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Home My WebLink About193-189 kckz • 2.1'‘0s WELL LOG TRANSMITTAL #904280670 To: Alaska Oil and Gas Conservation Comm. December 19, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGED Anchorage, Alaska 99501 '!'6/2011 M K BENDER DEC 2 2 2017 RE: Leak Detect Log with ACX: 2E-08 AO G C C Run Date: 9/13/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2E-08 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22428-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-22428-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 sattam =` Office: 907-275-2605 FRSANC@halliburton.com Date: Signed�A/2iw RECEIVED STATE OF ALASKA • NOV 3 Q 2017 ALA4I,OIL AND GAS CONSERVATION COMMISSION r. 8 8 9 1 REPORT OF SUNDRY WELL OPERATIONS ADCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development i J Exploratory❑ 193-189 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22428-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2E-08 ADL 25658 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,779 feet Plugs measured None feet true vertical 6,321 feet Junk measured None feet Effective Depth measured 7,543 feet Packer measured 7,294 feet true vertical 6,134 feet true vertical 5,937 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 15 " 121'MD SURFACE 4,002 feet 11 " 4,043' MD PRODUCTION 7,717 feet 6 " 7,756' MD Perforation depth Measured depth 7390-7410,7483-7509 feet Total Vertical depth 6013-6029,6087-6107 feet CANNED J AN 92N, Tubing(size,grade,measured and true vertical depth) 2 7/8 L-80 7,329' MD 5,965'TVD Packers and SSSV(type,measured and true vertical depth) PACKER•TIW SS PERMANENT PACKER 7,294'MD 5,937'TVD SAFETY VLV-CAMCO TRDP-1A•SSA SFTY VALVE 1,803'MD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7390-7410 and 7483-7509 Treatment descriptions including volumes used and final pressure: Total Well-Single Stage FRAC 199,000Ibs placed See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 118 76 7 1131 192 Subsequent to operation: 354 185 12 1080 170 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 ►► Exploratory CI Development 0 Service ❑ Stratigraphic 0 1:1Copies of Logs and Surveys Run /C • 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-301 Seo /7�/4744 contact Name: Sandeep Pedam Authorized Name: Authorized Title: COM-f grial�/S eV in It/reg contact Email: Sandeep.Pedam@cop.com � ' 0' Contact Phone: (907)263-4724 Authorized Signature: 114 / Date: 14 WOW / nn � yr y/3/Jg F r�cc7 Form 10-404 Revised 4/2017 /g/,Z0( �� Submit Original Only • • 2E-08 FRAC STIMULATE DTTMSTI JOBTYP SUMMARYOPS 11/1/17 DRILLING PUMPED SINGLE STAGE FRAC INTO KUPARUK A-SAND, PLACED A SUPPORT TOTAL OF 199,306 LBS OF PROPPANT (191,806 LBS OF WANLI 20/40, - EXPENSE 7500 LBS OF 100 MESH), WELL FREEZE PROTECTED WITH 26 BBLS 11/7/17 DRILLING PULLED FRAC SLEEVE © 1802' RKB. DRIFT TBG, TAG @ 7502' RKB. SUPPORT SET CATCHER @ 7317' RKB. IN PROGRESS. - EXPENSE REI 11/8/17 DRILLING PULLED DV'S @ 6564', 5800', 4722', 2919' RKB & SET GLV'S. PULLED DV SUPPORT @ 7238' RKB & SET OV(CONFIRM GLVD INTEGRITY BY BLEEDING IA - EXPENSE TO 0); PULLED CATCHER @ 7317' RKB. JOB COMPLETE. REI 11/25/17 PUMPING FREEZE PROTECT TRACKING PUMP 3 BBLS NEAT METH DOWN TEST FL, ONLY PUMP 3 BBLS NEAT METHDOWN PRODUCTION FLOWLINE PUMP 5 BBLSNEAT METH DOWN TBG. *****TBG.LOCKED UP***** 11/26/17 PUMPING PUMPED XX BBLS 180* DSL DOWN IA TO THAW TBG ( JOB TRACKING COMPLETE) ONLY PUMPED XX BBLS 180* DSL DOWN TBG FOR H.O.T ( JOB COMPLETE) KUPD ! 2E-08 Con©coPhi lips Well Attributes Max Angle&MD TD Alas"(5 nc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(9KB) Act Btm(ftKB) Mips 500292242800 KUPARUK RIVER UNIT PROD 41.84 3,898.98 7,775.0 Comment H2S(ppm) Date Annotation End Date IKBGrd(R) -Rig Release Date 2E-08,11/29/20178;34;00 AM SSSV:TRDP 60 12/2/2016 Last WO: 12/15/1993 Verpral sdremabc(actual). Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,502.0 11/7/2017 Rev Reason:PUMP FRAC,PULL FRAC pproven 11/13/2017 SLEEVE,TAG,GLV CIO(SET up for GAS LIFT) IA i Casing Strings 11:11 Casing Description OD(in) ID(in) Top(9KB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r1ANGER,3/7 - CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len p...Grade Top Thread SURFACE 9 5/8 8.921 41.7 4,043.4 3,463.3 36.00 J-55 BTC Casing Description OD(in) SID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ij PRODUCTION 7 6.276 39.4 7,756.0 6,303.5 26.00 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 9 TUBING 27/8 2441 37.7 7,329.3 5,965.4 6.50 L-80 EUE8RDMOD . r Completion Details Nominal ID Top(ftKB) Top(TVD)(RKB) Top Incl C) Item Des Com (in) 37.7 37.7 0.43 HANGER WKM GEN IV 5M TUBING HANGER 2.875 IrE M CONDUCTOR;43.0-121.0- ' -s,,,Ar 1,802.8 1,753.3 31.78 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 7,291.4 5,935.4 37.87 SEAL ASSY TIW LOCATOR SEAL ASSEMBLY,10"w/7 SEAL 2.375 UNITS 7,293.8 5,937.3 37.86 PACKER TIW SS PERMANENT PACKER 3.250 SAFETY VLV;1,802.88` 7,316.9 5,955.5 37.76 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,328.6 5,964.8 37.67 SOS BAKER SHEAR OUT SUB 2.441 Perforations&Slots Shot Dens GAS LIFT;2,919.1 - Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 9) Type Com 7,390.0 7,410.0- 6,013.3 6,029.1 C-4,UNIT B, 2/13/2005 6.0 APERF 2"HSD PJ,60 deg 2E-08 phase 7,483.0 7,509.0 6,086.7 6,107.2 A-5,2E-08 3/15/1994 4.0 IPERF 4.5"Casing Guns; Oriented 180 deg.CCW • • Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(lb) Date SURFACE;41.7-4,043.4--- Mandrel Inserts St GAS LIFT,4,722.4 t ai N Top(7VD) Valve Latch Port Size TRO Run 111 lop(R)(B) (9KB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 2,919.1 2,610.0 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,371.0 11/8/2017 GAS UFT;6,800.7 t-. 2 4,722.4 3,978.0 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,344.0 11/8/2017 3 5,800.7 4,789.8 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,321.0 11/8/2017 al 4 6,564.0 5,371.3 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,311.0 11/13/2017 Frued enber GAS LIFT;6,564.0 g Pkg • 5 7,238.9 5,893.9 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 11/8/2017 Notes:General&Safety End Date Annotation 10/6/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT:7,2389 I SEAL ASSY;7,291.4 PACKER;7,293.8 •i F•. II ir NIPPLE;7,316.91 4/9• I SOS;7,328.6 APERF;7,390.0.7,410.0—� IPERF;7,483.0-7,509.0 +— — PRODUCTION.39417560 i• • 2 8 8 9 1 HALLIBURTON Sales Order# 904402900 ConocoPhillips Alaska LLC KRU 2E-08 Interval 1 Kuparulk Sand C Kuparuk Sands C Formation Beechey Point County, AK API: 50-029-22428 Prepared for:Sandeep Pedam November 1, 2017 Stimulation Treatment Post Job Report Hybor G Prepared By: Jonathan Alcantar Alan Kaiser Nanook Crew Notice:Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application,therefore,by the user of this report or any part thereof,is solely at the user's own risk. • HALLIBURTON Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval Summary 5 Well Summary 6 Interval 1 Plots 7-14 Chemical Summary 15 Planned Design 16 Event Logger 17 Water Straps Day 1 18 15 min FANN 19 Bacteria Testing 20 Water Report 21 Lab Testing 22-23 ConocoPhillips Alaska LLC-KRU 2E-08 TOC 2 • • Engineering Executive Summary On November 01,2017 a stimulation treatment was performed in the Kuparuk Sands C formation on the KRU 2E-08 well in Beechey Point County,AK. The KRU 2E-08 was a 1 stage Vertical Single Zone Design. The proposed treatment consisted of: 18,760 gallons of 25#Linear 110,635 gallons of 25#Hybor G 1,000 gallons of Freeze Protection 7,500 pounds of 100 Mesh 192,500 pounds of 20/40 Wanli The actual treatment fully completed 1 of 1 stages.0 stages were skipped,and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 22,355 gallons of 25#Linear 121,633 gallons of 25#Hybor G 1,128 gallons of Freeze Protection • 7,500 pounds of 100 Mesh 191,806 pounds of 20/40 Wanli A more detailed description of the actual treatment can be found in the attached reports.The following comments were provided to summarize events and changes to the proposed treatment: During the 3ppg Wanli 20/40 sand stage(13:42 hrs),a sharp decrease in pressure was noticed. The crew checked for any leaks or potential release through the pop-off,after verifying that everything was still normal,it was then noticed that our fluid system lost the ability cross link. Diagnosis of the fluid showed that the pH was at a 9.5,and that all chemicals were being pumped downhole without any issue. We were currently pulling from tank#3,at this point the tank was shut and tank#2 was opened. Thank#3 had 223 bbls left in it. Within one ADP tub volume(40 bbls),our fluid was back to standards.Around the same volume as tank#3,our fluid system lost the ability to crosslink. Tank 2 was shut and resumed to pump with tank 1.As this was our last tank and with 40000 lbs left to pump we ramped from 1 ppg to 4 ppg to displace the remaining proppant.After the job,tank samples were taken from the two suspected tanks with issues.Field testing showed that the water still was with in specifications(irons,sulfates and S.G) Samples were taken by Conoco and samples will be at the Halliburton lab to further investigate the probable cause of why our fluid system lost crosslink.It was also noted that these two tanks had a strong odor of diesel. We will be waiting on lab testing for further action. • Halliburton is strongly committed to quality control on location. Before and after each job all chemicals,proppants,and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis,crosslink time,and break tests are performed before each job in order to optimize the performance of the treatment fluids. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Thank you, Jonathan Alcantar Technical Professional Halliburton Energy Services ConocoPhillips Alaska LLC-KRU 2E-08 Executive Summary 3 „ .. g,„._n 0 0 0 0 0 0 0 0 0 0 . m e n 'c d I - o _ 8 8 8 8 8 8 8 8 8 8 8 g EA'm n n ry n ry n n ry ry ry ry o— „� ry m 8 8 8 8 8 8 8 8 8 8 8 m h 3 ry n n n n .'4 '4 ry ry n ry 0 ° ^i 8 _ 8 8 _ 0. 5 `s_ § 5 ry u g , o 0 0 0 0 0 0 0 u 0 0 0 0 0 0 0 0 0 0 ,y ? 2 u P ° a . 0 0 0 0 0 0 0 0 0 o 0 o e f — 8 ;' 8 8 8 8 8 8 8 8 8 8 8 8 8 _ 8 E ° E o ? a c n n ' n c - _ E E E ? Si '-: o moff o o` 8 § § § § 8 - a - - 2 il :716 I E= m 4 a m .o m y ' n n m F' 1 y m c a u o Q a - o _ ti O g § § § gg . , oma o E '' :12 ' _ o 0 E, Z E dSnci�a ,;>.:1, 1 2 3 a c o i o 8 8 8 8 8 n c o LL w _ a 'a N o . . 5 ] ttt i 3 3 3 3 ti g r .$ 0 J co x d,E2LL IL LL 0 o N 0 0 0 0 0' 0 - C2 C _ _ $ $ . . . Y Jp Tv' n n ry ry n 0 f6QO Y N 6 %--g0, 00 „, 0000 8 4 4 .. 4 4 , z °- E 2 PueS HlnJetln2 w w 0 Llenie1ul 0 0 0 • Interval Summary KRU 2E-08-Kuparulk Sand C-Interval 1 Interval Summary Date: 11/1/2017 Start Time: 10:09:00 AM End Time: 2:32:00 PM Initial Rate(Breakdown): 8.4 bpm Initial Pressure(Breakdown): 5124 psi Max Rate: 75.0 bpm Max Pressure: 5731 psi Max Pressure(SLF): 5700 psi Average Rate: 17.9 bpm Average Pressure: 4970 psi Average Missile Pressure 4901 psi Average Missile HHP: 2153 hhp Average Visc: 20 cP Average Temp: 80 F Average pH: 9.6 ISIP: 1277 psi Initial Fracture Gradient: 0.651 psi/ft 5 min: 1044 psi 10 min: 1005 psi 15 min: 978 psi ISDP: 1717 psi Final Fracture Gradient: 0.724 psi/ft . 5 min: 1719 psi 10 min: 1714 psi 15 min: 1713 psi Proppant Summary 100 Mesh Pumped: 7,500 lbs 20/40 Wanli Pumped: 191,806 lbs Total Proppant Pumped* : 199,306 lbs Proppant in Formation: 199,306 lbs Fluid Summary(by fluid description) 25#Linear Volume: 22,355 gal 532 bbls 25#Hybor G Volume: 121,633 gal 2,896 bbls Freeze Protection Volume: 1,128 gal 27 bbls Fluid Summary(by stage description) Load Well Volume: 1,880 gal 45 bbls Pad Volume: 24,987 gal 595 bbls Proppant Laden Fluid Volume: 92,496 gal 2,202 bbls Flush Volume: 2,794 gal 67 bbls Scour Volume: 15,718 gal 374 bbls DFIT Volume: 4,150 gal 99 bbls Freeze Protection Volume: 1,128 gal 27 bbls Treatment Volume: 145,116 gal 3,455 bbls Total Fluid Volume: 145,116 gal 3,455 bbls Interval Summary 5 • Interval Status: • Completed Comments: See excutive summary for notes Engineer' Jonathan Alcantar Treater: Chad Burkett Supervisor: Alan Kaiser "Values for proppant are taken from software calculations based on multiple variables. 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O w D = • O G x S x w f 0 ry rv.ry ry 0 0 ry ry ry 41 41 - ~ ~ J H ¢ o w O f0 u Y w E ., 0 0 0 v, w 0 m ., ., .. .. ,. ., 0 - 0 xz a E , d 110-0@ LL ry 0 pu ag 0In.edn 1 u u O ,en..elu C 0 U 0 • Treating Calc'd BH Slurry Job Job Clean Job Proppant Time Activity Code Comment Pressure Pres Rate Vol(gal Slurry (100-Ibm) (psi) (psig) (bpm) Vol(gal) 11:12:06(10/31/17) Start Job Starting Job 0 0 0 0 0 0 12:33:13 Pressure Test Pressure Test-Globals 100 psi 84 2624 0 0 0 0 12:35:03 Pressure Test Pressure Test-locals 800 psi 99 2624 0 0 0 0 12:40:21 Pressure Test Pressure Test-7800 psi 6371 2624 0 0 0 0 13:13:02 Pause Suspending Job 0 0 0 0 0 0 06:54:39(11/01/17) Resume Resuming Job 0 39 0 0 0 0 9:29:44 Pressure Test Pressure Test-Globals 3 2622 0 0 0 0 9:31:49 Pressure Test Pressure Test-locals 47 2622 0 0 0 0 9:38:19 Pressure Test Pressure Test-N2 pop off 1788 2622 0 0 0 0 9:40:49 Pressure Test Pressure Test-N2 @ 6837 psi 6837 2622 0 0 0 0 9:45:17 Pressure Test Pressure Test-N2 @ 6727 psi 6727 2622 0 0 0 0 9:51:19 Pressure Test Pressure Test-Final N2 @ 6532 psi 6532 2622 0 0 0 0 9:54:50 Pressure Test Pressure Test-7800 psi 7920 2622 0 0 0 0 9:58:15 Pressure Test Pressure Test-7800 psi 7788 2622 0 0 0 0 10:09:43 Open Well Open Well 264 2622 0 0 0 0 10:13:23 Next Stage Load Well 224 2667 0 0 0 0 10:28:02 Next Stage Sand Slug 3831 6479 9.5 1880 1884 0.76 10:48:37 Next Stage Flush 4944 4976 20 17598 17864 81.93 10:51:01 Next Stage Shut-In 1096 3773 0 19522 19791 83.09 10:57:04 Next Stage Fluid Efficiency Test 4869 5036 19.1 21485 21754 83.09 11:04:51 Next Stage Shut-In for FET Analysis 1143 3811 0 25635 25904 83.09 11:22:23 Next Stage Pad 2805 5483 0 25635 25904 83.09 12:18:49 Next Stage Proppant Laden Fluid 5217 5907 17.8 50635 50904 83.19 12:52:08 Next Stage Proppant Laden Fluid 5054 5701 19 75617 77037 316.67 13:20:35 Next Stage Proppant Laden Fluid 5258 6049 19 95454 98799 732.13 14:04:23 Next Stage Proppant Laden Fluid 4661 5556 18.2 126200 132763 1494.64 14:29:24 Next Stage Flush 4750 5611 17.5 143119 151559 1941.51 14:30:35 Next Stage Other 4578 5056 17.4 143989 152429 1941.51 14:31:58 Next Stage Shut-In 1778 4455 0 145117 153557 1941.51 14:32:07ISIP ISIP 1717 4393 0 145117 153557 1941.51 14:37:05 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 1719 4397 0 145117 153557 1941.51 14:42:06 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 1714 4393 0 145117 153557 1941.51 14:47:05 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 1713 4392 0 145117 153557 1941.51 14:53:16 Shut In Well Shut In Well 1678 4357 0 145117 153557 1941.51 16:39:43 End Job Ending Job 40 2691 0, 145117 153557 1941.51 ConocoPhillips Alaska LLC-KRU 2E-08 Event Logger 18 • • Customer: ConocoPhillips Alaska, Inc. Well: 2E-08 Date: 11/1/2017 Zones: 1 TICKET#: 904402900 BEGINNING STRAP VOLUME VOLUME TEMP ENDING STRAP VOLUME VOLUME TANK# TANK TYPE FEET INCHES (GAL.) (BBLS.) DEG F FEET INCHES (GAL.) (BBLS.) 1 500 V-BTM 130 20,350 485 104 39 5,710 136 2 500 V-BTM 130 20,350 485 94 60 9,353 223 3 500 V-BTM 133 20,566 490 88 60 9,353 223 4 500 V-BTM 130 20,350 485 92 12 1,543 37 5 500 V-BTM 130 20,350 485 88 12 1,543 37 6 500 V-BTM 130 20,350 485 98 13 1,697 40 7 500 V-BTM 129 20,271 483 100 11.5 1,389 33 8 500 V-BTM 131 20,426 486 96 13 1,697 40 9 500 V-BTM _ 84.25 13,573 323 12 1,543 37 10 11 12 13 14 15 16 17 18100 19 100 20 100 21 100 22 _ 100 23 100 24 100 25 98 _ Transport TOTAL: 176,586 4,204 TOTAL: 33,828 805 Minus 50 bbl bottoms 3,664 Water summary Starting(gal) Used(gal) 142,758 Starting(bbl) Used(bbl) 3,399 ConocoPhillips Alaska LLC-KRU 2E-08 Water Straps Day 1 19 • • Fluid is broken at200cp Zone 1 Crosslink Tests -Pad -1 ppg -2 ppg -3 ppg -4 ppg -5 ppg 3500 3000 2500 a 2000 y 41111 dee.- U > 1000 F l 500 0 r 00 00 01 00 02:00 0300 04.00 05 00 0600 07:00 08 00 0900 10 00 11 00 12:00 13 00 1400 15 00 Time (min:sec) ConocoPhillips Alaska LLC-KRU 2E-08 15 min FANN 20 . • 0 z 0 ca m m n w E Q ¢ = CO 0 o N COLA OD V CO CO 'aft' N CO N m a N O N O ? a ti m C m 'o o `v m a > mO - v CO -0 OO u L C 0) 01 c y y c y m a n a°1 a � � > v1• 1Oi v1 < v1 V m L) v m a N v m Vl rre;-4 N N O m 11) N ee N l��l Lr) > v E N LL H - a 411 - p w 0 0 0 0 0 0 0 0 Vi ul ul V1 u1 V1 N V1 N O a E � � o v p m E >° ) E LL u a = ami v m 2 v v 00 CO m V, N V1 N V1 V1 u) ri W N N N N N N N N a 0 LI-1 0 L.1-1 0 o m o m A m m To c LL Q E O _• C w E O N O u1 CO 00 CO CO CO CO CO 00 m OO O N 00 00 00 00 00 00 00 00 D 00 a E _ o E o0 v O 'o >n To > ry 0 Cto • y, 01 G N O E 0) M N m e} ul tO n 00 To. w m ' «' '^ E c c c c c -se c c = L OJ m C > A f0 0f 16 10 A IC 10 • N F f- H F F H ♦- 8 • • • I HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocoPhillips Alaska,Inc. Well Name/No.: 0 Date Tested: October 31,2017 Water Type: Sea water Units Tank 1 Tank 2 Tank 3 Tank 4 Tank 5 Tank 6 Tank 7 Tank 8 Tank 9 Specific Gravity — 1.020 1.020 L020 1.020 L015 1.0200 L0200 L0200 pH — 6.95 7.01 7.05 7.04 7.1 7.1 7.1 7.2 Iron(Fe) mg/L 5 0 5 5 5 5 5 5 Chloride(Cl) mg/L 22392 17253 15867 15867 14607 13455 13455 13455 Sulfate(SO4) mg/L 800 800 800 200 800 800 800 800 Hardness mg/L 425 425 425 425 425 425 425 425 Linear Viscosity cp 22 20 22 19 18 20 19 20 Crosslink pH pH 9 9.5 9.8 9.9 9.9 10.5 9.8 9.8 Crosslink Test(Y/N) Y Y Y Y Y Y Y Y Units Tank 10 Tank 11 Tank 12 Tank 13 Tank 14 Tank 15 Tank 16 Tank 17 Tank 18 Specific Gravity -- pH — _,•-- Iron(Fe) mg/L Chloride(Cl) mg/I. Sulfate(SO4) mg/L Hardness mg/L Linear Viscosity cp -- Crosslink pH pH Crosslink Test(Y/N) --- Units Tank 19 Tank 20 Tank 21 Tank 22 Tank 23 Tank 24 Tank 25 Specific Gravity_ pH Iron(Fe)_ mg/L Chloride(Cl) mg/L Sulfate(SO4)_ mg/L Hardness mg/L Crosslink pH_ pH Crosslink Test(Y/N) This report is the property of Halliburton services and neither it nor any part there of nor copy thereof may be published or disclosed without first securing the express written approval of laboratory management.It may however,be used in the course of regular business operations by any person or concern and employees thereof receiving such report from Halliburton Services. NOTICE:This report is limited to the described sample tested.Any user of this report agrees that Halliburton shall not be liable for any loss or damage,whether due to act or omission,resulting from such report or its use. ConocoPhillips Alaska LIC-KRU 2E-08 Water Report 22 H.ALLIBURTON Prudhoe Bay Field Laboratory-Rockies NWA Laboratory Project ID Number: 2051SS6-1 Customer: ConocoPhillips Well Name&Number: KRU 2E-US Fluid System: Hvbor G Date October 31.2017 Snomry of Testing and Results Fut 10 minute:at 511 1.:ec at 100 degiee: -After 10 nnnute:the:hear rate wa:cecrea:ed to 100 1:e:.and the:ample wa:brought up to temperature with in 0minute: A:A testing wa:done u:mg Location Seawater(SL=60'-comp of 4 bottle:. Te:hnician::i Pe:fon-az Iwai Aa itfi Maniac. Re:sewed t Appn.ve: ConocoPhillips Alaska LLC-KRU 2E-08 Lab Testing 23 • • JOB INFORMATION AND TESTING CONDITIONS Custother C ow:era:laps Fluai System Hsbor G Bob Tspe 85 Wel:Narae 12.T.:2E-08 Water Source. Seawater Shear.Rate(I sec) 511 ICC Aare October 2.1 20:7 SHST(F) 150 Lib Project r, 20518E6-1 FLUID DESIGN Ter No . 2 r GA Want.(51110 Lot o abemscal taits Cbmescal Coacestralisss . - - - 6 _ _ = Fr 2 : . _ - SP Haul.: F7 ... . - 4.4 ILI 11)PR()PI KILL' Test No : 2 4 5 ... • Gel Nyirstimi q11,0 Water pH 6 93 690 690 M... ,.',....t. .-.2 Tor-p ...1- Base Gel(*) 2!OD 2!00 35,00 Base Gel Vasc(cp) .:.c.,0 :C 0 'IC 9 • Base Gel pli, '20 ... ": 3 334 IOC — . _ --- Base Gel Temp(I') 70 4 134 IOC Buffered pH s 46 S 4' ..: i''4 IOC C rc,s 431 pH 002 503 ,.^- ..• . IOC Fang pH 01' 10r. 3-, . IOC Tes:Taal) i F) :.6 L'S : • : ., . IOL Brea),Tune,lar Exas) s s- - 1!6 IOC 10 136 ICC To.t.:Sotet BREAK TEST CHART .....4.a —.44,..tv 5.1,44.Rale V6urt.t, Shaw 04Ia ..........Kart. Mao he.. 94,....4, ---Now...a.----.1,4.• 1..,.......• tooponotare---laRtt.M.A. i,,.......... 7/0 / LSO 160 . GOO- ____,--,..---.....----.--.............--_-__ _ 300 ' ' ! 6.f 11 WI* • 1 , 11 , 10 .111410 120 1 403 16231i h 11 i ---" 03 ka1 ll6'4VVVV•-.14.,,......1 1 SO I SOO--• 0 ‘.11L-A•I'N,...._ 40 ......,_ KO 100 k N........_ .40 ..... , —,— , 0 0.20 ,,12 2,24 319 040. 600 712 7001.0.44 ConocoPhillips Alaska LLC-KRU 2E-08 Lab Testing 24 • 0 T 112T g g gogf JE C�W OE IL .g. 2E o a Z 2. 2 E V m„ c W o 0 o E t - x x tt il t PER c .F iiRO v o $ § $ i$ $ i $ z$zr oiz..rm + E t' 2 ti to _ v m a U o 0 0 00 0 0 0 00 A _ 0 11S R2 CiNn E S �R a�<go '' E T a EE ca v �a m gO H E�, 0 0 0 0 ., x 0 0000 0 0 0000.,00000 `a co U — w oE 2 2 v Q^ Eo ECl t. °m a m- Ei & oa 25 U 2 g2 ` f«n r n i m m i m m m Z q r q R Y d q rv� g f° Z uE>. 04 C i; O ii .° u .L!'02 C Q 2 l. C 8 8 $ .g "P B a a ° m m- a 0 0 2 Ep € 3 c❑ i 2 i 2 2 i 1 y 3 , E . $ E i E 'r' _E W I o , E E E S fi_ 'm o' 9 E E E E E E c . oa i ]] 1 i ] ]am _ L` QE 1 °uU ? W`E nal a •2ggg 2 9.Ht °EU �� a UU v cDl l o 3 ``o�E' dory U ,"ga�i=4 Salo o`Io � E m U n 6 Tmig is c "a n v$a a d o2 o_ LLgi a a E g. a o x U o W 0 0 0 o 0 a a a� " E E E = S .‘ P',' E EEU�&$r �a v a 8 $ $$ $ Mt. ¢ of _i j z “E1312-0, §1 - C g - _ _ _n 1 111 :10,:1-21 '°” o ��r ; E7.- a = _ g_ 0 o x x x x x x x x x x ?a- E d O a 4 y m O K. J c- u 3 >°3 2 3 i§ - w_ -° Ell a p� "w - 2v °°- nTn /93-egy Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, November 01, 2017 7:39 AM To: 'Pedam, Sandeep' Cc: Wallace,Chris D(DOA) Subject: RE: [EXTERNAL]RE:2E-08(PTD 193-189, Sundry 317-301) Frac Sundry Questiona Sandeep, The modifications to the fracture stimulation outlined below are approved. Please include this approval with your approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SCANNED State of Alaska fir Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoem@alaska.gov From: Pedam,Sandeep [mailto:Sandeep.Pedam@conocophillips.com] Sent:Tuesday, October 24, 2017 3:06 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: 2E-08(PTD 193-189,Sundry 317-301) Frac Sundry Question Victoria, Please see attached for new model results and pump schedule.Our max.anticipated pressure from the model is 4276 psi. Regards, Sandeep From:Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,October 24,2017 2:31 PM To: Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: [EXTERNAL]RE:2E-08(PTD 193-189,Sundry 317-301) Frac Sundry Question Sandeep, 1 • Please provide a revised pump schedule with the maximum anticipated frac pressure. Please run the frac model with the new proppant loading/size to see any changes.You may email this information to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov From: Pedam,Sandeep[mailto:Sandeep.Pedam@conocophillips.com] Sent: Monday,October 23,2017 5:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: 2E-08 Frac Sundry Question Victoria, We were thinking about adding 100 mesh sand to the pump schedule to help scour the near well bore region.The remaining frac will be pumped with 20/40 wanli proppant. 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II/ • pro /43-Ir/ Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, November 01,2017 7:39 AM To: 'Pedam, Sandeep' Cc: Wallace,Chris D (DOA) Subject: RE: [EXTERNAL]RE:2E-08(PTD 193-189, Sundry 317-301) Frac Sundry Questiona Follow Up Flag: Follow up Flag Status: Completed Sandeep, The modifications to the fracture stimulation outlined below are approved. Please include this approval with your approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer g �Hr� State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.ciov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoerJo@alaska.gov From: Pedam,Sandeep [mailto:Sandeep.Pedam@conocophillips.com] Sent:Tuesday, October 24,2017 3:06 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: 2E-08(PTD 193-189,Sundry 317-301) Frac Sundry Question Victoria, Please see attached for new model results and pump schedule.Our max.anticipated pressure from the model is 4276 psi. Regards, Sandeep From: Loepp,Victoria T(DOA) [ma ilto:victoria.loepp@alaska.gov] Sent:Tuesday, October 24, 2017 2:31 PM To: Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Cc:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: [EXTERNAL]RE: 2E-08(PTD 193-189,Sundry 317-301) Frac Sundry Question 1 Sandeep, ! S Please provide a revised pump schedule with the maximum anticipated frac pressure. Please run the frac model with the new proppant loading/size to see any changes.You may email this information to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp[a�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From:Pedam,Sandeep [mailto:Sandeep.Pedam@conocophillips.com] Sent: Monday,October 23,2017 5:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:2E-08 Frac Sundry Question Victoria, We were thinking about adding 100 mesh sand to the pump schedule to help scour the near well bore region.The remaining frac will be pumped with 20/40 wanli proppant. Do we need to provide you with any documentation that supports this request? Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Cell: 512-507-9537 Office:907-263-4724 • 2 411 • SOF Tit ,,1y/,�,?, THE STATE Alaska Oil and Gas f , T O.f®® LASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O Main: 907.279.1433 ALAS- Fax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam Staff Completion Engineer %too AUG, 1 12Q17. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-08 Permit to Drill Number: 193-189 Sundry Number: 317-301 Dear Mr. Pedam: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair, Commissioner DATED this day of July, 2017. RBDMS (,c/AUG — 9 2017 • • RECEIVED STATE OF ALASKA `JUN 2 9 2017 AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 ' Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development 0• 193-189 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22428-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ KRU 2E-08 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25658 . Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,779' - 6,321' ' 7543 " 1 6134 NONE NONE Casing Length Size MD TVD Bgrst Collapse Conductor 78' 16" 121' 121' Surface 4,002' 12" 4,043' 3,463' Intermediate Production 7,717' 7" 7,756' 6,303' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7390-7410,7483-7509 , 6013-6029,6087-6107 2.875" L-80 7,329' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-TIW SS PERMANENT PACKER . MD=7294 TVD=5937 SAFETY VLV-CAMCO TRDP-IA-SSA SAFETY VALVE • MD=1803 TVD=1753 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 i Service ❑ 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 , WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: taff Complet• s Engineer Contact Email: Sandeep.Pedam@cop.com �j b� Contact Phone: (907)263-4724 Authorized Signature: / ��- Date: ("V 2 IV' ' COMMISSION USE ONLY Conditions of approval: Notify Co fission so that a representative may witness Sundry Number: 317- 30 \ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 NoSpacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0 --i 7/ 1' RBDMS t� AUGu - 9 2017 APPROVED BY Approved by: ,C ' COMMISSIONER THE COMMISSION Date: t lc ��*a 7.1140- YTG :�/Zf i.: c.4)1„,, -7/1z./eo i7'V' RAI �LicAlrvalidSubsin Form ane n1V Form 10-a03 Revised 4/2017 o for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska, Inc. JUN 2 9 2017 Paul K.Wharton � � Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Paul.K.Wharton@conocophillips.corn To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2E-08 Well Kuparuk River Unit, Alaska ADL 25658, KRU Tract 64 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2A-26 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about June 2, 2017. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Lynn Aleshire Rebecca Swensen 2E-08 Hydraulic Fracturing Notice Letter June 1, 2017 Page 2 Exhibit 1 1L • / 2E-12 2E-11 2E-14 2E-16 ADL025658 f ADL025657 t 11-17k1 ADL025659 2E-1511-02Pa 2E 15111-02 jy�1 / ZE-1511-03 2E-'15 2E-to 2E 13 .-.,w 2E-08 1L=17�' �_�-2E 1 i €L) v i t...L.. --- i ..----- j 1L 2E-15L1-01 t-17APE2 2E-09 2E 15L1P81 � \1L 17A 1511 2E-04P131 2E-07 ` r \ 2E-0602E-OS ADL025666 2E-'7 ADL025665 ADL025664 i 2E OE_1F81 2E06 2E 06L1 01 1 2E-C3 2E-04 2E-02 2E-01 • Frac Points Trajectory ADL025670 ADL025671 Kuparuk PA Open Interval — — — — — — N I-7 1/2 Mile Frac Point Radius A ConocoPhillips F-1 1/2 Mile Trajectory Radius Alaska,Inc. I Wells within Trajectory Radius 0 0.2 0.4 0.6 0.8 1 1.22E-08 L_ Kuparuk PA Miles� p Lease Plat CPAI Leases Date:5/17/2017 • 2E-08 Hydraulic Fracturing Notice Letter June 1, 2017 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO THEALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2E-08 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1)CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about June 1, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners,and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 1st day of June, 2017. /4 • 61*-eietz Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 1st day of June, 2017, by Paul K.Wharton. Not ry ot e�ate Public, State off` laska� My Commission Expires: 1 STATE OF ALASKA NOTARY PUBLIC `;` REBECCA SWENSEN 4;476' My Commission Expires Au..27,2020.: • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) • • Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within 0.5 miles 2E-12 2E-11 2E-14 2E-16\;ADL025658 I ADL025657 '' i1.-17AL1 ADL025659 2E-151.1-02PB1 r` 2E 15L1‘-02 .r 2E-15L'1-03' 1-03' 2E-1 • 20 2E-13 f""" ° i1.-17 ` 12E ZE-08 ,z ° 1L-17APBI /",/2E-15L1-01 ,---- .4 \ \ „..,, 2E-09f 2E-15L1PB1 i1.-17A 2E-15L11l �} \ „� • t 2E 04P61 ' \\I \ N., -...., 2E-07 2E-06_1 2E-05 ADL025666 7 2r-1' i✓ ADL025665 ADL025664 1 i 2E-06L1Pal -06 li il i 2E-061.1-01 '2E2 2E-03 2E-01 • Frac Points Trajectory ADL025670 ADL025671 Open Interval N n 1/2 Mile Frac Point Radius A ConocoPhillips n1/2 Mile Trajectory Radius Alaska,Inc. I -- - Wells within Trajectory Radius 0 0.2 0.4 0.6 0.8 1 1.2 -- -- 2E-08 Kuparuk PA Miles L_--_- p Lease Plat CPAI Leases Date: 5/17/2017 • Table 1:Wells within 0.5 miles Wells within 1/2 mile buffer of well track Data from SDE layer: SDE_DATA.AK WELL_BOTTOM_TD ATDB_DD83 API Well Name Well Type Status 500292215100 1L-17 INJ PA 500292215101 1L-17A INJ ACTIVE 500292242300 2E-05 INJ ACTIVE 500292238900 2E-07 PROD SECURED LTSI Section 3 - Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. • None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River oil and gas producing field". Section 4 - Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. /' Section 5 - Detailed Cementing and casing information 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g)when completed. See Wellbore schematic for casing details. • • Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) Casing &Cement Assessments: The 9-5/8" surface casing cement pump report on 12/08/1993 shows that the job was pumped with no issues, indicating competent cementing operations. The cement job was pumped with 700 sacks 12 ppg ASIII cement and 500 sacks 15.8 ppg class'G'tail cement. Took cement returns to surface (35 barrels). The pump bumped at 2,000 psi and floats were checked and they held. The 7" production casing cement report on 12/14/1993 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg premium class'G' cement. Full returns were seen throughout the job. The plug was bumped to 3,500 psi and the floats were found to be not holding, re-landed the plug and shut in the well. TOC was observed with logging tools at and determined to be 6,900' MD. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successful fractured within design limits. Section 7 - Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) On 5/9/2009 the 9-5/8" casing was pressure tested to 1,800 psi. On 3/14/1994 the 7"casing was pressure tested to 3500 psi. On 6/12/2013 the 2-7/8" tubing was pressure tested to 1,850 psi. It will be tested to 4945 psi prior to the frac. • al AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 4,945 Nitrogen PRV 6,460 Highest pump trip 6,260 • • Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 9 &5/8" 36 1-55 3,520 psi 2,020 psi 7" 26 L-80 7,240 psi 5,140 psi 2 &7/8" 6.5 L-80 10,567 psi 11,165 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up 3 Based 1 Tattle l Tale Tat* 04.44114 �$ fr g v toy 100 i 1141111104 J N d d a _.. Y A W 51Xu1 dwnd Pq Off Tank m Pap-Off Tank Pump Truck art d¢ ' 4Otet I"co. t N )„,3 Frac Pump --. - -fJ_ Frac Pump Frac Pump Frac Pump Frac Pump -(%11--; — —}1 Frac Pump • • Tree Saver with Wellhead t OIL STATES PROPOSAL: I Energy Services (Canada) Inc, QUOTE#: DATE: Maximum Allowable Pumping Rates SIZE ID OD RATE miimin CSG 2.250 3.750 10 m3/min 3 112" Big Bore 1.750 2.750 6 rn'lmn 2 71811&3 112" 1.438 2.360 4 m4lmin 2 318" 1.000 1.900 2 ms/min 3 1/16&4 1/16 with tapered mandrel 2.750 4.000 15 m'fmin 4 1116 X Tool Mandrel 3.610 4.760 24 mImin —. OPEN POSITION CLOSLO POSITION r axe i"VW.1 INNIVIKt,.I rW4k[n*1 I"fi4&`fill rWOO°M ri r' /4,441./WM* ,-, , , riii f4(KI MIMIfU ffin''M'UF,k v.vvi I f li ei Ory ,:o. eij _LL MK LI NMWt! e 1 ,,s,„ .. ........ 4.i'.t, k rb w•1.w Ir i HOW lit Man Mill N. F ' 11#414X10 i 1 (4441® gKy €k r(r. rt MAO N r.M.K. WI r www.osesc a nada,cora • • Wellhead Schematic KUP PROD 2E-08 ConocoPhillips i ' ' *NI atrIbute* Vitax Te&MD TD h....,As, I,...r... ;04,44,1,..i...-<•Ss...A I ._rt la, ir ..,, , ...,„.., o.,... itAar,tFL, Ca.Dios ,!..5-4,WIN' l ''''''. RIC7.5.5r12D,4 1a4144*" ' ' Mt ''. ' Min . :IV, ___ ,,,,,,....,, Omet Omit tee Dam Anna-m. -an,..L: tnalliss ow."ng.1... ?IT.:: 5,12.nnI: `.1.Tn.?. •,, -ac, fi-61 Casing Stmgs ,C eh j C., , ....1 1,..i......p.r,,r.23. 1....La.mi-oTe.. *Neu, ....... 154 rn.... . ... i iili -. . ,-. 4C$ ...I C 1,,i. 8210 5-4.il At Lill I: ; 64111; 541-Dearti inisi) &mem.rINCv,- Mit.,1, 4115. Tan Mstomt liL 111liEU .. Illi 4?? 4 CAN 4 1 se 31 1 I 3 LE-Wit. ETC IL I ..,,.1 C irr ":4 1.21 1.1.-watt I?NO 24.-Gap,*lilt?. OWL.r. .4atfin las 11,..4 no.4 DIDIng Sbl-ii?s , 4 I 1 _ ,....-......r,..^.,-• lite.,..,..,...,,r„,I.4.4,r„...,.,roe rkifetT r..„, I_4W-11:41,1,14,-..„ 1;,.„;‘,,,. Crnp6oton Detals '5,n:rat E I . IA,... 'S ATM tIt.ri rw 5AS....&k1sta 1.14,...4.1.; kr, 2 528 5 -•• • A 1 I”4e12.' LAIldtli 111121,14.-55A sm.Lry VA..J1 2 3SZ , I 015 4 2 i".5, r.e....._NS 15). Intli LADCATCV SLAC AS5G5151 t C.*a' C. ,. 2 375 I 1154 %MO 2 lust PA4.0.1.5 TM 5 Mt 5 3:85 SOPPLI. 55 MIIMAria511 PAL Kt 5 CAW:DID SW'S',F.W,CC 3.150 tannigrr 0,I/.3, r.1 .vrA t SlIT? 1-a 5A03 SI 5ILAT4,..:,..1'we 244? Ps-rorabcm 3,Slots .,I .....rIrAti IMes IT4Df team Ork:mat 1 4.,or:sl Iter+MR; AMA OMNI 80..s emm I Ta. Cs. acs4 AIM*? 4 I.... 88!1.5 5 USD I C--1 I...4 I 5 2}.1,:,..a.:5 I:: A,?..3,, 7.,rtnul`..1 55 rbsg. 711-005 Mawr 4 CII 5 Me 2 5 1.".,2......t:MAO DP tt"WA 4: i'L58 4 5'Zost-i;Claras Iners.1 i 4D Met CL7n Mandral irk3S78 . --, 1-•,`, ..ma. 4.114% Atm Um MDR.. ' 1-......15.111i 1..... Man. in,m ..11 - ,-, T.41 Tame i.; Mali O.DMA Gmvi ea...*4'e-1.441 9 .— ".' ..1 4 ..v-_ fo, 1 Ida ,45,1*15:117.1,3 •.. n Drx DO.W2'375 ID 0W? Mmoun 4Mr.e. a t„,... .... ,., ,....„ . .184 142?0 5,7t1;WM J llt...0 II V 2i 14 1115.4 ;Mattson CI.5 11 ffSt ,ea:Gefiefai&Safely P. L. 1 VIA%`IC It 1.11.,4".*Amt.5015,8020 santsan 1141114s II I ......laiiV 1,AllY. I I I 041.Li5_ ASMI 42*5404 han..Y.5.1-i.msas—- — - — -. ..- ... — ...- I • Section 9 - Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A sand interval, is approximately 105'TVT in the wellbore, with the top of the Kuparuk A at -5,923'TVDSS (7,462' MD). The Kuparuk A interval is composed of multiple packages of fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is approximately 12-13 ppg. The overlying confining zone has an overall thickness of 417'TVT (532' MD) and consists of HRZ and Kalubik mudstones, the Kuparuk C sandstone, and interbedded siltstones, shale, and thin, discontinuous, sandstones of the Kuparuk B interval. The Kuparuk C sandstone is thin at this location (16'TVT) and is siderite cemented, and the Kuparuk B interval is 41'TVD. The top of the HRZ is at -5,506 TVDSS (6,930' MD), the top Kalubik is at -5,698 TVDSS (7,178' MD), the top Kuparuk C is at -5,865 TVDSS (7,389' MD), and the top Kuparuk B is at -5,881'TVDSS (7,408' MD). The estimated fracture pressure for the overlying confining layer (HRZ and Kalubik) is approximately 15-16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500'thick. The estimated fracture pressure for the Miluveach is approximately 15 ppg. The top Miluveach is located at -6,028'TVDSS (7,594' MD) in the wellbore. Section 10 - LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing &Cement Assessments: 1L-17(A): The 7" production casing was cemented on 4/11/1991. 275 sacks of class'G'cement were pumped at 15.6 ppg. Full returns were seen throughout the job and floats held. TOC in the 7"x 9-5/8" annulus was observed with logging tools at and determined to be 7,100' MD and in good condition from TOC to TD. Prior to CTD operations in 2016, the existing A-sand and C-sand perforations were squeezed with 16.5 ppg class G cement. TOC of cement was observed to be at 8037' inside the 3.5"tubing after curing for 72 hrs. The cement was pressure tested to 2,000 psi. 2E-05:The 7" production casing was cemented on 12/6/1993. 275 sacks of class 'G' cement were pumped at 15.8 ppg. Partials returns were seen throughout the job and the floats held.TOC in the 7" x 9-5/8" annulus was determined to be 11,100' MD from the cement bond log. • • 2E-07:The 7" production casing was cemented on 10/24/1993. 300 sacks of class 'G' cement were pumped at 15.6 ppg. Good returns were observed throughout the job,the plug bumped, and floats held. TOC in the 7" x 9-5/8" annulus was determined to be 8,900' MD from the cement bond log. Well Status Casing Top of Top of Top of Reservoir Zonal Cement Mechanical Name Size Oil Cement cement status Isolation Operations integrity Pool determined Summary by 1L- Inj 7" 8,170' 7,100' Cement Slotted Top of 58 bbls, MITIA 17(A) MD MD Bond Log liner for cement at 15.6 ppg, passed (4/19/1991) injection. 7,100'MD class 'G' 10/17/16. in 7"x 9- cement. 5/8" annulus. Packer at 7,954'MD. 2E-05 Inj 7" 11,700' 11,100' Cement Open Top of 58 bbls, MITIA MD MD Bond Log hole for cement at 15.8 ppg, passed (12/19/1993) injection 11,100'MD. class 'G' 7/21/2016 Packer at cement. 11,571'M D. 2E-07 Prod 7" 9884' 8900' Cement LTSI— Top of 62 bbls, CMITTxIA MD MD Bond Log secured cement at 15.6 ppg, & MITT (12/20/1993) with 8900'MD. class 'G' passed plug. Packer at cement. 8/19/2016 9776'MD. Tubing plug set at 9792'MD. Section 11 - Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there are 7 mapped faults that transect the Kuparuk A interval and enter the confining zone (Kalubik and HRZ) within one half mile radius of the wellbore trajectory for 2E-08. The five north-south trending faults and the two east-west trending faults around 2E-08 terminate within shales of the confining zone, and fault throw ranges between 5-20' (see table below). No mapped faults intersect the 2E-08 wellbore trajectory. Fracture gradients within the confining zone will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zone is discussed in Section 9. • # 2E-08 Area Faults Orientation Throw in Feet Fault #1 North-South 5-10' Fault #2 North-South 5-10' Fault #3 North-South 5-10' Fault #4 North-South 5-10' Fault #5 North-South 20' Fault #6 East-West 5-10' Fault #7 East-West 5-10' • S Plat 2: 2E-08 Fault Analysis ADL025657 ADL025658 1L-17AL1 phik ADL025659 2E 2E-O8 1L0 A 1L-17APB1 17APB2 1 17A ADL025666 ADL025665 ADL025664 Frac Points Trajectory Open Interval ADL025670 ADL025671 Kuparuk PA I-1 1/2 Mile Frac Point Radius - 1/2 Mile Trajectory Radius ConocoPhillips ••••••••..,Faults within Frac Point Radius Alaska,Inc. Wells within Frac Point Radius 0 0.2 0.4 0.6 0.8 1 1.2 2E-08 Miles Kuparuk PA Frac Plat CPAI Leases Date:6/9/2017 • Section 12 - Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 2E-08 was completed in 2009 as horizontal producer in the Kuparuk A sand formation. The well was completed with 3.5" tubing and 7" production string with perforations. A single stage frac will be pumped through the perforations. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2,677 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 120 bbl breakdown stage (25# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 18 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 6,500 psi. • 0 Section 13 - Post-Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. 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Wt/Len(I...Grade Top Thread HANGER,37.7 II+ CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED II Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 41.7 4,043.4 3,463.3 36.00_J-55 BTC Casing Description .OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 39.4 7,756.0 6,303.5 26.00 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lbftt) Grade Top Connection TUBING 2 7/8 2.441 37.7 7,329.3 5,965.4 6.50 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com ((n) 37.7 37.7 0.43 HANGER WKM GEN IV 5M TUBING HANGER 2.875 1,802.8 1,753.3 31.78 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 .nn.r CONDUCTOR;43.0-121.0.A.AA.AJ -' -.ice 7,291.4 5,935.4 37.87 SEAL ASSY TIW LOCATOR SEAL ASSEMBLY,10"w/7 SEAL UNITS 2.375 7,293.8 5,937.3 37.86 PACKER 'TIW SS PERMANENT PACKER 3.250 7,316.9 5,955.5 37.76 NIPPLE 'CAMCO D NIPPLE NO GO 2.250 SAFETY VLV;1,802.8 7,328.6 5,964.8 37.67 SOS BAKER SHEAR OUT SUB 2.441 Perforations&Slots Shot — Dens Top(ND) Btm(ND) (shots/( Top(ftKB) _ Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;2.919.1.-17,390.0 7,410.0 6,013.3 6,029.1 C-4,UNIT B, 2/13/2005 6.0 APERF '2"HSD PJ,60 deg 2E-08 phase 7,483.0 7,509.0 6,086.7 6,107.2 A-5,2E-08 3/15/1994 ' 4.0 (PERF 4.5"Casing Guns; Oriented 180 deg.CCW Mandrel Inserts St ati On Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 2,919i 2,610.0 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,457.0 6/20/2013 SURFACE;41.7r.043a—.4 2 4,722.4 3,978.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2013 3 5,800.7 4,789.8 MMH FMHO 1 GAS LIFT GLV BK 0.188' 1,401.0 5/20/1994 GAS LIFT;4.722.4 mi. 4 6,564.0 5,371.3 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1994 5 7,238.9 5,893.9 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 6/20/2013 II Notes:General&Safety End Date Annotation GAS LIFT;5,800.7 10/6/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 I GAS LIFT.6,564.0II I I GAS LIFT;7,238.9 ' K:: �� SEAL ASSY;7,291.4 s PACKER;7293.8 .' NIPPLE;7,3169 ;i I SOS;7.328.6 11 APERF;7,390.0-7,410.0 I PERF:7,483.0-7,509.0�y PRODUCTION;39.4-7,756.0 • • -', /,1/0- rom a) c -a 0 N N L > .0 (p Q ate--+ +N-+ U a..+ M cu _ N a " 1 4-4 CO 0 OD Co a)o a, o N 4A C 0 u -C Ln c U 44- a) 0 .5.1.4 N a) -p t LL 'a v C a-+ O E 2 E v O L U 0- o N 13 (22 L-- a) i ca 0 i NQy_ tO Q C 4- 13 +.0 00 .� aO a 2 cdcN. Q >o W O 0 N w I- • M E �O C .c 2 W E cv _ F2 N 0 „,v) ,, C c� tao co +� U E Cu ( co 0 .N :v = E vi Ln = N N _ C 4%774. rn °' v — O I— a) a) 73 v o a) L N O - tto N ilo - •C O O N L OO O NZ " 4A L _ N `^ - �o o 0 ago �, N .N am c C col 0 • • S Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,July 5, 2017 2:47 PM To: sandeep.pedam@conocophillips.com Subject: Hydraulic Fracturing Application Sundry 317-301 2E-08 (PTD 1931890) Sandeep, We are reviewing the Frac stimulation sundry for 2E-08. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model use. Please provide. 20 AAC 25.283(a)(8) requires pressure ratings and schematics of wellbore, wellhead, BOPE, treating head. The application has a schematic of the Oil States tree saver but this has no rating? Possibly 15,000 psi? Please provide at your earliest so we can progress the sundry application. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday,July 10, 2017 1:39 PM To: Sandeep.Pedam@conocophillips.com Subject: KRU 2E-08: Hydraulic Frac Sundry Application Please provide the following information for the sundry application: 1. Please provide the legal description of the well (surface,top production interval and bottomhole locations) include township, range and section, and footage from section lines. 2. Discuss the principle horizontal stress orientation of the area. Which direction would the induced hydraulic fractures propagate? Based on mapping in the area,will the fracture wings extend into the faults or suspected faults? If the hydraulic fracture wings intersect faults or suspected faults,what would be ConocoPhillips' mitigation plan to halt fluid leakage into the fault zones(s)? 3. Discuss any occurrences of lost circulation in KRU 2E-08. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Wallace, Chris D (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Tuesday,July 11, 2017 4:30 PM To: Wallace, Chris D (DOA) Subject: RE: [EXTERNAL] Hydraulic Fracturing Application Sundry 317-301 2E-08 (PTD 1931890) Attachments: 2E-08 Frac Dimensions_2.pdf Chris, Please see answers to your questions below: 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model use. Please provide. Please see attached. 20 AAC 25.283(a)(8) requires pressure ratings and schematics of wellbore, wellhead, BOPE, treating head. The application has a schematic of the Oil States tree saver but this has no rating? Possibly 15,000 psi? Yes it is 15,000 psi. Thanks and have a nice day. Sandeep From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent:Wednesday,July 05, 2017 2:47 PM To: Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL] Hydraulic Fracturing Application Sundry 317-301 2E-08(PTD 1931890) Sandeep, We are reviewing the Frac stimulation sundry for 2E-08. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model use. Please provide. 20 AAC 25.283(a)(8) requires pressure ratings and schematics of wellbore, wellhead, BOPE, treating head. The application has a schematic of the Oil States tree saver but this has no rating? Possibly 15,000 psi? Please provide at your earliest so we can progress the sundry application. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • i Bettis, Patricia K (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Tuesday, July 11, 2017 4:30 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL] KRU 2E-08: Hydraulic Frac Sundry Application Patricia, Please see below: #1: Well 2E-08 Footages Location FNL FEL Township Range Section Meridian Surface 4600' 5119' T11N R9E 36 Umiat Top Open Interval 4533' 1245' T11N R9E 36 Umiat Bottomhole 4558' 1012' T11N R9E 36 Umiat #2: Based on regional analysis of borehole deformation from image logs and earthquake focal mechanisms,the principal horizontal stress in this area of the North Slope is believed to be between 330 and 335 degrees azimuth (NNW-SSE). If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic,well and other subsurface information currently available that the apparent faults will not interfere with containment. #3: 2E08 did not see any occurrences of lost circulation while drilling. Thanks and hope you have a nice day. Regards, Sandeep From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday,July 10, 2017 1:39 PM To: Pedam, Sandeep<Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL] KRU 2E-08: Hydraulic Frac Sundry Application Please provide the following information for the sundry application: 1. Please provide the legal description of the well (surface,top production interval and bottomhole locations) include township, range and section, and footage from section lines. 2. Discuss the principle horizontal stress orientation of the area. Which direction would the induced hydraulic fractures propagate? Based on mapping in the area,will the fracture wings extend into the faults or suspected faults? If the hydraulic fracture wings intersect faults or suspected faults, what would be ConocoPhillips' mitigation plan to halt fluid leakage into the fault zones(s)? 3. Discuss any occurrences of lost circulation in KRU 2E-08. 1 410 • Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 r c - C4 • • 1 `v L r ,- ~ T :Lir g 0 050 .Q > Z O NW N O }' 3 J r m L (0 > (13 I<-- L. of 0 D @ +,, (j) E Wp�S C a- r a- a- Tr OC y v O v U . r C c > N N C y Q .11 ui r r r ', Q./ O 6 m �3 l7 •I- L'' -E v u J a Go raO G W C rc u L a., HIA 01 < a- N NN N U -0 0 U Z v C Ql 0 C Q., , ro O r6 a: N Cui. 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E% _ .2 NE i J W 2 2 2 E raa < O J N M () N H Z N r 1" 'C jWc o.0rl = p N .ia! 0 C o. � QO..1 1- a aQ Ima~rojectWell History File Cover~e XHVZE This page identifies those items that were not scanned dudng the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J_~.~-/~ Well History File ldentifier Organizing (do,,e> RESC'AN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: DIGITAL DAT/~ [] Diskettes, No. [] Other, No/Type BEVERLY ROBIN~HERYL MARIA WINDY Project Proofing BY: BEVERLY ROBIN~ SHERYL MARIA WINDY Scanning Preparation C-~ x30: _/~ OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBI~ SHERYL MARIA WINDY Production Scanning Stage f PAGE COUNT FROM SCANNED FILE: [ ~'3 ~' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~ERE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: I$1 General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned,wpa Pagel Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, August 10, 2010 3:20 PM To: DOA AOGCC Prudhoe Bay Subject: FW: KRU 2E-05 MIT Exceptions follow-up inspection would be warranted Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~; k 1` > tE -a ~~5 t K2u ~ - ~~ ~ «~-_ ~ ~~ From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, August 07, 2010 2:34 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: KRU 2E-05 MIT Exceptions Jim, Initial action taken was to have corrosion inspections done on the well lines. All three well lines were inspected and all three have a pipe strength substantially above the strength required by the design pressure of the system Further actions are being taken to address the wellheads and fasteners. Those actions can or will include the following items as per well specific requirements: 1. Secure the well. 2. Abrasively clean the wellhead and associated piping to remove the current external corrosion. 3. Visual inspection by the Mechanical Engineer. If further evaluation needs to be done, it will be done at this time as well. 4. Paint the wellhead and valuing with a corrosion resistant type paint. 5. Replace any or all of the tree valves, casing head studs and nuts. This step will also repair insufficient bolt/nut engagement as well. 6. Evaluate on a case by case basis the replacement of any lockdown screws. Further mitigation ideas are being discussed in order to prevent this from reoccurring. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@al a.gov] Sent: Tuesday, July 27, 2010 12:25 PM To: NSK Well Integrity Proj; NSK Proble ell Supv Cc: DOA AOGCC Prudhoe Bay Subject: KRU 2E-05 MIT Excep ' ns Inspector's report attach for witnessed MIT 7-5-10. Please provide status of response to noted exceptions on wells -08, 2E-10, and 2E-15 8/10/2010 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 22, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 FEB 2 2005 Subject: Report of Sundry Well Operations for 2E-08 (APD # 193-189) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 2E-08. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J1l Jdg;r6 M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNEI>t FEB 2 8 2005 Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 147', Pad 106' GL 8. Property Designation: ADL 25658, ALK 2584 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONŠa&~:lì" Repair Well D Pull Tubing D Operat. ShutdownD Stimulate D Other Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development - 0 Stratigraphic D 193-189 6. API Number: 50-029-22428-00 Exploratory D Service D 9. Well Name and Number: 2E-08 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7775' feet true vertical 6319' feet measured 7543' feet true vertical 6134' feet Length Size MD 121' 16" 121' 3896' 9-5/8" 4043' 7607' 7" 7754' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3463' 6302' Measured depth: 7390'-7410',7483'-7509' true vertical depth: 6013'-6029', 6087'-6107' Tubing (size, grade, and measured depth) 2-7/8", L-80, 7329' MD. Packers & SSSV (type & measured depth) pkr= TIW '55' PERM pkr= 7294' Cameo TRDP-1A-SSA 1803' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS 8FL FEB 2 8 2005 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 627 1 741 1 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 121 95 CasinQ Pressure TubinQ Pressure 165 145 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Contact Printed Name Signature WDSPL D Mike Mooney @ 263-4574 4;;O¡~ Title Phone Wells Group Team Leader 907 -263-4574 Date <2/ 13/Ó5 Preoared by Sharon AI/suo-Drake 263-4612 ORIGINAL Submit Original Only Form 10-404 Revised 04/2004 2E-08 Well Events Summary ') ," Date Summary 02/12/05 DRIFTED TBG WI 15' X 2.125" STEM TO @ 7550' RKB, EST. 41' RATHOLE. [Tag] 02/13/05 PERFORATE INTERVAL 7390-7410 USING 2.00" HSD GUN LOADED 6 SPF 60 DEG. API CHARGE DATA: 2006 POWERJET HMX; PENETRATION: 18.6", ENTRANCE HOLE: 0.2". NOTE: TAGGED TD AT 7543'; WELL LEFT SHUT IN. TBG AND FLOWLINE FREEZE PROTD PER DSO INSTRUCTIONS. [Perf] MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: ,,.. Chuck Scheve; SUBJECT: Petroleum Inspector January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, January 28, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells and 18 components with one failure on 2D Pad and 5 wells and 10 components with one failure on 2E Pad; The Surface Safety Valve .on Well~ 2E-16 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. Earnie Barndt conducted the testing .today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at these'locations were clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2D & 2E Pads in'the Kuparuk River Field~ KRU 2D Pad, 9 wells, 18 components, KRU 2E Pad, 5 wells, 10 comPonents, 24 wellhouse inspections failure 5.56% failure rate 1failure 10% failumrate Attachment: SVS KRU 2D & 2E Pads 1-28-01 CS X Unclassified Confidential (Unclassified if doC. Removed) ..... SVS KRU 2D & 2E Pads 1-28.01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Prillips Operator Rep: ~amie Bamat "' AOGCC'Rep: Chuck Scheve Submitted By:' Chu~k Scheve Date: Field/Unit/Pad: Kuparuk ./KRU,/2D, PM, Separator psi: LPS .99 HPS 1/28/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GllNJ, Number Number psi PSI ,.Trip Code Code Code Passed GAS orCY,.C~.. 2D-01 1841710 '99 · 70 65 "P P OIL' 2D-02 1841520!. 2D-03 1841530' 2D-05 1841260 3750, 2000, ''1750 P 7 , wAG 2D-06B . 1981760 99 70! 55 ~' P P OIL 2D-07' 184i436 '~;750 2000 1850 '' e e ' ' ' ' 2D-68 184i270 ' . 99 " 70 .' 6'0 'P. P ' ' ' '0IL 2D-09 "184i03o 99 " ~0 .. ~5 P ' P ..... OIL 2D-10 1841010i 2D-11 1840990! 2D-12 1840940 · 99 ..70 · · 60 P P ', , OIL 2D-13.. 1840120 99 '70 60" p · P '" 0IL 2D-14. 1841590 · · · , , 2D-15 184'1600 99 70 "' ' 60 'P' P .' OIL · 'l 2D-16 184.1610 · ...... · . Wells: _ ,9 Components: 18 Failures: ,, 1 Failure Rate: 5.56% [] 9o Day Remarks: ,,~ufface, ,safety on 2D-05 not tested due a slow leaking wing valve Grove valve could be closed due to snow drffis. RJF 1/16/01 Page 1 of 1 SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phffiil~' Operator Rep: ,Earnie ,Brandt ' ' AOGCC Rep: Chuck Scheve Submitted By:. Chuck ~cheve Date: Field/Unit/Pad: KuPamk / KRU / 2E Pad Separator psi: LPS, , 9,9, lIPS 1/:28/01 Well Permit Separ Set L/P Test Test Test Date oik WAg, GmJ, · . Number Number PSI PSI, Trip Code Code Code Passed GAS or CYCLE 2E-07 1'9~1040 ' 2E-08 ~.~:,~8~0:~ 99 .70 60 "P' , 'P "' .' 2E-09 1842400 , , , 2E-10 .1842300 99 70 ' 60 P P 2E-11 . 1842260 99 70 50 · P ,P ' .", 2E-1'5 1841890 · 99 70 '50 .. P P · , 2E-'16' · .184i900 99 · 70 50 P 4 · . Wells: 5 Components: 10 Failures: 1 Failure Rate:· '10.00o/13 9o my RemarkS: Surface safety on 2E-16 had slow, 1,e.ak when pressure tested. Valve will be serviced a retested bY operator. , .... RJF 1/16/01 Page 1 ofl SVS KRU 2E Pad 1-28-01 CS.xls AOGCC Individual Well ~eological Materials Inventory PERMIT DATA 93-189 '~6042 93-189 ~07 / 93-189 JDAILY WELL OP 93-189 ~/SURVEY 93-189 v~fDN- LWD/DC 93-189 ~BT T DATA_PLUS T 3932-7775, OH-CDR/CDN J COMP DATE' 03/15/94 R 12/08/93-03/15/94 R 0-7775, GCT (2) L 3740-7030 L 6400-7616 93-189 ~CDN-LWD/DC L 6880-7740 93-189 ~DR-LWD/DC L 6870-7740 93-189 ~<~DR-VER/LWD/DC L 6900-7740 93-189 ~AB-LWD/DC L 4015-7030 93-189 ~SIT (C&C) L 6400-7645 Page- 1 Date: 10/13/95 RUN DATE_RECVD CMPS 03/21/94 04/15/94 04/15/94 01/31/94 1 03/21/94 1 01/11/94 3 03/21/94 3 03/21/94 3 03/21/94 1 03/21/94 1 01/11/94 Are dry ditch samples required? yes no And received? yes no Was the well cored? ~ ~/A~alysis & description re~ no Are well tests required? .yes ~kQ~Recei ~v~ no Well is in compliance ~ ~ Initial COMMENTS - ' STATEOFALASKA M!~~ ALASKA OIL AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Sen/ice Well OIL ~] GAS E~ SUSPENDED ~ ~ ,~I~Np~I~ ! ~ SI~RVICE [--'-I 2 Name of OperatorU ! 7 Permit Number ARCO Alaska, Inc 93-189 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~ 50-029-22428 4 Location of well at surface ~;~r~,i~,~ i O:'~ ~ [OC..,~]"J(;~I~ 9 Unit or Lease Name 680' FSL, 160' FWL, SEC 36, T 11N, R 9E, UMt ~.~ ~/~.J' :?' ~ ~_ ~ KUPARUK RIVER At Top Producing Interval ~ --/-~ u~'- .--.~_.,Z.~ ~ 110 Well Number 611' FSL, 1247' FEL, SEC 36, T11N, R9E, UM i ....~--'~V'~--~--_'~ 2E-08. At Total Depth~-- ........ ___,_,, . / 11 Field and Pool [ /_-I~' FSL, 1012' FEL, SEC 36, T11N, RgE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 147', PAD 106' GL ADL 25658 ALK 2584 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore J16 No. of Completions 07-Dec-93 11-Dec-93 03/15/94(COM P)I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 7775' MD, 6319' TVD 7665' MD, 6231' TVD YES X~ NO [~I 1803' feet MD 1500' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CBT, USIT, HNGS, CNT-G, IPLT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 S U R F 121' 24" 200 SX C MT 9.625 36# J-55 SURF 4043' 12.25" 700 SX ASIII, 500 ex G 7. 26# L-80 SURF 7754' 8.5" 210 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and , 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 6.5# L-80 7329' 7294' 7483'-7509' 4 SPF MD 6087'-6107' TVD 26 ACID, FRACTURE; CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE i~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *To be sent under separate cover by Development Geology. APR 9 1994 /~ss~,s L~[t & Gas Cons. Comaiss'ton Anchorage ,,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 2"§~ 30. · GEOLOGIC ~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 7387' 6011' NA BASE OF KUPARUK C 7387' 6011' TOP OF KUPUARK A 7459' 6068' BASE OF KUPARUK A 7588' 6170' : ,, 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY' 32. I hereby certify that the foregoing is true and correct to the be'st of my'kn0wle~]el " --~//', f. - #, s · 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 det.ails'6i'any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Page 1 Kuparuk 2E-08 Percussion Sidewall Core Descriptions Descriptions in Anadrill Trailer and geologist can't smell well (sick) Lighting conditions - poor fluorescent lights SWCs - difficult to determine 0 w/o breaking plugs Int. Depth Shows Description ,,. C4 7388 ~ Trace ! Sandstone, up fine to med-gr, mod. well sorted, green glau, siderite-cemented, i I grayish green w/brownish tint on scattered grains. Weak odor; trace brown ! stain. Very weak to no fluor, very spotty, brown. Poor porosity. Colorless cut; i i..very weak, pale yellow,. ..slow stream cut fluor. Light brown ring. . C4 7389 Trace i Sandstone, up. fine-med, glau (green), siderite-cemented as above. Poor to ~ i fair porosity. Greenish gray. Slight odor, light brown, irregular stain. No fluor; i ; colorless to pale straw cut; weak pale yel, streaming cut fluor/crush cut. Light i ! b.r. ow. n_.~g..__ ___ C4 7390 ~ Poor i Sandstone, upper fine- to'meal, gr., glau (green), $id cemented, as above. Mod i i ~. Mod. odor, brown uneven stain; very weak, to none, dull gold scattered i ~l_u~ale straw cut; weak ~al__e..¥eh stream!n.g cut~!~h~t brown ring. C4 7391 i : '"' i no recove .ry C4 7392 .... no rec~0_~ C4 7393 Fair Sandstone, upper fine- to lower medium-grained, mod. well sorted, glauconitic (green), siderite-cemented, greenish-gray w/local dark brown to black stain. Poor porosity. Slight odor, spotty black stain, trace yel-gold fluor; dark straw ....... ~ ............. - .......... .......... ~. c~_t~.. ~t..~?.a_rn_jn_g_; re_od..e ~r~te~.,_~__a.!_e_ ~el!~_w_._w_h_ite_._s~r_ea_~.i..n~g cut.. fiugr..e.~cen_9..?~ C4 7394 Fair . Sandstone, upper fine- to lower medium-grained, mod. well sorted, glauconitic (green), siderite-cemented, greenish gr.ay w/brownish tint on grains of qtz. : Moderate hydrocarbon odor, pinpoint spotty brown stain on qtz grains (wet · i appear.); v. weak, spotty, brownish fluor? to none; dark straw cut; moderately . strong, pale yellow, streaming cut fluorescence. Sticky, fluor, brown ring upon solvent extraction. Porosity unclear 5%-1' 0%? 04 7395.1 -;~ ......... 9~.r~.c_o...v e.r~ C4 7396 ~ Fair : Sandstone, upper fine- to lower medium-grained, mod. well sorted, glauconitic ~ (green), siderite-cemented, greenish gray w/minor brownish tinge. Moderate ~ !hydrocarbon odor, pinpoint spotty brown stain; weak, spotty, dull gold :. ~ fluorescence; straw cut; streaming (slow), pale yellow, moderate cut fluor. ~ Porosity...l~_O%~z~,_Stic~.,,~f!~uor.--, b_ro_w.~n r_.~.n_g u_jpon solvent extraction. 04 7397 ~ Poor ' Sandstone, up. fine to lower med, mod well sorted, green glau, siderite- · ~' cemented, greenish gray w/oil stain. Poor porosity. Moderate (in bottle) to ~ slight odor, uneven dark brown stain on grains; very weak dull brownish gold, ! scattered fluor; straw cut; weak pale yellow, slow stream cut fluor.. Weak I. ......................... - ..................... RECEIVED APR 1 9 1994 0[1 & Gas Cons. O0mmissi0r~ Anchorage DCS-JIZ/702 Page 2 7398 7399' 74OO 7400 Poor Good Sandstone, up. fine to med. grained, mod. well sorted, green glau, siderite- cemented, greenish gray w/minor brown stain on glau and other surfaces. Poor porosity. Weak odor; brownish wetness on scattered grains; v. weak to no fluor, dull brownish gold; crush cut fluor, pale straw to colorless, very weak pale yel white. Sandstone, up fine- to reed-gr., mod-well sorted, green glau., siderite-cemented with minor intercrystalline tar, and tar in glau. rims (more common); greenish gray w/brown staining. Porosity poor. MOd. odor; dark brown scattered stain (b/w grains, on grains, glau. grain rims),. Even, moderate, dull gold fluor; light amber immediate cut; streaming,.,.pale yel.cut fluor. St____~r..o_n~q light hr.o. W, n ring, ~_ .... mudcake Trace Sandstone, up. fine to lower med. grained, green glau, siderite-cemented, mod. well sorted, light greenish gray, poor ~. Trace light brown oil stain; slight odor; very weak, dark brownish gold fluor, spotty; colorless cut; very weak pale ........ y~II_._°.~?u§.h C~! ~f!~.o_.r~...scen~__ ~c.e_:. ................................................ 7401 Trace Sandstone as above (74,00). w/patchy dark brown oil residue, Slight to locally moderate odor; no fluor to very weak as above; light amber cut; moderate, pale .......... ¥~[!o_~.y?.ry_ slow saturated cu_t_f!u__o_r_.~.l_~t_b_r.o_wn rin~ 74O2 Trace ~ Sandstone, up. fine to lower med grained, green glau., std. cemented. Poor ~ ,~ Light brownish to brown, greenish gray. Weak odor, weak, dull acid. even .............. ?i~._oi_n~._fluor; colorless cut, no cut fluor, weak brown ring. 74O3 74O4 74O5 Fair Sandstone as at 7402 w/weak odor; weak, but obvious dull gold even pinpoint fluor. Local patchy black oil residue (no-fluor). Straw cut; mod, pale yellow, .......... ~.. s~t~re~m_ing_~ut fJ~9_r~,._~jg .ht..~.r~0w~ ..~ri_ng· Fair-Good Sandstone, up, fine-med gr sandstone, mod, well sorted, glau, aid cemented in part, unclear ~ as oily substance b/w grains. Light olive gray to dark gray/black. Mod. odor, uneven to spotty oil/tar stain,, light brown to black; dull gold, spotty (non-tarry zones) fluor; dark straw to amber cut, immed, saturated, .. moderate, pale. yellow., c~t .f!.u. ~r. Good Sandstone I to upper med.-grained to very coarse, mod well sorted, aid cemented, glau, porosity is fair (-10%), light olive gray to black. Moderate odor, even (in pore space) black stain/residue; moderate, scattered (pores), gold fluorescence; amber cut, saturated; mod. strong, yellow, saturated cut fluor. Dark brown rim. 74O6 Fair-Good , Sandstone, up. med to lower coarse grained (to granule tr), moderately sorted, · glau (green), siderite cemented in part, light greenish brown and light brown !(10% porosity) & I. very fine-grained sandstone (LCU contact w/B). Chert i pebbles, white (micro ~ chert too?). Light brown stain, mod odor; weak, spotty :dull gold fluor; light amber cut, moderate, streaming, light yellow cut fluor. ~ Brown rin~]. Same show for "B" sandstone. 74O7 Good Sandstone, upper very fine-grained, well sorted, quartzose, light brown 15%- .20% porosity. Light brown even stain; no fluorescence ~; light amber cut; fast ................ ~_~t_r..~._m_i~gg,_.~e_!~_t~e_st__rong,_p_a__l_e. y ellow cut f~u_ o_.r_e, sc~..n_c~, brown_d__n~_ B unit. 7408 Trace-Nil ~ Siltstone, clayey, well sorted, light brown; light brown stain; weak odor; trace, :very weak, dull brownish gold fluor; dark sh~w,.cj~;r~e~,rsti~aming, pale DCS-JIZ/702 APR ] 9 'i994 A~ska 0il & Gas Cons. Commission Anchorage A5 7482 Good ' Sandstone, very fine (I - u) grained, well sorted, quartzose, light brown; strong odor; light brown, even stain; no fluor; light amber cut; immed streaming, light .................... yel cut flu~r_;_b..r_o.._w.n- ._ri_ri. g._. A5___int_e~al_. A5 7483 Good Sandstone, lower very fine-grained, well sorted, quartzose, good O, soft. Even ' brown staining. Mod oil odor; weak dull gold fluor; light amber cut, immediate, , + ........ streamin~.s, aturated, light yellow cut fluor., light brown ring. A5 interval..... . · A5 7484 : Good ' Sandstone, lower to upper very fine-grained, well sorted, quartzose, soft, good i I porosity. Light brown even oil staining; mod. oil odor; no obvious fluor; light ~ ' amber cut; immediate streaming/saturated, light yellow cut fluor; light brown ..... i .... ~Lr_in_g. ~.A5 interval. ... __A5 _ -748.5_ i .... ~ not recovered · A5 7486 ~ Good Sandstone as 7487. A5 interval. A5 7487 ; ......... ~ ....... i.__S_.a.~d__~tP~.e a~ a..bo, ve,...!!g.h_t.~m._b_e_r_~ut__... ~5.}.n_t.e..rva_l~ A5 7488 ; Good Sandstone as 7489, 7494; same show light amber cut. A5 interval. .... ,A_~_ ....... ..7~_8...~ ..... ~0 ~o~1_....'.._S~_d_s..t.0ne~a..§ ~492;- ~.~..s_.h..o..~.~b.~.t_d_~.!l_e(. ~!_u.p_r._li_g~.h_t ,amber cut. A5 interval, A5 ...... -~-4~9-2 ....... i ..... F~i[ .... Sap.d~.t~ne..a~.7493_,.~9_~;.~__m.e_~sbo~:.....A_.5_i~t.e__~a__l:_ .,A5_ ......... .779__3~ ...... i ......... F~i_r .... .S,.a~..d.s,.t.o..~n~.~s. 7494,. ~e...c_.ut_,_~.hg~..e.!~:. A.5 inte.~9_l~ A5 7494 : Fair Sandstone, very fine-grained, well sorted, quartzose, light brown; 15% porosity good; mod strong odor; light brown even stain; dull brownish gold fluor, even; ...... d_~r~..s.~t,r~_,,.cut.;, pale..yel!0.?_,.,~_e..a~..m_i_n_~g.~c~u_t.~!u_0r.; .brP~,.w_q. ri~.g:...._A~.inte_n~.a_l: .......... A5 7495 : Fair ' Sandstone as 7496; mod strong odor; even light brown stain, dull gold / light . brown fluor?; cut as above except dark straw cut, A5 interval, '. A5 7496 Good :~ Sandstone, very fine-grained (u-I), well sorted, quartzose, light brown; mod strong odor; light brown even stain; no fluor (light brown?), immed cut light ' amber; pale yellow cut fluor, streaming; brown ring. A4 7576 Good Sandstone, very fine grained, well sorted, quartzose, light brown; mod. strong odor; light brown, even stain; even dull gold fluor; light amber cut; streaming, ....................... p~l,e.~y.~!~l~w..~ut fluor;, br~.~.ri.n,..g~ A4 7578 Good Sandstone very fine (I-u) grained, well sorted, quartzose, light brown; mod strong odor; light brown, even stain; no fluor; light amber cut; streaming, pale yellow cut fluor, mod stron~l; brown final, A4 interval, R£C£1V£D APR ] 9 i994 0[1 & Gas Cons. Commission Anchorage DCS-JIZ/702 ARCO ALASKA INt. DAILY OPERATIO~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2E-08 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25658 ALK 2584 50-029-22428 93-189 ACCEPT: 12/07/93 07:00 SPUD: 12/07/93 12:00 RELEASE: 12/15/93 04:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 03/15/94 RR 12/08/93 (1) PARKER 245 TD: 4060'( o) CIRC 8 TD 16"8 121' MW:10.5 VIS: 52 MOVE RIG TO 2E-08. NU DIVERTER. FUNCTION TEST DIVERTER-TEST ACCUM-FILL STACK-CHECK F/LEAKS. PU BHA-ORIENT TOOLS-C/O COND F/75'-121'. DRILL F/121'-372' SERV RIG & TOP DRIVE. DRILL 12.25" HOLE F/372'-4060'. 12/09/93 (2) PARKER 245 TD: 4060'( o) INSTALL WEAR BUSHING 9-5/8"8 4043' MW:10.6 VIS: 44 COND & CIRC MUD. SHORT TRIP TO HWDP-TIGHT. CIRC 8 4060'-COND MUD & HOLE. 'POOH. LD BHA. RU TO RUN 9-5/8" CSG-HOLD SAFETY MEETING. RUN 9-5/8" 36# J-55 CSG-BREAK CIRC 8 2000'. MU HGR & LJT, LAND CSG. SHOE SET 8 4043'. CIRC. FLUSH CMT LINE W/15 BBLS FW-TEST TO 3500#-DROP BTM PLUG-PMP 100 BBLS PREFLUSH. PMP 700 SX LEAD CMT & 500 SX TAIL CMT-FLUSH W/30-5.6 BBLS. BMP PLUG W/2000#-FLOATS HELD. CIP 8 0010 HRS 12/09/93. RD CMT HEAD, LJT. ND DIVERTER. MU SPEED HEAD. NU BOPE. RU TEST PLUG. TEST BOPE TO 300/3000 PSI. RD TESTING TOOLS, SET WEAR RING, BLOW DN CHOKE MANIFOLD & KILL LINE. 12/10/93 (3) PARKER ', 245 TD: 7033' (2973) TOH TO CHANGE BHA 9-5/8"@ 4043' MW: 9.0 VIS: 34 CUT DRILL LINE PU & ORIENT BHA, TEST @ HWDP-TIH. BREAK CIRC-TEST CSG TO 2050 PSI.. DRILL PLUGS, CMT, PLUGS, & 10' NEW FORM TO 4070'. CBU. EMW=730 PSI W/8.5 PPG MUD=12.5 PPG. DRILL 8.5" HOLE F/4070'-5258' SERV RIG & TOP DRIVE. DRILL 8.5" HOLE F/5258'-7033' CBUi TOH TO CHANGE OUT BHA. 12/11/93 ( 4) PARKER 245 TD: 7391' ( 358) DRILLING 8.5" HOLE 9-5/8"8 4043' MW:ll.3 VIS: 47 LD LWD, MWD, & TURBINE. PU LWD, TIH-BROKE CIRC 8 9-5/8" SHOE. BROKE CIRC-REAM F/6910'-7018' F/LWD LOG. CIRC & COND MUD W/LCM & WT UP TO 11.3 PPG. MONITOR WELL-NO FLUID LOSS-REAM F/LWD LOGS F/7018' TO/7033'. DRILL 8.5" HOLE F/7033'-7391' 12/12/93 ( 5) TOH-LD BHA 9-5/8"@ 4043' MW:ll.2 VIS: 44 PARKER 245 TD: 7391' ( 0)' DRILL F/7396'-7403'. CBU. NO GAS OR LESS. DRILL F/7403'-7565' DRILL 8.5" HOLE F/7565'-7775'. POOH. TIGHT F/7590'-7400' CUT DRILL LINE 260' RESET CROWN 0 MATIC. SERV RIG & TOP DRIVE. TIH-NO TIGHT SPOTS. CIRC & COND MUD. DROP SURV. PMP PILL. TOH. LD BHA. APR ] 9 1994 0i~ & Gas Cons. Commission Anchorage WELL: '2E-08 API: 50-029-22428 PERMIT: 93-189 PAGE: 2 12/13/93 ( 6) PARKER 245 TD: 7775' ( 384) 12/14/93 ( 7) PARKER 245 TD: 7775'( o) 12/15/93 (8) PARKER 245 TD: 7775'( o) 12/17/93 (9) DOWELL TD: 7775 CIRC & COND MUD 9-5/8"@ 4043' MW:ll.2 VIS: 48 TOH-RETRIEVE SURV & RA SOURCE. RU WL-PU LOGGING TOOLS. SCHLUMBERGER RUNNING DITE, CNTG, IPLT, & NGT LOG. TAG BRIDGE @ 7330'. AD LOGGING TOOLS-PU SIDEWALL CORE GUN. IH W/WL-B ~'. ATTEMPT TO WORK THROUGH BRIDGE. ~~7~"~OOH W/WL. LEFT 5 SHOTS & BULLNOSE IN "~~'~ TOP DRIVE. THAW OUT LINK TILT CYLINDERS ON TOP DRIVE. MU BHA-INSTALL RA SOURCE & RIH-BREAK CIRC @ 4000'. FILL PIPE @ 6900'-BEGIN REAM F/LWD LOGS @ 6900' REAM 6900'-7360' F/LWD LOG F/7360'-7465' @ 60'/HR, F/7465'-7500' @ 250'/HR, F/7500'-7565' @ 100'/HR, F/7565'-7630' @ 250'/HR. CIRC & COND MUD ON BTM. POH/LD DP 9-5/8"@ 4043' MW:ll.2 VIS: 48 PMP & ROTATE 5 STDS OUT OF HOLE, TIGHT & PACKOFF @ 7410'. RIH. NO TIGHT SPOTS. ATTEMPT TO RETRIEVE RADIO ACTIVE SOURCE F/LWD, JAMMED, RU EMER SHIELDS, DOWN LOAD INFO. LD TOOLS W/RADIOACTIVE SOURCE' RU SWS & RUN SW CORES, BRIDGE @ 7600', CORE F/7578'-7396'. POH, RD SWS. SERV RIG & TOP DRIVE. RIH F/WIPER TRIP, BREAK CIRC, BRIDGE @ 7720' REAM F/7700'-7765'. CIRC & COND MUD F/CSG. PMP FIRST FIVE STDS OUT OF HOLE. POH, LD DP & HWDP. RIG RELEASED 7"@ 7753' MW: 0.0 VIS: 0 FIN POOH. LD DP & BHA. RU CSG EQUIP & HOLD SAFETY MEETING. RUN 7" CSG. TOTAL OF 179 JTS 26# L-80 BTC/MOD. RECIP W/FULL RETURNS. CMT W/210 SX CLASS G CMT. BMP PLUG TO 3500 PSI. BLEED PRESS & CHECK FLOATS, FLOATS NOT HOLDING. RELAND PLUG & SHUT IN WELL. WOC. BEGIN TO ND STACK & CLEAN PITS. RD CMT HEAD & MAKE ROUGH CUT ON 7" CSG, LD LANDING JT. RD CSG EQUIP. ND BOPE. TEST WELL HEAD TO 3000 PSI & FREEZE PROTECT. RELEASE RIG @ 0400 HRS 12/15/93. PREPARE FOR RIG MOVE. 7"@ 7753' PERFORM ARCTIC PACK JOB ON 2E-08. 03/14/94 (10) NORDIC 1 TD: 7775 PB: 7665 RU TO RIH W/GR & JB 7"@ 7753' MW:ll.3 NaCl/Br MOVE RIG F/2E-07 TO 2E-08, ACCEPT RIG @ 0300 HRS 3/14/94, ND TREE & NU BOPE, TEST BOPE TO 3000 PSI, PRESS ANNULUS TO 3500 PSI; & HOLD F/30 MIN F/TEST, RU SCHLUMBERGER W-LINE & RIH W/4-1/2" PERF GUNS, PERF F/7503'-7509' @ 187 DEG CCW THEN F/7483'-7503' @ 182.5 FOR TOTAL 26', ALL SHOTS 4 SPF 90' PHASING, POOH WELL: 2E-08 API: 50-029-22428 PERMIT: 93-189 PAGE: 3 03/15/94 (11) NORDIC 1 TD: 7775 PB: 7665 RIG RELEASED 7"@ 7753' MW:ll.3 NaC1/Br MU 6" GR & JB W/SWS & RIH TO 7600', POOH, MU TIW PKR & TAIL ASSY ON SETTING TOOL & RIH ON E-LINE, SET PKR @ 7294' WLM, POOH, RD SWS, RU FLOOR EQPT F/ RUNNING TBG, NU FLOW RISER, MU TIW LOCATOR & RIH W/2-7/8" TBG COMPLETION STRING AS PER TBG DETAIL, PU CAMCO SSSV, ATTACH CONTROL LINE & TEST TO 5000 PSI, CONTINUE TO RIH W/2-7/8" TBG PLACING SS BANDS ON C LINE EVERY OTHER JT TO SURFACE, STING INTO PKR & VERIFY SEALS. SPACE OUT W/TBG PUPS, MU TBG HGR & ATTACH C LINE, TEST CONNECTION TO 5000 PSI F/10 MIN, LAND TBG HGR & LOCK DOWN SAME. TEST SSSV W/500 PSI DIFFERENTIAL F/15 MIN. PRESS TBG AND ANN TO 2500 PSI F/PKR TEST, HOLD 15 MIN, INCREASE TBG PRESS TO 3000 PSI TO TEST LOCATOR SEALS, HOLD 15 MIN, INCREASE TBG PRESS TO 3800 PSI & SHEAR OUT BALL IN SOS. RD LDG JT & SET BPV, ND FLOW RISER & BOPE, NU TREE, PULL BPV, INSTALL TEST PLUG, & TEST TREE & PACKOFF TO 5000 PSI, PULL TEST PLUG & OPEN SSSV, FREEZE PROTECT WELL BY DISPLACING ANN W/14 BBLS DIESEL & BULLHEADING TBG W/3 BBLS, BULL HEAD @ 2 BPM & 175~ PSI, SET BPV W/LUB, SICP = 0 PSI, SITP = 50 PSI, DRESS OUT TREE W/CAP & GAUGES, MOVE OFF WELL AND CLEAN AREA **** RIG RELEASED @ 0330 HRS 3/15/94 **** SIGNATURE: DATE: RECEIVED APR I 9 1994 AJ~ska Oil & Gas Cons. Cornmissio~ Anchorage ORIGII iAL $UB.~URFACE DIRECTIONAL I~UIDANCE I~ONTINUOUS IOOL ~URVEY RECEIVED APR 1 9 1994 Atgska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 2E-08 (680'FSL,160'FWL,SEC.36,T11N,R9E,UM), FieldlLocation KUPARUK, NORTH SLOPE, ALASKA Job Reference NO,. 94008 F ORN ! CA. Date 21-DEC-1993 Computed By: SINES . SCHLUIVlBEROER · ~CT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 21-DEC-1993 ENGINEER' FORMICA METHODS OF COMPUTATION TOOL LOCATION- MINIMUM CURVATURE INTERPOLATION' LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 89 DEG 33 MIN EAST COMPUTATION DATE' 18-JAN-94 PAGE ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 21-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 0.00 -147 O0 99 93 199 93 299 93 399 93 499 93 599 93 699 93 799 92 899 89 -47 07 52 93 152 93 252 93 352 93 452 93 552 93 652 92 752 89 0 0 N 0 0 E 0 16 S 15 5 W 0 17 S 16 6 W 0 16 S 20 59 W 0 16 S 18 48 W 0 18 S 12 3 W 0 21 S 14 46 W 0 21 S 14 54 W 0 35 S 37 9 E 2 25 S 79 3 E 0 O0 -0 09 -0 21 -0 36 -0 51 -0 65 TO 78 -0 92 -0 82 I 27 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 0 O0 0 02 0.00 N 0.22 S 0.67 S 1.12 S 1.58 S 2.05 S 2.60 S 3.17 S 3.86 S 4.77 S 000 E 0 09 W 021 W 0 37 W 053W 0 67 W 080W 0 95 W 085W 1 23 E OO0 N O 0 E 24 S 23 10 W 70 S 17 29 W 18 S 18 10 W 66 S 18 27 W 15 S 18 7 W 72 S 17 6 W 31 S 16 37 W 95 S 12 23 W 93 S 14 27 E 1000.00 1100.00 1098 1200.00 1196 1300.00 1293 1400.00 1388 1500,00 1482 1600.00 1574 1700.00 1664 1800.00 1750 1900.00 1834 999 62 82 951 98 1049 73 1146 90 1241 72 1335 66 1427 05 1517 81 1603 63 1687 852 62 5 47 82 8 58 98 12 53 73 16 23 90 19 1 72 21 34 66 25 0 05 28 20 81 31 42 63 34 30 S 89 9 E N 88 25 E N 87 1E N 86 11E N 86 13 E N 85 59 E N 86 35 E N 87 58 E N 89 2 E S 89 2 E 8 34 20 92 39 84 65 03 95 60 130 10 169 28 214 O0 263 67 318 18 0 O3 0 03 0 04 0 04 0 03 0 02 0 03 0 04 0 03 0 03 5.21 S 5.14 S 20 4.34 S 39 2.80 S 65 0.77 S 95 1.60 N 130 4.24 N 169 6.34 N 214 7.59 N 263 7.60 N 318 88 E 21 81E 40 O1E 65 60 E 95 11E 130 31E 169 06 E 214 74 E 263 25 E 318 8 29 E 9 79 S 57 53 E 50 S 76 10 E 04 S 83 46 E 07 S 87 32 E 60 S 89 32 E 12 N 89 18 E 37 N 88 34 E 15 N 88 18 E 85 N 88 21E 34 N 88 38 E 2000.00 1915.49 1768 49 37 33 2100 O0 1992 94 1845 2200 2300 2400 2500 2600 2700 2800 2900 O0 2068 O0 2144 O0 2219 O0 2294 O0 2369 O0 2444 O0 2520 O0 2595 70 1921 18 1997 37 2072 34 2147 32 2222 54 2297 13 2373 56 2448 94 40 34 70 40 51 18 41 8 37 41 20 34 41 34 32 41 24 54 41 2 13 40 52 56 41 11 S 89 8 E S 89 47 E S 89 45 E S 89 19 E S 89 3 E S 88 59 E S 89 7 E S 88 58 E S89 5 E N 88 56 E 376 99 440 23 505 49 571 09 637 02 703 20 769 36 835 25 900 72 966 36 0 O3 0 O3 0 02 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 0 01 6 57 N 377 06 E 377.11 N 89 0 E 6 04 N 440 5 74 N 505 5 17 N 571 4 17 N 637 3 04 N 703 1 96 N 769 0 86 N 835 0.34 S 900 0.17 S 966 29 E 440.33 N 89 13 E 55 E 505.69 N 89 21 E 15 E 571.17 N 89 29 E 07 E 637.08 N 89 38 E 24 E 703.25 N 89 45 E 40 E 769.40 N 89 51 E 28 E 835.29 N 89 56 E 74 E 900.74 S 89 59 E 39 E 966.39 S 89 59 E 3000 O0 2670 89 2523 89 40 53 3100 3200 3300 3400 3500 3600 3700 3800 O0 2746 O0 2821 O0 2897 O0 2973 O0 3049 O0 3126 O0 3203 oo 3280 43 2599 80 2674 47 2750 53 2826 78 2902 34 2979 38 3056 63 3133 43 41 8 80 40 57 47 40 37 53 40 22 78 40 14 34 39 52 38 39 30 63 39 49 3900.00 3355.95 3208.95 41 50 N 89 3 E 1032 10 N 89 16 E 1097 N 89 29 E 1163 N 89 27 E 1228 N 89 11E 1293 N 88 56 E 1358 N 88 51E 1422 N 88 33 E 1486 N 89 8 E 1549 S 89 16 E 1615 61 32 70 60 28 59 32 79 56 0 01 0 01 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 o ol 0 01 1.00 N 1032 14 E 1032 14 N 89 57 E 1.96 N 1097 2.69 N 1163 3.28 N 1228 3.98 N 1293 5.11N 1358 6.31N 1422 7.68 N 1486 9.04 N 1549 8.85 N 1615 66 E 1097 38 E 1163 76 E 1228 67 E 1293 36 E 1358 69 E 1422 42 E 1486 gl E 1549 68 E 1615 67 N 89 54 E 38 N 89 52 E 77 N 89 51E 68 N 89 49 E 37 N 89 47 E 70 N 89 45 E 44 N 89 42 E 94 N 89 40 E 70 N 89 41E ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION, DATE: 18-JAN-94 PaGE 2 DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000 O0 3430.66 3283 66 41 32 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3505.92 3358 O0 3581.13 3434 O0 3656.46 3509 O0 3732 09 3585 O0 3807 87 3660 O0 3883 96 3736 O0 3960 65 3813 O0 4037 51 3890 O0 4113 06 3966 92 41 11 13 41 15 46 4O 53 og 40 49 87 40 36 96 40 18 65 39 43 51 40 2 06 41 27 5000 O0 4188 O0 4041 O0 41 27 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4262 O0 4337 O0 4412 O0 4487 O0 4562 O0 4638 O0 4713 O0 4789 O0 4864 96 4115 95 4190 94 4265 93 4340 go 4415 02 4491 63 4566 25 4642 89 4717 96 41 27 95 41 24 94 41 25 93 41 25 go 41 27 02 40 57 63 40 51 25 40 52 89 40 52 6000 O0 4940 52 4793 52 40 51 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5016 O0 5091 O0 5167 O0 5244 O0 5322 O0 5399 O0 5475 O0 5552 O0 5630 20 4869 95 4944 93 5020 96 5097 02 5175 02 5252 94 5328 88 5405 07 5483 20 40 49 95 40 44 93 40 15 96 39 25 02 39 44 02 39 36 94 39 53 88 39 31 07 39 31 7000 O0 5707.44 5560 44 39 16 7100 7200 7300 7400 7500 7600 7700 7775 O0 5784 98 5637 O0 5863 16 5716 O0 5942 11 5795 O0 6021 15 5874 O0 6100 02 5953 O0 6179 31 6032 O0 6258 93 6111 O0 6318 61 6171 98 38 55 16 38 8 11 37 50 15 37 55 02 37 47 31 37 16 93 37 17 61 37 17 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLFrH EAST/WEST DIST. AZIMUTH DEG MIN FEET S 89 29 E 1682 03 N 89 46 E 1747 N 89 41E 1813 N 88 25 E 1879 N 88 6 E 1944 N 87 23 E 2010 N 88 5 E 2074 N 87 28 E 2138 N 88 14 E 2202 S 88 53 E 2268 87 77 52 89 O7 87 98 87 37 DEG/IO0 FEET FEET FEET DEG MIN 0 O1 0 O1 0 O0 0 O1 0 O0 0 O1 0 O0 0 O1 0 O1 0 O1 8.09 N 1682 15 E 1682 17 N 89 43 E 8.00 N 1747 8.28 N 1813 9.26 N 1879 11.39 N 1945 13.84 N 2010 16.61N 2075 19.12 N 2139 21.81N 2203 21.56 N 2268 99 E 1748 89 E 1813 65 E 1879 04 E 1945 24 E 2010 06 E 2075 20 E 2139 11E 2203 61E 2268 01 N 89 44 E 91 N 89 44 E 67 N 89 43 E 08 N 89 40 E 28 N 89 36 E 13 N 89 32 E 28 N 89 29 E 21 N 89 26 E 71 N 89 27 E S 88 55 E 2334 58 S 88 51 E 2400 76 S 88 47 E 2466 92 S 88 49 E 2533 06 S 88 48 E 2599 22 S 88 53 E 2665 38 N 88 49 E 2731 39 N 88 26 E 2796.79 N 88 25 E 2862.18 N 88 21 E 2927.56 N 88 23 E 2992.93 N 88 26 E 3058 26 N 88 25 E 3123 SO N 88 9 E 3188 47 N 85 56 E 3252 09 N 85 0 E 3315 59 N 84 46 E 3379 10 N 84 38 E 3442 69 N 84 26 E 3506 22 N 84 10 E 3569 42 N 84 6 E 3632 40 N 85 4 E 3695 N 88 46 E 3757 S 87 1E 3818 S 84 24 E 3879 S 84 16 E 3941 S 83 37 E 4001 S 83 11E 4061 S 83 11 E 4107 20 40 75 85 07 73 92 O7 0 O1 0 01 0 O0 0 O0 0 O0 0 O0 0 O1 0 O1 0 01 0 O0 0.00 0. O0 0. O0 0. O0 0.01 0.01 0.01 0. O0 O. O0 0. O0 0. O0 0.01 0.01 0.02 0.02 0.01 0.01 0. O0 0. O0 20 29 N 2334 81E 2334 90 N 89 30 E 19 17 16 14 13 12 14 16 18 O0 N 24OO 59 N 2467 lg N 2533 81N 2599 45 N 2665 91N 2731 61N 2796 40 N 2862 26 N 2927 99 E 2401 13 E 2467 27 E 2533 41E 2599 57 E 2665 57 E 2731 99 E 2797 40 E 2862 79 E 2927 06 N 89 33 E lg N 89 35 E 32 N 89 38 E 46 N 89 40 E 60 N 89 43 E 60 N 89 44 E O3 N 89 42 E 45 N 89 4O E 85 N 89 39 E 20 15 N 2993.18 E 2993 25 N 89 37 E 21 23 25 29 34 39 45 51 95 N 3058.53 E 3058 60 N 89 35 E 74 N 3123.78 E 3123 87 N 89 34 E 54 N 3188.77 E 3188 87 N 89 32 E 21N 3252.42 E 3252 55 N 89 29 E 17 N 3315.97 E 3316 14 N 89 25 E 84 N 3379.52 E 3379 75 N 89 19 E 73 N 3443.15 E 3443.45 N 89 14 E 83 N 3506.73 E 3507.12 N 89 9 E 17 N 3569.99 E 3570.46 N 89 4 E 64 60 N 3633,02 E 3633.59 N 88 59 E 7O 74 73 68 62 55 48 ' 43 64 N 3695.87 E 3696.54 N 88 54 E 33 N 3758.10 E 3758.83 N 88 52 E 17 N 3819.44 E 3820.14 N 88 54 E 35 N 3880.51 E 3881.11 N 88 59 E 19 N 3941.68 E 3942.17 N 89 6 E 90 N 4002.29 E 4002.68 N 89 12 E 78 N 4062.43 E 4062.72 N 89 19 E 39 N 4107.53 E 4107.76 N 89 24 E COMPUTATION DATE: 18-JAN-94 PAGE 3 ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 SO00 6000 7000 7775 0.00 -147 O0 O0 999.62 862 O0 '1915.49 1768 O0 2670 89 2623 O0 3430 66 3283 O0 4188 O0 4041 O0 4940 52 4793 O0 5707 44 5560 O0 6318 61 6171 0 0 62 5 47 49 37 33 89 40 53 66 41 32 O0 41 27 52 40 S1 44 39 16 61 37 17 N 0 0 E S 89 9 E 8 S 89 8 E 376 N 89 3 E 1032 S 89 29 E 1682 S 88 55 E 2334 N 88 23 E 2992 N 84 6 E 3632 S 83 11E 4107 0 O0 34 99 10 03 58 93 40 07 0 O0 0 O3 0 O3 0 O1 0 O1 0 O1 0 O0 0 O0 0 O0 0 O0 N 5 6 1 8 20 20 64 43 21S 8 57 N 377 O0 N 1032 09 N 1682 29 N 2334 16 N 2993 60 N 3633 39 N 4107 29 E 9 O6 E 377 14 E 1032 15 E 1682 81E 2334 18 E 2993 O2 E 3633 53 E 4107 0 O0 E 0 O0 N 0 0 E 79 S 57 53 E 11 N 89 0 E 14 N 89 57 E 17 N 89 43 E 90 N 89 30 E 25 N 89 37 E 59 N 88 59 E 76 N 89 24 E COMPUTATION DATE' 18-JAN-94 PAGE 4 ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 21-DEC-1993 KELLY BUSHING ELEVATION' 147,00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 -147 O0 O0 0 O0 O0 100 O0 O0 200 O0 O0 300 O0 O0 400 O0 O0 500 O0 O0 600 O0 O0 700 O0 O0 800 O0 0 0 N 0 0 E 0 16 S 14 25 W 0 18 S 19 26 W 0 16 S 19 14 W 0 16 S 16 52 W 0 20 S 12 28 W 0 20 S 14 43 W 0 24 S 2 55 E I 10 S 62 19 E 3 58 S 86 12 E 147 247 347 447 547 647 747 847 947 ENGINEER' FORMICA 0 O0 147 OT 247 07 347 07 447 OT 547 07 647 07 747 08 847 08 947 18 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1047.68 1047.00 900.00 7 2 1148.93 1147,00 1000.00 10 52 1251.50 1247.00 1100.00 14 43 1355.80 1347.00 1200.00 18 2 1461.75 1447 O0 1300.00 20 29 1569.62 1547 O0 1400.00 23 45 1680,68 1647 O0 1500.00 27 42 1795.53 1747 O0 1600.00 31 31 1915.03 1847 O0 1700.00 34 49 2040.10 1947 O0 1800.00 38 53 0, O0 -0.14 -0.27 -0.43 -0.59 -0.71 -0.84 -0.96 -0.26 3.81 N 89 54 E 13.66 N 87.36 E 29.38 N 86 25 E 52,09 N 86 18 E 81.59 N 86 7 E 116.46 N 86 10 E 156.76 N 87 48 E 204.93 N 88 59 E 261.34 S 89 3 E 326.73 S 89 26 E 401.79 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 0 02 0.00 N O.43 S 0.88 S 1.34 S 1.80 S 2.29 S 2.87 S 3247 S 4,28 S 5.05 S 0 O0 E 0 14 W 0 28 W 0 45 W 0 60 W 0 73 W 0 87 W 0 99 W 0 30 W 3 77 E 0.00 N 0 0 E 0.46 S 18 15 W 0.92 S 17 34 W I 41 S 18 20 W 1 90 S 18 27 W 2 40 S 17 35 W 3 O0 S 16 49 W 3 61 S 15 55 W 4 29 S 3 59 W 6 30 S 36 46 E 0 03 0 04 0 04 0 03 0 01 0 03 0 04 0 O3 0 O3 0 03 5.24 S 4.84-S 29 3.65 S 52 1.69 S 81 0.66 N 116 3.45 N 156 6.01N 204 7.55 N 261 7.46 N 326 6.27 N 401 34 E 29 06 E 52 58 E 81 47 E 116 79 E 156 99 E 205 41E 261 80 E 326 85 E 401 13 62 E 14 60 S 68 58 E 74 S 80 38 E 19 S 85 59 E 60 S 88 49 E 47 N 89 40 E 83 N 88 44 E 07 N 88 19 E 51 N 88 21E 88 N 88 42 E 90 N 89 6 E 2171 31 2047 O0 1900 O0 40 49 2303 2436 2570 2703 2835 2968 3100 3233 3365 74 2147 81 2247 25 2347 26 2447 57 2547 36 2647 75 2747 36 2847 17 2947 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 25OO O0 2600 O0 2700 O0 2800 S 89 44 E O0 41 8 S 89 18 E 573 O0 41 23 S 89 3 E 661 O0 41 24 S 89 7 E 749 O0 41 1 S 88 58 E 837 O0 41 0 S 89 48 E 924 O0 41 4 N 89 1E 1011 O0 41 8 N 89 16 E 1098 O0 '40 55 N 89 31 E 1185 O0 40 25 N 89 20 E 1271 3496 35 3047.00 2900 O0 40 14 3626 3756 3887 4021 4154 4287 4419 4551 88 3147.00 3000 43 3247,00 3100 99 3347.00 3200 79 3447.00 3300 60 3547.00 3400 48 3647.00 3500 70 3747.00 3600 47 3847.00 3700 4682.26 3947.00 3800 O0 39 41 O0 39 13 O0 41 49 O0 41 19 O0 41 12 O0 4O 56 O0 40 46 O0 40 27 O0 39 42 486 74 55 34 69 39 02 36 11 18 04 N 88 56 E 1355 92 N 88 51E 1439 N 88 45 E 1522 S 89 19 E 1607 S 89 39 E 1696 N 89 47 E 1783 N 88 36 E 1871 N 88 5 E 1957 N 87 28 E 2043 N 87 32 E 2127 79 10 55 44 84 32 75 46 66 0 02 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 0.01 0, O0 0. O0 0. O0 0. O0 0. O0 0.01 0 O1 0 O0 0 O1 0 O1 0 O0 0 01 5.83 N 486 80 E 486 84 N 89 19 E 5 14 N 573 3 2 0 0 0 1 2 3 61E 573 76 N 661 39 E 661 26 N 749 73 E 749 82 N 837 42 E 837 58 S 924 04 E 924 65 N 1011.40 E 1011 97 N 1098.16 E 1098 88 N 1185.24 E 1185 69 N 1271.11E 1271 64 N 89 29 E 4O N 89 40 E 73 N 89 50 E 42 N 89 57 E O4 S 89 58 E 4O N 89 58 E 16 N 89 54 E 24 N 89 52 E 12 N 89 50 E 5 07 N 1356.00 E 1356 01 N 89 47 E 6 8 8 7 8 9 11 15 18 65 N 1439.88 E 1439 51N 1522.21E 1522 95 N 1607.67 E 1607 98 N 1696.56 E 1696 14 N 1783.96 E 1783 05 N 1871.45 E 1871 83 N 1957.90 E 1957 37 N 2043.64 E 2043 62 N 2127.87 E 2127 90 N 89 44 E 24 N 89 41E 70 N 89 41E 58 N 89 44 E 98 N 89 44 E 47 N 89 43 E 94 N 89 39 E 70 N 89 34 E 95 N 89 30 E COMPUTATION DATE: 18-JAN-94 PAGE 5 ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 4812.43 4047 O0 3900 O0 40 16 4945.29 4147 5078.71 4247 5212.07 4347 5345.42 4447 5478.79 4547 5611.89 4647 5744.12 4747 5876.36 4847 6008.56 4947 N 88 49 E 2210 90 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 41 28 S 88 55 E 2298 O0 41 27 S 88 53 E 2386 O0 41 24 S 88 47 E 2474 O0 41 26 S 88 49 E 2563 O0 41 26 S 88 51E 2651 O0 40 55 N 88 39 E 2739 O0 40 52 N 88 25 E 2825 O0 40 50 N 88 21 E 2912 O0 40 49 N 88 24 E 2998 35 67 9O 11 34 17 64 10 53 0 O1 0 O1 0 O1 0 O0 0 O0 0 O0 0 O1 0 O1 0 O0 0 O0 21 98 N 2211 14 E 2211 25 N 89 26 E 20 19 17 15 13 13 17 2O 97 N 2298 29 N 2386 42 N 2475 57 N 2563 73 N 2651 09 N 2739 39 N 2825 81N 2912 31N 2998 59 E 2298 89 E 2386 11E 2475 31E 2563 53 E 2651 36 E 2739 85 E 2825 33 E 2912 78 E 2998 68 N 89 29 E 97 N 89 32 E 17 N 89 36 E 36 N 89 39 E 57 N 89 42 E 39 N 89 44 E 89 N 89 41E 39 N 89 39 E 85 N 89 37 E 6140.69 5047 O0 4900 O0 40 45 6272.53 5147 6402.64 5247 6532.47 5347 6662.32 5447 6792.38 5547 6921.93 5647 7051.09 5747 7179.42 5847 7306.19 5947 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 40 31 O0 39 26 O0 39 41 O0 39 45 O0 39 34 O0 39 28 O0 39 12 O0 38 17 O0 37 49 N 88 26 E 3084.83 N 88 28 E 3170.69 N 85 56 E 3253.76 N 84 56 E 3336.24 N 84 43 E 3418.68 N 84 26 E 3501.40 N 84 9 E 3583.28 N 84 29 E 3664.54 N 87 46 E 3744.67 S 86 49 E 3822.54 0 O0 0 O0 0 O1 0 O1 0 O0 0 O0 0 O0 0 01 0 O1 0 O2 22 68 N 3085 10 E 3085.18 N 89 35 E 25 29 35 43 51 59 67 73 72 O1N 3170 33 N 3254 99 N 3336 49 N 3419 36 N 3501 59 N 3583 84 N 3665 91N 3745 97 N 3823 99 E 3171.09 N 89 33 E 09 E 3254.23 N 89 29 E 63 E 3336 82 N 89 23 E 13 E 3419 40 N 89 16 E 91E 3502 29 N 89 10 E 86 E 3584 35 N 89 3 E 18 E 3665 81 N 88 56 E 37 E 3746 10 N 88 52 E 23 E 3823 93 N 88 54 E 7432.78 6047.00 5900.00 38 1 7559.34 6147.00 6000.00 37 32 7685.01 6247.00 6100.00 37 17 7775.00 6318.61 6171.61 37 17 S 84 17 E 3899.93 S 84 8 E 3977.17 S 83 11 E 4052.89 S 83 11E 4107.07 0.02 0.01 0. O0 0. O0 66.35 N 3900.57 E 3901.13 N 89 2 E 58.51N 3977.75 E 3978.18 N 89 9 E 49.86 N 4053.41 E 4053.72 N 89 18 E 43.39 N 4107.53 E 4107.76 N 89 24 E COMPUTATION DATE: 18-JAN-94 PAGE 6 ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A GCT LAST READING PBTD 7" CASINO DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 680' FSL & 160' FWL, SEC36 T11N R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOU'IH EAST/WEST 4043 O0 7387 O0 7387 O0 7459 O0 7588 O0 7635 O0 7665 O0 7754 O0 7775 O0 3462 95 6010 90 6010 90 6067 66 6169 76 6207 15 6231 08 6301 90 6318 61 3315 95 5863 90 5863 90 5920 66 6022 76 6050 15 6084 08 6154 90 6171 61 7.91 N 69.13 N 69.13 N 64.73 N 56.69 N 53.47 N 51.30 N 44.90 N 43.39 N 1710 53 E 3872 56 E 3872 56 E 3916 63 E 3995 06 E 4023 36 E 4041 38 E 4094 90 E 4107 53 E arco ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD COMPUTATION DATE: 18-JAN-94 PAGE 7 DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 68°, FSL t 160' FWL, SEC36 TllN R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 7387 O0 7387 O0 7459 O0 7588 O0 7665 O0 7775 O0 6010.90 5863.90 6010.90 5863.90 6067.66 5920.66 6169.76 6022.76 6231.08 6084.08 6318.61 6171.61 69.13 N 69.13 N 64.73 N 56.69 N 51.30 N 43.39 N 3872 56 E 3872 56 E 3916 63 E 3995 06 E 4041 38 E 4107 53 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7775.00 6318.61 6171.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4107.76 N 89:24 E COMPANY ARCO ALASKA, INC. FIELD 2E-08 WELL KUPARUK RIVER COUNTRY USA RUN I DATE LOGGED 21-DEC-1993 REFERENCE 94OO8 A interpretations are opinions based on inferences from elecl~ical or other measurements and we cannot, and do not gua,rantee the accuracy or correctness of any nterpretat ons and we shall not, except in the case of gross or wilfull negligence on our pad, be liable or responsible for any oss, costs, damages or expenses incurred or sustained by anyone resu ting from any nterpretation made by any of our officers, agenfs or employees. These interpretations are also subject to our General Terms and Conditions as set out n our current pr ce Sc 3edu e. ~/E L~L· 2E-08 , ( 680' FSL, 160' FWL ,SEC. 36, T11N ( ,UM) IORIZONTAL PROJECTION NORTH 4000 3000 2000 1000 -1000 -2000 -3000 SOU~'H -4000 FIEF 94008 ,SCALE = I / 1000 INIFT -2000 -1000 0 1000 2000 3000 4000 5000 6000 WEST EAST WELL- 2E-08 ' ~ ( 680' FSL, 160' FWL ,SEC. 36, T11N ,~ .,UM) VEl(I' JAL PROJECTION WEST -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 PROJECTION ON VERTICAl.. PLANE WE~T - EAST SCALED IN VEf:tTICAL DEPTHS HORIZ .~ALE = 1 / 1000 IN/FT RECEIVED UB.$URFACE DIRECTIONAL ~URVEY [~]UIDANCE [~ONTINUOU$ 'r~OOL Comparty ARCO ALASKA, INC. Well Nam® aL-08 (680'FSL,160'FWL,SEC.36,T11N,R9E,UM), Field/Location KUPARUK,u NORTH SLOPE, ALASKA Job Reference No. 94008 FORHICA Date 21-DEC-1993 Computed 8¥: SINES METHODS OF COMPUTATION ARCO ALASKA, INc. 2E-08 TOOL LOCATION: MINIMUM. CURVATURE VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 89 DEG 33 MIN EAST COMPUTATION DATE: 18-JAN-g4 PAGE ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 21-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT ENGIN~F_R' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH . SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 0.00 -147.00 99 93 199 93 299 93 399 93 499 93 599 93 699 93 799 92 899 89 0 0 N 0 0 E -47.07 0 16 S 15 5 W 52.93 0 17 S 16 6 W 152.93 0 16 S 20 59 W 252.93 0 16 S 18 48 W 352.93 0 18 S 12 3 W 452.93 0 21 S 14 46 W 552.93 0 21 S 14 54 W 652.92 0 35 S 37 9 E 752.89 2 25 S 79 3 E 0 O0 -0 09 -0 21 -0 36 -0 51 -0 65 -0 78 -0 92 -0.82 1.27 0. O0 0.01 0. O0 0. O0 0 O0 0 O0 0 O0 0 01 0 O0 0 02 0.00 N 0.22 S 0.67 S 1.12 S 1.58 S 2.05 S 2.60 S 3.17 S 3.86 S 4.77 S 0.00 E 0 09 W 0 21W 0 37 W 0 53 W 0 67 W 0 80 W 0 95 W 0 85 W 1 23 E 000 N 0 0 E 24 S 23 10 W 70 S 17 29 W 18 S 18 10 W 66 S 18 27 W 15 S 18 7 W 72 S 17 6 W 31 S 16 37 W 95 S 12 23 W 93 S 14 27 E 1000.00 1100.00 1098.82 951 1200.00 1196 98 1049 1300.00 1293 73 1146 1400.00 1388 90 1241 1500.00 1482 72 1335 1600.00 1574 66 1427 1700.00 1664 05 1517 1800.00 1750 81 1603 1900.00 1834 63 1687 999.62 852 62 5 47 82 8 58 98 12 53 73 16 23 90 19 1 72 21 34 66 25 0 05 28 20 81 31 42 63 34 30 S 89 9 E N 88 25 E N 87 I E 39 N 86 11E 65 N 86 13 E 95 N 85 59 E 130 N 86 35 E 169 N 87 58 E' 214 N 89 2 E 263 S 89 2 E 318 8.34 20 92 84 03 60 10 28 O0 67 18 0 03 0 03 0 04 0 04 0 O3 0 02 0 03 0 04 0 03 0 O3 5.21S 5.14 S 20.88 E 21 4.34 S 39.81E 40 2.80 S 65.01E 65 0.77 S 95.60 E 95 1.60 N 130.11E 130 4.24 N 169.31E 169 6.34 N 214.06 E 214 7.59 N 263.74 E 263 7.60 N 318.25 E 318 8.29 E 9 79 S 57 53 E 50 S 76 10 E 04 S 83 46 E 07 S 87 32 E 60 S 89 32 E 12 N 89 18 E 37 N 88 34 E 15 N 88 18 E 85 N 88 21 E 34 N 88 38 E 2000 O0 1915.49 1768 49 37 33 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1992 94 1845 O0 2068 O0 2144 O0 2219 O0 2294 O0 2369 O0 2444 O0 252O O0 2595 94 40 34 70 1921 70 40 51 18 1997 18 41 8 37 2072 37 41 20 34 2147 34 41 34 32 2222 32 41 24 54 2297 54 41 2 13 2373.13 40 52 56 2448.56 41 11 S 89 8 E S 89 47 E S 89 45 E S89 19 E S89 3 E S 88 59 E S89 7E S 88 58 E S89 5 E N 88 56 E 376 99 440 23 505 49 571 09 637 02 703 20 769 36 835 25 9O0 72 966 36 O. 03 0.03 O. 02 0. O0 O. 01 0. O0 O. O0 O. O0 O. O0 0.01 6.57 N 377.06 E 377 11 N 89 0 E 6.04 N 440.29 E 440 5.74 N 505.55 E 505 5.17 N 571.15 E 571 4.17 N 637.07 E 637 3.04 N 703.24 E 703 1.96 N 769.40 E 769 0.86 N 835.28 E 835 0.34 S 900.74 E 900 0.17 S 966,.39 E 966 33 N 89 13 E 59 N 89 21E 17 N 89 29 E 08 N 89 38 E 25 N 89 45 E 40 N 89 51E 29 N 89 56 E 74 S 89 59 E 39 S 89 59 E 3000 O0 2670.89 2523.89 40 53 N 89 3 E 1032 10 3100 3200 3300 3400 3500 3600 3700 3800 3900.00 3355 O0 2746.43 2599.43 41 8 O0 2821.80 2674.80 40 57 O0 2897 47 2750.47 40 37 O0 2973 53 2826 53 40 22 O0 3049 78 2902 78 40 14 O0 3126 34 2979 34 39 52 O0 3203 38 3056 38 39 30 O0 3280 63 3133 63 39 49 95 3208 95 41 50 N 89 16 E 1097 N 89 29 E 1163 N 89 27 E 1228 N 89 11E 1293 N 88 56 E 1358 N 88 51E 1422 N 88 33 E 1486 N 89 8 E 1549 S 89 16 E 1615 61 32 70 60 28 59 32 79 56 0.01 O. 01 O. O0 0. O0 O. O0 0. O0 0. O0 0. O0 0.01 0.01 1.00 N 1032.14 E 1032 14 N 89 57 E I 96 N 1097 66 E 1097 69 N 1163 28 N 1228 98 N 1293 11N 1358 31N 1422 68 N 1486 04 N 1549 85 N 1615 38 E 1163 76 E 1228 67 E 1293 36 E 1358 69 E 1422 42 E 1486 91E 1549 68 E 1615 67 N 89 54 E 38 N 89 52 E 77 N 89 51E 68 N 89 49 E 37 N 89 47 E 70 N 89 45 E 44 N 89 42 E 94 N 89 40 E 70 N 89 41E COMPUTATION. DATE~ 18~JAN-94 PAGE 2 ARCO ALASKA, INC., . .DATE. OF SURVEY' 21-DEC-1993 :::':": -':~ :::~'::'::' : ":% ~PO~ =V~u~' FOR :~: ~i:00 f~O~ M~~ D~ :.:' ' ' ' "'""' : M~~ V~IC~ V~TZC~ D~IATIDN~ ~ [~ 'SECTION S~~ NoR~'~SO~'~:~T~W~T '~DIST' ~IM~ ' D~~'~ '..' ~D~ ':-~ D~' DEG MIN.' ''''~ DS ~':;M:~: -' :::'FE~" DE~J~O0 e~' :~' .:':FE~ .: ..F~ DEG'MIN 4000.00 3430.66 a -: ~.~:00.. /00 !~SOS':.92 3 .4: 00.:~o' -3S8~ :[,3 . 3 -4e ~ :0~ :388~.:f:96 ':3 .:4s ~b'~o'o' -'~:~3:06 -~ 5000.. O0 .4t88'. 00 . 40~ '5~bO~O0 : 4~?.95 '::~4~~] '~53~007oo' ';~.~2:::9~..: Ss60:: :'bo · ~¢2 ::90 6000.00 49.4.0;52 4793.S2 ~0 S:L _N"~8'23:E 2992::,93 '- .-. :." .: :-- -:,- - : .~.- .: ::: ... -:: ..-:. - L-- · ::':- ~, :.<: · [S E 1682.17 N 89 43 E .'99"E-1-:748".01 N 89 44 E :~897:.E 181,3:.:91 N.:89 44 E .'.-!~'4: E i:9:46 ::~e N: 89 40: E ::24:'.:'E '2010~::28 N 89 36'E ~:06:'E 207S7333 'N 89:'32 E '..20:":E 2139:28 :N':89 29 E ~:::'ll':E 2j203.jl N89 26 -E ~::.'~33';E ~268:.7: N 89 27 E ~- ::' ~.· .,- - . · N 2334.81 E 2334,.90 N 89 30 E :<N~ .2~ao :99~.: E 246L ~6 N.'-e9 337E '.~-26~3:.27~E 2633;.32 'N ag ~e E fN 26~S: S7'::~E 2eSS. 60 N"89 43 E ~N. 2~3:1:~7:E 2~3[ ~60 N' 89~ .44 E ;N 28~2:.~40bE 2.e02..46 N e~ 40'~E ~ 2~?-~-~9: E 2~27.'~SN- e9 36: E 20.I5. N 2993, 3;8 E.,2993.2,5 N 89 37 E 211'::'95::N 30~8::.S3::':E 30~8:'.60 .N 89' 3,5'E :j3.-:::,::4::.N 3'Z~3i:78iE 3:1-~3:'87 'N 89"'34~'E ~5::'~4":N' 3.:~'~:/~7:::::E: 3188.:87 N,~'9 32:'E 34~:::..i:73::N 33,~5:97::E 33.~6: ~4 N 89 25'E 39:::~J~4':'h· 33~:9'. S2;:~'E 33~9.::'75 N.89 Z9 "E 5:i'.<::83.:-N 35~6':~73'::E 350:7: 12 N '~'9:9' E .... : .: :~ =.;'f:i" :j:.~ : ~ . . ?o:,. .:0-::: 30 7000..00 5707.44 ,5,560:44 39 3;6 '.N..84 : 6 E 3632.40 ._O.o0 _ ~.60' N 3633.02 E 3633.,59 N 88 ,59 E 7'~bO::'O0 ~7843':-98 S~::'98:::'-:'~8:."'.:5S N:::.~:'~:~ E. 36~:;:20 -"~ ',' ~*~::::b:: ...... ':':~b:':64-~N 36~:5~} 87- .. 36i{-(-54 " ' 7400.00 ~02:.:s se74.:s 37 65.. s s4 24.E _3679.'ss : ...... 0.02 ....68-.36 N._~aso.5z E 3s8:.::N 8~ 69 E 7600..00 6'179.31. 603~ 31 37 16 S 83 ~7 E 400:.73 0.01 55'.90' N 400~.29 E 4002.68 N..~9:2 E :-:770~..~:~:-:_.6258:~:~::._'-:6:::.93 37 z7 s s3 :: E 406:.92 0:00 4a.78 N 406~.43 E:40~'~'.72 N 09:.:9 E .-77~5:-D0,:' 63::8 61 5171 61 37 17 S 83 11 E 41-07.07 0 O0 43.39 N ~:107..53 E, 4:107.76 N 89 24 E --~< :~ ~ ' . :'-. :~> a: ;._ :.:' F:~. ~ ._ :- .,. :..,:. :- '- .: ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-JAN-94 PAGE 3 DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 999.62 852 2000.00 191S.49 1768 3000.00 2670 89 2S23 4000.00 3430 66 3283 SO00.O0 4188 O0 4041 6000.00 4940 S2 4793 7000.00 S707 44 S560 7775.00 6318 61 6171 0.00 -147 O0 0 0 N 0 0 E 0 O0 62 5 47 S 89 9 E 8 34 49 37 33 S 89 8 E 376 99 89 40 $3 N 89 3 E 1032 10 66 41 32 S 89 29 E 1682 03 O0 41 27 S 88 S5 E 2334 S8 S2 40 51 N 88 23 E 2992.93 44 39 16 N 84 6 E 3632.40 61 37 17 S 83 11 E 4107.07 0 O0 0 03 0 03 0 0 0 0 0 0 01 01 01 O0 O0 O0 O00N $ 21S 8 6 57 N 377 I O0 N 1032 8 09 N 1682 20 29 N 2334 20.15 N 2993 64.60 N 3633 43.39 N 4107 29 E 9 06 E 377 14 E 1032 15 E 1682 81E 2334 18 E 2993 02 E 3633 53 E 4107 0 O0 E 0 O0 N 0 0 E 79 S 57 53 E 11 N 89 0 E 14 N 89 57 E 17 N 89 43 E 90 N 89 30 E 25 N 89 37 E 59 N 88 59 E 76 N 89 24 E ARCO ALASKA, INC. 2EE~08 KUPARUK RIVER NORTH'sLOPE, ALASKA COMPUTATION DATE: 18-.JAN,94 PAGE 4 DATE OF SURVEY' 21-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN' 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE' VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/iO0 FEET FEET FEET DEG MIN 0.00 0.00 -147.00 0 0 N 0 0 E 147.07 147.00 0.00 0 I6 S 14-25 W 247.07 247.00 100.00 0.18 S 19 26 W 347.07 347.00 200.00 0 16 S 19 14 W 447.07 447.00 300.00 0 16 S 16 62 W ,547.07 64'7.00 400.00 0 20 S 12 28 W 64'7.07 647.00 ,500.00 0 20 S 14 43. W 747-.08 747.00 600.00 0 24. S 2 S,5 E 847.08 84.7~00 700-~00 I 10 S 62 I9 E 947.18 947'..00 800'.00 3 `58 S 86 12 E 0.00 0,00 0.00 N 0.00 E -0.14 0~01 0..43 S 0.14 W -0'.27 0.00 0..88 S 0.28 W -0.43 0.00 1.34 S 0.4,5 W -0'.,59 0.00 1.80 S 0.60 W -0.71 0.00 2- 29 S 0.73 W -0.84 0.00 2.87 S 0.87 W -0.96 0'.00 3~47 S 0.99 W -0.26 0.01 4.28 S 0.30 W 3-.'81 O. 02 5.0'6 S 3.77 E 1047.68 1047.00 900.00 7 .2 N 89 54 E 13.66 1148.93 1147;00 1000.00 10.,52' N 87 36 E 29:3'8 '1251.S0 I247.00 1100.00 14 43 N 86:25 E 52.09 13,5`5.80 1347.'00 1200'.00 18 2 N 86 18.,E 8-1.59- 1461~76 1447,00 1300:00 20 29 N86 7 E 116.46 '1,569..62 15.47..00 1400,'00 23 4`5 N 86 10 E 166'~76 1680.68 1647.00 1,500;00 '27.42 N 8~7 48E 204..9~' 1.79,5.~53- 1747.00 1600.00 3'1 31 N88'69. E 261..34 1915.03 1847..00 1700.00 34 49: S89 3 E 326:73- 2040.I0 1947.00 1800~00' 38 63' S 89 26. E 401.79 0-.03 0..04 0,04 0.03 o~ol o~0~ 0:04 .0.03- 0~03 0.03 21."/1 · 31 2047. O0 1'900.00 40 49. S 89-. 44 E. 48.6'~ 74 2303.74 214~ 2436~8''~.. ~z 270: 2835..-S~' 264~ 3496.36 3047..00 2900..00-'40 14~ N'88 `56. E 3626.~.88 3~ ~.00. 3887.99 3347.: O0:3~20~00 · 41 49~;~;~:'?S~89 19 E 4021.79 3~7 ~00 4154.60 3~7. O0 3400-'~' 4287,48 3647. O0 3600. O0 40 ~4419~:~T0' '-~7~0~0~:~/~3600. O0 4'0 46 455~.47 :::.~7.00 3700..00 40 27 N 87 28 E 2043..46 0.:00 .4682~: 26 3947. O0 3800. O0 39 42 N 87 32 E 2127.66 0: 01 O. 02 '*..00. 2000.00 41 ' 8 S 89 18 E · ,573.`56 0.00 `5.14'N 573.61 E `573.64 {,;:-00, ~20~.00- S 8~: 7 E '~T~g:69. 0,00 -2,26 N.74.9'.73E ~.00' 2~3:.'0~· 4~--'~:~:,1 $8:8 ~8..E ~8/,.3~':~' G.'O0' ~-0~82.'-:'N :-783:~.4~ ':0~' 280~:00 40.25- N: 89:.20.-E 127~-;0~ 0.:00' 3:69' N 12~i. il~t' E S789 .19 E .:~:~60~:-: S~. ;~;:.~'~- 0~-1 ;:~:.~:/~': :: 8~:~9:5~/N~::~ 160~;:-67~:- ~E ;~ ~60~:;~.~~0 S-89 39_ E 16~96.,44 0;01 ' . 7.98-N: 1696'-56''E 1696~58 N 88-36' E' 1871.32 ' °~01 -9.05 N i871'.45 E 1871.47 N a8 5 E 1957.75 0.0[ 3Z.83 N 1957.90 0.00 N 0 0 E 0.46 S 18 1,5 W 0.92 S 17 34 W 1.41 S 18 20 W 1.90 S 18 27 W 2.40 S 17 36 W 3.00 S 16 49 W 3.61 S 15 56 W 4.29 S 3 `59 W 6.30 S 36 46 E 6:24 S 13.62 E 14..60 S 68 58 E 4.84 S 29; 34 E 29.74 S 80 38 E 3.:65 S 62.06 E 52.19 S 86 59 E 1:69 S 81.58 E -81.60 S 88 49 E' 0.66 N 1!6.47 E 116.47 N 89 40 E 3.46 N 156'..79 E 156.83 N 88 44 E 6.01 .N 204.99'E 205.07 N 88 19 E 7'~'56 N. 261'.41 E 261.61 N 88 21 E 7.46~N 326.. 80 E 326.88 N 88 42 E 6.27 N 4011.86 E 401:90 N 89 6 E 6.83 N 486.80 E 486.8'4 N 89 19 E N 89 29 E N' 89 40'E : 89 5'0 E 8:~. ~7 E S 89 5'8 E N 89 5:4 E N 8~i) 52 E N 89 $0 E N 89 47 E N:i' 8g 44.-,E N.'89 41,. N 89 44 E N 89 44 E N 89 43 E 16.37'N 2043..64E.2043.70 N 89' 34 E lej's~:'N' :2."~'i-e~-.:'SC~['~'7'~;§S N =89 30 E COMPUTATION DATE: 18-JAN-94 PAGE ARCO ALASKA, INC, 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SL~-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4812 43 4047.00 3900 O0 40 16 4945 5078 5212 5345 5478 5611 5744 5876 6008 29 4147.00 4000 71 4247.00 4100 07 4347.00 4200 42 4447.00 4300 79 4547.00 4400 89 4647.00 4500 12 4747.00 4600 36 4847.00 4700 56 4947.00 4800 O0 41 28 O0 41 27 O0 41 24 O0 41 26 O0 41 26 O0 40 55 O0 40 52 O0 40 50 O0 40 49 N 88 49 E 2210.90 S 88 55 E 2298.35 S 88 53 E 2386.67 S 88 47 E 2474 90 S 88 49 E 2563 11 S 88 51 E 2651 34 N 88 39 E 2739 17 N 88 25 E 2825 64 N 88 21 E 2912 10 N 88 24 E 2998 53 0 O1 0 01 0 01 0 O0 0 O0 0 O0 0 01 0 O1 0 O0 0 O0 21 98 N 2211.14 E 2211 25 N 89 26 E 20 19 17 15 13 13 15 17 2O 97 N 2298 59 E 2298 29 N 2386 42 N 2475 57 N 2563 73 N 2651 09 N 2739 39 N 2825 81N 2912 31N 2998 89 E 2386 11E 2475 31E 2563 53 E 2651 36 E 2739 85 E 2825 33 E 2912 78 E 2998 68 N 89 29 E 97 N 89 32 E 17 N 89 36 E 36 N 89 39 E 57 N 89 42 E 39 N 89 44 E 89 N 89 41E 39 N 89 39 E 85 N 89 37 E 6140 69 5047.00 4900 O0 40 45 6272 6402 6532 6662 6792 6921 7051 7179 7306 53 5147.00 5000 64 5247.00 5100 47 5347.00 5200 32 5447.00 5300 38 5547.00 5400 93 5647.00 5500 09 5747.00 5600 42 5847.00 5700 19 5947.00 5800 O0 40 31 O0 39 26 O0 39 41 O0 39 45 O0 39 34 O0 39 28 O0 39 12 O0 38 17 O0 37 49 N 88 26 E 3084 83 N 88 28 E 3170 69 N 85 56 E 3253 76 N 84 56 E 3336 24 N 84 43 E 3418 68 N 84 26 E 3501 40 N 84 9 E 3583 28 N 84 29 E 3664 54 N 87 46 E 3744.67 S 86 49 E 3822.54 0 O0 0 O0 0 01 0 01 0 O0 0 O0 ~ 0 O0 0 01 0 01 0 02 22.68 N 3085 10 E 3085 18 N 89 35 E 25.01N 3170 29.33 N 3254 35.99 N 3336 43.49 N 3419 51.36 N 3501 59.59 N 3583 67:84 N 3665 73.91N 3745 72.97 N 3823 99 E 3171 09 E 3254 63 E 3336 13 E 3419 91E 3502 86 E 3584 18 E 3665 37 E 3746 23 E 3823 09 N 89 33 E 23 N 89 29 E 82 N 89 23 E 40 N 89 16 E 29 N 89 10 E 35 N 89 3 E 81 N 88 56 E 10 N 88 52 E 93 N 88 54 E 7432.78 6047.00 5900.00 38 1 7559.34 6147.00 6000.00 37 32 7685.01 6247.00 6100.00 37 17 7775.00 6318.61 6171.61 37 17 S 84 17 E 3899.93 S 84 8 E 3977.17 S 83 11 E 4052.89 S 83 11E 4107.07 0.02 0.01 0. O0 0. O0 66.35 N 3900.57 E 3901.13 N 89 2 E 58.51 N 3977.75 E 3978.18 N 89 9 E 49.86 N 4053.41 E 4053.72 N 89 18 E 43.39 N 4107.53 E 4107.76 N 89 24 E ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18- JAN~94 ~ INTERPOLATED VALUES FOR 'CHOSEN-HORTZONS ~ -~ PAGE 6 DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00. FT ENGINEER: FORM[CA . _ MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A SURFACE LOCATION:'~680' FSE & 160-~ FWL, SEC36 TllN R9E MEASI.:JI~ED DEPTH.- .:=TVD RECTANGULAR COORDINATES BELOW KB FRoM KB SUB-SEA NORTH/SOUTH EAST/WEST 4043.00 - 3462.95 3:315.95 738.7,00 ~ 60~0.90 5863.90 7387.00 ~'~ 6.010:90 5863.90 7459:-00 ~ - 606~.66 5920.66 7588,-00 - .~: 6169~76 / 6022.76 7.91N 1710.53 E 69.13 N 3872.56 E 69.13 N 3872.56 E 64.73 N 3916.63 E 56.69 N 3995.06 E OCT LAST READTNG 76~$. O0 r 6207;. iS = 6060L IS ' 53.47 N 4023.36 E -.7'._ CASINO- '-: .... ~ 7865:~:-'0'0:: 823I-;¥~08 :~' :~084~;.08'-~ 5:1.30 N 4041.. 38 E ~" :':":' :":'-'-' ,-- 77~:?.'00 6318::,:~61 :- -: .6-17:1:;... 6;~"; 43~. 3g N 4107.53 E " ~*,' ~ , '.-~ '- ::~*", ~_ /'-.~ , - +~-:- . ::,;._ :.- .......... ..~ :,-:.- · '~../ .. %-. ~,{ -.. ::,~,-? -:: _::- 1F COMPUTATION DATE: IS-JAN-94 PAGE 7 ARCO ALASKA, INC. 2E-08 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARU~ A BASE KUPARUK A PBTD DATE OF SURVEY: 21-DEC-1993 KELLY BUSHING ELEVATION: 147.00 ET ENGINEER: FORMICA ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 680' FSL ~ 160' FWL, SEC36 TllN RgE DEPTH B~OWKB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 7387 O0 7387 O0 7459 O0 7588 O0 7665 O0 7775 O0 6010.90 5863.90 6010.90 5863.90 6067.66 5920.56 6169.76 6022.76 6231.08 6084.08 6318.61 6171.61 69 13 N 69 13 N 64 73 N 56 69 N 51 30 N 43 39 N 3872.56 E 3872.56 E 3916.63 E 3995.06 E 4041,38 E 4107.53 E FINAL WELL LOCATION ATTO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7775.00 6318.61 6171.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4107.76 N 89 24 E COMPANY FIELD COUNTRY U. SA RU'N I 21 'DE:C- 1993 DATE LOGGED REFERENCE 94'008' All interpretations are opinions, based on i_nferenceS fr~/,e!ecffiCal or other measurements:aDd :we cannot, and do.not gua[..antee the accuracy, pr c..o.r..r.ectness of an.y jn,te~r~'jta~ons, :.an~:we.!shal! ~ot" excet0t.!~ tt~:~' cas~ of gross o.r wilfull neg,gence .o.n o~ pan, oe ~ame. or resl3ons[o.l,e for any,~ose, ..c, ps~; aero:ages.or expenses,~nc~Fe'd or sustmned by anyone resum.ng from any interp[etalion. _maoe oy Rr~ o1~ our omcers, agents or emp!oyees.'31.~ese!interpretations are al~o subject to Our Generm .~ erms ~na. L;ondifions as;set (Sut' n Our current Pflcb ,S~hei:tule: WELL: 2E'08' (680' FSL, 160' FWL,SEC. 36,Tl1~ JE,UM) HORIZONTAL PROJECTION NOI=PFH 4000 3000 2OOO lOOO -1OOO -2000 -3000 soum -4000 SCALE = 1 / 1OOO IN/IT -:. ::~ :. . .:. ..... ~:~i ...?.-!.-!.i.t--: ~ ....... i ,~ ....... : ..... ~.' · · . ~ .! . :i:: ' ]~ i'"'~' .... 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' ............ : ........................ ; ................. .......... ! ......... . . , : : ........ _..,~.i;i.,.,, ,,,, ~,:.,,..~i.i!..i...L!..!.;.':!!..:~/.::.,:~:~ ~': ~:~ ~: ' ' ' ..... . ~ i i i ~.i.: i .......... ~..~ ~.~ ! ..~ .... i i i i i.: : ! ~ = i i i..i .i..~ ..................... .::: ::. ::.. ,::: · : ... ::. ..:: .. .:: :..: :::: :: . . : .... i L . =. e : :..e ~.! !.= .... ! : ! . ~ : = = · . ~ : , ! , · / ! : ! = ..... : . , . . ; .... h..~..~...~ > ::' !'":'"~'~ :' :i: i':"h'~ .... : : :iii ..:, ;i:! ':i: .:,. :;..:.,: ']! .... :: ...... :: :: .... :':. :::' ::' !!i: .:. ' ii'::, i:': : '': :.: ! : !.:., .: i..i .~.! :. .:.: . . ~ ~ .. ~.. ! . !.. .: : !. :.. ! : . . : : : ..:..:...:.: :..: :.:...:.:..,.., ..... ,.:..., ,., , , : ; i }. ~ : : : : ? : ..,.:.! i }.i :..~ .:...!. : i : ; : · ,.:: . :: .:, :: .... 2 L!.2~i .... i.i..~..i...i ....... i ..... L..i..L.L ...L..! .......... :.:. !.. : . ~;.! ........ : : ......... : ................... :: ...... . . ~ . : . : . . ~,:. .i!!!.~.i...i...;.I ~:..:.!.~.,..:.!,..~.:..::. .~ ~ .... . ~.+.i-! i..~..!...~ ....... i...h...i ;...i...i...i i....i..i~ ....... ~.~!..!..~.i.-:..:,ri.: .... i.i.:.:~::..~.:..: ~..i...i ...... ~.:.: .... ~: ' i..!-,i.[..i-.'i.'.i'-.i'.,!-'-i'-'!'"!'"i ..... i"'i-!"i !'"11...2 ..... i'i''~ .... .~!'. ...... . :': .... :.i ; i ..i.i..i.i..~..-i...L.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..: ...... ,.:.:-:...:..] ..... , ....... . :::: :::: :.: :.: . : ;h;..; ;.h..~...~.~.,.h..i-..;...; ..... !...i..!...> ..]...i ''... ::J'] ~ . .::: :::::::: :::: ::,: :.. ,.. ,: . :..~ ~ ....... ~'+'.~-.~ .... ~ ..... ~'"~ '--~"'~-~'-," '~ ~-~ ...... ~ ,'- i ' ; : I i'ii ! i : ~ : : : : ' ~' ! "~ : :':' ' .................. i-.-i...i...i i"'i"i"i'-'j'"!'-i'"i"i ...... !'"!"i"i ...... i'":'"i"! ..... ;";';"; ! ......... ;..{..i...;.--i..;..~..-,.!...~ i .... i-.; ; .... ; 'i .... ; '! ........ !'": .... !"i': ; ~- <J::: ~;;;-.--~i,i ;,;i ;i;, ,' ' ': ' , i;;, i, ii'i ,, -I ............... - ! ~ ~ : ' ! i i :"! ~ .... ~ .... ~'= ~' ~ . i ..... :.: .... !..! ..... i .... !..i~.i...i i ...:.i...} , i . . -2000 -1000 0 1000 2000 3000 4000 5000 6000 WEST EAST WELL' 2E-08 ~-,.. ( 680" FSL', 160 ' FWL, SE C. 36' TllN ,%..~ ,~ UM ) WEST 1000 -2000 -1000 0 0 3000 PROJECTION ON VER33CAL I=LANE 4000 5000 6000 EAST EAST ~CALED IN VERTICAL DEPTHS HC:~IIZ~CALE = 1/ 1000 IN/FT ARCO Alaska, Inc. Date: March 18, 1994 Transmittal #: 9037 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the followin~s-ope~3_.b~ items. Please acknowledge receipt and return one signed copy of this transmittal. 2E-08 2E-08 2E-08 2E-08 2E-17 2E-17 ~oo -- 7-7 ~fo 5" ~'~0- ~a,-f¢ 12-9-13-93 P''> 6000-12200 DISTRIBUTION: D&M Drilling 12-9-13-93 ~'5 6000-12200 u~.~-0--~'~'o 12-9-12-93 ¢.~ 113t9(~F2200 ~-~5 ~,~0- 12-9-12-93'~ 1~ ~ 1-14-94 ~. 8690-9110 5 11-23-25-93 ~87~-9186 Date: , ~~~~~/~~ Cathorino Worloy(Ooolo~y) . NSK ~State 5f~A' a~~+Sep~a)~ Bob Ocanas ARCO Alaska, Inc. Date: March 18, 1994 Transmittal #: 9036 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 2E-08 Please acknowledge receipt ~u,;.. LIS Tape and Listing: 02-22-94 93557 o~r-C.~ and A~ Runs with QRO Proc ~-~s' 2E-17 eoq5 LIS Tape and Listing: - - 0~-9~ _ 94021 ~-TDTP-3Passes and Average ~t 2E-17 ~oq~ LIS Tape and'Listing: . 03-04-9'4' 9345Z ~- CD~CDN an~ ADN~RAB~ns~ith QRO Processing ~-~' Receipt Acknowledged: ~~~~ ~ Date: DISTRIBUTION: Bob ~nas 'Stateof AlaSka ~'~ ARCO Alaska, Inc. Date: January 28, 1994 Transmittal #: 8992 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · ~5-' ~9--2E-05 ?~-~ --2E-06 ~1%-~ ~ -2E-07 ,¥~..\~-2E-08 .-~Directional Survey Directional Survey Directional Survey ~_Directional Survey Receipt Acknowledged: 12-19-93 12-20-93 12-21-93 12-21-93 DISTRIBUTION: Date: D&M State of Alaska (2 copies) 94003 94OO4 94O08 ARCO Alaska, Inc. Date: January 7, 1994 Transmittal #: 8972 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. ~'~-'Ib~, 2E-06-~ c~'5--I~ 2E-05-~/ '~ %.--1~c~ 2E-08~ ¢j'5-' ~'7'~ 2E-171 /! 2E-05~ ! 2E-06~--/i ¢/~ .-- io~{ 2E-071 J 2E-08{-'" 2E-17) Receipt Acknowledge' -'Ultrasonic (.Cement & -Ultrasonic LCement & -- Ultrasonic (..Cement & -Ultrasonic Imager-USIT Corrosion) Imager-USIT Corrosion) Imager-USIT Corrosion3 Imager-USIT (,Cement & Corrosion') --Cement Bond Log (CBT) .--Cement Bond Log (CBT) .-Cement Bond Log (CBT) -'Cement Bond Log (CBT) -Cement Bond Log (CBT) 12-20-93 [ 12-19-93 I 12-20-93 ! 12-20-93 12-19-93 12-2O-93 12-20-93 12-20-93' 12-20-93" Date: Drilling State of Alaska(+sepia) NSK Please acknowledge . 8900-10548 10700-120;~1 6400-7645 5" 7400-9088 5" 10700-120~[~ 8900-10520 5" 8400-10206 5" 6400-7616 5 7400-9059 .5 '' ALASKA OIL AND GAS CONSERVATION COMMISSION .WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10, 1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If I may be of any assistance, please call me at 279-1433. Yours very truly, ~.,/,/ ' ~? . Robert P Crandall Sr Petr Geologist encl jo/A:RPC:~dstats .1/o4/94 OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INS ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 . 93-0163-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV ~rNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPAR[;K RIV UNIT KUPARUK RIV UI~IT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2E-05 2E-06 2E-07 2E-08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 PAGE ALASKA OIL AND GAS CONSERVATION CO~I~llSSION December 3, 1993 WALTEFI J. HICKEL, GOVERNOFI 3OOl PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-~192 PHONE: (907) 8794433 TELECOPY: (907) 2767542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 · Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2E-08 ARCO Alaska, Inc. Permit No: 93-189 Sur. Loc. 680'FSL, 160'FWL, Sec. 36, TllN, R9E, UM Btmhole Loc. 648'FSL, 1021'FEL, Sec. 36, TllN, R9E, UM Dear Mr. McBride: 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 BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman ~ . BY ORDER OF THE COMMISSION dlf/Enclosures ' cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental.Conservation w/o encl. STATE OF ~ OIL AND GAS CONSERVATION COMMI PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r""l lb Type of Well Exploratory r""l Stratigraphic r""i Development Oil X Test Re-Entry r"l Deepen D Service I--! Development Gas D Single Zone X Multiple Zone r'l 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 147', Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25658, ALK 2584 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 680' FSL, 160' FWL, SEC. 36, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (O TARGET ) 8. Well number Number 650' FSL, 1300' FEL, Sec. 36, T11N, R9E, UM 2E-08 #U-630610 At total depth 9. Approximate spud date Amount 648' FSL, 1021' FEL, Sec. 36, T11N, R9E, UM 1 2/4/93 $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 2E-18 7766' MD 648' @ TD feet 12.5' @ 800' MD feet 2560 6315' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 800 feet Maximum hole angle 40.43° Maximum surface 2044 psig At total depth (TVD) 3450 psig 18. Casing program Settin! Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length lYE) TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 3964' 41' 41' 4005' 3452' 420 Sx Arcticset III & HF-ERW 500 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 7725' 41' 41' 7766' 6315' 170SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented .~le~l~ured depth True Vertical depth Structural bU ConductorRECEIV Surface Intermediate Production LinerDEC- 2 199;5 Perforation depth: measured Al~k~ 011 & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat D BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'l Refraction analysis i-1 Seabed report I-1 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~j~~ ~ Title Area Drillin~ En~lineer Date Commission Use Only Perm, 2um e ' I APl number 5o-~.z.? ~2..~'z.~' IApprova, da,~,~.....~....:~.~~ I See cover ,etter for , - other requirements Conditions of approval Samples required D Yes !~ No Mud log required r"'l Yes I~ No Hydrogen sulfide r'"l Yes J~ No Directional survey required J~ Yes r""l No measures Required working pressure for BOPE r"l 2M I~ 3M D 5M E] 10M r"l 15M Other:Original Signed Byby order of Approved by David W. Johnston Commissioner the commission Date ~ Form 10-401 Rev. 7-24-89 Su iplicate I , , . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2E-08 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4005')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7766') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and Production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. R£C£1V£D DEC - 2 199) Oil & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well 2E-08 Spud to 9-5/8" surface casing Density 9.0-10.8 PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <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 Notes: Drilling fluid practices will be in accordance with the apPropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2044 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2E-08 is 2E-18 (propOsed). As designed, the minimum distance between the two wells Would be 13.0' @ 825' MD. The wells would diverge from that point. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut doWn (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. DEC - ?- 199) Anchorage I I V 250 _ 500_ _ 750 _ _ 1000_ 175O_ 2250- 2750~ 3250~ 3760~ 4260 - 4750_ _ 5000_ _ 5260_ · 5500. 6000 6250. 6500 RKB ELEVATION: 147' ARCO ALASKA, Inc. .. Structure : Pad 2E Well : 8 Field : Kuporuk River Unit Location : North Slope, Alaska S 89.55 DEG E 3820' (TO TA]mET) Created by : jones For: MATHEIS / ELLIS Date plotted : 22-Aug-93 Plot Reference is 8 Version Coordinates ore in feet reference slot #8. True Vertical Depths ore reference wellhead. Baker Hughes INTEQ --- Scoie 1: 150.00 3000 3430 t I I I I I East --> 600 900 1200 15001800 2100 2400 2700 I II II II II I[ II II 30043 3300 3600 3900 4200 I I I I I I I I I I KOP ']'VD=BO0 TMD=800 DEP=O 3.00 9.00 BUILD 3 DEG / 100' ,.00 ~ : = = : 21.00B/ PERMAFROST TVD=1502TMD=1519 DEP=134 ISURFACE LOCATION: I 27.00 680' FSL, 160' FWL 3;5.00 SEC.56,TllN,RgE 39.00 EOC TVD=2039 TMD=2148 DEP=4-56 T/ UGNU SNDS TVD=2127 TMD=2264 DEP=551 T/ W SAK SNDS TVD=2697 TMD=3015 DEP=1017 TARGET LOCATION: J 650' FSL, 1300' FEL SEC. 36, Tl lN, RgE TARGET lVD=5987 TMD=7535 DEP=5820 SOUTH 30 EAST 3820 o Z 0 ! B/ W SAK SNDS TVD=3252 TMD=3742 DEP=1490 9 5/8" CSG PT lVD=3452 TMD=4005 DEP=1660 K-lO TVD=3782 TMD=4438 DEP=1941 TD LOCATION: I 648' FSL, 1020' FEL SEC. ;36, T11N, R9E AVERAGE ANGLE 40.43 DEG K-5 TVD=5082 TMD=6146 DEP=3049 TARGET - T/ ZONE C TVD=5987 TMD=7335 DEP=3820 T/ ZONE A TVD=6055 TMD=7424 DEP=3878 ~ B/ KLIP SNDS 'TVD=6165 TMD=7566 DEP=3970 TD / 7" CSGPT TVD=6315 TMD=7766 DEP=4IO0 0 250 500750 1000 1250 1500 t750 2000 2250 2 2750 3000 3 50 3500 Scale 1 : 125.00 Vertical Section on 90.45 azimuth with reference 0.00 N, 0.00 E from slot #8 i i 5750 i i 4000 4250 DEC -'2 1995 Oil & Gas Cons. commission Anchorage ARCO ALASKA, Structure : Pad 2E Field : Kuparuk River Unit Well : 8/ 18 / 7 / 17 / 6 Locofion · Norfh Slope, Alosko Scale 1 · 50.00 5O 1 O0 15O I I I I I 800 800, 1001 121 East 200 250 I I I I I 400 --> 500 550 400 450 500 I I I I I I I I I 1600 1400 14O0 1600 180O 1800 20OO 1800 1800 2000 2000 2000 55O I . 75O -- _700 _650 -- _600 _550 _500 -- _450 %- _400 %- _350 _500 -- _250 DEC, ' P- ~99) Oil & Gas Cons. C~mmisslon Anchorage Casing Design/Cement Calculations 2-Dec-93 Well Number: 2E - 08 Surface Csg MD: Surface Csg 'rVD: Production Csg MD: Production Csg TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 4,005 ft 3,452 ft 7,766 ft 6,315 ft 3,013 ft 7,335 ft 5,987 ft 3450 psi 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,452 ft {(13.5'0.052)-0.11}*TVDshoe =1 2,044 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =i 3,450.0 ppg 5,987 ft 100 psi 11.4 PPgl Design lead bottom 500 ft above the Top of West Sak = 2,513 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 787 cf Excess factor = 15% Cement volume required = 905 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 420 sxJ Surface tail: TM D shoe = 4,005 ft (surface TD - 500' above West Sak) * (Annulus area) = 467 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 502 cf Excess factor = 15% Cement volume required = 577 cf Yield for Class G cmt = 1.15 Cement volume required =1 500 sxJ RECEIVED DEC -2 199~ A~,ska Oil & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 2-Dec-93 Production tail: TMD = 7,766 ft Top of Target, TMD = 7,335 ft Want TOC 500' above top of target = 6,835 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 162 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 180 cf Excess factor = 15% Cement volume required = 207 cf Yield for Class G cmt = 1.23 Cement volume required =1 170 sxJ TENSION - Minimum Design Factors are: T(pb)=1.5 and T(!s)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 564000 lb 4,005 ft 36.00 Ib/ft 144180.0 lb 24326.0 lb 119854.0 lb 4.7] Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 4,005 ft 36.00 Ib/ft 144180.0 lb 24326.0 lb 119854.0 lb Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 604000 lb 7,766 ft 26.00 Ib/ft 201916.0 lb 34725.5 lb 167190.5 lb 3.61 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =! 667000 lb 7,766 ft 26.00 Ib/ft 201916.0 lb 34725.5 lb 167190.5 lb 4.01 Casing Design ! Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum sudace pressure Casing Rated For: Max Shut-in Pres = Design Factor =L Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating/Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 2-Dec-93 3520 psi 2043.6 psi 7240 psi 7244 psi 2923 psi 4322 psi 1.71 2020 psi 0.593 Ib/ft 1111 psi 1.8) 5410 psi 0.593 Ib/ft 3744 psi 1.4J REEEIVED DEC -2 199~ Alaska Oil & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 2-Dec-93 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi .6 . 5 4 3 I 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH 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 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI 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 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11"-3000 PSI X 1:~5/8"- 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 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 ,.JPARUK RIVER UNI'i( 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. 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 TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 ITEM (1) Fee (2) Lo~ ::* CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE -thru8] ' - (5) ,BOpE -~ [23 thru 2'8] (6) Other '[29 th~u' 3i] (7) Contact~Fc ~ [32] (8) A,ddl .~C ~ Company .~_~-~ YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property 1 in. ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Does operator have a bond in force ................................... ~ Is a conservation order needed ....................................... Is admini strat ive approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ...................... ,. ..... .~,.... Is conductor string provided .............. Wi 11 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel 1bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOP[ attached .... Does BOP[ have sufficient pressure rating -- test to ~ psig ..... Does choke manifold comply w/APl RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Lease & Well NO Additional requirements ............................................. ,, , , . , INITIAL GEOL UNIT oN/oFF POOL CLASS STATUS AREA ~ SHORE , , , , ,,, ,,,, , REMARKS Additional remarks' MERIDIAN' sU~~' rev 6/93 jo/6.011 Red ri 11 Rev , ~ 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. Date_ II ,qlnl RECEIVED MAR 2 1 1994 Alaska Oil & Gas Cons. Commi~ion Anchorage bis Tar~e l, erif~cation ~,~st.!nq $chluinher~jer AlasKa Co.,~[, Itinq Cent 22-!~ EB-'~ 994 i6:55 ; F.~hCO /,LASK~, li~..iC,.,KUPARL,'.w .PfI.'E~ [-~N!'I', 2[']-08 , 50-029-22428-00 IST ~TR!i~,~G 9F 9]577 SPR I NGER ,~. 500 O. 6~B 404-3 PAGE: LiS Tame ?"er!ficatJop ~ist~n~ Scblum~er,.~er AJasKa Co~t~!:i~.~t~n~ Center i994 16 55 i'.~,[ir, i #! ¢,i/~S LOGGF]!.> ~.]TF! EXPERI~;EiqTAL RAB-AOH bOGC!h~G ~-~HIt, E DRi. bL!HG 4043 TO 7030 FT. ...... .~ ;. · ~ .~ 37, ,-~, , .. ............ iNTF[i:~¥A[:: 696~ 7775 FT. .. ............ ~:Ob~ 7775 FT. LIS 00! COl [>r'p~-~ I~,CRE~E~,~T~ ;'), 5000 C[.~ ~:.~51~. 5 775! asks Comput~in~ Cer~ter ~ ,--,.~ 19q4 16:55 7576,0 748!.5 732q.~ 7570.0 7331.0 731].~, 7296.0 71 b4..5 FIGF UGET.(}G4. A*'~!., E;TN~R Ci.,~VES E~ERE CARRIED WITH THE GR 8}.~[FT, ;?~ESE St;'!FTS ONLY APPLY TO THE CDR/CDN PAGE: ...... . ~.~ .4 ~ ........ 2.349 V ~ A. ~4"~I'; 2.343 -999.250 -999 250 183~604 -999.250 9.862 2.368 504,042 0.025 ,,,~,pt41, . ,..:, ,, <.,, .., .qqo,:.. :,. _2'50 .... ~'~.~. ~,~ T [:),, -~9°... ~. 250 RP . .b;v~D' '999, 250 ;tF;'P.i~:~:,:,:,,,, -r~9o.2:50,,. , VDA.'~,,~-D~,, -09~. ...25(~. ROP.~'~D, , -999.250 LiS Schlumbert~er ,~.lasKa Co~i:.':.utInn Cent(*.r PAGE~ r'urve$ anc~ .lo,.'~ hr, a:.]er 4ara fr~r each bit tun in separate :- . .. i;, . files. FAST 2.4!bOGO$ 20.4 7775,0 7775.¢. 22-~EB-~,994 16:55 PAGEt 8.500 4043,0 10,00 150.0 3,i40 2.680 2.65 I , bO0 kC6 i:':{' '.;"~ BIT 14,74 GP'q'O aTT 2~.87 Fm t;E~'.~51'"~ t~7 BIT 38.44 ~"~FL.:'T[<{';:~'.~ TO BIT 45.42 f)R'lbt:~:L) I~'.:TERVAL: 4o6e 7775 i~,~TEiS::v~tb; 096~ 7775 FT. LT~ F[~F~AT Dh,'r~ 68.0 64.0 ~,,. verification ~ i~t~ 22-~EB-.!904 t6:55 ~Pl ~PI FILE ... NUmB SIZE . UCES6 CLASS ~,~r'}D NUma Sa~P ELEa CODE (hEX) PAGE: .echo 250 nPHI. U:" l -99 -999.230 TNPH.L41 -g99.250 -999.250 ROPF2, Gt< i 183.604 GR.Lt~I -q99.~50 TA~. L~:L -999.250 T~.BD. [,~' 1 '999,,25U '999.250 '999 250 2~-FE?~-1994 16:55 19.700 48.000 503.978 0.027 -g99.250 -999.950 -999.250 -999.750 ATR.L*! DRHO.L~I TABD.L~I 0.023 2.435 1~2,660 0.0"1 -999.250 -999.250 -999.250 -999.250 I o. 5 0 0 0 for each bit r~..an I.n separate 1 3 - i:; F C- 9 3 files. 22-Ff;B-I 904 PAGE~ P/~ ':~ "* E S T '{ m ',' v I "' O?TLf,EPS CA;:5;TNG DEPTH (F'T)~ 4043.0 ?.lid DFt4SIT~' (I,~/G): J.O.O0 ,,:';O VlSCOSim"f tS): F'I,,0!D bOSS lC3): bOgO;~;f.~(.; YPiLR ORlr..,bTri(; 4043 T~:'~ 7030 FT. ...... · , t . · ~. ~ PAST 2.4/hOGOS 20.4 $ PAGE~ 10 SIZE REP PROCESS CODE CHEX:} -999.250 ~46.63g ~38.237 3!2.78~ 2.27° DRHO. AOiq 322,5i3 7 O. 455 R 236. R .~9 -g99.250 -999.250 -999.250 -090.250 -999.250 3.297 -o.013 86.000 2.787 -0.019 -0.557 69.323 -999.250 -99~.250 DRHO.AB4 -99q.250 -999,250 RPM.AD~, -999.250 -999.250 RBl'f. RAb -999.250 LDI~..ADU R!NG.RAB PEP [,Dig RTNG.PA8 LD1 A. RING.ITAB LDIA.ADN LDIA.ADN RTNG.RAB -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 2.978 8,400 2,734 2.913 8,400 3.0]1 ~7.828 8.824 -999,250 -999.250 -999 250 -999:250 11 12