ence ~8 (Park~ J245). <- West (feet) 1500 1400 1500 1200 1100 1000 900 800 700 600 500 4-00 500 200 100 0 I I I I I I I I I I I I I f I I I ~ I I I I I I I t I I I I I ,.'~ooo 11oo ~ 3ooo / ,,' 54oo~ / ,," 1000 J[ / 2200 ,,,,' 1000 aoo 5ooo~,, soo 700 700 0 '/ 600 5600 '""~0 400 /" 400 44( 1600 ~oo 300 q 300 3200 4200 ..'"' 1600~ 1400 200 3000 200 100 2800,, ,,'"' 1400~ 1200 100 / · 2400 1200~X, 500 0 8OO '"' 2200 ,," 100[ 600 / ,' 2000 100 ." 1200 100 ,,,," 1800 · 1600 1400 ,." 2200 / 200 1400 2400 200 ,,' / 1200 2600 40O ,, 1000 800 300 300 /' " 1000 ,/ · / " 4O0 400 [~_-zr. 31g6 2800 1200 3200 340( 500 500 I t I ~ i i i [ [ I ~ I I I I I ] I I I I I I 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 <- West (feet) ARCO Alaska, Inc. Pad 1H Ugnu-01 slot #Ugnu-01 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : Ugnu-01 Version #10 Our ref : prop2896 License : Date printed : 5-May-98 Date created : 20-Mar-98 Last revised : 5-May-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 21 29.028,w149 35 28.07 Slot location is nT0 21 24.415,w149 35 51.574 Slot Grid coordinates are N 5980233.800, E 549540.918 Slot local coordinates are 469.00 S 804.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEA2Ju~CES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath GMS <0-6750'>,,6,Pad 1H PGMS <0-8086'>,,4,Pad 1K GMS <0-8740'>,,8,Pad 1H GMS ¢0-8155'>,,3,Pad 1H GMS <0-8300'>,,7,Pad 1H PGMS <O-10332'>,,15,Pad 1H PGMS <O-10172'>,,12,Pad iH PGMS <0-9774'>,,Il,Pad IH PGMS <0-11653'>,,9,Pad 1H PGMS <0-11172'>,,13,Pad 1H PGMS <O-7880'>,,1,Pad 1H PGMS <0-10300'>,,20,Pad IH PGMS <O-8455'>,,17,Pad 1H PGMS <0-7510'>,,16,Pad 1H MSS <0-10840'>,,5,Pad 1H PGMS <O-8990'>,,19,Pad 1H PGMS <0-8670'>,,18,Pad 1H PGMS <O-8090'>,,2,Pad 1K PGMS <0-8315'>,,21,Pad 1H PGMS <O-7561'>,,lO,Pad 1H PGMS <0-10228'>,,14,Pad 1H PGMS ¢0-7440'>,,22,Pad 1H Closest approach with 3-D Minimum Distance method Last revised Distance 21-Aug-91 177.7 8-Jan-93 21-Aug-91 21-Aug-91 21-Aug-91 17-May-93 17-May-93 17-May-93 17-May-93 24-Jun-93 5-May-93 18-Feb-93 22-Feb-93 17-May-93 21-Aug-91 18-Feb-93 17-May-93 17-May-93 24-Jun-93 17-May-93 24-Jun-93 23-Jun-93 554.2 417 8 270 7 298 0 419 0 90 1 118 8 269.3 240.1 435.4 368.1 222.7 404.8 59.0 372.9 330.1 452.6 210.3 149.7 29.0 381.8 M.D. Diverging from M.D. 300.0 4500.0 300.0 5100.0 300.0 5489.6 4900.0 4900.0 300.0 3840.0 300.0 4500.0 0.0 0.0 300.0 4400.0 200.0 4300.0 200.0 4100.0 0.0 5000.0 600.0 2940.0 3660.0 3660.0 325.0 4600.0 300.0 300.0 300.0 4100.0 300.0 4500.0 0.0 4900.0 0.0 4200.0 300.0 4400.0 300.0 4100.0 0.0 4700.0 2-7/8" Guide String 20" Conductor Casing 1H-Ugnu-01 Wellbore Schematic Heat Trace 4-1/2" Production Tubing with ESP Power Cable 0-3/4" Surface/Production Casing Progressive Cavity ESP w/Wireline & CT Retrievable Pump 2-7/8" Slotted Tubing 7" Slotted Liner w/0.02" Slots TAB, 5/12/98, v.2 NOTES I BASIS OF LOCATION AND ELEVATION IS D.5. I-H MONUMENTATION PER LOUNSBURY 8 ASSOCIATES. 2. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. ~,~ 5. COORDINATES SHOWN ARE A . S . P . ZONE 4, N. A . D . 2?'. 4. LOCATED WITHIN PROTRACTED SECTION 33, TWP. 12 J., RGE. ,0 E. , UMI~ T MERIDIAN, ALASKA. 5. DaTE OF SURVEY IS APRIL 25. /998. ~CI~ITY 28 27 20, ~ ~ · 6 19 · 12~11 ,17. ~ 16. , j m 2' 7~18 ~ LEGEND ~ ~~[ , EXI~FING CONDUC[O~ SECTION 33, TO.SHIP 12 NORTH, R~NGE I0 E4ST NO. Y X L~ TI TUDE LONG I TUDE F. N. L . F. E. L . O. G. 5,980,234.0 549,542.3 tO' 2/ 24.42 /49' 35 5/.53 469' 804' 50.0' 54. /' ~r c~ o~r~ o~sc~/~r/o~ ~ LOUNSBURY ~ - DRILL SI~ 1-H - A CO Alaska, lno. cou uc o u uu-o Subsidiory of Atlontic ~ichfield Company CADD FILE NO. ~ ~ DRAWING NO: I PAOE: IREv: LK650D4 4/27/98 NSK 6.50-d4 1 OF 1 0 'KUPARUK RIVER U[_T 20" DIVERTER SCHEMATIC 6 4 3 2 5 DO NOT SHUT IN DIVERTER .'AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENTTHAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25,035(b) 1. 16' CONDUCTOR. 2. SLIP~3N WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSi BALL VALVE. 4. 20' - 2000 PSi DRILLING SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 r 7 6 13 5t8" 5000 FSi BOP STACK ACCUMULATOR CAPACITY TE~;T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AI='I'ER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4, RECORD ON THE IAOC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PS! REMAINING PRESSURE. 5 4 3 2 1. 16' - 20(X] PS! STARTING HEAD 11' - 3000 PSI CASING HEAD 11'-3000PSIX 13-5/8'-5000 PSI SPACER SPOOL 4. 13-5/8' - 5~:X:)0 PSI VARIABLE PIPE RAMS 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL DNES 6. 13-S/a' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BUND RAMS ON 8TM 7. 13-5/8' - 5000 PSI ANNULAR EDP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER ANO CHOKES ANO BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 30(30 PS! ONLY. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 7. TESTTO 250 PS! AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. MNES. AND CHOKES WITH A250 PSI LOW AND 5000 PS! HIGH. TEST AS IN STEP 4. DO NOT PRES.5'IJRE TE~T ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAM~ AND CLOSE BO3TOM PIPE RAM& TEST BOTTOM RAMS TO 250 PS! AND 5000 PS! FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BUND RAMS AND TESTTO 5000 PS! FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND lINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIEJNG POSITION. 11. TEST STANDPIPE VALVES TO 5000 PS! FOR 3 MINUTES. 17_ TEST KELLY COCKS AND INSIDE BOP TO 5000 PS! WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TESTAND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PS! HIGH ARCO Alaska, Inc. -- ~ Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor May 12, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill 1H-Ugnu-01 Ugnu Test Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Ugnu interval from 1H Pad in the Kuparuk River Unit ("KRU"). The well is designed to test the production potential of the Ugnu interval in the vicinity of 1H Pad. Completion plans call for setting a horizontal slotted liner through the Ugnu interval and then running a dual completion string consisting of a progressive cavity ESP on 4-1/2" tubing and a 2-7/8" tubing guide string. Sand production is expected in this unconsolidated formation and it is planned to produce this sand through the slotted liner and ESP. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Ugnu sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Ugnu sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 1H-Ugnu-01, such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as _such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is May 26, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincer.¢l¢;', ' Thomas A. Brockway Operations Drilling Engineer Attachments: CC: 1H-Ugnu-01 Well File Tom McKay ATO-1202 Larry Gipson ATO-1262 Drew Hembling ATO-1278 Lewis Ledlow ATO-1282 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Kuparuk River Unit, ARCO Alaska, Inc. by letter dated May 4, 1998 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a deviated oil well to an undefined pool in the Kuparuk River Unit. The exception would allow ARCO Alaska. Inc. to drill the Ugnu 1H-01 oil well to a bottom-hole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 469' from the north line (FNL), 805' from the east line (FEL), Section 33, T12N, R10E. Umiat Meridian (UM) to a target location of 280' from the south line, 1170' FEL, Section 28. T12N, R10E. UM. and a bottomhole location of 874' FNL, 2153' FEL, Section 33, T12N. R10E, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, May 21, 1998, with the Alaska Oil and Gas Conservation Commission. 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on June 4. 1998, in conformance with 20 AAC 25.540. If a hearing is to be held. interested parties may confirm this by calling the Commission's office, (907) 279-1433 after May 21. 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the no later May 27, 1998. David W~hnston Chairman Published May 6, 1998 ADN AO02814045 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ INIT CLASS ADMINISTRATION ENGINEERING ..-., I~ REMARKS 1. Permit fee attached ....................... 2. Lease number appropriate ................... ~ N ~, /~. - '.~ -/( '~"'-/'~ , '" 3. Unique well name and number .................. .~.~.,~_ ¢~,': 4. Well located in a defined pool .................. / 5. Well located proper distance from drilling unit boundaw .... 6. Well located proper distance from other wells .......... 7. Su~cient acreage available in drilling unit ............ ~ N 8. If deviated, is wellbore plat included ............... ~ N 9. Operator only affected pa~y ................... ~ N 10. Operator has appropriate bond in force ............. ~ N 11. Permit can be issued without conse~ation order ........ 12. Permit can be issued without administrative approval ...... ~N 13. Can permit be approved before 15-day wait ........... Y ...... . _~.~.: ..... : .. ~_-.:~=~=. _ :~ ~ =.: ............................................................ 14. Conductor string provided ................... ~N 15. Su~ace casing protects all known USDWs ........... ~N 16. CMT vol adequate to circulate on conductor & su~ csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ ~~ ~ ,~ ,., _ ~~~ . ~8. CMT ~i~ ~r ~, kn~w. pr~d~ti~ h~riz~ns .......... 19. ~::in~a~~ a~:~e~re C~tT, B & permafrost ....... 20. q g p'. ................ 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. DOPEs do they meet regulation ...... ~ ....... ~ N 26. DOPE ~ress rating appropriate; test to ~' psig. 27.28. ~h~kl~~¢E~~~;;~fl~~ ~4~ . ....... 29. p g ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~ ,, ,, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............ .~Y N ' 33. Seabed condition survey (if off-shore) ........... ~. Y N 34. Contact name/phone for we.eklypro~lress repo. rts . . ._//'... Y N lexp~orarory omy] GEOLOGY: ENGINEERING: COMMISSION: RNC. co ¢/~-~ '"" Comments/Instructions: 0 0 .-I A:\GE~, Misc\FORMS\cheklist rev 05/!:)8 dlf C :\msoffice\wordian\cli,ar~a\~:h~,::M i~t 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Jul 06 17:12:26 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-80248 P. SMITH D. BREEDEN 1H-UGNU-01 500292288700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 06-JUL-98 MWD RUN 2 AK-MM-80248 P. SMITH D. BREEDEN MWD RUN 3 AK-MM-80248 P. SMITH D. BREEDEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 5 AK-MM-80248 P. SMITH D. LUTRICK 33 12N 10E 469 804 JUL 08 Alask~ Oii& 8as 6o,~s. ~mmi~ion A.~borage ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 95.60 54.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 10.750 3980.0 9.875 5511.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,3, AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 4 CONTAINS NO VALID DATA AND IS NOT PRESENTED. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 25 JUNE 1998. 5. SPERRY-SUN MWD DATA IS CONSIDERED PRIMARY DEPTH CONTROL (PDC) FOR WELL 1H-UGNU-01 PER MIKE WERNER OF ARCO ALASKA, INC. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5511'MD, 3199'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 92.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 ROP 133.0 FET 134.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 5468 5 5468 5 5468 5 5468 5 5468 0 5511 5 5468 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 133.0 350.0 2 350.0 2688.0 3 2688.0 3998.0 5 -3998.0 5511.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 · Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 92 5511.5 2801.75 10840 92 GR 14.349 119.524 53.8162 10720 92 RPX 0.3723 2000 26.1846 10646 121 RPS 0.5107 2000 42.3544 10647 121 RPM 0.5924 2000 72.6441 10647 121 RPD 0.4328 2000 81.5074 10648 121 ROP 4.861 4604.37 238.058 10758 133 FET 0.1197 117.949 1.39113 10619 134.5 Last Reading 5511.5 5468.5 5468 5468.5 5468.5 5468.5 5511.5 5468 First Reading For Entire File .......... 92 Last Reading For Entire File ........... 5511.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 92.0 309.5 RPD 121.0 302.0 RPM 121.0 302.0 RPS 121.0 302.0 RPX -121.0 302.0 ROP 133.0 350.0 FET 134.5 302.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 05-JUN-98 ISC 5.06 CIM 5.46 MEMORY 350.0 133.0 350.0 .0 2.0 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ........ ' .............. -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1013CGR6 P1013CGR6 9.880 9.9 LSND HT 182.70 29.0 9.0 400 7.8 7.000 8.930 7.000 3.400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 13.0 First Name Min Max Mean Nsam Reading DEPT 92 350 221 517 92 GR 15.2475 88.2552 36.4631 436 92 Last Reading 350 309.5 RPX 11.9764 50.9132 30.8396 RPS 17.938 86.5216 50.0219 RPM 17.1956 574.291 76.6532 RPD 11.5542 2000 84.2746 ROP 21.9397 1645.67 194.946 FET 0.2448 2.4169 1.00863 363 363 363 363 435 336 121 121 121 121 133 134.5 302 302 302 302 350 302 First Reading For Entire File .......... 92 Last Reading For Entire File ........... 350 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 303 0 303 0 303 0 303 0 303 0 311 0 351 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 2639.5 2639.5 2639.5 2639.5 2639.5 2647.0 2687.5 06-JUN-98 ISC 5.06 CIM 5.46 MEMORY 2688.0 350.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: · NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .... ' .............. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2688.0 2.0 40.8 TOOL NUMBER P1013CGR6 P1013CGR6 9.880 9.9 LSND HT 200.00 85.0 9.0 400 7.4 4.500 4.120 4.100 4.500 28.6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68. 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 303 2687.5 1495.25 4770 GR 14.349 119.524 63.519 4673 RPX 0.7911 198.838 40.3368 4674 RPS 0.7022 2000 59.2545 4674 RPM 0.5924 2000 79.4358 4674 RPD 0.4328 2000 64.5654 4674 ROP 4.861 4604.37 261.14 4673 FET 0.1197 5.0648 0.586298 4674 First Reading 303 311 303 303 303 303 351.5 303 Last Reading 2687.5 2647 2639.5 2639.5 2639.5 2639.5 2687.5 2639.5 First Reading For Entire File .......... 303 Last Reading For Entire File ........... 2687.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 · FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 2640.0 RPD 2640.0 RPM 2640.0 RPS 2640.0 RPX 2640.0 GR 2648.0 ROP 2689.5 $ LOG HEADER DATA STOP DEPTH 3949.5 3949.5 3949.5 3949.5 3949.5 3957.0 3997.5 RPS 3974.5 RPX 3974.5 GR 3974.5 RO? 3999.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 5468.5 5468.0 5468.5 5511.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 13-JUN-98 ISC 5.06 CIM 5.46 MEMORY 5511.0 3998.0 5511.0 86.5 98.9 TOOL NUMBER PO 94 6CRG6 PO 94 6CRG6 9.880 9.9 HOLLYWOOD MUD 180.80 58.0 9.5 27000 4.2 · 160 .164 .140 .220 26.7 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 5 API 4 1 68 MWD 5 OHMM 4 1 68 MWD 5 OHMM 4 1 68 MWD 5 OHMM 4 1 68 MWD 5 OHMM 4 1 68 MWD 5 FT/H 4 1 68 MWD 5 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 3974 5511.5 4742.75 3076 GR 17.602 91.5195 37.76 2989 RPX 0.3723 2000 9.0367 2988 RPS '0.5107 2000 29.2581 2989 RPM 0.5992 2000 100.541 2989 RPD 0.567 2000 154.429 2990 ROP 15.4255 625.781 224.798 3026 FET 0.2034 117.949 3.0175 2988 First Reading For Entire File .......... 3974 Last Reading For Entire File ........... 5511.5 First Reading 3974 3974.5 3974.5 3974.5 3974.5 3974 3999 3974.5 Last Reading 5511.5 5468.5 5468 5468.5 5468.5 5468.5 5511.5 5468 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Reel Name ................ UNKNOWN Scientific