Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-186
Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: r AOGCC a ATTN: Natural Resources Technician II Alaska Oil &Gas Conservation Commision 333 W. 7th Ave, Suite 100 vww;y Anchorage, AK 99501 185136 30 85 9 TRANSMITTALDATE30-May-19 3Way79.Mo1 Recei Signatu(e' V /I " v \/ Date Please return via courier or sign/scan and email a copy to Sl hlumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. DATA LOGGED STATE OF ALASKA k It1<20/11 ALIPA OIL AND GAS CONSERVATION COMMON t'y SER REPORT OF SUNDRY WELL OPERATIONS z3q 1 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate E 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 p Exploratory❑ 185-186 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-21412-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3A-01 ADL 25632,ADL 25631 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 9,600 feet Plugs measured None feet true vertical 6,350 feet Junk measured None feet Effective Depth measured 9,175 feet Packer measured{413, 8900, 911 feet true vertical 6,038 feet true vertical 1534, 5845, 599 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 feet 15 " 104' MD SURFACE 4,323 feet 11 " 4,353' MD RECEIVED PRODUCTION 9,551 feet 6 " 9,575'MD Perforation depth Measured depth 9020-9036,9165-9195,9210-9260 feet JAN 0 3 2018 True Vertical depth 5928-5939,6030-6052,6063-6099 feet (� • AOGCC Tubing(size,grade,measured and true vertical depth) 3.5" L-80 9,151' MD 6,020'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FHL RETRIEVABLE PACKER 8,413' MD 5,534'TVD PACKER-BAKER PREMIER PACKER 598-287 8,900' MD 5,845'TVD PACKER-BAKER F-1 PACKER 9,111'MD 5,991'TVD SAFETY VLV-TRMAXX-5E SAFETY VALVE 2,003'MD 1,803'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9020-9036 MD amd 5928-5939 TVD � � ,IA.,, `j OO )U,_.,!L) Treatment descriptions including volumes used and final pressure: 6d r3 Total Well-Single Stage 201,7271bs 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: 98 355 mscf 1290 1285psi 145psi Subsequent to operation: 409 560mscf 2570 1230psi 175psi 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service El Stratigraphic ❑ Copies of Logs and Surveys Run El ())wo�16.Well Status after work: Oil 0 Gas 0 WDSPL 1=IPrinted and Electronic Fracture Stimulation Data d \\�ti\ GSTOR ❑ WINJ 0 WAG El 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: 317-385 Contact Name: Sandeep Pedam Authorized Name: Sandeep Pedam Contact Email: Sandeep.Pedam©cop.com Authorized Title: Staff Completion Engineer • Contact Phone: (907)263-4724 Authorized Signature: , 4,441; Date: Jai\2-1 KJ t d Form 10-404 Re 7ed 41 VTL. ( `BCi 'V i/�2/2„018 �� d�:�� �—' P j � "i? Z Submit Original Only < j r 2 cc etved- • • 3A-01 FRAC STIMULATE DTTMSTP JOBTYP SUMMARYOPS 12/2/17 DRILLING PERFORMED SINGLE STAGE REFRAC INTO KUPARUK C-SANDS. SUPPORT- PUMPED 201,727 LBS WANLI 20/40 PROPPANT INTO FORMATION EXPENSE REI (100% OF DESIGN). JOB COMPLETE. 12/6/17 DRILLING GAUGED TBG TO 2.84" TO TAG FRAC SLEEVE @ 2003' RKB; PULLED SUPPORT- FRAC SLEEVE ©2003' RKB. IN PROGRESS. EXPENSE REI • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 12/2/2017 Job End Date: 12/2/2017 State: Alaska County: Beechey Point API Number: 50-029-21412-00-00 Operator Name: ConocoPhillips Company/Burlington Frac FocusResources Well Name and Number: 3A-01 Chemical Disclosure Registry Latitude: 70.40234900 Longitude: -149.94035800 Datum: NAD83 GROUNDWATER Federal Well: NO ><Oi I&C;�t� Indian Well: NO True Vertical Depth: 6,349 Total Base Water Volume(gal): 120,778 Total Base Non Water Volume: Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS#) (%by mass)** (%by mass)** WATER CONOCOPHILLI BASE FLUID PS Sea Water 7732-18-5 79.45032 Density=8.540 BE-6 Halliburton Biocide MICROBIOCIDE Listed Below • • Wanli 20/40 Halliburton PROPPANT Listed Below MO-67 Halliburton pH Control Addtive Listed Below CL-31 Halliburton Crosslinker CROSSLINKER Listed Below WG-36 GELLING Halliburton Gelling Agent AGENT Listed Below LVT-200 Halliburton Additive Listed Below OPTIFLO-III Halliburton Breaker DELAYED RELEASE BREAKER Listed Below CL-22 UC Halliburton Crosslinker Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below SP BREAKER Halliburton Breaker • • Listed Below Items above are Trade Names with the exception of Base Water.Items below are the individual ingredients. Corundum 1302-74-5 55.00000 8.90239 Mullite 1302-93-8 45.00000 7.28378 Sodium chloride 7647-14-5 4.00000 3.31172 Hydrotreated Distillate, 64742-47-8 100.00000 0.55131 Light Guar gum 9000-30-0 100.00000 0.23919 Water 7732-18-5 100.00000 0.09233 Borate Salts Proprietary 60.00000 0.05374 Potassium formate 590-29-4 60.00000 0.05374 Ethanol 64-17-5 60.00000 0.04127 Oxylated phenolic resin Proprietary 30.00000 0.02751 Potassium metaborate 13709-94-9 60.00000 0.02626 Heavy aromatic 64742-94-5 30.00000 0.02064 petroleum naphtha Ammonium persulfate 7727-54-0 100.00000 0.01926 Sodium hydroxide 1310-73-2 30.00000 0.01176 Crystalline silica quartz 14808-60-7 30.00000 0.00587 Cured acrylic resin Proprietary 30.00000 0.00578 Naphthalene 91-20-3 5.00000 0.00344 Poly(oxy-1,2-ethanediyl), 127087-87-0 5.00000 0.00344 alpha-(4-nonylphenyl)- omega-hydroxy-, branched Potassium hydroxide 1310-58-3 5.00000 0.00219 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00168 propanediol Acrylate polymer Proprietary 1.00000 0.00090 Sodium glycollate 2836-32-0 1.00000 0.00090 Sodium carboxymethyl 9004-32-4 1.00000 0.00090 cellulose 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00069 Sodium persulfate 7775-27-1 100.00000 0.00032 • • I Sodium sulfate 7757-82-6 0.10000 Total Water Volume sources may include various types of water including fresh water,produced water,and recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% "'If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) • • HALLIBURTON ConocoPhillips Alaska Inc Kuparuk River Unit 3A-01 Interval 1 Kuparuk A Kuparuk A Sand Formation Beechey Point County, AK API: 50-029-21412 Prepared for:Sandeep Pedam December 2, 2017 Stimulation Treatment Post Job Report Hybor G 25# 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 P.-o.+""'”" Enh...c.m.est Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval Summary 5 Well Summary 6 Interval 1 Plots 7-12 Appendix 13 Event Logger 14-13 Chemical Summary 14 Planned Design 15 Water Report 16 Water Straps Day 1 17 Bacteria Testing 18 Real-Time QC 19 15 Min Fann 20 Lab Testing 21-22 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 TOC 2 • • Engineering Executive Summary On December 02,2017 a stimulation treatment was performed in the Kuparuk A Sand formation on the Kuparuk River Unit 3A- 01 well in Beechey Point County,AK. The Kuparuk River Unit 3A-01 was a 1 stage Vertical Tubing Design. The proposed treatment consisted of: 3,262 gallons of 25#Linear 113,899 gallons of 25#Hybor G 1,000 gallons of Freeze Protect 200,000 pounds of Wanli 20/40 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: 6,465 gallons of 25#Linear 114,313 gallons of 25#Hybor G 1,006 gallons of Freeze Protect 201,727 pounds of Wanli 20/40 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: 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 Inc-Kuparuk River Unit 3A-01 Executive Summary 3 . • CUSTOMER CasxoPhillips Alaska inc API 59029-21.2 M0LLOSAR 2 : BED(M/poi) e04 UT 70.4026419 LEASE Rupiah Ricer unit 3Ao1 S ORDER 149 BUST CO LONG 93322 FORMATION RuwrseA DATE12/2/17M as Pressure(psi) 5600 1i94id4dditiv24 ryAdditives Prop DActual• Slurry Design Clean al Cleanan Actual Clean Ca14212494 Slurry Design Prop Calculated Prop Le-Surf M66)Cl-22 UC CL-31 LVT-100 WG-36 BE-6 Opliflo-1115P Breaker Treatment Stage Fluid Stage Volume Volume Volume Volume Total Total IntervalNumber Description Description 02/9400049 (980) (4pm) (980) (gad) (140) (661) Ms) (Ws) (9001) (0001) (041)Mr (opt) (gpt) (p,l) (071) (pl.) /448) Shut-ln Shut-in - MR inear load Well 18.0 1,000 688 88 88 1.00 25.00 0.15 2.00 MP HyborG OFIT 18.0 6,524 156 156 1.00 0.40 0.90 0.45 25.00 0.15 2.00 2 Shut-In Shut-in 254 klybarG Pad 18.0 25,000 24,982 595 595 1.00 0.40 0.90 0.45 25.00 0.15 2.00 254 HybarG tLaden Fluid ani20/40 0.50 18.0 9,000 4,964 444 001 2,900 2,182 0.40 0.90 0.45 25.00 0.15 2.00 Ts ee 014 Hyb«G Proppant Laden Fluid 00481100/40 1.00 18.0 15,000 14,989 357 373 15,000 14,989 1.00 0.40 0.90 0.45 25.00 0.15 2.00 _lam 254 Hybor G Proppant Laden Fluid Wan1i 20/40 2.00 18.0 21,000 21,280 507 552 4x,000 42,560 1.00 0.40 0.90 0.45 2,00 0.15 2.00 -Y� 054Hy1470 Prop9ant Laden Fluid Wan1i 20/40 3.00 18.0 25,000 25,100 598 677 75,000 75,300 1.00 D.40 0.90 0.45 25.00 0.15 2.00 05000904,1 Proppant Laden Fluid Wanli 20/40 16,375 16,431 391, 461 65,500 66,396 1.00 040 090 0.45 25.00 0.15 2.00 0.25 259 Linear Flush 18.0 2,262 2,777 66 1.00 25.00 015 2.00 0.50 freeze Protect Freeze Protect 5.0 1000 24 24 1000.00 1 Shut-In 5199.1n _ 118,161 121,784 2,900 3,113 200,000 201,727 Fluid Type Design Total(Rol) Actual Total(pol) Proppant e Design Total(114) Calculated Total(104) Ticket Total(lbs) L 4.54,43000 M 7 C LVT-200 WG-36 BE-6 Op5flo-Ill 54 Breaker 258 Linear 3,262 Wank 20/40 200,000 201,727 201,727 (040) (941) (got) (9011 (94)) (141) (101) (101) (004) 254 Hybor6 113,899 114,313 - - nitial Design Material Volume 117.2 116.2 104.5 52.3 Freeze Protect 1,000 1,006 - - - - Actual Design Material Volume 120.8 45.7 102.9 51.4 1,006.0 3019.5 18.1 241.6 5.5 - - - - - - • Physiol Material Volume Pumped 114 46 95 50 2981 21 MO 4 - - - - - Physical Material Volume Deviance 6% 1% 85 -3% -100% -1% 16% -1% -27% • - - ae I/O numbers)r4,0477nt ore token from software calculations based on multiple variables icro o a Volume Pumped - - - - - - • • - . . 11propp0nt is billed from Weight Ticket volumes MicroMoeon Volume De0ance - - - - - - - • Loaded - - Excess.Bid1 - EawssmActual -w -103 51 3 01- ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Actual Design 4 • •i Interval Summary Kuparuk River Unit 3A-01-Kuparuk A-Interval 1 Interval Summary Date: 12/2/2017 Start Time: 9:53:00 AM End Time: 1:15:00 PM Initial Rate(Breakdown): 14.6 bpm Initial Pressure(Breakdown): 5067 psi Max Rate: 20.8 bpm Max Pressure: 5482 psi Max Pressure(SLF): 5409 psi Average Rate: 19.1 bpm Average Pressure: 4099 psi Average Missile Pressure 4106 psi Average Missile HHP: 1926 hhp Open wellhead Pressure 1490 psi Average Visc: 22 cP Average Temp: 76 F Average pH: 9.3 ISIP: 2107 psi Initial Fracture Gradient: 0.798 psi/ft 5 min: 1386 psi 10 min: 1144 psi 15 min: 991 psi ISDP: 2554 psi Final Fracture Gradient: 0.874 psi/ft 5 min: 2375 psi 10 min: 2226 psi 15 min: 2179 psi Proppant Summary Wanli 20/40 Pumped: 201,727 lbs Total Proppant Pumped* : 201,727 lbs Proppant in Formation: 201,727 lbs Fluid Summary(by fluid description) 25#Linear Volume: 6,465 gal 154 bbls 25#Hybor G Volume: 114,313 gal 2,722 bbls Freeze Protect Volume: 1,006 gal 24 bbls Fluid Summary(by stage description) Load Well Volume: 3,688 gal 88 bbls Pad Volume: 24,982 gal 595 bbls Proppant Laden Fluid Volume: 82,764 gal 1,971 bbls Flush Volume: 2,777 gal 66 bbls DFIT Volume: 6,567 gal 156 bbls Freeze Protect Volume: 1,006 gal 24 bbls Treatment Volume: 121,784 gal 2,900 bbls Total Fluid Volume: 121,784 gal 2,900 bbls Interval Status: Completed Interval Summary 5 • • • Comments: Pumped to design Engineer: Jonathan Alcantar Treater: Chad Burkett Supervisor: Keith Olson *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Hanna Sylte • Interval Summary 6 • • Customer ConocoPhillips Alaska Inc Formation KuparukA „9 a Lt..;Ji}}:,"ff:iry Lease Kuparuk River Unit 3A-01 API 50-029-21412 Date December 02,2017 Well Summary Fluids Proppants Average Max 254 Linear 254 Hybor GFreeze Protect Total Fluid Wanli 20/40 Total Proppant Interval Pr essure Rate Visc I Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl lbs lbs 1 4099 19.1 ' 22 I 76 9.3 5482 208 6465 154 114,313 2,72 624 121,784 2,900 101,727 70171 Fluids Proppants Average Max 254 Linear 254 Hybor G Freeze Protect Total Fluid Waell 20/40 Total Proppant Pressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl lbs Total Planned 3,262 78 113,899 2,712 1,000 24 118,161 2,813 200,000 200,000 Recorded 4099 19.1 22 76 9.30 5482 20.8 6,465 154 114,313 2,722 1,006 24 121,784 2,900 201,727 201,727 Weight Tickets 201,727 201,727 ••IFS numbers for proppant are taken from software calculations ••Proppant Is billed from Weight Ticket volumes ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Well Summary 7 • • Pressure Test Treating Pressure(psi) - — Treating Pressure©Pump(psi) 11 Global Kickout Pressure(psi)— P1 Kickout Pressure(psi) 8000 ® 13 F7—----- 7000 0 ' 6000 L` 5000 4000 11 3000 2000 1000 0 —� 08:55 09:00 09:05 09:10 09:15 09:20 09:25 09:30 12/2/2017 12/2/2017 Time Global Event Log ❑2 Pressure Test-Testing Locals 08:52:04 ❑3 Pressure Test-Testing Globals 08:52:19 ® Pressure Test-PRV Test 08:55:36 ❑5 Pressure Test-Succesful PRVTest 09:12:12 © Pressure Test-one side of pumps 09:14:48 E7 Pressure Test-2nd side of pumps 09:18:43 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 8 • Treatment Plot- DFIT Interval 1 Treating Pressure(psi) A Slurry Rate(bpm) Slurry Proppant Conc(Ib/gal) — C BH Proppant Conc(lb/gal) A B Actual Bottomhole Temp(OF) D Gauge Bottomhole Pr(psi) A C D 8000- 50- l 10 -160 7200- 45- L-9 -144 6400- 40- -8 -128 5600- 35- -7 -112 4800- 30- -6 -96 4000- 25- -5 -80 3200- 20- 4 -64 2400- 15- 3 -48 1600 10- -2 -32 800- 5- -1 -16 - - 0 p ® Q - 0— 0 0 —0 09:55 10:00 10:05 10:10 10:15 10:20 10:25 10:30 12/2/2017 12/2/2017 Time ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 9 • S Treatment Plot- Interval 1 Treating Pressure(psi) A Slurry Rate(bpm) Slurry Proppant Conc(Ib/gal) C BH Proppant Conc(lb/gal) A B Actual Bottomhole Temp(OF) D Gauge Bottomhole Pr(psi) A C D 8000— 50— —10 —160 7200— 45— —9 —144 6400— 40— —8 —128 5600— 35— —7 --112 4800— 30— —6 —96 4000— 25— —5 --80 3200— 20— �• �.4il�lrhtoc�l 4 64 2400— 15— E+"ryM,w.n!! —3 —48 1600 10 —2 —32 800 —1 —16 5 ® ©Ir • • 1 0:00 10:30 11:00 11:30 12:00 12:30 13:00 12/2/2017 12/2/2017 Time ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 10 • • Blender Chemicals -Interval 1 CL-22 UC Conc(gal/Mgal)— A MO-67 Conc(gal/Mgal) A CL-31 Conc(gal/Mgal) A A Optiflo-III Conc(Ib/Mgal) C SP Breaker Conc(Ib/Mgal)— B B C 3.0 —5.0 -100 2.7- -4.5 -90 2.4- -4.0 -80 2.1- -3.5 -70 1.8- -3.0 -60 1.5- -2.5 -50 1.2 k -2.0 -40 0.9 -1.5 -30 0.6- -1.0 -20 M4M 0.3 ® �P -0.5 -10 OQQ ©� ® r. Q� 0.0 , -- -- 1 I 0.0 -0 10:00 10:30 11:00 11:30 12:00 12:30 13:00 1212/2017 12/2/2017 Time ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 11 • • ADP Chemicals - Interval 1 Losurf-300D Conc(gal/Mgal)-- — A WG-36 Conc(Ib/Mgal) B A WG-36 LA-1 Conc(gal/Mgal) C B2 WG-36 Conc-DA1 (Ib/Mgal) B B C 10 100 1000 9- -90 900 8- -80 800 7- -70 700 6- -60 .1' 5- -50 500 4- -40 400 3- I -30 300 2- (�I 61��1i, i,6 6 6 6����ill�ll I lilil 1�����I�16 11 6 16 16iI�I�I ISI I I L -20 200 1 © -10 100 �� ® © ®© ® ® ® oo- 0 1- , , , , , , , 0 0 10:00 10:30 11:00 11:30 12:00 12:30 13:00 12/2/2017 12/2/2017 Time ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 12 • • Net Pressure Plot- Interval 1 —Net Calc'd BH Pres(psi) —BH Proppant Conc(lb/gal) A Slope of Net Pressure(psi/min) C B 100008_ Closure Pressure= 1596 psi —5 7_ 8_ 5- 4 , 3 \ I/yyw _di *1 -3 1000z- 8- 7- e- 0009_8_7_e- -2 5_ 4- 3. /iA"84044#4, -1 2_ 0 Ake=�f2/02/1'f 07:21:5 •• 41 100 3 0 Time(min) Customer: ConocoPhillips Job Date: 02-Dec-2017 Sales Order#: 0904483002 Well Description: KRU 3A-01 3A-01 UWI: 50-029-21412 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Interval 1 Plots 13 • • HALLIBURTON ConocoPhillips Alaska Inc Kuparuk River Unit 3A-01 Interval 1 Kuparuk A Kuparuk A Sand Formation Beechey Point County, AK API: 50-029-21412 Prepared for:Sandeep Pedam December 2, 2017 Stimulation Treatment Appendix - Event Logger - Chemical Summary - Planned Design - Water Report - Water Straps Day 1 - Bacteria Testing - Real-Time QC - 15 Min Fann - Lab Testing ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Appendix 14 s • Stage Treating Slurry Stage Type Time Activity Code Comment Proppant Pressure Rate Slurry (100*Ib) (psi) (bpm) Vol(gal) E 07:21:57 (12/02/17) Start Job Starting Job 0 0 0 0 E 8:52:04 Pressure Test Pressure Test-Testing Locals 2.72 94 0 0 E 8:52:19 Pressure Test Pressure Test-Testing Globals 2.72 123 0 0 E 8:55:36 Pressure Test Pressure Test-PRV Test 2.72 5329 0 0 E 9:12:11 Pressure Test Pressure Test-Succesful PRV Test 2.72 172 0 0 E 9:14:48 Pressure Test Pressure Test-one side of pumps 2.72 5350 0 0 E 9:18:42 Pressure Test Pressure Test-2nd side of pumps 2.72 5740 0 0 S 9:54:13 Next Stage Shut-In 2.72 1517 0 0 S 9:57:40 Next Stage Load Well 0 1851 5.4 4 S 10:03:46 Next Stage Fluid Efficiency Test 0 4402 17.4 12 S 10:12:40 Next Stage Shut-In for FET Analysis 0 2105 0 0 S 10:28:28 Next Stage Pad 0 992 0 0 S 11:02:37 Next Stage Proppant Laden Fluid 0.01 3826 18 24982 S 11:09:19 Next Stage Proppant Laden Fluid 0.12 4118 19.8 14 S 11:27:57 Next Stage Proppant Laden Fluid 154.95 4116 20 15677 S 11:55:32 Next Stage Proppant Laden Fluid 433.11 4112 20 23203 S 12:29:21 Next Stage Proppant Laden Fluid 750.61 4259 20 28433 S 12:52:05 Next Stage Flush 598.05 3868 20 19087 S 12:55:23 Next Stage Other 0.43 4047 20.4 2779 S 12:57:52 Next Stage Shut-In 0 2529 0 1006 E 14:58:43 End Job Ending Job 0 -3743 0 0 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Event Logger 15 • • Customer ConocoPhillips Alaska Inc Formation KuparukA HALL I Production E nhcfncement Lease Kuparuk River Unit 3A-01 API 50-029-21412 Date 12/2/2017 Interval Summary-Chemicals Liquid Additives Dry Additives Lo-Surf 300D MO-67 CL-22 UC CL-31 WG-36 BE-6 Optiflo-Ill SP Breaker Interval (gal) (gal) (gal) (gal) lbs lbs lbs lbs Prime Up 0 0 0 0 0 0 0 0 1 114 46 95 50 2981 21 240 4 Total 1 114 46 95 50 2981 21 240 4 w/o Prime Up 114 46 95 50 2981 21 240 4 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Chemical Summary 16 0 0 CUSTOMERCono.Phillips Alaska Inc API RFO06/pal) 854LAT 70.4025419 LEASE Kuparuk Mer Unit3A0i SALES ORDERBHST(F) LONG 14993717 FORMATION avparokA DATE 04/1/40 Mu Pressure(psl) 5600 Liquid Adddlves Dry Additives Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Menial Lo-Sort 3000 MO-67 CL-22 UC CL-31 400-200 WG-36 0E-6 Opbflo-III 53 Breaker Trea.ent Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total s Time m• creed... . er + er r e is Breaker ea er !MenialNumber Description Description Description WO (b,..1 (gal) (6611 (40) (lbs) (49751144) (AA:mm:1,) (ppz) WO No)) WO) (go) (pp)) (p39) OA) (p7: Shut-In Shut-In 214'.03 pLoad Well 1,000 24 24 0'.01'.19 2500 0.15 2.00 pHyb.,4 NIT 18 6,524 155 155 0'.00138 14203 1.00 1.00 0.90 0.45 25,00 0.15 2.00 4 Shut-In Shublo 2,30. • 250 HyborG Pad 18 25,000 :34:06 1.00 1.00 0.90 25.00 0.15 2.00 _` 258 HyborG Proppant Laden Fluid Wanli 20/40 0.50 18 s,000 0:06:46 2:01:02 1.00 1.00 0.90 2s.00 0,15 2.00 etc 254 Hybor0 Proppant Laden Fluid Wang 20/40 100 18 15,000 357 0:20:45 1:50:16 1.00 1.00 090 0.05 25.00 0.15 100 „g _jci 8 354 HyborG Proppant laden Fluid Wanli 20/40 21000 500 0:30:19 1:33:31 1.00 1.00 0.911 0.45 25.00 0.15 2.00 9 254 HyborG Proppant Laden Fluid Wan(20/00 3.00 18 25,000 595 675 75,000 0:37:36 1:03:12 1.00 1.00 0.90 0.05 25.00 0.15 2.00 10 251 HyborG Proppant Laden Fluid Wanli 20/00 400 18 16,375 390 459 65,500 .5:37 0:25:37 100 1,00 090 015 2.00 11 IIR linear Flush 18 2,263 54 54 0:03:00 0:07:45 1.00 1,00 0,90 0,45 25.00 0.15 2.00 0.50 Freeke xe Protect 5 1,000 24 24 0:0416 0:.:06 1000.00 13 Shut-In Protect reshut-in 118,161 2,813 3,025 200,000 25110 Fluid Type Design Total(gal) Propnanc 0 Design Total(lbs) 10-5.13008110-5.130081MO-67 C1-2200 CL-31 401-200 WG-36 BE-60ptiflo-III 54 Breaker 254 Linear 3.262 Pad Volume 25,000 Wank 20/40 200,000 (gal) (got) (901) (9o)) NO lbs 141 lbs lbs 154 Hybar G 113.899 PLF Volume 82,375 17iga1 Design 0811011 Volume 117.2 116.2 104.5 52.3 1,000.0 2,929.0 17.6 234.3 1.1 Freeze Protect 1,000 Pad Se, 0.23 - • to". - - 1300D MD-67 6122 UC CL-31 LVT-200 WG-36 R Cpti80411 5P Biea leer ,) - - - (9p (4001) (4/214 (Ppm) (ppm) ppm ppm OM ppm - ax Additive Rate 0.8 0,8 0,7 0,3 756.0 18.9 0.1 1.5 0.4 . - Min AddltNe Rate V ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-U1 Planned Design 17 • • HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocoPhillips Alaska,Inc. Well Name/No.: 3A-01 Date Tested: December 1,2017 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 -- 1.023 1.023 1.022 1.023 1.022 1.0220 1.0230 pH -- 7.5 7.66 7.67 7.64 7.68 7.75 7.76 Iron(Fe) mg/L 0 0 0 0 0 0 5 Chloride(CI) mg/L 18792 22392 22392 32850 22392 18792 22392 Sulfate(SO4) mg/L 1200 1200 800 1200 1200 1200 1600 Hardness mg/L 425 425 _ 425 425 425 425 425 Linear Viscosity cp _ 18 18 20 17 17 16 18 Crosslink pH pH 9.6 9.2 9.5 9.9 9.5 9.8 9.13 Crosslink Test(Y/N) • 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(CI) mg/L Sulfate(SO4) mg/L Hardness mg/L • Linear Viscosity cp Crosslink pH pH _ Crosslink Test(YIN) Units Tank 19 Tank 20 Tank 21 Tank 22 Tank 23 Tank 24 Tank 25 Specific Gravity pH Iron(Fe) mg/L Chloride(CI) 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 pan there of nor copy thereof maybe published or disclosed without first securing the express written approval of laboratory management.It may however,be used hr 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 Inc-Kuparuk River Unit 3A-01 Water Report 18 • • Customer: ConocoPhillips Alaska, Inc. Well: 3A-01 Date: 12/1/2017 Zones: 1 TICKET#: BEGINNING STRAP VOLUME VOLUME TEMP ENDING STRAP VOLUME VOLUME TANK# TANK TYPE FEET INCHES (GAL.) (BBLS.) DEG F FEET INCHES (GAL.) (BBLS.) 1 500 MISER 101 20,370 485 99 7 1,323 32 2 500 MISER 102 20,580 490 100 40 7,602 181 3 500 MISER 102 20,580 490 93 7 1,323 32 4 500 MISER 103 20,790 495 94 10 1,890 45 5 500 MISER 99 19,950 475 93 6.5 1,134 27 6 500 MISER 102 20,580 490 93 6 1,134 27 7 500 MISER 94 18,900 450 94 10 1,890 45 8 500 MISER 70 13,860 100 70 13,860 330 9 10 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Transport TOTAL: 155,610 3,375 TOTAL: 30,156 718 Minus 50 bbl bottoms 3,015 Water summary Starting(gal) Used(gal) 125,454 Starting(bbl) Used(bbl) 2,987 ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Water Straps Day 1 19 • 0 • Date: Analysts Data 3A-01 Sampling data Chemistry batch N Sample collection Date Reaction Time Minimum reaction time is 10 minutes Sampled by Standard Value Measured 600.1 Ambient temperature deg t 3%of Instrument STD VAL Samples analysed by Instrument Standard Value 60 deg F Company BV Substrate Vial 1: 66.81 15.6 deg C Sample ID Room temp Reaction time Analytical Blank Value Sample Volume filtered Dilution Multiplier Sample Analysis value BQ value Sample and Analysis Notes (degC) (min) (FLU) (ml) if needed (FLU) Calculated Tank 1 15.6 30 • 66.81' 50 1 158.2 399 Tank2 15.6 30 66.81 50 1 93.44 116 Tank3 15.6 30 66.81 50 1 92.75 113 Tank4 15.6 30 66.81- 50 1 140.4 321 Tanks 15.6 31 66.81. 50 1 • 119.6 223 Tank 6 15.6 31 66.81 50 1 668.9 2545 66.81 50 1 200.4 565 rmocoPMlips Alaska lrc-NuparukR UNtak01 axterla Testing 20 • • HALLIBURTDN Customer: ConocoPhillips Alaska,Inc. Wellname&#: 3A-01 Date: December 2,2017 XL Linear Linear XL Interval Stage Visc pH Temp°F pH Comments Interval Stage Visc pH Temp°F pH Comments I Mini-Frac 25 76 9.4 2 Pad 22 78 9.2 3 1# 20 78 9.21 4 2# 21 76 9.2 5 3# 22 76 9.2 6 4# 22 76 9.32 ConocoPhlllips Alaska Inc.Kupa,uk River Ilnh 30.01 Real Time 51 71 • • HALLIBURTON Fluid is broken et200ep Zone 1 Crosslink Tests ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report -Pad -1 ppg -2 ppg -3 ppg -4 ppg —5 ppg 3500 Fluid System: Date: 12/2/2017 3000 Company: ConocoPhillips Project No: 2500 Well Name: 3A-01 Stage(s): 1 2000 BHST(°F): 165 Water Source: O 1500 Depth: Water pH: Formation: Hydration pH: > loco Analyst: ' Hydration Visc: cp @ 500 oP- 00:00 01:00 02:00 03:00 04:00 05:00 08:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time(min:sec) All oh.miul concentrations below are in gallon per thousand/pounds per thousand Lot Number--> ConocoPhIllips Alaska Inc-Kuparuk River Unit 3A-01 15 Min Fann 22 S HALLIBURTON Prudhoe Bay Field Laboratory-Rockies NWA Laboratory Project ID Number: 2053385 Customer: ConocoPhillips Well Name&Number: 3A-01 Fluid System: Hsbor G Date: December 2.2017 Summary of Test ar.d Rrsdts u:t 10 minutes at 11 ...sec at 100 deg ces ARet 10 minute:the:heat rate wa:decreased to 100 1 ;ec-and the.ample wa:brought up to temperatue with in 2 0uuautes te:ttng wa:done u:mg Location SeawatertSLa622l e;Pertom:ug Te:.n :ucm Doyle Renew. t.Apps oc'ed H} ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Lab Testing 23 S • JOB INFORMATION AND TESTING CONDITIONS 0.11000110: Celiac*Phalli's Fx.:3,:vstetr.,. Hybor G Bob Tip.. 35 Weil Name 3A-01 Water Source Seawater Sbear Rai*(:vec1 512 10) Date. December 2.2017 BRIT t.F 259 Lab Project D 20533E5 FLU1D.i Test No 0 : Gel Ifyinrire eive, 1,09 Chemical Volts atitaMa(-41WM176Mal 331= Vt.cos, cP 74./kc 4F :'30 05 CC 0":: ::00. 20 C0 1 14 C 55-31 Fp 003 015 :1' C:` C:' 1 r e ... -: 00 1 CC :CC 1 a: 1 1,3 3 19 C Fr 005 0.25 315 505 '0' - 000 -, 003:01:: FF• 090 090 093 090 C34: 010 1 g,t 045 045 5.33 000 C4' :0 6 ,.„ 00 0 3: : 20 C :P Er4a1.4.-. Pr 4 :0 C -; . . . . . . .. null)PROPERTIES est No 0 2 3 r, . ay, 1.14 Water pH 090 699 699 999 699 s:za vl.•J., .t 7taaap ,F Base Gel(a) :'30 0009 0000 200'S 2C 00 Base Gel'cur(cP) 250 :0 0 200 140 140 , BaseGelpH "4.: '42 -4' -4: *4: 1'4 :.):. Base Gel Temp(7; ": 'C -0 -0 . l'4 :X Buffered pH 103 0 51 303 1?) 09: i'4 :30 (casaba pH On 931 3-. 4 4 ':3 t r 3 m Fula;pH on S S3 '00 '0: o E: - 30: 100 Tetz Temp ma)(F1 :'o 1 1•..., .-- .', I' 1 15.5 100 Break Time;la :.• I . 1 ... _ 1 c. 154 ICC IC 15.4 090 Test Noses Break Time 2 was to.200cp.sae:pi/wan tmaer 509...1-34brs Break'Anse 2,Nr3 5:o 200cp sample nem taa&_r 5113,cp,,5 00brs BREAK TEST CHART .....,••. .....,....,, —.....t. ,,„,.,„ 799 ' f 00 -7•7.7-3 7.4k 5 - - '11 " -1: 570 ., . ' A .• ' t sal - 'C. : 4 C , • 1 la: *I 411i1.11'IA 4. „.., : •100 f : v • ao *......,, oo 100 L \,•,..,_....... '1/4\.44................. eo ,ao ...---, 000 L.LI 7.000 RN .0411 000 tit 1:14 Villejlt.IM ConocoPhillips Alaska Inc-Kuparuk River Unit 3A-01 Lab Testing 24 KUPOD 3A-01 ConocoPhillips0.4'.' Well Attrib Max An MD TD ral/lskh.in, Wellbore APIIUWI Field Name Wellbore Status Inc'(°) MD(ftKB) Act Btm(ftKB) Caroo, ph- o, 500292141200 KUPARUK RIVER UNIT PROD 56.28 2,400.00 9,600.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-01,1/21201810121 PM SSSV:TRDP 160 11/30/2016 Last WO: 10/16/2006 35.19 9/1/1985 Vertical sphamaPp(aplva') Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.RKB 9,310.0 9/5/2017 Rev Reason:SET CATCHER 8 FRAC SLEEVE, pproven 1/2/2018 FRAC,PULL FRAC SLEEVE,GLV C/O,PULL -1!ti',1nrT'1t1r Casing Strings NI HANGER 30.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I Grade Top Thread R Casing Description riOD(in) 16 ID('In)15.062,Topp(ftKB)31.0 Set Depth(ftKB)104.0 MG)104.0 62.50 H-40 WELDEDTea u.wSet Depth(TVD)...Wt/Len(1 Grade Top Thread MOWS SURFACE 95/8 8.921 30.2 4,353.4 3,157.2 36.00 J-55 BTC CONDUCTOR,31.0-104 0 Casn Description OD(in) ID(m To ftKB Set Depth ftKB) 'Set Depth(ND)...Wt/Len(I. Grade Top Thread PRODUCTION 7 6.276 23.7 9,575.0 6,331.3 26.00 J-55 BTC i`�q Tubing Strings SAFETY VLV;2,003.4 t ',, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection lam TUBING WO 31/2 2.992 30.2 9,151.5 6,020.7 9.30 L-80 EUE 8RD Completion Details IF Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,6446 30.2 30.2 0.11 HANGER FMC TUBING HANGER 2.992 2,003.4 1,802.9 48.47 SAFETY VLV TRMAXX-5E SAFETY VALVE 2.812 8,398.9 5,526.3 53.49 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 8,398.9 5,526.3 53.49 PBR PBR 80-40 3.000 8,412.6 5,534.4 53.36 PACKER BAKER FHL RETRIEVABLE PACKER 2.990 SURFACE,30.24,353.4_J 8,900.1 5,845.1 46.88 PACKER BAKER PREMIER PACKER 598-287 2.870 8,957.4 5,884.4 46.44 NIPPLE HES'X'NIPPLE 2.813 9,034.7 5,937.9 45.67 BLAST RING CARBIDE BLAST RING(1) 2.992 GAS LIFT;5,975.7 9,101.9 5,985.3 44.80 SLEEVE-O BAKER CMU SLIDING SLEEVE w/2.812'BX PROFILE 2.812 (OPEN 3/15/2007) 11 9,110.5 5,991.4 44.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 9,110.5 5,991.4 44.71 PACKER BAKER F-1 PACKER 4.000 GAS LIFT;7,315.1 9,113.8 5,993.8 44.67 SBE BAKER SEAL BORE EXTENSION 4.000 al 9,124.0 6,001.0 44.56 MILLOUT MILL OUT EXTENSION 4.390 EXT It 9,145.9 6,016.7 44.32 NIPPLE CAMCO'D'NIPPLE w/2.75"PROFILE 2.750 GAS LIFT,8,340.5 9,151.0 6,020.3 44.26 WLEG WIRELINE ENTRY GUIDE 3.000 Perforations&Slots 111 Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date k) Type Com PBR;8,398.9 9,020.0 9,036.0 5,927.7 5,938.9'C-1,3A-01 11/10/1985 ' 12.0 IPERF 5"HyperJet II,120 deg. ph PACKER;8,412.6 ° 9,165.0 9,195.0 6,030.3 6,051.9'A-3,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet 11,90 deg. ph 9,210.0 9,260.0 6,062.8 6,099.2'A-2,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet II,90 deg. ph Stimulations&Treatments PACKER;8,900.1 ,.wa eca. Proppant Designed(lb) Proppant In Formation(Ib) Date ..-.: 201,727.0 201,727.0 12/2/2017 Stimulations&Treatments Vol Clean Pump Stg 6 Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl( Vol Slurry(bbl( NIPPLE;8,957.4 1 9,020.0 9,036.0 12/2/2017 Hybor G,Gelled Salt Water 2900.00 Mandrel Inserts PRODUCTION;8,978.7 St '-' ati -1 on N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,644.9 2,742.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,258.0 12/7/2017 7.00 Hydraulic Fracture;9,020.0 IPERF;9,020.0-9,036.0 _ 2 5,975.7 4,103.5 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 12/7/2017 9:00 3 7,315.1 4,903.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/26/2017 '3:30 4 8,340.5 5,491.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/26/2017 '5:00 5 8,978.7 5,899.1 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 10/16/2006 11:30 Close • / d Notes:General&Safety SLEEVE 0;9,101.9 End Date Annotation 9/29/1998 'NOTE:Top of junk @ 9332'MD 12/21/2010 NOTE: IA x OA COMMUNICATION PACKER;9,110.5 1/6/2011 'NOTE:View Schematic w/Alaska Schematic9.0 SBE;9,113.8 10/12/2012 NOTE:RIG RKBs ORIGINAL vs 2006 WORKOVER AFFECTS PROD/TBG TOPS 11/12/2017 NOTE:DUMP BLR(LOADED W/CALCIUM CARBONATE)9,131'-9,124' MILLOUT EXT;9,124.0 rii4 I NIPPLE,9,145.9 WLEG;9,1510 ,' ~ IPERF,9,165.0-9,195.0- IPERF;9,210.0-9,280.0 PRODUCTION;23.7-9,575.0 • RECEIVEC 2:41c.2 NOV 01 2017 CEPS Memory Multi-Finger Caliper AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-01 Log Date: October 21, 2017 Field: Kuparuk Log No.: 12807 State: Alaska Run No.: 3 API No. 50-029-21412-00 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 9,151 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the WLEG at 9,151 feet(Driller's Depth). During the first caliper run, the tool opened late resulting in a loss of coverage for the bottom of the 3.5 inch tubing. A second run was made to log what was missed with the first run. This report is a combination of both caliper runs. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in good to fair condition, with a maximum recorded wall penetration of 24% in a line of pits in joint 56 (1,743 ft). No significant areas of cross-sectional wall loss are recorded. The caliper recordings indicate scale-like deposit throughout the majority of the 3.5 inch tubing, increasing in severity with depth, restricting the I.D. to 2.41 inches in joint 241 (7,619 ft). 3-D log plots of the caliper recordings across the bottom of the 3.5 inch tubing where the scale is most significant are included in this report. A graph illustrating minimum recorded diameters on a joint-by-joint basis is included in this report. This is the third time a PDS caliper has been run in this well and the second time this 3.5 inch tubing has been logged. A comparison of the current and previous log (May 16, 2017)of the minimum recorded diameters indicate a slight decrease in recorded I.D. restrictions from -8,400 feet to-9,000 feet. A graph illustrating the difference in minimum recorded diameters on a joint-by-joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : SCANNED y; rt Percent\P'-'1 Thnetration Line of Pits 24 56 1,743 Ft. (MD) Line of Pits 24 53 1,642 Ft. (MD) Line of Pits 22 57 1,775 Ft. (MD) Line of Pits 22 281 9,003 Ft. (MD) Line of Pits 20 59 1,838 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MAXIMUM RECORDED ID RESTRICTIONS : Minimum Recorded Diameter Joint Heavy Deposits 2.41 inches 277 7,619 Ft. (MD) Deposits 2.71 inches 267 8,850 Ft. (MD) Deposits 2.72 inches 281 8,968 Ft. (MD) Deposits 2.73 inches 282 8,736 Ft. (MD) Deposits 2.73 inches 268 8,872 Ft. (MD) R. Holden C. Waldrop E. Zemba Analyst(s) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3A-01 Date : October 21, 2017 Description : Detail of Caliper Recordings Across Scale Recorded in 3.5 Inch Tubing(Run 1). Comments Depth Nominal I.D. 3-D Log Image Map 1ft:600ft 2.5 0°3.5 0° 0° 90° 180° 270° 0° Maximum I.D. 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 Average I.D. 2.5 inches 3.5 Joint 189 _ I Pup Joint GLM 2 5975 Pup Joint 911111.11111111111 6000 _ 11111114M111111111111.111111 Joint 190 (! 6025 361111 Joint 191605011111111 Joint 1926075Joint 193 6100 Joint 194 6125 :1175: J�Joint 193 11111 Joint 196 6200 111Joint 197 6225 6250 F Joint 198 6275 2 I Joint 1991• k ll 6300 ' 11111. Joint 200 6325 IIIIII Joint 201 6350ll � a 6375 Joint 202 III 6400 i Joint 203 6425 MI Joint 204 6450 ► 11 a III Joint 205 6475 I. 6500 Joint 206 k /1111 6525 Joint 207 6550 Joint 208 6575 1 Joint 209 6600ir 1 6625 11 Joint 210 E 111111 6650 d Joint 211 6675 Joint 212 6700 ii.jf'iu... Joint 213 6725 , It. 6750 ` Joint 214 r 6775 Joint 215 :.' hi 6800 k 11 Joint 216 6825 i a Joint 217 6850 t i j 6875 Joint 218 ' ii r 43 6900 f Joint 219 i 6925 Joint 220 6950 1 Joint 221 6975 I 7000 Joint 2227025 Joint 223 7050 .. Joint 224 i 7075 ' 'w i t Joint 225 7100ii . a a.a 7125 Joint 226 1 7150 JVII1I.GG/ 7175 • Joint 228 7200 Joint 229 7225i i_. 7250 Joint 230 7275 - it i . Joint 231 1: 7300 Pup Joint GLM 3 7325 Pup Joint Joint 232 7350 li 7375 Joint 233 i I 7400 . Joint 234 • 7425 = Joint 235 7450 • Joint 236 7475 Joint 237 7500 7525 Joint 238 7550 Joint 239it 7575 ....!1/4. - Joint 240 7600 7625 Joint 241 7650 Joint 242 7675 Joint 243 7700 I-- Joint 244 7725 7750 Joint 245 7775 Joint 246 7800 Joint 247 7825 • Joint 248 7850 7875 Joint 249 7900 t< Joint 250 7925 Joint 251 7950 Joint 252 7975 8000 Joint 253 8025 f: Joint 254 8050 Joint 255 - _ 8075 Joint 256 8100 3f 8125 • Joint 257 8150 • Joint 258 - 8175 Joint 259 ir 8200 Joint 260 8225 Joint 261 8250 8275 Joint 262 8300 ' I r } Joint 263 8325 Pup Joint — GLM 4 8350 ...11111111 — — , Pup Joint _ Joint 264 8375 Pup Joint• 8400 • • Seal Assembly PBR >r Packer 8425 Average I.D. f I 2.5 inches 3.5 Minimum I.D. 2.5 inches 3.5 Maximum I.D. 2.5 inches 3.5 Comments Depth Nominal I.D. 3-D Log Image Map 1ft:600ft'2 5 3.5 0° 0° 90° 180° 270° 0° (114-3S PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3A-01 Date : October 21, 2017 Description : Detail of Caliper Recordings Across Scale Recorded in 3.5 Inch Tubing(Run 2). Ccmments Depth Nominal I.D. 3-D Log Image Map 1ft:360ft 2.5 3.5 0° 0° 90° 180°;, 270° 0° Maximum I.D. I I 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 Average I.D. I I 2.5 inches 3.5 vrvv r Seal Assembly ` — � IMP PBR ■ ; iit i ! Packer 8425 111 r Joint 285 (f 8450 — i 6 Joint 266 -7-1F--1111 ' 8475 ' 7 A I Joint 267 8500 4 - lit i L 8525 .74W i Joint 288 7,...5.1 ..n. ... ..:.zi 8550 J Joint 269 s, 8575 Joint 270 8600 Joint 271 8625 8650 Joint 272 8675 Joint 273 8700 Joint 274 8725 nrirlE Joint 276 8750 8775 Joint 276 - 8800 Joint 277 Air 8825 11_ L411 Joint 278 8850 1111 11111 Joint 279 8875 C Pup Joint ::: IIMIPII PackerPup Jointmu Joint 280 11111Mt6ill1111111111 1111111111.11111111111111 Pup Joint 8950 Npple PupiJoint --� �--N,EI----- Pup Joint 8975 III 11111111 GLM S mumiu � � .M. AM "" ^^— Pup Joint 9000 110 i111111 Iil EE 11111 9025r11LJi1111! 9050 9075 t 9100 Sliding Sleeve 81=.1111111111- Packer 1,11..11. Millout Extension 9125 • Pup Joint / Ili D Nipple Pup Joint 9150 WLEG • Average LD. I 2.5 inches 3.5 Minimum I.D. I 2.5 inches 3.5 Maximum I.D. I- 2.5 inches 3.5 Ccmments Depth Nominal I.D. 3-D Log Image Map I1ft:360ft 2 5 3.5 0° 0° 90° 180° 270° 0° Minimum Measured Diameters Comparison To Previous Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Previous Date: May 16,2017 Company: ConocoPhillips Alaska, Inc. Tubing: 3.5"9.3 lb L-80 EUE 8RD Country: USA Tubing I.D.: 2.992 inches Overlay Difference Minimum Measured Diameters(in.) Difference in Minimum Diameters(in.) 1.75 2 2.25 2.5 2.75 -0.5 -0.25 0 0.25 0.5 0.1 9 1 0.1 1 25 764 25 50 1,544 50 72 2,257 72 97 3,038 1 119 3,751 I 1119 `+ e d a 3 CZ 144- 4,532 3 X1.4 Z Z ; , ..y 1 t c I y I 169- 5,310 G 1.9 I 191- 6,023 1•1 216= 6,805 21. i 238- 7,520 238 1 263 8,301 263 i 279.2 8,900 279.2 I U October 21,2017 U May 16,2017 Correlation of Recorded Damage to Borehole Profile • Pipe 1 3.5 in (9.1'-9,151.0') Well: 3A-01 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: October 21,2017 ® Approx.Tool Deviation ■ Approx.Borehole Profile 1 12 1111 40 1,232 80 — 2,505 ANN GLM 1 120 3,782 160 5,030 CLI GLM2 tt Z200 _'i 6,305 n o p GLM 3 240 7,583 GLM 4 ..•�• GLM 5 280 "Wm= 8,920 Pr- 283.9 r-283.9 9,151 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=283.9 Minimum Diameter Profile CES.4, Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters(in.) 1.75 2 2.25 2.5 2.75 0.1 - 9 25 764 50 1,544 72, 2,257 97 3,038 119 3,751 144 4,532 CIZ e a. O 169 5,310 y G 191 6,023 216 6,805 I I I � � 2387,520 263; 8,301 279.2 8,900 PDS Report Overview Body Region Analysis Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD 2.992 in. 9 ft. 9,151 ft. Penetration(%wall) Damage Profile(%wall) 400 Imo Penetration body Metal loss body 0 50 100 0.1 300 200 50 100 0 0 to 20 to 40 to over 98 20% 40% 85% 85% Number of joints analyzed(total=305) GLM 1 (7:00) 300 5 0 0 146 Damage Configuration(body) 30 __-- GLM 2 (10:30) 194 20 �- s= 10 GLM 3 (4:00) 242 0 GLM 4(5:00) Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (12:30) Number of joints damaged(total=46) 27 0 19 0 0 Bottom of Survey=283.9 11:RS PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 9 0 0.02 6 0 2.92 Pup Lt, Deposits. 1 12 0 0.03 11 2 2.94 a 2 44 0 0.03 13 3 2.94 3 78 0 0.03 13 3 2.94 ■ 4 106 0 0.03 10 2 2.94 U 5 142 0 0.03 11 3 2.94 ■ 6 172 0 0.03 12 3 2.95 ■ 7 203 0 0.03 12 4 2.94 ■ 8 235 0 0.03 12 3 2.95 ■ 9 266 0 0.04 17 4 2.94 Shallow Line of Pits, 10 297 0 0.04 15 3 2.94 Shallow Line of Pits. a 11 329 0 0.03 12 4 2.94 12 360 0 0.04 15 3 2.95 Shallow Pitting. a 13 390 0 0.03 12 3 2.94 a 14 422 0 0.04 15 3 2.95 Shallow Pitting. 15 453 0 0.03 12 2 2.94 ■ 16 484 0 0.04 16 3 2.94 Shallow Pitting. 17 515 0 0,04 17 3 2.95 Shallow Pitting. 18 547 0 0.04 16 4 2.94 Shallow Pitting. 19 578 0 0.04 15 3 2.94 Shallow Pitting. ■ 20 609 0 0.05 18 3 2.94 Shallow Pitting. ■ 21 639 0 0.04 15 4 2.95 Shallow Pitting. ■ 22 671 0 0.03 12 1 2.93 Lt. Deposits. ■ 23 702 0 0.04 16 3 2.93 Shallow Pitting. Lt.Deposits. ■ 24 733 0 0.05 19 4 2.94 Shallow Line of Pits. 25 764 0 0.05 18 3 2.94 Shallow Line of Pits. 26 796 0 0,04 17 4 2.95 Shallow Pitting. 27 827 0 0.03 13 3 2.94 ■ 28 858 0 0.04 15 3 2.94 Shallow Pitting. 29 889 0 0.04 17 4 2.93 Shallow Line of Pits.Lt. Deposits, 30 920 0 0.04 17 3 2.94 Shallow Line of Pits. a 31 951 0 0.04 15 3 2.95 , Shallow Pitting. 32 983 0 0.03 13 3 2.94 ■ 33 1014 0 0.04 15 2 2.93 Shallow Pitting. • 34 1046 0 0.04 15 3 2.93 Shallow Line of Pits. a 35 1076 0 0.04 15 2 2.93 Shallow Pitting. Lt.Deposits. a 36 1108 0 0.03 13 2 2.93 ■ 37 1139 0 0.03 12 2 2.93 Lt. Deposits. a 38 1170 0 0.03 13 3 2.92 Lt. Deposits. ■ 39 1201 0 0.04 15 3 2.93 Shallow Pitting. Lt.Deposits. 40 1232 0 0.05 18 2 2.88 Shallow Pitting. Lt.Deposits. ■ 41 1264 0 0.04 17 2 2.90 Shallow Line of Pits.Lt. Deposits. ■ 42 1294 0 0.03 10 2 2.89 Lt. Deposits. r 43 1326 0 0.04 16 4 2.88 Shallow Pitting, Lt.Deposits. 44 1357 0 0.04 17 3 2.90 Shallow Pitting. Lt.Deposits. ■ 45 1387 0 0.05 19 3 2.90 Shallow Pitting, Lt.Deposits. 46 1418 0.05 0.04 17 2 2.90 Shallow Pitting. Lt.Deposits. ■ 47 1450 0 0,05 18 4 2.86 Shallow Pitting. Lt,Deposits. 48 1482 0 0.04 17 4 2.91 Shallow Line of Pits.Lt. Deposits. 49 1513 0 0.05 18 4 2.93 Shallow Line of Pits.Lt. Deposits. Penetration Body Metal Loss Body Page 1 \-1-i6 PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 UM 50 1544 0 0,05 19 4 2.92 Shallow Pitting. Lt.Deposits. 51 1575 0 0.05 19 3 2.93 Shallow Pitting. 52 1606 0 0.03 13 3 2.94 C 53 1638 0 0.06 24 2 2.89 Line of Pits. Lt.Deposits. 54 1669 0 0.05 18 3 2.88 Shallow Line of Pits.Lt. Deposits. 55 1699 0 0.05 18 3 2.88 Shallow Line of Pits.Lt. Deposits. 56 1731 0 0.06 24 4 2.87 Line of Pits. Lt.Deposits. - 57 1762 0 0.06 22 4 2.87 Line of Pits. Lt.Deposits. - 58 1794 0 0.04 17 3 2.88 Shallow Line of Pits.Lt.Deposits. - 59 1825 0 0.05 20 2 2.90 Line of Pits. Lt.Deposits. 60 1856 0 0.04 15 2 2.89 Shallow Pitting. Lt.Deposits. im 61 1888 0 0.04 16 2 2.88 Shallow Line of Pits.Lt. Deposits. in 62 1919 0 0,03 11 0 2.88 Lt. Deposits. IN 63 1950 0 0.04 15 1 2.88 Shallow Pitting. Lt.Deposits. VII me 63.1 1982 0 0.03 13 0 2.93 Pup Lt. Deposits. 63.2 1992 0 0 0 0 2.81 3.5"TRMAXX-5E SSSV iii 63.3 1996 0 0.03 11 1 2.89 Pup Lt. Deposits. r 64 2007 0 0.03 12 0 2.88 Lt. Deposits. 65 2038 0 0.02 9 0 2.88 Lt. Deposits. • 66 2069 0 0.03 11 1 2.90 Lt. Deposits. r 67 2100 0 0.02 9 0 2.88 Lt. Deposits. • 68 2131 0 0.02 6 1 2.89 It Deposits. II • 69 2162 0 0.02 7 0 2.88 It Deposits. 70 2193 0 0.02 9 0 2.88 It Deposits. • 71 2225 0 0.02 7 0 2,87 It Deposits. 72 2257 0 0.02 9 0 2.87 Lt. Deposits. • 73 2287 0 0.03 10 0 2.88 Lt, Deposits. • 74 2318 0 0.03 11 0 2.87 Lt. Deposits. • 75 2350 0 0.02 7 0 2.86 Lt. Deposits. • 76 2381 0 0.02 9 0 2.87 Lt. Deposits. • 77 2412 0 0.03 10 0 2.84 Lt. Deposits. • 78 2443 0 0.02 7 0 2.88 Lt. Deposits. • 79 2474 0 0.03 13 0 2.85 Lt. Deposits. im 80 2505 0 0.04 15 0 2.88 Shallow Pitting. Lt.Deposits. MI 81 2539 0 0.03 12 0 2.88 Lt. Deposits. • 82 2569 0 0.02 9 0 2.87 Lt. Deposits. • 83 2600 0 0,02 9 0 2.87 Lt. Deposits. ■ 84 2631 0 0.03 10 0 2.88 Lt. Deposits. a 85 2663 0 0.02 7 0 2.88 Lt. Deposits. • 86 2694 0 0.03 11 0 2.87 Lt. Deposits. MI 87 2724 0 0.01 4 0 2.87 Lt. Deposits. 88 2755 0 0.03 12 0 2.89 Lt. Deposits. Om 89 2786 0 0.02 7 0 2.88 Lt. Deposits. • 90 2818 0 0.02 7 0 2.87 It Deposits, ■ 91 2849 0 0.02 7 1 2.87 It Deposits. s 92 2881 0 0.02 6 0 2.88 Lt. Deposits. o 93 2913 0 0.01 5 0 2.88 Lt. Deposits. i • 94 2944 0 0.03 10 0 2.88 Lt. Deposits. 95 2974 0 0.02 9 0 2.88 Lt. Deposits. • 96 3005 0 0.01 5 0 2.89 Lt. Deposits. • Penetration Body Metal Loss Body Page 2 iiirS PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 • 97 3038 0 0.02 7 0 2.89 Lt. Deposits. 98 3069 0 0.02 9 1 2.88 Lt. Deposits. a 99 3100 0 0.02 9 0 2.89 Lt. Deposits. U 100 3131 0 0.02 9 0 2.89 Lt. Deposits. • 101 3162 0 0.01 4 0 2.89 Lt. Deposits. • 102 3193 0 0.02 7 0 2.91 Lt. Deposits. • 103 3225 0 0.02 6 0 2,88 Lt. Deposits. 104 3256 0 0.03 11 1 2.89 Lt. Deposits. ■ • 105 3288 0 0.03 10 0 2.89 Lt. Deposits. • 106 3318 0 0.03 10 0 2.90 Lt. Deposits. 107 3349 0 0.02 9 0 2.90 Lt. Deposits. • 108 3380 0 0.02 7 1 2,89 Lt. Deposits. U 109 3410 0 0.01 5 0 2.89 Lt. Deposits. 1 110 3441 0 0.02 6 0 2,89 Lt. Deposits. • 111 3472 0 0.02 6 1 2.90 Lt. Deposits. 112 3503 0 0.02 9 1 2.90 Lt. Deposits. • 113 3535 0 0.02 7 0 2.90 Lt. Deposits. l• 114 3566 0 0.01 4 0 2.90 Lt. Deposits. 115 3598 0 0.02 6 0 2,89 Lt. Deposits. II II 115.1 3629 0 0.01 5 0 2.90 Pup Lt. Deposits. 115,2 3639 0 0 0 0 2.88 GLM 1 (Latch @ 7:00) • 115.3 3648 0 0.02 7 1 2.91 Pup Lt. Deposits. U 116 3658 0 0.02 6 0 2,90 Lt. Deposits. • 117 3689 0 0.02 6 0 2.90 . Lt. Deposits. U 118 3720 0 0.01 5 0 2.89 Lt. Deposits. 119 3751 0 0.02 7 1 2.90 Lt. Deposits. IN 120 3782 0 0.03 11 0 2.90 Lt. Deposits. I• 121 3813 0 0.02 6 0 2.91 Lt. Deposits. 122 3845 0 0.02 6 1 2.89 Lt. Deposits. s 123 3876 0 0.02 9 0 2.86 Lt. Deposits. • 124 3907 0 0.02 7 1 2.90 Lt. Deposits. U 125 3940 0 0.03 10 1 2.90 Lt. Deposits. U 126 3971 0 0.02 7 0 2.89 Lt. Deposits. • 127 4002 0 0.02 7 0 2.89 Lt. Deposits. • 128 4033 0 0.03 10 0 2.87 Lt. Deposits. • 129 4065 0 0.02 6 1 2.89 Lt. Deposits. ii 130 4096 0 0.03 10 0 2.90 Lt. Deposits. • 131 412 7 0 0.02 7 1 2,90 Lt. Deposits. U 132 4159 0 0.02 6 0 2,90 Lt. Deposits. • 133 4190 0 0.02 7 0 2.85 Lt. Deposits. • 134 4219 0 0.02 6 0 2.89 Lt. Deposits. 0 135 4251 0 0.02 6 0 2.90 Lt. Deposits. • 136 4282 0 0.02 6 0 2.90 Lt. Deposits. U 137 4313 0 0.02 6 0 2.91 Lt. Deposits. i 138 4345 0 0.02 6 0 2.90 Lt. Deposits. • 139 4376 0 0.02 6 1 2.89 Lt. Deposits. is • 140 4407 0 0.02 9 1 2.89 Lt. Deposits. 11 141 4438 0 0,03 10 0 2.84 Lt. Deposits. 142 4469 0 0.03 10 0 2.90 Lt. Deposits. ■ 143 4500 0 0.02 6 0 2.88 Lt. Deposits. • IPenetration Body Metal Loss Body Page 3 Pi ILI 0, PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 144 4532 0 0.02 6 0 2.88 Lt. Deposits. • 145 4562 0 0.02 9 0 2.87 Lt. Deposits. • 146 4593 0 0.02 9 0 2.88 Lt. Deposits. 147 4623 0 0.03 10 0 2.87 Lt. Deposits. • • 148 4656 0 0.03 10 0 2.83 Lt. Deposits. iii 149 4687 0 0.02 6 0 2.86 Lt. Deposits. 150 4718 0 0.02 9 0 2.86 Lt. Deposits. U 151 4749 0 0.02 7 0 2.86 Lt. Deposits. • ii 152 4781 0 0.02 7 0 2.87 Lt. Deposits. • 153 4812 0 0.02 9 0 2.83 Lt. Deposits. 154 4843 0 0.02 7 0 2.87 Lt. Deposits. • 155 4874 0 0.03 11 1 2.85 Lt. Deposits. rii • 156 4905 0 0.03 10 0 186 Lt. Deposits. 157 4936 0 0.03 12 0 2.79 Deposits. sis 158 4968 0 0.02 9 0 2.87 Lt. Deposits. • 159 4999 0 0.02 9 0 2.86 Lt. Deposits. • 160 5030 0 0.01 5 0 2.87 Lt. Deposits. II 161 5061 0 0.02 7 1 2.86 Lt. Deposits. U 162 5092 0 0.02 7 0 2.76 Deposits. • • 163 5123 0 0.02 7 0 2.87 Lt. Deposits. 164 5154 0 0.03 10 1 2.87 Lt. Deposits, • E s 165 5185 0 0.03 11 0 2.86 Lt. Deposits. 166 5216 0 0.02 7 0 2.88 Lt. Deposits, it 167 5247 0 0,02 6 0 2.88 Lt. Deposits. 168 5277 0 0.03 12 0 2.86 Lt. Deposits. • ✓s 169 5310 0 0.03 12 1 2.88 Lt. Deposits. 170 5341 0 0.02 9 0 2.87 Lt. Deposits, • 171 5373 0 0.02 7 0 2.86 Lt. Deposits. • 172 5404 0 0.02 7 0 2.88 Lt. Deposits. U 173 5433 0 0.02 9 0 2.87 Lt. Deposits. U 174 5465 0 0,02 6 0 2.87 Lt. Deposits. ii 175 5497 0 0.01 4 0 2.89 Lt. Deposits. 176 5529 0 0.03 10 0 2,87 Lt. Deposits. • 177 5559 0 0.02 7 0 2.86 Lt. Deposits. • 178 5590 0 0.03 11 0 2.87 Lt. Deposits. IN 179 5621 0 0.02 7 0 2.86 Lt. Deposits. • 180 5652 0 0.02 7 0 2.86 Lt. Deposits. It 181 5684 0 0.02 7 0 2.85 Lt. Deposits. • 182 5715 0 0.02 7 0 2.80 Deposits. r 183 5746 0 0.02 9 0 2.88 Lt. Deposits. ■ 184 5778 0 0,02 7 0 2.86 Lt. Deposits. • 185 5809 0 0.02 9 0 2.88 Lt. Deposits. • 186 5840 0 0.02 6 0 2.88 Lt. Deposits. ii 187 5871 0 0.02 9 0 2.88 Lt. Deposits. U 188 5901 0 0.02 9 0 2.86 Lt. Deposits. • 189 5931 0 0.02 7 1 2.88 Lt. Deposits. • 189.1 5963 0 0.00 2 0 2.88 Pup Lt. Deposits. 189.2 5972 0 0 0 0 2.87 GLM 2(Latch @ 10:30) 189.3 5981 0 0.01 5 0 2.89 Pup Lt. Deposits. • • 190 5992 0 0.02 6 0 2.87 Lt. Deposits. IPenetration Body Metal Loss Body Page 4 VS PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 • 191 6023 0 0,02 7 0 2,87 Lt. Deposits. • 192 6055 0 0.02 7 1 2.88 Lt. Deposits. • 193 6086 0 0.02 7 0 2.88 Lt, Deposits. • 194 6117 0 0.02 7 0 2.86 Lt. Deposits. II 195 6148 0 0.02 6 0 2.88 Lt. Deposits. 196 6180 0 0.03 10 1 2.89 Lt. Deposits. • 197 6211 0 0.02 7 1 2.90 Lt. Deposits. 198 6242 0 0.02 9 0 2.90 Lt. Deposits. • • 199 6273 0 0.02 7 0 2,85 Lt, Deposits. oi 200 6305 0 0.03 10 0 2.88 Lt. Deposits. 201 6336 0 0.01 5 0 2.88 Lt. Deposits. it 202 6367 0 0.02 7 0 2.90 Lt. Deposits. • 203 6399 0 0.01 3 0 2.86 Lt. Deposits. 204 6430 0 0.01 5 1 2.88 Lt. Deposits, 205 6461 0 0.02 7 0 2.88 Lt. Deposits. • 206 6492 0 0.02 7 1 2.86 Lt. Deposits. • 207 6523 0 0.03 11 0 2.86 Lt. Deposits. im 208 6554 0 0.01 5 0 2.89 Lt. Deposits. 209 6585 0 0.03 12 0 2.90 Lt. Deposits. Im • 210 6617 0 0.02 7 0 2.88 Lt. Deposits. 211 6648 0 0.01 5 0 2.88 Lt. Deposits. i 212 6679 0 0.02 7 0 2.89 Lt. Deposits. • 213 6711 0 0.02 6 0 2.90 Lt. Deposits. 1 214 6742 0 0.01 5 0 2.88 Lt. Deposits. 215 6773 0 0.01 4 0 2.87 Lt. Deposits. 1 216 6805 0 0.00 2 0 2.87 Lt. Deposits. 217 683 6 0 0.02 6 0 2.87 Lt. Deposits. 218 6868 0 0.02 7 1 2.90 Lt. Deposits. • 219 6899 0 0.01 5 0 2.89 Lt. Deposits. 220 6930 0 0,02 9 1 2.87 Lt. Deposits. r 221 6961 0 0.01 4 0 2.89 Lt, Deposits. i 222 6992 0 0.01 3 0 2.88 Lt. Deposits. I 223 7024 0 0.01 5 0 2.88 Lt. Deposits. i 224 7054 0 0.01 3 0 2.88 Lt. Deposits. I 225 7086 0 0,01 3 0 2.89 Lt. Deposits. I 226 7116 0 0,01 4 0 2.89 Lt. Deposits. 1 227 7149 0 0.02 7 0 2.87 Lt. Deposits. • 228 7180 0 0.01 5 0 2.90 Lt. Deposits. II 229 7211 0 0.01 4 0 2.89 Lt, Deposits. 230 7242 0 0.01 3 0 2.86 Lt. Deposits. 231 7273 0 0.01 4 0 2.88 Lt. Deposits. 231.1 7305 0 0.01 3 0 2,87 Pup Lt. Deposits. 1 231.2 7315 0 0 0 0 2.85 GLM 3(Latch @ 4:00) 231.3 7323 0 0.02 6 0 2.86 Pup Lt. Deposits. it 232 7334 0 0.04 15 1 2.85 Shallow Pitting. Lt.Deposits. mi 233 7366 0 0.02 6 0 2.86 Lt. Deposits. 234 7396 0 0.01 3 0 2.86 Lt. Deposits. i 235 7428 0 0.02 6 0 2.85 Lt. Deposits. a 236 7459 0 0.03 10 0 2,84 Lt. Deposits. r 237 7489 0 0.01 4 0 2.85 Lt. Deposits. i IPenetration Body Metal Loss Body Page 5 PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 238 7520 0 0.01 5 0 2.84 Lt, Deposits. 239 7553 0 0.01 5 0 2.85 Lt. Deposits. 240 7583 0 0.02 6 0 2.83 Lt. Deposits. • 241 7615 0 0.02 6 0 2.40 Heavy Deposits. 242 7647 0 0.02 7 0 2.83 Lt. Deposits. U 243 7678 0 0.02 6 0 2.84 Lt. Deposits. U 244 7709 0 0.01 5 0 2.83 Lt. Deposits. 245 7741 0 0.03 11 0 2.85 Lt. Deposits. • 246 7772 0 0.00 2 0 2.84 Lt. Deposits. 247 7803 0 0.01 5 0 2.85 Lt. Deposits. 248 7834 0 0.00 0 0 2.83 Lt. Deposits. 249 7865 0 0.01 3 0 2.83 Lt. Deposits. 250 7896 0 0,01 4 0 2.84 Lt, Deposits. 251 7928 0 0.01 3 0 2.77 Deposits. 252 7959 0 0.02 6 0 2.84 Lt. Deposits. 253 7990 0 0.01 3 0 2.83 Lt. Deposits. t 254 8021 0 0,01 4 0 2.84 Lt. Deposits. 255 8053 0 0.01 5 0 2.80 Deposits. 256 8084 0 0.00 0 0 2.79 Deposits. 257 8115 0 0.01 5 0 2,80 Deposits. 258 8146 0 0.02 6 0 2.82 Lt. Deposits. U 259 8177 0 0.02 7 0 2.80 Deposits. • 260 8208 0 0.01 3 0 2.81 Lt, Deposits. 261 8239 0 0,02 7 0 , 2.82 Lt. Deposits. • 262 8270 0 0.01 5 0 2.79 Deposits. 263 8301 0 0.01 4 0 2.81 Deposits. 1 263.1 8333 0 0.02 7 0 2.86 Pup Lt. Deposits. • 263.2 8342 0 0 0 0 2.84 GLM 4(Latch(0 5:00) 263.3 8350 0 0.02 7 0 2,76 Pup Deposits. • 264 8362 0 0,02 7 0 2.75 Deposits. • 264.1 8393 0 0.00 2 0 2.74 Pup Deposits. 264.2 8399 0 0 0 0 2.77 Seal Assembly 264.3 8411 0 0 0 0 2.91 PBR 264,4 8413 0 0 0 0 2.75 Baker FHL Retrievable Packer 265 8424 0 0.02 7 0 2.75 Deposits. • 266 8455 0 0.02 6 0 2.74 Deposits. 267 8485 0 0.01 5 1 2.76 Deposits. 268 8516 0 0.02 6 0 2.74 Deposits. • 269 8548 0 0.01 4 0 2.75 Deposits. 270 8579 0 0.02 9 0 2.74 Deposits. • 271 8611 0 0.02 7 0 2,75 Deposits. 272 8641 0 0.01 3 0 2.75 Deposits. t 273 8672 0 0.00 0 0 2.73 Deposits. 274 8704 0 0,01 3 0 2.75 Deposits. t 275 8735 0 0,00 2 0 2,72 Deposits. 276 8766 0 0.02 9 0 2.73 Deposits. 277 8798 0 0.01 5 0 2.73 Deposits, iN 278 8830 0 0.03 12 0 2.71 Deposits. 279 8860 0 0.03 12 0 2.73 Deposits. IN 279.1 8891 0 0 0 0 2.74 Pup Deposits. Penetration Body Metal Loss Body Page 6 CI et PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 9 ft. 9,151 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 279.2 8900 0 0 0 0 2.74 Baker Premier Packer 279.3 8911 0 0 0 0 2.74 Pup Deposits. 280 8920 0 0,01 3 0 2.73 Deposits. 280.1 8949 0 0 0 0 2.75 Pup Deposits. 280.2 8958 0 0 0 0 2.75 HES X Nipple 280.3 8959 0 0.00 2 0 2.72 Pup Deposits. 280.4 8969 0 0 0 0 2.73 Pup Deposits. 280.5 8979 0 0 0 0 2.79 GLM 5(Latch C@ 12:30) 280.6 8988 0 0.03 10 0 2.81 Pup Deposits. 281 8999 0 0.06 22 1 2.74 Line of Pits. Deposits. 282 9035 0 0.02 6 0 2.75 Deposits. 283 9067 0 0.01 4 0 2.78 Deposits. 283.1 9096 0 0,01 4 0 2,73 Pup Deposits. 283.2 9105 0 0 0 0 2.79 Baker CMU Sliding Sleeve 283.3 9111 0 0 0 0 2.92 Baker Fl Packer 283.4 9123 0 0 0 0 3.00 Millout Extension 283.5 9130 0 0.02 7 2 2.91 Pup Lt. Deposits, 283.6 9141 0 0.01 3 0 2.91 Pup Lt. Deposits. 283.7 9147 0 0 0 0 2.73 Camco D Nipple 283.8 9147 0 0.00 2 0 2.92 Pup Lt. Deposits. 283.9 9151 0 0 0 0 2.95 WLEG IPenetration Body Metal Loss Body Page 7 PDS Report Cross Sections Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 56 at depth 1,743.377 ft. Tool speed=48 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=98% Tool deviation=41° 1 N••••-.. Finger=20 Penetration=0.061 in. Line of Pits 0.06 in.=24%Wall Penetration HIGH SIDE=UP VS. PDS Report Cross Sections Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 53 at depth 1,641.540 ft. Tool speed=52 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=98% Tool deviation=38° / 40Nt 1 k Finger= 13 Penetration=0.060 in. Line of Pits 0.06 in.=24%Wall Penetration HIGH SIDE=UP PDS Report Cross Sections Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 241 at depth 7,619.220 ft. Tool speed=54 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=53° f Minimum I.D.=2.405 in. Heavy Deposits Minimum I.D.=2.41 in. HIGH SIDE=UP Ca PDS Report Cross Sections Well: 3A-01 Survey Date: October 21,2017 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 278 at depth 8,849.660 ft. Tool speed=56 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=47° 'i t • , - Minimum I.D.=2.713 in. Deposits Minimum I.D.=2.71 in. HIGH SIDE=UP _,,\ KUP PROD 3A-01 ConocoPhillips O°- \ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWl Field Name Wellbore Status nd TI MD(ftKB) Act Btm(ftKB) ,_,earl 500292141200 KUPARUK RIVER UNIT PROD 56.28 2,400.00 9,600.0 -.. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-01,5115r2017 1 0.41.13 AM SSSV:TRDP _ 160 11/30/2016 Last WO: 10/16/2006 35.19 9/1/1985 Vertical schematic(actual) Annotetkm Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:RKB 9,327.0 5/12/2017 Rev Reason:TAG,H2S pproven 5/15/2017 Casing Strings HANGER;302 j; Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)... WULen 0...Grade Top Thread - ' CONDUCTOR 16 15.062 31.0 104.0 104.0 62.50 H-40 WELDED uus,Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...WULen 11...Grade Top Thread a ,- . SURFACE 9 5/8 8.921 30.2 4,353.4 3,157.2 36.00 J-55 ETC CONDUCTOR;31.0-104.0 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread PRODUCTION 7 6.276 23.7 9,575.0 6,331.3 26.00 J-55 BTC Tubing Strings SAFETY VLV;2003.4 /'�': Tubing Description String Ma...ID(In) Top(RKB) Set Depth(ft..'Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 30.2 9,151.5 6,020.7 9.30 L-80 EUE 8RD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top loci(°) Item Des Corn (In) GAS LIFT,3,644.9 30.2 30.2 0.11 HANGER FMC TUBING HANGER 2.992 2,003.4 1,802.9 48.47 SAFETY VLV TRMAXX-5E SAFETY VALVE 2.812 8,398.9 5,526.3 53.49 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 8,398.9 5,526.3 53.49 PBR PBR 80-40 3.000 8,412.6 5,534.4 53.36 PACKER BAKER FHL RETRIEVABLE PACKER 2.990 SURFACE:30.2.4,3534-+ 8,900.1 5,845.1 46.88 PACKER BAKER PREMIER PACKER 598-287 2.870 �r i 8,957.4 5,884.4 46.44 NIPPLE HES'X'NIPPLE 2.813 GAS LIFT,5.975 7 9,034.7 5,937.9 45.67 BLAST RING CARBIDE BLAST RING(1) 2.992 9,101.9 5,985.3 44.80 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/2.812'BX PROFILE 2.812 -""- (OPEN 3/15/2007) 9,110.5 5,991,4 44.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS UFT;7.376.1 9,110.5 5,991.4 44.71 PACKER BAKER F-t PACKER 4.000 9,113.8 5,993.8 44.67 SBE BAKER SEAL BORE EXTENSION 4.000 9,124.0 6,001.0 44.56 MILLOUT EXT MILL OUT EXTENSION 4.390 GAS LIFT,8.3405 9,145.9 6,016.7 44.32 NIPPLE CAMCO'0'NIPPLE w/2.75"PROFILE 2.750 9,151.0 6,020.3 4426 WLEG IMRELINE ENTRY GUIDE 3.000 Perforations&Slots Shot Dena J Top(TVD) Mtn(TVD) (ahoteM Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zana Date 1) Type Com PBR;8,388.99,020.0 9,036.0 5,927.7 5,938.9 C-1,3A-01 11/10/1585 12.0 IPERF 5"FyperJet II,120 deg. PACKER;8,412.6 ph 9,165.0 9,195.0 6,030.3 6,051.9 A-3,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet It.90 deg. Ph 9,210.0 9,260.0 6,062.8 6,099.2 A-2,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet II,90 deg. ph Mandrel Inserts St PACKER;8.900.11,1111 eh on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com 1 3,644.9 2,742.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 3/11/2011 2 5,975.7 4,103.5 CAMCO MMG ' 1 1/2 GAS LIFT GLV RK 0,188 1,276.0 10/19/2006 NIPPLE;8,9574 -j 1 3 7,315.1 4,903.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,270.0 10/19/2006 PRODUCTION,8,978.7-4 4 8,340.5 5,491.7 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 8/15/2013 6 8,978.7 5,899.1 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 10/16/2006 Close d Notes:General&Safety (PERF;9.020.09,036.0-- i .i End Date Annotation 9/29/1998 NOTE:Top of junk 9332'MD 12/21/2010 NOTE:IA OA COMMUNICATION 1/6/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/12/2012 NOTE:RIG RKBs ORIGINAL vs 2006 WORKOVER AFFECTS PROD/TBG TOPS SLEEVE-O;9,101.9 i -11 PACKER;9,110.5 SBE;9,113.0 i MILLOUT EXT;9,124.0 I NIPPLE;9,145.9iii W LEO;9.161.0 IPERF;9,165.0-9,195.0-- IPERF;9,210.0.9,260.0- . I PRODUCTION;23.79.575.0 WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. It/2/2o1/ RECEIVED M.K.BENDER To: AOGCC NOV 0 1 2017 Makana Bender 333 West 7th Avenue AOGCC Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 AN ` 1) Caliper Report 21-Oct-17 3A-01 1 Report /CD 50-029-21412-00 2) Signed . 40.417 C Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE Ci.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx OF T,r • • tw\�0 II/7, THE STATE Alaska Oil and Gas rw*0164Ps ��.—'A of/\ LA S KA6. Conservation Commission ttitr2 _ - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0' Main: 907.279.1433 S ALAFax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam 'j' 6""17 Staff Completions Engineer " ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 3A-01 Permit to Drill Number: 185-186 Sundry Number: 317-385 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, �G `L Cathy‘!)"_,v Foerster Commissioner DATED this day of August, 2017. RBDMS k v SEP - 5 2017 i • STATE OF ALASKA AUG 0 8 70 / ALASKA OIL AND GAS CONSERVATION COMMISSION /-S 8'r3/ / 7 APPLICATION FOR SUNDRY APPROVALS t j ,A 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate El Repair Well El Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 • 185-186 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21412-00 ' 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 CINo 0 ✓/ KRU 3A-01 9.Property Designation(Lease Number): , 10.Field/Pool(s): ADL 25632 c.1$(a•.3) 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): 9,600' - 6,350' ' 9175 6038 , NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 73' 16" 104' 104' Surface 4,323' 9 5/8 4,353' 3,157' Production 9,551' 7" 9,575' 6,331' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9020-9036,9165-9195,9210- 59278-5939,6030-6052,6063- 3.500" L-80 9,151' 9260 • 6099 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL RETRIEVABLE PACKER i MD=8413 TVD=5534 PACKER-BAKER PREMIER PACKER 598-287 ` MD=8900 TVD=5845 PACKER-BAKER F-1 PACKER • MD=9111 TVD=5991 SAFETY VLV-TRMAXX-5E SAFETY VALVE • MD=2003 TVD=1803 • 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 ' WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ 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: Sttaffti.• - '' -'gineer ..-' Contact Email: Sandeep.Pedam@cop.com \ 014, i / "'j ��/ Contact Phone: (907)263-4724 Authorized Signature: ,� Date: . _ t (.7t' COMMfSSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i-7-35 Plug Integrity ❑ BOP Test ❑ MechanicalLIntegrity Test ❑ Location Clearance 0 r Other: f o �j t I-1'5-4 4 to J—.7U O /2 t `f -p Y c`v,," to r 'moo[ c Tv!a ►‘.--t� /4- jv b � (21.--z. 55 1..,-y—c Ft s It-e---o! to /iv o�� 5 j.) ' o r >4, -- c Post Initial Injection MIT Req'd? Yes ❑ No II/ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /D -4 0,9,/ RBDMS L`' SEP - 5 2017 APPROVED BY Approved by: ACOMMISSIONER THE COMMISSION Date: 6 _3/... / 7 /i Iio ❑ 9/30" 1-7w Vo/Io/Zo`7 Submit Form and Form 10-403 Revised 4/2017 1�-'[` i n is valid for 12 months from the date of approval.rV9 Attachments in Duplicate • • RECEIVED ConocoPhillips Alaska, Inc. AUG ® 8 2017 Paul K.Wharton O , re Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3A-01 Well Kuparuk River Unit, Alaska ADL 25632, KRU Tract 23; and ADL 25631, KRU Tract 12 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 3A-01 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 3A-01 Hydraulic Fracturing Notice Lette June 1,2017 Page 2 Exhibit 1 3A-15 3A 13 3A-14 3A-16 ADL025630 ADL025631 AAhlri 3A-10 3A-12 3A-11 linprdi 1,,,,..4414 „` 3A-/8 3A-0711-02 \\ 3A-17AL2-0 , 3AA2 7LL11-01 \3A117 3A D7 -03A-07L1 3A-06 3A-17ALIPB1, 05 3A-03 L1-02 (; 12 p e R 9 3A-17AL1 1 1 Y F'� 3A-17A 0 3A-03BL2-01 -Tv) 3A-031U A-03A 3A-04 38-01 3A‘3.1;)\s. 3A-02 3A-03 31 3F-21 ADL025632 3A-030L1 3A-038L1-01 ADL025633 1 3F 0 ADL025642 • Frac Points Well Trajectory Well Open Interval ADL025643 ConocoPhillips _ Half Mile Frac Point RadiusA Alaska,Inc. MIHalf Mile Trajectory Radius 3A-01 Wells within Trajectory Radius 0 0.2 0.4 0.6 0.8 Lease Plat CPAI Leases Miles I 5/9/2017 3A-01 Hydraulic Fracturing Notice Lette• • 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 THE•ASKA OIL AND GAS CONSERVATION COSSION 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 3A-01 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. 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. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA • NOTARY PUBLIC = 61 REBECCA SWENSEN 'r 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) Well 3A-01 Footages Townshi Location FNL FEL p Range Section Meridian Surface 48011 737' T12N R9E 7 Umiat Top Open Interval 3759' 1311' T12N R9E 17 Umiat Bottomhole 4033' 1020' T12N R9E 17 Umiat • 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 7" casing cement pump report on 9/03/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 469 sacks of CL"G"with 3% KCI, 0.8% D-60, and 0.2% D-46 at 15.8 ppg. The cement was displaced using rig pumps and the plug was bumped with 3000 psi. Summary All casing is cements 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. i r Section 7 — Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) On 08/25/2015 the 9 5/8" casing was pressure tested to 1800 psi. On 10/18/2006 the 7" casing was pressure tested to 2000 psi. On 06/04/2014 the 3.5"tubing was pressure tested to 2500 psi. It will be tested to 5,900 psi prior to the frac. CPAI System Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,000 Annulus pressure during frac 1,000 Annulus PRV setpoint during frac 1,050 Annulus pressure test 1,100 Tubing pressure Test 5,900 Nitrogen PRV 5,800 Highest pump trip 5,600 Table 1: Required Pressures 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 J-55 3,520 psi 2,020 psi 7" 26 J-55 4,890 psi 4,320 psi 3 &%2" 9.3 L-80 11,560 psi 12,120 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up a y C-I Road f Tattle Tale Tank __. 1°47- ►! a/ INF Iy a� 11 t1 P.1/ a b Al p 0 i ► i m -G 6— -H* J m •r 5 V +b 01 E a Jl dwnd t� Pop-Off Tank v m - E N 6 G1 Dal Pump Truck Pop-Off Tank aCo. m J t. C J g Frac Pump ►i I PrJ Frac Pump Frac Pump NI ►.* • Frac Pump Frac Pump , .��. 11104 ' . Frac Pump 0 • Tree Saver With Wellhead Au OIL STATES PROPOSAL: Ng Energy Services (Canada) inc,_ QUOTE#: DATE: Maximum Allowable Pumping Rates SIZE ID OD RATE m'imin CSG 2.250 3.750 10 mlmin 3 1/2"Big Bore i 1.750 2.750 6 mshnin 2 7/8"&3 1/2" 1438 2.360 4 m3/min 2 3/8" 1.000 1.900 2m13/mniInn1i 3 1/16&4 1/16 with tapered mandrel 2.750 4.000 15 m 4 1/16 X Tool Mandrel 3.610 I 4.760 24 m7/min OPEN POSITION CLOSED POSITION p„zog *u sworn Alf otita.4 WW,0,11 MO Ell 1, .WARt,„, oNVAAnt, , ” -..,- rt. i = Ii ., ; 1,1 11 ,00.0901s0C. ilp i tan , 1 .." A .,...mg...... rir i ' 1 r c„ .... ... :...,........= 41 ., ,, .., wilf it L t Lt, 11,% ,,it 'tow In Mu ItittlnAtilf I t I • .... ONO v40.1 0044 '• e A < ttitAm ' 4 i 0,11m ;• 44 AO _ * rtt i . 4.441,MtluCI 1 ,N, 44 I r 7 ,,,....4.., ..... www.osescanada.com Tree Saver Rating: 15,000 psi • • Wellbore schematic SCUP PROD 3N-19 CanocoPhillips i 1.,Vise 4, b4rtse w, Max &MD m *tit f ar. t,r.. MP, .-1 au'r: 1.4..ax 1/Wtt4110 NV...4SS _:,V:'.:.f ,S: 21-..!:I- l.r.-,_ U&8 tx.._n.11C aa.Nac....111,:In , Araa^rvr :..^..iYtitll lr.r P.1. Are.edor ..r lfaail4 tMPs. ...._._. _01', l.. 0.r0 .Y. tIa"1! !1 t.1-..c:' „�It nl Casican.Isavutps rq ;ary , LI aR IMM 14,Lase 1.. St-LW... lt4,w.4.1 1-Il 1,,,,7..1 t� � [ V J it a4T. 421 , !L• !»k H-IR 4*14141 it li '-+.e. s. . tl £.444th 14e-MK et Mat Ur 9.a Tut MA.i...44.e. 1.411.4.4 .,-,,1i •1 3444 9 .i! .531.' 4,34 41 3'C 4.,4.3 fe f 5-.a lM-t wa..t S.4 "top x1.. .a.rw�,�.14e,a.warr.ww,A - 1 x.4411 Id, »,t. 4.. M _._1•.n 42!6 -as fl c��.a to 16'2 :4,z>ac s•e.ww _..et-,..."..,"+. C1 t -v,IWH, Ar.wea 4.3 541..1 OW,...wtL.r 1. I.hnw: MI _'''' I .TA.tft,lti t.. RAS, ?A,kw., ,.v r:rl4,:L 1Nhi 4:: 141:e 13414:, ii4.gy._ :'< IrtwA 4.:4.4.4.... 4249 LI 44434 4442 3t 11 tV.M- r:.... ."4t lu .., an? i 4k_. . 1._94., 3a:t2 5411 t'Cl' CV 484.4:?U4.Ir.at0. 01ulrb_e .;1.Yr - 1,4149 44141 le 4,.tt+8,,, J-r,413C1*Oft..x 1-4'2-4.144 i.1:.IM :921 4431,♦ 1.41.5 1444 t..:48CC 41344.; 12214 514 4 1...- 51nrtr.e -'!r2 "'.`,�9�'�^pry,,1.:'�'1{•!'.'.7�. -s1+'n 3! 4:.`I 44. 4- '4 6 n *„4F_° 1.44,.54;32 FA,.' I A+ Ts, at`<.'� „,,,,,,,,.+11: �'u-y w.re. I:a,'a3 ISr:.r4t. IS.Lnt,rtC �YM'.ifiit:.l l d.. II.131,-,,,,,::'-' 1 J. 4,4 4 • Loniprsnon olrt4ts I 1 writ ',WA.. t'.FITLw 4,4.48: '-FwGI`, man Dr duan rtr/ 24.4` .2. 148-1A04:24.1 3.12,t.-:..-I TSLrq f•-r9.1 2942 +43!41 41-4.4 4L`I.4449134 1.4ros 11:,FIaa2.4.t3-83- 2819 "Ltl6 12-A.a.'. 4.2LL7 491,FLT: 3 Of 2"'1Z-4111IR..••a..Ytmn. ]62, - 444:.4 4249! 414!evkee1.,-. :e-zee FM.fl.tM.ati.P*. 3014 ';101 1,341-5 33,8 KLflLC SA9.1 4 CM-=On 14.4.9.Cirrae E1.R=?"4..2.4!7 21112 ..na.. ± IDIG""'"""Jl 41.4C'A17 • ! ::"511?9 144 3 !2 49 U..t.1....4.1 91.4..91[44.31414 4✓ .Caen.13 Ityllo,::J9^ :'•�.: - tD 1544111..C62!3'484 - 14;3.! -At, 91.44 2XAT111 1..'.>:-430!5218 44.428.9'.l;.za- 1174,:, -4t..... 21.ti MAL Ann 3,r,9:-43 9.✓AMelealtr, 3 - Other le MOM itAtralble rem v2ble plums_whin.plumpstesty ete.l Y.,„,r'u, 1441.414 ,rat, 01,Ca. CIH, ... ((((((((((((J tAltl• .. _ A:5 4,41. - ha r:- 111.1.t:1),J. :.. :144:4. 1.1, D•t6 I:4- !'1^VJ:.,L'(::;V __ t _, _. _.5.:. IIPsrrlx3tlon8&Si0 8 T.141.,4 Am TM 2-.L 441149{. WT"AL:.• I }ta, $14: 64412 SA. 1..4. In. CM. l 7993:4- 4-42.3 ... 4.]842 A-I 141-48 t.1.4,2= 51 34'.41;1 '.`-32444 .1 'f'2::.: 02.114: - 14469 A-2..A-2 4-4. 12144/342 254.2 IPLITI 4.:,,'2-44[.4449: - A R tl � y 4tr . ,1.491 :�, 142,84 "fp �N. PW. 130 - :etc: !AMP 12910 4,:..!i"MR_ 48":2113 1.:FC 1"IMYL':-' ".163411A44i3&5534t90 N .b1 �_, 311&( arts - 2,r '9$MC( vaM 0444. MON. T4F4U8t •}w€ *. 11.62W2 .999. Mr, 1 ^M. 3W 4444 44.43 Mrsv !9 . 1 1, !3 7194-4 term. NUM :3-1" .22'1 KY 1 is 129;1I 22-23"131.8 Oil 24314*32': -4,1243 4.31.Lam. NN4: .1 ._L': 111. 9.4'91 I-MS.P 42:42= N 4,4122 1.1124.:t. 14444- 24'4 5+. 1211 111'11 4210021 44.44.9414'of, ',I''.9 1441-];=sm. NW. .. f- '.i IX:R 2::111 I 1, a_"tw^&2 - '.421? 414425: 1.4.... .r_...r tett. _.94 : ._,2'ta 1&0.[43:Gomm a sanitye< 1x.1 P.. 326::48 8x5*;..•..:L er:1„11.Wt'',;_v4'Fax 4:.. . _ vs,.It, weAts2r4twc1:22.1) L 1 ARRA:i,tirfir,Mik .I 44 • • 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 Kuparuk interval is approximately 275'TVD thick. In the 3A-01 the top and base Kuparuk are picked at 8990' MD/-5835'TVDSS and 9317' MD/-6069'TVDSS respectively. The Kuparuk interval is composed of fine-grained sandstone, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 12.5ppg. The overlying confining zone consists of greater than 285'ND of Lower Kalubik, Upper Kalubik and HRZ mudstones. The top of the HRZ was encountered at 8554' MD/-5548'TVDSS. The fracture gradient for each of these zones is estimated to be 15ppg, 15ppg,and 16ppg respectively. The underlying confinement zone consists of greater than 100'TVD of marine mudstones comprising the Miluveach Shale. The top Miluveach was encountered at 9317' MD/-6069'TVDSS,the base Miluveach was not penetrated. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. • • 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 the 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 for All Wells That Transect The Confining Zone: 3A-04: The 7"casing cement pump report on 09/21/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 400 sacks of CL"G"with 3% KCI, 0.8% D-127, 0.25% D-13, and 0.2% D-46. The cement was displaced using rig pumps and the plug was bumped. 3A-05: The 7"casing cement pump report on 10/12/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 400 sacks of CL"G"with 3% KCI, 0.8% D-60, and 0.2% D-46. The cement was displaced using rig pumps and the plug was bumped. 3A-17A: The 3-1/2"x 5-1/2" liner was cemented on 9/1/1996. The job was pumped as designed and displaced using rig pumps. 3A-17 CBL shows competent cement to 7267' MD. 3B-01: The 7"casing cement pump report on 4/13/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 375 sacks of CL"G"with 3% KCI, 0.8% D-60, and 0.2% D-46. The cement was displaced using rig pumps and the plug was bumped. 3F-05: The 7"casing cement pump report on 10/19/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 200 sacks of CL"G"at 15.6 ppg. The cement was displaced using rig pumps and the plug was bumped with 3500 psi. • • Y 80. c d o_ c_ N1,71 Y p O 8 0 'c W 4 N O W -� j a 1p " .a) d. OO .m^-I 0~0 N bD a-iQ� � va frl C `'i c O atoC N OM O C a ) O N 2 ^ \ O N a N 7 N 7 U ,--, a a N .FNa c a (JD_ H Q . N \ SV VI 0 T N V) C o ++ W d -TO• F � - ) — co@ ao O Q N a+ asy p_ LO. 1-1 on Q 0. c-I 01)v F8 1 T aJ to OQ§ V Q al Q < - a1 mQ pc p p \ c ^ a C IL ns 5 m\0u g 2 S a C C• 0 (7 (7 (9 (7 (7 Z a, sn aN Na fo m co m m m O- E 0 0 V 0 0 0 • 2 x N i C T O in a) 8 E V V N N m U C @ 2 cc 2 m 2 a) co 2 to 2 o ON Oi00 oON O) O 10 ic -I c ^ G � G 7; 0 G < mn co p O) n c-I f6 C O --1.o00 N\ Q 8 . in oo - § nNNJ@) n To' 00 O ta_ • Y v, Y v' Y n@) Y @, Y NJ U U U U U UU CL UU VU O O p_ O a O - O o a a a a a a a 8 ti Y 2 a) al cu a) (`6 @ @ C (`0 f`6 a al v 0 v E v a) n. n. a U a C. CU C m v a a a a a CC E as a v v v a, 4_ v 5 m m m m 2 m U O O - U U V V U V (a d. a) o (0 o N N U U U V V L r 0 Q a, c N O a, m N N N o0 .-' +- U O f0 0 v v v °n° t(n = Q (n c aN • U O N 0 Ls) N O co 0 N N V' Ln UaO l0 to N Lf) N fBQ L F LL O CO H N III cn N Ol �m-I o �m-I U _ 0 (9 LLD snn (9 t(n O p O N- a ci c ra tf, kip U -1-I cmn r N tmD o '-.0 O 0 co W N N COCO 0- 0_ _ I-• O • CaCV _ _ _ _ _ N n r a-I n n • U to • to 0 0 0 0 Q c Z cc c Z cc I- NZ d a 0. w Q O O ti O O w m m m m m m ADL025631 ADL025630 3A 0 4.)14 '7 3A-17AL1PB1 3A-05/ 3A-WA 4,) 3A-LVAL1 N\ 14k, 3A-04 3B-01 3B ADL025632 3F-05 AiOPP ADL025633 • Frac Points Well Trajectory ..•••••Well Open Interval Ire" Half Mile Frac Point Radius \DL025643 N ConocoPhillips Half Mile Trajectory Radius Alaska,Inc. amominw Faults within Frac Point Radius 3A-01 Wells within Frac Point Radius 0 0.2 0.4 0.6 0.8 Frac Plat Miles CPA! Leases 8/3/2017 _ , • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFIING 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 24 mapped faults that transect the Kuparuk interval and terminate within the confining zones inside a one-half mile radius of the 3A-01 wellbore trajectory. One fault intersects the 3A-01 wellbore and terminates within the confining layers. No other wells within the one-half mile radius intersect the fault present in the 3A-01. Fracture gradients within the confining zones will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zones are discussed in Section 9. The effective fracture half-length is estimated to be 420'. Stress orientation in 3A-01 is interpreted to be approximately North-South and we expect the fractures to propagate parallel to this maximum stress direction.There were no losses incurred or reported when crossing the C-sand fault. If there are indications that a fracture has intersected a fault during fracturing operations, CPAI 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. Fault Intersected in 3A-01 Wellbore Fault MD(ft) TVDSS(ft) Throw(ft) Fault#1 9016 -5853 27 (DTS) Faults Within One-Half Mile Radius Fault Orientation Throw(ft) 1 East-West 27 DTS 2 East-West 30-50 DTS 3 East-West 15-25 DTS 4 North-South 30-40 DTW 5 East-West 10-15 DTS 6 East-West 10-15 DTS 7 North-South 15-20 DTW 8 East-West 5 DTS 9 North-South 5-10 DTW 10 North-South 20-30 DTE 11 East-West 10-20 DTS 12 North-South 5 DTE 13 North-South <5 DTW 14 East-West 5-10 DTS 15 East-West 15-20 DTN 16 North-South 15-20 DTW 17 North-South 35-50 DTE 18 North-South 25-30 DTE • • 19 East-West 15 DTN 20 North-South 10-20 DTE 21 East-West 5-10 DTS 22 North-South 10-15 DTW 23 East-West 5-10 DTS 24 East-West <5 DTS Section 12 — Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 3A-01 was completed in 1985 as producer in the Kuparuk A sand formation. The well was completed with 7" production casing and 3.5"tubing. The well was frac'ed in 2009 (84Mlb prop) in the A-sand (9165-9195'MD and 9210-9260'MD).A single stage frac will be pumped through the C-sand perforations at 9020-9036'MD after placing a plug in the nipple at 9145.9'MD and opening the sliding sleeve at 9101.9'MD. Proposed Procedure: Halliburton Pumping Services: (C 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 1002 F seawater(approx. 2,301 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 75 bbl breakdown stage (25# Hybor) 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 1,000 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 5,000 psi. • i 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. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) b KUP PROD • 3A-01 ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cern vn 76ps 500292141200 KUPARUK RIVER UNIT PROD 56.28 2,400.00 9,600.0 •.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3A-01.25120151:17:58 PM SSSV:TRDP 100 12/29/2014 Last WO: 10/16/2006 35.19 9/1/1985 Vertical schematic(actual _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .- ....__ ..__... . Last Tag: 9,291.0 6/15/2007 Rev Reason:ADD WAIVER NOTE,H2S hipshkf 2/9/2015 9' L9[# Casing Strings HANGER.30.2 Y Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 104.0 104.0 62.50 H-40 WELDED aa.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread 1�1/r ,SURFACE 95/8 8.921 302 4,353.4 3,157.2 36.00 J-55 BTC CONDUCTOR;31.0-104.0 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 23.7 9,575.0 6,331.3 26.00 2-55 BTC Tubing Strings SAFETY VLV;2,003.4 OriTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 30.2 9,151.5 6,020.7 9.30 L-80 EUE 8RD Completion Details Nominal ID • Top(ftKB) Top(TVD)(ftKB) Top tool(°) Item Des Com (in) GAS LIFT;3,644.9 - 30.2 30.2 0.11 HANGER FMC TUBING HANGER 2.992 2,003.4 1102.9 48.47 SAFETY VLV TRMAXX-5E SAFETY VALVE 2.812 8,398.9 5,526.3 53.49 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 8,398.9 5,526.3 53.49 PBR PBR 80-40 3.000 I 8,412.6 5,534.4 53.36 PACKER BAKER FHL RETRIEVABLE PACKER 2.990 8,900.1 5,845.1 46.88 PACKER BAKER PREMIER PACKER 598-287 2.870 SURFACE;30.2-03534- 8,957.4 5,884.4 46.44 NIPPLE HES'X'NIPPLE 2.813 9,034.7 5,937.9 45.67 BLAST RING CARBIDE BLAST RING(1) 2.992 GAS LIFT;5.975.7 9,101.9 5,985.3 44.80 SLEEVE-O BAKER CMU SLIDING SLEEVE w/2.812'BX PROFILE 2.812 (OPEN 3/15/2007) 9,110.5 5,991.4 44.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 9,110.5 5,991.4 44.71 PACKER BAKER F-1 PACKER 4.000 GAS LIFT;7,315.1 9,113.8 5,993.8 44.67 SBE BAKER SEAL BORE EXTENSION 4.000 9,124.0 6,001.0 44.56 MILLOUT EXT MILL OUT EXTENSION 4.390 9,145.9 6,016.7 44.32 NIPPLE CAMCO'D'NIPPLE w/2.75"PROFILE 2.750 GAS LIFT;8,340.5 9,151.0 6,020.3 4426 WLEG WIRELINE ENTRY GUIDE 3.000 Perforations&Slots Shot:.:. Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Blot(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PBR;8,39e.9 9,020.0 9,036.0 5,927.7 5,938.9 C-1,3A-01 11/10/1985 12.0 IPERF 5"HyperJet II,120 deg. P PACKER;8,412.6 - 9,165.0 9,195.0 6,030.3 6,051.9 A-3,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet II,90 deg. ph 9,210.0 9,260.0 6,062.8 6,099.2 A-2,3A-01 11/10/1985 4.0 IPERF 4"Hyper Jet 11,90 deg. ph Mandrel Inserts PACKER;8,900.1 St atl on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 3,644.9 2,742.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 3/11/2011 2 5,975.7 4,103.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,276.0 10/19/2006 NIPPLE;8,9574 P 3 7,315.1 4,903.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188'1,270.0 10/19/2006 PRODUCTION;8,978.7all 4 8,340.5 5,491.7 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 8/15/2013 5 8,978.7 5,899.1 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 10/16/2006 Close d IPERF;9.020.0-9,036.0- Notes:General&Safety End Date Annotation 9/29/1998 NOTE:Top of junk @ 9332'MD sk 1111 12/21/2010 NOTE:IA x OA COMMUNICATION 1/6/2011 NOTE:View Schematic w/Alaska Schematic9.0 MI 10/12/2012 NOTE:RIG RKBs ORIGINAL vs 2006 WORKOVER AFFECTS PROD/TBG TOPS SLEEVE-0;9,101.9 PACKER;9,110.5 SBE;9.113.8 61 MILLOUT EXT;9,124.0 ,.A L_J NIPPLE;9,145.9 til WLEG;9,151.0 ini ---. IPERF;9,165.0-9,195.0- IPERF;9,210.0-9,260.0 PRODUCTION;23.7-9,575.0 III • ,n v, o n i :: : o ' 0 . 6 . ' ' ' ' m - M °'. Son ry n n ry n ry ry ry 3 � ,.i 3 AE � 8 8o o = 0 S S a n u 0 0 0 0 0 0 0 a o dil" V P5'J - 0008888 _= = --E', ,, 'rv" o 0 0 0 0 0 0 0 0 u i0 d u u a \ p 0 •°, .+ :2,,, :2,, , A !,, a tiO O 5' o 0' N 0 E E > FO 0 0 0 0 < 0 h ' .g - 5 °m - :20m mo . 0 s3 Z ;z 5 mom` t i' p' m . ry m v 2 Ln ,,, C o v v v i;.41 rv , n V N N N .,rv ^ N E vN .t 5aa 1 :0 ;; amt m_aNxQ ig W4R mm2 -vca m mo o ,,P,' ,.<z un m < 3° r =tS 11: 1:',2, 0 . .i ;10 rn ° C C '.m M m ' 7 ' 777 p 6 6 ° ° il ;-.7 . ,q,'-4,-7. ,'I m y \� EE V \\Pv. 333333 4 u� - " $V kt w - o 3 O a EE CC ". a ^ `$ Fv ,,r Qnc. At '''' °'-' 780 "5' nLL —oy nnnan nannnn wu 0 Yx Vi 4 Lgs a� s co ? tgt� t? O o YmO - , sxxxxxxa mxnw mm QLLQry nn in iry ryn ,ryn ry ry LL o r O , N i r in v r n a x - a Q E ry m e m m ^ m a .. .. .. w cx H i il> ,2› ,, �., n o o sir 3 E =>° t r L a> ° i.:.,4„ ,, ! � a « i g60S9LU09Z6-0(06@7 3 !4 ;. -g-°--. ; « N o " 0 E' -`,4 pue3 tl8nrednH `� i Z E U C L lensal0I a,. c �' .4' O 0 U • • N -0 .N vi .(4 tan L- `� co (f) - .4_i 4 +-) c6 a) o -0 2o o o be O 4_, _Cco O a) (13 •tZA a� U O -a i N vi O +� ocu O E E i U �' 0- O N N 'a N 44- -0 Q S- (10 Li- c6 O LCU y Q co � .� O la p = t:).° . 1. > . >. � E E E CL CU c6 N O v) cn oU •1- c6 n 'n E `er C . a t �? E — o c c6\ p N Uv `0 °� 4A • � a- 1 Um E o H + 00 v — O '4- 00 N hA — -' Q • (13 IO CD ._ N C a) N N O v CU C E C C la0 •t-ib Q.) o (f) C, o -� N NJ 0 Z -0 CU CO N '- .(// -0 4 (-) O c6 L v a0 v--1U I- .( a_ ma) E co 0 • • • v n m f s 3 c W r4 W .12 a 'il N 2u w ilE liE II E E v E Z 9 u u 0m5 ,N y E 2E_ Z LL Z ti O O Al T o 2 = 2 UP E `O mA`xo _N t3,- , E n E T a Ez; - dom U o z z z zz z $ z 2 $ ox"zam a Et a 3 a -- a19 o- 00 0 0 0 0 o N .'FN N n` ;rnM r n F,2N�N' 'Ar,c2 -� Ea E c o g °'wa V; o 0 0 000omo 0 0 oaooMo00000 c a c a Uo S a y 1E d9 a .� m n .a .y E n e e a Q^ .+ - r n . E o E a 6.2 E 9 Ua g c £$ U .`7.1 Q 2 �r 'V° U o 0 0 o a o o a o o A `T 5 L ,v(.', ` a s P w u� m m m °1 m m m m m m I d@ 1O 4:4,:-4,12 1 W4;L n��M� c m E a 0Qm ; E 9 9 9$ E 8 3 3 E PA m - �dA,; dda$40ed�hno `°E #'o o 1 ▪ 1 > j >j > j > 3 m a` �m a gmA3^m a` in72, mnrvn� n T uo N o • - y - 3 nU X °i` adv o 4-2.g ili ava E o3 =a "o 11-1E g 0 i g . t; ! 31 214 ,,, .. :-,1 In Slb g :Zo a 4o E0“1-.1-7-1 aayEouaE=E a 1 o' Ye as s 0) 0 o 2 rN- _tBoca ° m° m mm ° m . £Ec _S•23 - o8_EE E E c/ 31¢N PE "g2 E FE N o z Ec- ! Una_ = bbvbdV n - VL,.,- Fl >j ? > j > jnN UUU wZga� mn °yyw yQN U g 8 a 8 o m a a c m 2g u 5o m aa E ..03.1, o °° to ° v t,11 - o o . E8 ° - 0o vojz ` a - , .g..2- m - aool .u Y d -• g 5) mm m hU Z m m0 Q d 1& ERa ry • „ Mit n E S 9 v G i O c 3 N ;; • c r a E v N 8 E E V m o. i4 5 7 7 > > > $3 m°o Q o« c� .y u°z oz' own_ c n? _ N i s a s as a a s cc yU m.!a iO o u a ` - ” 0 O S,S x x x x x x ai<<V.. - E i E v a E LL 5 U. OEJ -°� �a m W m U ��.� v z E o x 8 = w `0 4 `a° u` ELL $E 3 Y. .° =' �� w� owmwi7F° 3 o 0 a �� v ° 3'4��mom�FS"���mMzR co ea_ m-l�ao amwma5i75 S i InmE000�sooamm3a� a _ ;": z •” • N .. o NI 1 E a a d a a a IL Os. a u u a V U N U 00 Lel co Q 0 en tn+a M o a`, � o �--aa � -0 = • o NI C - t—I o c o 7.c .-+ •c Y C • s� M Fa" a) oVz � aJ4) Q u ti O ctee.1 Q)N e..1 O 4J -- aCr/sr)i � 4-, (00 (.0 „.' d = 0a • z o ? 4- 0 c r, o a. a o ;, o �. m } a r, o ci 4'1; _c a•, c co Ll O co Y C fI v by U u L• Y CD V) '*. ••4- n3 ns ; a f0 +� ,S 4- 'c =VI° -C c o > CO sow.V 0. �•//�.\� (I Q a) c i = .e- 0 s-. '! o" _ > 3 ami c• o __ Y/ a) . c > •t 0. +�1 O 1 O s. 0 Y v 4- [a ? CL > o o ami 3 `° w P. 3 i'y µ? a c v -a -a7 = z o_2 o > -c a,1Q o CU � c v tt a'CLI in a � 00 ,� .u. rl o c o w a O z a t yam, c , ca �, a• v0 00 0 0 a) 41 'L O N —I O aJ O i a) I- N N ° vo f6 � a'▪ ZCD oa ! Q °'a LL F ca Q. c — 2 w o O `'r co �1 o -c > Q Q O o a v N O �' n om, an CL 0 O co E� a. 0 Z to a=., c Z f- \ cc Z Z 0. Q. Z d a. 1- +7, ,i d 01o CO N .e' o a — 1 t C Q a O _ a:. = a.. I M = a°, c°, c a. o ° o o a 00 v v o 0. c c v c � -a o � `�° ' = 3 °' 3 ° v v = ui c c uc N• O a o �. Zr Cr E t c ,a; `�' oo 4_ LA z • a ;; ...... o 0 .. V.' �, v C o Q ' y c N o c � �; ° ao v qC a c, o 3 .c �. U CU to - +�. a a -t, to a s c v N t a' a 'a,', Q o = 3 3 = a, en h o V, a.. W a H H a' fi O 4, 4*+0+ to .Z' Q 2 o - , i '' a cs a b '^ v IN O Z Q Cl. aI CO U ti ti v m V tJ h Q. g m y O. =i esi Q v� O ° � a M ° ° 0 I. CZ a. C.) Q a Q 0 1 = U ° tn o a • • M 0 0 I O CO CO COY Y Y O0 0 CCI m (.1 - o_ d u u IZ 4-, N ^. v 0 — _-_.. -. -__- _._- -.__.--__. Q Ln 00 -' a) a on a) •F+ M Q 1,- C a a o (O ' -0 v la as Imo-- (V 0 m +�+ "a M Y 0 0.) E as 0 a) c bb 13 a oa c Q CD 3 a� 0 a)to c = ea ai 3 I N oA o u co _c as+� C v V v; t 'B • CU a)ro N!.-I 00 •a a .v u + ._ C a� O ▪ a) - 1- 7• ~ N ee-I C L' \ > N Q III' COMin s2 c 76 oco mo �-- II; on C 3 0 J CO U 3 ac CO— N Y C N N V• 00 �',, •_ :a •� a a) m va- v •- N C •� ,,•^ +' `�- a) c1' c0 = O co Q 'F' C {' cn O ' Q. W i _C C i ON +. Q rl 0 M G i V U OD CC as a cOi� a�j 0. 00 a) •1-, aJ C Ca (A 0 o 2 Lfl (0 co O as 0 - a O 3 a) ▪ O U �I' O O CL Z C �+CD u' OA l'n (6 a •_ Y c •C° T To C o a � c _ 3 a oU U• -. a) a`i oo C t; 0 an i > C > C Y 147- N ,- " >'',C C a) s ' O co s_ a'' O •- 4-,'. V Z C aO+ % O O O V �I Q N =iF C "C 'O Ivy- E ,N N ,t- v CU U COCNJ Q u N t +� a Y 2 , Ia > '0 O N v •a v 24a 'O L I v o co C 6 °• C a o C a a a a Q- 'o o' a) a — °a° — C C a) aA V- 1--• I L- s. (6 Q' ' O O a) O O O tO a) L. s_ _ C N co O O CO C 1'1 co V A d u. in a-+ D 3 --I e-i fl. 1- F- h!i Y Y s- .L CI Q. ,co•C [0 CO > i > C.) v) .- a. OJ Y iH v c o Is ° { °i 1 u .0 o z, n) E 0 a N C t °iC o a, M ▪ s c' o v o v 'a aa oo .; I U s. *E- 4_ -C aU4, L. v a,Lp as o c L °-z U -• a oM '-a • Ls ° a °-, oao Op L. = w as L.) a, a a) a) v :.: a) o 3a $ ", 4.4 L CU c ._N o c v • ca, m p o a a < L v N avIs L._ 0 aa1a " " CIL Ln `)• a C s �o '(� a) 4 oa a o 0 0 a) �- " a v L. c Z , m o c O i s -o ¢ O 01 10 01 p OI H ; ..... SyC "1 U L ° N ° c—. 3 ° . E Z- oa I L a- (0 L O (a ; cp a 0 i a • • h !. o 1 a, 0 0 0 0 o 0 (-) 0 o m in ! 0 ' ..�. Ln a 00 4-. v +.• $ a-+ Mo o C = in > IMIMII '-I • o z +3 '�j >o a) �' c ate+ N _c in V M �r > o CU a s in `° o °i wo a ° aCU 132 To oVZ c co v- .. +C .n c o a, '^ c1 C L a v o - .0 -t3 Q p T a a, v a, :7 o tin y •— C e �' a Q �, `.i o 0 0 a O °' m c o v 00 G - o4- V) � o v � c . v, .a4- aC o - °' - Vco a) 'v 0 x to C `" `" aL. - > , c C v a) - Q. 00 a, E o v v o 0 4, v p Q. Q. �, s. I c a c a. $ x .x ;-, p m co 0 O a. .t C c co co p [5 n 0 v h p v v v > .a > i ( 8 p' of a oLo. c 'Q a,LI: ❑. a. r-i •L- o c a`, +' a 00 a`, c v a cn 0 a. ' " = Ies1 mo w o = p a, a o c o n. u *' i 0 0 s o o s > V Z a) 0 v v , @ V v ° = - v Y 0) tN 00 0 00 :o ° Q m +. _ -a a, -a a) -a v 3 rn 3 0 co LLil 0fl cu `V-° 4- v ° ]c N Cl. O. cy G a ,e fo Q F— n. lu l� O a.. Q cz Cc. 0 13 ICC o M a a Q o1 L. 01 0 `` ,a I s L. c : t--) .45 CL 1:3 L. o o -, .aa. M Y E cu v •4Si '� °i o, o E o N a q 0 o c o a a. '- 01 c a a °�. Q Lf• 0 a 0 "a •• c a, �, h o c o N Z -a a= les. '2 a •a o a, a, a. v E H Q V E N ¢ 0,,o wv c,ii o a 3 Q c4m °' 4'' cDu 0,a o ...i0O ' a C NZ i _ N O N N a, N 0 N •� . Q-,ry �. i Fr c .Q O 01 0 s a Q. u on L c L9 0 — a • • r`, I. o itG. 0 0 0 0 0 E V V (..) V u o V LA a O u, CU Y CT 4n .0 V M - N In ;; bp i 0 co "' V v n +0 a! Z • "' co j . a N •y cis = L ° 5 to Q v ' a a oOa a to •.... 0 c° in � +C-+ O Z CO 77) V N ani H d ` a .� ..4.. V! tom.) $ f1 +.' cn O Ma 00 2 $1$ O a) o. ui Q lll Q ,t O cn Oiu3, S o '^ 0 q., r O ++ ca o. tD Q to c 4-i= j O Ts 00 4- C 00 in o L 0 ca a Q. N O .0 sal- O `i -0 C O!, 0.0 Q- .moi ° O `n (Q 4gN w' +t0 .Q • .0 fa 4, O. Cr LCIcit Y p 010 O L . • O- T E on Va a a` oO1oi°-' O aQ a •� V = r—I v fa 0 cu Q O O O Oi N u ►. C >. M v0 c iv •c v a I M co N o h a la c ` i Co � � a ; E v v :c o a o N . � � ' p n o w 3 v a o, o10 4-1 C� N Z ,i2 , o o a �°' a, �' o Q ° V N O '_ ^ i V � �.. QJ O . a� 3 CC < L v N i `Z �' u Z I _ u !� i ° + O Z V 1r1 4L Q O ,� o4. a o 0 0 --, v CIL. 0. -.1 vU.. � a V) a v Z +.. C o a o a, , i ci) 0 v 3 v' CO a L O C 1 u h -- C in Cs1 O L `L 4 N O O = O +• = 1VI O> a C O a. N' ° O h O a O Ogi VI CC O Q u po v TS . o a C L h` Q • • N M O d N dc-I a, m O n V to LA a OO IA 1 ..1C '-1 VM CU . VO Z >• CL O '13 .— C c c V VI u .— . I C▪I. Up Q 00 Q L1'1 4A 00 .= rI � O V Z �n CO a., I. to u a - Io "0 a IA >4 r 4 _ ce ' M cc 0 ' 00 Y b„ v � C N • 1 � c � :- • O L, O o N Z •11- � � � ; 0 t j GJ -a -z r o a ,. c c Q C6 a ol 0 O Z �� oa 0 c..) " CU i U a g o -- 4...ro H a° c v o cL ,� . c vk It13 0 O O j QJ in J, U U c L v 0 Q lif • 2A 251 L LO TRANSMITTAL DATA LOGGED I�. G/G/2011 PROACTIVE DINNOSTIC SERVICES, INC. M.K.BENDER To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue MAY 2 5 2017 Suite 100 Anchorage, Ala (907) 793-1225ska 99501 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED JUN ff201 , 1) Caliper Report 16-May-17 3A-01 Report/CD 50-029-21412-00 2) Signed : 1. 2.24z4VI & kADate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx R!ECEIVE® • 2. 251, MAY 2 5 2017 Memory Multi-Finger Caliper .411.1 AOGcc Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-01 Log Date: May 16, 2017 Field: Kuparuk Log No.: 15075 State: Alaska Run No.: 2 API No. 50-029-21412-00 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 9,151 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the WLEG at 9,151 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in good to fair condition, with a maximum recorded wall penetration of 33% in a line of corrosion in joint 67 (2,146 ft). Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss are recorded. The caliper recordings indicate scale-like deposit throughout the majority of the 3.5 inch tubing, increasing in severity with depth, restricting the I.D. to 2.64 inches in joint 277(8,806 ft). A graph illustrating minimum recorded diameters on a joint-by-joint basis is included in this report. This is the second time a PDS caliper has been run in this well and the first time this 3.5 inch tubing has been logged. MAXIMUM RECORDED WALL PENETRATIONS : C (inion pek,ent Penetration C i'i+; Line Corrosion 33 67 2,146 Ft. (MD) Line Corrosion 31 80 2,565 Ft. (MD) Line Corrosion 31 88 2,814 Ft. (MD) Line Corrosion 29 155 4,897 Ft. (MD) Line of Pits 28 162 5,139 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%)are recorded. MAXIMUM RECORDED ID RESTRICTIONS : scriptior; Minimum Ret.-ted Diameter ,iO!n! :oih Deposits 2.64 inches 277 8,806 Ft. (MD) Deposits 2.65 inches 267 8,499 Ft. (MD) Deposits 2.66 inches 281 9,027 Ft. (MD) Deposits 2.66 inches 282 9,039 Ft. (MD) Deposits 2.67 inches 268 8,538 Ft. (MD) R. Rupe C. Waldrop T. Wiese F ie. 9 E r nee€(s) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (60.9'-9,151.0') Well: 3A-01 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 16, 2017 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 64 40 1,271 80 — 2,539 GLM 1 — 120 3,808 160 — 5,047 CS y � < GLM 2— � 200 — 6,315 a .o GLM3 240 A 7,589 GLM 4 GLMS 280 8,918 283.9 9,151 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=283.9 • • Minimum Diameter Profile Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters(in.) 1.75 2 2.25 2.5 2.75 0.1 1 - ' 61 1 25: 805 3 l 50 1 1,582 72 2,291 971 3,065 119 3,777 L C 144 l 4,551 CZIc Z w c O 169 5,325 c' v CI 191 6,036 216 6,813 238 7,527 2637 8,301 279.2 8,899 ' I- 1 • • PDS Report Overview Body Region Analysis Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD 2.992 in. 61 ft. 9,151 ft. Penetration (%wall) Damage Profile(%wall) 250 Penetration body am Metal loss body 0 50 100 0.1 200 150 100 50 50 0 97 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=306) GLM 1 (7:00) 223 83 0 0 144 Damage Configuration(body) 150 GLM 2 (9:00) 191 100 50 GLM 3 (3:30) 238 0 GLM 4(5:00) Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (11:30) Number of joints damaged(total= 189) 41 1 147 0 0 Bottom of Survey=283.9 • • Plil , I 00PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 61 0 0.03 11 3 2.92 Pup Lt. Deposits. 1 64 0 0.04 14 2 2.94 • 2 93 0 0.05 18 3 2.94 Shallow Line of Pits. ■ 3 124 0 0.03 11 2 2.95 • 4 154 0 0.03 10 3 2.94 5 185 0 0.03 12 3 2.94 6 216 0 0.03 11 3 2.95 ■ 7 247 0 0.04 15 2 2.94 Shallow Line of Pits. • 8 278 0 0.03 10 4 2.95 9 309 0 0.04 15 4 2.95 Shallow Pitting. 10 340 0 0.03 12 2 2.95 ■ 11 371 0 0.04 17 4 2.95 Shallow Line of Pits. 12 402 0 0.04 17 4 2.95 Shallow Line of Pits. 13 433 0 0.03 11 3 2.95 ■ 14 464 0 0.04 16 2 2.95 Shallow Line of Pits. ■ 15 495 0 0.03 12 3 2.94 16 526 0 0.04 17 3 2.96 Shallow Line of Pits. 17 557 0 0.04 15 3 2.95 Shallow Pitting. 18 588 0 0.04 16 4 2.95 Shallow Line of Pits. 19 619 0.04 0.04 17 3 2.94 Shallow Pitting. ■ 20 650 0 0.04 16 2 2.95 Shallow Pitting. 21 681 0 0.04 16 3 2.95 Shallow Pitting. 22 712 0 0.03 13 4 2.94 23 744 0 0.05 18 2 2.94 Shallow Pitting. 24 774 0 0.04 16 4 2.94 Shallow Pitting. 25 805 0 0.03 13 2 2.95 ■ 26 836 0 0.04 17 3 , 2.95 Shallow Pitting. ■ 27 868 0 0.05 19 3 2.94 Shallow Pitting. ■ 28 899 0 0.04 16 3 2.94 Shallow Pitting. ■ 29 930 0 0.06 22 4 2.93 Line of Pits. Lt.Deposits. ■ 30 961 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 31 992 0 0.04 15 2 2.95 . Shallow Line of Pits. • 32 1023 0 0.03 13 2 2.94 ■ 33 1054 0 0.04 16 2 2.95 Shallow Pitting. ■ 34 1085 0 0.04 14 2 2.94 ■ 35 1116 0 0.04 15 3 2.94 Shallow Pitting. ■ 36 1147 0 0.03 13 3 2.94 ■ 37 1178 0 0.04 15 2 2.94 Shallow Pitting. • 38 1208 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. 39 1239 0 0.04 15 4 2.93 Shallow Pitting. Lt Deposits. 40 1271 0 0.04 14 3 2.89 Lt.Deposits. ■ 41 1302 0 0.05 19 2 2.89 Shallow Line of Pits.Lt. Deposits. ■ 42 1333 0 0.04 15 3 2.89 Shallow Line of Pits.Lt. Deposits. 43 1364 0 0.05 19 4 2.89 Shallow Line of Pits.Lt. Deposits. 44 1396 0 0.05 19 3 2.88 Shallow Line of Pits.Lt. Deposits. 45 1426 0 0.05 20 3 2.88 Line of Pits. Lt.Deposits. ■ 46 1458 0 0.05 18 3 2.88 Shallow Line of Pits.Lt. Deposits. 47 1488 0 0.04 17 3 2.88 Shallow Line of Pits.Lt. Deposits. ■ 48 1520 0 0.05 19 4 2.89 Shallow Pitting. Lt Deposits. 49 1551 0 0.04 17 4 2.88 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page1 • • PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 50 1582 0 0.04 17 3 2.89 Shallow Pitting. Lt Deposits. ■ 51 1613 0 0.04 15 3 2.91 Shallow Pitting. Lt Deposits. ■ 52 1644 0 0.04 17 3 2.89 Shallow Pitting. Lt Deposits. ■ 53 1675 0 0.05 19 3 2.87 Shallow Line of Pits.Lt. Deposits. ■ 54 1706 0 0.05 21 3 2.87 Line of Pits. Lt.Deposits. ■ 55 1737 0 0.05 18 4 2.87 Shallow Line of Pits.Lt. Deposits. ■ 56 1768 0.04 0.06 22 4 2.85 Line of Pits. Lt.Deposits. ■ 57 1800 0 0.07 26 6 2.87 Line of Pits. Lt.Deposits. ■ 58 1831 0 0.04 16 4 2.88 Shallow Line of Pits.Lt. Deposits. ■ 59 1862 0 0.05 20 4 2.90 Line of Pits. Lt.Deposits. ■ 60 1893 0 0.06 23 4 2.89 Line Corrosion. Lt.Deposits. ■ 61 1925 0 0.05 19 5 2.88 Shallow Pitting. Lt Deposits. ■ 62 1956 0 0.04 17 3 2.90 Shallow Line of Pits.Lt. Deposits. ■ 63 1987 0 0.05 20 4 2.89 Line of Pits. Lt.Deposits. ■ 63.1 2018 0 0.06 23 4 2.93 Pup Line Corrosion. Lt.Deposits. 63.2 2028 0 0 0 0 2.80 TRMAXX-5E SS SV 63.3 2032 0.04 0.07 26 4 2.88 Pup Line Corrosion. Lt. Deposits. ■ 64 2042 0.05 0.06 25 6 2.88 Corrosion.Lt. Deposits. ■ 65 2073 0.04 0.07 26 4 2.91 Line Corrosion. Lt.Deposits. ■ 66 2105 0 0.06 22 6 2.86 Line of Pits. Lt.Deposits. ■ 67 2136 0.04 0.08 33 4 2.88 Line Corrosion. Lt.Deposits. ■ 68 2167 0.04 0.06 25 4 2.90 Line Corrosion. Lt.Deposits. ■ 69 2198 0.04 0.06 24 4 2.89 Line Corrosion. Lt.Deposits. ■ 70 2229 0.04 0.06 24 0 2.87 Line Corrosion. Lt.Deposits. • 71 2260 0 0.05 20 0 2.86 Line of Pits. Lt.Deposits. • 72 2291 0 0.05 20 1 2.88 Line of Pits. Lt.Deposits. 73 2322 0.04 0.07 27 5 2.89 Line of Pits. Lt.Deposits. ■ 74 2353 0 0.04 16 0 2.88 Shallow Line of Pits.Lt. Deposits. • 75 2384 0.04 0.05 19 0 2.87 Shallow Line of Pits.Lt. Deposits. • 76 2415 0 0.04 17 0 2.88 Shallow Line of Pits.Lt. Deposits. 77 2446 0.05 0.06 23 2 2.88 Line of Pits. Lt.Deposits. • 78 2477 0 0.05 20 1 2.89 Line of Pits. Lt.Deposits. • 79 2508 0.04 0.06 24 1 2.88 Line of Pits. Lt.Deposits. • 80 2539 0.05 0.08 31 4 2.88 Line Corrosion. Lt.Deposits. ■ 81 2570 0.05 0.07 28 3 2.88 Line Corrosion. Lt.Deposits. ■ 82 2600 0 0.05 18 1 2.83 Shallow Line of Pits.Lt. Deposits. • 83 2631 0 0.05 19 0 2.87 Shallow Line of Pits.Lt. Deposits. • 84 2662 0 0.06 23 1 2.89 Line of Pits. Lt.Deposits. • 85 2693 0 0.04 14 1 2.88 Lt.Deposits. 86 2724 0 0.04 17 0 2.88 Shallow Line of Pits.Lt. Deposits. • 87 2754 0 0.04 . 14 0 2.88 Lt.Deposits. • 88 2785 0.05 0.08 31 6 2.88 Line Corrosion. Lt.Deposits. 89 2816 0 0.06 22 4 2.90 Line of Pits. Lt.Deposits. ■ 90 2847 0.04 0.05 21 , 4 2.88 Line of Pits. Lt.Deposits. ■ 91 2878 0.04 0.06 24 4 2.88 Line of Pits. Lt.Deposits. ■ 92 2909 0 0.06 22 4 2.88 Line of Pits. Lt.Deposits. ■ 93 2940 0.05 0.05 18 5 2.89 Shallow Pitting. Lt Deposits. ■ 94 2972 0 0.05 19 5 2.91 Shallow Line of Pits.Lt. Deposits. ■ 95 3003 0.05 0.06 22 4 2.91 Line of Pits. Lt.Deposits. ■ 96 3034 0 0.05 19 3 2.90 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page 2 • • PDS Report joint Tabulation Sheet Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 97 3065 0 0.05 19 4 2.90 Shallow Line of Pits.Lt. Deposits. 98 3096 0 0.05 20 5 2.90 Line of Pits. Lt.Deposits. ■ 99 3127 0 0.05 20 4 2.89 Isolated Pitting. Lt.Deposits. 100 3159 0 0.06 22 5 2.90 Line of Pits. Lt.Deposits. ■ 101 3190 0 0.04 17 4 2.88 Shallow Line of Pits.Lt. Deposits. 102 3221 0 0.05 19 4 2.90 Shallow Line of Pits.Lt. Deposits. 103 3252 0 0.05 19 1 2.89 Shallow Line of Pits.Lt. Deposits. • 104 3283 0.05 0.05 21 3 2.89 Line of Pits. Lt.Deposits. 105 3314 0.05 0.06 23 5 2.89 Line of Pits. Lt.Deposits. ■ 106 3345 0.04 0.06 23 3 2.90 Line of Pits. Lt.Deposits. 107 3375 0 0.07 26 5 2.89 Isolated Pitting. Lt.Deposits. ■ 108 3406 0.04 0.05 20 5 2.92 Line of Pits. Lt.Deposits. ■ 109 3437 0.04 0.05 19 6 2.90 Shallow Line of Pits.Lt. Deposits. ■ 110 3468 0.04 0.05 18 6 2.91 Shallow Line of Pits.Lt. Deposits. ■ 111 3499 0 0.05 19 4 2.92 Shallow Line of Pits.Lt. Deposits. 112 3530 0.04 0.05 19 4 2.90 Shallow Line of Pits.Lt. Deposits. 113 3561 0 0.05 18 4 2.92 Shallow Line of Pits.Lt. Deposits. 114 3592 0 0.05 18 4 2.92 Shallow Line of Pits.Lt. Deposits. 115 3623 0.05 0.06 22 6 2.89 Line Corrosion. Lt.Deposits. ■ 115.1 3654 0 0,03 12 3 2.92 Pup Lt. Deposits. 115.2 3664 0 0 0 0 2.88 GLM 1 (LATCH @ 7:00) 115.3 3673 0 0.04 15 3 2.91 Pup Shallow Line of Pits.Lt. Deposits. 116 3683 0 0.05 19 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 117 3714 0 0.05 19 5 2.89 Shallow Pitting. Lt Deposits. ■ 118 3746 0.04 0.04 17 4 2.89 Shallow Line of Pits.Lt. Deposits. ■ 119 3777 0.04 0.05 20 5 2.91 Line of Pits. Lt.Deposits. ■ 120 3808 0 0.05 21 5 2.91 Line of Pits. Lt.Deposits. ■ 121 3839 0.05 0.05 18 5 2.75 Shallow Line of Pits.Deposits. ■ 122 3870 0.04 0.05 21 5 2.91 Line of Pits. Lt.Deposits. ■ 123 3901 0 0.05 20 4 2.90 Line of Pits. Lt.Deposits. 124 3932 0.04 0.04 17 5 2.92 Shallow Line of Pits.Lt. Deposits. 125 3963 0 0.05 19 6 2.92 Shallow Line of Pits.Lt. Deposits. ■ 126 3994 0 0.04 17 4 2.90 Shallow Line of Pits.Lt. Deposits. 127 4026 0 0.06 22 7 2.90 Isolated Pitting. Lt.Deposits. 128 4057 0 0.05 19 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 129 4088 0 0.04 17 3 2.90 Shallow Line of Pits.Lt. Deposits. 130 4119 0 0.04 17 5 2.91 Shallow Pitting. Lt Deposits. ■ 131 4150 0 0.04 17 4 2.91 Shallow Line of Pits.Lt. Deposits. 132 4181 0 0.05 20 4 2.91 Line of Pits. Lt.Deposits. 133 4212 0.04 0.05 18 3 2.91 Shallow Line of Pits.Lt. Deposits. 134 4242 0 0.05 19 3 2.90 Shallow Line•of Pits.Lt. Deposits. ■ 135 4273 0 0.04 17 4 2.91 Shallow Line of Pits.Lt. Deposits. 136 4304 0 0.05 20 4 2.91 Line of Pits. Lt.Deposits. 137 4335 0 0.04 14 2 2.93 Lt.Deposits. 138 4366 0 0.04 16 4 2.90 Shallow Line of Pits.Lt. Deposits. 139 4397 0.04 0.05 19 5 2.91 Shallow Line of Pits.Lt. Deposits. 140 4427 0 0.05 19 4 2.90 Shallow Line of Pits.Lt. Deposits. ■ 141 4458 0 0.06 22 6 2.88 Line of Pits. Lt.Deposits. ■ 142 4489 0 0.04 17 5 2.90 Shallow Line of Pits.Lt. Deposits. ■ 143 4520 0 0.07 26 4 2.88 Line of Pits. Lt.Deposits. IPenetration Body Metal Loss Body Page 3 • • III S PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 144 4551 0 0.05 . 20 4 2.88 Line of Pits. Lt.Deposits. ■■ 145 4581 0.04 0.06 25 5 2.89 Line Corrosion. Lt.Deposits. ■ 146 4612 0 0.05 . 19 4 2.87 Shallow Line of Pits.Lt. Deposits. ■� 147 4643 0 0.06 24 3 2.89 Line of Pits. Lt.Deposits. ■o 148 4674 0 0.06 23 3 2.88 Line of Pits. Lt.Deposits. ■o 149 4705 0 0.06 24 4 2.87 Line Corrosion. Lt.Deposits. ■o 150 4736 0.04 . 0.06 22 5 2.86 Line of Pits. Lt.Deposits. ■E 151 4767 0 0.05 21 5 2.89 Line of Pits. Lt.Deposits. ■o 152 4798 0.04 0.07 26 3 2.86 Line Corrosion. Lt.Deposits. ■■ 153 4829 0 0.06 24 4 2.85 Line of Pits. Lt.Deposits. ■ 154 4860 0 0.04 17 0 2.86 Shallow Line of Pits.Lt. Deposits. .3 155 4891 0.04 0.07 29 4 2.88 Line Corrosion. Lt.Deposits. a 156 4922 0 0.03 13 1 2.86 Lt.Deposits. ■i 157 4954 0 0.05 21 3 2.87 Line of Pits. Lt.Deposits. ■■ 158 4985 0.04 0.07 28 5 2.88 Line Corrosion. Lt.Deposits. n■ 159 5016 0 0.05 20 4 2.88 Line of Pits. Lt.Deposits. ■ 160 5047 0 0.04 17 6 2.89 Shallow Pitting. Lt Deposits. ■a 161 5078 0.05 0.05 21 4 2.89 Line of Pits. Lt.Deposits. ■■ 162 5109 0 0.07 28 5 2.89 Line of Pits. Lt.Deposits. ■■ 163 5139 0 0.05 21 0 2.88 Line of Pits. Lt.Deposits. ■■ 164 5170 0 0.07 26 4 2.87 Line Corrosion. Lt.Deposits. ■■ 165 5201 0.04 0.05 21 4 2.89 Line of Pits. Lt.Deposits. ■■ 166 5231 0 0.06 25 3 2.88 Line Corrosion. Lt.Deposits. ■ 167 5263 0.04 0.05 19 4 2.86 Shallow Line of Pits.Lt. Deposits. ■O 168 5294 0 0.06 24 0 2.84 Line of Pits. Lt.Deposits. ■■ 169 5325 0 0.05 21 4 2.87 Line of Pits. Lt.Deposits. ■ 170 5356 0 0.04 14 0 2.87 Lt.Deposits. ■A 171 5387 0 0.05 21 4 2.86 Line of Pits. Lt.Deposits. ■ 172 5418 0.05 0.05 19 5 2.90 Shallow Pitting. Lt Deposits. ■� 173 5450 0 0.05 21 5 2.87 Line of Pits. Lt.Deposits. ■ 174 5481 0 0.05 19 1 2.87 Shallow Line of Pits.Lt. Deposits. -2 175 5512 0.06 0.05 20 3 2.88 Line of Pits. Lt.Deposits. ■ 176 5543 0 0.07 26 4 2.88 Line Corrosion. Lt.Deposits. ■ 177 5574 0 0.03 12 0 2.87 Lt.Deposits. mi 178 5605 0 0.05 20 5 2.87 Line of Pits. Lt.Deposits. ■■ 179 5636 0.06 0.05 21 4 2.88 Line of Pits. Lt.Deposits. ■ 180 5667 0 0.05 19 0 2.86 Shallow Line of Pits.Lt. Deposits. ■ 181 5699 0 0.04 15 0 2.88 Shallow Pitting. Lt Deposits. ■ 182 5730 0 0.03 12 1 2.88 Lt.Deposits. a 183 5761 0 0.05 21 5 2.89 Isolated Pitting. Lt.Deposits. ■ 184 5792 0 0.05 18 0 2.88 Shallow Pitting. Lt Deposits. ■ 185 5823 0 0.04 17 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 186 5854 0 0.05 19 4 2.89 Shallow Line of Pits.Lt. Deposits. ■ 187 5885 0.05 0.05 20 3 2.88 Line of Pits. Lt.Deposits. ■ 188 5915 0 0.05 20 4 2.89 Line of Pits. Lt.Deposits. ■ 189 5945 0 0.04 15 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 189.1 5976 0 0.03 11 2 2.91 Pup Lt. Deposits. ' 189.2 5986 0 0 0 0 2.87 GLM 2(LATCH @ 9:00) 189.3 5995 0 0.03 10 2 2.88 Pup Lt. Deposits. ■ 190 6005 0 0.03 13 4 2.82 Lt.Deposits. IPenetration Body Metal Loss Body Page 4 • • 11111 4:14 S PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 191 6036 0 0.04 15 3 2.88 Shallow Pitting. Lt Deposits. ■ 192 6067 0 0.04 15 4 2.90 Shallow Line of Pits.Lt. Deposits. ■ 193 6098 0 0.03 . 11 4 2.89 Lt.Deposits. ■ 194 6129 0 0.03 13 3 2.85 Lt.Deposits. ■ 195 6160 0 0.03 12 2 2.90 Lt.Deposits. ■ 196 6191 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 197 6222 0 0.04 14 3 2.90 Lt.Deposits. ■ 198 6253 , 0.04 0.04 15 3 2.90 Shallow Line of Pits.Lt. Deposits. ■ 199 6285 0 0.04 14 5 2.88 Lt.Deposits. ■ 200 6315 0 0.03 11 3 2.89 Lt.Deposits. ■ 201 6347 0 0.03 13 3 2.89 Lt.Deposits. ■ 202 6378 0 0.04 14 4 2.93 Lt.Deposits. 203 6409 0 0.02 6 0 2.88 Lt.Deposits. 204 6440 0 0.03 11 4 2.88 Lt.Deposits. ■ 205 6471 0 0.04 14 3 2.91 Lt.Deposits. ■ 206 6502 0 0.03 11 4 2.88 Lt.Deposits. ■ 207 6533 0 0.04 14 4 2.88 Lt.Deposits. ■ 208 6564 0 0.03 11 2 2.90 Lt.Deposits. 209 6595 0 0.03 12 3 2.90 Lt.Deposits. ■ 210 6627 0 0.03 11 4 2.91 Lt.Deposits. ■ 211 6658 0 0.03 11 2 2.91 Lt.Deposits. ■ 212 6688 0 0.03 10 2 2.92 Lt.Deposits. ■ 213 6719 0 0.03 13 2 2.91 Lt.Deposits. 214 6750 0 0.04 15 3 2.89 Shallow Pitting. Lt Deposits. ■ 215 6782 0 0.03 11 3 2.89 Lt.Deposits. ■ 216 6813 0 0.03 11 4 2.90 Lt.Deposits. ■ 217 6844 0 0.04 14 2 2.89 Lt.Deposits. 218 6875 0 0.04 . 16 5 2.90 Shallow Pitting. Lt Deposits. ■ 219 6906 0 0.04 14 3 2.90 Lt.Deposits. ■ 220 6938 0 0.03 13 4 2.88 Lt.Deposits. 221 6969 0 0.02 9 2 2.91 Lt.Deposits. 222 7000 0 0.03 11 2 2.91 Lt.Deposits. 223 7032 0 0.04 14 3 2.90 Lt.Deposits. ■ 224 7063 0 0.03 11 2 2.89 Lt.Deposits. 225 7093 0 0.04 14 3 2.89 Lt.Deposits. ■ 226 7124 0 0.03 11 2 2.90 Lt.Deposits. 227 7156 0 0.04 16 2 2.89 Shallow Pitting. Lt Deposits. 228 7187 0 0.03 12 4 2.91 Lt.Deposits. ■ 229 7218 0 0.04 15 4 2.89 Shallow Pitting. Lt Deposits. ■ 230 7249 0 0.04 16 4 2.89 Shallow Line of Pits.Lt. Deposits. • 231 7280 0 0.03 10 2 2.90 Lt.Deposits. 231.1 7312 0 0.02 8 2 2.87 Pup Lt. Deposits. 231.2 7322 0 0 0 0 2.86 GLM 3(LATCH @ 3:30) 231.3 7330 0 0.05 20 5 2.88 Pup Line of Pits. Lt.Deposits. ■ 232 7341 0.04 0.04 14 4 2.88 Lt.Deposits. ■ 233 7372 0 0.04 15 3 2.86 Shallow Pitting. Lt Deposits. 234 7401 0 0.01 3 0 2.87 Lt.Deposits. 235 7433 0 0.02 9 0 2.87 Lt.Deposits. • 236 7465 0 0.02 6 0 2.86 Lt.Deposits. ■ 237 7496 0 0.02 7 0 2.86 Lt.Deposits. • IPenetration Body Metal Loss Body Page 5 • i PI PDS Report Joint Tabulation Sheet Cir Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 • 238 7527 0 0.02 6 0 2.86 Lt.Deposits. • 239 7558 0 0.02 8 0 2.87 Lt.Deposits. • 240 7589 0 0.02 6 0 2.86 Lt.Deposits. II 241 7620 0 0.02 6 0 2.85 Lt.Deposits. II 242 7651 0 0.01 5 0 2.86 Lt.Deposits. • 243 7682 0 0.02 8 0 2.87 Lt.Deposits. 244 7713 0 0.02 6 0 2.86 Lt.Deposits. U I 245 7744 0 0.01 4 0 2.69 Deposits. II 246 7775 0 0.01 5 0 2.87 Lt.Deposits. 247 7806 0 0.04 15 4 2.88 Shallow Pitting. Lt Deposits. 1 248 7837 0 0.01 4 0 2.87 Lt.Deposits. 249 7868 0 0.00 2 0 2.86 Lt.Deposits. 250 7899 0 0.01 5 0 2.87 Lt.Deposits. • 251 7930 0 0.01 4 0 2.87 Lt.Deposits. • 252 7961 0 0.02 9 1 2.85 Lt.Deposits. 253 7992 0 0.02 9 0 2.85 Lt.Deposits. • 254 8023 0 0.02 9 0 2.86 Lt.Deposits. • 255 8054 0 0.02 7 0 2.83 Lt.Deposits. • 256 8085 0 0.02 7 0 2.82 Lt.Deposits. • 257 8116 0 0.02 6 0 2.82 Lt.Deposits. • 258 8147 0 0.02 9 1 2.83 Lt.Deposits. • 259 8177 0 0.03 10 1 2.83 Lt.Deposits. INI 260 8209 0 0.02 7 0 2.82 Lt.Deposits. r 261 8239 0 0.05 18 0 2.82 Shallow Pitting. Lt Deposits. 262 8270 0 0.03 10 0 2.81 Deposits. • 263 8301 0 0.02 7 0 2.81 Deposits. • 263.1 8333 0 0.03 10 0 2.87 Pup Lt. Deposits. • 263.2 8342 0 0 0 0 2.85 GLM 4(LATCH @ 5:00) 263.3 8351 0 0.01 5 0 2.79 Pup Deposits. • 264 8362 0 0.04 14 0 2.77 Deposits. NM 264.1 8393 0 0.02 7 0 2.78 Pup Deposits. • 264.2 8399 0 0 0 0 2.75 BAKER LOCATOR SEAL ASSEMBLY 264.3 8412 0 0 0 0 3.39 BAKER FHL RETRIEVABLE PACKER 264.4 8413 0 0.04 16 2 2.74 Pup Shallow Pitting. Deposits. C 265 8424 0 0.02 9 0 2.73 Deposits. 266 8456 0 0.02 6 0 2.70 Deposits. • 267 8485 0 0.02 9 0 2.65 Deposits. • 268 8516 0 0.07 27 0 2.66 Line of Pits. Deposits. INNIN 269 8548 0 0.02 6 0 2.71 Deposits. • 270 8579 0 0.05 19 0 2.70 Shallow Line of Pits.Deposits. r 271 8610 0 0.04 14 0 2.70 Deposits. im 272 8641 0 0.02 6 0 2.67 Deposits. • 273 8672 0 0.02 7 0 2.69 Deposits. • 274 8703 0 0.03 10 0 2.71 Deposits. • 275 8734 0 0.03 12 0 2.72 Deposits. • 276 8766 0 0.03 12 1 2.67 Deposits. NN 277 8797 0 0.01 5 0 2.64 Deposits. • 278 8828 0 0.02 9 0 2.70 Deposits. • 279 8856 0 0.02 8 0 2.67 Deposits. • 279.1 8887 0 0.01 3 0 2.68 Pup Deposits. IPenetration Body Metal Loss Body Page 6 • • Eli tit PDS Report Joint Tabulation Sheet Well: 3A-01 Survey Date: May 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. ' 0.254 in. 61 ft. 9,151 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 279.2 8899 0 0 0 0 2.74 BAKER PREMIER PACKER 279.3 8906 0 0.00 2 0 2.72 Pup Deposits. 280 8918 0 0.02 6 0 2.71 Deposits. 0 280.1 8946 0 0.01 4 ; 0 2.70 Pup Deposits. 280.2 8957 0 0 0 0 2.77 HES X NIPPLE I 280.3 8958 0 0.01 4 0 2.71 Pup Deposits. 280.4 8969 0 0 0 0 2.71 Pup Deposits. 280.5 8978 0 0 0 0 2.70 GLM 5(LATCH @ 11:30) 280.6 8986 0 0.04 16 0 2.72 Pup Shallow Pitting. Deposits. m 281 8997 0 0.05 20 0 2.66 Line of Pits. Deposits. NEN 282 9028 0 0.04 17 0 2.66 Shallow Pitting. Deposits. 283 9059 0 0.03 11 0 2.67 Deposits. IN 283.1 9089 0 0.01 5 , 0 2.69 Pup Deposits. 283.2 9103 0 0 0 0 2.80 BAKER CMU SLIDING SLEEVE 283.3 9109 0 0 0 0 2.94 BAKER F-1 PACKER 283.4 9122 0 0 0 0 3.01 MILLOUT EXTENSION 283.5 9129 0 0.03 13 4 2.92 Pup Lt. Deposits. 283.6 9139 0 0.03 11 3 2.93 Pup Lt. Deposits. 283.7 9145 0 0 0 0 2.74 CAMCO D NIPPLE 283.8 9146 0 0.03 13 3 2.91 Pup Lt. Deposits. r 283.9 9151 0 0 0 0 3.36 WLEG Penetration Body Metal Loss Body Page 7 • • PDS Report Cross Sections Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 67 at depth 2,146.460 ft. Tool speed=57 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=98% Tool deviation=50° 1 Finger= 10 Penetration=0.084 in. Line Corrosion 0.08 in.=33%Wall Penetration HIGH SIDE=UP • • 4_4rS PDS Report Cross Sections Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 80 at depth 2,565.040 ft. Tool speed=57 Nominal ID=2.992 Nominal OD=3.5 — — ` Remaining wall area=97% Tool deviation=54° „Is 1 i Finger= 15 Penetration=0.080 in. Line Corrosion 0.08 in.=31%Wall Penetration HIGH SIDE= UP 0 • dli4S PDS Report Cross Sections Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 277 at depth 8,806.370 ft. Tool speed=54 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=49° ' I , 1 i 1 vol Minimum I.D.=2.641 in. Deposits Minimum I.D.=2.64 in. HIGH SIDE=UP 1 S CIPS PDS Report Cross Sections Well: 3A-01 Survey Date: May 16,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 267 at depth 8,498.990 ft. Tool speed= 54 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% �\ Tool deviation=49° 1 Minimum I.D.=2.646 in. Deposits Minimum I.D.=2.65 in. HIGH SIDE=UP �- 5, KUP PROD • 3A-01 ConocoPhilhps -; Well Attributes Max Angle&MD TD Alaska,Inc. • Wellbore APuuWI Field Name Wellbore Status Inc!(°) MD(566) Act Btm(ftKB) 0.,,,,,, , 500292141200 KUPARUK RIVER UNIT PROD 56.28 2,400.00 9,600.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-01.2/9/20151:17.58 PM SSSV.TRDP 100 12/29/2014 Last WO: 10/16/2006 35.19 9/1/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .......... ......_........ ..... ..._.__ __ Last Tag: 9,291.0 6/15/2007 Rev Reason:ADD WAIVER NOTE,H2S hipshkf 2/9/2015 Casing Strings HANGER;30.2 - � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 104.0 104.0 62.50 H-40 WELDED /.. 0,n„a,u uaw Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread _inti,, SURFACE 95/8 8.921 30.2 4,353.4 3,157.2 36.00 J-55 BTC CONDUCTOR;31.0-104.0-4 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ___ PRODUCTION 7 6.276 23.7 9,575.0 6,331.3 26.00 J-55 BTC Tubing Strings SAFETY VLV;2,003.4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(WD)(...Wt(Ibftt) Grade Top Connection TUBING WO 31/2 2.992 30.2 9,151.5 6,020.7 9.30 L-80 EUE 8RD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top In (') Item Des Com (in) GAS LIFT;3,544.9 30.2 30.2 0.11 HANGER HANGERVALVE 2.992 2,003.4 1,802.9 48.47 SAFETY VLV TRMAXX-5EFMCTUBING SAFETY 2.812 8,398.9 5,526.3 53.49 SEAL ASSY -BAKER LOCATOR SEAL ASSEMBLY 3.000 8,398.9 5,526.3 53.49'PER PBR 80-40 3.000' 8,412.6 5,534.4 53.36 PACKER 'BAKER FHL RETRIEVABLE PACKER 2.990 8,900.1 5,845.1 46.88 PACKER BAKER PREMIER PACKER 598-287 2.870 SURFACE;30.2.4.353.4-el 4 8,957.4 5,884.4 46.44 NIPPLE 'HES'X'NIPPLE 2.813 9,034.7 5,937.9 45.67 BLAST RING CARBIDE BLAST RING(1) 2.992 GAS LIFT;5,975.7 - 9,101.9 5,985.3 44.80 SLEEVE-O BAKER CMU SLIDING SLEEVE w/2.812'BX PROFILE 2.812 (OPEN 3/15/2007) •,.. 9,110.5 5,991.4 44.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 lIl 9,110.5 5,991.4 44.71 PACKER BAKER F-1 PACKER 4.000 GAS LIFT;7,315.1 - 9,113.8 5,993.8 44.67 SBE BAKER SEAL BORE EXTENSION 4.000 9,124.0 6,001.0 44.56 MILLOUT EXT MILL OUT EXTENSION 4.390 i 9,145.9 6,016.7 44.32 NIPPLE CAMCO'D'NIPPLE w/2.75"PROFILE 2.750 GAS LIFT;8,340.5 ' .,' 9,151.0 6,020.3 44.26 WLEG WIRELINE ENTRY GUIDE 3.000 Perforations&Slots 11 shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (fB(B) (ftKB) Zone Date t) Type Com { PBR;8,398.9 9,020.0 9,036.0 5,927.7 5,938.9 C-1,3A-01 11/10/1985 12.0 IPERF 5'HyperJet II,120 deg. ph < . PACKER;8,412.6 • ,,- 9,165.0' 9,195.0 6,030.3 6,051.9 A-3,3A-01 '11/10/1985 4.0 IPERF 4"Hyper Jet II,90 deg. V ph ft 9,210.0 9,260.0 6,062.8' 6,099.2'A-2,3A-01 '11/10/1985 4.0 (PERF 4"Hyper Jet II,90 deg. 11 ph ' Mandrel Inserts PACKER;8,900.1 St ail on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model _OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,644.9 2,742.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 3/11/2011 ill 2 5,975.7 4,103.5'CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188' 1,276.0 10/19/2006 NIPPLE;8,957.4 3' 7,315.1 4,903.4 CAMCO MMG 1 1/2 GAS LIFT 'GLV RK 0.188 1,270.0 10/19/2006 PRODUCTION;8,978.7 4 8,340.5 5,491.7'CAMCO -MMG 1 1/2 GAS LIFT 'OV RK 0.250 0.0 8/15/2013 5 8,978.7 5,899.1 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 10/16/2006 Close _ d Notes:General&Safety (PERF;9,020.0.9,036.0= AEnd Date Annotation 9/29/1998 NOTE:Top of junk @ 9332'MD - - 12/21/2010 NOTE: IA x OA COMMUNICATION 1/6/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/12/2012 NOTE:RIG RKBs ORIGINAL vs 2006 WORKOVER AFFECTS PROD/TBG TOPS SLEEVE-0;9,101.9 II lai PACKER;9,110.5 SBE;9,113.8 MILLOUT EXT;9,124.0 ;r NIPPLE;9,145.9 WLEG;9,151.0 IPERF;9,105.0-9,1950- .�- IPERF;9,210.0.9,200.0-+ PRODUCTION;23.7-9,575.0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_ ~,.~)--- 1 ~'_~2 Well History File Identifier Organization (done) RESCAN [] Color items: E] Grayscale items: Poor Quality Originals: Other: DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No. [] Maps: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES:~I NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL ~OWELL Project Proofing [] Other [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES: ~ I (at the time of scanning) SCANNED BY; ~BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.wpd • • • • ConocoPh~ll~ps ~~r~~ - ..~v Alaska P.O. BOX 100360 A P ~ ~ ~ ((,' , ANCHORAGE, ALASKA 99510-0360 gg /(~~ AChQt«~ April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue0,lSuite 100 ~ `' `~ . ~~~~~~' Anchorage, AK 995 y' ~ ~ -~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kv lein- ConocoPhillips Well Integrity Projects Supervisor ! ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off '--~ Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-036 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 / 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30!2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 Schlumbepger {õS -106 c~ 04/20/07 NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~1A y () 4 2001 sCANNED MAY 0 7 Z007 Oil/:l; (>ommis$iof,! Field: Kuparuk Well Log Description BL CD Job# Date Color 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (0 . . . . Gary Eller Wells Group Engineer Drilling & Wells Conocó'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 November 7,2006 RECEIVED !'lDV ;] 2006 Commissioner State of Alaska Cons. Commission Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3A-01 (APD # 185-186/306-254) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the Kuparuk well 3A-01. If you have any questions regarding this matter, please contact me at 263-4172. Sin~ ~ J. a Elle~ Wel oup Engineer CPAI Drilling and Wells JGE/skad ~..~',r J,¡>,~~"r;:- n. ~"'ì;i',N~& ç/.t.lo. '.' r:, v c 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 72' . RECEIVED . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION:. REPORT OF SUNDRY WELL OPERA Tfat!J~)¡j Repair Well 0 . Pull Tubing 0 Operat. ShutdownD Other "DC] Time Extension 0 Re-enter Suspended Well 0 Stimulate 0 Waiver 0 Plug Perforations 0 . Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory Service o o 5. Permit to Drill Number: 185-186 / 306-254 6. API Number: 50-029-21412-00 . 9. Well Name and Number: 3A-01 . 8. Property Designa!ion: ADL 25632, ALK 2448 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 9600' feet true vertical 6350' feet measured 9175' feet true vertical 6038' feet Length Size MD 80' 16" 104' 4329' 9-5/8" 4353' 9551' 7" 9575' Plugs (measured) Junk (measured) 9332' TVD Burst Collapse 104' 3157' 6331' Measured depth: 9020'·9036',9165'-9195',9210'-9260' true vertical depth: 5928'-5939',6030'·6052',6063'-6099' Tubing (size, grade, and measured depth) 3.5", L-80, 9151' MD. Packers & SSSV (type & measured depth) Baker FHL pkr, Baker Premier pkr, Baker F-1 pkr @ 8413',8900',9110' Cameo TRMAXX-5E SSSV @ 2003' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 217 675 676 133 Subsequent to operation 269 556 644 148 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0' Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 Gas 0 WAG 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. \. Form 10-404 Revised ~ Contact Printed Name Signature Wells Group Engineer Date Title Phone \ \ \\'\:)\\)\c b Sh ron All u -0,,, 263-4612 ~ 1(.1$. tJt... Subm~inal..o.~9'; ,r ~v Ilð~(t~h Pre a 2006 k\.\(l'-'\, . . KRU 3A-01 ConocoPhillips Alaska, Inc. ~ 3A-01 - Tubing API: 500292141200 Well Tvoe: PROD Anale (1ì) TS: 46 dea (â) 9016 (0-9151, SSSV Tvoe: TRDP Oria Comoletion: 9/1/1985 Anale (1ì) TD: 42 dea (â) 9600 OD:3.500, Annular Fluid: DSUBrine Last W/O: 10/1712006 Rev Reason: WORKOVER ID:2.992) Reference Loa: Ref Loa Date: Last UDdate: 11/312006 Last Taa: 9175' TD: 9600 ftKB Last T éKI Date: 10/23/2006 Max Hole Anale: 56 ~400 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 104 104 62.50 H-40 SUR. CASING 9.625 0 4353 3157 36.00 J-55 PROD. CASING 7.000 0 9575 6331 26.00 J-55 Tubina Strina . TUBING Size TaD 1 Bottom 1 TVD 1 Wt T Grade 1 Thread 3.500 0 1 9151 1 6020 1 9.30 1 L-80 1 EUE-ABM Perforations Summary Interval TVD Zone Status Ft SPF Date TVDe Comment 9020 - 9036 5928 - 5939 C-1 16 12 11/10/1985 IPERF 5" HvnerJet II, 120 dea. Dh 9165 - 9195 6030 - 6052 A-3 30 4 11/10/1985 IPERF 4" Hvner Jet II, 90 dea. oh 9210·9260 6063 - 6099 A-2 50 4 11/10/1985 IPERF 4" Hvner Jet II 90 dea. oh Gas Lift MandreJsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3645 2743 CAMCO MMG GLV 1.5 RK 0.188 1274 1 0/191200 2 5976 4104 CAMCO MMG GLV 1.5 RK 0.188 1276 1 0/19/200 3 7315 4903 CAMCO MMG GLV 1.5 RK 0.188 1270 1 0/19/200 4 8340 5492 CAMCO MMG OV 1.5 RK 0.250 0 1 0/19/200 Production MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 5 1 8979 58991 CAMCO MMG DMY I 1.5 RK I 0.000 I 0 11 0/16/2006 other [plugs, equip., etc.) - COMPLETION POST WORKOVER 10116120061 Depth TVD Type Descrintion ID 2003 1803 SSSV TRMAXX-5E SSSV set 10/16/2006 2.812 8399 5526 SEAL BAKER PBR SEAL ASSEMBLY, size 80-40, set 10/16/2006 3.000 8413 5535 PACKER BAKER FHL PACKER, size 47B2-7" 26# set 10/16/2006 2.990 8900 5845 PACKER BAKER PREMIER PACKER 7" x 3.5" 598-287 set 10/16/2006 2.870 8957 5884 NIPPLE 'X' NIPPLE set 10/16/2006 2.813 9035 5938 Blast Rings CBJ BLAST JOINT w/CBRs; 26' CARBIDE BLAST RINGS SPACED 5' 2.992 Perf ~ - ABOVE & 5' BELOW C-SAND PERFS, set 10/16/2006 (9020-9036) ~ - 9102 5985 SLEEVE-C BAKER CMU SLIDING SLEEVE 2.812" 'BX' PROFILE set 10/16/2006 2.812 ~ - 9110 5991 PACKER BAKER F-1 PACKER, size 85-40, set 10/5/2006 4.000 ~ - ~ - 9114 5994 SBE BAKER SEAL BORE EXTENSION, size 80-40 set 10/16/2006 4.000 ~ - 9146 6017 NIP CAMCO 'D' NIPPLE set 10/16/2006 2.750 ~ - ~ - 9151 6020 WLEG BAKER WIRELlNE ENTRY GUIDE set 10116/2006 3.000 ~ - General Notes ~ - Date I Note 9/29/19981 Too of iunk (1ì) 9332' MD Perf ~ - (9165-9195) ~ - ~ r-- ~ '-- ~ '-- ~ '-- Perf = ï== (9210-9260) ~ '-- ~ f-- ~ f-- ~ f-- ~ f-- Conocó'Phillips Wellview Wet> Reporting Time Log summary. 09/24/2006 00:00 05:00 05:00 10:30 10:30 19:00 19:00 00:00 09/25/200600:00 03:00 03:00 04:00 04:00 05:00 05:00 12:00 12:00 16:00 16:00 00:00 09/26/2006 00:00 03:00 03:00 04:30 04:30 08:30 08:30 11 :00 5.00 MIRU MOVE DMOB P Scope down and lower derrick. Move pit module and pipe shed away from carrier. Move rig carrier off wellhead. Pick u ri mats and herculite liner. MIRU MOVE MOB P Move camp, shop, and generator skid to 3A-01, return Peak trucks to 1 C-01 for pits, pipe shed and rig, Move e ui ment to 3A-01. MIRU MOVE RURD P Rig on location. Spot rig over wellhead. Lay down herculite. Spot pits and pipe shed. Berm up around rig. Raise and scope derrick. Has able to spot rig straight over wellhead do to well being at end of well row. Rig accepted 17:00 on 9/24/06. COMPZ WELCT CIRC P Rig up and pull BPV. 800 psi on tubing, Rig up Hot oil to pump down the tubing taking returns to outside tanks. 60 bbls diesel, 100 bbls Hot deg sea water, 190 bbls sea water, followed b 9.6 Brine. COMPZ WELCT CIRC P Pump 360 bbls of 9.6 ppg Brine down the tubing up IA @ 3.5 bpm from 1100 psi to 0 psi. Monitor well 30 minutes, well static. COMPZ RPCOII. NUND P Rig down circulating equipment, 30 psi on casing, bleed off into bleed tank, install BPV. RPCOII. NUND P ND Tree, inspect lift threads, look ood, install blankin lu RPCOII. NUND P NUBOPE, function test. 5.50 8.50 5.00 3.00 1.00 1.00 RPCOII. CIRC P Bleed IA to outside tanks Pull blanking Plug attempt to pull BPV small amount of as under BPV ri u to cir. RPCOII. CIRC P Circulate out gas with 9.6 ppg brine 7.00 4.00 RPCOII. DHEQ P Pressure test BOPE, annular failed. 8.00 RPCOII. DHEQ T Redress annular BOP 3.00 WELCT BOPE P Finish testing BOP's 1.50 4.00 2.50 WELCT CIRC P Shut down and monitor well, 70 psi on both sides wt u to 10 Circulate in 10 ppg brine down the tubing up IA to outside tanks, holding 30 psi on choke unable to exceed 1.2 bpm with out suffering 50% losses. Company Man Changeout. Good 10# brine back to tanks. Break circualtion, shut down and monitor well. Well a ears dead. 15:00 17:00 2.00 COMPZ RPCOI\ PULD P BOLDS; unland hanger and pull up to max. pull92k (10k blocks). See approx 4' of movement including stretch. Work pipe; no change - unable to get pipe moving. Fill hole, approx 7 bbl to top oft, sma III amount of gas breaking out of rtns. Begin circualting to its 2.0b m. 17:00 20:00 3.00 P Call out SLB E-line for string shotlchem cut. Pull landing joint and resume circulating back to pits at 1.5 bpm. Begin picking up Kelly & loading i e shed wI PH-6. 20:00 00:00 4.00 P Wait on longer bails to arrive from Deadhorse. Continue to rig up SWS equipment and load pipe while waiting on bails. 09/27/200600:00 02:00 2.00 RPCOI\ RURD P Rig up longer bails to accomodate SLB pressure equipment during chemical cut. Losing approx 12 bbls of brine er hour. 02:00 05:00 3.00 RPCOI\ SLKL P Fire string shot from 8578' - 8590' md. Unable to reach target depth of 8595' due to fill. POOH. 05:00 07:00 2.00 RPCOI\ RURD P At surface; chem cutter BHA approx. 9" longer than string shot BHA, unable to get enough distance from blocks to run. BOLDS. Pull82k (10k blocks, 8k over string wgt) on string and unseat hanger, fill hole (approx. 4 bbls) and set floor slips. Unlatch elevators, attach dog collar. Hang e-line sheave off blocks, make up 2-1/8 chem chem cutter and run same in hole. 07:00 09:00 2.00 RPCOI\ PL T P Conduct pre-job. Make chem cut at 8582' md; begin POOH wI wireline, fillin across to of hole. 09:00 10:30 1.50 RPCOI\ RURD P At surface wI chem cutter; tool fired. Lay down SLB equipment and prep to pull tubing. Pick up, free movement at 86K. Conduct pre-job safety meeting. Pull hanger to the floor. Rig up cable sheave, remainder of spooling equipment, lay down remaining SLB e ui ,break out and la down han er. 09/27/2006 10:30 16:00 16:00 22:00 22:00 00:00 09/28/2006 00:00 03:30 03:30 04:00 04:00 05:00 05:00 06:00 06:00 09:30 09:30 11 :30 11 :30 14:00 14:00 20:00 20:00 22:00 22:00 00:00 09/29/2006 00:00 01 :00 01 :00 06:00 06:00 09:00 5.50 RPCOI\ PULD P Begin pulling completion out of hole. Losses averaging approx 4 bph. 24 jts out, having problems getting tongs to grip, change out dies. Continue out of hole. Make crew change (55 jts out at shift chan e . RPCOI\ PULD P Pull 139 joints then shut-down to release s oolin unit to Do on 141. RPCOI\ WOEQ NP Rig down cable sheave and spooler. Circulate bottoms up from approx 4275' md with 10# brine. RPCOI\ WOEQ NP Circulate 10# brine from approx 4275' to suñace. No increase in pit volume, but circulating pressure = 150 psi at 3 b m. RPCOI\ OWFF T Shut down pump to monitor well. Gas breaking out at suñace, so started to um 10.3# viscosified ill. WELC1 CIRC T Close Annular Preventer and bullhead 65 bbls of 10.3# viscosified brine. WELC1 CIRC T Shut down pump and monitor pressures. Tubing pressure = 20 psi, Annular ressure = 190 si. WELC1 CIRC T Brine up to wgt, 10.2#. Initial pressures IA=210 psi, tbg=O. Online circuating at 3.0 bpm, begin bleeding IA ressure off, maintainin 1:1 rtns. WELC1 CIRC T 10.2 brine circulated at the way around; continue circulating while discussing options wI WO Engineer. Note: loss rate @7 bph while circulating. Begin weighing up pit s stem to 10.5#. WELC1 OWFF T Circulate 10.5# brine around at 3.0 bpm (no losslgain during circulation). Shut down and monitor; well dead. Open bag and monitor fluid level; static at flowline. WELC1 WOEQ P Well dead/static; waiting on ESP cable s ooler. RPCOI\ WOEQ NP Spooler arrived on location. Begin to RU. RPCOI\ WOEQ NP Finish rigging up spooler. 6.00 2.00 3.50 0.50 1.00 1.00 3.50 2.00 2.50 6.00 2.00 2.00 1.00 RPCOI\ CIRC P Circulate bottoms up of 10.5# brine from 4300' md. Pressure = 260 psi, rate = 3 bpm, no losses or gains. Shut down pump and monitor well. Well is dead/static. P Pull 2-718" tubing and ESP cable. Displacement of tubing and cable is approx 1.35 bbl/10 jts. Losing approx 1.5 bbls/10 'ts ulled. P Crew changout. 230 jts out of hole. Well a ears stable, sli ht losses. 5.00 RPCOI\ PULD 3.00 RPCOI\ PULD 09/29/2006 09:00 10:00 1.00 RPCO~ PULD P All of the completion out of the hole. Clean cut on joint of pipe that was chem-cut; cable broke approx 15' below cut depth. Took sample of scale and what appears to be dried mud caked sporatically on outside of tubing (sample taken to lab). Note: 140 of 142 LaSalle clam s recovered. 10:00 12:30 2.50 RPCO~ RURD P Begin picking up 3-1/2" pipe handling equipment. Rig down cable sheave. Clean u ri floor. 12:30 13:30 1.00 RPCO~ SFEQ P Set test plug and tesUchart annular reventer to 250/2500 si 13:30 18:00 4.50 FISH PULD P Make up fishing BHA=5-3/4 overshoUbumper sub/jar/POS/(6) 6" drill collars/intensifier/x-over & begin runnin in hole on PH-6 workstrin . 18:00 00:00 6.00 FISH TRIP P TIH with fishing BHA and 3-1/2" PH-6 Workstrin . 09/30/2006 00:00 06:00 6.00 FISH TRIP P TIH with fishing BHA and 3-1/2" PH-6 workstring to 8400' md. Latch up to tbg stub at 8552', a rox. 15' in on 't 267. 06:00 10:00 4.00 FISH CIRC P Circulate surface to surface at 4.0 bpm to get consistent brine wgt throughout s stem, waterin back to 10.3#. 10:00 12:30 2.50 FISH JAR P Attempt to pull pump free with existing lifting equipment. No luck, beat down, no movement. Swap elevators. RIW=46k, PUW=100k; begin trying to free pump woirkin up licks from 20k over to 50k over. Approx 13 licks, um free however still stick . 12:30 14:00 1.50 FISH CIRC P Fill hole across top; 8 bbls to fill. Make up headpin and begin circualting at 3.0 b m. Pum bottoms u ,workin i e. 14:00 18:00 4.00 FISH TRIP P Begin pulling out of hole with workstring/ESP completion. Pulling wet; drop balllrod and open circ-sub. Continue out of hole. 18:00 18:00 0.00 FISH TRIP P Crew change. 18:00 00:00 6.00 FISH TRIP P Continue to TOH with fishing string, standin back PH-6 workstrin . 00:00 00:00 0.00 FISH TRIP P Drill Collars at rig floor. Begin to break down fishin BHA. 10101/200600:00 04:00 4.00 FISH PULD P Lay down fishing BHA, ESP pump and motor. Recover one LaSalle clamp. All parts of ESP appear to be at surface except for 1 missing LaSalle clamp recognized as missing when ullin tubin . 04:00 06:30 2.50 RPCO~ RURD P Make up BHA=5-3/4 rev-circ junk baskeUboot baskets/casing scraperlbumper sub/jars/(6) drill collars on PH-6 workstrin . 10101/200606:30 17:00 10.50 RPCO~ TRIP P Begin running in hole wI cleanout BHA on PH-6 workstrin . 17:00 17:00 0.00 RPCO~ FCO P Tag up at 9015' md. 17:00 00:00 7.00 RPCO~ RURD P Drill mouse hole. Pick up Kelly and Test. 10102/2006 00:00 01:30 1.50 RPCO~ FCO P Test Kelly. Start picking up PH-6 jts and TIH while pumping 3.4 bpm. Circulating pressure = 550 psi. Up wt 105K, down wt 60K. 01:30 03:00 1.50 RPCO~ FCO P Gas breaking out of fluid at surface. Pump bottoms up of 10.3# brine and monitor hole. 03:00 06:00 3.00 RPCO~ FCO P Continue to TIH for clean out. Tag on jt 286, pick up and start rotating with Kelly. Pull joint 286, make up 17.66' pup and work down with kelly. Torq'ing up, unable to make hole. Work pipe to keep casing scraper from siting in one s ot too Ion . 06:00 08:00 2.00 RPCO~ FCO P Changeout. Sill torq'ing up, unable to make hole. Pick up off fill and circulate hi h-visc swee around. 08:00 10:30 2.50 RPCO~ FCO P Drop 17' pup jt and replace wI full jt. Wash/rotate down 20' up on Kelly (jt 286 in the hole) to 9178' corrected RKB. Hard tag, unable to make hole. Drop ball for rev-circulating junk basket. Be in circulatin to bottom. 10:30 12:30 2.00 RPCO~ OWFF P See 2 bbl pit gain, pull kelly bushing to get visual, substantial gas breaking out. Close annular preventer and line up through choke line. Begin monitoring. Initial csg=50, tbg=10. Notify State rep (John Spaulding) of shut in. 12:30 15:00 2.50 RPCO~ OWFF P Casing pressure =170, tbg remaining at 10 psi. Are weighing up pit system u to 10.5#. 15:00 23:30 8.50 RPCO~ CIRC P Circulate 10.5# brine at 3 bpm. Avera e losses of 20 bbls/hr. 23:30 00:00 0.50 RPCO~ Getting 10.5# brine back to pits. Shut down pump to monitor pressure. No pressure increase for 30 minutes. Open Annular preventer and monitor well. 10103/200600:00 00:30 0.50 RPCO~ FCO Open annular preventer to monitor well. Fluid level dropping, decide to try and rotate with Kelly and continue clean out. Tagging up approx 5' higher than revious ta at 9173' rkb. 00:30 03:00 2.50 WELCT CIRC Take 1 bbl kick and close in annular preventer. Start circulating with 10.5# blended with10.6# through choke. Pump rate = 4 bpm @ 730 psi. Losing 30 bbl/hr. 10103/2006 03:00 04:00 1.00 RPCOII. OWFF Shut in well and monitor hole. Fluid level drODDinQ. 04:00 04:30 0.50 9,175 RPCOII. FCO Start rotating with Kelly and continue FCO. Clean out to 9175' (3' from original depth) but not making any more hole. 04:30 07:00 2.50 RPCOII. CIRC Circulate hole around to 10.7# brine. 07:00 16:00 9.00 9,175 RPCOII. TRIP TOH standing back workstring. Losing 18 bblslhr 16:00 18:00 2.00 0 0 RPCOII. TRIP Lay down Baker BHA. Junk basket full of solids (formation & frac sand). Did not recover any metal inside reverse junk basket. Minimal signs of metal wear on outside of iunk basket. 18:00 00:00 6.00 0 0 WELCT BOPE Weekly test of BOP's. (State witnessed by Jeff Jones). Keep hole full during BOP test. 10104/2006 00:00 02:00 2.00 0 WELCT BOPE Finish testing BOP's and begin to test Kelly. 02:00 12:00 10.00 WELCT KLWL Take 2 bbl kick. Shut in Blind Rams. Monitor pressures. SICP = 120 Dsi 12:00 18:00 6.00 WELCT KLWL Attempt to kill well by bullheading 11.3# brine down casing. Pump 350 bbls 11.3# brine at 2 bpm, final pump pressure of 570 psi. 18:00 19:00 1.00 WELCT KLWL Shut down pumps and monitor pressure. Initial shut in pressure = 410 psi. 19:00 19:00 0.00 WELCT KLWL Spoke with Chuck Scheve with AOGCC to waive testing of Blinds until after we have set the packer with a plug in the TT to isolate the A and C sands. 19:00 21:30 2.50 WELCT KLWL Monitoring pressure. Casing pressure dropped to 100 psi after 2.5 hrs. 21:30 22:00 0.50 WELCT KLWL Pressure stabalized out at 100 psi. Crack choke with 100 psi. Small amount of gas on surface, then brine back to pits. Shut well in with 70 psi, beQin to monitor again. 22:00 00:00 2.00 WELCT Monitor Pressures. Pressure has increased to 150 psi. 10105/2006 00:00 02:00 2.00 WELCT KLWL Monitor Casing pressures. Pressure = 170 psi. 02:00 03:30 1.50 WELCT KLWL Begin to Lubricate and bleed. Pump 1 bbI11.2# brine and bleed no more than 1 bbl back to pit. Continue until only gas is at surface and pressure bleeds to 0 DSi. 03:30 04:00 0.50 WELCT KLWL Monitor well for no flow. Open Blinds and monitor fluid in well. Gas breaking out at surface, but fluid level drODDina. 04:00 09:00 5.00 RPCOII. RURD Rig up shooting flange for wireline operations. Currently losing 16 bblslhr . keeDinQ hole full. 10105/2006 09:00 12:00 3.00 RPCOI\. PACK RU Schlumberger Wireline 12:00 16:00 4.00 RPCOI\. PACK Tag bottom with junk basket at 9150' ELM. Well still losing between 16-20 bbls/hr. 16:00 22:00 6.00 RPCOI\. PACK Set Baker Model F packer at 9088.4' mid element (top of packer = 9086.3'). Bottom of tubin tail is at 9128' ELM. 22:00 00:00 2.00 RPCOI\. SLKL RU equipment to run PDS memory cali er on Schlumber er Wireline. 10106/2006 00:00 04:30 4.50 COMPZ RPCOI\. SLKL P Run PDS memory caliper log on Schlumber er Wireline 04:30 05:30 1.00 P LD PDS tools & E-line tools. RD SWS. 05:30 06:30 1.00 RPCOI\. NUND P ND shooting flange. NU flow nipple. 06:30 08:00 1.50 P Pull wear bushing. Set test plug. Re-test blind rams to 250 psi & 3500 psi. Advised Chuck Scheve, AOGCC Field Ins ector of re-test. 08:00 09:00 1.00 P Pull test plug. Fill hole circulating across the top in riser. Set wear bushing. Blow down lines. RD fill-up hose from IA. 09:00 12:00 3.00 RPCOI\. OTHR P Break out & LD bumper sub & oil jars. LD drill collars. Clean ri floor. 12:00 18:00 6.00 RPCOI\. OTHR P Continue cleaning up rig floor. Clear ice buildup from derrick. Load completion equipment into pipe shed. Waiting for Baker "Premier" Packer assembly to be assembled and delivered to ri , 18:00 21:00 3.00 RPCOI\. OTHR MU blast rings on IBT tubing. Baker Premier Packer arrived on location. 21:00 00:00 3.00 RPCOI\. RCST Run in hole with bottom section of completion equipment on PH-6 workstring. Bottom section of completion string includes seals, sliding sleeve, blast rings, GLM, x-ni Ie, remier acker, FHL acker. 10107/200600:00 10:00 10.00 COMPZ RPCOI\. RCST P TIH with bottom section of completion on PH-6 workstring, 134 stands plus Baker PBR/FHL Packer + 15 jts 3-1/2" tubing + Baker Premier Packer + 1 Jt Tbg + 2.813" X-Nipple Assy + MMG GLM (dummy valve) Assy + 1 Jt Tbg + 1 Jt IBT Tbg wI 26' of Carbide Blast Rings + 1 Jt IBT Tbg + Baker CMU Sliding Sleeve Assy + LocatorlSeal Ass. PU pup joint of PH-6. Stab into seal bore on 'F-1' Packer (Set on E-Line @ 9086' ELM) and land locator sub. Unsting and circulate at 1 BPM, 70 psi - Sting in and saw pressure rise when seals entered bore, shut off pump and held 600 psi. Bled off and relanded to verify position. Top of 'F-1' Packer at 9096' MD (Nabors 3S RT). 92K# PU, 49K# SO, 10K# Blocks. 11:00 12:00 1.00 COMPZ RPCOtl. CIRC P Circulate 2 BPM, 230 psi. Pump 33 Bbls of 11.2 ppg Brine with 1 % CRW-132 Corrosion Inhibitor, chase with 63 Bbls brine, putting 28 Bbls of inhibited brine in annulus, leaving 5 Bbls in tubing. Stab seals back into 'F-1' Packer and hold 0.50' up from full landed osition. 12:00 13:30 1.50 COMPZ RPCOtl. PACK P Pressure up to 2500 psi and hold 5 minutes, saw FHL setting shear at 2000 psi. Continue pressure up to 4500 psi to set Premier Packer, hold 3 minutes. Bleed pressure down to 2000 psi, PU & sheared Seals from PBR, PU 3' to assure pins sheared, OK. Bleed off pressure, slack off and tag PBR. Test tubing to 2500 psi for 5 minutes, OK. Bleed off tubing. Close bag & test annulus & packer to 2040 psi for 15 minutes, no loss, good test. Bleed off pressure. Open bag. PU and pull seals out of PBR, 85K# PU wt. LD pup joint. Prepare to POH LD 3-1/2" work strin . 13:30 00:00 10.50 COMPZ P TOH laying down PH-6 workstring 10108/2006 00:00 07:30 7.50 COMPZ P TOH laying down PH-6 workstring. Inspect seal assembly, like new condition. Break 6' pup on top of seal ass . bent, to be re laced. 07:30 10:30 3.00 COMPZ RPCOtl. OTHR P Clear & clean up rig floor. RU to run completion. Clear last of work string out of pipe shed. Load 53 joints of tubing and completion jewelry into pipe shed. 10:30 11:30 1.00 COMPZ P PU locatorlseal assembly. MU new 6' u on same. 11:30 20:00 8.50 COMPZ P Run 3-1/2" completioon string. (Joints #18 thru #92, & 3 GLM's in hole at 1700 hours). Having to run completion slow due to extreme high winds blowin blocks. 20:00 00:00 4.00 RPCOtl. WOW Shut down an wait for wind to subside. Wind gusting to 60 mph, causing blocks to swin and derrick to twist. 22:00 00:00 2.00 COMPZ RPCO~ RCST 10/10/200600:00 04:00 4.00 RPCO~ RCST 04:00 05:00 1.00 RPCO~ RCST 05:00 10:00 5.00 RPCO~ RCST 10:00 13:30 3.50 RPCO~ RCST NP Shut down due to extreme high winds. Blocks swinging in derrick. LocatorlSeal Assembly + 3 GLM's + Joints #18 thru #101 in hole, muleshoe depth -2709'. (Jts #1 thru #17 already set with isolation and production packer assemblies.) Crews working on ri while WOw. Winds beginning to subside. Resume runnin 3-1/2" com letion. P Running 3-1/2" completion, Jts #120 thru #218. P RU Camco Spooler to run control line from SSSV to surface. MU Camco SSSV Assembly. MU control line to SSSV, test line & hold 5000 psi on line while runnin rest of com letion. P Continue to run 3-1/2" completion with control line. Stab seals into PBR and land Locator on landing shoulder, top of PBR at 8390' MD (Nabors 3S RT), seals full in PBR. P MU head pin & hose. Pressure up on tubing to 500 psi to verify seals stabbed-in, OK. PU and saw pressure drop when last seal cleared PBR, verified position. Re-check RT to LDS height. Swap out 31' joint for 29' joint to get proper space out (no pups required). MU FMC tubing hanger. MU control line to hanger and to hanger neck, repressure line to 5000 psi to hold SSSV open to stab in seals and land hanger. Land FMC hanger. RILDS. 62K# PU, 42K# SO, 10K# Block Wt.. Spaced out 2' up from fully landed position in PBR. Ran 264 joints (Jts #18 thru #281) 3-1/2", 9.3#, L-80, EUE-Mod Tubing; 4 MMG GLM's, TRMAXX-5E SSSV, and Baker LocatorlSeal Assembly. Ran SS control line from SSSV to surface, secured with 67 SS bands. 10/10/2006 13:30 17:30 4.00 RPCOI\ DHEQ P RU line to lA, test line to 3000 psi. Test tubing to 2500 psi for 30 minutes, no return from annulus, good test, (lost 75 psi, mud manifold valve leaking slightly). Test IA to 2000 psi, holding 1400 psi on tubing, for 30 minutes, lost 20 psi, good test. Hold 2000 psi on lA, bleed down tubing and sheared open DCR-1 valve in GLM @ -8332' MD (1 joint above PBR seal assembly.) Bleed off all pressure. RU reversing line and reverse circulate 5 Bbls at 1 BPM, 70 psi and verify DCR-1 is open. Bleed off control line and close SSSV. Pressure up on IA thru GLM and below SSSV flapper to 1040 psi, hold 15 minutes for SSSV test, lost 20 psi, good test, no returns from tubing above SSSV. Bleed off test, repressure control line and open SSSV. Reverse circulate briefly to veri SSSV 0 ened, OK. 17:30 18:30 1.00 RPCOI\ RURD P Drain lines and blowdown. Close SSSV. Back out and LDLJ. Drain stack. Set BPV. 18:30 19:30 1.00 RPCOI\ RURD P Lay down SWS spooling unit. Set BPV. 19:30 23:00 3.50 RPCOI\ NUND P NDBOP 23:00 00:00 1.00 RPCOI\ NUND P NU adapter flange/tree. Vac pits. 10/11/2006 00:00 03:30 3.50 P Finish NU tree. Test void and tree to 5000 psi. Pressure up control line and reopen SCSSV. Pull test plug. Lay down kelly equipment. Rig up lines to circulate out 11.2 kwf. 03:30 04:00 0.50 P Hold PJSM 04:00 08:30 4.50 P Start reverse circulating out 11.2 ppg kwf to pits with 8.6 ppg seawater. Reverse circulated 400 Bbls of 8.5 ppg SeaWater, with clean SW returns, 2 BPM, 180 psi final circulating pressure, 850 psi maximum when SW rounded bottom. Recovered 400 Bbls of 11.2 ppg brine from well and pits, sent to storage at KCS tank farm for use on next well. (Note: 270 Bbls of newlclean 11.2 ppg lo-temp brine, -23 de F, stored at MI Mud Plant. 12:00 13:00 1.00 COMPZ RPCOII. RURD Rig up LRS to freeze protect well. Test lines. PJSM. Reverse circulate 93 Bbls of diesel into lA, taking SW returns from tubing thru open choke to outside tank. 2 BPM, 50 psi ICP, 300 psi FCP. Connect annulus to tubing and allow diesel to U-Tube until equalized for freeze protection to 2650' MD (2179' TVD). Break down and lay down Kelly while U-tubing diesel. Shut in tubing & annulus. Break out and clean out circulating lines, blowdown lines to its. Start cleanin its. P Close SSSV. Set BPV. Secure well. Finish RD circulating lines. Clean pits. Clear and clean up cellar area. Release Ri 1300 hrs, 10/11/06. RE: Modified Completion Design for 3A-OI e e Tom - The portion of the casing that was opposite gas lift gas was in excellent condition. The portion at the interface of gas lift gas and produced fluids was in worse condition. The portion of the casing that was in the worst condition, the portion that we isolated, was opposite the dead ESP. It was line corrosion but it was not apparently on the low side or the high side of the hole. Immediately below the old ESP the casing was in pretty good shape. Thanks for the reply. -Gary -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, October 10, 20067:48 AM To: Eller, J Gary WI:;: "'('\-1 ~{î ÎOQ1=¡ Subject: Re: Modified Completion Design for 3A-01 ~Ç^N,,~¿X) I,)'í,,< l' " ¿ _v y Gary, Sorry I didn't get back sooner. Packers are an effective way to isolate problems such as this. Any speculation as to why only this area of the casing was so bad? T om Maunder, PE AOGCC Eller, J Gary wrote, On 10/6/2006 1 :27 PM: Tom - As I explained in the message I left on your phone, we're looking at installing a modified completion design on well 3A-01. We will set a second packer at ±8400' MD as compared to the original recommendation. The 7" casing between the packers at 8400' and 8900' MD has some areas that are significantly corroded with the top of cement being at approximately 8900' MD. The packers will isolate the worst of the corroded 7" casing, and we'll spot corrosion inhibitor there to prevent further degradation. Please call me it you have any questions. «3A-01 proposed schematic. pdt» J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 1 of I 10/1 0/2006 8:08 AM eonocóPhillips API: 50-029-21412 AOGCC: 185-186 Lift thds: 3Yz" 8rd BPV: FMC ISA Wellhead: FMC Gen-IV Proposed Completion · Tubing = 3W', 9.3 ppf, L-80, EUE 8rd Mod · Cameo TRMAXX-5E SCSSV at 2000' wi 2.813" X-profile · Baker FHL packer at 8400' · Baker Premier packer at 8900' · X-nipple at 8949' ID = 2.813" · Gas lift mandrel at 8964' · Carbide blast rings on 3~", 9.2 ppf, L-80, IBT-Mod 9015' - 9041' (26') · Baker CMU sliding sleeve at 9075' wi 2.813" X-profile · Baker F perm packer at 9087' · Camco D nipple at 9122' ID = 2.75" · Re-entry guide at 9128' Directional: Max hole angle: 560 at 2300' Angle at top perf: 460 at 9020' Max doglegs: 4.10/100' at 700' e PROPOSED x Tag = 9332' (8/2/98) TD = 9600' e Well: 3A-01 Field: Kuparuk \ ~'5~ \ ~.l::, Conductor: 16",62.58 ppf, H-40 at 104' Surface Casinq: 9%",36 ppf, J-55 at 4353' Corroded 7" casing detected via caliper on 10/6/06, ±8450'-8800' Gas Lift Mandrels MD 3628' 5970' 7309' 8227' 8859' TVD 2750' 4100' 4900' 5425' 5815' Type MMG-dummy MMG-dummy MMG-dummy MMG-DCK MMG DCK C-Sand Selective 8964' 5889' MMG-dummy Perfs C-1: 9020' - 9036 (12 spf, 11/85) A-3: 9165' - 9195' (4 spf, 11/85) A-2: 9210' - 9260' (4 spf, 11/85) Surface CasinQ: 7",26 ppf, J-55 at 9575' Last Updated: 6-0ct-06 Updated by: JGE . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 6 - \ ~ft, \Cö RE: Cased Hole/Open Hole/Mechanical Logs and/orTubinglnspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowtedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 3A - 01 Caliper Report 5-Dct-06 1) 2J 3) 4) 5) 6) 7) SCANNED Print Name: i)' l r 'I I,! í¡ " i·t~ l /_./ j /1 ¡ . II I 'II ., ;,'V'./¡·fc." !j(;\íl3h i /l it I· I I 'Iv l/l vL!, ~~ ,'-- Signed: PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~ '....;: _ _~_', -;. . '.' - . __ . _ -,_ .~- ._,.....;J h~.. ._~<--_. . -,',"-, '-.,. -' . WEBSITE :j·'¡:/',j":Ö;·')",C. ~ 3, ::;:.'.'; D-"OO. PDSA:-JC·2006\Z_ Word\DistributIoll\Transmittal_ SheetsìTratlsrmt_ Origmal,doc I I I I I I I I I I I I I I I I I I - . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 5, 2006 7610 1 7" 26 lb. J-55 Casing Well: 3A-01 Field: Kuparuk State: Alaska API No.: 50-029-21412-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 9,073 Ft. (MD) Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of the C-1 Zone Perforation Interval @ 9,020' Depth. This log was run to assess the condition of the 7" casing with respect to corrosive and mechanical damages. The caliper recordings indicate the 7" casing is in good to poor condition, with a recorded maximum wall penetration of 82% in joint 208 (8,644'). Wall penetrations in excess of 20% are recorded in 36 of the 218 joints logged. The damage appears in the forms of lines of corrosion, isolated pitting, and an area of general corrosion. The deeper penetrations are recorded in the interval between 6,050' and 9,073', as illustrated in the Body Region Analysis Page of this report. A bend is recorded in the perforation interval, with a recorded minimum I.D. of 5.98" at 9,034'. Light deposits are recorded below 7,500', with a recorded minimum I.D. of 6.0" at 8,591'. No significant areas of cross-sectional wall loss are recorded in the 7" casing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WAll PENETRA 110NS: Perforation Interval ( 97%) Jt. 217 @ 9,032 Ft. (MD) Line Corrosion ( 82%) Jt. 208 @ 8,644 Ft. (MD) Line Corrosion ( 65%) Jt. 206 @ 8,547 Ft. (MD) Line Corrosion ( 65%) Jt. 209 @ 8,668 Ft. (MD) Line Corrosion ( 61%) Jt. 205 @ 8,499 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 18%) are recorded in the casing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Bend in Perfs. Light Deposits Light Deposits Light Deposits Light Deposits Minimum I.D. = 5.98" Minimum I.D. = 6.01" Minimum 1.0. = 6.04" Minimum I.D. = 6.05" Minimum I.D. = 6.06" @ @ @ @ @ 9,034 Ft. (MD) 8,591 Ft. (MD) 8,670 Ft. (MD) 8,767 Ft. (MD 8,814 Ft. (MD Jt. Jt. Jt. Jt. Jt. 217 207 209 211 212 Field Engineer: J. Ha/vorsen M. T ahtouh Witness: B. Gathman coRE o 77497 f:ax: 659-23.14 OCT 1 0 2006 1'75f)- ("6~ 1=1. ILl rl;:). .o\1aSka Oil & Gas ConS. commission Anchorage I I I Well: Field: Company: Country: 3A-01 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 7ins Weight 26 f Grade & Thread -55 I I Penetration and Metal Loss ('Yo wall) penetration body metal loss body 150 I 100 I 50 o o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85<}'o I 1 o I pene, loss I Damage Configuration ( body ) 40 20 I 30 I 10 o I isolated pitting general line ring hole / poss corrosion corrosion corrosion ib!e hole I I I DS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: Nom.ID 6,276 ins October 5, 2006 MFC 40 No. 99494 2.75 40 M. Tahtouh Nom. Upset 7ins Upper len, 1.2 ins Lower len. 1.2 ins Damage Profile ('Yo wall) penetration body o 1 !ij))))d!I metal loss body 50 100 201 51 101 151 Bottom of Survey = 218 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 7. in (8.9' - 9049.0') Well: Field: Company: Country: Survey Date: 3A-Ol Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Approx. Tool Deviation Approx. Borehole Profile 75 25 50 9 961 1958 2946 100 4008 0 ~ ::E (J) ..Q '-' E L.L ::J C z 125 5091 ..;:: E ã. 'õ (J) 0 150 6133 175 200 218 o 50 Damage Profile ('Yo wall) / Tool Deviation (degrees) Bottom of Survey = 218 I I - 7190 8275 9049 100 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal J.D.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3A-Ol Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Joint Jt. Depth Pen. Pen. Perl, . ,\/¡elal Min. Damage Profile No. (Ft.) 'i Body J.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 1 9 ( 0.02 I 6.25 2 44 I) 0.ü1 I 6.24 3 90 0 0.ü1 ! 6.22 4 136 0 0.01 2 6.24 5 173 U 0.01 3 6.25 6 214 U 0.01 3 6.23 7 253 0 0.01 4 6.24 8 294 0 0.03 i 6.24 9 334 0 0.00 ¡ 2 6.25 10 372 ( 0.01 4 I' 6.25 , 11 411 0 0.01 4 'I 6.25 12 451 ( 0.01 'j 6.24 13 490 ( 0.02 .2 6.24 14 529 ( 0.01 1 6.25 15 566 U 0.01 ! 6.24 16 605 () 0.01 2 6.25 17 643 U 0.01 2 6.23 18 686 0 0.01 ! 6.24 19 726 0 0.01 3 .2 6.24 20 765 0 0.01 2 .2 6.24 21 805 0 0.01 .2 6.25 22 842 () 0.01 .2 6.24 23 882 0.01 ! 6.24 24 921 0.02 ( I 6.24 25 961 ( 0.01 'I 6.24 26 1000 0 0.ü1 3 I 6.24 , 27 1040 ( 0.01 ! 6.24 28 1077 0 0.02 'j 6.24 ~ 29 1117 () 0.01 ! 6.25 I 30 1157 0 0.02 ( 2 6.23 31 1198 0 0.02 .2 6.24 32 1239 ( 0.02 6 'J 6.23 33 1278 ( 0.01 4 I 6.24 34 1318 0.01 3 ¡ 6.25 35 1357 ( 0.03 ¡ .2 6.24 Shallow pittinQ. 36 1396 0 0.01 6.24 37 1437 0 0.01 2 6.24 38 1476 ( 0.01 I 6.24 39 1516 () 0.01 .2 6.24 40 1557 () 0.01 " I 6.24 41 1596 () 0.02 I 6.24 42 1636 () 0.03 1 6.25 43 1677 () 0.01 ! 6.24 44 1717 () 0.01 I 1 6.24 45 1758 () 0.01 .2 6.24 Lt. Deoosits. 46 1799 () 0.01 I 6.24 i 47 1838 0 0.01 .2 'I 6.24 48 1877 0 0.02 '5 2 6.23 ~ 49 1919 () 0.01 J .2 6.24 50 1958 0 0.ü1 ¡ ¡ 6.24 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: NominaII.D.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3A-Ol Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Joint )1. Depth Pei) Pen. Pen. ! ¡''/1ce11 Min. Damage Profile No. (Ft.) Body J.D. Comments (%wall) ( ) (Ins.) (Ins.) 0 50 100 51 1998 ( 0.01 3 1 6.24 52 2037 0.01 4 1 6.24 53 2077 D 0.02 .5 1 6.24 54 2114 LL 0.01 2 .2 6.25 55 2154 LL 0.03 7 1 6.25 Ii! 56 2193 LL O.DO 1 1 6.25 57 2233 (I D.Ol 1 6.25 58 2272 (I 0.01 '1 6.25 59 2312 0 om 1 6.26 60 2352 I D.Ol 1 6.25 61 2392 {J 0.02 4 J 6.24 62 2431 1 0.01 4 2 6.20 63 2475 L om .3 ¡ 6.25 64 2515 1 0.01 2 6.24 65 2554 ( om 1 6.24 66 2593 1 0.01 I 6.24 67 2633 0 om ¡ 2 6.24 68 2673 (I 0.01 1 1 6.24 69 2713 () 0.02 _6 1 6.24 70 2752 Q 0.01 J 6.23 71 2792 LL 0.01 2 6.24 72 2831 -º-- 0.02 2 6.24 73 2868 C 0.01 I 6.25 74 2905 (I 0.02 2 6.24 75 2946 _0 0.01 1 ! 6.23 76 2987 0.01 3 I 6.24 77 3026 0.01 .2 ¡ 6.24 78 3065 _.!l 0.01 1 ~ 6.25 79 3104 0 0.01 3 ¡ 6.23 80 3144 0 0.00 1 1 6.22 81 3187 0 om 3 1 6.19 U. Deposi Is. 82 3230 (I 0.01 2 2 6.18 83 3273 J1 0.01 I 6.22 84 3316 .LL 0.01 1 6.23 85 3357 0.01 1 6.23 86 3400 Jl 0.02 ì 6.23 87 3444 (I 0.02 1 6.22 88 3487 (I 0.01 1 6.23 89 3531 (I 0.01 1 6.22 90 3574 (I 0.01 3 1 6.23 91 3617 J1 0.01 4 _I 6.23 92 3661 0.01 -' J 6.23 93 3704 0.01 1 6.23 94 3747 J 0.01 1 6.21 95 3791 ( 0.01 I 6.21 96 3834 0 0.01 2 6.21 97 3878 LL 0.01 1 6.21 98 3922 lei 0.01 1 6.22 99 3965 Jl 0.01 I 6.22 100 4008 0 0.01 1 6.22 Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3A-Ol Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Joint Jt. Depth h'n Pen. Pen. ,À. ,( Min. Damage Profile No. (ft.) ,( Body 1.0. Comments (%wall) ( ! (ins.) (ins.) 0 50 100 101 4052 ( 0.01 ! 6.21 102 4096 (J 0.02 ~j 6.22 103 4139 0 0.01 1 6.23 104 4183 0 0.01 I 6.22 105 4226 0 0.01 I 6.24 106 4270 0 0.01 ( 6.22 107 4314 JJ 0.01 1 6.24 , 108 4354 J 0.03 1 6.23 !ITI 109 4395 ( 0.01 3 I 6.24 110 4439 J 0.01 6.23 111 4482 0 0.01 I 6.22 112 4525 U 0.01 I 6.22 113 4569 U 0.01 2 6.21 114 4612 0 0.01 2 6.20 115 4656 .0 0.01 2 6.21 116 4699 JJ 0.01 6.19 117 4743 0 0.01 2 6.19 118 4786 0 0.01 6.19 119 4830 0 OJ)] 6.19 120 4873 0 0.01 2 6.20 121 4917 0 0.01 I 6.21 122 4960 [) 0.01 2 , 6.19 123 5004 ( 0.01 3 I 6.21 124 5047 ( 0.02 U ¡ 6.20 ¡ 125 5091 ( 0.07 19 2 6.20 Shallow oitting. 126 5134 0 0.01 ; 6.22 127 5178 U 0.01 ;; 6.21 128 5221 0 0.01 ;; 6.22 129 5265 0.02 6.22 130 5308 ( 0.01 3 6.21 131 5352 ( 0.02 4 6.16 132 5395 ( 0.01 4 6.19 133 5439 0 0.00 6.18 134 5482 0 0.01 I 6.20 135 5519 0 0.01 2 6.21 136 5557 0 0.02 2 6.19 137 5600 j) 0.01 4 6.13 138 5644 0.02 ] 6.15 139 5687 ( 0.01 3 ( 6.06 Bend middle body (Kick Off Point ). 140 5730 ( 0.05 13 6.15 Shallow pitting. Lt. Deposits. 141 5773 ( 0.01 4 6.14 142 5817 0 0.01 ;; 6.15 '* 143 5860 0 0.06 .1.5 ;; 6.21 Shallow.PittiUg. 144 5899 0 0.07 Jß 3 6.20 ShallowQittilJ&, 145 5935 U 0.06 ìÏ I 6.21 Shallow pitting. 146 5976 () 0.11 0 ) 6.19 Line corrosion. 147 601 7 0 0.11 0 2 6.19 Line corrosion. 148 6054 0 0.15 2 6.19 Line corrosion. 149 6093 J) 0.03 1 6.20 Shallow Ditting. 150 6133 0 0.D3 -'.J 2 6.19 Shallow!Jitting. Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominall.D.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3A-Ol Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Joint )t Depth Pel! Pen. Pen. I !vietal Min. Damage Profile No. (Ft) Body I ID. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 151 6177 0.06 0.16 4 6.20 Line corrosion. I 152 6217 0 0.18 Ii 6.20 Line corrosion. 153 6257 It 0.03 6.18 Shallow.l2i tti!}g. 154 6300 0 0.14 ) 6.19 Line corrosion. 155 6342 -.i 0.03 ( ...£ 6.21 ShallowJ2itting. 156 6384 -.i 0.19 tl¿ --'1 6.15 Line corrosion. 157 6424 J 0.20 54 3 6.19 Line corrosion. 158 6463 -.i 0.04 12 2 6.19 Line shallow corrosion. 159 6507 0 0.04 12 2 6.20 Shallowpittiog. 160 6550 0 0.04 11 1 6.17 Shallow pi tti r¡g. 161 6591 0 0.06 lJL ( 6.19 Shallow_pi tti r¡g. ¡ 162 6635 0 0.04 II 1 6.20 Shallow-Ri tti I}g, 163 6678 _(1 0.11 3J --'1 6.20 Line corrosion. 164 6719 J) 0.04 JQ .£ 6.19 Shallow.12itting. 165 6763 J 0.06 17 1 6.18 Shallow pitting. 166 6806 J2J.2 0.20 55 1 6.19 Line corrosion. 167 6845 0 0.17 .46 4 6.17 Line corrosion. 168 6886 It 0.07 )L ...£ 6.19 IsolatedJ2ittiog, 169 6929 -D.. 0.16 '12. ...£ 6.18 Line corrosion. 170 6973 .Jl 0.03 Jl I 6.18 171 7016 Jl 0.05 15 ') 6.15 Shallow pitting. ) 172 7059 Jl 0.04 1 6.18 Shallow pitting. 173 7103 0 0.04 ¡ 6.18 Shallow.pittil]g. 174 7147 () 0.07 1 6.15 Shallowpi tti /]g. 175 7190 J) 0.04 6.16 Shallow..QÍ ttiog. 176 7234 J) 0.07 1 ...£ 6.17 ShalloW.1}i tti!}g. U. DE±19si ts. 177 7277 J2 0.03 --'1 6.10 178 7321 J) 0.04 JQ .£ 6.19 ShalloW.QÍtting. 179 7364 () 0.07 20 2 6.18 Isolated pitting. 180 7407 Jl 0.03 a 2 6.18 181 7451 0 0.06 I 4 6.15 Line shallow corrosion. Slight bend lower bodY, 182 7495 0 0.06 I 2 6.15 Shallowj)i tti ng. 183 7538 J 0.05 L' -D 6.15 ShalloW.1}i tti!}g, 184 7582 j 0.06 1 J.. 6.16 Shallow.12ittí!}g. 185 7625 j 0.11 .Jl 6.16 Isolated pitting. 186 7669 i 0.05 .Jl ...: 6.16 Shallow pitting. Lt Deposits. 187 7713 1 0.16 43 6.15 Line corrosion. It. D~posits. 188 7756 Jl 0.05 14 6.10 line shallow corrosion. Lt Deposits. 189 7799 0 0.07 1..9 6.15 Shallow.pittin~. Lt. Dt¿¡¿osits. 190 7843 0 0.09 212 6.17 line corrosion. 191 7886 j) 0.08 2J .Jl 6.17 Line corrosion. 192 7928 J) 0.15 .:1J .Jl 6.16 line corrosion. 193 7972 J. 0.15 ..:1I. 6.16 Line corrosion. L t. Deposi ts. 194 8015 ...l 0.09 25 6.17 Line corrosion. 195 8058 t 0.10 27 6.17 Line corrosion. 196 8102 0 0.17 46 6.16 line corrosion. 197 8145 _il 0.06 12 6.17 line shallow corrosion. 198 8188 Jl 0.11 .Jl1 6.l3 Line corrosion. It Deposits. 199 8232 Jl 0.10 27 6.12 Line corrosion. Lt. D~pOsits. 200 8275 0 0.09 24 6.14 Line corrosion. Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I r-- PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3A-01 Kuparuk ConocoPhillips Alaska, Inc. USA October 5, 2006 Joint Jr. Depth Pel' Pen. PelL r i\1elal Min. Damage Profile No. (Ft.) Body I 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 201 8319 0 0.07 6.15 Line shallow pitting. 202 8360 0 0.09 6.13 Line of pits. Lt. Deposits. 203 8404 Q()5 0.12 6.15 Line of pits. Lt. Deposits. 204 8447 OJ)(¡ 0.11 6.14 Line o(pits. 205 8491 Ji 0.22 6.08 Line corrosion. Lt. DEôposits. 206 8534 JlD5 0.23 6.06 Line corrosion. Lt. Deposits. 207 8578 Jl 0.07 ..le î 6.01 Line corrosion. Lt. Df:illQsits. 208 8617 Jl 0.30 Jl 6.08 line corrosion. L t. Df:illosi ts. 209 8661 0 0.23 6S 6.04 Line corrosion. Lt. DepOsits. 210 8704 0 0.06 I 6.07 Shallow pitting. U. Deposits. 211 8747 J) 0.04 J 6.05 ShallowpittiOg. Lt. Df:illosits. 212 8789 Jl 0.06 J 6.06 Line shallow corrosion. Lt. DE:posits. 213 8833 Jl 0.04 ì -L 6.07 Line shallow corrosion. Lt. D~osits. 214 8877 Jl 0.08 ..lei --'c 6.12 Line corrosion. Lt. Df:illQsits. 215 8920 0 0.07 19 6.06 Line shallow corrosion. Lt. Deposits. 216 8963 0 0.17 46 ii 6.14 Isolated pitting. 217 9007 0 0.35 97 113 5.98 Perforation Interval. Slight Bend in perfs. J 218 9049 0 0.09 2S IJ 6.18 Corrosion. Body Metal Loss Body Page 5 - - -- - - ------- - - -- - .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 3A-01 Kuparuk Conocophillips Alaska, Inc. USA 7 ins 26 f J-55 Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: October 5, 2006 MFC 40 No. 99494 :1.75 40 M Tahtouh Cross Section for Joint 208 at depth 8643.87 ft Tool speed = 68 Nominal 10 = 6.276 Nominal 00 = 7,000 Remaining wall area = 96 % Tool deviation = 570 Finger 15 Penetration = 0.296 ins Line Corrosion 0.30 ins = 82% Penetration HIGH SIDE = UP Cross Sections page 1 ------ Well: Field: Company: Country: Tubin : - - ----- 3A-01 Kuparuk ConocoPhillips Alaska, Inc. USA 7 ins 26 )f J-55 Cross Section for Joint 209 at depth 8668.29 ft Tool speed = 72 Nominal 10 = 6276 Nominal 00 = 7.000 Remaining wall area = 97 % Tool deviation = 56 0 - - -.. - .. PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: October 5, 2006 MFC 40 No. 99494 2.75 40 M. Tahtouh Finger 26 Penetration = 0.234 ins Line Corrosion 0.23 ins = 65% Penetration HIGH SIDE = UP Cross Sections page 2 .. .. - .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. 3A-01 Kuparuk Conocophillips Alaska, Inc. USA 7 ins 26 f -55 Cross Section for Joint 206 at depth 8546.63 ft Tool speed = 60 Nominal 10 = 6276 Nominal 00 = 7.000 Remaining wall area 95 % Tool deviation 570 .. .. .. .. .. .. PDS Report Cross Sections SUlVey Date: Tool Type: Tool Size: No, of Fingers: Anal st: October 5, 2006 MFC 40 No, 99494 2.75 40 M. Tahtouh Finger 35 Penetration 0.234 ins Line Corrosion 0,23 ins = 65% Penetration HIGH SIDE = UP Cross Sections page 3 .. .. .. -- .. I KRU 3A-01 I ~A.l'lt API: 500292141200 Well Type: PROD Anqle (âJ TS: 46 de¡:¡ (âJ 9016 Tubing SSSV Type: None Orig 9/1/1985 Angle @ TO: 42 deg @ 9600 (0-8641, Completion: 00:2.875, 10:2.442) Annular Fluid: DSUBrine LastW/O: 8/4/1998 Rev Reason: Taq Reference Loq: Ref Log Date: Last Update: 5/25/2006 Last Tag: 8611' RKB (on top TD: 9600 ftKB of oumo) ~ate: 5/23/2006 Max Hole AnDie: 56 deo (â) 2400 DescriDtion Size Too Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 104 104 62.50 H-40 SUR, CASING 9,625 0 4353 3157 36,00 J-55 PROD, CASING 7.000 0 9575 6331 26.00 J-55 IU"'INl Size I Too I Bottom I TVD I Wt I Grade I Thread 2,875 I 0 I 8641 I 5674 I 6.50 I J-55 I 8rd mod Interval ND Zone Status ft SPF Date Tvoe Comment 9020 - 9036 5928 - 5939 C-1 16 12 11/10/1985 IPERF 5" HvnerJet II, 120 deQ. ph 9165 - 9195 6030 - 6052 A-3 30 4 11/10/1985 IPERF 4" Hvoer Jet II, 90 deg. ph 9210 - 9260 6063 - 6099 A-2 50 4 11/10/1985 IPERF 4" Hvner Jet II. 90 deo. nh G;;; St MD ND Man Man Type V Mfr V Type VOD latch Port IRO Date Vlv Mfr Run Cmnt 1 94 94 CAMCO KBMM CAMCO DMY 1.0 BK 0,000 0 7f111999 (1) 2 3652 2747 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1289 5/25/2001 3 5733 3959 CAMCO KBMM CAMCO OV 1.0 BK 0.188 0 9/28/2004 4 6500 4414 CAMCO KBMM CAMCO DMY 1,0 BK 0,000 0 8/4/1998 5 8564 5626 CAMCO KBMM CAMCO HFCV 1.0 BK 0,000 0 4/24/2000 GAUGE Bæ ·X fllD 0;;:;" ' Pumo (8611-8612, ..c....., ¡¡:;;W¡:;;(DV 00:3.500) Tvoe Descriotion ID 8610 5655 NIP CAMCO 'D' NIPPLE W/NOGO 2.250 8611 5655 GAUGE BAKER SENTRY GAUGE - discharge 2,875 8638 5673 GAUGE BAKER SENTRY GAUGE - ¡unction 2.875 8641 5674 PUMP Centrilift 513 triole taoer oumo 0.000 8677 5697 SEAL Centrilift Tandem seal section 0.000 8691 5706 MOTOR Centilift266 HP series 562 0.000 I Gene!'!! Iotas Date Note 9/29/1998 StandinQ valve or valve catcher should be run in CAMCO D niDole Drior to anv wireline work 9/29/1998 T OD of iunk (âJ 9332' MD PUMP 8/31/2001 PACKER LESS COMPLETION, FTS WELL (8641-8677, 00:2.875) 2/30/200 WAIVER ED WELL: T x IA COMMUNICATION; PACKER LESS WELL, FAILED ESP SEAL (8677-8691, 00:2.875) Perf (9020-9036) .- 1·- -- - .- , --.,. ,- - PROO. --- CASING -.. .-- (0-9575, - -.. -- -, 00:7.000, - - Wt:26.00) -- - Perf --. - (9165-9196) -- - -- -- -- f-- - f-- - , i-- .- ,1--- -- , --- - --- Perf --- -- (9210-9260) '- - ._, -- - .-- - '- -- - -.-- 1--- --, 1-·- -, '- I I I I I I I I I I I I I I I I I 3A-Ol Well Shut In . . John, \C{)<S~ \~.-Ö\ To reiterate our conversation, we took a 4 bbl kick at approx 10:30 this morning while performing a cleanout at approx 9178'. The annular preventer was closed and we now have wI 110 psi on the casing and 10 psi on the tubing; brine weight is 10.3 ppg. Currently monitoring our pressures. Give me a call if you have an questions. Thanks, Chris Kennedy 659-7457 ( ~3 1 of 1 10/2/2006 12:55 PM JA-U I close Annular Preventer . John, While pulling out of the hole with our old 2-7/8" ESP completion on 3A-01, we had to shut down and release our spooler. We had 4300' of tubing pulled to surface with another 4300' of tubing left in the hole. While monitoring the well, gas began to break out at surface. The hole was filled with 10# brine and after a 3 bbl pit gain the annular preventer was closed. We are currently weighting up brine to 10.2# and will begin circulating through the choke to kill the well. Please call with any questions, Brad Gathman/Chris Kennedy 659-7457 I of I 9/28/2006 8:56 AM e e f? ,II ~F b ,~ II J :1.= ¡ ¡ U FRANK H. MURKOWSKI, GOVERNOR A"~SK.& OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-0 1 Sundry Number: 306-254 r. "-' Dear Mr. Eller: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisllday of July, 2006 Encl. ,- ... ./1 Lj,~ ,. /''6(0 :) - I p~ r¡j¡7/6 STATE OF ALASKA ~ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUt 2 7 '\nJli' APPLICATION FOR SUNDRY APPROVA /;,-'-) - ¿uuo Alaska Oil & Gas Cons. Commission Waiver []nChOragether 0 P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Requires? Yes 0 No 0' 3A-01 9. Property D~signation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25632, ALK 2448 RKB 72' Kuparuk River Field 1 Kuparuk Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9600' . 6350' 8611' Casing Length Size e 20 MC 25.280 1. Type of Request: o o o Suspend 0 Operational Shutdown Abandon o o Alter casing Repair well Plug Perforations Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Pull Tubing Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic 0 MD CONDUCTOR SUR. CASING PROD. CASING 80' 4329' 9551' 16" 104' 4353' 9575' 9-5/8" 7" Perforation Depth MD (ft): 9020'-9036',9165'-9195',9210'-9260' Packers and SSSV Type: no packer no SSSV 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Ope rat 17. Verbal Approval: Commission Represe Perforation Depth TVD (ft): 5928'-5939',6030'-6052', 6063'-6099' Packers and SSSV MD (ft) September 1, 2006 Date: 18. I hereby certi Printed Name Commission Use On I d correct to the best of my knowledge. Signature Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Other: '3500 "^-\"'-\ __-.:)~ ~~ ~\- Subsequent Form Required: . Approved by: Form 10-403 Revised 06/2 o o o Perforate 0 o Stimulate Exploratory 0 Service 0 Time Extension 0 Re-enter Suspended Well o 5. Permit to Drill Number: 185-186 6. API Number: 50-029-21412-00 8. Well Name and Number: TVD 104' 3157' 6331' Tubing Size: 2-7/8" Contact: Title: Phone 265-4021 Location Clearance 0 Junk (measured): 9332' Burst Collapse 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Tubing Grade: J-SS Tubing MD (ft): 8641' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 J. Gary Eller @ 263-4172 Wells Group Engineer Date RBDMS BFL JUL 3 1 2006 APPROVED BY THE COMMISSION .MII.. Submit in Duplicate iVl-ø."tb ,.$.b "'·Z7.. Ob e e Gary Eller Wells Engineer Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 July 26, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 3A-01 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 3A-01. As per sundry 305-302, this well is on a waiver to produce ./ via gas lift without a packer. T~is ~or~over will install tubing and a packer. ,¡...~ç.\\~,>~'è0 E<;? ~'(~'\ If you have any questions regarding this matter, please contact me at 263-4172. JGE/skad e e WORKOVER PROCEDURE FOR 3A-Ol 1. MIRU Nabors #3S rig. 2. Kill well. ND tree, NU and test BOPE to 250/3500 psi. Pressure test annular BOP to 250/2500 psi. Œote: Maximum calculated surface pressure is 2410 psi assuming a full gas gradient based on SBHP of2735 psi at 8611' MD, 5655' TVD.) ;¡.'ì~S -" "5"~5S-~-:. d- \CQ~"";\ 1fL<1"f1 3. Pu1l2W' completion. If tubing does not pull tree, e-line cut will be required. "),~" 4. Clean out the wellbore. 5. E-line run caliper log in 7", 26 ppf, J-55 casing. 6. E-line set permanent packer below the C-Sand for a 3W' selective completion. 7. Run 3Yz" completion, tying into permanent packer below the C Sand. ' 8. Set FHL packer. Space out and land completion. Pressure test tubing and IA. < 9. ND BOP, NU and test tree. 10. RDMO workover rig. .,...../ ConocoPhillips API: SO-029-21412 AOGCC: 18S-186 Lift thds: 3Yz" 8rd BPV: FMC ISA Wellhead: FMC Gen-IV Proposed Completion · Tubing = 3Yz", 9.3 ppf, L-80, EUE 8rd Mod · Camco TRMAXX-SE SCSSV at 2000' w/2.813" X-profile · Baker FHL packer at 8904' · X-nipple at 8949' 10 = 2.813" · Gas lift mandrel at 8964' · Carbide blast rings on 3%", 9.2 ppf, L-80, IBT-Mod 901S' - 9041' (26') · Baker CMU sliding sleeve at 9071' w/2.813" X-profile · Baker F perm packer at 9081' · Camco 0 nipple at 9113' 10 = 2.7S" · Re-entry guide at 9120' Directional: Max hole angle: S6° at 2300' Angle at top perf: 46° at 9020' Max doglegs: 4.1 °/1 00' at 700' e PROPOSED x Tag = 9332' (8/2/98) TO = 9600' e Well: 3A-Q 1 Field: Kuparuk Conductor: 16", 62.S8 ppf, H-40 at 104' Surface Casinq: 9%", 36 ppf, J-SS at 43S3' Gas Lift Mandrels MD TVD Type 3628' 27S0' MMG-dummy S970' 4100' MMG-dummy 7309' 4900' MMG-dummy 8227' S42S' MMG-dummy 88S9' S81S' MMG-DCR C-Sand Selective 8964' S889' MMG-dummy Perfs C-1: 9020' - 9036 (12 spf, 11/8S) A-3: 916S' - 919S' (4 spf, 11/8S) A-2: 9210' - 9260' (4 spf, 11/8S) Surface Casinq: 7",26 ppf, J-SS at 9S7S' Last Updated: 31-May-06 Updated by: JGE ConocoPhiUips Alala, Inc. tit KRU 3(\-01 3A-01 API: 500292141200 Well Type: PROD Angle @ TS: 46 deç¡ @ 9016 Tubing SSSV Type: None Orig 9/1/1985 Angle @ TO: 42 deg @ 9600 (0-8641, Completion: 00:2.875, 10:2.442) Annular Fluid: DSUBrine Last W/O: 8/4/1998 Rev Reason: Tao Reference Log: Ref LOQ Date: Last Update: 5/25/2006 Last Tag: 8611' RKB (on top TO: 9600 ftKB of pump) Last Too Date: 5/23/2006 Max Hole Anole: 56 deo (â) 2400 , DescriDtion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 104 104 62.50 H-40 SUR. CASING 9.625 0 4353 3157 36.00 J-55 PROD. 7.000 0 9575 6331 26.00 J-55 Size I TOD I Bottom I TVD I Wt I Grade I Thread 2.875 0 I 8641 I 5674 I 6.50 , J-55 I 8rd mod Interval TVD Zone Status Ft SPF Date Type Comment 9020 - 9036 5928 - 5939 C-1 16 12 11/10/1985 IPERF 5" HvoerJet II, 120 deo. Dh 9165-9195 6030 - 6052 A-3 30 4 11/10/1985 IPERF 4" Hyper Jet II. 90 deg. ph 92 10 - 9260 ( 063 - 6099 A-2 50 4 11/10/1985 IPERF 4" HVDer Jet II. 90 deo. Dh Gas St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 94 94 CAMCO KBMM CAMCO DMY 1.0 BK 0.000 0 7/7/1999 (1) 2 3652 2747 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1289 5/25/2001 3 5733 3959 CAMCO KBMM CAMCO OV 1.0 BK 0.188 0 9/28/2004 4 6500 4414 CAMCO KBMM CAMCO DMY 1.0 BK 0.000 0 8/4/1998 5 8564 5626 CAMCO KBMM CAMCO HFCV 1.0 BK 0.000 O. 4/24/2000 GAUGE 1. SBK-DF 318" X 7/16" for ESP Pump (8611-8612, \J"'~I \1 1IUY::'. eauip.. etc.) - 00:3,500) DeDth TVD Type Description 10 8610 5655 NIP CAMCO '0' NIPPLE W/NOGO 2.250 8611 5655 GAUGE BAKER SENTRY G\UGE - discharge 2.875 8638 5673 GAUGE BAKER SENTRY G\UGE - iunction 2.875 8641 5674 PUMP Centrilift 513 triple taDer DumD 0.000 8677 5697 SEAL Centrilift Tædem seal section 0.000 8691 5706 MOTOR I Centilift 266 HP 0.000 Date Note 9/29/1998 Standing valve or valve catcher should be run in CAMCO 0 nipple prior to any wireline work PUMP 9/29/1998 TOD of iunk (â) 9332' MD (8641-8677, 8/31/2001 PACKERLESS COMPLETION, FTS WELL 00:2.875) 2/30/200 WAIVERED WELL: T x IA COMMUNICATION; PACKERLESS WELL, FAILED ESP , SEAL (8677-8691, 00:2.875) Perf - (9020-9036) - r-- - r-- - ,-- - r-- PROD. c-- CASING - r-- (0-9575. - c-- - r-- 00:7.000, - - Wt:26.00) - '-- Perf - c-- (9165-9195) - - - '-- - c-- - - - - - - - - - - Perf - - (9210-9260) - - - - - - - - - - - - - - - - ) '~j~~, ' ',j lr:;i,-!j"ú","'~' \' ,:i.'TI, rJ r,' '6, ' '~ \\"""' :: i n'l) '\ i I I ~ '~ 'J "" 'J' I " I I ): \, ;, 'I \ I '. \ I I I f [Ù) : '; ¡ ,:ï-¡ \~ ! i I [I ~_ ".Nt!,~ l ~ ,,'\ !::JJ ! ¡I 'i)... ; 1:1 U r: Il' I i :~ ~i~l ,I \\ l~, ' ¡W' Uru FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W, "{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gatham Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 \Cö 5-- \ ff0 Re: Kuparuk 3A-01 Sundry Number: 305-302 Dear Mr. Gatham: 'O'\Ð g~ ç» tr)nq~~ ~{;^~~ED N',~, u 0 '-u~¡'" 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. DATED this/~ay of October, 2005 Encl. Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 72' 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9600' 6350' Casing Length Size CONDUCTOR 104' 16" SUR. CASING 4281' 9-5/8" PROD. CASING 9503' 7" Perforation Depth MD (ft): 9020'-9036', 9165'-9195', 9210'-9260' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman ~A..? 1. Type of Request: Abandon Alter casing 8. Property Designation: Kuparuk River Unit Signature ",.I ALA~KA OIL AND ~~;~g~~L:;;~i:~::~s,~~ S ~~~~'~rP ~~j APPLICATION FOR SUNDRY APPROVAh O. 20 MC 25.280 IS I ., & Gas Cons. Commission D Suspend D Operational Shutdown D Perforate D wa~ßCnOr~e Other D D Repair well D Plug Perforations D Stimulate D Time Extension 0 D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Development 0 Stratigraphic D Exploratory D Service D 185-186 6. API Number: 50-029-21412 -00 9. Well Name and Number: 3A-0 1 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Burst Collapse 104' 4353' 9575' Perforation Depth TVD (ft): 5926'-5937',6029'-6050',6061'-6098' Packers and SSSV MD (ft) no packer no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Tubing Size: 2-7/8" Tubing Grade: J-55 Tubing MD (ft): 8641' Service D Plugged D WINJ D Abandoned D WDSPL D Immediately Date: Contact: Title: Brad Gathman, 659-7224 Problem Wells Supervisor Date ,.... ¿Jr"- 0$ Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 365 - 3 ö 2 ~7~ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: 4 ~<2:.Q.\,~\'D~o.\ \<L~.", SV~"1<2--W'\\€:'> \~ (/ -o~. \7~~ ...;) c "'- <l:S'-.-\- \'--t <::J-.. \- +N 'c:ke:.~ s. \- c'LM. RBDMS BFl 0 CT 1 3 2005 AD IG J N þpqOVEDBY COMMt.siIdmJ=~ ;.J /nE.. C_OMMISSION /ffdŠ' Date: Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3A-01 (PTD 1851860) September 28, 2005 This application is for an extension of Sundry 303-277 for we1l3A-Ol (PTD 1851860) and to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. We113A-Ol was originally completed in September 1985 as a gas lifted producer. The well was re-completed with an ESP in July 1998. The well produced via ESP until June 1999, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will befor standard gas lift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gas lift mandrel at 8564'measured depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 3652' and 5733' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per regulations. As per this request, ConocoPhillips intends to produce 3A-0 1 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ) .tØppçøÞhÎn¡p$AI:~~a·J~p:'500292141200 Wen Type PROD Tubing ~ hj)1 SSSV Type: None Orig 9/1/1985 ~7m; II ! ,I. R:f:~~~:~~~: DSUBrine R:~~~~Z~: 8/4/1998 ¡·]I[ c~dii~~;:AtF~i~~~;mp Max HOle.An~~~:~~ ~ 2400 ! ::r ·::~ji~~~~~~gp ·I~~¡~;~m ;,~,P ~~ B~~,~,m 6~~ ~~~~e ifí~ .....~.'.'''':...,'il· IÞårfóråti(jns SÜmrnåry . .. < Interval TVD Zone ¡¡¡i:i::.::::~:!·· ~~~~ ~ ~~~~ ~~;~ ~ ~~~~ ¡~~ .'." ...',.... 9210 - 9260 6063 - 6099 A-2 ).::!I;:. c;,~ L~DMa~~sN~~ Man Type V Mfr VType V 00 Latch Port TRO 1m::::_ 1 94 94 CAMCO KBMM CAMCO 1.0 BK -":,:,,<,:,,,.::,', 2 3652 2747 CAMCO KBMM CAMCO 1.0 BK 3 5733 3959 CAMCO KBMM CAMCO 1.0 BK 4 6500 4414 CAMCO KBMM CAMCO 1.0 BK 5 8564 5626 CAMCO KBMM CAMCO 1.0 BK 1. SBK-DF 3/8" X 7/16" for ESP Pump Oth.erÚ)lugš;~Üip;,etc·.) <,; ~EWELRY.· Depth TVD Type 8610 5655 NIP 8611 5655 GAUGE 8638 5673 GAUGE 8641 5674 PUMP 8677 5697 SEAL 8691 5706 MOTOR General Notes Date Note 9/29/1998 Standing valve or valve catcher should be run in CAMCO D nipple prior to any wireline work 9/29/1998 Top of junk @ 9332' MD 8/31/2001 PACKERLESS COMPLETION, FTS WELL 12/30/2003 WAIVERED WELL: T x IA COMMUNICATION; PACKER LESS WELL, FAILED ESP GAUGE (8611-8612, 00:3,500) I",,·:" ......:.: " ..... .............. miJi ~ ," PUMP (8641-8677, 00:2,875) SEAL (8677-8691, 00:2,875) I ICWo'" ,:::t.;:;:; Perf (9020-9036) PROD, CASING (0-9575, 00:7.000, Wt:26,00) -r ~~ Perf (9165-9195) Perf (9210-9260) ) KRU 3A-01 , ., . ..... . . . . . . . ....... .,.,. . .... .. . . .... ... , . . . .. ... . .. . . ",. ..... . ".. ., ..",. Angle @ TS: 46 deg @ 9016 Angle @ TD: 42 deg @ 9600 Rev Reason: Adjust Port Size Last Update: 10/25/2004 Grade H-40 J-55 J-55 Thread Thread 8rd mod Status Ft SPF Date Type Comment 16 12 11/10/1985 IPERF 5"HyperJetll,120deg.ph 30 4 11/10/1985 IPERF 4"HyperJetll,90deg.ph 50 4 11/10/1985 IPERF 4"HyperJetll,90deg.ph DMY GLV OV DMY HFCV 0.000 0 0.156 1289 0.188 0 0.000 0 0.000 0 Date Run 7m1999 5/25/2001 9/28/2004 8/4/1998 4/24/2000 Vlv Cmnt (1 ) Description ID 2.250 2.875 2.875 0.000 0.000 0.000 CAMCO 'D' NIPPLE W/NOGO BAKER SENTRY GAUGE - discharge BAKER SENTRY GAUGE - junction Centrilift 513 triple taper pump Centrilift Tandem seal section Centilift 266 HP series 562 ~ -0-- ~ -0-- -,-.- ~ ~ -,-.- -,~ ~ ~ ----.-.- CO~SERYATION COMMISSI05~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 should be allowed to continue production with no restrictions. . The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C-16 should be changed to be similar to the other failed ESP wells with the fluid entry Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, Commissioner i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [~ Operation Shutdown E~ Perforate [] Vadance [~ Repairwell [~ Plug Perforations [~ Stimulate {--] Time Extension ~] Pull Tubing r--] Perforate New Pool E~ Re-enter Suspended Well [--] Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ [] Stratigraphic [] Exploratory Service 5. Permit to Drill Number: 185-186 6. APl Number: 50-029-21412-00 7. KB Elevation (ft): I 9. Well Name and Number: RKB 72' I 3A-01 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): iTotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9600' 6350' 9332' 6150' Casing Length Size M D TVD CONDUCTOR 104' 16" 104' 104' SUR. CASING 4281' PROD. CASING 9503' Perforation Depth MD (ft): 9020'-9036', 9165'-9195', 9210'-9260' Packers and SSSV Type: no packer no SSSV 9-5/8" 4353' 3154' 7" 9575' 6330' Perforation Depth TVD (ft): 5926'-5937', 6029'-6050', 6061'-6098' 12. Attachments: Description Summary of Proposal [] Detailed Operations Program E~ BOP Sketch 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: Tubing Size: 2-7/8" Junk (measured): Burst Collapse Tubing Grade: Tubing MD (ft): J-55 8641' Packers and SSSV MD (ft) no packer no SSSV 13. Well Class after proposed work: Exploratory r-1 Development 15. Well Status after proposed work: oil Gas I--I WAG [--] GINJ [~] Plugged WINJ Service Abandoned WDSPL r'-'l 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name /~ot:o~~ Signature / ,.------- Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BI BOP Test E~] Mechanical Integrity Test E] Location Clearance~ C' ¢'~'~i:~ .~,,~. ...... ~, Other: ~~~1 ~, ~ ~ ~O~ Subsequent Form Required: ~~ ~ ~[ ~ ~ 0 ~ ,~,c~8ra~8 Approved by: /~~ ,/~'~-~.,,. C__OMMISSIONER Form 10-403 Revised BY ORDER OF THE COMMISSION Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3A-01 (PTD 1851860) September 11, 2003 This application for Sundry approval for well 3A-01 (PTD 1851860) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3A-01 was originally completed in September 1985 as a gas lifted producer. The well was re-completed with an ESP in July 1998. The well produced via ESP until June 1999, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at 8564'mea_s_o~d depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 3652' and 5733' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per reg~ Recent well test data shows the following results: WELL TEST SUMMARY REPORT WATER OTAL FORM TOTAL LIFT GA DS WL LENGTH CHK FTP FTT SAND OIL FLUID GAS GOR GLR RATE 3A 1 20:00 104 157 105 A.C. 211 815 1026 118 560 408 300 /PREs I 3A 1 16:53 104 208 110 A.C. 252 947 1199 242 961 866 796 I1276 I I 3A 1 9:52 104 205 112 A.C. 288 1005 1293 236 820 757 743 3A 1 5:12 104 250 109 A,C. 261 984 1245 315 1204 1329 1340 As per this request, ConocoPhillips intends to produce 3A-01 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. · ~ ConocoPhillips Alaska, Inc, Tubing ~ 3A-01 0D:2.875, ID:2.442) PUMP (8641-8677, 0D:2.875) SEAL (8677-8691, 0D:2.875) Perf (9020-9036) Perf (9165-9195) Peri (9210-9260) KRU 3A-01 APl:1500292141200 SSSV Type:I None Annular Fluid:I DSL/Brine Reference Log:I Last Tag:lB641 top of pump Last Tag Date:l 9/1/2002 Well Type:I PROD Orig 19/1/1985 Completion:I Last W/O:18/4/1998 Ref Log Date:I TD:I9600 ftKB Max Hole Angle:156 deg (~ 2400 Angle (~ TS: 146 deg @ 9016 Angle @ TD:I42 deg @ 9600 I Rev Reason:lFTS WELL Last Update:15/24/2003 Casing Strin9 - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Top 0 104 104 0 4353 3157 Boffom TVD Wt GradeI Thread 62.50 H-40 I 36.00 J-55 9575 6331 26.00 J-55 Tubin9 Strin9 - TUBING Size I Top I Bottom TVD Wt GradeI Thread 2.875] 10 8641 5674 6.50 J-55 8rd mod Perforations Summary TVD Interval 9020-9036 5928-5939 9165-9195 6030-6052 9210-9260 6063-6099 Zone Status Ft SPF Date I Type Comment C-1 16 12 11/10/1985~ IPERF 5" HyperJet ll~120 deg. ph A-3 I 30 4 11/10/1985~ IPERF 4"HyperJetll, 90deg. ph A-2 I 50 4 11/10/1985{ PERF 4 HyperJetll, 90deg. ph Gas Lift Mandrels/Valves St MD TVD I Man Man V Mfr VType VOD Latch Port TRO Date I VIv I Mfr Type I Run Cmnt 1I 941 94]CAMCO] KBMM ICAMCOI DMY ]1.0 I BK 10.0001 0 17~7~19991 (1) 2 3652] 2747]CAMCO KBMM CAMCO GLV I 1.0 I BK 10.156 1128915/25/2001l 3]57331 3959lCAMCOI KBMM ]CAMCO] OV ] 1.0 ] BK 10.2501 0 14/24/2000] 4165oo144141cAMc01 KBMM I CAMCOI DMY I1.0 I ~K 10.000I 0 18/,~/19981 5185641 56261CAMCOI KBMM I CAMCOI HFCV I 1.0 I BK 10.0001 0 14/24/20001 1. SBK-DF 3/8"X 7/16" for ESP Pump Other(Pl:UgS?;equiPi;:etc:);~:JEWEERY: :: : :i : ::::;;: ::;::;; i::::~ ;; :::: : Depth TVD Type I ................................ Description 'I'D 8610 1 5655 I N~P ]CAMCO'D'NIPPLEW/NOGO 2.250 8611 5655 I GAUGE BAKER SENTRY GAUGE - discharge 0,000 8638 I 5673 I GAUGE I BAKER SENTRY GAUGE-junction 0.000 8641 ]5674 ] PUMP ]Centrilift 513 triple taper pump 0.000 8677 5697 I SEAL ICentrilift Tandem seal section 0.000 8691 5706 I MOTOR ICent ft 266 HPseres 562 0.000 Date i Note 9/29/19981 Standing valve or valve catcher should be run in CAMCO D nipple prior to any wireline work 9/29/1998 Top of junk (~ 9332' MD 8/31/2001 PACKERLESS COMPLETION, FTS WELL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission- TO: Julie Heusser, Commissioner DATE: January 7, 2001 THRU' Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3A & 3B pads Sunday, Janua ,ry 7, 2001' I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety Valve System TeSt Reports indicate I Witnessed the testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure observed. The surface safety valve on well 3^-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test proCedure and was a pleasure to Work with The wellhouses on these two pads were very clean and all related eqUipment appeared to be in good condition. ~ Summary: I witnessed the semi annual SVS testing at 3A & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components, KRU 3B Pad, 6 wells, 12 components, 19 wellhouse inspections I failure 0 failures Attachment: SVS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad 1-7-01 CS X Unclassified Confidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 1/7/01 Operator Rep: John Arend Field/Unit/Pad: Kuparuk / KRU / 3A Pad AOGCC Rep: Chuck Scheve Separator psi' LPS 64 HPS Well Permit Separ Set L/P Test Test Test Date· Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3A-01 1851860 64 70 50 P P OIL 3A-03 1852060 3A-05 1852210 64 70 50 P P OIL 3A-08 1852240 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810i 64 70 40 . P P OIL 3A-16 1852840 64 70 70 p P OIL ,3A-17 1961320 · 3A-18 1961330 64 70 50 P P OIL · . Wells: 8 Components: 16 Failures: 1 Failure Rate: 6.3% [] 90 Day Remarks: Surface Safety Valve on well 3A-08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: .Kupamk / KRU / 3B Pad Separator Psi' LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i 3B-03 1850600 64 70 60 P P OIL 3B-04 1850610 64 70 50 P P OIL 3B-06 1850760 64 70 50 P P OIL 3B~08 1850870 3B-09 1851130 64 70 70 P P OIL 3B-11 i851150 64 70 50 P P ' ' OIL 3B-13 1850230 ,= , 3B-14 1850240! Wells: 6 Components: 12 FailUres: 0 Failure Rate: []90 var Remarks: Good Test 1/9/01 Page 1 of 1 svS KRU 3B Pad 1-7-01 CS.xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 21, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3A-01 (Permit No. 85-186/398-109) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 3A-01. If there are any questions, please call 265-6120. Sincerely, Graham C. Alvord Kuparuk Drilling Team Leader Kuparuk Drill Site Development GCA/skad RECEIVED AUG 26' 1998 Alaska Oil & Gas Cons. AnChorage AUG 2 G l !)B hnch0ra~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown ~ Pull tubing Stimulate_ Plugging__ Perforate Alter casing __ Repair well __ Other X Install ESP completion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 478' FSL, 736' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1522' FSL, 1294' FEL, Sec. 17, T12N, R9E, UM At effective depth At total depth 1248' FSL, 1003' FEL, Sec. 17, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory __ Stratigraphic _ Service 9600' feet Plugs (measured) 6348' feet 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-01 9. Permit numbedapproval number 85-186/398-109 10. APl number 50-029-21412 11. Field/Pool Kuparuk River feet Effective depth: measured true vertical 9332' feet Junk (measured) 6150' feet Casing Length Structural Conductor 80' Surface 4329' Intermediate Production 9551' Liner Size Cemented 16" 199 sx AS II 9-5/8" 1100 sx AS III & 360 sx Class G 7" 469 sx Class G & 250 sx AS I Measured depth True vertical depth 104' 104' 4353' 3154' 9575' 6330' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) NONE 9020'-9036',9165'-9195',9210'-9260' 5926'-5937',6029'-6050',6061'-6098' 2.875",6.5#,J-55 @ 8714' RECEIVED ^ii¢. 1998 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORI !klAL Alaska 0il & Gas Cons. c0mmlsst0~a Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ff5~ 7~/.~ ~ Form 10- 1 9 Title Kuparuk Drilling Team Leader SUBMIT IN DUPLICAT% Date: 8/19/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3A-01 WELL_ID: 999223 TYPE: AFC: 999223 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:07/20/98 RIG:NORDIC ~ 2 WI: 0% SECURITY:0 API NUMBER: 50-029-21412-00 BLOCK: FINAL:08/06/98 07/20/98 (Cl) TD: 9575' PB: 9485' 07/21/98 (C2) TD: 9575' PB: 9485' 07/22/98 (C3) TD: 9575' PB: 9485' 07/23/98 (C4) TD: 9575' PB: 9485' 07/24/98 (C5) TD: 9575' PB: 9485' NU BOPE MW:10.9 SW SUPV:M.C. HEIM & RICK OVERSTREET Move rig from 3A-03 to 3A-01. Accept rig @ 1100 hrs. 7/20/98. Displace sea water w/brine. Monitor well, well static. RIH W/ SCHLUMBERGER 3-1/2 MW:10.9 SW SUPV:DONALD L. WESTER Monitor well flowing up tubing. Circulate 10.9 ppg brine. N/D tree. NU BOPE and test to 300/3500 psi. Well unstable and flowing. Pump 10.9 ppg kill weight fluid. Pump LCM ahead of 11.2+ kill fluid. Unable to shear PBR. Spot LCM pill at perfs. RIH w/3.5" chemical cutter. L/D 283 JTS 3.5" TBG + CU MW:10.9 SW SUPV:DONALD L. WESTER Continue running e-line w/3.5" chemical cutter to 8920' Cut 3.5" tubing the middle of last joint. POOH to 200' well flowing up tubing. Circulate kill weight fluid down tubing. Monitor well not taking fluid. Spot calcium carbonate pill across perfs. Pull 3.5" tubing. Hole not filling right. Spot 12.0 pps fluid down tubing. Continue to POOH 3.5" tubing. RIH W/ WASH PIPE ON BOTTO MW:10.9 SW SUPV:DONALD L. WESTER P/U fishing tools. RIH work over top of 3.5" tbg fish @ 8920'. Jar on fish. Appear to have moved fish up hole 6' Top of fish now @ 8914'. Unable to move fish up or down. POOH for wash pipe. Hole take about 4 bph over displacement. JARRED ON FISH 1.5 HRS @ MW:ll.3 SW SUPV:DONALD L. WESTER Continue to fish. Wash over fish from 8914' top of Baker packer. Unable to move packer back down. POOH w/wash pipe. Hole not filling right behind 10 bbls. M/U overshot, well started to flow from annulus, drill pipe dead. Circulate and condition fluid to 11.3+ ppg. Date: 8/19/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/25/98 (C6) TD: 9575' PB: 9485' 07/26/98 (C7) TD: 9575' PB: 9485' 07/27/98 (C8) TD: 9575' PB: 9485' 07/28/98 (C9) TD: 9575' PB: 9485' 07/29/98 (C10) TD: 9575' PB: 9485' 07/30/98 (Cll) TD: 9575' PB: 9485' WHILE RAISING FLUID WEIGH MW:ll.5 SW SUPV:DONALD L. WESTER Jarring on Baker PBR and packer @ 8951' Moved up hole 20' to 8931' and came free. POOH hole fill 12 bbls over. Recover 19.1' cut off, pup, seal assy and PBR & 4.35' of FHL packer inter mandrel. Top of fish now @ 8932' RIH with chemical cutter. Cut not parted lower fish moving up hole. Unable to log below blast ring joint to check @ 9070' Recut 3.5" tubing 3' below 9020' tubing cut. Well starting to flow pressure coming up 20 psi on annulus. Circulate and slowly raise fluid weight to 11.5 ppg. RIH W/ BHA #5 INGAUGE FIS MW:ll.5 SW SUPV:DONALD L. WESTER Continue to circulate and condition completion fluid to 11.5 ppg. Started loosing fluid @ 40 bph. Pump 50 bbl hi-vis calcium carbonate 80 ppb LCM pill. POOH well taking over displacement volume. RIH with spear grapple. IN HOLE @ 0430 HRS. MILL MW:ll.5 SW SUPV:DONALD L. WESTER Continue RIH w/BHA ~5 bull nose w/2.933" spear. Tag top of junk packer @ 8934' Set spear @ 8934'. Jar on packer. Tools parted pressure dropped. POOH Part of PRT lost in hole. RIH with BHA #6 to push old spear down. Tag PKR @ 8934' push spear down. Beat down on PKR. PKR did not move down. POOH. RIH with BHA #7 6"x 4.75" washover shoe w/2.25" x 1" PRT bar inside to keep center of packer open. MILL OVER PACKER MW:ll.5 SW SUPV:MORRISON/OVERSTREET Tag top of packer at 8934' Mill over packer with 4.75x6.0 burning shoe from 8934' to 8935'. Losing 6-10 bbls fluid while milling. Monitor well, flowing. Bullhead 20 bbls 11.5 brine. RIH, 10 STANDS OFF BOTTOM MW:ll.5 SW SUPV:MORRISON/OVERSTREET Tag fish at 8935' Mill over packer with wash shoe. No progress made. Well kicked, 8 bbl gain brine weight out 11.2 ppg. Shut in well. Circulate out kick through choke with 11.5 brine while maintaining constant bottom hole pressure at 45 spm. Open well and circulate bottoms up the long way at 95 spm, lost 31 bbls mud while getting bottoms up. Observe well, static. VISCOSIFY BRINE MW:ll.5 SW SUPV:MORRISON/OVERSTREET Tagged fish @ 8935' Pushed fish down 18' & catch, swabbed 14 bbls, filled hole took 25 bbls to fill. Hole taking 30 bph with pumps off. Pump high-visc salt pill. POOH with fish. Date: 8/19/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/31/98 (C12) TD: 9575' PB: 9485' 08/01/98 (C13) TD: 9575' PB: 9485' 08/02/98 (C14) TD: 9575' PB: 9485' 08/03/98 (C15) TD: 9575' PB: 9485' 08/04/98 (C16) TD: 9575' PB: 9485' O8/O5/98 (C17) TD: 9575' PB: 9485' 08/06/98 (C18) TD: 9575' PB: 9485' POOH WITH FISH MW:ll.6 SW SUPV:MORRISON Run in and spear fish at 8955'. POOH with fish. 10 bbs short on fill after pulling 25 stands. Observe well very minor flow. CBU. Brine at 11.5 ppg all the way around. No gas or oil shows in brine. Observe well very slight flow. CBU. Gas and oil to surface after pumping 153 bbls. Circulate long way and increase weight to 11.6 ppg. POOH WITH LOWER PACKER SE MW:ll.6 UNKN SUPV:MORRISON Continue circulate and condition oil cut mud and increase weight to 11.6 ppg. Observe well, static. RIH with overshot to catch blast ring joint. Tag fish at 9009' and work over. Observe well, static. CIRCULATE BOTTOMS UP AT 9 MW:ll.6 SW SUPV:MORRISON RIH with mill. Tag fish at 9063' and work over. POOH with fish. Mill packer from 9063' to 9065' Push packer to 9332' RUNNING COMPLETION MW:ll.6 SW SUPV:MORRISON RIH with clean out assembly. Work tight spot in casing from 9310' to 9312', scraper hanging up at 8925'. Spot hi-vis salt pill on bottom. SPLICING POWER CABLE & 'I SUPV:DONALD L. WESTER RIH with 2-7/8" tubing. MW:ll.6 SW MOVE OFF 3A-01 @ MIDNIGHT MW:ll.6 SUPV:DONALD L. WESTER RIH w/2-7/8" tubing. N/D BOPE. N/U tree and test to 250/5000 psi. Freeze protect tubing and annulus. SW MW: 0.0 DOIL SUPV:DONALD L. WESTER Move off well, clean up location. Secure well. Release rig @ 0200 hrs. 8/6/98. STATE OF ALASKA ' - - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS APR 21 1998 1. Type of Request: Abandon Suspend _ Operation Shutdown __ Re-enter suspended well ...... ~'~" Alter casing _ Repair well _ Plugging __ Time extension _ Stimulate _ Change approved program_ Pull tubing_ Variance_ Perforate_ Other X Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 478' FSL, 736' FEL, Sec. 7, T12N, R9F, UM At top of productive interval 1522' FSL, 1294' FEL, Sec. 17, T12N, R9E, UM At effective depth At total depth 1248' FSL, 1003' FEL, Sec. 17, T12N, R9E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 72' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-01 9. Permit number 85-186 10. APl number 50-029-21412 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 9600' feet (approx) true vertical 6348' feet Plugs (measured) None Effective depth: measured 9485' feet Junk (measured) (approx) true vertical 6263' feet Casing Length Size Cemented Structural Conductor 80' 16" 199 sx AS II Surface 4329' 9.625" 1100 sx AS III Intermediate & 360 sx Class G Production 9551' 7" 469 sx Class G & Liner 250 sx AS I Measured depth 104' 4353' 9575' True vertical depth 104' 3154' 6330' Perforation depth: measured 9020'-9036', 9165'-9195', 9210'-9260' true vertical 5926'-5937', 6029'-6050', 6061'-6098' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9105' Packers and SSSV (type and measured depth) Baker FHL Pkr @ 8961' MD and Baker FB-1 pkr @ 9086' MD, Baker FVL SSSV @ 1876' 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions._ Detailed operation program __ BOP sketch -- 14. Estimated date for commencing operation June 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .,~~ ~¢' ~,~. Title Kuparuk Drilling Team Leader Date FOR COMMISSION USE ONLY . ~-'~ ~, ' Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test ~ Location clearance Mechanical Integrity Test_ Subsequent form require 10- /.(0~ ~,pproved by the order of the Commission David W. Johnston Commissioner IAppr°va' N~- ~:,¢¢' -/~) ~I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KRU 3A-01 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline. Pull valve from bottom GLM leaving an open pocket. Dummy off all other GLM's. 2. RU E-line unit. Chemical cut tubing above and below blast ring joints, adjacent to C Sand pegs. 3. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 11.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down 3-1/2" tubing and all jewelry. 5. PU DP and RIH with spear. Latch into PBR barrel and pull retrievable packer free. POOH with packer and tubing down to cut above blast joints. 6. RIH w/overshot. Wash over tubing stub and fish blast ring joints. POOH and lay down fish. RIH w/overshot and fish remaining completion equipment down to bottom production packer. 7. RIH and mill permanent packer. POOH. RIH with spear and fish permanent packer. POOH w/fish. 8. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. POOH standing back DP. . RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 10. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 8.5 days Expected Case: 9.5 days Upper Limit: 11.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 04/17/98 3A-01 Proposed Completion L. 2-7/8" 5M FMC Gert IV Eccentric tubing hanger with 'BIW' penetrators for ESP cable (100 amp) and downhole gauge conductor wire. 2-7/8" L-80 tubing pup on bottom. Round #2 power cable with tech wire in double armor wrap K. 2-7/8" L-80 EUE 8rd Mod tbg to surface with the bottom +/-1500' IPC. Space-out 2-7/8" x 1" Camco 'KBMM' mandrels w/DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 8' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as procedure Cable splice from flat to round cable adjacent to 10'~ pup above pump J. 2-7/8" X 1" Camco 'KBMM' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 2-7/8" x 8' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 8' and 15' pups. H. Pup jt, 2-7/8" x 15' L-80 EUE 8rd Mod tubing. G. Internal sensing Baker 'Sentry' gauge with special cplg to replace conventional cplg on full joint of tubing below gauge. Conductor Wire for gauges will be run to surface with-in the 2nd Armor wrap of ESP cable. F. I jt of 2-7/8" L-80 EUE 8rd Mod IPC tubing with annulus sensing Baker 'Sentry' gauge clamped to tbg OD. E. 2-7/8" Camco 'D' landing nipple with 2.25" No-Go profile. Standing Valve to be set as nipple is made-up. D. Pup jt, 2-7/8" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. LaSalle Protectolizers at each flange of ESP assembl' C. Centrilift '20 GCNPSH/36GC3500/74GC2900' Series 513 Triple Taper Pump with bolt-on intake and bolt-on discharge head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift 'GST3 4B HL PFS' Tandem Seal Section. A. Centrilift '304 HP KMH 2290/81' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/-8700' MD RKB. C Sand Perfs 9020' - 9036' A Sand Perfs 9165' - 9195' 9210' - 9260' 7" 26# J-55 @ 9575' PBTD @ 9485' WSI 3/31/98 STATE OF ALASKA .~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 2. Name of Operator Operation Shutdown ~ Stimulate X Plugging Pull tubing ~ Alter casing ~ Repair well ~ 5. Type of Well: Development X Exploratory Stratigraphic __ 99510 Service ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 4. Location of well at surface 478' FSL, 736' FEL, Sec 7, T12N, R9E, UM At top of productive interval 1522' FSL, 1294' FEL, Sec 17, T12N, At effective depth 1302' FSL, 1059' FI=L, Sec 17, T12N, At total depth 1248' FSL, 1003' FEL, Sec 17, T12N, 12. R9E, UM R9E, UM R9E, UM Perforate Other Present well condition summary Total Depth: measured 9 6 0 0 true vertical 6 3 4 8 feet feet 6. Datum elevation (DF or KB) RKB 72 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-01 9. Permit number/approval number 85-1 86 10. APl number 5o-029-21 41 2 11. Field/Pool Kuparuk River Field/Pool Plugs (measured) None feet Effective depth: measured 9485 true vertical 6 2 6 3 feet feet Junk (measured) None Casing Length Structural Conductor 7 9' Surface 4 5 2 6' Intermediate Production 9 5 51 ' Liner Perforation depth: measured 9020'-9036', true vertical 5926'-5973', Size 1 6" 9.625" Cemented Measured depth True vertical depth i, 199 Sx AS I 104' 1 04' 1100 Sx AS III & 4553' 3274' 360 Sx Class G CMT w/120 Sx AS I Top Job 469 Sx Class G & 9575' 6 3 3 0' 250 Sx AS I ~.~, !~ ~.,_~ 9165'-9195', 9210'-9260' ~:'~: ~' '~' 6029'-6050', 6061'-6098' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55@ 9105' Packers and SSSV' (type and measured depth) Pkr: Baker 'FHL' @ 8937', Baker 'FB-I' @ 9063'; SSSV: Baker 'FVL' @ 1797' 13. Stimulation or cement squeeze summary Fracture "A" Sand on 1/13/96. Intervals treated (measured) 91 65'-91 95', 921 0'-9260' Treatment description including volumes used and final pressure Pumped 84 Mlbs 20/40 & 12/18 ceramic Proppant into formation, fp was 6000 psi. 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 289 3 6 6 353 1200 157 Subsequent to operation 420 331 630 1250 163 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. =orm 10-404 Rev 06/15/88 Title Wells Superintendant Date ~'~,~ ~ SUBMI'F'IN D/UPEICATE . ARC° Alaska, Inc. KUPARUK RIVER UNIT ,am WELL SERVICE REPORT ~ K1(3A-01(W4-6)) WELL JOB SCOPE JOB NUMBER 3A-01 FRAC, FRAC SUPPORT 1209951 415.16 DATE DAILY WORK UNIT NUMBER 01/13/96 PUMP "A" SANDS FRAC. DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes O NoI (~) Yes O No DS-YOAKUM JOHNS FIELD AFC,~ CC~ DAILY COST AOOUM COST~~,.~ ~ ~Si - ESTIMATE 998505 230DS36AL $108,305 $123,701 ./C/F/¢_~-"~'~ ~ Initial Tb.q Press Final '!'i3.(3 Press Initial Inner Ann Final Inner Ann I Initial Out 1400 PSI 1800 PSI 3500 PS! 1500 PSII 250 PSi! 310 PSI DAILY SUMMARY IPUMPED "A" SANDS FRAC. JOB SCREENED OUT EARLY WITH 84,000 # PROPPANT PLACED IN PERFS, 23,000# LEFT IN PIPE. PLACED WITH 1453 BBLS OF FLUID. MAX. PSI DURING SCREEN OUT 6,000 PSI_ TIME LOG ENTRY 07:00 MIRU DOWELL FRAC. EQUIP., HOT OIL PUMP AND APC SUPPORT EQUIP. 08:38 10:27 HELD SAFETY MEETING AND PRES,SURE TESTED SURFACE LINES TO 7545 PSI PUMPED CONDITION STAGES 230 BBLS FLUIDS, 2011# 20/40 PROPPANT AND FLUSHED WiTH 90 BBLS SEAWATER. 20 TO 25 BPM AND MAX. PRESSURE 6234 PSI. SHUT DOWN FOR ISlP. 11:21 PUMPED DATA FRAC AND FLUSHED, 'TOTAL FLUIDS 193 BBLS, 5 TO 20 BPM AND MAX. 4174 PSI. 12:37 PUMPED 400 BBLS. PAD AT 20 BPM AND 3883 PSI. 13:10 PUMPED PROPPANT STAGES 2# TO 8.3 # PPA, 13,500# 20/40 AND 94,361# 12/18 AT 20 BPM AND SCREENED OUT TO 6000 PSI. WHP. · STATE OF ALASKA ..__ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ,SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter Stimulate X Plugging Perforate casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 4. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 478' FSL, 736' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1522' FSL, 1294' FEL, Sec. 17, T12N, R9E, UM At effective depth 1299' FSL, 1073' FEL, Sec. 17, T12N, R9E, UM At total depth 1248' FSL, 1003' FEL, Sec. 17, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) 72' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-01 9. Permit number/approval number 85-186 10. APl number 5o-029-21412 feet 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 9600' 6350' feet feet Plugs (measured) Effective depth: measured 94 85' true vertical 6265' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9020'-9036', true vertical 5928'-5939', Length Size 62' 16" 4311' 9 5/8" 9533' 7" measured 9165'-9195', 6030'-6052', 9210'-9260' 6063'-6099' Cemented Measured depth True vertical depth 199 Sx AS I 104' 1100 Sx AS III & 4353' 360 Sx Class G; Top job performed w/120 sx AS I 469 Sx Class G 95 75' 250 Sx AS I Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55 EUE Tubing; Tail at 9081' MD Alaska Oil & Gas C.ns.'n C0mmis¢or~ Packers and SSSV (type and measured depth) Baker FHL Pkr @ 8937'; Baker FB-1 Pkr @ 9063'; Baker FVL SSSV @ 1853' Anchorage 13. Stimulation or cement squeeze summary Refracture A Sand Intervals Intervals treated (measured) 9165'-9195', 9210'-9260' Treatment description including volumes used and final pressure 273 BBL GW Pad; 173 BBL GW Slurry; 38M lbs Carbo-Lite in formation, FP -- 6500 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 333 263 19 780 112 Subsequent to operation 1269 847 73 900 490 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~ ~ Title Senior Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL ARCOAlaska, Inc · Subsidiary of Atlantic Richfield Company iPBDT TRACTOR REMARKS FIELD - DISTRICT- STATE OPERATION AT REPORT TIME C~o ,,~,P ~ e"'"r-~ WELL SERVICE REPORT IDAY~ iDATE ~ 1/-/_~- ~, ~ m:., ~- ' / Z.r. 2 / FY/ [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I Signed knots ARCO Alaska, Inc. Date: June 30, 1989 Transmittal #: 7501 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 C- 05 Kuparuk Well Pressure Report 4 - 23 - 8 9 Sand 'A' 3 C - 12 Kuparuk Well Pressure Report 4 - 23 - 8 9 Sand 'A' 3C-05 Sub-Surface Pressure Survey 4-23-89 #63940 3 C - 12 Sub-Surface Pressure Survey. 4 - 23 - 89 # 5 8231 3 A- 01 Kuparuk Fluid Level Report 6 - 2 7 - 8 9 Tubing 3A-07 Kuparuk Fluid Level Report 6-27-89 Tubing Receipt Acknowledged' AlaSka 0ii & Gas Cons, (;ommisoion - - :- ........................ D a t e' _ ...... ~?!2.0rage DISTRIBUTION: BP Chevron Uncoal Mobil State of Alaska D&M sssv ~5,~ GLM OV or GLV ! Fluid Level CC: O~ Engr. NSK l~lee Proa. Forem~n KUPARUK FLUID LEVEL REPORT Well Fluia Level Sho~ Down: .._..__ Ca~ing ~ Tubing CSQ Preu During Shot TBO Pres~ During Shot Reason For Shooting FL: To Oetermine Ogerating Valve Well Status: · On Continuoua QL Oget,~ng ¢S(3 I~ee~- GL Rate (If Availa~e)- _.=. On Intermittent GL _ On Time - Min. Off Time- Hr.__,_ Min. Delta Time From End (Df On Cycle =__...._ Min. _ N~GL Comments: ARCO Alaska, Inc. Date: February 9, 1989 Transmittal Ct: 7422 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 B - 1 3 Kuparuk Fluid Level Report 2 - 0 6 - 8 9 2 W - 0 1 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 2 X- 1 4 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 3 F- 1 5 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 3 A- 0 1 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 2 G- 0 6 Kuparuk Fluid Level Report 1 - 3 1-- 8 9 30-14 Kuparuk Well Pressure Report 1 0-25-89 Casing Casing Casing Tubing Tubing Tubing Amerada Receipt Acknowledged: Alask~, '~ Anchorage ........................... Date: ............ DISTRIBUTION' D&M State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Date: January 13, 1989 Transmittal #: 7408 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3A-01 ~ 3A-O 1 '~,-2W-O 1 '"'~-~ 2X- 14 '--3K-06 -.--3K-06 '" 3H-21 "--3F-16 '=="3K-06 ~ 2Z-01 KU )aruk Ku )aurk Ku3aruk Ku3aruk Ku3aruk Ku 3aruk Ku3aruk Ku'3aruk Ku'3aruk Kuapruk Fluid Level Report (2:15) I - 0 5- 8 9 Fluid Level Report (1015) 1-05-89 Fluid Level Report 1 - 0 5 ~ 8 9 Fluid Level Report 1 - 0 5- 8 9 Fluid Level Report 1 - 0 5 - 8 9 Fluid Level Report 1 2- 1 3- 8 8 Fluid Level Report 1 2- 1 3- 8 8 Fluid Level Report 1 2- 1 9- 8 8 Fluid Level Report 12-17-88 Fluid Level Report I 2- 1 8- 8 8 Casing Casing Casing Casing Casing Casing Casing Tubing Casing Tubing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron SAPC Unocal Mobil ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7362 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 0 3 Kuparuk Fluid Level Report I I - 1 I - 8 8 Casing 3 H - 1 8 Kuparuk Fluid Level Report I 1 - 1 1 - 8 8 Casing 3 A- 01 Kuparuk Fluid Level Report 1 1 - 2 3 8 8 Casing 3 A-0 1 Kuparuk Fluid Level Report 1 1 - 1 8 - 8 8 Casing 3 O- 0 2 Kuparuk Fluid Level Report 1 1 - 1 9 - 8 8 Casing 3 H- 2 2 Kuparuk Fluid Level Report 1 1 - 1 7 - 8 8 Tubing 3 H - 1 2 _Kuparuk Fluid Level Report 1 1 - 1 7 - 8 8 Tubing Receipt Acknowledged: DISTRIBUTION: D&M SAPC Chevron Mobil State of Alaska Unocal ARCO Alaska, Inc. Date: October 7, 1988 Transmittal #: 7314 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-02 Kuparuk Fluid Level Report(4:20) 1 0-02-88 ,3Q-02 Kuparuk Fluid Level Report(3:10) 1 0-02-88 2 D - 01 Kuparuk Fluid Level Report 1 0 - 0 2 - 8 8 '1 Y- 1 6 Kuparuk Fluid Level Report 1 0 - 0 2 - 8 8 $A-01 Kuparuk Fluid Level Report(3:55) 10-02-88 3A-01 Kuparuk Fluid Level Report(4:45) 10-02-88 1 F- 0 5 Kuparuk Fluid Level Report 1 0 - 0 4 - 8 8 I F- 0 8 Kuparuk Fluid Level Report 1 0 - 0 4 - 8 8 1 F-02 Kuparuk Well Pressure Report 9-30-88 Casing Casing Casing Casing Casing Casing Tubing Tubing Amerada ~Alaska Oil & Gas Cons. Commission Anchorage Receipt Acknowledged: ........................... Date: ......... DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC _-t ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7296 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 0 4 Kuparuk 3 B - 1 3 Kuparuk Fluid Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid / I D-08 Kuparuk Fluid - 0 3 Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid "/ 1E-06 ' Kuparuk Fluid Fluid Kuparuk k 1E-02 . Receipt Acknowledged: Level Report 9 - 06 - 88 Level Report 9 - 05 - 88 Level Report 9 o 05 - 88 Level Report 9 - 05 - 88 Level Report 9 - 01 - 88 Level Report 9 - 01 - 88 Level Report 8 - 31 - 88 Level Report 8 - 31 - 88 Level Report 8 - 31 - 88 Level Report 9 - 1 7- 88 Level Report 9 - 1 7 - 88 Casing Casing Casing Casing Casing Tubing Casing Casing Casing Casing Casing DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Post Office Bo 0360 Anchorage, Aia~a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal =5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: --~1R-14 CET/CEL ~1R-14 CET/CEL 2A-14 CET/CEL ~J~3A-1 CET/CEL -~f3A-2 CET/CEL -JJ-3A-3 CET/CEL --3A-15 CET/CEL ~-~3A-16 CET/CEL ~--3C-15 CET/CEL '-J~3C-16 CET/CEL '~J3F-1 CET/CEL ~...3F-10 .CET/CEL '-~-3F'11 CET/CEL ~3J-4 CET/CEL ~3J-6 CET/CEL ~3J-9 CET/CEL 10-12-85 Run =2 8600 10-13-85 Run =3 8550 10-02-85 Run #1 6795 10-01-85 Run #1 7550 10-01-85 Run #1 6680 10 01-85 Run ~ - ~1 6080 12-30-85 Run =2 6400 12-30-85 Run =2 7300 10-!5-85 Run ~1 5887 10-15-85 Run ~1 3995 10-!7-85 Run ~1 7000 12-19-85 Run ~1 5166 12-19-85 Run #1 6950 10-05-85 Run #1 6860 10-19-85 Run ~1 7000 12-18-85 Run #1 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 36 - 6678 REC"IV · Receipt Acknowledged: .~.--~/"~'~U'VD:~i~e~b'~-/ - _~ ....... // /~ Alas.kg Oil~ & Gas Cmr~. Commission. ' ~ ~K Drilling Vault(1 f~lm) ARCO Alask3, Inc. is a Subsidiary of Aflenli¢l:ilchfi~;dCompany ARCO Alaska, Inc. Post Office B~,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-1 Dear Mr. Chatterton: Enclosed is a copy of the 3A-1 Well History (completion details) to include with the Well Completion Report, dated 12/4/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L82 Enclosure cc: 3A-1 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas ComPany Daily wel'~History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fina! Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an officiaJ test is not required upon completion, report completion and representative test date. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting coat center code District IC°unty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ADL 25632 3A-1 Auth. or W.O. no. ~Title AFE AK0243 I Completion API 50-029-21412 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete A.R.Co. W.I. 56.24% Date 11/9/85 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our ' ~ Prior status if a W.O. ' 1430 hrs.~ Date and depth as of 8:00 a.m. 11/10/85 thru 11/11/85 11/12/85 Complete record for each day reported 7" @ 9575' 9485' PBTD, Prep to RIH w/3½" compl 10.2 ppg NaCl/NaBr Accept rig @ 1430 hfs, 11/9/85. NU & tst BOPE. RIH w/7" csg scrprs & 3½" tbg, C&C and filter brine, POH. RU Schl, perf w/4" gun, 4 SPF f/9210'-9260', & 9165'-9195'. Perf w/5" gun, 12 SPF f/9020'-9036'. Rn 6-1/8" gage ring & JB. RIH w/Bkr FB-1 pkr, set @ 9063' WLM, RD Schl. 7" @ 9575' 9485' PBTD, Operations suspended Diesel RIH w/3½" tbg. Set FHL pkr @ 8961. Tst tbg & ann. Displace to diesel. RR @ 2145 hrs, 11/11/85. ND/NU tree Note: SSSV @ 1876' FHL pkr @ 8961' FB-1 @ 9086' TT @ 9105' Old TO New TD Released rig Date 2145 hrs. Classifications (oil, gas, etc,) 0il Flowing Producing method I PB Depth 11 / ! tKind of rig 11/85 Type completio~ngle, dual, etc,) Single Official reservoir name(s) Kuparuk Sands 9485' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval iOil or gasTest time Production oiT on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and dis~ribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date . . -- ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchoi'age, Alaska 99510..0360 Telephone 907 276 i215 December 9, 1985 .~.lr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SA-! Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 3A-1. I have not yet received the Well History (completiOn details). When I do, I will forward a copy to you. if you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU12/L105 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Er_~. AND GAS CONSERVATION CO. ,IISSION WELL COMPLETION OR RECOMPLETION I EPORT AND LOG 1. Status of Well Classification of Service Well OIL dx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-186 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510-0360 50- 029-21412 ....... 9. Unit or Lease Name 4. Location of well at surface ~ LC)cATIONS~ 478' FSL, 736' FEL, Sec.7, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1522' FSL~ 129#' FEL, 5ec.17, T12N, RgE, UN Surf. '_---~ 3A-1 At Total Depth ~ 11. Field and Pool 1248' FSL~ 1003' FEL, Sec.17, T12N, RgE, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 72' RKB ADL 25632 ALK 2448 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/23/85 08/30/85 09/01/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9600'r, lD,6348'TVD 9485'MD,6263'TVD YES~[~ NO[]I 1876 feetMD 1550' (approx) 22. Type Electric or Other Logs Run D I L/SFL/LDT/CNL/Mi crol og/GR/SP/Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 199 sx AS I 9-5/8" 36.0# J-55 Surf 4353' 12-1/4" 1100 sx AS Ill & 360 s~ Class G Top job performed w/12( sx AS I 7" 26.0# J-55 Surf 9575' 8-1/2" 469 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9260' - 9210' 3-1/2" 9105' 8961' 9195' - 91 65' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9020' - 9036' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ., 27. N/A 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 IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. i24-HOUR RATE ~ 28. CORE DATA CCi: i Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch~.~,~ ~ ~f None Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and the well perforated 11/11/85. TEMP2/WC67 CONTINUED ON REVERSE SIDE Submit in duplicate .. 29. 30. ': ' ' · '..' ~. - r : : TESTS ~):oLoGjc'MARKERS' : ': - : FORMATION' :" · NAME , Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH 'GOR, and time of each phase. Top Kuparuk C 9016' 5923' N/A Base Kuparuk C 9038' 5939' Top Kuparuk A 9148' 6016' Base Kuparuk A 9316' 6139' 31. LIST OF ATTACHMENTS C, yrn~rn,ni~ F,,rve. y (7 ~n,nie.~) 32. I hereby certify that the foregoing is ~rue and correct to the best of my knowledge Signed (~ .~_/'~(_.~ ~,L~j Title Associate Engineer Date // - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, a~r injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and :24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RETURN TO: ARCO Alaska, Inc. Post Office B'6x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 *. ,.,~_..?;..;:..:*. ~:,_- ::. :. ,/ 'ARCO" ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 11-19 -85 TRANSMITTAL NO: 5453 TRANSMITTED HEREWITH ARE %'HE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE ~IGNED COPY OF THIS TKANS~iITTAL. OPEN HOLE LIS TAPES PLUS LI3TING/ SCHL/ ONE COPY OF EACH 3F-7 11-03-85 RUN $1 3456 · 0- 8045 · O~ ~-~ -- ~--~/xe z2 -~'~ ,zZ-~--~d ~45- 3C-13 10-26-85 RUN ~1 4793 0-9420 3A-8 10-30-85 RUN $1 3134 0-7117 3A-1 09-30-85 RUN $1 4331 0-9618 2A-8 10-29-85 RbN ~1 3392 5-8527 RECEIPT ACKNOWLEDGED: DIST~{iBUTION: BPAE DRILLING W. PASHER B. CUIqRIER L. JOHNbTON EXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEF~K J. RAThMELL "'- SOHIO UNION VAULT/ANO ARCO Alaska. Inc. is a Subsidiary of AllanlicRichlieldCompany ARCO Alaska, Inc. Post Office Box' 100360 Anchorage, Alaska 995i0~0360 Telephone 907 276 12!5 October 15, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ~,nchorage, ~..K 99501 SUBJECT' 3A-1 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3A-1. The bottomhole location, TVDs, geologic markers and tubing details, will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Associate Engineer JG/lt GRU11/L141 Enclosure ARCO Alaska. Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ; ALASKA L_ .... -AND GAS CONSERVATION CC,__ ¢ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-186 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21412 4. Location of well at surface 9. Unit or Lease Name 479' FSL, 735' FEL, Sec.7~ T12N, RgE, UN (Approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when Gyro is run. 3A-1 At Total Depth 11. Field and Pool To be submitted when Gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72' RKBJ ADL 25632 ALK 2448 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 116. No. of Completions 08/23/85 08/30/85 09/1/85t N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD): 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9600'MD 9485'MD YES [] NO [~X N/A feet MDI 1550' (approx) 22. Type Electric or Other Logs Run D I L/SFL/LDT/CNL/Mi crol og/GR/SP/Ca 1 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 199 sx AS I 9-5/8" 36.0# J-55 Surf 4353' 12-1/4" 1100 sx AS ill & 360 s> ~lass "G" Top job performed w/12( sx AS 7" 26.0# J-55 Surf 9575' 8-1/2" 469 sx Class "G" 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) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · ~iaska Oi~ & Gas ~ ~-,-.;, .... GRU121WC01 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ' .30. · . . ,GEOLOGIC-MAR'KERS !~' ' :'FORM/~TI(~N T-E'STs ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wl-;n Gyro is run N/A 31. LIST OF ATTACHMENTS W¢.l 1 Hi.~tnrv 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed____ ~l _//?/~/~_/ ~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO OII and Gas Company 4} Well History - Initial Report- Daily fnetru~tlona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally wor~ prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough IState Alaska North Slope. Borough Alaska Kuparuk River ADL 25632 3A-1 Auth. or W.O. no. little · - AFE AK0243 I Drill Field Parker 141 AP1 50-029-21412 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate JHour tPrior status if a W.O. Spudded 8/23/85' 1600 hrs. Date and depth aa of 8:00 a.m. 8/21/85 8/22/85 8/23/85 8/24/85 thru 8/26/85 ComlMete record for each day reported 16" @ 104' 0' (0'), Unstring Bridel Lns Move rig f/2A-16 to 3A-i 56.24% 16" @ 104' 0' (0'), RN on 3A-1 Rig'g UP 16" @ 104' 0' (0'), RU Floor Move derrick & pin, raise same. Set wind walls, load floor, set Matts & rails, NU 20" ann, hook-up diverter vlv & Ins, flow nipple & ins, RU floor. 9-5/8" @ 4353' 4367' (4263'), Cmt 9-5/8" Csg Wt. 9.4, PV 16, YP 8, PH 9.5, WL 17.2, Sol 5 Accept ri~ @ 0700 hrs, 8-23-85. Fin RU floor, PU Kelly, PU GO tools, BHA, chg upper kelly vlv, & tst. Spud @ 1600 hrs, 8-23-85. Kick-off @ 395', Dyna Dril to 1651', POOH, LDDP, PU new BHA, TIH, dril to 2254'. POOH, chg BHA, RIH drl to 2768', pmp pill, POOH, chg BHA. RIH wsh & ream to btm.. Drl 12¼" hole to 4367', TD f/surface. Circ, Hi-Vis, short trip, 25 std. Cut drl ln, POOH, LD BHA.- RU csg service, rn 103 its of 9-5/8", 36#, J-tt, HF-ERW, BTC csg. Land on FMC hgr, FS @ 4353', FC @ 4266'. Circ prior to cmt, RU Dowell, tst ins to 3000#. Drop btm plug, pmp 45 bbl wtr, mix 1100 sx AS III w/½ #/sx of cellophane. Drop middle plug, mix & pmp 360 sx of CL "G", w/2% S1, + 0.2% D46, mix @ 15.8 ppg. Drop plug, good returns 531', 5.2°,S53.7E, 530.86 TVD 6.16 VS, S3.95, E4.74 1160', 25 3°,S41 1E, 1133.76 TVD~ 174.98 VS, S116.85, E130.30 1470', 1898', 2219', 2705', 3345', 3669', 4040', 4327', The above is ~l~rect Si~ture ~X ~ 'X,~,~N,,,.~~OR W.S. CONGDON For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 33.3°,S48.6E, 1403.03 TVD, 327.97 VS, 46.2°,S47.1E, 1730.45 TVD, 602.63 VS, 54.9°,S48.3E, 1934.41TVD, 850.45 VS, 56°, S47.5E, 2207.44 TVD, 1252.47 VS 55.3°,S45.SE, 2569.15 TVD, 1780.44 VS 55.0°,544.2E, 2754.29 TVD, 2046.21VS 54.1o,s45.3E, 2969.47 TVD,- 2348.28 VS 53.3°,545.3E, 3139.38 TVD, 2579.52 VS S226.67, E237.01 S410.17, E441.52 S576.99, E624.85 ,S849.96, E920.03 ,S1212.82,E1303.53 ,S1401.32,E1491.05 ,S1615.96,E1703.82 ,S1778.66,E1868.23 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Atfach descriptioi3 of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska ICounty or Parish IState North Slope Borough Alaska ILease or Unit IWell no. ADL 25632 I 3A-1 Kuparuk River Date and depth as of 8:00 a.m. 8/27/85 8/28/85 8/29/85 8/30/85 Complete record for each day while drilling or workover in progress 9-5/8" @ 4353' 5025' (658'), Drl 8½" Hole Wt. 8.7, PV 7, YP 7, PH 10, WL 19.4, Sol 4 Pmp plug down w/rig pmp, bmp w/1500#, release press, floats held OK. ND ann, RIH into 16", & 9-5/8" ann, wsh cln. Perform Top Job, w/120 sx of AS I. LD 1", NU BOPE, tst to 3000#, PU BHA, RIH, tst csg to 150#. Drl out 10', new hole, rn leak-off w/8.7 ppg. POOH, PU turbine, RIH , turbine drl to 5025' · 4686',54.3°, S45.2E, 3351.41TVD, 2869.14 VS,S1982'61,E2073.97 9-5/8" @ 4353' 7030' (2005'), Turbine Drl'g Wt. 9.4, PV 12, Y? 7, PH 9.5, WL 10.6, Sol 7 Turbine drl to 5435', loss 1000 pmp press, check surface equip; OK, POOH. Found WO , POOH, LD, RIH w/bit. Correction & Turbine drl to 7030' · 5215', 55.2°'S46,7E, 3656.72 TVD, 3301.12 VS, S2282.98,E2384.47 6057', 53.6°,S47.3E, 4154.87 TVD, 3979.86 VS, S2745.24,E2881.52 6525', 53.4°,S46.7E, 4433.24 TVD, 4356.05 VS, S3001.81,E3156.66 9-5/8" @ 4353' 8636' (1606'), Turbine Drl'g Wt. 9.7, PV 9, YP 7, PH 9.0, WL 10.2, Sol 8 TD f/7071'-7816', correction rn f/7816'-7848'. Turbine drl f/7848'-8101', correction rn f/8101'-8148', Turbine drl f/8148'-8636'. 7058', 52.3°, S48.1E, 4755.12 TVD,4780.83 VS, S3289.36,E3469.36 7500', 54.4°, S49.7E, 5018.94 TVD,5135.13 VS, S3522.45,E3736.57 8240', 53.7°, S52.5E, 5446.83 TVD,5737.70 VS, S3910.43,E4199.00 9-5/8" @ 4353' 9424' (788'), Drl'g Wt. 10.2, PV 18, YP 17, PH 9.0, WL 6.0, Sol 11 Turbine dril f/8636'-8696', drop Eastman single shot, TOH f/new bit, retrv surv, LD Turbine, PU BHA, TIH w/new BHA. Broke circ @ 7700', ream to btm, drl f/8696'-9424'. 8625', 51.6°,S55.3E, 5680.39 TVD, 6041.23 VS, S4090.72,E4446.25 9116', 44.7°,S46.3E, 6007.78 TVD, 6405.40 VS, $4321.51,E4729.22 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test date. in blocks provided. The "Final Report" form may be used for reporting the entire operation Jf space ~s available. I Accounting State District Alaska Field cost center code I County or Parish North Slope Borough Lease or Unit Kuparuk River ADL 25632 Auth, or W.O. no. ~Title AFE AK0243 I Drill Parker 141 AP1 50-029-21412 Operator A.R.Co. W.I. ~otal number of wells (active or inactive) on this, ARCO Alaska, Inc. 56.24% Icost center prior to plugging and I J abandonment of this well Spudded or W.O. begun Date IHour Prior status if a W.O, Spudded 8/23/85 ~ 1600 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. Alaska JWell no. 3A-1 8/31/85 thru 9/03/85 7" @ 9575' 9485' PBTD, RR 10.2 Brine Drl f/9424'-9600'. C&C mud & hole, made 20 std. Pmp Hi-Vis sweep to cln hole, drop'd Eastman single shot, TOOH to log, cut drl in. FTOH, retrv surv, no correction SLM. RU SCHL, RIH, log w/DIL/SFL/LDT/CNL/MICROLOG/GR/SP/CAL to 9592' (WLM). Chg'd log'g tools to SCHL RFT, POOH, RD SCHL. TIH circ & work tight hole, made 20 std short trip. Work'd first 5 stds out tight hole, LD 14 jts DP, ream tight hole f/9223'-9600'. TOH, CBU, made 10 std short trip, pmp Hi-Vis sweep & spotted lube 106 pill. POOH, LD BHA, pulled wear ring, chg rams to 7", tst doors to 3000 psi. RU to rn 7" csg. Rn 228 jts, of 7", 26#, J-55, HF ERW, BTC csg, FS @ 9575', FC @ 9485'. C&C mud & hole. M&P 96 bbls CL "G", w/3% KC1, + 0.8% D-60, + .2% D-46 @ 15.8 ppg. Cln cmt lns, tst Ins to 3500 psi, pmp 60 bbls Dowell spacer 3000# ahead of cmt. Bmp plug w/3000 psi, CIP @ 2040 hrs, 9-1-85. Chg rams, install packoff & wellhead, tst packoff to 3000, RR @ 2400 hrs, 9-1-85. Old TO New TO Released rig Date 2400 hrs. Classifications (oil, gas, etc.) Oil I PB Depth 9/1/85 IKind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potenti'~l test data 9485' PBTD Rotary Well no. Date Reservoir Producing interval iOil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable i Effective date corrected The above is correct ~~ --- IDat~ ~ ITM ,r---~ ,,..'r ~. ........ ~ ...... ~0 %~, Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. UB. SURFACE DIRECTIONAL URVEY [~[UIDANCE I~ONTINUOUS I'~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED qA-] (~8' FST,. 7q6' FF, I,. S7. T12N. RqF,. TT~ KUPARUK. lq0BTH SLOPE. AI.ASKA . _ Jol~ Reference No. 70874 Loaae<l By: LESNIE Date ~,i.:? ii~-'~?: ~'-~ '~'i,?~ ~I~CTOBER-1985 ~ ~..:. .... Computed ay: CCT DIRECTIONAL SURVEY CIISTOMER LISTIN~ FOR ARCO ALASKA, INC, KUPARUK NL)DTH ,SDDP£oADAGKA SURVEY DATE~ 02-0CT-85 ~N~INEFR: I, ESNIE METHnD8 D~' COMDUTATIOi~ TODD bOC~?IO))= ?ANG~.CNTI~b- averaged deviation and azimuth INTEDPOLh?IONI LINEIR V~R?ICAL SECTION: HORTZ. DIS?, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 46 DEG 36 MIN EAST ARCO ALASKA, INC, 3A-1 KHPARtlK NORTH ST,OPE,At,ASKA COMPLJ?ATI~N DATE: INTFRPOI,A?ED VAI~UE$ FOR EVEN 100 TRUE SUB-SEA ~EASIIRED VERTICAL VERTTCAL DEPTH DFpTH DEPTH 0.00 0.00 -72,00 100.00 lO0.0n 28.0'0 ?00.00 1q9,99 127,9g 300.00 209.90 ~27,99 400.00 309,gB ~00.n0 409,8~ 427,89 600.00 599.35 ~27.35 700.00 697,84 625,84 800.00 705.16 72~,16 900.00 891..40 R19,40 1000,00 1100.00 1700.00 1300.00 1400,00 1500,00 1600,00 1700,00 1800.00 1000.00 986 21 1078 93 1169 54 1257 70 1344 06 1427 89 1508 61 15~6 53 1661,39 1732,61 1800 39 1865 10 i925 35 1981 65 ~0~7 40 2093,07 2149.36 ~20~.40 ~26 ~46 2317.64 2374 00 2430 70 2487 64 2544 53 ~601. 4~ 2658.6n ~715.89 2773 35 ~830i76 2888 45 2000.00 ,oo:!o 2~00 0 2300,00 240O 0 2soo:Oo 600,00 ~700,00 2800,00 2900.00 3000.00 3100.00 3200,00 3300.00 3400,00 3500.00 3600,00 3700,00 3800.00 3900.00 COURSF VERTICAL DEVIATION AZI~i.)TH S~CTION DEG MTN DFG MIN FEET 0 0 ~ 0 0 E 0.00 0 2] S ~5 11 W -0.18 0 16 $ 65 5~ F -0,42 0 30 S ~9 59 W 0.74 0 50 S ~8 27 F 0.61 4 n S 49 27 ~ 4.62 7 43 S 5~ 32 ~ 14.69 11 46 $ 51 57 E 31.69 14 26 S 51 q E 54.51 17 12 S 48 48 E 81.55 q14.21 1. O06 93 IO97:54 1185,70 1272.06 1355.09 1436,61 1514,~3 1,58g.39 166o.61 90 q $ 46 16 ~ 113.33 23 24 $ al 56 E 150.67 26 36 $ 41 1 E 19~,74 29 27 $ 42 2Y E 239.70 ]1 1~ S 46 6 E 790.05 34 45 S 48 g E 344,53 37 2] S 48 49 F 403,49 40 q $ 49 5 F 466,10 a] 0 $ 49 17 E 53~,30 46 11. $ 48 50 F 602,41 172~.39 1793.10 1853,35 190q,65 10b~.49 2021,07 2O7?.36 2133,49 218g,46 2245.64 48 2] ~ 48 36 E 675.86 51 lO S 48 11, E 752,04 54 40 S 48 2 E 831,80 2]02.00 2358,79 2415.64 2472.53 2520.44 2K86,60 2643,89 2701,35 2U5~,76 2~16.45 55 29 S.47 2] E 1494.01 55 23 S 46 58 E 1576.32 55 21 S 46 7 F 1658,58 55 17 $ 45 ]5 E !740 82, ~5 1.5 S 45 27 E 182],03 55 ] $ 45 28 E 1g05.06 55 3 S 45 30 E 1987,01 54 54 $ 45 lO K 2068,83 54 54 S 45 20 E 2150.70 54 34 $ 45 29 ~ 2232.35 IA-OCT-~5 PAGE DATE OF SURVEY{ 02-OCT-85 KELLY BUSHING EhEVATION{ ENGINEER{ LESNIE '/2,00 FT FEET OF MEASURED DEPTH DO~LEG RECTANGUbAR COORDINATES HORIZ,~ DEPARTURE SEVERITY NORTH/SOUTH EIST/WEST DEG/IO0 FEET FEET 0,00 0,28 2 6 3 8 2,70 4,39 3,09 3,08 2.46 ,32 ,48 2,71 2,62 2,92 2,57 2,54 3,5! 3,.10 0,58 0,66 0,69 0,40 0,50 0,26 0,36 0 51 0 77 0 0 20 0 25 o 0 .,g :II 0,00 N O, 19 O. 18 $ 1 05 S 1998 4928 10 90 S 9{. 24 $ 35 47 $ 52 9{. 8 0,00 E 0.42 W 0,75 W 0,67 W 1,05 W I 70 E 9 90 E 2 E 4~ 52 48 E 62 24 E DIST.,~ AZTMUTH FEET<...> DEG MIN 81,69 $ 49 38 74 O1 ~ 33 168 204 241 28O 321 364 410 81 E 42 75 17 ~ 403 ~! 466 55 ~ 532 6! 6O2 42 8 47 E 675 552 92 ~ 563 13 612 30 831 67{ 67 9~4 841 13 O! 896 90 980 56 E 1{28 88 1041 60 1411 1121 1222',52 1658 1236 1! 1340,13 1823 ,293 69 ~ 1398,60 ~ 1905 17 8 2351 10$ 1,457.10 ; 1987 }! 1408 56 i 1515,37 2068 1466 15 152] 49 $ KUP~RIYK CP~PUTATI~N DATE: t~-OCT=85 DATE OF SURYE¥I 02q, O~T-,86 KELbY BUSHING EI~EVATZONI 72,00 FT ENG~.NEERI bESN[E VERTTCAL DOGLEG SECTION SEVERITY NORTH/SOUTH EAST/~EST DZ~,' A~ ',INUTH FEET PEG/] O0 FEET FEET FEET' . PEG NZN .. 4000.00 ~946.67 2~74,67 54 12 4100.00 3005.49 2933,49 53 41 4?00.00 ]064.99 2992.99 53 26 4400:00 t1"3.9t 3111.93 ~3 50 4600.00 3301 15 3~29.15 54 22 4700 O0 ~3~9~35 3287,35 54 24 4800'00 ]4i7 50 3]45.50 54 37 4900:00 ]475:41 3403.41 54 41 5000,00 3533,13 3401,13 54 5! 51.00,00 3590,50 3518,50 55 10 5~00.00 3647.50 3575.50 55 14 5~00,00 ]704 3~ ]63?.38 55 2~ 5400.00 3761 28 ]68q,~8 55 4 5500.00 3819 11 3747.11 54 6 5600.00 3878 59 3~06,52 5~ 26 5700,00 3938 01 3866,01 53 27 5800.00 3997 60 :}925.~0 K3 2~ 5qO0.O0 4057 26 3q85.~6 53 lq 6000 oo 411.6 87 4n44.87 53 3~ 6100:00 4176:06 410~.06 5] 5~ 6200.00 4234 86 4,67.86 53 57 00.00 4293 8~ 4721..82 53 47 6400.00 4353 0~ 4~81,02 53 37 6500 00 4412 45 4340.45 K3 23 6600[00 4472 17 4400.17 53 15 6700.00 4532 22 4450,~2 53 1 6800.00 4592.4~ 4~20.43 52 55 6900.00 4652.58 4580.58 53 ~ 7000.00 4712.8g 4640.89 52 43 7100.00 4773.56 4701.56 52 45 7~00.00 4833.84 4761..84 53 ~ 7]00.00 48~3 27 4821.97 K3 54 7400.00 4951 82 4870.82 54 25 7500.00 5009 96 4937.96 K4 23 7~00.00 5068 04 4996,04 54 49 7700.00 5125 14 5053,14 55 30 7800.00 5181 29 5109.29 55 5~ 7900.00 5237 55 5165.55 55 53 $ 45 2R E 2313.64 S 45 2R E 2394.50 $ 45 3R E 2474.86 $ 45 47 F 2555.20 $ 46 12 E 2635.63 S 46 1~ E 2716.53 S 46 31 ~ 2797.68 $ 46 44 E 2878,~9 $ 46 51 K 2960.35 $ 46 57 F 3041.88 a7 0 E 3123.53 47 0 ~ 3205.44 4'1 g ~ 3287.60 47 13 ~ 3369.85 47 17 ~ 3452.07 47 34 ~ 3533.64 47 14 E 3614.07 47 19 E 3694.44 47 33 E 3774.74 47 44 E 3854.98 $ 47 40 E 3935.26 $ 47 40 F 4015 84 $ 47 41 E 4096:72 S 47 41 E 4177.47 S 47 40 E 4~58.~5 S 47 49 ~ 4]38.46 $ 47 47 $ 4418.65 $ 47 5~ F 4498.59 S 47 57 ~ 4578,41 S 48 4 E 4658.28 $ 48 12 E 4739.01 S 48 33 E 4817.47 S 49 1 ~ 4897.20 S 49 27 E 4977.53 S 49 41. E 5058.49 $ 49 31 ~ 5139.74 $ 49 37 E 5221.04 $ 49 58 ~ 5]03.00 S 50 16 E 5385.59 S 50 50 E 5468.07 0.21 0.52 0,15 0.31 0 69 0!45 0 2~ 0.12 0,23 0,26 0,37 0.55 0 25 0 11 ! 64 0 30 0 13 0 3! 0 28 0 28 0 48 0 21 0 20 0 10 0 34 0 50 0 08 0 20 0 31, 0,37 0,61 6 0,12 0,87 0'$0 0,65 0,85 247 { 46 1749 61 i805 46 1920,14 26 "$ 46 1861 39 1978.59 19~7 35 2037 36 1973 17 ' 2879,00: 'S 4~ 2028 86 $ 2155,80 2910,~6 2084 55 S 2215.34 E 3041,89 S 4¢ 2140.'26 S ~275 03 E ~196.13 S 2334 69 , 81~ 94 E ;~ ~ $ 4~4544 E 36~ 46 45 !! ,' ,, 46 4~ ]1 ; 177 46 $0 85~ 01 ~ 46 $1 i 65 , 2690 88 S 2872 2744 2 99 2~53 2907 2961 3015 3069 12 S 29 805110 65 S 3229 ~3 S 3298 88 $ 3348 31S 3407 02 E 3935 4O E 4O 16 E 4! 9} ~ 4418 g 4498 21, g 4578 60 E 4658 54 ~S [ 12 S 46 $5 g 54 46 S6 69 S 52 S 46 40 S 47 O6 3492 3545 3704 ]I ~ 3467 3526 3647 94 S ~709 67 S 50 S 3833 49 $ 3895 54 { 08 8 4023 00 E 4738 40 4817 48 ~ 4897 3S g 4977 5058 1E 522! ~2 E 5303 21E 5]96 04 E 5468 62 ~ g 47 55 $ E TRUR SUR-SEA COURSF MEASURED V~RT1CAI, VERTICAL DEVIATION ATI~IJTH DEPTH DFPTH DEPTH DEG MIN DEG HIN INTERPOLATED vAT.UES FOR EVEN 100 FEET OF MEASURED DEPTH ARCO AbASKA, TNC. 3A-1 KI1PARIIK COMPUTATION DATE: 18-0CT-85 PAGE DATE OF SURVEY{ 02-0CT-85 KEL4Y BUSHZNGE4EVATION{ 72'.oo rT ENGINEERI bESNIE 1NTERPOI.A?ED VA[.UFS FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUm-SEA COURSE VERTTCAb DOCbEG RECTANGUbAR COORDINA~E$ ~E~$I,'RED VERTICAL VE"TTC~b DEVTATI.N AZI.UTH SECTION SEVERITY NORTH/SOUTH E'ST/WE$. DEPT. DEPTH DEPT. DEG M,N DFG MTN FEET DEG/,O0 FEET , I · · · 8~00 O0 5407 6~ 5)35 53 5~ $ 53 15 ~ ~ · 8400 O0 ~525 35 5453 53 20 S 53 52 ~ 5~74 8600 O0 5646 92 5574 51 4' $ 54 41 6031,$~ ~ ~9 ~ 05 ~ ~ ~6·92 48 8700'00 '709'875637: 495R $ 545g ~ 610". ~·50. ·26 ~ 6'10.~96033'4' 4747 5~'53 8800' O0 5775' 61 5703. 47 59 S 52 3~ ~ 6183 ~[~. 34 .85 6185.5! ' ' . 48 5 · , , . .. · 6259,0 9000.00 5912.14 5~40.14 46 7 00.00 5982 16 5910.16 44 49 ~00.00 6053 81 5981,8! 43 44 9300 O0 6~26 73 6054.73 42 35 9400:00 6200 75 612~,75 42 28 9500,00 6274 50 620?.50 42 28 9600,o0 6348 25 6~76,25 422~ 48 3 E b129.32 47 40 E b400.71 4'7 34 g 6470,44 47 11E 6538'86 45 4~ ~ ~606,08 45 41 E 6673,6! 45 4! E 6741'13 1 29 1 08 1 43 0 O0 0 O0 0 O0 42 4322 4369 4415 4462 4509 87 S 4713,07 E 6331.50 $ 48 6 E 87 S 4765,95 ~ 6402,~ 6 S 48,7.48 E 6472. 4 S 4 $ 4~ E 8609 $ 4867.93 E 6541.07 S 4, ~ ~ 39 8 49,6.66 E 6608.~? S 48 4 E 56 S 4964.99 E 6675,?,5 S 48 3 E 7] 85013.33 ~ 6743'23 $ 48 I E. ARCO ALASKA, KIIpARIIK NORTH SLOPE,ALAAKA TRUF SUR-SEA MEASURFD V~RTICA[, VERTYCAL DEVIATION AZIMUTIi DEPTH DFP?H DEPTH DEG MTN DEG MTN COMPUTATION ~TE: 18-0CT-85 DATE OF SURVEY{ 02-OCT-85 KELLY BUSHYN~ ~EVAT~ONI ENG~N~ERI LESNIE I.TFRPO~,ATED VA[,UES FOR EVE. 1000 FEET OF .~ASURED DEPT VE~TTCAL DO~LEG SECTION SEVERITY 0.00 0 O0 -72 O0 0 0 1000.00 9fl6 21 014 ~1 ~0 g 2nO0 no 18n0 30 1,28 ~9 48 )000 O0 2374 O0 2)02O0 55 4000 O0 2946 67 2~74 6~ 54 5000 O0 ~533 13 3461,{3 54 51 6000 O0 4116.87 4044,87 53 33 7000.00 4712.8q ~640,89 52 8000.00 5203.4n 5~21.40 55 58 9000.00 5912.14 5840,14 46 FEET OEG/100 ~ 0 0 ~ 0.00 0.00 S 46 16 ~ 113.]3 4.39 S 48 36 E 67~.86 2,54 $ 47 23 E 1494.0! 0.51 $ 45 2fl ~ 2113.64 0 21 $ 47 n ~ 3123.53 0:]~ S 47 40 E 3935.~6 O,2fl S 48 ~ E 4718.01 0,3? $ 51 11 E 5550.77 0,52 S 48 3 ~ 6329,32 1,29 PAGE 4 72*00 RECTANGULAR COORD~NATES_HORI~, DEPARTUR~ EAST/WEST O~ ,,'~ NOR?H/SOUTH ' {~' AZZMUTH FEET FEET Fi .:,.'. DEG MIN : .,1,, , 89 46 , 75 3 , . 4 ,{ {. 42~7,87 47i],07 . 0 S 49 :'. E ARCO AI,ASKA. TNCo 3~-1 Kt}D~RITK T~U~ SUR-SEA COURSF MERSUR~D VFR?ICA[, VERTICRL DEVIATION AZIMUTH DEPTH DFPTH DEPTH D~G MIN DFG ~TN PAGE: COMPUTATION DAT~: I~-DCT-~5 DATE OF SURYE¥1 02-OC~-85 KELbY BUSHTN~ EbEVATIONI ENG~NEERI LESNZE INTERPOLATED VALUFS F~R EVEN ~00 FEET OF SUR-SEA DEPTH VERTTC~L DO,bEG RECTANGULAR COORDINATES ND~I~,,DEPAR~DN~ S~CTION SEVERITY NORTH/SOUTH EAST/WEST D~~,' A~ZMU~H FEET DE~/100 FEET FEET ~~" :. P~ NIN o oo ().on -7~.oo o o ~ o o F 7~00 72,00 0,00 0 25 S 7~ 2~ W 172.01 172.00 ]00.00 0 ~ N 35 O W 272.01 2?2.00 ~00.00 0 36 ~ 4 35 ~ 377.01 372.00 300.00 0 34 S 7 46 W 472,o6 472,00 400,00 3 2 S 46 ~ E ~72,42 572,00 500,00 6 ]4 S 55 16 F 67],61 672,00 600,00 ~0. 49 ~ ~2 15 F 776,11 772,00 700,00 13 54 ~ ~ 26 ~ 870,74 872,00 B00,00 ~6 37 $ 49 16 E 0.00 -0.06 -0.45 2.86 li.15 26.36 48.67 75.75 q84.q2 972.00 000.O0 19 38 1092.44 1072.00 1000.00 73 lO 1202.75 i172.00 ilOO.O0 ?6 4~ 1316.44 1272.00 1200.00 ~9 49 1432.92 1372.00 1]OO.O0 32 23 1554.28 1472 OO 1400.00 ]6 14 168i.02 1572 00 l~0n.oo 39 40 181a.52 1672 00 1600.00 43 27 1957.70 1.772 Oh 1700.00 47 26 2210.07 ~872 00 1~00.O0 51 ]3 S 46 50 E 10B,28 S 42 7 E !.47,66 S 41 2 E 193,06 $ 42 48 ~ 247,79 s 46 52 E 307.46 S 48 50 E ]76.14 $ 48 56 E 45].90 S 49 ~4 E 542 $ 48 48 ~ 644:52 8 48 g E 760.58 2282,?0 1972 00 lO00,O0 55 57 2462,25 2072 00 2noo,oo 56 10 640.32 2172 00 210n.00 ~5 51. ]818.76 2272 O0 2200.00 55 ~q96.46 ~372 00 2300.00 55 20 3172.48 2472 O0 2400.00 55 21 ]]4~.~6 2572 O0 2500.00 55 352].37 2672.00 2600.00 55 ]69?.66 2772.00 2TO0.O0 54 54 3871.60 9872.00 2800.00 54 S 47 53 E 900.'06 S 47 52 ~ 1049.15 S 47 40 ~ 1196.46 $ 47 3g E 1344 21 ~ 47 23 E 1491:09 S 46 18 ~ 1635.94 S 45 28 E 1780.49 S 45 ]l E 1924.20 S 45 19 E 2066.92 S 45 26 F 2209.~1 4043.76 2972.00 2900.00 54 0 4211.96 ]072.00 3000 O0 53 27 4379.79 ~172.00 3100:00 53 43 4550.00 3272.00 ]200'00 54 15 472~.73 3372 O0 3300.00 54 2K 3472:00 3400.00 54 40 4894.10 5067.67 3572.00 3KO0.O0 55 ~ 5243.04 3672 O0 3600.00 55 10 541~.65 3772:00 3700.00 54 56 5589.07 3872.00 3RO0.O0 ~3 25 0,00 0,54 1.16 1.05 2 47 4 6O 4 0~ 2 2] 3.03 3.98 2.95 3.08 2.23 3,73 2 46 2 58 2 98 2 O4 0 76 0 52 0 19 0 28 0 50 0 59 0 06 017 051 0 42 0.00 0.15 0.16 0.76 ,?0 .75 8.84 17,94 ]1.82 49.08 0,00 E O~ W 0.58 W I 16 W 0 39 E 6 99 E I 3t E 57 84 E 438 515 02 S 140 36 S 395 52 $ 47 53 $ 55~ ?3'00 r~. 608 7O 9O? ~00~ 1 07 1.407 84 8 663 94 $ 77 85 8 88{ 34 S 992 48 S 1 28 S 1309 10 $ 141~ 21 8 i5 26 S i~i5 i!E 900 gE 1049 E 163~ 26 £ 1924 ot~ 2066 24 £ 2209 2~ ~ 93 07 E 542 39 E 644 28 E 760 ]605. 'i!~ 2348,73 46 53 ,oo.8 i Il i ,9 889. . ~ 2757. 2896. 0~ 36 0'1. 82 3037. ~ ~! 04 3467, '.o, [ S 45 27 E 2348.70 S 45 30 E 2484.30 S 4b q E 26i9 32 S 46 24 E 2757:06 S 46 46 E 2896.67 S 46 57 E 3037,06 S 46 50 F 3178.93 S 47 10 F 3322.98 $ 47 21 E 3467.33 $ 4,7 14 F 3605.30 ARCO AbAGKA, TNt. KIIPARUK NORTH 5[.OPE,A[,A~KA cn~Pu~AT]nN DATR: 1B-OCT-~5 DAT£ O~ $URVE¥I 02-0CT-85 KgLbY ~USHTNG EbEVATIONI 72.00 ENGTNEERI INTERPOLATED VALUES FOR EVEN 100 FEET OF SUF-$EA DEPTH TRU~ ~UR-SEA C~URS~ VgRTTCAL ~U~bRG R~CTANGUbRR COORDINATE& HORaCe' DEPARTUR~ MER&I,IR~D V~R~ICAL VERT~CRb DEVTATION AZI~UTH $~CT~O~ SEVERITY NORTH/SOUTH ER$T/~E$T P~STe'? R~MUTH ~EPTH DEPTH DEPTH DEG ~N DFG MTN FEET DEG/tO0 FEET FEET ~T' PEG MXM 2827,26 E ~81"'. :i::!"': 46 51 E ~740.90 3029.09 E 4147,~0 ..':.'~ 46 54 E ~ 2927.51E 40t0~4.":S 46 53 E 833,38 925.08 3129,79 E 4283,,.e1 $ 46 S6 E 015,49 o 3229,55 E 44t8,5t S 46 57 E 3 193,54S 3426,82 ~ 4684,~ & 47 J. ' i281,02 ~524,86 E 4815,57 S 47 ~ 368,5! ~ 3625,30 E 4948.70 $ 47 6 ~ 5757.05 3972 O0 3qO0.O0 53 24 5924.64 4072:00 4000,00 5322 6093.12 4172'00 4100,0.0 53 51 6~63.~4 4272.0o 4~00,00 53 51 6432.00 4372.00 4~00,00 53 35 6599.71 4472.00 4400.00' 53 15 6766,1.0 4572.00 4500,00 52 57 6932 31 4672 O~ 4600,00 52 57 7o97~42 4772~00 4700,00 52 44 7263.q9 4872'00 4800,00 53 38 S 47 26 F 374~.26 0.27 ~ 47 42 ~ 3874.73 0,47 $ 47 40 E 4010.29 0.41 $ 47 43 E 4147,64 0,18 S 47 43 F 4~83.81 0,25 S 47 47 F 4418,42 0,50 S 47 53 E 4551.~7 0.14 S 48 6 E 4684,08 0,43 $ 48 32 F 4815.42 0,62 S 49 18 F 4948.51 0,9~ 7434.77 4972,00 4900.00 54 27 7606.86 5072.00 5000,00 54 59 7783 38 5172.00 5100,00 55 54 7961 71 5272 00 5200,O0 56 5 8139 34 5372 00 5~00,00 54 25 8]09 42 5472 O0 5400,00 54 6 8477 76 5572 00 5500.00 52 47 8640,29 5672 O0 5600.00 51 q 8794.62 5772 00 5700,00 48 4 8941,90 5872.00 5800.00 46 2q 9085 66 5972 00 5000.00 45 2 9225 11 6072 00 6000,00 43 20 936123 6172 O0 610o,00 42 1.~ 9496 61 6272 O0 6200,00 42 28 9600 O0 6348 25 6276,25 42 28 $ 49 38 E 5086.76 $ 4938 E 5226.63 S 50 13 E 5371.84 S ~1 3 E 5519,12 $ 52 31 E 5665.36 S 5342 E 5801.98 S 54 IA F 5936,31 $ 54 5R F b063,15 $ 52 46 E 6179,54 $ 49 7 E b287.]4 S 47 41 E 6390.59 $ 47 33 E 6487,75 $ 46 14 r 6580,09 S 45 41 E 6671.32 $ 45 41 E 674~.~3 0 42 0 88 0 51 0 5O 2 5O 0 09 1,16 1,74 2,61 2,12 1 70 I 02 O0 0 O0 345826 S 373070 g 5087 O! S 4710 g 354913 S 383728 g.525 3642 72 $ 3948 62 3736 3! S 4062 83 3909 3989 4063 4131 42 O0 75 $ 4288 54 $ 4397 4 $ 4502 1 $ 4597 O1 $ 4681 05 E 6064 68 £ 6181 65 £ 6289 53 $ 48 51 $ 48 g ii: 4269 4334 4397 4460 4509 ARCO ~bASKA, TNC. 3~-1 'KI~P~EUK NORTH $[.UPE,Ar,A~KA ~OP KIlP~RtlK C B~SF KUPARUK C ~OP KIIP~RI, IK A B~S~ KUPARUK A PBT~ TO COMPUTATInN DATE: I~=OCT-R5 nA?E OF SURVEY1 02-0CT-85 KELEY 6USHING Eb£VATIONI 72,00 FT' ENGINEER{ INTFRPOI,ATED VAf,UF$ ~'BR CHOSEN HORIZONS MEASURED DEPTH BEt,OW ~8 g016.00 OOlS,00 0148.00 g3~6 O0 9485~On 0600.00 ORIGIN: 478' FSL, 736' TVD FRO" KB SUB-SEA 5q23.23 5851,23 5q38.56 5866,56 6016.42 5944.4~ 6t38.53 6066,53 6263.44 6191,44 b348.~5 6276.25 KI]P~RI{K NORTH S[,OPE.A[,A~KA ~ARK~R TDP KUPARIIK C B~SE KUPARUK C TOP EUPARUK A BASF KUPAgUK ~ COMPUSA?ION DAT~: M~ASURED DEPTH BE[OW KB 90~6.00 9038 O0 q148 O0 9316 O0 9495 O0 9600 O0 IS-OCT-R5 SUMMARY FROM 5923, 5938, 6016, 6138, 6~63. 6348. PAOE DATE OF SURVEY! 02-0C~'~5 K£LL¥ BUSHING E~EVA~ION ENGTN£ERI SURFAC~ LOCA~XON RIGIN= 478' FSL, 736' FEI,. SEC 7. ~ 2M. RgE. UM TVD' R£CTANGU~AR,i,~D~D~#A~8 KB SUB SEA NORTH/8OUTH...'EA$?/W~$T 56 5866 56 42' , 42 5944 42 4 , 53 6066 53 43 6, ' 44 6191 44 4455.~ 25 6276 25 4509, ~2,00 F~ FINAl, M~ASURED D£DTH 9600.00 WEI, L LOCATIOM TRU~ VERTICAl, D~PTH 034~,25 AT TD: SUB-$ER VERTICAL DEPT~ 6276,25 HORTZONTAb DEPARTURE DISTANCE AZIMUTH FEET DEG M~N 6743.93 $ 48 I E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A- 1 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 02-0CT-85 REFERENCE 0000?08?4 WELL NAME: 3A- 1 SURFACE LOCATION: 4'o FSL, 736' FEL, S7, T12N, R9E, ..... HORIZONTAL PROJECTION NO~TH 2000 REF 0000'70874 1000 -lOOO -2000 -3000 -4000 -5000 -6000 - 1000 ~EST 1/1131313 IN/FT -+?--+~-i--~+? ..... ~--?~-+-t-+-~--?-~.--*-+--+--+-+-+-?.-.~-+-,:-. -+--?-.+-~--+.-?.-~..+--?-. -*+-~-+-~.+-?~---+-..?--~-.-?--.-~-.~..*~---~..~..-~-.-~--+..~...~ ....... ~...~...~..+..;..~..+..~...~...z..~.~_.~._~_~...~.. ~-"~-~-~*-.-+4--~-+--F++-'-.+*+-~'"~'-+.~-~-'+'-~--- "+'+-+-+~-~--~-.+--~ ..... ~-+...~...~..4...~...~..?+.~-~...~".~...?..~.~...~.~..+..~4...~..+~.+...~...~..+.+..~.~.+.~...~...~..4...~..+.. · .,-+.+.~..~ -+-+~.+.L.~..+-+.+....-~-+-+..~ ..... ~.--?.+--+- -m.:--P-~-~-+-e-?-*? ---~--.~--~---~-~-..~-.+-~-+-.+-+--+--*~--~--.~--~-. ---~--~-=---~-.+--~-.-*--~--.~--~-~.-~-;--~.+--~-~.~..-~-.- · 4...;...~.~..~.-b..;...:-,..~...*.-.;...J..4...~---~..-~ ...... ~.-.;...~...t--L.L.~..4---~.-.,...*.--~..~.4 ...... m;...;...~ ...... ;...;...~..,...i...~ ....... ~.--;.-~-.;-.-~..-~..4..-;...?..;...;...; ...... ;-..L~.L-~...L-L.~..-;.--J-..~..4...L.L.i...~...,._L.L. -~-L.L~-L4.... ~-L.L..;.4..i..z.~;...-.;.-;..-L-~-~..~...L.~-L.,..L.~*-L.L.~..-g.~--;.--~ ..... L.~.*~"*~j"~.*L`L~L`j~`~~.~.~.~"~;.~.~"L~;~L.~;"~.L~L~L~`~.~.~.~ -.~--4-.F+-~-;-..~.+--;---]-.;-;-.-;...;.-]4---;---L-;- 4...;.-.;...L.i--.;..~.g4 ...... ;..~4...~4.-&-~.~-; ..... ~..4.4.-~..g~.~.4.-t-~..L.~...:+4...L.L.} ....... ~...L4_;...~.4_.L&.~...4._.L&.g~...~.4...L..&_ ..~...;...~..~._~..L.~...~ .4.,, _.; ...... L..L.,_4..~..;..~.. -.~..~4.-L.L.L.L.; ...... ;._L2..&~.L.L.L-L...-L4..~..L.L4~.~4.-;.4-g.L~..,...L.i..:.2...: ...L.L&4-..t...L2...L~...4...'- .:.2..4.~ L.,_i..:_. 4.4.4...;--.F.;-4...L.~F ~ ....... L.I...;..4..&4 ...... ;.4...;.4.-.~...;...~.4...~ ...... ;..;4...;.~-&~..L.; ........ ;...;..;-..F~.4...~.4-.L~--.~.;4~..;...L.......;.-=&4-.*4-g-.~-4.... 4...LL&.L.~_~4.~_ ................... ~ ............... / ............................................................................................................ ~ ................... ~ ............................................. t ~-;--N-.+-.~--?-;q---~ ~--;-4-4.4-+.-~--.F.;---.-.4---~-4-.4..-,--~..~-+--;---.--4-;-~j--~-;--.-4--4--~--F.J-~-~.-N--F~-;-;-.F-b~-4--4-?-~ ~4-~-~4--;--~.~-- _~_~.;..z4..~...;..~.&_ · -+~-.~--+--t q.-+.-F.+...~--~-4-..~.--~...f.--~---~---;-..;---..-4-4.+---~---~---~--+--~-.-~ ..... ?;--.-~..~-+-+-~----~-~ ....... ~.-.F-+--~---t-4---~--~-.-F-+--~---F--~--~--4--4.-~-.4---~--~--~.--t.-+--~.-~.~--F-4.-.~ ....... ;-..~-~4...;...~-~-.-~ .... ~"f"f"?+'f H'"'~ ..... f-~-; f"u--: .... f"f .... t ....... ;'"t-'t '?'~' ? '; .... ~"f";"'~"t'"?":' ,'t .... ~-"~'"?"-?~' ~"t ...... ~'--~'"~'-c":'-'k-:'"'~'-:':',' t ........ :'-"f+'f"~.' '~-"~ ....... : -f'r"t-'~'-t--f-f-'~ ...;...~...~ .F~...~..;...~...;.,, ~.~..~...~-..~..+ ...... ~.. ~.. N.. ~--.~..F~..; ..... ~---N-..N-.-N---~- ~ ...... ~..F~..+-i---~--~---~--FJ-.~-.;-..~q..-i.--~.. FN..-J~. ~.4..N.-~..]--.N ...... ~---~-4--;-;--~-.-+---~-.~--.~-- '"f"~ "~"f' +--'~'"';' ~'":- .... f~u'~ J"~"~"'~'"f ..... ?"f" f' ~" f'"?"?"f"f ..... f"f-'~'"?'J"+"?P-f ...... f..f...~b.f...~...?..+..f.q...j-f..f..+.+...~..~..~4..+..~..+.4"+.+..P+..~.+..?...~..+..?+...:...~.~+.+.+..+ .... '~'"F'F'fTF+";'"7'' ."?'u~T~ ~'~ ~ "'F'?'r"TTT'T~"!-- "T"F~-TT"~-T-!-' '-r'T"r'F'F~-T~J~'F~'T'F~+'T'' ~F~-F~i -;--'f'T'~?~?- ...~...~.-.~...-FF~...~.-;.-.~......-,.~. ~...LI~..~..,...~-u.--;..-;-.-N-.~.~...~.--~..~.4...u~...N...~..~..+.q...~...:..;4...i.~x.~...N.~F;...:...~.~...~.~.~.~.;.~.; ~ 44.~..;...~-6.~..~..~.,.-~-.+..;.--~--z..F~ ::::::::::::::::::::::::::::::::::::::: ::::~:::~:::~:::~::~:~X:~ :::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ..~.-.;...~.. ~..t.4. :...;...; ....... F..:..~. ~. ,...~ ~.~ ;~ ~:- 4-.-;- -; ...... ~...: ....... ~.-L4..~.-N...J...F.~..-.;...;-4---~-.N..-~---'-4--4-4--N-- ---N----; ....... F4--~4..+-F-;.4..4--.~-F.N-..~..I.-.F.F.~...~.~ : . . . ]~ ~ ~ , , ; . l . i , ; I~._ . : : ; ~ ; ~ : : ~ . ~ ; ~ ~ : i ' . j ; , ' ;: . ~ I : ~ i ~ ....... ...... :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::: ::::::::::::::::::::::: -'T'T"FT'Y~''7'''r'~ ....... r-'"?-r"[~~~"'~"~'~"T-~S~'~"~'FTTT'r~'-FT'~'"r"r"? ...... *-T"TZ- -T'-F'TT'T'~T"t'T'' ''T''T~'TTT~'T''F' : ' I ~ ' ~ ' I ' ' ' ~ . · : ' - : '~ : : ' i ; ' ~ ' : ' · : I ' : : ' : ~ : ' 1 : ' : : ; ; : : ' : ; ' ' : ...~...~...;...~...,..~ ....... ~...~......~...:..+..~...,...~....m.~ ...... ~..-~--~.--~--4..-J-..~Y ~q..-~--+.+..z..~...~..+..J...~..-z-.~-.-~.-+..~.-.~ ....... ;---...~.;-..~.;..+..~.x-..~.-~-. -~..-~...~..-~.-~.+..-~..~...~ ....... ~..+.~..+.+-.~ ....... ~..4..] · --f--f-.H--.f-.~-. ~-.-~-.-:-.. -.-~-+.f--~..-f.-~-..~--.-~. .-~ ..... ~---H-+.f--~.-+~-.+-fff-~---I.-+-f--~.--H-+-+++-N--~.-.;-~-)-~--~-=++S~S~- -.~-~.-~ff-f d--+-~+-~--~m+-~ '"T"t"'T"?'"t ' r"";' '~'"; ...... ~'"~'"T" ;'"t ~'7''' :" -' .'" ~'" F"T-'F'"; ¥'":' q~"~ %~" 7'"T"$ "F'T'"T"7 "~-I'"'?';'"T"T "t'"'."'";'"?"7"T"3"'T"7 'T"i'" ;'"?'"T"T- "~-'?~T'T"T"T"T'";"' ""r"~'"'T'-7'"t'"T"'~'-'s'"T'' · ..4...~..~...~. L. ;...~ ........... ~...~---; ...... i.-.~ ............... ~-.-;---~---~--.-- .~.-.~---~.--~-.. ~--~---~-.-~--. ---b.-s.--~---~-J ....... ~---~---~---~---4 ....... ~-..~-- ~---~---;-- ~--~---~.--~- .¢...~---~.- -..~---~-~-~--~...~--=---~---~--- ,-~---~---~---~-~.- ~.--¢.--~- -~..- · ..?.~-.~-...~-.-~...t..: t ...... : .... ?.~- f......., .. : ~...:...?.t.......:. ~- ..;..-~ ....... t-.~...~...:..t- ~.-,~---?---:-.-;-.-?.,*---?-.?.-~.-- ...?..?..~.~..........._~....,...t ...... t.. ?-?.~.- .-.~--,? ..?.-~-..i---f-..~...~....~..~...~.-..-t...~..- -;..4...;...; .... ...... ~ ~...;...;.,.~ ' ............ ........... L..~..,.~...~...L.,; .......................... ;-.L--;.-g-.g.. ~' .......... .~~;-4 .... : -~,.~-..,...:-. ....... .-.&.~.4.-!...~ ~, : ~' .~---,~-~ -~.-~--~..~.-- j.-4--.-~---: .... ; ' ~ ...... ..... ~---~--; --;--~-~ ---;---~.--~ ............ ..iS.4...LLL.L;...L ..~...Li..L.LL.~ ...... z.L.;...LLL.M...L;...L~..~..Lg.;.+..L~....~..L~..N.4.~q...~...L.;.~...I.4..L..~.~..I~.L.~.~Li..LL~..~ .-,.-.,...~..~.--,..,...~...~ ..... :.: t..: . t ~ ~, .... H~ .... ~ ~ ~ ...~.. ~ ............. ; ............................. f..~ ............................. ~ ................................... ~ .................. ~., .~ ................................. , .................. ~ .............. ,..? ......... ~...._+ ....... ~,-.~+- .. L.~. ~ ..... ]...~ ...... L..:. .... L ~..: ...:. t..~ . .: .... J....L..i ..... L..L.L..L. L 2:. ] .~ i...L...L .L ..~-. !....LL..,~..L..~...L..;...z...L..~. L..!..2...~..~ ..~...j..~. ~...L..~...LL.i...L..L.L..z..i...~...4...._.~...~...L..~..+...L4_4..~.. ...~...~.4 ...... J...mL. z...~ .... ;..: ....... :. ~ .................. ~ ....... z...L..: ............ ; ...... ;...i.._L..~..~..4....:. 4.. L.., ........... j ~i..4....;...z..~...~...j...~...; .......... L...,-..z.:--.z-.I-.-:-..L..z..;-.-~ ...... ~...L...L.~..L&_L.L '...L.~_L~_ ..~...~ ........... ~.. ~....; ..~ ..: ..' ..... ~..~ ...... ~ ................ L..; ....... ~...~...~.. ~...~..~;.._; ....... ~...L.~.~..~...;_..~..;_.~...~..~ ...... ~...~_.~...~...~_~...~.~..~.~.~...~_~.. ~ .~c..~...~...~ ...... ~...~_L..~...~_~..~...~_~... -~..~..~..~..;-.~.~...~...~_.~ ...... : ....... ~ ...... ~ ........... '...~ ............... ~...' .......... :..4 .~ ......... ~ ........ ~ ....... ~---~---~-.-+4-..-~ ...... :--:--+..~---~. ....... ~-F4-..~..-M%..~--.~-..;.--:--[--~ .......... ~4.--~--~ ...... F-'-4--~-.~--.~---F-~---~---~- -.-r..~...~...~...~...t''~'''~'q'4~ ~ ~ ~ ~ . ~ ~-~ ....... ~-.-~ ~-. ~--~ ..... ~ ........... : ....... ~ -+.+--~--4~...~ ......... ~ .......~F--~-+-.-~--??~ ,-+r'?~'+~"~'"'~'"~'"'~'"~-'"'~'"~-~-~"'~'"~'-~'"~"'~~ ~ ~~ ~ ~ ~~~~ ~ ~- ~-------?'~?q---~--'-~ ......~ iF~-+"~'++'+"~'-~" ?+.-~.-~-~-~---~-~~..: ~ ~ , ~ .~ ; ~ ~ ....... ........... ...... .......... ......... ........ ...... ...... ......... . ........ .......... .............. . ......... ......... ~-.+.~--.F.~--+--~---~-----+~-~-?~..~-~-! ~ ~ -~ .... ..... ~..-?---?~---~.-+-?~.-+-[--??~ ....... ~- ' ....... ~--~ .... ~--.?+-.~.-+.+-~--?-+-~+-+ ....... .~..~ ~...~-?..~..- ~.-.~ ........... ~---'..-~---~---~--.~ .......... ?~.-+--~ ..... ?-~+--~-.. ~. +-F-~--~ ...... ~-..~---~---~--f-4~.~---~---~---t~:---~---~--~-+--~-. '.-:--~ ........ ~---~-~-~.--?------+--~-.4--~---F-+-~-~ ..... ", ....... : ....... , ...... + ....... :'t'"~'"~'"~'"~"-~ .............. ~"'f~+'-'~"+'-f' ~..+~.+.~.+.+.5.+~.+-+...+.-~-.....+..+.+q~+..+...~..+4...~...~.....+..f..*..?..r.~...=f4".~..-~...??t..~..+.?/-':--?--t--.'4---f---~---:-'-I 2 5 2 ~: · :1 2 ;..; ..& ~.:... ...... *.5..;... ...... ;. ~ ....... :..:...;...;...,..;..&..;...i. ....... i'";'"*'"~'"~"¢"'; ":-':'"t'":'"~'-x'"~'"}[ ........... ;"'*'-~ ,";'": ........ }~ ........ ~ .; .............. i'-;'";" ;'";"2"';'":"'x'"l"'~--"':'"~'-}" ;: :' ~- ~- ~ . : , - I ....... : : : '' ~ ~ ............................J I-' ' I' ~ t .... '' ' : I~'~ ~' ~ ~ ~ .: .... ~. .~ 4 ......... :..: ..... : ....... ~. . : ..... ; .... ~ .... ~...L ~ ......... L.; ...... ~...~ ...L.~...I.-.:...L..: ...... i...L.~.. ;. .L L.L4. .L..;.. ~...L..~.. -...;...: ....... :. .~. .; ........ :..L. ~. ~...; ................... ;.4...: ........ I.-.:.-~ ........... .... :.4 ...... i...: :-.:: ........ :.-; ..... ~ ....... ~ ..... :...t-.~-.}...}...:...I.+..-: ....... }-.~--.-;-.} ....... ~--4---~.-.-¢ ...... ~_~....U.~ ........ F+..¢...:.4...~...;...x..+..~...F : .......... :...~.-; ............ ~..{ ....... ~...~..+..~_.¢....~.._:...u } ...... ~..x...~..q ~: . :; .~: I. ['; ....... · · "~i ': .... .'. ~. ..... ~ ~.. ~t ....... ~ .......... }..1. ::' :t'";~ ..i: .;~ ......... ;..: [ !..i:' ..~...;...L. :. .......,. ~-..~...~.-.1---4..-;, ~ ~ ~ : .4~ ...... - ~: '~- ' .... ]"": ~,:"' ~:" ~: ~"'~- i "':"'~" :" . ;.:.~....,...~. i ..;.. }.~ :. : ....... :1 ...... ~ ....... :"~ ..................... : - ": - ' - ~: ' - :-'-r~ r :'-~'"~'".'--: ....... :'"r': ...... : ....... ~ ......... ~ ...... :--'~ ....... r"v?'-~-'?':"-:-'-?-r"-."':'": ....... ~ .......... :'"~"-~ ....... :": ....... N'"r":'":'"~'":"':'":'"':"'i ~'~-:'-: ....... t ................ ~": ..... ~.-:.-.f-~-.~---~'--:"-f-~---~'"~---:---i--~---~---':--+--~-~ ....... ~ ~--i---~----~-~' ~---~----~--~---~--'*-j'~--'~----:---t--V'---~-----~---[-~-.-t-~,--~--~---+ ........... f--f..t,.-~---~-.--.-.f--~---;..~--~.--~ '"f'"f'"~'"F ~'"~"~'"r":"T": ........... :'"r"-: .......... ~"T"F'T"F't" ?'~'"~'"F'?F'T":'":'"c"~ ............ :'-'~'T'F'F":' :'". ....... T"F'wT-~"~"~'"':'/v'"~'"':'"'%"T"r'~"'~'"T'"':"T"':'"'~"T"~"'~"~'"';'T'~'"[-'~' u'"! ::::::::::::::::::::::::::::::::::::::t:..~:.::::::::::::::::::::::::::::::.::~:::~:::::::~:::;:::~::::::::::::::::::::::::::~::.:.:t:::.;:::i:.:~::.:.:::F~::.~:::~.::~::::~.::~:::~::.~.:::::~:::F~:::~:.:;:.::~:::;::.i:::::::::::::::::::::::::::::::::::::::::::V.:~:.~F::~xx::~x::~::~:}] O looo 2000 - 3000 4000 So00 6000 ?OO0 EAST WELL NAME: 3A-1 SURFACE LOCATION: 4' FSL, 736' FEL, S7, T12N, R9E, vm- CA PROdECTION ON VERTICAL PLANE 133. - 913. SCALEO IN VERTICAL OEPTH~ HORIZ SCALE = 1/2000 IN/FT I~1. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. bfERATOR, 'WEL~ NAME AND NUMBER Reports and Materials to be received by: /~-'~/--~"' Date Required Date Received Remarks , Completion Report Samples ' ~d~ .' . Core Description Registered Survey Plat , Inclination Survey .......... /~ ~~,.. .qxd~,x , Directiona~ur~~ ARCO Alaska, Inc. Post Office B'~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-15-85 TRANSMITTAL NO:5398A RETURN TO: ARCO ALASKA, INC. KUPAI<UK-OPERATIONS ENGINEERING RECORDS CLERK AWO- 1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTLD HEREWITt! ARE TtiE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUF, N ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN ttOLE FINALS/ SC}fL/ ONE * OF EACit ~2" LIThO DEN/NEU 5" < .MICROLOG-GR 2" "~i,~ICROLOG-GR PORO 2 "~ DEN/NLU I~AW 5"~, DEN/NEU ' ~2''/ DEN/NLU PO[(O 5 D E N / N EU PO kO 2''~ DIL/SFL-GR CYB E icl 00~ / 2" DEN/NEU~ RAW 5" DEN/NLU/ RAW 2" DEN/NEU ~ PORO 5" DEN/NEU / PORO 08-30-85 RUN #1 4355-9584 08-30-85 RUN ~1 4355-9584 08-30-85 ttUN ~! 4500-9558 08-30-85 i<UN #i 4500-9558 08-30-85 RUN ~1 4500-9558 08-30-85 RUN #1 4500-9558 0~-31-85 RUN ~,1 ~900-9550 08-31-85 RUN #t 4500-9520 0S-31-85 RUN ~1 4500-9520 08-27-85 I<UN ,~2 6000-7570 0~-27-85 RUN #2 2440-759-~ 0~-27-85 ~UN ~2 2440-7593 08-27-85 RUN #2 2440-7593 08-27-85 RUN ~,2 2440-7593 08-27-85 RUN ~2 2440-7619 08-27-U5 RUN ~2 2440-7619 0U-31-85 RUN ~I 8710-9403 08-31-85 RUN ~1 8550-9426 08-31-85 i<UN ~1 8550-9426 08-31-85 RUN #1 8550-9426 08-31-85 RUN ~1 8550-9426 08-31-85 RUN #1 2390-9452 0U-3!-85 RUN ~i 2390-9452 [<ECEiPT ~iCKNOWLEDGED: bPA'z b. CUR}liEF, CHEVRON D & £4*bL !3 ]~ b'£' !< £ b U'.L'i t3iq: t)i<i Lb i£4G'* iSL ~',". PASiiER L. JOHNSTON EXXON ~,:OD!L PhTM~LIPS OiL N~K CLERK*DL J. ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~. _ 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the August monthly reports for the following wells: 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) L1-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Encl osures Alast(a 0~t & Gas Cons. commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKA O-r~ AND GAS CONSERVATION CON ...... ,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-186 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21412 9. Unit or Lease Name 479' FSL, 735' FEL, Sec.7, T12N, R9E, UM (approx) Kuparuk R~ver Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 25632 ALK 2448 10. Well No. 3A-1 11. Field and Pool Kuparuk River Field Kuparuk River 0il Poo] For the Month of. August , 19.85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1600 hrs, 8/23/85. Drld 12-1/4" hole to 4367'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9600'TD (8/30/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 9485'. Secured well & RR ~ 2400 hfs, 911185. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 104'. Cmtd w/199 sx AS I1. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4353'. Cmtd w/ll00 sx AS II! & 360 sx Class G. Top job performed w/120 sx AS I. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 9575'. Cmtd w/469 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run D I L/SFL/LDT/CNL/Mi crol og/GR/SP/Ca 1 f/surface - 9592' (WLM) 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Repor(C~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by tbl~l:~t~/~Rt~le succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate MEMORANDUM TO: THRU: State of Alaska ALAS~%q. OIL At,iD GAS COi. iSERVATION Cu[,R,~ISoiO.,_-~ C. V. :~'a~cn~erton Cna2rmran~ . Co~~one~ FROM: Do~g ~]OS '~-_~ SUBJECT: Petrole~ Inspector DATE: FILE NO: September I0, 1985 D.ADA. 43 TELEPHONE NO: BOPE Test ARCO KRU 3A- i Permit No. 85-186 Kuparuk River Field Sund~_-, August 25, 1985: I traveled this date from Conoco ~---~-W~ ~0 ARCO~S ~A-1 well to witness the BOPE Test. con61uded at : 'PM THe Inside BOP f=iled, but was repaired and retested during this test. I filled out an A.O.G.C.C. BOPE in- spection Report ~hich is attached. In su~-mnary, I witnessed the BOPE Test at ARCO KRU 3A-I well. Attachment 02-O01Af,qev. 10/79) O&G ~4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~ . ~v~05 Ope rator ~V~ ~, 0 . Location: Sec '~ T ibgR q ~M ~.g- Drilling Con.actor ~ % ~ Date__ ~- ~-~ -~ Well ~ . Representative Permit ~/~'~asing Set Rig ~ ~%~ Representative Location, General Well Sign. General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams ~ Choke Line Valves H.C.R. Valve ~ Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~ ~ psig Pressure After Closure [~DO psig 200 psig Above Precharge Attained: min~ s~ Full Charge Pressure Attained: ~ min~_~s~ I / '-/ Controls: Master O~ Remote ~ Blinds switch cover~ Kelly and Floor Safety Valves Upper Kelly I ~,,,Test Pressure ~_ OOO' ! Lower Kelly I ~ Test Pressure ~I. Ball Type ! ~Test Pressure '~ Inside BOP [ ~est Pressure /~ Choke Manifold No. Valves No. flanges., Adjustable Chokes Test Pressure Hydrauically operated choke. Test ResUlts: Failures [ Test Time '-/-- hrs. ~d~ Repair or Replacement of failed equipment to be made within.. , days and Inspector/Commission office notified. Remarks: .~4~$"~'~ ~,0.~, ~_~%~_~. '~ ~~ ~J~k~ ~6~'u~'~ t Distribution orig. - LO&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wel 1 s 1-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~'~. Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If i ECEtVED Alaska Oil & Gas Cons, Commission Anchora!;e ARCO Aleska. Inc. is a Subsidiary of AtlanticRichfieldCompany AS BUI 7 8 NOTES COCROI.NAT~$ ;,RE A.S.P., ZONE 4 SECTION ~iNE DISTANCES ARE TRUE. HOR!ZONTAL POSITIONS BASED CN THE D.S.-OA WEST & 3AMID PER LHD 8~ ASSOC. 4. VERTICAL POSITION BASED ON 3A EAST & ;SA MID PER LHD E~ ASSOC. 5.aG. ELEVATIONS iNTERPOLATED FROM S/C DWG, CED- RIXX- 3020 rev. ~ .~e..~v-' ,,-', -,,. ~.~ ~'~'..' ~ %'~ HEREBY CERTIFY THAT I AM PROPERLY R~GIST~RED AND LISCENSED TO PRACTICE LAND SURVEYIN~ IN THE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14,1985 LOCATED IN PROTRACTED SEC.7,T. 12 N. R. 9~ I s r,a Oil THIS SUF1 18 CONDUCTORS I- 16 l- Y=5,996,860.05 LAT= 70°24'09.520'' X= 507,712.01 LONG= 149°56' i;.020" 478' FSL, 736' FEL, 36.9' 0G, ~0.8 PAD 2- Y=5,ggG,88~.17 tAT= 70°74' 09.758'' ×= 507,705.57 LONG= 14~°56' 14.207" 503' FSL, 743' FEL, 35.8 3- Y=5,996,g08.32 LAT= 79o2&'.3g..~95'' X= 507,699.06 ,_ONG= !~-J°55' l~. j97" 527' F5L, 749'FEL, 35.7 ©O, 40.8 ~- Y=5,996,932.72 LAT= 70°24'10.235'' X= 507,6~2.55 LONG= 149°56' 1~.58/'' 551' FSL, 756' ;EL, 36.7 0G, &0.8 PA" 5- ¥=5,996,956.61 LAT= 70°24' lO.~70'' X= 507,686.21 LONG= 1~9°56' 14.773'' 575~FSL, 762~¢EL, 36.5 OG, 40.9 P&D 0 6- Y=5,996,980.8~ LAT= 70 24' I0.709'? X= 507,679.66 LONG= 149°56'14.963'' 599' FSL, 708' FEL, 30.50G, ~0.8 PAD 7- Y=5,997,004.90 LAT= 70°24'10.gq5'' X= 507,673.26 LONG= 149°56'~5.151'' 623' FSL, 77~'FEL, 36.5 OG, &t.1 8- Y=5,997,029.03 LAT= 70°24' Ii. i83'' X= 507,666.81 LONG= 149°56' 15.33~'' 647' FSL, 781' FEL, 36.40G, 40.9 9- Y=5,997,101.24 LAT= 70°24' 1! 893" X= 507,647.70 LONG= 149o56' 5.896" 720' =SL, 800' KEL, 36.3 OG, a .7 tAT= 70°2&'t2 134" LONG= 1~9°56' 6.095" FEL, 36.3 OG, ~ .6 LAT= 70°2~' 12 371" LONG= 149°56' ~.283" FEL, 36.20G, ,~ PAD LAT= 70°24'12 509" LONG= la9°56' FEL, 36.10G, - .3 LAT= 70°2-' i2 LONG= lagJ$6 ~EL, 36.0 OG, ~ .0 l~- ~n-= ~0°'2~ !3 :38-' _ONG= i~g°55' ~EL, 35.8 OG. ~ .0 15- Y=5,997,246.~ LAT= 70°24'13 322" EIVED '5' =SL, 838 FEL, 35.6 0G " 3 Cons. ommi~Bh' ~ ~ : [~ ~5 ~ 0¢. ~,~. 10- Y=5,99~,125.66 x= 5~ .6a0.89 ?&a' ~$L, 806! il- Y=5,99-,lgO.S& X= 507,634.44 768' FSL, 813' 12- Y=5,997,173.97 X= 507,627.96 792' FSL, 819' 13- Y=5,997,198.08 x= 50~.621.~8 8i7' ~S_, 825' Y=5,997,222.29 X= 50~,615.01 8~I' eSL, 832' helI ' ' SBSSDG, tI~lllI ~# LIIII IIll#llIlll ARCO Alaska, Inc__ Kuporuk Pro:ect DRILL SITE 3A CONDUCTOR AS- BUILT LOCAT I 0 NS Date AUG. t6, 1985 l Scale: I" = ,~" Drafted Dy:~./_~! DwQ. no.: NSK 85-16 August 8, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-1 ARCO Alaska, Inc. Permit No. 85-186 Sur. Loc. 479'FSL, 735'FEL, Sec. 7, T!2N, RgE, UM. Btmhole Loc. 1093'FSL, 1079'FEL, Sec. 17, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important.for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 3A-1 -2- August 8, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, i ~' {-' i ' t /,../// ~ /~' · C. V. Chatt'erton Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI~fl~,ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o enclo Department of Environmental Conservation w/o encl. Mr. Doug L. LoweR, ARCO Alaska, Inc. Post Office: 100360 Anchorage, Alaska 99510 Telephone 90'/ 276 1215 July 31, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3A-1 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3A-1, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment We estimate spudding this well on August 20, 1985. If you have any questions, please call me at 263-4970. Sincerely, ~~r JBK/TEM/tw PD/L142 Enclosures Ataska 0il & Gas Cons. 6ommis¢on Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Oi-L AND GAS CONSERVATION COr~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~]X - REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~X DEVELOPMENT GAS [] SERVICE [] SINGLE ZONE [] MULTIPLE ZON Ej~ 2. Name of operator ARCO Alaska, Irc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 __. 4. Location of well at surface 479' FSL, 735' FEL, $ec.7, T12N, PgE, UM (Approx.) At top of proposed producing interval 1438' FSL, 1444' FEL, Sec.17, T12N, R9E, UN At total depth 1093' FSL, 1079' FEL, Sec.17, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 72' PAD 41' ADL 25632 ALK 2448 , 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-1 11. Field and pool Kuparuk River Fie]d Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1079' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9624' MD, 6309' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 400 feet. MAXIMUM HOLE ANGLE 54 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 3A-9 well 250' @ surface feet 18. Approximate spud date 08/20/85 2737 ~132 psig@ 80OF Surface psig@ 6069 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE -- CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT _ Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" -62.5# H-40 Weld 80' 29' I 29' 1091 109' + 200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 4232' 29' 29' 4261'1 3157' 1200 sx AS Ill & I HF-ERW ~ I 360 sx Class G 8-1/2" i 7" 26.0# J-55 BTC 9596' 28' Ii 28' 9624'1 6309' 270 sx Class G blend ' HF-ERW I I ~ I __ 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9624' MD (6309' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 4261' MD(3157' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2737 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 2-7/8", 6.7#, J-55, 8rd tbg. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby,c~rtif~/ that the foregoing is true and correct to the best of my knowledge SIGNED _ · ~ TITLE Area Drilling Engineer The spa s CONDITIONS OF APPROVAL DATE Samples required ~YES Permit number APPROVED BY Form 10-401 (TEN) PD/PD142 Mud Icg required Directional Survey required []YES ~-NO [ ~'~¢ES f-]NO Approval date APl number 50--O 't-~7 - w i ~/t -'L_ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 8, 1985 . by order of the Commission Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL (cont'd) 3A-1 installed and tested upon completion of the job. 3A-1 will be 250' away from 3A-9 (West Sak 23) at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 8003'MD, approximately IO00'MD above the top of the KuParuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. On completion of disposal injection, the 9-5/8" x 7" annulus will be downsqueeze Arctic packed with approximately 200 sx of Class G cement and sufficient Arctic pack to place the cement/pack interface below the permafrost. After the workover rig has moved off location, this well will be fracture stimulated. ............... ~LELIYIN;:~__. 1000 FEET-! PAD ~A. WELL.NO, '1' 'PROPOSED ............ 1.000 _. 1000 0 . - _ lO00 2000 -'- SURFACE LOCATION, -- 479' FSL. - SEC. 7. TI2N, RgE .................. . : ..... . ---T ............................... ~ ............ ...... , - - ............ ................................ .... j - . .............................. . .............. ............................................. ................ 1000 ....... J ...... zu.uu · ~ : - ...................... : ...... ...................... · .......... A~a &-Gas Cons;LCornmissi~ .... ........ .................................................. ............. _ "_ _:-.:_':_: .' TAROT LOCATION, ........... T~-921~ .......... - ........ O' . DEP-6~I - ..................................... SEC .-- -i 7,--T 12N.-- R~ ..... SOUTH -~9 -~ :'.~_:.-__:::'..: '._.- "i .-..'~ ....... :-: :_: _~: /_.:_ :: '.i:,:-&:- i; ' ::. i_::- __ EAST- ~95 ...................... . ........ PAD' 3A, ~ELL NO~ 1 r-,-v . ~ : · ~_.._._~.-.~__.~ .... :_ .: .... ~ ....... - ~-~nnn - . -~4~ s~ EOC TVD=1945 TMD=2200 DEP=787 ': .... ~_2-_-.: .7_: .' TOP UPPR SNDS- :TVD=Sg45 T,HD=9003 DEP=6291 ~_'~-_/-:5:._-._~ ' .. .7-. ¢.:- -'_2_..: '. -8000 ...... : TOP LOWR SNDS TVD=6062 TMD=g202 DEP=6452 ' .......... ..... TAROET-'"ONT~--TVD=6069 TMD=g21 4 DEP=646i.- ....... BASE KUP SNDS ;TVD=6192 TMD=9424 DEP=6630 :, .................. ......... ..... ~ .......... ~UUU I I I I I I I .............. ~ ................ .......... ................. : ..................... ~ ................. ~ . .... . - - _ ................................... ' ......... I.~1 L.J.i>. I ! i .... · ii00 1000 9"'q . _800 . 7'00 . O0 .......... ~ ~ ~ ~ ~ 60O 50O 40O 1 1T? ' 1 ~T7 227 . 1555 ..... . 1355 .. . ........ : _ _ _: .......... 14.o5 - - ~4.55 :--':,"" ::':::::-'--:'-' :.._ ::___: ._ ''" , ..:_.:.._::_::: ..:: ::::__:?::: :: ._::. ::.::..: : , .- ..... :::::::::::::::::::::::: :-:-.. ................ ---~ ~ ~' ..... ~2~ .......................... ................ ........ 16~2 ....... : .............. ......... ......................... . . : ........ 18T8 ..... O0_L_.: ................ ~ ' - ............... .................. ....... 1T28 ............. .............. - '1778 - ' - : .... ~oo · ' 1832 ' :._ .. '-__::_ .-_' . _ . . _ . . . _.. .... - ,~: c~ VED ' : -.': :'. 4:L:'-':L:_::..'-:::.::': '__.: - :_ ' - :. ':::7::"--1:::::: ARCO - _~ ...... . ......... t ........... .__:_ __'L L: . .L_ :./.._._-:_PAD ~A.-~ELL NO~ _1-2-]-4_-_:PflOPOSED ........ _~_-:..: :' ......... :7t:'~--':~:::-:- :-- -I ~.,,,., '::: ..... : I--::LL-:-:- --V--~.-::.:L : :L-::-:' .... .... --~': :-~7._ ....THI 8 V IEWINO WINDOW' --:: .................. ~00 ' ' - ...................................... KUPARUK RI VER UNIT 20" DI VERTER $CHEMAT I C DE SCR I PT I ON I. 16' C~CTOR. 2. TAI'~O STARTER HEAD, 3. TAN(O SAVER SUB. 4. TANKO LOWER (DUICK-C~CT ASSY. 5, TANI<O UPPER (DUI CK-C~CT ASSY, 6. 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. '7, I0" HCR BALL VALVES W/lO' DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AD, N.A. AR PREVENTER, 8, 20" .2000 PSI AD, tIJLAR PREVENTER. 2 MAINTENANCE & OPERATION io UPON INITIAL INSTALLATION~ CLOSE PREVENTER Ah[] VERIFY THAT VALVES HAVE OPENED PROPERLYo 2. CLOSE At~NULAR PREVENTER AND BLOW AIR THROUGH DI VERTER L I NES EVERY 12 HOURS. CLOSE ADa'~LAR PREVENTER I N THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, IF NECESSARY, MANUALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DO~NWlh~) DIVERSION. RECEIVED Alaska 0il & Gas Cons, Commission Anchora,.:3e DO NOT SHUT IN V~E:LL UNDER ANY CIRCU~TANCES.. 6 L_ DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK I. 16' - 2000-F~SI TAN<~ STARTING FEAD 2. I1' - 3000 PSI CASING ~E. AD 3. I1' - 3000 PSI X 13---5/8' - 5000 PSI SPACER SPOOL 4. 1~-5/8' - 5000 PSI PIP~ P~ 5. 13-5./8' - 5000 PSt DRILLING S~ W/CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RAMS CN TOP, ?. 13-5/8' - 5000 PSI AN~ ACCLMJLATOR CAPACITY TEST I. O-ECK A~D FILL AO2IJVU. ATOR RESERVOIR TO ~ LEVEL WITH HYDRALLIC FLUID. 2. ASSUR~ THAT ACOJVU_ATOR PRE~ IS 3000 PSI WITN 1500 PSI ~TREAM OF ~ REGLLATOR. 3. OBSERVE TIt~E, THEN CLOSE ALL UNITS SIIvLLTA~EOUSLY ALL UNITS ARE CLOSED WITH CHARGING PLIVP OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LO~ LIMIT IS 45 SEC~ CLOSING TIIVE A~ 1200 PSI REI4AINING PRESSL~. 5 4 2 13. RECEIv 13-5/8" BOP STACK TEST ]. FILL BOP STACK AN3 CHOKE MANIFOLD WITH ARCTIC DIESEL. 2. CI-ECK THAT ALL LOCK DOAN SC~ IN ~SLL]-~ ARE FLE_LY RETRACTED. SEAT TEST PLUG IN WELL]-E. AD WITH RL~ING JT AhD RUN IN LOC~ SCREWS. LI~E VALVES ADJAC~ TO BOP STAC~ ALL OTNER VALVES AN3 C~S S~ BE OPEN. 4. PRESSURE UP TO 250 PSI A~D NOD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI A~D HOLD FOR I0 MIN. BL~'~D PRESSl~ TO 0 PSI. 5. OPEN A~ PREVENTER AN:) MA~IJAL KILL AND OHOKE LI~E VALVES. CLOSE TOP PIPE RA~ AN3 NCR VALVES ON K~[LL /~ CHOKE LINES. 6. TEST TO 250 PSI A~D 3000 PSI AS IN STEP 4. 7. CONTINJE TESTING ALL VALVES, LINES, A~ CHOKES WITH A 250 PSI LO~ A~D 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRE~ TEST ANY CHOI~ T]-IAT IS N~T A Fl~, CLOSING POSITIVE SEAL CHOKE. ON_Y FL~ION TFST CHOKES THAT DO NOT FULLY CLOSE. B. OPEN TOP PIPE RAMS A~D CLOSE BOTTC~ PIPE RAMS. TEST BOTTO~ PIPE RAMS TO 250 PSI A~D 3000 PSI. 9. OPEN BOTTCI~ PIPE RAN6, BACK OUT RL~ING JT A~D PULL OJT OF HOLE. I0. CLOSE BLIND RA~ AND TEST TO 250 PSI AND 3000 PSI. II. OPEN BLIhD RAMS AN:) RETRIEVE TEST PLUG. MAKE SURE k~NiFOLD AND LINES ARE FULL FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COO<S, DRILL PIPE SAFETY VALVE, A~D INSIDE BOP TO 2..50 PSI A~D 3000 PSI. RECORD TEST INFORMATION ON BLOHOJT PREVENTER TEST FC~, SIGN, AN3 SEN3 TO DRILLING SUPERVISOR. P,~RFC~ ODVPLE~ BGPE TEST AFTER NIPPLING UP AN3 ~EKLY THEREAFTER FUNCTIC~LLY OPERATE BOPE DAILY. Alaska Oil & Gas Cons, Oommission 510084001 REV. 2 MAY 15, 1985 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin ', ~'5~-~~ (9 thru 12) . ~ (10 'and 1~)-- (13 thru 21) (22 thrd 2~6) YES NO 1.~ Is the permit fee attached ......................................... 2. Is well to be located in a defined pool .................. .. .<~ 3. Is well located proper distance from property line ..... 4. Is well located proper distance from other wells ....... 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is wellbore plat included ... 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day Wait ..i ............ · 9. Does operator have a bond in force .................................. ~-~ 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... _ 12. Is the lease number appropriate ..................................... 13. Is conductor string provided .......... 14. Is enough cement used to circulate o~ ~~;~ ~'~j;~ 111[][[[1,'V,t/t7 "' 15. Will cement tie in surface and intermediate or production 16. Will cement cover all knom productive horizons .............. 17. Will surface casing protect fresh water zones ...... 18. Will all casing give adequate safety in collapse2 19. Is ,this well to be kicked off from an existing wellbore ............. 20. Is old wellbore abandonment procedure included on 10-403 ............ 21 Is adequate wellbore separation proposed ............................. 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does nOPE have sufficient pressure rating Test to ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS Additional Remarks: ~eology: Eng~.~ering: WVA ~ MTM ~ HJH '~qZ'i~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. V~'R,TFTCA'.I'TO~ , DATA ,A~)D A'R~ ~OT TNC!SUD~D: :IN b):8:TI))G * , ********************************************************************************** SE~¥tCE NA ~,~E :EDIT CONTINUATION ~ :01 ~R~V~Ot~S R~EL COmMeNTS ~LISR.ARY TAPE ** T.&PF, HEADFR SERVICE' ~ANE :EDIT ~ONT~NUATIDN ~ ~01 PR~V~O~S T~P~ : CO~NT8 :t,I~R.~RY TAPE ******'***'*EOF SERVIC~ NA~E : hATE : MAXI~U~ LENGTH : :1024 WILE TYPM : PRMVIOUS FIbM COMPANY :. ARCO &LASKA INC, COUNTY : NORTH SLOPE OOROU~H STAT~ : At, ASKa ,.,10:~ ~!UM.BRR AT ACCC 70796 ~U'~, #ONE, hATE LOGG'ED~ 30-~UG-85 CASI~G TYPE FLUI'D rl, UiD LOSs = A C3 RA AT BHT ::~ 2,1,..~ ~ 139,0 DF * SCR~UMBE~G~R ~OGS iNC[,I.,IDrD WITH THIs MAGNETIC TAPE~ .,...O.p~N~ATED NEUTRON [,0~ (L~T} * . YE ....IFICATIDN L"YSTING PAGE ~NTRY BL~C~S TYPE $I~E ~'EPR CODE EN?EY 2 1 66 0 9 4 6fi .:lin 1.6 I 66 1 0 ! 66 0 DATU, SPECYF'YCAT~ON BbOCKS {N~M SERVICE SERVfCE UN:YT API ~PY APl AP! FILE SIZE SPb REPR PROCESS iD' SFLU DIt, O.H~.~ O0 220 01 0 0 4 I 68 O00OO000OOOOO0 iLD 9IL OH~ oo i20 46 0 0 4 1 68 00000000000000 lb~ DXL OH{~ O0 120 44 0 O 4 SP ~IL ~V oO 010 01 0 0 4 O0 I 0 4 ~ DI~ ~API ~i0 0 0 ~ Y.DT ~APi O0 ,10 01 0 O o½ o o DR~O LOT G/C3 O0 35~ Ol 0 0 4 ~R~T [,D· O0 420 O1 0 ~NRA LDT O0 000 O0 0 0 4 PE~ LD~ O0 t55 01 0 0 {CN~ LDT CPS O0 t30 )1 0 0 4 ~C~L £,D? CPS O0 330 ~0 0 0 4 {INV EPT OHMM 00 250 00 0 0 4 GR EPT GAUl O0 ]10 Oi 0 0 4 ~D ~PT YN 00 ~80 01 0 0 00000000000000 1 6868 000~000~000000 I ooo o. oo,oooooo I 00000000000000 I ~ 00000'000000000 i O0000gO0000000 1 68 00000 00000000 I 6~ 00000000000000 I ~ O00000000gg000 ! 000000000 000 oooo'ogggog 00~0000o 1680 0 1. 68 000 68 gO000000000000 ~ 68 0000000000000 68 00000000000000 ~ 68 00000000000000 I 68 00000000000000 "PHI 36 8652 PEP 2: 866 MCNL VNOR 1~442 ~INV 2.13~1 gR 00 FCNb 43 18 g 2 8 -4144 -0 52"t'6 5020 ~167 500 4512 LVP OIO.HO~ VEPlF,ICAT,[ON LISTING PAGE 5 DEP? .9.400 sp -'I ~, RHOB NPHI 37 N~NOR D:EUT 930n SP -20 RHOB ~ NPHI 38 ~NDR 9.' DEPT 9~00 SP 3~ NpHI 30 ~NOR 5 9EPT 9t00 8P -4; ~H~B ., '~' PH I' '3 O ~ N 0 R ~ 0o00 ~.FLU 294,9 ~R ~305 DRHO uINV 0000 ~FLIJ ~764 ~R ~t475 DRHO ]1~7 ',~INV .nO00 ~FLU , ,.104 HO . ~0 70 PEr . 503 '~INV 0000 SFI,,U 6RHO 4688 , ~r 07~0 MIt,)V 0000 5508 4436 DRHO 7 PEF OEPT 9000 . 0000 ~P -50.7383 RHO8 ?,0592 DRHO NPHI 3~,~754 DEr ~NOR 4,087~ ~INV DE:PT 8000.0000 ~FT, U SP -31.~764 GR RHOB ~.4436 DRHO ~PHI 42.724b PEF ~NOR R.07~3 ~INV ~EOT 8800 SP -33: NPHI 45. 0000 .... i~ LU 9.07O ~R ]733 DRHO 1660 ~Er 9756 v I ,".~V 331. .~2 8 0~0 6995 6780 8303 0898 017'1 3167 4 ,I 76] 6,9500 '~,0063 ,~659 6.~t765 6 .02~1 -0 I17 2 6370 4 ,1,765 ~ ~4~0 1064648 00000 12 72~5 42468 1.2100 10~.9023 O.bO~3 ?.0823 1~,4648 ~090 2~8479 2.5901 NR~T NCN~ CR I'GD NR;~T NR .RT NCNL NRAT NCNb IGD NR~T NR~T ~R TL, D NRAT NCNb ~R NR~ NCNL NRAT wC~L ~R 10 · 3,~717 88~7.3 87,:65~3 , 2'9518 2599,$000 87,6523 '10ii196046489963 106.4648 3.~452 174~.6675 ~0 .9023 ~ .26)9 I 4648 12 "7463 · 1~41.6875 121,4648 RNRA HD .~CN'b HD. CA:bi RD C'ALZ ~N~A HD CAb l PCNb HD CALl CALI FCNL gD CAT, I RNRA PCNL, WD 3 674 8 ~7 5, :9460 9,2441' 2,.9865 969,3125 9 "OOt~ 1 4 6570 9 ~7598 8 3125 .~4~0 1 4366 ~ 3601 3 ~6~ 489 :3906 10 0425 2.2952 710 45 ,. ~406 11. 969 LVP 010,gO~ vE~iFIC~?IO~ L]'STING PA~E 6 DEPT 8700,0000 SFLU ~HO8 .3694 ~R~O NPHI ,.:~405 S P ,3 ~HOB ~,3909 MNOR ?,~209 8500 0 0 3~ ~ ~706 E~r 8~00,.0000 ~O~ 4,2117 n~T s~Oo.o000 5~.5S~0 9HOB 2,4.6..~ vPHi 3~.~7~9 9~T 8~0~,0000 SP. -64.~477 ~HOB ~PH! 3~.':J777 ~NoR ..,4749 DEPT 8t00,0000 SFLU .oB ~EPT 8000 0000 SFY,t.I sp, .4o!os o 4 os4 ~P~i 3~,~359 PEF {NnR ~,}795 uI~V r~HOB ~PHi ~I~V ~RHO' ~FY.~I.J ORHO ~INV ~FI, U ~R DRHO ~iNV SF~U GR DRHO ~INV 4' ,437:5 0'. o 005 4065 4 89 0 4 0 640 3 O, 0254 ~ :2:06 05.gO~ :0; ~. 0901 027 ~ 6,7117 -0: 01S 002 5 6335 82:58~8 -o oo ~ 2 6096 ~ 5901 NRA ? NCNb CR N R ,R T NRAT NC:Nb GR Tbn NRAT NCNb OR NRA? ~CNb ~R ! bD GR NCNb ~R NRAT NCNb C,R ThO ~R NRAT NCNb ~R NR.aT NCNb 208.9375 , 3o ! 4,4929 3,0627 138.4375 .OS o 3.44~7 4,54?6 105'90~3 2403.~000 ~.05,90~3 5 7468 2159 5090 12 0273 4,~02~ 2 254~ 00~ 98 s :i° RNRA HD NRA rC: R NRA HD ~:N~A ~CN:b HD RNRA CALl ENRA r:e N b ~D RNRA rCNb CAbI RNRA HD YbM CALl RNRA ~CNb 4,6960 9 86 i,,,, 3 · 3,7 834 567 10, :5860 ~0 I ~,40 4 3,06~7 3,4280 ~.,4929 6057 28 ,,3 ! ~ 5 11,6426 5 0046 5254 ~ ,1604 ~04 3125 9 7940 4 8093 ~, 76 .. ~PT 7700 S 'P - "5 RHOB 2', ~PHi 3{7 DE,.T 7 7500 EPT N'PH! nEpT 7400 SP flPHI DECT 7~00 ~P 3~ RHOB ~PHI 36 OE~T 7200 NPHI 39 DEPT 7100 SP -24 RHOB 2 NPHI 36 DE~T 7nO0 SP. -6: RHOB NPHI 40. ~NOR o000 ~FLL} 4377 DR~O 026 '~T.: ~V nooo SFL[I :204 ~INV oOnO 4:014 4.104 ~RHO 68~5 1819 000 793 4006 5488 ~819 o000 SF[,U ~592 DRHO ,094 ..ZW o000 SFLU 2383 GR 41~4 DRHO 40?6 ~INV 0000 SF~U 04~0 ~R ~7~3 ~R~o ~OqO egr ~000 ~FLU 6201 ~R 3850 ~R~O 0352 PE? ~040 fir 91~0 DEF d. 4~4 "INV 9612 OX t7 '~088 2 3 t06 0 :2 01,4 2,1.155 .,8i25 2,'~07'3 1.5098 · 0 O0 ~ 0901 ~,'t624 3 6389 ~40 0625 0 0059 6?80 ~ .3264 4,] "6 0.00 3.5 47 ~.6~84 50~5 5 ii ° 1.9917 ~O& 5273 2.0745 ~.5782 ~RaT ~R IbP NRAT R N R.R T ~C~tl~ g'R (~R NRAT GR ~ICNt, NRRT NRAT NRAT NCNb fir IbP NRI~T ¸!. . 3,7346 3,:~I, 1~6 39 ' 3,9612 1, 40.06 5 ], :3{'694 2051,S000 140 ,'0625 4 5164 134 4375 3 ~081 4.6765 15~;0625 .3147 2079,5000 155,06~5 ~.0979 106,52~3 3.50 ~ 237].50~0 ~ 06.52 3 ,! b~ RN~A CA:b::I RNRR CAt,~ l mN~A :gab l RNPA CAbI RNRA rCNb HD ~N~A RN~A FCNL "D CALl ~N~A FCNL 4,4460 ~090! 16,6407 65 ! 652, t3 ~69 3,t018 14,5840 16.~5S~ 4 ]757 t~ 42~8 ~ 8i67 498 6406 [5 45~2 4 6257 ~o0510 1~,0566 .0002 ller. 07 ~'~T 6~oo'oooo SP::, gR. ~OB ~,§4'99 DRHO MN~R J,,~ 40 6 oo.oooo ~ 6700'0000 SKLL: O..PT SP OE.T 6600,0000 PHOB 2,.~4?9 ~PHI 3:4707 '~' , ~':):633 NP~I 2~.36F2 gErT 6400,0000 SFi,,,U SP -41"7070 ,HOB ~.3401 NP.I 3]:~3)6 PEr 6300 -37 3633 ~ 3381 39 T46i 1 6~43 DEVT 6~00 0000 SFt, U ~HnB ~ 1,47 DR~O ~P~I 34:7168 PEr mNOR ~.6006 mI~V 6100 0000 -4, ~B52 2 3362 3~ ~2~4 ~ ~950 gErT ~P~I SP NPUI MNOR SFI:U ~R DRMO PEF ~ FI., U GR r~RWO PEr ~I MV 0 s~R ~ T ~0 i 4,:it2:~6 ,.S Oo ~,:0:898 2.4865 2 .2737 86:9648 -0 0156 1,T042 2,2014 3 ~.0 2,69?5 1-6954 ,og: TM 148 -0.0122 2.4377 !.,9776 ~ R MRAT' T'LO ~R NRRT R NR~T N'¢NL NRAT NCN~ ~R NR[T NCNb NRAT NCnb ~R 24 1, 2 :5000 ~148 * 0 4 ??:gooo ~.6350 4651. 9648 2.6135 8i*0273 ' ,~151 211R.0273 10).4182 2~8~$000 ~0q~2148 CALI ~C':: HD RNRA RNRA CAbI' rc'Nb ~CNb ~O CA. bl RNRA ~CNb HD ibm CALl ~N~A 2 67 47 11 735 0 90'~ I0 .44 1: ,.265 I0'~949 · ' ,12~2 698 ~125 12 ~i68 2.49~4 588,.3t~5 11,8574 2 4788 2854 66~ 8125 1 45J2 2,~479 10, 0 LVP 010 HO~ ~ '~' ..... '" · , IL,D, I ~'I CAT,I ON Lt$?I~G PAgE 9 UEPT N:PNI ~NnR DEPT NP~i DEPT ~HOB ~HOB S P ~HOB NPHI DEPT ~N~R SP NPHI ~P 6000,0000 1.~,885 5900.0000 5'5007 1,6661 5voO'oooo '24:'~4:014 ~,:1702 56001,'0000 -2~,5107 3~..6895 ,4670 5~00~0000 ~,~0~0 1311 5aO0 -13 Y 3713 32 4219 ? n530 5300 0000 -10 6309 ~ 3284 37 54~8 2 6213 ~R SFb{.I DRHO ~ I N V DRHO MiNV ~FLU DRH'O DRHO ~INV ~FLU ~R DR~O MINV SFT,,U DRHO PEW SF!..U 5~On 0000 SFLU -28i7295 GR ~ ~678 DRHO 40 1855 DEF ? n9~O ~INV ,00~,!0 109 0.0015 ~.06°~ ~07.8398 -,O,.OOlO m,8245 2,8870 1,1i,8198 0,0977 9,1694 ~ 9065 9~ 714S 0 0244 3 2444 ? 6194 ].0432 2'9983 N~AT NCNb g,R NR~T NCNb gR ~R NCN~ NRAT NCNb ~R NRAT :NCNb NRAT NCNb GR NRAT NCNL GR NCNb ~R NRRT NCN}., ~R 74 23 8 216:! I 173 3,0452 2141~:~'5000 107'.8398 3.2600 100.0273 II '8398 1991':11'94 ,6875 T148 22 $000 7148 3,75O2 108.~773 ~ ~393 2015!6875 108 2773 HD ~'b~ R N'R A '~ N~ A HD mNtmA HD A t I RNRA FC:Nb H D C'ALi RN~A CALl rCNL CAbI HD ~ALI FCNG {.6917 11,5753 12 12 · ~9 1 '606 14 ~96 3,' 0627 698.:~t2:5 13,4297 ,8809 3 ]108 i2 0566 ~ 38~o 1 8340 657..31 5 14.6172 3 467o 1~.5957 14,0437 498,6406 14,~657 b'VP 010 HO~ tF,~IPICATION L!STIWG ~A~E 10 DEPT NPMI NP~I ~EPT ~R ~EPT DEPT ~HOB SP WPWI ~NOR DEPT ~PHI 5~00 0000 · ~ o ]8 5742 ~ 3245 ~INV 5~00~000 -34;O.50a ~:R , ' 9690 ~'I ~V 4. 264 ~,2815 3 , :69:~3 ~EF .9600 4800.0000 ?.~l. 3l. . 02~9 41oo' oooo srt;u' . 40. 3008 : 5234 PEr 3:5700 4600 O00O $~..,U 9 .... 1760 DRHC) .~INV 4~00.0000 SFt, O 38.~633 ~R 542 ORHO 3!?,178_ . ~INV 440.0 .n. 000 SFLU 11.'13 .~.6 ~O 24 _DR 06~$8 ? 03~ 9 ~INV 4331 0000 gFLU -37 9883 GR 2 2170 ORHO 53 1738 PEr 0 0000 ~INV NR~T ~CNL 2,4553 3'0495 96,,40~3 -o'ooo5 NRAT ~,g709 GR 0,005~ ~;RAT 0,0.0:7'3 96°.46~B 0.007,3 NR,iT ~.~600 NC.L. 2,~2'68 2,6624 .o.oi66 ~T 1.8897 -0::' 54 ~RAT .3~4~ ~CNb 1.79~2 GR 6804 098 ~147 1 09~9 50 4180 GR -0 4390 ]8~5~ 0000 WCN5 0 0000 4.3815 ~.4553 2165'5000 ~.04.5273 4 :049 114 fab I C N b BD ~'LN C/,ALI 5000 FCNb ;402 3 HO rCNb .0898 HO 9~ eat, ,34 5g ~N'RA ,,$~ 0'0 F:C'NL 20~i.4E48 HD 87.1 CALX .3.6 87.1 ;~ .5061 RNRA 98.9148 RD 3..4690 16.0810 50,4! 0 4.0789 1t80.6875 ~CNL 50'4180 4.04,3 7 1 !. 6816 3,7463 577.. 25 14; 5840 4:, 343 I 37 ,2 ,4B$. !406 15 i99' 4 554 2 ,, 8 0 B 8 12:; 00~0 '3,'8655 · 498,3,906 14,:3B~9 .0801 14. ,.034 1 1 9004 4,1126 ·8906 4902 LVP O10.NO~ VERIFIC~?InN LISTIMG PA~E ** F!bM TR~ILE~ WlbE N~ME :EDIT .001 DATE : OR~GIN TAPE CONTTNI~AT~ON NERT, TDPE NAME COMMENTS :~.,IBRARY SE~VTCM WA~E :EDIT OR~G~N : CONT!NHATI~N ~ NEXT R~EL ~A~E : ********** EOF **~******* ********** EOF
