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208-180
ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 RECEIVED STATE OF ALASKA 'AKA OIL AND GAS CONSERVATION COII SIONR 201 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing❑ p( ,t'' ep"/ ❑ 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 0 Exploratory❑ 208-180 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-103-20587-00 7.Property Designation(Lease Number): 8.Well Name and Number: CRU CD2-468 ADL 25529,ADL 25530, ADL 380075, ADL 387212 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Qannik Oil Pool 11.Present Well Condition Summary: Total Depth measured 17,850 feet Plugs measured None feet true vertical 4,071 feet Junk measured None feet Effective Depth measured 17,850 feet Packer measured 9,262 feet true vertical 4,071 feet true vertical 3,797 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 " 114'MD 114 TVD SURFACE 4,476 feet 10 3/4" 4,513'MD 2387 TVD INTERMEDIATE 10,586 feet 7 5/8" 10,620'MD 4076 TVD LINER 7,394 feet 3 12 17,837'MD 4071 TVD Perforation depth: Measured depth: 10,610- 17,803 feet p , True Vertical depth: 4,074-4,081 feet j(J4 1 . zuer rwskvitat Tubing(size,grade,measured and true vertical depth) 3.5" L-80 10,464' MD 4,064'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER PREMIER PACKER 9,262' MD 3,797'TVD SAFETY VL-Camco TRMAXX-5E 4,506'MD 2,384'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10,610'-17,802' Treatment descriptions including volumes used and final pressure: Total Well-single stage,147,452 lbs Wanli 20/40 proppant 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: 293 149 55 650 197 Subsequent to operation: 483 230 16 787 253 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 ,700 Exploratory ❑ Developmentl] Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ -1,.*16.Well Status after work: Oil El Gas El WDSPL ❑ Lyll Printed and Electronic Fracture Stimulation Data /J` GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-479 Contact Name: Hanna Sylte Authorized Name: Hanna Sylte Contact Email: Hanna.Sylte@cop.com Authorized Title: Completions Engineer • Authorized Signature: D i^) Date: 3115 120 l a Contact Phone: (907)265-6342 vfiL 5/3 f/1 g r� Form 10-404 Revised 4/2017 `.D.h) 3/2 7/io' 0.1 t RBOMS Submit Origin y • • CD2-468 FRAC STIMULATE DTTMSTAI JOBTYP SUMMARYOPS 02/15/18 DRILLING PUMPED STEP RATE INJECTIVITY TEST WITH 200 BBLS SEAWATER, SUPPORT- STEPPED UP TO 10 BPM AT 1830 PSI. CAPITAL (JOB COMPLETE) 02/21/18 DRILLING PUMPED 147,452 LBS (98% OF DESIGN) OF WANLI 20/40 PROPPANT SUPPORT- INTO QANNIK FORMATION, JOB COMPLETE. CAPITAL **TREATING REPORT ATTACHED** 02/22/18 DRILLING DRIFT TO & PULL FRAC SLEEVE @ 4508'RKB. SET 2.7 BAITSUB& SUPPORT- 2.77" GAUGE RING AS CATCHER @ 9340'RKB. ATTEMPT TO PULL CAPITAL DGLV @ 9173'RKB. TOOL NOT FUNCTIONING DUE TO FRAC SAND. PULL CATCHER @ 9340'RKB. IN PROGRESS... 02/23/18 DRILLING PUMP 90BBLS CRUDE w/LRS. B&F TO 10002'RKB. SET 2.79" SUPPORT- CATCHER(2'-11") @ 9340'RKB. MULTIPLE ATTEMPTS TO LATCH DGLV CAPITAL @ 9173'RKB. IN PROGRESS... 02/24/18 DRILLING PULL CATCHER @ 9340'RKB. LRS PUMPED 105BBLS SLICK DSL. B&F SUPPORT- TO 10002'RKB. DEPLOY CATCHER @ 9340'RKB. LOCATE ST#2 @ CAPITAL 9173'RKB. UNABLE TO SD. LAY DOWN DUE TO PHASE CONDITIONS. IN PROGRESS... 02/25/18 DRILLING PULL DGLV @ 9173'RKB. SET 1/4" OV w/HIGH SEALABILITY PACKING SUPPORT- ON BK LATCH @ SAME. PULL CATCHER @ 9340'RKB. READY FOR CAPITAL PTS FLOW BACK. • 0 • Hydraulic Fracturing Fluid Product Component Information Disclosure i Job Start Dater 2/21/2018 Job End Date: 2/21/2018 State: Alaska • County: Harrison Bay " ' API Number: 50-103-20587-00-00= Operator Name. ConocoPhillips CompanyBurlington Resourcesr�Fr1ac Well Name and Number: CD2.468, Cal Disclosure Registry Latitude:' 70.33730400' Longitude: -151.04718600 Datum:' NAD83, $ NOWATER Federal Well: NO ,.ro , Oil&+Gas ( Indian WellNO &. 'True Vertical Depth: 4,071 Notal Base Water Volume(gal): 90,509', 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 7732-18-5 80.22632 Density=8.540 SP BREAKER Halliburton Breaker Listed Below • • LOSURF-300D Halliburton Non-ionic Surfactant Listed Below BE-6- Halliburton Biocide MICROBIOCIDE Listed Below CL-31 Halliburton Crosslinker • CROSSLINKER Listed Below WG-36 GELLING Halliburton Gelling Agent AGENT Listed Below CAT-3 Halliburton Activator ACTIVATOR Listed Below Items above,are,,.Trade Names with,the e tNater.Barns below are the in i,iTtdual ingredients Corundum 1302-74-5 65.00000 10.36243 Mullite 1302-93-8 35.00000 5.57977 Sodium chloride 7647-14-5 4.00000 3.34276 Guar gum 9000-30-0 100.00000 0.18499 WATER 7732-18-5 100.00000 0.16285 Potassium metaborate 13709-94-9 60.00000 0.07502 Ethanol 64-17-5 60.00000 0.04829 Oxylated phenolic resin Proprietary 30.00000 0.03220 EDTA/Copper chelate Proprietary 30.00000 0.02635 Sodium persulfate 7775-27-1 100.00000 0.00811 Potassium hydroxide 1310-58-3 5.00000 0.00625 • • Poly(oxy-1,2-ethanediyl), 127087-87-0 5.00000 0.00402 alpha-(4-nonylphenyl)- omega-hydroxy-, branched Naphthalene 91-20-3 5.00000 0.00402 Heavy aromatic 64742-94-5 5.00000 0.00402 petroleum naphtha 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00227 propanediol 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00080 *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) WNSAROD CD2-468 • conocoPhilhhps01% Well AttriMax AT MD r0 Wellbore APVU Field Name Wellbore Status ncl(1 ) Act Btm(ftKB) Al,1554 Iit:. 501032058700 QANNIK PROD 94.30 10,863.34 17850.0 ConoC � Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) 'Rig Release Date .-. SSSV:TRDP Last W0: 36.98 1/4/2009 HORIZONTAL-CD2-468,3/12/2018 3:41:57 PM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag: Imosbor HANGER;314--. �� � il I Last Rev Reason ..t1° Annotation End Date Last Mod By Rev Reason GLV C/O and FRAC 3/8/2018 pproven Casing Strings 'ti Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 3/'Iniwkted; I. s CONDUCTOR 34" 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded 37.0.114.0 Insulated Casing Description OD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread SURFACE 103/4 9.950 36.7 4,512.9 2,386.8 45.50 L-80 BTC-M _ i Casing Description 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,1 INTERMEDIATE 7 5/8 6.875 34.4 10,620.2 4,075.8 29.70 L-80 BTCM © Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 10,443.0 17,837.4 4,070.9 9.30 L-80 SLHT Liner Details Nominal ID az Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV,4,506.0 --- 10,443.0 4,062.5 85.83'SETTING SLV Baker"HR"Liner Setting Sleeve 5.000 P.,lel: 10,455.7 4,063.4 85.85'NIPPLE Baker"RS"Packoff Seal Nipple 4.910 SURFACE,36.7-4,512 9-. 11 i 10,458.2' 4,063.6 85.85 HANGER Baker 5 1/2"x 7 5/8"Flex Lock Hanger - 4.940 It Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection VIT TUBING 31/2 2.992 31.4 4,496.4 2,381.3 12.60 L-80 IBTM 4.5"x3.5"@149' GAS LIFT;7,882.0 Completion Details Top(TVD) Top Incl Nominal III Top(ftKB) (ftKB) (°) Item Des Com ID(in) 31.4 31.4 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.27'pup 4.500 am 149.0 149.0 0.08 XO-Reducing XO-3 1/2"IBTM(P)X 4 1/2"IBTM(B) 3.500 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection SLEEVE,9,0697 TUBING 31/2 2.992 4,496.4 10,464.71 4,064.0 9.30 L-80 IBTM Completion Details Top(TVD( Top Incl Nominal Top(ftKB) (ftKB) )°) Item Des Corn ID(in) GAS LIFT 9,1727 1g,;; 4,506.0 2,384.4 70.47 SAFETY VLV '3 1/2"Camco TRMAXX-5E SSSV w/2.813"profile S/N S CXS0065 2.813 111. Si 9,089.7 3,746.2 72.67 SLEEVE 'Baker 3 1/2"CMD Sliding Sleeve(2.812"ID WP'BX"Profile) 2.812 111 PACKER;9,261.7. ---- 9,261.7 3,796.7 72.61 PACKER Baker 3.5"x 7 5/8"Premier Packer 6.58"OD x 2.87"ID 2.870 El 9,340.1 3,820.7 71.82 NIPPLE HES XN Nipple W 2.750 10,4637 4,064.0 85.86 WLEG WLEG 2.980 NIPPLE;9,340.1 Perforations&Slots L a Shot Dena i Top)TVD) Btm(TVD) (shoMIS Top(RKB) Btm(ftKB) (MB) (ftKB) Zone Date ) Type Com 10,610.0 10,671.0 4,075.0 4,080.0 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe WLEG,10,463.7 is I 10,890.1 12,329.3 4,083.0 4,074.3 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 12,454.4 12,674.2 4,073.6 4,080.8 12/29/2008 32.0 SLOTS Alternating solid/slotted IJ pipe 12,892.8 13,677.0 4,080.4 4,078.5 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 13,771.0 13,865.0 4,080.0 4,080.0 '12/29/2008 32.0 SLOTS Alternating solid/slotted __ pipe 13,958.6 14,021.5 4,079.3 4,079.2 12/29/2008 32.0 SLOTS Alternating solid/slotted INTERMEDIATE;34.4-10,620.2 SLOTS;10,810.0-10,671.0 _ pipe 14,146.5 14,892.2 4,080.0 4,080.4 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 14,986.4 16,768.0 4,079.9 4,076.4 12/29/2008 32.0 SLOTS Alternating solid/slotted SLOTS;10,890.1-12,329.3 - pipe -. 16,862.0 17,802.9 4,074.9 4,069.7 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe SLOTS;12,450.4-12,674.2 - I - Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date - - 150,000.0 147,452.0 2/21/2018 Stimulations&Treatments SLOTS;12,892.8-13,677.0 Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Stiml Treat Fluid )bbl) Vol Slurry(bbl) 1 10,610.0 17,802.9 2/21/2018 20 lb Borate,Gelled Salt Water 2210.00 2366.00 _ - Mandrel Inserts SLOTS;13,771.0-13,865.0 St ati - on Top(TVD) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com - I - 1 7,882.0 3,384.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2009 SLOTS;13,958.6-14,021.5 2 9.172.7 3,770.5 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/25/2018 HIGH - - SEAL ABILI Hydraulic Fracture;10,610.0 - TY SLOTS;14,148.5-14,892.2 PAC KIN Notes:General&Safety ! - End Date Annotation SLOTS;14,986.4-16,76e.0 1/5/2009 NOTE:VIEW WELL w/Alaska Schematic9.0 - 12/1/2011 NOTE:FREQUENT SSSV BRUSH&FLUSH PROCEDURES SLOTS;16,862.0.77,802.9 LINER;10,443.0-17,837.4 v. • I HALLIBURTDN Sales Order,* 904659562 ConocoPhillips Alaska Inc CD2-468 Interval 1 Qannik Formation Harrison Bay County, AK API: 50-103-20587 Prepared for:Hanna sylte February 21, 2018 Stimulation Treatment Post Job Report Borate 20# Prepared By: Jonathan Alcantar Alan Kaiser Alaska 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. S PrnAurt�f1� I HALLIBURTON e ti...e..n.e+t Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval Summary 5-6 Well Summary 7 Interval 1 Plots 8-13 Appendix 14 Chemical Summary 15 Planned Design 16 Water Straps Day 1 17 Water Report 18 Bacteria Testing 20 Lab Testing 21 15-Min Fann 22 Real-Time QC 23 Event Logger 24 ConocoPhillips Alaska Inc-CD2-468 TOC 2 i Engineering Executive Summary On February 21,2018 a stimulation treatment was performed in the Qannik formation on the CD2-468 well in Harrison Bay County,AK. The CD2-468 was a 1 stage Vertical Sleeve Design. The proposed treatment consisted of: 1,680 gallons of Freeze Protect 7,910 gallons of 20#Linear 82,350 gallons of 20#Borate 150,000 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: 2,308 gallons of Freeze Protect 7,985 gallons of 20#Linear 82,524 gallons of 20#Borate 147,452 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: During the treatment the sand castle was having issues with frozen sand.As a result we had trouble with the 3 ppg.At the end of the treatment the castle was not able to keep up with 4ppg. 4670 lbs were left in the castle. 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-CD2-468 Executive Summary 3 . • ct MI El El - - c' ,1, 11 e g8.F?W l «= , m ; q § k 8888 ,9 :28888 ,9 :2 ; ! \ - - « e ) \k § . . , '-' -' � 2 , , , . % 9 / ) \ :,34 . . . . . j \ , , , , 99 ! § ! ! ! ! ! ! \ m « G %; & @F\\ ) \ § $ E EFU \ 7 ] % . ,rlL , , . f } § \ ) \ k ! / ! f ] -V-1 _. k 8- \ jkkk \ 01 \ \ ( \ ( /ƒ t2 § 0 � ) k ! ! - @ , 0 , : « § - - , , , , , , , , , ,liE ' r 17,1 |E2 . ® 8 Ti 40 \ r . ; ® ! � ! = m ' ® - � § 2 R - , la ; RE# 76 - | - - - - - : \ - { / « ) ! . � , 83383 S \ : �\ \ ) ! ! i - \ , ,17, ) 1 \{ § § ! ( « # , , 00 § ® ° � � ` q R , , , {\ : \ ! q ! 2 E0 L .. » ! ) / ) ) 11, \ { § » / ! ! ! ii ) ) 6 ! ! \ ; ) ; 2a - ; ; ® ,, \ \ \ � � \ I $ \ / _ § , \ , , , �, , ` ) }! , , , LO , , , , e = ; « co- ` � _ . , . . . . . , 0. ) ) so-o e : , , e lir 0 Interval Summary CD2-468-Qannik-Interval 1 Interval Summary Date: 2/21/2018 Start Time: 9:43:00 AM End Time: 12:04:00 PM Initial Rate(Breakdown): 14.7 bpm Initial Pressure(Breakdown): 2926 psi Max Rate: 24.3 bpm Max Pressure: 3475 psi Max Pressure(SLF): 3475 psi Average Rate: 23.1 bpm Average Pressure: 2876 psi Average Missile Pressure 2885 psi Average Missile HHP: 1636 hhp Average Visc: 13 cP Average Temp: 73 F Average pH: 9.2 ISIP: 430 psi 5 min: 261 psi 10 min: 173 psi 15 min: 110 psi ISDP: 817 psi 5 min: 696 psi 10 min: 667 psi 15 min: 644 psi Proppant Summary Wanli 20/40 Pumped: 147,452 lbs Total Proppant Pumped* : 147,452 lbs Proppant in Formation: 147,452 lbs Fluid Summary(by fluid description) Freeze Protect Volume: 2,308 gal 55 bbls 20#Linear Volume: 7,985 gal 190 bbls 20#Borate Volume: 82,524 gal 1,965 bbls Fluid Summary(by stage description) Load Well Volume: 1,008 gal 24 bbls MiniFrac Volume: 12,609 gal 300 bbls Flood Lines Volume: 2,308 gal 55 bbls Pad Volume: 14,996 gal 357 bbls Proppant Laden Fluid Volume: 54,919 gal 1,308 bbls Flush Volume: 6,977 gal 166 bbls Treatment Volume: 92,817 gal 2,210 bbls Total Fluid Volume: 92,817 gal 2,210 bbls Interval Status: Completed Comments: See notes I Engineer: Jonathan Alcantar Interval Summary 5 • I • • Treater: Chad Burkett Supervisor: Alan Kaiser *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may varyslightly from this number. Customer Rep: Hanna Sylte Interval Summary 6 410 ill o ,, a ooae ' s l'- '72, 1 o m o7 a a 1 1212 0 n a 0 0 w n` a 22 2 8 ry o a v ° . 02 ti ° a .y a. v Y 3 3 v m w 3 a E Y nwF o 7, ' ' 9 N N 6 9 s32. 84 — — 3Ema T. Ig r I E c v a a 0 m m = m m 0 0 tt tt SI a n co mm a o $ n n n (`o E E v v v 0i a`0 a v LI-. 1%! LL ii m 2 0 T.p Ta 7 M QE Rn, E n _ g a `w E a' a a aLO m N o U u Y c o 'c Y a a (o V d o u (° Q a r9 W a L E = 8 a • o E _ 10 y 0 E .. n z u H1 - E _ c v O u° LL 0 3 U . • 00 e r N ON a _ 0 a,..., `I N ,- O' o N E • • CO N O = a N r N iti d an an O O O Rif N - W 00 0 01 lJ m 0 0 0 0 N in . N a Zya C ._- ( 0 J N .N CD NY N a N N C o o -a a }' Hd N o o c Na)I— _S E_ J 5 U7 N •� p� W rn m rn a • O (m .s s o g IT 2 N 1- 1- F H - � N N N N ap N N N N a a` a` a` y fV❑ "❑ ❑ ❑ a _ d 0 00 N _ 0 ci ED. E o N Y N y U <p aY Lc) Toa - o a a aoiV - o F- = U S S 8 8 M N a 0 u • S o0., v� ro, e C 01O E N 8 N N . a a 2 M co \ i N Ct N n `o • Y O 0 a V C c.) _I m N �a -5 Woo y MTo dw N Q Q N N - I 0 it) lief m m y I F- F- ' d E N > LO Ch d N a I o n` - ❑ ❑�- N ii 2 Y a MR m 713 'n O V a F- = _ 0,1 1 I a 0 0 0 V ! 0 0 O If) 0 U) U to c'> N d o in O in O U) O m tOnin o co M N NLO 0 U) 0 da m U ® . 1a O ro N N N U L s 2 fl O r ® o C "u5 ci - E O a - c O O E 1.--\\\_...._co a) L TO Is s Q N• U �_ a c � . o mU O°°° j i o N n I OA D_ o I - Ca .775 E irc: a 2 = o F- (7 1 I I __-F I T I I T I $ oo 0 0 0 0 pO 0 0 0 00 Q S (O N O V O O N OD V V CO CO N N N ,- , _ 0 0 u • • r 0 U) 0 U) U U) f") fV O O In 0 In 0 In 0 a- a- .- Oi 1-: (0 M O I I , I , I I I I I I I I COS , f , 1 k () , ) , N . N , 7 , - , U) 0 i CO U I ✓ pp • N lq a L N- r C C T N 2° ) - ccf N m n - C Q a — d .. Ocnm N E v a < 0 T.. F= c - CD 1111t- N H 8 m N U n C p 2 0 0V Nc �tR N n ^ON n a o - c d e F I I I I 1 1 1 I 1 0 • • 0 M N N N O) (O M O 1 , I 1 I . 1 t L , L , l I O to 0 t() 0 In 0 U) O u) O m 0 V M M N N , OO , l 9 Q CO i • N o)_ -_..0_ m /I� 8m - .- N C 8-- Y O t No r no V) m M ♦- • c6 aQ z U 0 at Nv¢ Q r • _ H t v U o C i 11 - as N L N O a0e (0 l0 c6 O to 22 0 Om 9 t6 O OR U O1v _ aN O• Cci N • O r ;7;5 v U 3 O - O r v - m to N 0 (D M O M N N N .- ,- ,- O 0 O O a 0 0 V . 0 m Li) v M N ,- O d 9 e 1 t 111 g T- O TO N C o • m to N d +-0 i m U a) Z c E O it Z--6 a, e N U H 6. a U e 41111 CO aV To CO Q U a E. N 2 C II Z CO CO N {= IP o on m .n 4 A n IAmn m A 4 A w V I § 8 - 0 V • HALLIBURTDN Sales Order# 904659562 ConocoPhillips Alaska Inc CD2-468 Interval 1 Qannik Formation Harrison Bay County, AK API: 50-103-20587 Prepared for:Hanna sylte February 21, 2018 Stimulation Treatment Appendix - Chemical Summary - Planned Design - Water Straps Day 1 - Water Report - Bacteria Testing - Lab Testing - 15-Min Fann - Real-Time QC - Event Logger ConocoPhillips Alaska Inc-CD2-468 Appendix 14 P • I ti tro m N N u C C O E > M N U Y U U 0 a y v) 0 Lil U1 v) oC Q 01 6 C Q W N ` -- m E Z Ei O LO @ M a u V N N E 3 m J J M _ 4 u crl x 0 01 ON1 N I ul 0J a+ 'o i1 u Q J O O O O � 1.3 v a cc Y0' Vf J Q 0 .- 00 N 0 U1 N M oo O Y▪ co M ON 01 01 Ol a U •- til N O O- N 0 U 0 C C N U O ca O O U C7 U u1 N I):- c (p Q Y Era 1 E Ta a v Q I- C = > y co E a CU C _N 11 41 i1 pi ` H Q. a O c 41 d 0 O ul CU v�1 L f0 d -. 4! \ 0 L.) U. 4¢ c = 3 u • E m ° g 6 0 0 0 0 0 0 6 Lc:zi - .d m n o n • k ID ? E a -:s,• d a es o 0 0 0 .. E ` A n n n O 0 0 0 0 0 0 0 m . 3 a ry ry ry o 0 o ry ry 3 - .-. 3 ¢ m o 0 ',-'- o Q 3 V1 q a .i .y .� .v .� .y U ` g V a O .im n -7. V m 00 m E Vo a " N .y .y ti U ` W V a o Q O O OO O -• O r+ ..=, O O OE m t o r .Y r ti ti ti n ,41 O , O M o a 8 ry O o ry c,43 00 n Z 2 v o 0 o v o -oo o 2 5 2 I- 052 N 0 1Ego8 o a g = m ot o 0 0 0 0 0 0 0 a G ° DO m a q m .. ry O r :i 0 K ' o o N N Fl m a m m m m �., m � ry 0 u E ^ ^I' ry ry 0 o0 a a m m a n ry a i N m ] N ,1A - O ca O % m m 2 N C C o f0 a D E o o — a W l0 O ti C C .'A ii," Fi Z.7." E Q ry',, ry ry ry ry ri ry ry '^ b 8 ,, m a ce p n o ry o o 3 u a a va, o v a a o 0 0 0 Z. o 3 3 3 3 Y o = a 3 y o LL LL o r 0 E: a d a 8OU C 00 o o - - V 2 m m m Y N 1' Q — SC m m m .-i n Q 2 I. LL N ry ry ry SC it 43C N ry ry ry ry ry ry m m U Q O, * w LL LL 8 U ti 2 C U fd Y gm'g , NmOv, IOI-- os O, 2 _I .' .y N 2 O O. E . A.H0-0@7 0 LL .9n a Hlu uep O u O v L leI O U • Customer: ConocoPhillips Alaska, Inc. We l l: CD2-468 Date: 2/21/2018 Zones: Treatment 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 PCI Step Front Tank 103 19,368 461 95 99 18,595 443 2 PCI Step Front Tank 103 19,368 461 94 73 13,565 323 3 PCI Step Front Tank 104 19,562 466 95 31 5,277 126 4 PCI Step Front Tank 106 19,949 475 93 8 1,079 26 5 PCI Step Front Tank 105 19,755 470 92 9 1,262 30 6 PCI Step Front Tank 106 19,949 475 94 9 1,262 30 7 PCI Step Front Tank 108 20,336 484 95 15 2,357 56 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Transport TOTAL: 138,286 3,293 TOTAL: 43,398 1,033 Minus 50 bbl bottoms 2,943 Water summary Starting(gal) Used(gal) 94,889 Starting(bbl) Used(bbl) 2,259 ConocoPhillips Alaska Inc-CD2-468 Water Straps Day 1 17 i • HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocoPhillips Alaska,Inc. Well Name/No.: CD2-468 Date Tested: February 20,2018 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 — 1.025 1.024 1.024 1.024 1.025 1.0250 1.0250 PH — 7.3 7.2 7.2 7.2 7.2 7.2 7.19 • Iron(Fe) mg/L 0 0 0 0 0 0 0 Chloride(Cl) mg/L 22770 19170 20880 36500 24880 36500 29940 Sulfate(SO4) mg/L 800 800 800 800 800 800 800 Hardness mg/L 2500 2500 2500 2500 2500 2500 2500 Linear Viscosity cp 16 15 16 15 15 15 15 Crosslink pH pH 9.01 9.05 9.1 9.11 9.06 9.06 9.03 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 M Iron(Fe) mg/L Chloride(Cl) mg/L Sulfate(SO4) mg/L Hardness mg/L Linear Viscosity cp _ Crosslink pH pH Crosslink Test(Y/N) Units Tank 19 Tank 20 Tank 21 Tank 22 Tank 23 Tank 24 Tank 25 Specific Gravity — pH Iron(Fe) mg/L Chloride(Cl) mg/L Sulfate(SO4) mg/L Hardness mg/L Crosslink pH pH Crosslink Test(Y/N) This report is the property of Halliburton services and neither it nor any pan thereof nor copy thereof may be published or disclosed without first securing the express written approval of laboratory management.It may however,be used in the course of regular business operations by any person or concern and employees thereof receiving such report from Halliburton Services. NOTICE:This report is limited to the described sample tested.Any user of this report agrees that Halliburton shall not be liable for any loss or damage,whether due to act or omission,resulting from such report or its use. ConocoPhillips Alaska Inc-CD2-468 Water Report 18 • • s alz • v . ry N ry 0 W N E N W E a a = M to mNtootiui . 2. 00 a en o n ` m .-1 a m N .4 co o c v o y w a > Is v E T 9 a sem+ N >, -p d Ol 2) .. W c d N i> E E E E E o d l� �Ra < ao mu" O M ti m l00 Ct N m Ln n .+.+ 0 n a, com ry j Ts a t... .n f v c w O a v J O1 0 C w 1 0 0 0 0 0 0 0 u1 0 ul 0 ul of of r E 0 m 0 g 22w E E d E >° D w E , u n— c 0 0 E a a In x CO CI" 0 CO 00 CO 00 m a u) ul of . ul N N 0! m to l0 l0 l0 u) N q) C 10 8 10 N c• LL a _ 0 0 0 0 0 0 0 w m m CO CO m m m E O ^, E c al E 0: 00 O m < a a a a a a O1 b N a. 'a. .a-1 .a-i .ai fa. fa. m a E 0 a E m o O v u -0> g a2 w -o 10 . m r E = ' 61 Itw c v ' 0 o A `o Ea w .yrvmaln ,,,L0 ,r, P'. TEE -2 'e « g .t e m c t w c m 'n Ery c c c c c O a U K .., . - m V1 F F I� H f H !� �` • • I--I A LLI E LJ R r NI Prudhoe Bay Field Laboratory-Rockies NWA Laboratory Project ID Number: 2056494-1 Customer: ConocoPbilbps Well Name&Number: CD2-468 Fluid System: Hybor G Date: February 20.2018 irst minutes at +see at Ree, Alter 10 nnnutes the shear rate was decreased to 100 1'sec All testing wan done wins Locatto=Seawater(SLe681)and Field Cheurucals(SLe565) TechuL::a s. Parto[narns Tesuaa Araart=t S'.omson P stewed A Approved By. ConocoPhillips Alaska Inc-CO2-468 Lab Testing 20 i • JOB INFORMATION AND TESTING CONDITIONS 1 Customer. Co oocoPatllaps Fknd S3steta Hybc Cr Bob Tape. B' We11 Name CD2-o63 Rater Source- Seawater Sbear Kate t:sec. 511 100 Date- Febttta,-:0 101E BHST(F) 90 Lab Project ID 2056494-1 - FLUID DESIGN Test No. - _ _ 004 476144.140 011:0 Lot# C bem.cal Deets C1e4•0001C00Ceatr041040 Man 1-0201.a,..cp; 7.zp cr: 11",-36 pp/ 20 00 l 6.0 10[-6 pp 015 _ y__ 100 __ 1.054331 300L w 100 .. 3 120 Si 0131 Fr 4 12 0 S: 120 9] Car 3 PPr 1 CC ' 12 0 PO 1 120 l0 S 120 t0 10 12 0 IO , Fl UID PROPERTIES est No. 1 2 + - �a} Water pH '33 5..31 Mee Viscoas(cP:4 7440 tor: Base Gel(0) 20 00 20 00 1 3 C IC0 Base CelSt.(cP) 140 1420 10.0 160 Base GelpH , , 562 3 110 100 Base Ciel Tem0 Temp l') 50 'C11.0 100 Buffered pH s 1120 100 Crosslank pH 401 892 6 11.0 300 Das]pH 1348 1360 I 11.0 100 Teat Ttatp_CF) 90 9C 4 11 0 100 Tin.BreaTin.{Lr man)` 3 - -16 9 11 0 100 1C _ 11.0 100 BRF_16 1001 4 11.1HI ..........raw ...a... 2222_2222 seste e.. —...,.rt.. w..... w 2222,,, .-,e.r.4... ........... r 4...........___r�..r..e.. r�.r...... -_--._.-1. .0 .. 220 __2_2 2 2 _---- .0 1. iii ,Imilliimmilm,„ . I_ _.__ b �� 40 toe _- ��/�r.�......_ 2222. ----- ao e_{ --T — --r-- -- — — 000 012 634 1.3e 4:ee 400 7:12 4:24 41440.0.004 ConocoPhlllips Alaska Inc-CD2-958 labresting 21 • Rind la beckon at 200cp Zone 1 Crosslink Tests —Ped —1 ppg —2 ppg —3 ppg —4 ppg —5 ppg 3500 3000 1 - - 2500 N • a `� 2.2000 i .. — .7".........."---\,,,.../ss, , 1500 /�/'_'� _ 10 S 1000 / 500 /�� 0 0000 01:00 0200 03:00 04:00 05:00 06:00 07:00 08.00 0900 1000 1100 1200 1300 1400 15-00 i Tim,(mtn:we) Conomphillips Alaska Inc-CD2-462 15-Min Fann 22 • HALLIBURTON Customer: ConocoPhillips Alaska,Inc. W el lnatne&8: CD2-468 Date: February 21,2018 XL Linear Linear XL Interval Stage Visc pH Temp°F pH Comments Interval Stage Visc pH Temp°F pH Comments Mini-Frac 14 70 9.31 II Pad Pad 12 70 9.2 14 IS 12 70 9.1 2# 20 12 75 9.2 3# • 30 13 75 9.1 4# 40 13 73 9.1 5# 6# 2 Pad 12 Pad 1# 1# 29 2# 3# 3# 4# 4# 5# 58 6# 68 3 Pad 13 Pad 1# 1# 2# 2# 3# 39 4# 4# 5# 59 6# 6# 4 Pad 14 Pad # 1# 2# 29 3# 3# 4# 4# 5# 5# 6# 6# 5 Pad 15 Pad 19 18 2# 2# 3# 3# 4# 4# 5# 5# 6# 6# 6 Pad 16 Pad # 1# 2# 26 3# 3# 49 49 5# 5# 69 6# 7 Pad 17 Pad 1# 1# 2# 28 3# 3# 4# 4# 5# 5# 6# 6# 8 Pad 18 Pad 1# 1# 211 2# 3# 3# 4# 49 5# 5# 6# 6# 9 Pad 19 Pad 1# 1# 2# 2# 3# 3# 4# 4# 5# 59 6# 6# 10 Pad 20 Pad # 1# 2# 26 3# 3# 4# 4# 5# 5# • 69 6# • I. 110 • Treating Calc'd BH Slurry Rate Job Clean Job Slurry Job Hydraulic Pressure Pres Vol Vol Proppant Power Type Time Activity Code Comment (psi) (psi) (bpm) (gal) (gal) (100•1b) (hp) E 07:53:56(02/21/18) Start Job Starting Job 0 0 0 0 0 0 0 E 8:55:31 Pressure Test Pressure Test-Testing Locals 43 1816 0 0 0 0 0 E 8:57:51 Pressure Test Pressure Test-Testing Globals 1303 1816 0 0 0 0 0 E 9:02:14 Pressure Test Pressure Test-Testing 5500 psi 5522 1816 0 0 0 0 0 E 9:05:00 Pressure Test Pressure Test-5500 psi 2nd set of pumps 5462 1816 0 0 0 0 0 S 9:33:22 Pressure Test Pressure Test-N2 Pop Off 4481 psi 102 1816 0 0 0 0 0 E 9:36:22 Pressure Test Pressure Test-N2 sencond test 4488 psi 153 1816 0 0 0 0 0 S 9:44:20 Next Stage Load Well 52 1829 0 0 0 0 0 S 9:53:32 Next Stage Fluid Efficiency Test 2847 2442 13.3 1008 1008 0 922 S 10:09:08 Next Stage Flush 2695 2242 22 13617 13617 0 1458 S 10:13:50 Next Stage Shut-In 411 2250 0 17584 17584 0 0 S 10:27:40 Next Stage Pad 111 1948 0 17584 17584 0 0 S 10:43:46 Next Stage Proppant Laden Fluid 2990 2077 24 32579 32579 0 1757 S 10:54:17 Next Stage Proppant Laden Fluid 2746 1874 24 42714 43157 99.87 1617 S 11:07:45 Next Stage Proppant Laden Fluid 2730 1854 24.1 55217 56742 343.43 1609 S 11:23:11 Next Stage Proppant Laden Fluid 2937 2134 24 69156 72310 710.42 1729 S 11:44:34 Next Stage Flush 3071 2235 23.5 87499 93629 1380.59 1767 S 11:47:54 Next Stage Other 3082 2902 23.6 90510 96643 1381.32 1765 S 11:57:08 Next Stage Shut-In 678 2305 0 91348 97481 1381.32 0 E 13:06:55 End Job Ending Job 12 1638 0 91348 97481 1381.32 0 Conecophillips Alaska Inn-CD2-468 Event Logger 24 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ SC repairs 0 2.Operator ConocoPhillips Alaska, INC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory❑ 208-180 3.Address: P.O.Box 100360,Anchorage Alaska 99510 Stratigraphic ❑ Service❑ 6.API Number: 50-103-20587-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025529/ADL0025530/ADL0380075/ADL0387212 CRU CD2-468 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Coville River Field/Qannik Oil Pool 11.Present Well Condition Summary: Total Depth measured 17,837 feet Plugs measured NA feet true vertical 4,071 feet Junk measured NA feet Effective Depth measured 17,837 feet Packer measured 9,262 feet true vertical 4,071 feet true vertical 3,797 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' NA NA Surface 4,476' 10 3/4" 4,513' 2,387' NA NA Intermediate 10,586' 7 5/8" 10,620' 4,076' NA NA Production Liner 7,394' 3 1/2" 17,837' 4,071' N l®1�/QED Perforation depth Measured depth 10,610-17,803 feet True Vertical depth 4,074-4081 feet JAN 1 / 2018 Tubing(size,grade,measured and true vertical depth) 3 1/2",L80,MD 10,465',TVD 4,064 AOGCC Packers and SSSV(type,measured and true vertical depth) Baker Premier,MD 9,262',TVD 3,797,Camco TRMAXX-5E,MD 4,506',TVD 2,384' 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA t Treatment descriptions including volumes used and final pressure: SCANNED JAN 3 12018 18 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development0 Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-574 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Sup rvisor Contact Email: N1927a,conocophillips.com i/eztAuthorized Signature: Date: ///y/is'g Contact Phone: 659-7506 Form 10-404 Revised 4/2017 /�� �.!i 4 1 9 RBDI 11 Lv�; t7 1 6 2G1 Submit Original Only • • ConocoPhillips Alaska r P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JAN 1 / 2018 January 13, 2018 AOGCC Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. CRU well CD2- 468, PTD#208-180 Sundry# 317-574 for repairing the surface casing leak. Please contact Roger Winter/Roger Mouser at 907-659-7506 if you have any questions. Sincerely, lem../ Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Summary of work 10-404 CD2-468 Wellbore Schematic Pictures damage &repair • • CD2-468 Summary 11/26/17 Leak in OA appears to be 27" below OA flange. 12/24/17 Remove conductor and locate hole at 16" below bottom of flutes. 1/9/18 Install 2'2" 10" X65 .500 wall sleeve over damaged area. 1/10/18 Pressure up to 1,230 psi and hold for 30 minutes to confirm no leaks to surface. • Li i WNS PROD • CD2-468 • i! onoc ) f il��lpS ; Well Attributes Max Angle&MD TD t Af2SkaInc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) e arrnca061etps if 501032058700 QANNIK PROD 94.30 10,863.34 17,850.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD2-468,11/222017 11:4229 AM SSSV:TRDP Last WO: 36.981 1/4/2009 .....Vertical schematic{actuaq... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,31 4� Last Tag: Rev Reason:PULL RHC PLUG,GLV C/O(#3 to pproven 11/22/2017 ..__. ...__ 4..- II�I ._ HIGH SEALABILITY PACKING) Casing Strings S,1 Casing Description OD(in) ID(In) Top(MB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread + " I, CONDUCTOR 34" 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated �; �'� . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread ' CONDUCTOR 34"Insulated;___o - y SURFACE 103/4 9.950 36.7 4,512.9 2,386.8 45.50 L-80 BTC-M 37.0-1140 I Y Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread it INTERMEDIATE 75/8 6.875 34.4 10,620.2 4,075.8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread LINER 31/2 2.992 10,443.0 17,837.4 4,070.9 9.30 L-80 SLHT Liner Details Nominal ID' Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Coin (in) 10,443.0 4,062.5 85.83 SETTING SLV Baker"HR"Liner Setting Sleeve 5.000 10,455.7 4,063.4 85.85 NIPPLE Baker"RS"Packoff Seal Nipple 4.910 11 10,458.2 4,063.6 85.85 HANGER Baker 5 1/2"x 7 5/8"Flex Lock Hanger 4.940 SAFETY VLV;45050 .•••=-- 'I'.1Ii....., Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...WI(lb/ft) Grade Top Connection SURFACE;36.7-4,512.9- VIT TUBING 31/2 2.992 31.4 4,496.4 2,381.3 12.60 L-80 IBTM 4.5"x3.5"@149' Completion Details j Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.4 31.4 0.00 HANGER FMC 41/2"Tbg hangerw/2.27'pup 4500 GAS LIFT;7,8820 1, 149.0 149.0 0.08 XO-Reducing XO-3 1/2"IBTM(P)X4 1/2"IBTM(B) 3.500 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)1...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 4,496.4 10,464.7 4,064.0 9.30 L-80 IBTM al Completion Details Nominal ID SLEEVE;9,089.7 :.aF_ Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 4,506.0 2,384.4 70.47 SAFETY VLV 31/2"Camco TRMAXX-5E SSSV w/2.813"profile S/N# 2.813 11 CXS0065 .11 9,089.7 3,746.2 72.67 SLEEVE Baker 3 1/2"CMD Sliding Sleeve(2.812"ID WP'BX" 2.812 GAS LIFT;9,172.7 - Profile) -` '. 9,261.7 3,796.7• 72.61 PACKER Baker 3.5"x 7 5/8"Premier Packer 6.58"OD x 2.87"ID 2.870 9,340.1 3,820.7 71.82 NIPPLE HES XN Nipple W 2.750 PACKER;9,261.7 -_ -_ 10,463.7 4,064.0 85.86 WLEG WLEG 2.980 NIPPLE;9,340.1 -T-,‘ Perforations.&Slots ,;� ',��',le Shot Dens r i Top(TVD) Btm(TOD) (shotstt + Top(ftKB) Btm(ftKB) _ (ftKB) (ftKB) Zone Date t) Type Com Ili 10,610.0 10,671.0 4,075.0 4,080.0 12/29/2008 32.0 SLOTS Altemating solid/slotted pipe 10,890.1 12,329.3 4,083.0 4,074.3 12/29/2008 32.0 SLOTS Altemating solid/slotted WLEG;10,463.7 I, pipe 12,454.4 12,6742 4,073.6 4,080.8 12/29/2008 32.0 SLOTS Altemating solid/slotted pipe 12,892.8 13,677.0 4,080.4 4,078.5 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 13,771.0 13,865.0 4,080.0 4,080.0 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 13,958.6 14,021.5 4,079.3 4,079.2 12/29/2008 32.0 SLOTS Altemating solid/slotted pipe INTERMEDIATE;34.4-10,620.2,_.* ,._ 14,146.5 14,892.2 4,080.0 4,080.4 12/29/2008 32.0 SLOTS 'Altemating solid/slotted SLOTS;10,610.0-10,671.0�_... ...,, pipe -.011 ...,, 14,986.4 16,768.0 4,079.9 4,076.4' 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 16,862.0 17,802.9 4,074.9 4,069.7 12/29/2008 32.0 SLOTS Altemating solid/slotted SLOTS;10,890.1-12,329.3 pipe Mandrel Inserts St SLOTS;12,454.4-12,674.2 at, 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 7,882.0 3,384.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2009 2 9,172.7 3,770.5 CAMCO KBMG 1 GAS LIFT OV RT 0.250 0.0 11/18/2017 HIGH SLOTS;12,892.8-13,677.0 _ _ SEAL ARIL! TY PACK! N SLOTS;13,771.0.13,865.0 Notes:General&Safety /.14;ithintitiN.ol11 iiil1pliilid r End Date Annotation 1/5/2009 NOTE:VIEW WELLw/Alaska Schematic9.0 SLOTS;13,958.6-14,021.5-1: 12/1/2011 NOTE:FREQUENT SSSV BRUSH&FLUSH PROCEDURES SLOTS;14.1465-14.5522 SLOTS;14,986.4-16,7680 SLOTS;16,862.0-17,8029 LINER,10,443.0-17,837.4 -. 't*:',..*' it„*, , „*Allr‘ 4, '411 4 �€ m °R s r .711 i, ' :. $ a - .fes a/+� fir' xi k F 4 >E _ i 3 s c • • ',?t4 41 F , a uIT 4184 I A Frights reserved. This 7 ovided to he AOGCC with ' y •y for its own use. Copying pose or by any other party eat the express consent of ska, 1nc.' • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 70,�( h - DATE: 1/7/2018 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Casing Repair Petroleum Inspector CRU CD2-468 CPAI - PTD 2081800; Sundry 317-574 1/6/2018: I traveled to Alpine and met up with CPAI Well Integrity representative Roger Mouser and drove out to the CD2 drill site. Well CD2-468 has been identified as having a casing integrity issue after a failed Tubing Integrity Fluid Level (TIFL) according to Mr. 4 Mouser. Further diagnostics indicated a surface casing leak approximately 27 inches below the casing landing ring. The well house remained over the well and the cellar intact due to the shallow depth of the leak. Prior to my arrival, conductor piping had been cut and removed to expose the surface casing, and the leak was plugged ✓ temporarily until they can weld a patch. Mr. Roger Mouser will update progress as work proceeds. Attachments: Photo SCOW - 2018-0106_Surface_Casing_Repair_CRU_CD2-468_mh.docx Page 1 of 2 0 Surface Casing Repair— CRU CD2-468 (PTD 2081800) Photo by AOGCC Inspector M. Herrera 1/6/2018 ' 1111 i, , 4y ® I" 4 ...._, . ,,,,..,--"it,,,,k.t.,,,,,,,,,.._., ,.. --,-.1'''''''',..',..i: ::::.:i. , it: :,....-.114, j:, ..1::_,‘. ...i4.4......,,Y.,..: 41, ,yG„� 't �* „` '.fir _. - N- ►� ,sem. ) 7 ., t K J.;" y. �rt Temporary plug i in surface casing • 'trip., i r 2018-0106_Surface_Casing_Repair_CRU_CD2-468_mh.docx Page 2 of 2 • • 24V), 0 WELL LOG TRANSMITTAL#904417539 To: Alaska Oil and Gas Conservation Comm. December 20, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGEDAVOlt Anchorage, Alaska 99501 K BENDER DEC 2 2 2017 AOGCC RE: Multi Finger Caliper Log: CD2-468 Run Date: 11/4/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-468 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20587-00 Multi Finger Caliper Log 1 Color Log 50-103-20587-00 SCANNED " SF PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: ' ✓adv - / `Ei;e"-C of TFJ • 0,14 \���,�s THE STATE� Alaska Oil and Gas ti111 ►"!-��iA� LAsKA Conservation Commission 4.2 is 333 West Seventh Avenue ITh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 QA' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Well Integrity Supervisor s HgEo JAN 2 6 z0V6 ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Oil Pool, CD2-468 Permit to Drill Number: 208-180 Sundry Number: 317-574 Dear Mr. Smith: 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, 142E2cir — Hollis S. French Chair 4 DATED this (3 day of December, 2017. R8D iS L � �� r + ° i7 Q .�-s l 2`/3/i? , . • 'E1VED • STATE OF ALASKA DEC 0 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 2 ` Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ SC Repair Q, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q+ 208-180 A 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ P.O.Box 100360,Anchcorage,Alaska 99510 50-1032-0587-0000 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • CD2-468 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025529/ADL0025530/ADL0380075/ADL0387212 • Colville River Unit/Qannik 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): 17,837 • . 4,081 17,837 4,081 NA NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 114 114 Surface 4,476 10% 4,513 2,387 Intermediate 10,586 7% 10,620 4,076 Production Liner 7,394 3'% 17,837 4,071 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,610-16,862 + 4,074-4,081 3-% L-80 16520 Packers and SSSV Type: SSSV:Camco TRMAXX-5E Packers and SSSV MD(ft)and TVD(ft): 4,056'/2,384'• Packer:Baker Premier 9,262'/3,797' 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑, ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/1/2018 Commencing Operations: OIL 2 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: NA 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: Travis Smith Contact Name: Travis Smith/Rachel Kautz Authorized Title: Wel ntegrity Sup��''�- Contact Email: N2549(C7conoCophillips.com Contact Phone: 659-7126 Authorized Signatu• �� ilk0 Date: 12/2/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n S n • 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Er Other: /Ph0 71-0 Gi0 G v KY,tv pro e t of vim,- Post Initial Injection MIT Req'd? Yes ❑ No V RBS 3,'r sS ,' h,�,, 4 2617 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6 — i 7 . f 6a—C2APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: (-Z- l t 3 C 6 ,11 �I i1 / " /e/7-(>67 VTL /2/fi' l/� �'\ McAt Submit and ZForm 10-403 Revised 4/2017 Approved application is vane() f approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 D E C 0 7 2017 ANCHORAGE,ALASKA 99510-0360 AOGCC CC December 2, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. CRU well CD2-468 (PTD#208-180) for repairing a surface casing leak. / Please contact Travis Smith/Rachel Kautz at 907-659-7126 if you have any questions. Sincerely, ‘01° Travis Smith ConocoPhillips Well Integrity Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approvals CD2-468 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Alpine Well CD2-468 (PTD 208-180) SUNDRY NOTICE 10-403 APPROVAL REQUEST December 2, 2017 This application for Sundry approval for Alpine well CD2-468 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to—20'. 4. Install nitrogen purge equipment for the conductor and OA(if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test(Open OA shoe)to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and return the well to injection. 13. File 10-404 with the AOGCC post repair. • a WNS PROD CD2-468 lir ConocoPhillips 01 Well Attributes Max Angle&MD TD Kaska,Inc. wellbore API/UWI Field Name Wellbore Status Incl(°) MD(BKB) Act Btm(ftKB) icrofoP1Yerps ` 501032058700 QANNIK PROD 94.30 10,863.34 17,850.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-CD2-468,1122/201711'4229 AM SSSV:TRDP Last WO: 36.981 1/4/2009 Vertical schematic(actual) _ Annotation Depth(ftKB) End Date 'Annotation Last Mod By End Data HANGER:31a 111 u Last Tag: Rev Reason:PULL RHC PLUG,GLV CIO(#3 to pproven 11/22/2017 -- -- 11:1,A111 j8HIGH SEALABILITY PACKING) Casing Strings . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread . CONDUCTOR 34" 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded L` ■1 Insulated ^I ,,, I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 34•Insulated; - SURFACE 10 3/4 9.950 36.7 4,512.9 2,366.8 45.50 L-80 BTC-M 37.0-114.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 34.4 10,620.2 4,075,8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..,Grade Top Thread - LINER 31/2 2.992 10,443.0 17,837.4 4,070.9 9.30 L-80 SLHT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) I 10,443.0 4,062.5 85.83 SETTING SLV Baker"HR"Liner Setting Sleeve 5.000 10,455.7 4,063.4 85.85 NIPPLE Baker"RS"Packoff Seal Nipple 4.910 10,458.2 4,063.6 85.85 HANGER Baker 5 1/2"x 7 5/8"Rex Lock Hanger 4.940 SAFETY VLV;4,506.0 "'; Tubing Strings Tubing Description String Ma...ID(in) I Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/fl) Grade Top Connection SURFACE;36.7-4,512.9- VIT TUBING 31/2 2.992`11 31.4 4,4964 2.381.3 12.60 L-80 IBTM - 4.5"x3.5"@149' Completion Details Nominal ID -- Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Corn (in) GAS LIFT;7,882.0- - .__�. 31.4 31.4 0.00 HANGER FMC 4 112"Tbg hanger w/2.27'pup 4.500 149.0 149.0 0.08 XO-Reducing XO-31/2"IBTM(P)X41/2"IBTM(B) 3.500 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 4,496.4 10,464.7 4,064.0 9.30 L-80 IBTM Completion Details Nominal ID SLEEVE;9,089.7- Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) 4,506.0 2,384.4 70.47 SAFETY VLV 3 1/2"Cameo TRMAXX-5E SSSV w/2.813"profile S/N# 2.813 - _ CX60065 9,089.7 3,746.2 72.67 SLEEVE Baker 3 1/2"CMD Sliding Sleeve(2.812"ID WPBX" 2.812 GAS LIFT;9,172.7 E ,9 Profile) 9,261.7 3,796.7 72.61 PACKER Baker 3.5"x 7 5/8"Premier Packer 6.58"OD x 2.87"ID 2.870 9,340.1 3,820.7 71.82 NIPPLE HES XN Nipple W 2.750 PACKER;9,261.7 10,463.7 4,064.0 85.86 WLEG WLEG 2.980 NIPPLE;9,340.1 Perforations&Slots Shot Dens _ Top(ND) Btm(ND) (shoLaf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,610.0 10,671.0 4,075.0 4,080.0 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe till 10,890.1 12,329.3 4,083.0 4,074.3 12/29/2008 32.0 SLOTS Alternating solid/slotted WLEG;10,463.7 pipe 12,454.4 12,674.2 4,073.6 4,080.8 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe • 12,892.8 13,677.0 4,080.4 4,078.5 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 13,771.0 13,865.0 4,080.0 4,080.0 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe 13,958.6 14,021.5 4,079.3 4,079.2 12/29/2008 32.0 SLOTS Alternating solid/slotted - pipe INTERMEDIATE;34.4-10,6202L� ,,as.- 14,146.5 14,892.2 4,080.0 4,680.4 12/29/2008 32.0 SLOTS Alternating solid/slotted SLOTS;10,610.0-10,671.0% .- pipe 14,986.4 16,768.0 4,079.9 4,076.4 12/29/2008 32.0 SLOTS Alternating solid/slotted pipe - 16,862.0 17,802.9 4,074.9 4,069.7 12/29/2008 32.0 SLOTS Alternating solid/slotted SLOTS;10,890.142,329.3 pipe Mandrel Inserts St SLOTS;12,454A-12,874.2-T - a8 - on Top(TVD) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sale Type Type (in) (psi) Run Date Corn 1 7,882.0 3,384.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2009 - 2 9,172.7 3,770.5 CAMCO KBMG 1 GAS LIFT OV RT 0.250 0.0 11/18/2017 HIGH SLOTS;12,692.8-13,677.0 r.rSEAL ABILI . TY PACK! - N SLOTS;13,771.0-13,865.0 - Notes:General&Safety - - End Date Annotation 1/5/2009 NOTE:VIEW WELL w/Alaska Schematic9.0 SLOTS;13,958.6-14,021.5 _ - 12/1/2011 NOTE:FREQUENT SSSV BRUSH&FLUSH PROCEDURES SLOTS;14,146.5-14,8922 SLOTS;14,986.4-16,768.0 SLOTS;16,862.0-17,802.9 LINER;10,443.0-17,837.4 voF T� • • w \ l//7,',s.\ , THE STATE Alaska Oil and Gas ti��►� 7 °f Conservation Commission a 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572,.„ , Main: 907.279.1433ALpSY Fax: 907.276.7542 www.aogcc.alaska.gov Hanna Sylte h•i 2?017 Completions Engineer " ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Oil Pool, CRU CD2-468 Permit to Drill Number: 208-180 Sundry Number: 317-479 Dear Ms. Sylte: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair � r DATED this 'day of October, 2017. RBD&MMS LL'OLf 1 3 2017 • IV STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION CCT 0 6 2017 APPLICATION FOR SUNDRY APPROVALS /07/Z�i 20 AAC 25.280 A0GCc 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑., Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips ` Exploratory ❑ Development Q. 208-180 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20587-00 • 7.If perforating: •fit 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N A- CD2-468 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380075, 025530, 025529, 387212 Colville River Field, Qannik 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): 17,850' ' 4,071' , 17,837'. 4,070' . 5,500 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 4,476' 10-3/4" 4,513' 2,386' Intermediate 10,583' 7-5/8" 10,620' 4,075' Tubing 10,426' 3.5" 10,463' 4,064' Liner 7,394' 3.5" 17,837' 4,071' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 3 1/2" L80 10,463' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Premier Packer,Camco TRMAXX-5E SSSV SSSV at 4506'MD/2,384'TVD,Packer at 9,261'MD/3,796'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/16/2017 OIL ❑., , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ 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. Contact Hanna Sylte,907-265-6342 Email Hanna.Sylte@ConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer a C64— - lobsa19— Signature Phone 907-265-6342 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [`r- 2011 Spacing Exception Required? Yes El No 2( Subsequent Form Required: /0 - *U1- RBicJOCT1 L I APPROVED BY Approved by: C1:2(ff----M -- COMMISSIONER THE COMMISSION Date: { d It Z t �/ /pp R f/'� 1 A SubsinF and Form 10-403 Revised 11/2015 Ap'� cit..,8` ifcation is valid for 12 mo h f +vet pJnt�r Attachments it Duplicate ?Alb {o/u1 i' 0)ki IO//2/2-oi7 • S CD2-468 Qannik Schematic I 1 I L 16"Insulated Conductor to Upper Completion: Top MD TVD 114' Item 1) Tubiig Hanger,444 37 32 3-''/z"x 4-1/2:'cross-o cross-over 2) 444"x 3-Y-Crossover " :_ 4) 3-%"x4-Y_-"VIT Tubing,ISTM 5) Camco TRMAXX SCSSSV • 4506' 2384' 2.813"TRMAXX SCSSSV 6) 3-Y-".9.3#/ft,EUE 8rd Mod Tubing 7) Camco KBMG-GLM(2.867"ID) 7882' 3384' 8) 344",9.3#/ft EUE 8rd Mod Tubing 10-34"45.5 ppf L-80 BTCM 9) Sliding sleeve 10) Camco KBMG-GLM(2.867"ID) 9172' 3770' Surface Casing 11) 3-1/.",9.3#/ft,EUE 8rd Mod Tubing 4512'MD!2386'TVD 12) Baker Premier Packer 12) HES"XN"(2,750") 9340' 3820' 13) WLEG Lower Co moletion• Too MD .IYD Item 14) Baker ZXP Liner top packer 10443' 4062' 15) Baker RS Nipple 10455' 4062' 16) BO3-Baker 5"x 7"Flexlock Liner Hanger 10458' 4063' 3-'14"x 4-1/2"VIT Tubing 17) ",9.3/t/1t,SLHT Tubing+1-23 its 4496'MD/2381'TVD 18) 3-Y-_"9.3#/ft L-80 SLHT liner w/blanks and constrictors across shale and slots across sand19) Baker Shoe wf packoff bushing 3-1/2"9.3 ppf L-80 EUE 8rd Mod Tubing \ \ 3-Y:"9.3#/ft SLIT liner. 8 slots/ft,2-1"x 118"slots 41! ---1 —_ == _ i:=-7-:..---==================-=-=- ' : -- 0 0 0 Baker Premier Packer 9,261'MD!3796'TVDTD 6-3/4"hole 5 constrictors at 10,576',10,676', 17,850'MD!4071'TVD 7-518"29.7 ppf L-80 BTC Mod 10,899',12,336'and 12,450' 10,443'MD,4066'TVD • • 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). TO THEIASKA OIL AND GAS CONSERVATION CO•SION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD2-468 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and 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 October 5,2017,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 5th day of October,2017. Jason E. Lyons STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT This instrument was acknowledged before me this 5th day of October,2017, by Jason E. Lyons. otary Public, State of A� laska STA OF ALASKA NOTARY PUBLIC ` REBECCA SWENSEN ?t My Commission Expires Au•.27,2020. 0 Jason Lyons Staff Landman IP.'" Alaska Land&BO ConocoPhillips lli ConocoPhillips Company ■ 700 G Street,ATO-1478 Alaskahonc r9AK 99501 A se . Office:907-265-6002 Fax:918-662-3472 jason.lyons@cop.com October 5,2017I V A CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operationspursuant to 20 AAC 25.283 (1)for CD2-468 Well P ADL-380075,ADL-387207, ADL-38721 I ADL-387212,ADL-025529,and ADL-025530 Colville River Unit,Alaska CPAI Contract No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") 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 CD2-468 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about October 5, 2017. This Notice is being provided pursuant to subsection of 20 AAC 25.283. i# The Well has been drilled as a directional horizontal well on leases,ADL-380075,ADL-387207,ADL- 387211,ADL-387212,ADL-025529,and ADL-025530 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 2198' 1904' T11N R4E 2 Umiat Top Open Interval 377' 1739' T12N R4E 34 Umiat Bottom hole 3937' 5131' T12N R4E 23 Umiat Exhibit I shows the location of the Well and the lands that are within a one-half mile radius of the culTent 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. If you require any additional information,please contact the undersigned. Sin_erely, l .son Ly taff Landman Attachments: Exhibits 1 &2 IP • i Exhibit 1 ADL380095 AA084140 I•• ADL025529 -•-t -.ADL2553 I Fiord f _ _ 'Nechelik PA i , ADL387211 j ADL387211 _.._ Qannik PA j f ADL388466 j j \ j j 1 cA ov, ADL025530 i I�A% ob vNs,,,.\\. :To o er n � rn t ADL0255580 v,\ ADL380096 I n,an I a � , •, co Qb t_ iADL387212 k d, \me \Lqm ` 1ASRC•NPR2 \`'.�. ' � 1 i21vlklL 1-121,jk5L ADL387207 coal .\` _ ' �i i1l ?F I � i _' COa--`pB/ \ . CD2 rn U ADL025559 0 Frac Points --Trajectory ADL380075 ++®on•Open Interval ®Half Mile Frac Point Radius ! ADIhII$8047 i Kuparuk PA _ Half Mile Trajectory Radius I r"-' -"""-'-'r---j ------- Other Well ! j i 1 -� Qannik Well ! ! Nanu 1 Nanuq PA! L.._.3Alpine PA L..__._.._.._.._.._.._.._ ._.._.._..� ! L.._ Fiord Nechelik PA __ NOTE: There are no faults within _ N ConocoPhillips t.._.., the Half Mile Frac Paint Radius. — ' Nanuq Kuparuk PA I Alaska,Inc. Nanuq Nanuq PA ! CD2-468 1 L........; ; ADL3I L••_• Qannik PA 0 0.2 0.4 0.6 0.8 1 1.2 1.4 Frac Plat [ 1CPAI Leases Miles \ 9/19/2017 ! 1 z r • • Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator&Owner: ConocoPhillips Alaska,Inc. 700 G Street, Suite ATO 1226(Zip 99501) P.O. Box 100360 Anchorage,AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): Anadarko E&P Onshore LLC P.O. Box 1330 Houston,TX 77251-1330 Attention: Frank D. Meyer,Director Land-Alaska Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,AIaska 99503-5963 Attention: Teresa Imm,Resource Development Manager State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501 Attention: Chantal Walsh, Director Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuigsut,AK 99789-0187 Attention: Joe Nukapigak,President • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles ADL380095 AA084141 r-----= ADL025529 ------if L025538 Fiord (•_•.` _,AD 1 / i Nechelik PA j ADL387211 i I Alpine PA' AD L387211 r--"-- I 1 Qannik PA j AD L388466 ASRC-NPR2 \�`,�_ j J t, t ADL025530A'. ' 4 4 . o \ \ i wzd� k z g ADL025558 Iii, 2 Oa a/ i \ '141 ,4411;k,' IA zai,,,,, t', co,„,,,, z61 1 l ' : DL380096� 1 ,, C01.71 ` _"_"! I, T 12 R5EKd � o .� 11 NR5E ' '11.k 4,11.1k cme, ..zze- i CD]-SVB1 � . �� WI 1� ! AD 87.2,078, meg. .-..,,"—"____'"".- 3W-32".1787,5319' I' '°Poi 64 '� o j �y/��,, •CDZ 2e I !4,,/ ='i 1 rr r i i ��D1. D, < 1 \ ADL025559 o e 1 I %., % SNN\ • Frac Points w I ::rval • '' .1111Half Mile Frac Point Radius _ %+ ' g i KuNparuk PA _ Half Mile Trajectory Radius 1 I s — —": i ____.- Other Well �_.. '23.4 > — —%' I Qannik Well I ADL380075 1 0 I Nanu a Nanuq PA i L____.1 Alpine PA i.._.._.._ — —.._.._. i „„, L L Fiord Nechelik PA N N _ ConocoPhillips Alaska,Inc. L.._..1 Nanuq Kuparuk PA I L"_ Nanuq Nanuq PA i CD2-468 77 L.._..; Qannik PA 0 0.2 0.4 0.6 0.8 1 1.2 1.4 Lease Plat CPAI Leases Miles \ 9/19/2017 • 0 Table 1: Wells within 1/2 mile buffer of well track API Well Name Well Type Status 501032042900 CD2-38 INJ ACTIVE 501032049200 CD2-57 INJ ACTIVE 501032043100 CD2-13 PROD ACTIVE 501032043170 CD2-13PB1 EXPEND PA 501032043171 CD2-13PB2 EXPEND PA 501032043400 CD2-37 PROD ACTIVE 501032043500 CD2-28 PROD ACTIVE 501032049300 CD2-31 PROD ACTIVE 501032049370 CD2-31PB1 EXPEND PA 501032049400 CD2-53 PROD ACTIVE 501032049500 CD2-05 PROD ACTIVE 501032049560 CD2-05L1 PROD ACTIVE 501032054600 CD2-72 PROD ACTIVE 501032041570 CD2-50PB1 EXPEND PA 501032041800 CD2-25 PROD ACTIVE 501032042100 CD2-22 INJ ACTIVE 501032042200 CD2-48 INJ ACTIVE 501032042300 CD2-19 PROD ACTIVE 501032038700 CD2-39 PROD PA 501032047470 CD2-43PB1 EXPEND PA 501032042400 CD2-41 PROD ACTIVE 501032042500 CD2-23 PROD ACTIVE 501032042570 CD2-23PB1 EXPEND PA 501032042600 CD2-16 INJ ACTIVE 501032042800 CD2-44 INJ ACTIVE 501032057900 CD2-467 INJ ACTIVE 501032057970 CD2-467PB1 EXPEND PA 501032058000 CD2-469 PROD ACTIVE 501032058100 CD2-470 PROD ACTIVE 501032058300 CD2-465 PROD ACTIVE 501032058700 CD2-468 PROD ACTIVE 501032049600 CD2-09 PROD ACTIVE 501032044100 CD2-51 INJ ACTIVE • • 501032044200 CD2-08 INJ ACTIVE 501032044700 CD2-36 INJ ACTIVE 501032045500 CD2-12 INJ ACTIVE 501032045700 CD2-58 PROD ACTIVE 501032045760 CD2-58L1 PROD ACTIVE 501032046100 CD2-20 PROD ACTIVE 501032045900 CD2-52 PROD ACTIVE 501032046300 CD2-55 INJ ACTIVE 501032046400 CD2-40 INJ ACTIVE 501032046470 CD2-40PB1 EXPEND PA 501032046500 CD2-30 INJ ACTIVE 501032049670 CD2-09PB1 EXPEND PA 501032049800 CD2-56 INJ ACTIVE 501032049860 CD2-56L1 INJ ACTIVE 501032046600 CD2-18 INJ ACTIVE 501032046670 CD2-18PB1 EXPEND PA 501032049660 CD2-09L1 PROD ACTIVE 501032047100 CD2-27 INJ ACTIVE 501032047200 CD2-07 INJ ACTIVE 501032051370 CD2-02PB1 EXPEND PA 501032051400 CD2-01 PROD ACTIVE 501032051470 CD2-01PB1 EXPEND PA 501032057300 CD2-75 PROD ACTIVE 501032057400 CD2-464 PROD ACTIVE 501032057600 CD2-466 INJ ACTIVE 501032057700 CD2-463 PROD ACTIVE 501032047270 CD2-07PB1 EXPEND PA 501032047271 CD2-07PB2 EXPEND PA 501032047300 CD2-10 PROD ACTIVE 501032047370 CD2-10PB1 EXPEND PA 501032051471 CD2-01PB2 EXPEND PA 501032051500 CD2-11 INJ ACTIVE 501032049900 CD2-54 INJ ACTIVE 501032049960 CD2-54L1 INJ ACTIVE 501032050400 CD2-21 PROD ACTIVE 501032050470 CD2-21PB1 EXPEND PA 501032050570 CD2-59PB1 EXPEND PA 501032051100 CD2-60 INJ PA 501032051101 CD2-60A INJ ACTIVE • 501032051170 CD2-60PB1 EXPEND PA 501032051200 CD2-03 PROD ACTIVE 501032051260 CD2-03L1 PROD ACTIVE 501032047400 CD2-43 PROD ACTIVE 501032062900 CD2-77 PROD ACTIVE 501032060100 CD2-78 INJ ACTIVE 501032059000 CD2-73 INJ ACTIVE 501032059070 CD2-73PB1 EXPEND PA 501032059100 CD2-74 PROD ACTIVE 501032060300 CD2-76 PROD ACTIVE 501032060370 CD2-76PB1 EXPEND PA 501032060371 CD2-76PB2 EXPEND PA 501032038701 CD2-39A PROD ACTIVE 501032038760 CD2-39AL1 PROD ACTIVE 501032039400 CD2-47 PROD PA 501032039401 CD2-47A PROD ACTIVE 501032039460 CD2-47AL1 PROD ACTIVE 501032021101 ALPINE 1A EXPLOR PA 501032050500 CD2-59 INJ SUSP 501032042700 CD2-29 INJ ACTIVE 501032053000 CD2-404 INJ ACTIVE 501032025600 CD2-35 INJ PA 501032025601 CD2-35A INJ ACTIVE 501032037400 CD2-42 PROD ACTIVE 501032037470 CD2-42PB1 EXPEND PA 501032037700 CD2-24 PROD ACTIVE 501032038600 CD2-15 INJ ACTIVE 501032038670 CD2-15PB1 EXPEND PA 501032038671 CD2-15PB2 EXPEND PA 501032039000 CD2-14 PROD ACTIVE 501032038770 CD2-39PB1 EXPEND PA 501032037770 CD2-24PB1 EXPEND PA 501032038100 CD2-33 PROD PA 501032038101 CD2-33A PROD PA 501032038102 CD2-33B PROD ACTIVE 501032039300 CD2-34 PROD ACTIVE 501032039370 CD2-34PB1 EXPEND PA 501032039500 CD2-45 PROD ACTIVE 501032039771 CD2-26PB2 EXPEND PA • # 501032040100 CD2-49 INJ ACTIVE 501032040600 CD2-17 INJ PA 501032040601 CD2-17A INJ ACTIVE 501032041100 CD2-32 INJ ACTIVE 501032041170 CD2-32PB1 EXPEND PA 501032041500 CD2-50 PROD ACTIVE 501032039700 CD2-26 INJ ACTIVE 501032039770 CD2-26PB1 EXPEND PA 501032043570 CD2-28PB1 EXPEND PA 501032041900 CD2-46 INJ ACTIVE 501032044770 CD2-36PB1 EXPEND PA 501032047000 CD2-06 INJ ACTIVE 501032051300 CD2-02 INJ ACTIVE • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. 3 35 See Conclusion number Xof the Area Injection Order AIO 08-24 - Colville River Field, Colville River Unit, Qannik Oil Pool which states "There are no underground sources of of drinking water beneath the permafrost in the Colville River Unit area. Examination of well log fata from exploratory wells in and near the proposed Qannik development confirms that there are no aquifers within the affected area that could serve as underground sources of drinking water." • • 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 10-3/4" casing cement report on 12/7/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7-5/8" casing cement report on 12/16/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 1,200 psi, and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 12/7/2008 the 10-3/4" casing was pressure tested to 3,050 psi for 30 mins. On 1/3/2009 the 7-5/8" casing was pressure tested to 3500 psi for 30 mins. On 1/3/2009 the 3.5" tubing was pressure tested to 4300 psi for 30 mins. The 3.5" tubing will be pressure tested to 2,875 psi prior to frac'ing. The 7-5/8" casing will be pressure tested to 3,300 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,500 Annulus pressure during frac 3,000 Annulus PRV setpoint during frac 3,100 7 5/8" Annulus pressure test 3,300 3 1/2" Tubing pressure Test 2,875 Nitrogen PRV 6,650 Highest pump trip 6,150 • 0 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 10-3/4" 45.5 L-80 2,090 psi 3,580 psi 7-5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Wellbore pressure ratings • • Stimulation Surface Rig-Up rm Bleed l Tattle (75 Tale 7ar� �� , • a v • r- •.1 i 2 m� o m� o • Minimum pressure rating on all surface treating lines 10,000 psi 1r�1► 1 ►41 1 • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3,100 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 �s ` psi. N c .Y a .m5rui&Ind U Fop Off Tarn Pop-Ort Tank Pump Truck C Z a d C Q �J 7p J ui L,Li Frac Pump a -- — - Frac Pump _w Frac Pump N }— - Frac Pump Frac Pump -1*I- — --[: 1'.J Frac Pump • S Stimulation Tree Saver OPEN POSITION CLOSED POSITION PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON OONNEOTION i , „ .t i i i i i i / + + i . i „<YT,,,., + 1” MITER �,,.F, ,..,, 1111111111111111111 w ( MASTER VALVE ! .1•0rrwi 111 it 46 PO Al. MANUAL OPERATED MAt OP# MASTER VALVE enems alililliiiiilin 101111110010 Pi\ �� o tris Stinger Stinger PPP 77>,. MANDREL 4•1 Iv /' .. VENT fi ,;1041,ii 4—VALVE I I I",' LL OPEN *1>i '#+l► !t// I//lf :1S. mod , kUk tt S.! .�N FLOW TEE AND / , '" (-- 11111l.mo ^' /�■f( VENT VALVE WELLHEAD a•.' Olt VALVES fr1/fA OPEN tt ,,µ WELLHEAD VALVES .1, " 4 7„ s 0.01E0 ti � d\, .l.� OUAD PACKOTE SO L. '`. ASSEMBLY IN +I' — PLACE IN TUBING -,f-Ik,it,' 1 ,r-N.I _ 'l. e TUBING • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm • • Alpine Wellhead System , k., i, ,/ I 'it k ffaillikal 1 II: wIVIIPc-11;;Iii11191111‘10191 , i.:. .El .....„,fy..PL II iIme~la F......AL AI ,1_, J hi. . , ..1,7 I 1111101 -------Ekgra,- [,1 .."•....1•1 :MIT P..0.1_,,,ITSPDP I .. PO4 ,C PITY!V RANI,.T.two4nr.5 12 illt,= FR tfriegh.014, LC,44.13,,PICIM3,7, rcn 10,cAsi, iLAE,A.e.,,vc it.l.La . )-•1,6•>.......iN 7....61 i...i.11_ El ... 11. \\III MM. . III, 711%•,-an. \ ,pi NI— 4 W- „ . '.1__,,v •-,,r47-74. ---,.,.-T. 411.-.1`6_47.i-r.,4=..,--„,,-- im... :,m_...... _:„.. . -410 7 ••••.,•••• 'M='-'‘•.....Th :1, .- -. I!. == - .1.1 1111 irIll'irl li1C1-' PIM ..,..m. --'.• nis !im.-. "„ .. ...../" - a, . 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ABROoko6 W674413Etz,*aliad My4st wpm -voczu,-, — 11,103C tAIHEAO StiTEM..IlePIN.Tal.PEE •I TN Stor.,-11 WET AL 0,11E1 SEALS . .-,-,1,0•F' 7-7,......A.cn...,..no. wi—.-- .= .r:...7. - ......,___-:... .. • ... .. .fir---......-- - ---........_- • 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 Qannik interval is approximately 100' TVD (21' net pay) thick at the heel of the lateral. The Qannik reservoir is very fine grained and quartz rich, with a coarsening upward log profile. Top Qannik (K-2) at 10,535' MD/4,016' TVDSS. The estimated fracture gradient for the Qannik reservoir is 12.3-12.5 ppg. The overlying confining zone consists of greater than 1500' TVD of Seabee (dominantly mudstones), beginning at base of C-30 (2,578' MD, 2,541' TVDSS). The estimated fracture gradient for this interval is 16-17 ppg. The underlying confining zone consists of approximately 150' TVD of Albian mudstones, based on nearby well control and was not penetrated in the CD2-468 wellbore. The estimated fracture gradient for this interval is 16-17 ppg. • • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: CD2-469: The 7-5/8" casing cement report on 11/19/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1200 psi and the floats were checked and they held. CD2-466: The 7-5/8" casing cement report on 7/2/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1200 psi and the floats were checked and they held. CD2-404: The 7-5/8" casing cement report on 5/14/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 950 psi and the floats were checked and they held. i • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that no faults or fracture systems transect the Qannik reservoir or enter the confining zone within one half mile radius of the wellbore trajectory for CD2-468. No faults were encountered during drilling of this well. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. • • Plat 2: CD2-468 Fault Analysis ADL380095 AA084140\,t••--•—: ADL025529 I `-•ADL258 .. IFiord t— Nechelik i PA t I ' ADL387211 I I !) I _.._.-_ ADL387211 _. Qannik PA i I I ADL388466 I I `.p I \ \ L 1 al�� ADL025530 i i `�°�q I \ '4?-0, 4\ \ N 1 \ a Ody C1:\ la -�,4 ADL380096 ADL025558 i i ADL387212111111410 � ' t ASRC-NPR2 ` 1-12I n II2NR5 F ADL387207 r TiI N 111 R5ospa �?4CD2 Y U „..... ADL025559 • Frac Points Trajectory I'"'—•1 ADL380075 I I Open Interval Q Half Mile Frac Point Radius ADE021 Q7 Kuparuk PA _••_-__,• O Half Mile Trajectory Radius I —Other Well 1 I — i III Qannik Well I ! 1 _.._.._ - Nanus{Nanuq PA I I I ...._ , 1 t.._.._.._.._.._.._.._.._.-i.._.._..—..1 L____.;Alpine PA Fiord Nechelik PA NOTE: There are no faults within ConocoPhilli�s L........ the the Half Mile Frac Point Radius. — N - Alaska, rinc. L. .. Nanuq Kuparuk PA \ A L.._..1 Nanuq Nanuq PA I ADL31 CD2-468 L. Qannik PA 0 0.2 0.4 0.6 0.8 1 1.2 1.4 Frac Plat CPAI Leases Miles I I • 9/19/2017 With the exception of the offset Qannik wells, CD2-466, CD2-469 and CD2-404, there are no wells within .5miles in the Qannik Pool. The closest Alpine well, CD2-76, and it's plug backs (PB1, PB2) intersect the Qannik Pool 2,920' to the south of the open hole of the CD2-468 wellbore. All other Alpine wells that penetrate the Qannik Pool are further away from the CD2-468 open hole. The `other' wellbores on the map depict Alpine wells and their intersection with the Qannik Pool are all outside of the .5 mile radius. • • f I0_ a _C t. 0. _L t. y C N p n ry N G I. d ul 11,Ci_ I,a m m m 7ry _ $ P .i ° tiP.. Y a N a N a d O aN , ryU) N W W _ C O g E = 0-0. d 6 d W m e m e oo C U Y C N O O O d E Y y 12 U m • N o m m m `d `d te E'. m mY cz o o $ o- c0 0 0 2. 5m 2 Wry.- m m m m $ m 0 ite m ai O . N ,ri a± v @3 @i o O _ 3 p L L A/l . d O YO :C 0 a /l q N L G CC lei ii L O O O O d W d IDry / C L a) O O L G H H a C ,. > d m vv VC m 0 J13 O co E 1 I 'c e `- u u o O d TO U TOU EH O {J C N d u o ^ b r.. D tri4-0 tE U L.L {j 0 m m o e m a a 0 s SO N e an Na o 0 0 5I I n 0 .lac cn o m cr Gry N C G n w N a H O d N W C u"., of Y1 n n n 10 U tot to w io • G G G tow a < < 00 2 a 10 a z Y Y q N o 0 f V 3 U U U 0 U SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD2-468 was be completed in 2009 as a horizontal producer in the Qannik formation. The well was be completed with 3.5" tubing and a 3.5" slotted liner which will be perforated prior to the frac. The frac will consist of a single stage, pumping 150,000 lbs of 20/40 Wanli proppant. Proposed Procedure: Halliburton Pumping Services: (Qannik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 8,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Slowly increase annulus pressure to 3000 psi. 9. Pump the 300 bbl breakdown stage (20# Borate) according to the attached HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. 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 attached HES schedule @ 20bpm with a maximum expected treating pressure of 5,500 psi. • 1 stage, 150,000 lbs of 20/40 Wanli proppant 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). I •ry d 0 0 0 0 0 0 0 0 0 0 L'2:—A ,. m n a s a o d E m o - tO 0 0 0 0 0 0 tO iO 0 0 0 0 0 0 0 0 0 0 "' E r ` c�. a o � o � n., 3. n ry ry ry ry ry ry ry ry ry ry 3 3 n m m o ":, r2 ": `2 `.'' ''' `:1 ":' m m a 0 Saa 0 V5 �� 2)o « _ . . . 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W oo Uo a a a aaaQz a 81z.. %m ELIO m V Li :9 oc ato c m 0 0 0 00000 v22 7 M 2 2 m m M w m mma2-8 Ii -22' ma E c o v « ii E lca D GE x � � c LL o 0 o m o 0 00-42 0 0 0 0 0 0 o m o 0 0 = a ° en U °`o c o0( o ° N al E N ,S W E 0. o N =w a DL,'=.0. 1 1!i1 2 .0'1 3 3 3 0gmNNn ->.,I F aE" aib; m m m mmmmm m m mm UaN a as : :: d n on d = E _ c � MMFM � � mmmVaa :¢m >NOau n vW -- __ - v n f vmN K fi aQ o q - 3"ap m-E2 c 0 300 0 0- 0 oE `Q E m S A-4,- o' g III o t 2:22 HI 0 0 rigE oEE _ 0OEEn 3 vt m mmmmm m ° mE ° - v =aEE coo . 2' ..1'..2 aAaa0''aC 1 4E _ 2 2 -mtE rmad s . nun wSN 2 N Y 'li 00 w w0ccEz 0 0c co o!to - -1nE0 maNmC C v.,:=7 F,. 1-3 ?, QO,9 OW m U _V rmN N U y 4.2-0 _c a u LL a `o o - av Eamv o 3! ..Q3a 11 , aum W m u Z 3 j 2 Z 1 0 - m LwJ - «I dLc -5 y`o = a VOO W� o 3 'g 342 t=r m AmOwr ¢ MONmwN - oy o- m -0a a aIgnu0 ;S- z ¢2 C CU CI 0 00 G Lio U d- ro 1 L... N u.., O U • • tu___ O O E o oco = N C c) 0 0 0 0 0 0 0 in as To 0 0 0 0 0 0 LO 0 _ o) 0 0 0 0 0 0 . O (� , 11) I� f` I 00 I� Ci O to f= a) a c 0 0 0 0 0 0 a) 0 0 0 0 0 Co Q.- N N N N N N Q L •- •- •- •- •- .— O C C C C C C CL a) t0 (O (O CO (O (O C U C O ) 0 0 0 0 0 0 • � C) Q O O O O O O ^^L O_ Q .- N co 4' Lo Co O a) r_ L L 121 /a) \V U)-I-. V C L LLL j 5 5 5 5 5 5 o LL LL LL LL coO_ = U C C C C C C 01.)L a) C a) a) a) a) a) (1) O C /L 0 LL -2 (O (O (O (O (O (O fn CL a) - a) -O .! D J J J J J J C C LL aO (n C C C C C C N (n O J (O (O tO (6 (O (O N O Q Q Q Q Q Q L Co Q Q Q_ Q_ Q a. LL (/) 0 0 0 0 0 0 CL CL CL CL CL CL C 0 U+� Q ca w a) a) a) a) a) a) a) ca m . a) (LO C U) U) (B U) Co Co CO O O C a) CJ m -5 m m m CC1 C CC1 m J 15 a) � 0 -1 0 0 ' 0 0 0 0 0 0 0 0 0 75 N N N N N N N N N N S2 L LL L ^L,) a) a o)-0 N M CO E N— N CO LO CO fl'`. CO O c- - U Z e • ,. , .,-, , ,v) cu . C -I—, _s_ tvo CL > .4--) v)Q �' +� m O v •_ v rre N �' ca 4— O n mc v 0 U bD 0 N L U 00 CU U —0 _C Ur O vi 4-1+ I v Q.) La v -o I o �' 4-- s_� ca +-� c6 O -O CO a) O E cn N 0 O •c co D2 I 4— .� s_ N `� �, _ o O N N C W �" v }; 03 O0 tuo CO U o � N � N � 0 v v = N Q � O v v O a) s- CU 0 . 6 (1)C a, a) Li) o N Q) C CU O _C2 �' .47-, N O O +-' O O ti c cu L O cu E v) 7:5 (1) co 5 co 73 N U _ co . • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Pending job execution, flowback will either be initiated to tanks or directly to the plant. If flowing to tanks, flowback will be initiated until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208 -180 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil ig Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation Q or Final ❑ 312 -257 7/19/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: 1111 cement - contaminated domestic waste water descriptions in block 12) disposal 2013 drilling mud, completion occurred in 0 9 fluids, formation fluids and SCO4E9 any necessary water added Previous totals (bbls): 22311 100 477* 22888 20 1/3/2011 2/6/2011 CD2 -77 2012 / 3rd 36852 100 0 36952 50 7/22/2012 9/29/2012 CD1 -22B 2012 / 4th 7005 100 0 7105 8 10/4/2012 10/12/2012 CD1 -01A 2013 / 1st 2013 / 2nd 2013 / 3rd • Total Ending Report is due on the 20th Volume 66168 300 477 66945 78 i ll month f o f the monoown the final month of the quarter. Ex: (bbls): 9 q April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. I v rr /j Signature: Date: I t. f5 1 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • G. L. Alvord Alaska Drilling Manager Drilling & Wells A. rag Anchorage, AK AK 99510-0360 Phone: 907 - 265 -6120 ConocoPhiflips ?T 0 g ?(5 November 12, 2012 RECEIVED Commissioner NOV 1 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 AOGCC Anchorage, Alaska 99501 Re: Corrected Annular Disposal Report for CD2 -468 Dear Commissioner: Please find attached the corrected Report of Annular Disposal for CD2 -468 for 3rd quarter 2012. The initial report overstated the disposal volumes due to data entry of duplicate reports. Please call me at 265 -6120 should you have any questions. • Sincerely, SCANNED JAN 2 3 2013 C 011 G. L. Alvord �� v10`1 15 1 Alaska Drilling Manager • GLA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208 -180 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 0 or Continuation ❑ or Final ❑ 312 -257 7/19/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: III cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 22311 100 477* 22888 20 1/3/2011 2/6/2011 CD2 -77 2012 / 3rd 36852 100 0 36952 50 7/22/2012 9/29/2012 CD1 -22B 2012 / 4th 2013 / 1st 2013 / 2nd 2013 / 3rd • Total Ending Report is due on the 20th Volume 59163 200 477 59840 70 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes I hereby certify that the foregoing is rue and correct to the best_of my knowledge. Signature: e_a( Date: 11(1242_, ( 7..._ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • SEAN PARNELL, GOVERNOR n ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. (108 _ i � P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Colville River Unit, CD2 -468 Sundry Number: 312 -257 1 r4 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must= comply with the requirements and limitations of 20 AAC 25.080. As provided in 20 AAC 25.080 (d) (1), after review of the information provided to demonstrate that compliance with the 35,000 barrel limitation is imprudent, the Commission has determined to authorize disposal of drilling waste in a volume of not greater than 70,000 barrels through the annular space of CD2 -468. As provided in 20 AAC 25.080 (d) (4), after review of the information provided to demonstrate that compliance with the same drill pad generation and disposal of waste limitation is imprudent, the Commission has determined to authorize disposal of drilling waste through the annular space of a well CD2 -468 not located on the same drill pad as the drilling operation generating the drilling waste wells CD 1 -22B, CD 1 -01, and CD 1 -47. 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, Cathy . Foerster ,, Chair DATED this Ii of July, 2012 Encl. • ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh • I I ps Telephone 907 - 276 -1215 July 13, 2012 RECEIVED Alaska Oil and Gas Conservation Commission JUL 16 2012 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 AOGCC Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD2 -468 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2 -468 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The totally volume applied is 70,000 bbls. The anticipated start date for annular disposal operations on CD2 -468 is July 23, 2012. CPA is requesting AOGCC approval to annular dispose of 45,000 bbls of muds and cuttings from the well we are currently drilling CD1 -22B and CD1- 01(new Class 1 disposal well). We will need this approval as soon as possible and to continue to through November 30 This will give us time to sidetrack and complete new Class 1 disposal well in CD1 -01. Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 10 -3/4" x 7 -5/8" casing annulus. 11. List of Wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within % mile radius at AOGCC: CD2 -02, CD2 -09 and CD2 -76 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The CD2 -468 well was permitted for 35,000bbls volume on 12/17/2010, total injection volume is 22,888bb1s when permit expired on 12/17/2011. A recent injectivity test conducted on 7/14/2012 shows the annular LOT (14.9 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (17.9 ppg). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT /LOT. If you have any questions or require further information, please contact Weifeng Dai at 263 -4324; Chip Alvord can also be reached by calling 265 -6120. Sincerely, Weifeng Dai W mt Drillin g Engineer ineer ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocOPh 1 11 ps Telephone 907 - 276 -1215 Bcc: CD2 -468 Well File Chip Alvord ATO -1577 Sharon Allsup -Drake ATO -1530 II • 411V RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 6 2012 ANNULAR DISPOSAL APPLICATION ����� 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 208 -180 ConocoPhillips Alaska 4. API Number: 50- 103- 20587 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2 - 468 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: Torok and Seabee formation, shale, siltstone and sandstone • CD2 - 02, CD2 - 09, CD2 - 76 b) Waste receiving zone: • b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1911' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 9 JC. c 2e \ . �lJ v' .22 3g g / >'6 2 bb Dec.2008 densities range from diesel to 12# /gal 2222 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: •,I 35,000 bbls. Dry L-0 t . - > �`� Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - 'izcE f `t 7 � bb' contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act 16. Estimated start date: of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added 26- Jul -12 water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 151 Cement Bond Log (if required) ❑ FIT Records w /LOT Graph Q Surf. Casing Cementing Data 0 Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /+�C Title: f i -�� Printed / /// ���\���J Phone Name: Chip Alvord Number: 265 -6120 7/16/2012 Commission Use Only Conditions of approval: LOT review and approval: ()Y.! t7 �U &Y i2 Subsequent form required: / 0 4 2 Approval number: ✓' (��� ✓� APPROVED BY /; Approved by: BDMS JUL / (• l THE COMMISSION Date: 7-1q... / / ;1 `v Form 10 -403AD Rev /2004 CI) i 7-Sw.-zci2 INSTRUCTIONS ON REVERS \.# • J Submit in Duplicate \ r1 / Annulus Disposal Transmittal Form - Well D2 -468 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD2 -468 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15. 19991 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. Maximum volume to be pumped is 70,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling /completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2222 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the r Pr0vide, GDS ($ • �v�y' 12, annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD1 -22B, CD1 -01( New waste disposal well), CD1 -47. will be generated. 15 If the operator proposes not to comply with a limitation I; A S le- Cpl- -J it-- Tv L-7-20/2, established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Verson 1.o -Jan X05 Well CD2 -468 Assumptions Date 12/6/2010 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft Gas /Fluid Gradient in tubing/casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 1,000 psi :..4 Maximum Fluid Density to avoid Burst of Surface Casing a v Pburst85% = PHydrostatic + PApplied - PFormation - ' 3,043 = ( 2,387 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,387 ) r- MW„„,„ = 20.77112 ppg L 2,387 TVD Surface Casing String Size 10.75 in Weight 45.5 ppf d v v Grade L 80 . . ec Pburst10o% 3,580 psi :e Pburst85% 3,043 psi U Depth of Shoe 2,387 ft FIT /LOT @ Shoe 17.9 ppg or 2,222 psi FIT/LOT for Annulus 13.9 ppg r9 Max Surf. Pressure 1,500 psi TOC Est. @ 8,954' MD-..._ 3,741' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,072 = ( 3,741 * 0.052 * MW )+ 1,500 - ( 0.0700 * 3,741 ) - 1,000 Z Z MWmax = 19.7056 ppg 3.5 "Tubing 2nd Casing String Size 7.625 in 4,513 TVD Weight 29.7 ppf Grade L 80 Pcollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 3,741 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax allowable = ( 2,387 * .052 * 17.9 ) Pmax allowable = 2,222 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". • • SURFACE CASING SHOE SEPARATION FROM CD2 -468 CD2 -468 x Y Surface Casing Shoe ASP 4 Coordinates: 369193.60 5976400.42 Distance - from Surface csg. Details @ Ann. " Object Shoe X Surface csg. Wells AOGCC Permit # Permit Date Source well Vol. "•• Start Date End Date well* Coord. Shoe Y Coord. CO2 -01 y 3939 373114.47 5978019.08 002 -02 y 368 369431.33 5976119.22 CO2 -03 included 1849 371040.60 5976495.42 CD2 -05 y 0 2870 370258.60 5973735.40 CD2 -06 y NA 0 2447 371610.81 5976018.45 CD2 -07 y NA 0 3027 372218.06 5976287.95 002 -08 y 3553 372655.88 5975603.76 CD2 -09 y 304 -362 9/30/2004 418 1136 370318.00 5978239.00 CD2 -10 y 304289 7/30/2004 002 -09, 002 -56 30703 8/27/2004 10/15/2004 2637 371800.58 5976006.36 CD2 -11 y 1912 370835.25 5975420.76 CO2 -12 y 303 -365 12/12/2003 CO2 -57, CO2 -31 32000 5/15/2004 6/14/2004 2107 371071.29 5975445.60 CD2 -13 y 3519 372658.78 5975785.31 002 -14 y 301 -288 10/9/2001 CO2 -45, 002 -47, CD2 -32 31073 11/13/2001 3/5/2002 3338 372202.47 5974960.87 CO2 -15 y 301 -308 11/6/2001 CO2 -50, CD2 -25, CD2 -44 31852 3/6/2002 9/21/2002 2166 370832.00 5974984.02 CO2 -16 y 3642 372460.34 5974790.01 CD2 -17 y 302 -122 4/1012002 CD-48, CD2 -08 18181 5/29/2002 2/7/2003 3121 371774.00 5974645.00 002 -18 y 1799 369825.76 5974716.05 CO2 -19 y 303-083 4/28/2003 CD2 -58, 002 -52 31337 5/19/2003 8/27/2003 3537 372284.88 5974681.33 002 -20 y 304-288 7/30/2004 452 2349 371366.14 5975507.11 CD2 -21 - y 1579 370286.77 5975261.48 CD2 -22 y 302 -274 9/20/2002 CO2 -08, CD2 -36, CO2 -51 31253 2/7/2003 3/16/2003 3091 371678.61 5974562.30 002 -23 y 303-080 4/28/2003 CD2 -18, CO2 -55, CO2 -06 32000 9/4/2003 1/1/2004 2254 371013.17 5975070.46 CD2 -33 ( +ABB), CD2 -39, CD2 -14, 002 -24 y 301 -186 7/13/2001 CD2 -15 33999 7/16/2001 10/9/2001 2209 370630.11 5974721.81 002 -25 y NA 3075 371594.00 5974479.00 CO2 -26 y 302 -068 3/4/2002 CO2 -44, CD2 -29, C132 -13 29626 9 /7/2002 10/17/2002 3193 371798.52 5974554.55 CO2 -27 y 304226 6/23/2004 CO2 -53, CD2 -05, CD2 -09 32000 7/9/2004 8/27/2004 5091 373046.07 5973071.83 CD2 -28 y 3387 372139.80 5974728.95 CO2 -29 y 303 -249 8/25/2003 CO2 -06, CD2 -30, CD2 -27 29036 10/8/2003 11/19/2003 3772 372652.44 5974896.02 CD2 -30 y NA 0 3069 370473.52 5973610.96 CD2 -31 y NA 0 2049 369824.37 5974451.30 002 -32 y 302- 119 4/30/2002 CD2 -19, CO2 -41, 002 -23 31113 8/14/2002 7/23/2002 2970 371295.61 5974302.38 CO2 -33 B'•` y - 2692 370155.64 5973886.23 CD2 -34 y 302 -069 3/4/2002 CD2 -13, CO2 -37 22842 10/17/2002 11/28/2002 3264 371803.06 5974439.79 CD2 -35•" y 3925 372312.31 5974017.68 002 -36 y 303 -365 12/12/2003 CD2 -43, CO2 -31, CD2 -57 32000 12/31/2003 7/9/2004 3906 371848.22 5973535.38 CD2 -37 y 4252 371569.79 5972874.47 CD2 -38 y 303 -082 4/28/2003 CO2 -40, CO2 -30 30011 7/28/2003 9/4/2003 4040 372033.86 5973527.13 002 -39 y 301 -281 10/9/2001 CO2 -15, CO2 -47, CD2 -44 29945 10/10/2001 9/16/2002 4198 372350.61 5973633.17 002 -40 y NA 0 3000 370691.87 5973801.44 I CD2 -404 y 307 -154 6/8/2007 CO2 -72 6764 5/14/2007 5/31/2007 1922 370646.55 5975142.76 CD2-41 y 303 - 081 4/28/2003 CO2 -20, CD2- 55,CO2 -43 32000 6/27/2003 7/28/2003 3817 371990.58 5973802.52 r CD2-42 y 301 -140 6/1/2001 CO2 -24, CD2 -33, CO2 -33A, CD2 -15 33892 6/1/2001 10/10/2001 3070 371098.46 5973992.48 CD2 -43 - e-` i" 5. sY- s0 F -V4-k2-4-41,..-,.- " - Arrfk rilideb �#ti s' i;=: 3c %fi �� _. L' Zt fit W48101 ? • .03.4:4404 a 59 3520;68 CO2 -44 y 3516 372034.57 5974328.53 CD2 -45 y 301 -345 12/13/2001 CD2 -49, CD2 -17 22991 1/20/2002 2/19/2002 4387 372785.13 5973853.74 CD2 -46 y 302 -273 9/20/2002 CD2 -51, 002 -12 31864 4/15/2003 5/19/2003 3259 371694.80 5974310.85 CD2 -47 y 301 -322 12/312001 CD2 -34, CD2 -26 27349 12/17/2001 1/20/2002 3715 371231.72 5973294.19 002 -48 y 302 -275 9/20/2002 CD2 -28, CO2 -35a, CO2 -45, CD2 -08 32000 12/10/2002 2/4/2003 3611 371631.74 5973736,14 CD2 -49 y 302 -070 3/4/2002 CD2 -50, CO2 -48, CD2 -22 27980 4/22/2002 5/28/2002 3113 371252.38 5974065.93 CO2 -50 y 302 -121 4/30/2002 CD2 -41, CD2 -19, CO2 -18, CD2 -38 32000 7/24/2002 9/7/2002 3291 371665.21 5974227.65 CD2 -51 y 303 -312 10/28/2003 CD2 -07, CO2 -10 31789 11/19/2003 12/24/2003 4930 373114.02 5973411.81 CO2 -52 y NA 4400 372637.61 5973661.63 002 -53 y 304-361 9/30/2004 CO2 -56, CO2 -54, CD2 -02 26072 10/3/2004 8/5/2005 5372 372696.87 5972509.19 CO2 -54 y NA 0 3140 369991.09 5973363.59 CO2 -55 y 3739 371118.23 5973194.84 CO2 -56 y 305 -307 10/11/2005 CO2 -404 11167 5/7/2006 5/23/2006 3416 369875.93 5973053.08 CD2 -57 y 305 -238 8/17/2005 CO2 -01 19181 8/22/2005 9/12/2005 5272 372537.05 5972324.37 CO2 -58 y NA 4740 372102.03 5972857.80 CO259- y -- = - - - 2395 - 389650.94 5974049.86 CD2 -60 y 4584 371269.33 5972336.05 CD2 -75, CD2 -464, CD2 -466, CD2 - CD2-72 y 308 - 153 4/28/2008 463 26564 5/3/2008 7/6/2008 1411 369745.64 5975101.63 CD2 -75 308 -213 7/8/2008 CD2 -465 002 470 10645 8/22/2008 10/30/2008 3200 369536 59 5973218 56 „, , CD2 "-464 � �'w P.s �%�' 'Q4 D2, 63�tb2467 • ''''t16,1.4 'P "�`i�'� °9� '� n r 7• 097J4t1'J9 CDZ 483 W ; ate `' C. Wail , '' r ` 3 ` �2 f ' L '72 ' S 59i 4s : C-46.W- :.ga --- -' :-.a • .:X tv .d,: .- ms s;;.... A.:44,-V _, . - - -..a .. 312tga W 78-b21--710 002 -468 y 308 -294 10/23/2009 CD2 -73 15623 7/26/2009 11/1/2009 1858 370684.18 5977125.90 CD2 -467 _ y 308 -295 10/20/2009 002 -468, CD2 -73, CO2 -469 18892 11/10/2008 1/10/2009 2369 370335.86 - 5974325.43 CD2 -468 n , __, =;: „0 :-:'- 369193.60 'L - ;x..5976400 CD2 -489 n ./11111 3035 389453.78 5973376.17 , 4,7", 3z; 41 o e oW . -" � 483 ;'>x a. ° :1b b9ft9it2i &1 002 -73 n 1421 369210.81 5974979.59 CD2 -74 . ' n - - = -51• - -Y a . - _ , - - - � =- ,4 '- ,-, T - -.1801 - ",- 369260.37 , 5974601.12 CO2-78 n - 2712 369256.11 5973689.42 CO2 -76 n 1118 370074.88 5975712.70 CO2 -77 n 4729 371551.00 5972301.20 - CD2 468 Name WELLBORE TARGET DETAILS (MAP CO-ORDINATES) TVDSS .N/-S +E/-W Northing Easting Shape 11:23, July 16 2012 CD2- 468vp05 H 4015.00 7149.13 - 5021.24 5981146.52 1506465.35 Point Quarter View CD2- 466wp05 Toe 4015 14555 - 3625.65 5988527.53 1507988.09 Point CD2 -468 :::: ■■■∎ ■ \\im iI \ M ` \ , • 4\11 , i 000 • 611 Lo z 250 ` • ` ` ''i'' '�V 2 .' �1 X150 -� \ , • � � . \ r .. " • 750 N WM \ , la irumir% 0 111 1:: - __.,,_141... -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 West( -) /East( +) (750 ft /in) • • Casing OR Tubing OR Drilling Detail Well: CD2-468 103/4", 45.5#, L-80 BTC-M Casing Date: 12/6/2008 1r Conoco Phillips Rig: Doyon 19 Alaska, Inc, Depth Jt Number Joints Well Equipment Description and Comments Tops Pagel F ,• :•:-:.:::•:•:•:•: : : '.1 of String Or Top of Flinge : RKB to Landing Ring 36.65 , _ FMC 10 3/4" Casing Hanger 2.15 36.65 Jts 100 to 111 12 Jts 10 3/4", 45.5 #, L-80, BTC-M Casing 478.54 38.80 10 3/4" Tam Port Collar 2.98 517.34 Jts 3 to 99 97 Jts 10 3/4", 45.5 #, L-80, BTC-M Casing 3906.27 520.32 10 3/4" Hallibutron Super Seal Float Collar 1.21 4426.59 Jts 1 to 2 2 Jts 10 3/4", 45.5 #, L-80, BTC-M Casing 82.86 4427.80 10 3/4" Ray Oil Tools Float Shoe(Silver Bullet) 2.25 4510.66 4512.91 10 314" Casing shoe @ 4513' MD / 2387' TVD 4512.91 13 1/2" hole TD. 4525' MD /2390 ' TVD 4512.91 4512.91 4512.91 4512.91 RAN 62 BOWSPRING CENTRALIZERS - 4512.91 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 2 ) 4512.91 Every other jt from jts # 14 thru # 96 4512.91 One each on jts.# 98,99, & 100 4512.91 Every other jt. f/ 102 to 108 & 109 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 Remarks: Up Wt 170K Dn Wt 112K Block Wt 75 K Supervisors: D. Mickey/J. Browning III • Driiliin : Cement Detail Report _ -- . .„ I ts ., CD2 -468 , ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 12 /2/2008 00:00 Cement; Willi :, r 7 -`- _ -- &. s - ' - - , �` _ - - ..' ", ; 411 � , M 3 - - - => 4L -. Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/7/2008 15:30 12/7/2008 19:30 CD2 -468 Comment Cement 10 3/4" Csg as follows : Rig Pumped 50 bbls WBM w/ Nut Plug as Marker, 40 Bbls Biozan w/ Nut Plug, Switched to Dowell and pumped 5 bbls water. Pressure Tested Lines to 3,500 psi. Dropped Btm Plug and Pumped 50 bbls MudPush @ 10.5 ppg at 6 BPM & 482 Psi -Mixed & pumped 615 bbls Lead Slurry (ASL) © 10.7 PPG © 6.5 BPM © 320 Psi ( *Observed Nut Plug Marker @ Shakers w/ 600 Bbls Lead Pumped then Pumped Down Surge Can) Pumped 57 Bbls of 15.8 PPG Tail Slurry (Class G w/ Additives) @ 4.5 BPM at 530 Psi. Dropped Top Plug w/ 20 bbls Water f/ Dowell. Switched Over to Rig Pumps & Displaced Cmt w/ 401 Bbls 10.0 ppg Water Based Mud. Displaced @ 6.5 BPM for First 390 bbls Then Slowed to 3.5 BPM @ 600 Psi for 11 Bbls, Bumped Plug w/ 1100 Psi (Pre Bump Pressure600 Psi) Check float (held OK) CIP @ 1930 Hrs. Had Full Circulation Throughout Job w/ 300 bbls 10.7 PPG Cement Retums to Surface. Reciprocated Pipe While Circulating & Landed Casing at start of pumping tail slurry due to Loss of Down Weight- Full Returns Thorughout Cement Job. Cement Stages g * 0 3_ Stage # 1 __ .: _Z _-; _ Z_ .� - - >, tl Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 37.0 4,525.0 Yes 300.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 534.0 600.0 No 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Full Returns Throughout Job - 300 Bbls Lead Cement to Surface - Plugs Bumped and Held , ``,<, Demerit Fluids & Addiitives '� . �` : � - - � � � s ;,,,::;;; - ,-.1 �` Fluid A _ �_ v - .. n 0 _0 t:_ _ - :-* Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 0.0 0.0 90.0 Yield (ft' /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Additives Additive Type Concentration Conc Unit label Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 0.0 0.0 50.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives 1 Additive Type Concentration Conc Unit label .. - . - , - _ . _.s - Fluid - _ „ _ . - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 37.0 3,880.0 755 G 615.0 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (1b/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.57 20.50 10.70 Additives Additive Type Concentration Conc Unit label ` ~z Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tall Cement 3,880.0 4,525.0 280 G 50.0 Yield (ft'lsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/3/2010 e • :-- Security Level: AK Development Daily Drilling Report Jr - !6t'':iiiWeits CD2-468 „.. ---_ - _, Report Number: 6 ConocoPhillips - . ..7 Rig: DOYON 19 Report Date: 12/712008 10239757 10,220,999.00 Wellbore Well Type Reid Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-468 Development QANNIK 5.03 6.0 0.00 4,525.0 4,525.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,901.95 103,254.85 529,212.88 1,744,827.78 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/2/2008 12/2/2008 28.24 28.79 -0.55 12/30/2008 Last Casing String Next Casing OD (In) Next Casing Set Depth (ftKB) SURFACE, 4,512,9ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE w/ AOGCC Insp. Jeff Jones as Witness N/D Surface Riser - N/U & Test BOPE - Drill 20' New Hole - Perform FIT t/ 18 PPG - Displace to LSND - Drill 9 7/8" Hole Last 24hr Summary Conitnue to Wash Down 10 3/4" Casing f/ 1799' - 4513' MD - Stopped to Circulate Hole Clean © 2,402 - 2731' and 3,260' MD - Land Casing @ 4513' MD - Circ and Condition Mud for Cementing - Cement Casing w/ 10.7 PPG ASL Lead and 15.8 PPG Class G Tail Cement (300 Bbls ASL Lead Returned to Surface) - Conduct Casing Test t/ 3050 Psi f/ 30 Minutes (good) - R/D Cement Head and Casing Handling Tools - Remove Mouse Hole and N/D Surface Riser Lost 128 Bbls to Hole in Previous 24 Hours - Total Losses for Casing Job 325 Bbls General Remarks Weather Head Count No Accidents and No Spills -17 / WC -36 / Clear / Wind ESE © 9 Mph 49.0 Don Mickey, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer -..vit= I imetclq , ' , fla:::::!:::: - - ,----:.; : ;- :,-,,,,21:-:--,:--,,,:::.-4-A::::--:-i,--r,07:---.:::ff:=4,--=:-1`:-..-:::::::::7-_:, `1.:" -- - - ,-tIg&w . , : , •--;.:'::-' .w:, Start , - :!End '-: ,--, :::'' .- !: 1 ''':?:...9: , ] V:ii -:- .i: I:" * :-S -,. Depth Start 'peAttt:g- -::'4::::' -= - s ; Time , ::Tit : The ' !re) . - ::; , Pha 'Y.. 7 ''''':" ' OP . COCIe ' -7 4.Otii;16). Code !1',T-X, ;J:::::Triii :.t Glitis, :::::: Aft103V-2 ,,, ..(ftl931.4--,' ,-,:-s;: 00:00 02:00 2.00 SURFAC CASING RNCS P 1,799.0 2,402.0 Cont. Running 10 3/4" 45.5# L-80 BTCM csg f/ 1799' to 2402' (60 jts total in hole) Washing casing down © 3.5 bbls/min @ 400 psi - Hole taking fluid while pumping 02:00 02:45 0.75 SURFAC CASING CIRC P 2,402.0 2,402.0 Circ btms up @ 2402' - ICP 4 bbls/min © 420 psi - FCP 5 bbls/min © 460 psi Hole taking fluid while pumping 02:45 04:00 1.25 SURFAC CASING RNCS P 2,402.0 2,731.0 Cont. RIH w/ csg f/ 2402' to 2731' (69 jts total in hole) - washing casing down © 4 bbls/min @ 400 psi w/ diminished returns Hole taking fluid while pumping 04:00 04:45 0.75 SURFAC CASING CIRC P 2,731.0 2,731.0 Ciro btms up - ICP 4 bbls/min © 460 psi FCP 4 bbls © 309 psi Hole taking fluid while pumping 04:45 06:45 2.00 SURFAC CASING RNCS P 2,731.0 3,260.0 Cont. RIH w/ csg f/ 2731' to 3260' (76jts total in hole) washing down casing © 4 bbls/min @ 430 psi Hole taking fliud while pumping 06:45 07:30 0.75 SURFAC CASING CIRC P 3,260.0 3,260.0 Est. Circ & circ hole - ICP 4 bbls/min © 430 psi - FCP 4 bbls/min @ 370 psi Hole taking fliud while pumping Latest BOP Test Data Page 1/3 Report Printed: 12/3/2010 Security Level: AK Development Daily Drilling Report ik w ells- -.. CD2-468 Report Number: 6 ConocoPhillips Rig: DOYON 19 Report Date: 12/7/2008 Time Lad - DepthStart , DeptkEnd? $tart , Time Tirne (here Phase - '7-! Code Ac.TvIty Coe P TX :,--Tra Code - up .oranon,.. 07:30 12:00 4.50 SURFAC CASING RNCS P 3,260.0 4,513.0 Cont. RIH w/ csg f/ 3260' to 4476' (111 jts total in hole - Made up Tam PC © jt # 99 ) washing down casing © 4 bbls/min @ 560 psi - MU hanger & landing jt. Land casing on FMC fluted hanger on landing ring w/ float shoe @ 4513 & float collar @ 4426' - Tam PC @ 517' - PU wt 170 SOwt112 Hole taking fluid while pumping 12:00 12:30 0.50 SURFAC CASING OTHR P 4,513.0 4,513.0 LD fill up tool - Blow down TD - RU cement head & lines 12:30 15:15 2.75 SURFAC CEMENT CIRC P 4,513.0 4,513.0 Establish circ - Circ and condition hole & mud for cement job - ICP 2.2 bbls/min 420 psi- FCP 350 psi @ 6 BPM 15:15 15:30 0.25 SURFAC CEMENT SFTY P 4,513.0 4,513.0 PJSM on Surface Cement Job 15:30 19:30 4.00 SURFAC CEMENT DISP P 4,513.0 4,513.0 Cement 103/4" Csg as Follows : Rig Pumped 50 bbls WBM w/ Nut Plug as Marker, 40 Bbls Biozan w/ Nut Plug, Switched to Dowell and Pumped 5 bbls Water. Pressure Tested Lines to 3,500 Psi. Dropped Btm Plug and Pumped 50 bbls Mud Push @ 10.5 ppg at 6 BPM & 482 Psi -Mixed & Pumped 615 bbls Lead Slurry (ASL) @ 10.7 PPG @ 6.5 BPM 320 Psi (*Observed Nut Plug Marker © Shakers w/ 600 Bbls Lead Pumped then Pumped Down Surge Can) Pumped 57 Bbls of 15.8 PPG Tail Slurry (Class G w/ Additives) @ 4.5 BPM at 530 Psi. Dropped Top Plug w/ 20 bbls Water f/ Dowell. Switched Over to Rig Pumps & Displaced Cmt w/ 401 Bbls 10.0 ppg Water Based Mud. Displaced @ 6.5 BPM for First 390 bbls Then Slowed to 3.5 BPM @ 600 Psi for 11 Bbls, Bumped Plug w/ 1100 Psi (Pre Bump Pressure600 Psi ) Check float (held OK) CIP @ 1930 Hrs, Had Full Circulation Throughout Job w/ 300 bbls 10.7 PPG Cement Returns to Surface. Reciprocated Pipe While Circulating & Landed casing at start of pumping tail slurry due to Loss of Down Weight- Full Returns Throughout Cement Job. 19:30 20:15 0.75 SURFAC CASING DHEQ 4,513.0 4,513.0 R/U and Perform Casing Test - Pumped 6.4 Bbls © 8 SPM t/ Pressure Build of 3050 Psi - Held 3050 Psi f/ 30 Minutes 20:15 22:00 1.75 SURFAC CEMENT PULD p 4,513.0 4,525.0 PJSM RID & LID Cement Equipment, 10 3/4" Elevators, Bales, Landing Joint and Mouse Hole - Clean 2" Demco Valves 22:00 00:00 2.00 SURFAC WELCTL NUND p 4,525.0 4,525.0 PJSM - UD Surface Riser, N/D Starting Head, Service IBOP Page 2/3 Report Printed: 12/3/2010 • • Security Level: AK Development Daily Drilling Report sq- __.., . _. :,.., , ... CD2-468 ,---,-,-- Report Number: 6 ConocoPhillips - 7` Rig: DOYON 19 Report Date: 12/712008 Mud. Cheek Datelf '',==73,1 -13.;1.4:j.',--,;-,Arifgt-4:::-----:;-<---ipiv,,. -.: .:- ,,, ! .,: a; ,=:, - : - IsisaFiiiz,N:::„.,:i4,1, - W.---='!---_ - :' - `5!'f. - . ::: --=- P Cal- Gel (10e) L .Gel 410* - "'_. Gel 60ssla - :;:,.,p f ,-: --_ '-:,•-•-• F.:,..171.prEllt '..igt.t 4 Gensirerop ,:$0ftds ' Type .- 5.0eOth Ott* ' Geris "(IWOM) 'Via (s/qt) krate (op): AbIllOPftV f1114 f : ,11131/190ftVi: teliitr(Iorbbi) =.0.14,PO100):' '1, - :_ - ' - ',':(T) - ; - :... : t - .- - i.'(1,4): - .WS Spud Mud 4,525.0 10.00 26.0 21.0 83.0 107.0 120.000 25.0 8.3 10.0 i InjeCtIon.:Fiiiid ;-" - - , "::.=.4 - it.i..tti::=2 --, ';--,;Va.-l i ke.4.:A=:".F:•:' , := = . , 0 4 *.t - z.Z.1:::.:: ,- .= - , i;V:::5-;'Te , ==‘ --- ' - F,'-' - '=-:': -- cg -0 4f: - :-:- - - -, == ,, = ,, :T.-=';':, -: . Fluid :-.. : . - . ..., .=.:GOOroe 5, 'From Lease . : Destination-=:* .5555 - 5 Nendor, t =.: . 5 - ). 5 =-,1Manifest : Number, - ;. , = 5 :.55 =5 :f5.5.: - --- 5, :5 :, - Diesel CD2-468 5.0 CD2-467 Injectivity Test Water Based Mud CD2-468 825.0 CD2-467 Drilling Mud Wetitioree 44:.k:4 3 1 14f-111.t: l:t.' Welibore Name Wellbore API/UWI CD2-468 501032058700 -:, .._ , , •,,.. :-.5.,.5..;. ,5=,, .,- (rt:KG)- 5=51 - .5. :u-5P.art,Gate-5:55 , : ,-, .,„.i. .;,..Encl:Datej, CoND1 18 37.0 114.0 '1 SURFAC 13 1/2 114.0 4,525.0 12/2/2008 12/5/2008 INTRMI 97/8 4,525.0 10,632.0 12/9/2008 12/13/2008 PROD1 6 3/4 10,632.0 17,850.0 12/18/2008 12/26/2008 Citing'Stringsf :::: --''' .:' ... ,=- ':: :="Tr ':=17-_: oasfr4DescriFitorv:' , .' ' ''', - .55,5.' - :7, =;51 Gale :-.1!: at: :::: :::: (In) .': --." ''',4'.(itigit) - 4, String Grade :=5:5 Deptn :::1:Z.-: .70biiini SURFACE 12/7/2008 10 3/4 45.50 L-80 4,512.9 Ran 111 Joints and 62 Centralizers - TAM Port Collar @ 517' MD Cement , - ,',,..*:;i. , :le.::?:!\:1 - , , , - ,' ,- , , H=.::.:A:.- -- ir . :1"-: - : .;= 'e, -- :=: =- 'W-#. , R§!: - .4=.::.. - -', -, &;,A.k. -, ::::f: - ..- - ,' Surface Casing Cement - Started @ 12/7/2008 Typo Wellbore Cemented String Cement Evaluation Results i . casing CD2 SURFACE, 4,512.9ftKB Stg No. Description Top (ftKB) - Bottom (ftKB) Q (end) (bbIL.. P (final) (psi) 1 Surface Casing Cement 37.0 4,525.0 4 534.0 : :..-. ,-, : :. :Fluitl:Ezf --; =„55,- . - g=.5--Class - :5 5,5: =, Amaint(secks) . , :- (t)131) --; : 'Density (lb/gal) i , ; , ,Yield (trisack): r 2:,...2,...., Est Top (ftKB) - 55 ' 5 :. -,- 5- -,Est-Sim (ftKB) -: Pre Flush 90.0 10.00 0.0 0.0 Pre Flush 50.0 10.50 0.0 0.0 Lead Cement G 755 615.0 10.70 4.57 37.0 3,880.0 Tail Cement G 280 50.0 15.80, 1.17 3,880.0 4,525.0 Pressure Test Data ,---, :.4: W::': ,'-: - ..' ,7 -. , :: - Alt?:.' , :: - ->i:. , .',;,:.%;:':-::.',.'-'S':' ' : item Tested,:: -;-..:',..,.::- ::.: - -- :-,T.."; :?-3 Date' ", :- .::, -.:,...:: 1.:i. . -::: :-- Pres(ps1) ':- -.."' ... : - :.,:::;:Failed? =5 5-=',75:= -, - z=5, -,- 5:„ :55 = , ,Comment 55:=5.:::: SURFACE, 4,512.9ftKB 12/7/2008 3,050.0 No Pumped 6.4 Bbls @ 8 SPM t/ Pressure Build of 3050 Psi - Held 3050 Psi f/ 30 Minutes Page 3/3 Report Printed: 12/3/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD2 -468 1 Rig:I Doyon 19 IDate: 1 12/9/2008 I Volume In.ut Volume /Stroke 1 Pump Rate: Drilling Supervisor: I Mickey /Browning 'Pump used: #1 Mud Pump ■ Strokes ■ 0.1000 Bb(s /Strk ♦ 8.0 Strk/min ■ Type of Test: Other - See Comments ■ Pumping down drillpipe. ■ - Casing Test Pressure Integrity Test Hole Size: 13 - 1/2" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I 36.61Ft 4,513IFt -MD1 2,3871Ft -TVD _ 4,5451Ft -MD 1 2,3971Ft -TVD Strks psi Min psi Strks psi Min , psi Casing Size and Description: 10 - 3/4" 45.5 # /Ft L - 80 BTC v. 6 260 0 3050 1 10 0 1020 Casing Test Pressure IntegrityTest 8 :!'400 1 3050 2 40 0.25 1020 Mud Weight: 10.0 ppg Mud Weight: 9.8 ppg ;,1 0 ' 2 3050 3 100 0.5 1000 Mud 10 min Gel: 107.0 Lb /100 Ft2 Mud 10 min Gel: 42.0 Lb /100 Ft2 ' ' ' • 12 600 3 3050 4 150 1 960 Test Pressure: 3,000 psi Rotating Weight: 140,000 Lbs 14 700 4 3050 5 200 1.5 930 • Rotating Weight: 125,000 Lbs • Blocks/Top Drive Weight: 75,000 Lbs 16 780 5 3050 6 250 2 920 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 18 . 875 6 3050 7 320 2.5 910 Estimates for Test: 4.6 bbls Estimates for Test: 1018 psi 1.6 bbls 20 950 , 7 3050 8 400 3 900 ■ v 22 1010 8 3050 9 460 3.5 900 EMW = Leak -off Pressure + Mud Weight = 1000 + 9 8 PIT 15 Second 24 '41'00 9 3050 10 520 4 900 0.052 x TVD 0.052 x 2387 Shut -in Pressure, psi 26 ';1225 10 3050 11 580 4.5 890 EMW at 4513 Ft -MD (2387 Ft -TVD) = 17.9 1020 '.:28 ' 1275 15 3050 12 620 5 880 3500 Lost 0 psi during test, held 30 1350 20 3050 13 680 5.5 880 100% of test pressure. . 32 :1400 25 3050 14 720 6 880 3000:3:711. a == 34 '1550 30 3050 15 760 6.5 880 36 ,,1650 IIIPIl111',ililill6 800 7 880 ' 38 ji.1750 11'Ii1liClll!17 . 840 7.5 880 2500 ' • Ii111!I idil820 I �iillifill'�i11i1'8 880 8 875 w 11111i11111142 IMO 19 900 8.5 875 2000 ; i!i !lii':f ' ;020'50' 20 940 9 875 co . .5:ii '621i25 21 970 9.5 870 u) 2 2 25 >:,;G ,22 1000 10 860 al 1500 48 1110 re ' 50 2300 23 1020 : .. ,52 2450 1iIIIIN24 1000 _ ; �,�'� i 154 2550 25 . IrAlViNI56 2675 lulp!I11.I1: 26 500 Ii l:illii'1!1 2750 27 kiilii'ilii'60 2875 28 , ill 62 2950 29 o ' 64 3050 30 0 1 2 3 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume ametr■oCASING TEST -U —LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 6.4 Bbls if 1 '1 I''P 3.0 Bbis 11110l!'1Bbls i �illl.l. ii.l�l,�,i i L. Comments: Tested 10 3/4 " csg after bumping plug to 3000 psi for 30 mins. • • CD2 -468 7.625" Intermediate Casing Well: CD2 -468 7 5/8', 29.7 ppf, L -80 BTC -M Date: 12/15/2008 ConocoPhillips r Rig: Doyon 19 Alaska, Inc. f Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 • Top of Strin or To of Flange Doyon 19 RKB to Lower lock down 34 40 _r FMC Gen V Hanger 3.30 34.40 Jts 3 to 247 245 Jts 7 5/8" 29.7# L -80 BTCM Csg 10494.01 37.70 Halliburton Float Collar 1.03 10531.71 Jts 1 to 2 2 Jts 7 5/8" 29.7# L - 80 BTCM Csg 85.35 10532.74 Silver Bullet Float Shoe 2.10 10618.09 10620.19 10620.19 10620.19 10 3/4" Shoe @ 4,513' MD/2,387' TVD 10620.19 10620.19 10620.19 10620.19 9 7/8" Hole TD @ 10,632' MD / 4,077' TVD 10620.19 7 5/8" Shoe @ 10,620' MD / 4,076' TVD 10620.19 10620.19 Total Centralizers - 60 Tandem Rise & 53 straight blade 10620.19 30 - 7 5/8" Stop Rings on middle of jt. #'s 1 -30 10620.19 Tandem Rise centralizer two per jt on jts # 1 -30 10620.19 Straight blade centralizer on jts # 143, 144, & 145 Across 10 3/4" Shoe 10620.19 Straight blade centralizer one perjt on every other joint f/ # 147 to # 245 10620.19 10620.19 10620.19 10620.19 10620.19 260 joints in shed - 247 total jts. to run 10620.19 Last 13 jts. Stay out 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 Remarks: Up Wt 255K Dn Wt 128 K Block Wt 75 K Supervisors: David Burley / Jeff Browning 0 • fnIIifl Cement Detail Report jt :: = .illf+e!! `, CD2 -468 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 12 /2/2008 00:00 - - �- yea s- . % >.r - ; , ' . = Gement;Details -= __ _ = = "- �� _ Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/16/2008 18:30 12/16/2008 20:45 CD2 - 468 Comment Cemented casing as follows, pumped 3 bbis CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbls of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbis (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 464 bbis of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out job with full retums. Checked floats and held. Cale TOC @ 8,954' MD/3,705' TVD. Cement Stages _ - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Tail Cement 8,954.0 10,620.0 No Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 5 730.0 1,200.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented casing as follows, pumped 3 bbls CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbis of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbis (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbis water then turned over to the rig and rig fin. displacing cmt with 464 bbis of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out Job with full retums. Checked floats and held. Calc TOC @ 8,954' MD/3,705' TVD. _ _ � ,_ _ >:- :_,- ��a.., -�.. - tea- - -._- .may- , , _n .� v.,; _ CementFlulds - &- Additives -: ��, - „_ =��.� �� -. - ; °�a,•�.:.- . <- _,:..,,�_ : W aWgZ M-Ci r - V Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 8,954.0 10,620.0 463 G 96.0 Yield (ft' /sack) Mix H2O Ratio (gailsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC I Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) S002 0.8 %BWOC Page 1/1 Report Printed: 12/3/2010 • • Security Level: AK Development Daily Drilling Report CD2-468 Report Number: 15 Conoco Phillips Rig: DOYON 19 Report Date: 12/16/2008 - . -- -; - 10239757 10,220,999.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-468 Development QANNIK 14.03 15.0 0.00 10,632.0 10,632.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,572.19 335,586.95 633,403.19 3,939,208.88 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/2/2008 12/2/2008 28.24 30.44 -2.20 1/1/2009 Last Casing String Next Casing OD (In) Next Casing Set Depth (ftKB) INTERMEDIATE, 10,620.2ftKB Ops and Depth @ Morning Report 24hr Forecast LD 5" DP out of the derrick Fin LD 5" DP, MU Cleanout BHA & single in 4" DP, Drill out shoe track & 20' new hole, FIT, POOH & test BOPE Last 24hr Summary Phase 3 condition lifted @ 04:30 Hrs. Cont. to RIH with 7 5/8" csg & landed same @ 10,620'. Circ & cond mud then cemented csg with full returns, CIP @ 20:45 hrs with est. TOC @ 8,954. RU & tested 7 5/8" csg to 3,500 psi for 30 min. RD cmt head & landing jt. Installed packoff & tested same to 5,000 psi. General Remarks Weather Head Count No Accidents and No Spills 6 Deg, WC -11, Partly Cloudy, Wind E@ 11 50.0 mph Dave Burley, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer ime uoff •<„: Start: End Dur - , 1 - _ ,- ;=- ,- ;;; - - Depth Start Aiiet$.0:EnW* "07 - ;: =M*441,, Ofloi 00:00 04:30 4.50 INTRMI 'CASING WOW T Waiting Wait on 4,062.0 4,062.0 Wait On Weather - Phase 3, circ hole at Weather 4 bpm at 280 psi. NOTE: Phase 3 was lifted at 04:30 hrs. 04:30 08:00 3.50 INTRMI CASING RNCS P 4,062.0 6,635.0 Cont. RIH w/ 7 5/8" csg f/ 4,062 to 6,635' (155 jts total) 08:00 08:45 0.75 INTRMI CASING CIRC P 6,635.0 6,635.0 Circ btms up at 6,635' staging pump rate up to 7 bpm at 640 psi, st wt up 175K, dn wt 120K 08:45 11:30 2.75 INTRMI CASING RNCS P 6,635.0 8,823.0 Cont. RIH from 6,635' to 8,823'. (206 jts total) 11:30 13:00 1.50 INTRM1 CASING CIRC P 8,823.0 8,823.0 Circ btms up staging pump rate up to 6.5 bpm at 680 psi and hole appeared to have taken approx. 20 bbls, slowed rate to 5 bpm at 450 psi with no add. losses. St wt up 215K, dn wt 125K 13:00 15:30 2.50 INTRMI CASING RNCS 8,823.0 10,620.0 Cont. RIH with 7 5/8" csg from 8,823' to 10,582', MU FMC hanger and landed csg at 10,620' and fit collar at 10,532' with no problems. PU wt 255K, SO wt 128K. Ran a total of 247 jts of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 10,585.79'. Ran 60 Tandem rise cent, 30 stop rings and 53 straight blade cent. per well plan. 15:30 16:00 0.50 INTRM1 CEMENT RURD P 10,620.0 10,620.0 RD Franks fill up tool and MU Dowell cement head. 16:00 18:30 2.50 INTRM1 CEMENT CIRC p 10,620.0 10,620.0 Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm at 320 psi to 7 bpm at 600 psi, cond. mud to 10.0 ppg. in and out with 15 YP. St wt up 235K, dn wt 125K. Held PJSM on cement job while circ hole. Latest BOP Test Data 12/8/2008 Test BOPE - Annular to 250 & 2500 psi - Pipe rams - blind rams - choke manifold valves - kill & choke line valves - TD IBOP's - Page 1/2 Report Printed: 12/3/2010 Security Level: AK Development Daily Drilling Report CD2-468 Report Number: 15 C.onocoPhillips • Rig: DOYON 19 Report Date: 12/16/2008 Start Ed Depth Start ETptith i-Is) 18:30 21:00 2.50 INTRMI CEMENT DISP P 10,620.0 10,620.0 Cemented casing as follows, pumped 3 bbls CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbls of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbls (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 464 bbls of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out job with full returns. Checked floats and held. Calc TOC © 8,954' MD/3,705' TVD. 21:00 22:00 1.00 INTRMI CASING DHEQ P 10,620.0 10,620.0 RU and tested casing to 3,500 psi for 30 min. 22:00 23:00 1.00 INTRM1 CASING RURD P 10,620.0 10,620.0 RD cmt head, landing jt and long bales. 23:00 00:00 1,00 INTRM1 CASING OTHR P 10,620.0 10,620.0 Pulled thin walled wear bushing and installed 7 5/8" packoff, tested same to 5,000 psi for 10 min. MtaiCheOk.Data: pertsky Temp Tye Depth (ftKB) bens (i/Cit) PV Pate (cp) (IbfIlQOft .(lbftlagtP) N ', E(1PrilPPfP) :•':•(mt4Qn#6)1 LSND 10,635.0 10.00 41 13.0 15.0 7.0 9.0 11.000 0.0 0.0 0.0 Injection :=E-E74 From Lease.(bb1): Ntirnber:-: Note. 0.0 Welibore Name Wellbore APIAJWI CD2-468 501032058700 - Act Top (ftKB) Eltat(ftl<J3) End-lqate CONDI 18 37.0 114.0 SURFAC 13 1/2 114.0 4,525.0 12/2/2008 12/5/2008 INTRM1 97/8 4,525.0 10,632.0 12/9/2008 12/13/2008 PROD1 63/4 10,632.0 17,850.0 12/18/2008 12/26/2008 Intermediate Casing Cement - Started @ 12/16/2008 Type Welibore Cemented String Cement Evaluation Results casing CD2-468 INTERMEDIATE, 10,620.2ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bb1/... P (final) (psi) 1 Intermediate Casing Cement 8,954.0 10,620.0 4 730.0 Class - Amount (sacks), ,=:-; (OW) DentitY (lOrgaI) fYiekt(fP/sack) , EstTop Est stm Tail Cement G 463 96.0 15.80 1.17 8,954.0 10,620.0 Pressure Data . . ItemJested = (psi) Comment INTERMEDIATE, 10,620.2ftKB 12/16/2008 3,500.0 No Tested 7 5/8" csg to 3,500 psi for 30 min. Page 2/2 Report Printed: 12/3/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 -468 Rig: Little Red (Date: 7/14/2012 I Volume Input _ --- Pump Rate: Drilling Supervisor: I D. Mickey (Pump used: Other SeeComments Barrels ♦ Bbls /Strk ♦ 0.5 Bbl /min Type of Test: Annulus Leak Off Test for Disposal Adequacy ♦ Pumping down annulus. ♦ ^- Casing Test Pressure Integrity Test Hole Size: 13 -1/2" Iv Casing Shoe Dept I Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I IFt 4,513 It -MDR 2,387IFt -TVD _ 8,954IFt -MD I 2,397IFt -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC ■ 6 0 0 1030 0 1020 Changes for Annular Adequacy Test Pressure IntegrityTest 8 1 1 1030 1 g6r •uter casing shoe test results 10.0 in comments Mud Weight: 6.8 ppg 10 2 1.5 1020 2 Description references outer 107.0 casing string. Inner casing OD: 42.0 In. 12 3 2 1020 3 .ize is that drilled below outer 3,000 casing. 140,000 14 4 2.5 1020 4 .timated TOC for Hole Depth. 125,000 75,000 16 5 3 1025 5 MI Enter inner casing OD at right 75,000 Desired PIT EMW: 15.5 ppg 18 6 3.5 1020 6 925 Estimates for Test: 1080 psi -62.2 bbl 20 7 4 1020 7 925 Vi V 22 8 4.5 1020 8 925 EMW = Leak -off Pressure + Mud Weight = 1000 + 6 8 PIT 15 Second 24 9 5 1020 9 920 0.052 x TVD 0.052 x 2387 Shut -in Pressure, psi 26 10 5.5 1025 10 920 EMW at 4513 Ft -MD (2387 Ft -ND) = 14.9 960 28 15 6 1010 15 915 1500 - 20 6.5 1010 20 910 32 25 1010 25 910 34 30 7.5 1010 30 910 36 8 1010 38 8.5 1015 1000 40 9 1015 ����� 42 9.5 1015 CL 44 1 10 1020 U 46 w 48 • w - 50 500 52 54 56 58 60 62 0 64 I 0 10 20 30 40 50 60 70 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume 61 CASING TEST —0-LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 64.0 Bbls IBbls 10.0 Bbls IBbls Comments: 9 5/8" casing shoe LOT = 17.9 EMW LRS hot oil unit Do not exceed 1405 psi with diesel • • • • ‘• 795 f,14#0 *Wig thinatir Ond.'Peittens.wat:"..14.1:pina as well a.g4he:•:Piate up ilutiti.:resuititq. rom 0fAni;ng' W . cTloe • ig****0 tiaA 00P5...4474 41** - 'Ads34014# ddsoaL CD 1. 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" - • > iat.:.her..!.4.y.- ea,-• --..--,--. : ....„ r-qs. 4.. :,, .Q 0 PP.,..,:, - ' ,:---'•:,' '','' • 1: ,1,--'-'.--(3.ii•ica,%41.14 Isc -t'"7.-•'. • >' ka • - - ...s - . SOV rvetiti.0#0 P;LW.4 ''''''''' 4 ,..t.-, -j . 3 14N . At 1 0 . --:r...-...::::.:1 .1,, . ..........-.. . , . .. ..........:7.-.. s.;.*:......!....--4.:i4 . i ,„...„ 7 ., , s4ia.- , .. ,,, ...4:! ,,, . :.. ikiii.4i*.,::V4...00 v .,,....- ,.........,_ . i 2 .... .....• .• - . • 4PM-111m' ---tocetv01 • . • . . ....... ,. • • - • • • _ • I 1 . . • ( . . • • Note to File CD2 -468 (PTD 2081800 Sundry 312 -257) Colville River Unit (Qannik) ConocoPhillips Alaska, Inc (CPAI) ConocoPhillips has made application to authorize an additional 35000 bbl annular disposal in the subject well to bring the maximum documented to 70,000 bbl. This document examines the pertinent information for the well and recommends approval of CPAI's request. -- No unusual events were reported while drilling the surface hole of the well (CD2 -468). -- 10 -3/4" Surface casing was cemented to surface successfully. No problems were reported. Approximately 300 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 22% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 12/09/2008, the pressure slope rises smoothly to -16.2 EMW and continues at a slightly shallower slope to 17.9 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 16.6 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems are reported drilling the intermediate hole. The 7 -5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. - -An injectivity test down 10 -3/4" x 7 -5/8" annulus was conducted on 12/17/08. Pressure steadily increases until the break at 13.9 ppg EMW. The pressure declined with additional pumping to 13.5 ppg EMW. During the observation period, the pressure declined to 12.3 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. - -On the most recent LOT performed on 11/28/10 the pressure rises smoothly to a 15.5 ppg EMW and then continues on a shallower slope to a max of 15.9 ppg EMW. After breaking over, the stabilized pumping plateau is about 16.5 ppg EMW. Pumping pressure increased slightly during continued injection. Still under the surface shoe LOT of 17.9 ppg EMW. - -A pressure integrity test down 10 -3/4" x 7 -5/8" annulus was conducted on 7/14/2012. Pressure was consistently 1000 psi for 10 bbl diesel pumped at 0.5 bpm for a 14.9 ppg EMW. - -There are 3 wells within '/ mile radius of CD2 -468. The surface shoe of CD2 -02 is closest, about 368' distant. CD2 -09 is 1136' and CD2 -76 is 1118' distant. AD was recommended for CD2 -09 in 2004. There are no identified issues with any of the proximal wells. G: \tommaunder \Well Information\By Subject\Annular Disposal \120719_CD2 -468 AD request.doc • • As provided in 20 AAC 25.080 (b) (15), CPAI has provided information on their current well inventory status, schedule, well identification and decision process, and future disposal plans and options. CD1 pad wells were evaluated for annular injection operations and rejected for various factors relating to high injection pressures and wellbore integrity. Class I well CD1- 19A is currently non - operational and in need of a workover, and CRU WD -02 is deemed critical to the successful continuation of the project (sanitary waste disposal) and is at risk of being compromised by the injection of the high solids drilling waste streams. Other wells were evaluated and rejected based on overall project risk, operational status, workover risk, production impacts, and schedule impact. As provided in 20 AAC 25.080 (d) (1), after review of the information provided to demonstrate that compliance with the 35,000 barrel limitation is imprudent, I recommend that the commission determine to authorize disposal of drilling waste in a volume of not greater than 70,000 barrels through the annular space of CD2 -468. As provided in 20 AAC 25.080 (d) (4), after review of the information provided to demonstrate that compliance with the same drill pad generation and disposal of waste limitation is imprudent, I recommend that the commission determine to authorize disposal of drilling waste through the annular space of a well (CD2 -468) not located on the same drill pad as the drilling operation generating the drilling waste (wells CD1 -22B, CD1 -01, and CD1 -47). Based on examination of the submitted information, I recommend approval of CPAI's request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC July 18, 2012 G: \tommaunder \Well Information\By Subject \Annular Disposal \120719_CD2 -468 AD request.doc • • Note to File CRU CD2 -468 (PTD 2081800) December 14, 2010 Revised July 17, 2012 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well CRU CD2 -468 Request ConocoPhillips requests approval to dispose of 45,000 barrels of additional waste fluids generated through drilling operations by injection into the annulus surrounding the 7 -5/8" casing within well CD2 - 468. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10 -3/4" surface casing shoe is set in this well at about 4,513' measured depth ( "MD;" - 2,335' true vertical depth subsea, or "TVDSS "), near the base of a 500 -foot thick shale and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone, sandy siltstone, and sandstone open to the annulus surrounding the 7 -5/8" casing within this well to accept the proposed injected fluids. 3. The lower confining strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed additional disposal injection operations will not affect potential oil or gas reservoirs. The area most strongly impacted by the proposed disposal of an additional 45,000 barrels of waste drilling fluids will be limited to a radius of less than 150' from the wellbore. Injection of an additional 45,000 barrels of drilling waste may impact nearby well CD2 -72, but properly cemented surface casing and thick, upper confining strata will prevent migration of drilling wastes out of zone. Discussion CPAI's application was reviewed along with records from nearby wells Nuiqsut 1 and Alpine 1. The discussion that follows is based on those records and well logs from Nuiqsut 1, Colville River Unit (CRU) CD2 -33, CD 2 -467, CD 2 -32, and Alpine 1. An index map is provided in Figure 1, below. The CD2 -468 development well was drilled to the Qannik Oil Pool within the Colville River Unit. To date, ConocoPhillips has disposed of 22,888 barrels of drilling wastes into CD2 -468 by utilizing the open annulus that extends downward from the 10 -3/4" surface casing shoe, which is set at about 4,513' measured depth, or (- 2,333' TVDSS), to the top of cement for the 7 -5/8" casing string, which is estimated to lie at about 8,695' MD (- 3,376' TVDSS). This annulus begins within Section 35 of T11N, R4E, Umiat Meridian (UM), and it extends into Section 34 of T11N, R4E, UM. It lies more than 3 miles from the current boundary of the CRU. • • CD2 -468 July 17, 2012 Note to File Page 2 of 6 f CD2 -468 i 2 I , , `�\ I ._ Area of Review CRU CD2 -468 Annulus 2 3 3 4"1"411N4 . / \ ■ W ill C �, li I 4 1 , visik 14m IMIIIIII-, *- •-•?-- :0C411111k Surface Casing Shoe Alv I1 '- 10 /al 4 11111110- ; ,..- Figure 1. Index Map (The path of the cross - section shown on Figure 3 is highlighted with red; the path of well CD2 -468 is depicted by the blue line; all remaining Colville River Unit wells are depicted with gray lines and symbols. The gray - colored squares represent governmental sections that typically measure 1 mile on each side.) The section of open annulus that will most likely accept the proposed 45,000 barrels of additional injected waste fluids (the most likely receptor interval) is a portion of the Seabee formation that extends from 4,710' to 5,005' MD (- 2,405' and - 2,509' TVDSS; see Figure 2). This interval contains numerous 1- to 8 -foot thick beds of siltstone, sandy siltstone and sandstone that are separated by mudstone and shale. The aggregate thickness of the siltstone, sandy siltstone and sandstone beds open to the annulus is about 25'. On the well log recorded in from CD2 -468, the gamma ray curve suggests the presence of a prominent siltstone bed at the shoe of the 10 -3/4" surface casing. This apparent siltstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 10 -3/4" casing shoe consist of shale, claystone, with only minor amounts of siltstone (see Figure 3, below). The 10 -3/4 " surface casing shoe lies near the base of a 500 -foot thick interval that is dominated shale g ated by s a e and mudstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 40 -foot thick zone of claystone and mudstone that is also continuous throughout the area. This interval, which lies between about 5,212' and 5,357' measured depth (- 2,572' and - 2,612' TVDSS), and two similar, underlying strata will provide lower confinement for injected wastes. In vicinity of Drill Site CD2, the base of permafrost occurs at about - 1,200' TVDSS, which is about 1,200' shallower than the top of the most likely receptor interval. • • CD2 -468 July 17, 2012 Note to File Page 3 of 6 Correlation Depth Resis Porosity GR <MD Res RPD) RIIOB -10 API 24C 12 OI-tM 201 .65 GICC 2.6' • and - Si - Shale T� D S 5> ResM(RPM) ow Pao 12 OHMM 2n SP(NIA) T','D ResS(RPS) NPOR -100 10C 0.2 O44M 11.1 <MD DTCP(N /A) 70 71 m....o St 11111111111.111111111111111111111111 Upper 4000 •trim..-- - - -- - T .nxm..r�..r.iu.trr.. Confining —► ouni ..-. -.-10 Strata 1111111I�� = = ... 4700 -2400 U11i11ii:i-- wwimla Most Likely 4800 ■out emi�iiii Id iom Receptor •uuiiiiiiiii:iill -ilia Interval for ► Oi=lllllungi=w =H 11 nom. IN .m Disposed 4900 •i Hill 111111 Fluids �.-... a11N10�- ... -N- 5000 annu X1111. l......-.- a 1111111111111111111111111111111.111111 NMI II M 5100 IWJ rn . E lu.r�.- 1 1r111t 1 1 -'- =-`" " •1111111lIBM..r -.- " 5200 NW In 1111111111111111111111111111111111 __ - 5300 nWIm�Iii>fi��ll ■r 11111111lI■...m. 1 ilil •mums.... ■ii1111fmommi t1♦ 5400 •win. -- - -- gm ■ Wm..lr. -.IIIII L Lower 1nmmour .a.- -- Confining — o. a u i _____ m I 5 500 nnm.at- alr..ta�alr.u.tr Strata iu IInI- -.. - -- \ 5600 :11 :11 'I i e - , T \ an1n1INIMISM MINA. �... 2 ?0U ��.u11111iMI..MINI... i r i . a. 5700 1111u1111•!a- .1•.1•M1 111111.....E --111111•! . - ' IuiA/... -. . - 11111111-- .- .- -111111r /111 5800 ..nlm..-.u..inIrlaii. you 1111H � . � 1 ' ■IIIIIII---- IA- .irNkg , .allNlll�- .... -- 5900 ..num...nrmi....anw. 1111111111111 1111111111111•1111111111111111111111111101 ' '.fi /111111 . _ Figure 2. CD2 -468 Well Log Displaying Affected Intervals Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine 1 is an exploratory well located about 1 -1/2 miles southeast of the likely receptor interval. In Alpine 1, methane was first encountered at 760' measured depth (about -720' TVDSS), and it was • • CD2 -468 July 17, 2012 Note to File Page 4 of 6 1980250 2081800 2020290 1941720 501032025300 16891 ft 501032058700 1316 ft 501032041100 4309 R 501032021100 W ARCO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK ARCO NUIQSUT 1 COLVILLE RIV UNIT CD2 -468 COLVILLE RIV UNIT CD2 -32 ALPINE 1 1512 FSL 1457 FWL 2197 FNL 1904 FEL 1885 FNL 1525 FEL 1468 FSL 2248 FWL TWP: 11 N - Range: 4 E - Sec. 5 TWP: 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 1 „° Upper ,. Confining i 7., _ -2000 .,, ' Strata -2000 10 3/4" Casing Shoe _ . fist '' ;r .. - l ikely _ - -2500 s e eptor y -2500 . ° #tervalvw _ - — - _ ,over J ► ii Annulus _ ' . — - Co�tlfining ® • available _ # -3000 m -. *rata _ for - _ - - i f di sposal _ -3000 _ injection _ - 3500 = _ i S 3500 <- Cement Top _ : - _ I t — f " 1 � - i t * r -1000 • TD =7650 TD =17850 TD =11720 TD =7500 -4000 Figure 3. Structural Cross - section from Nuiqsut 1 to Alpine 1 encountered in significant quantities (more than 1% methane in air, or 50 units) at 1,155' measured depth (about - 1,015' TVDSS). In Nuiqsut 1, located about 3 miles southwest of CD2 -468, methane gas was first encountered at 710' measured depth ( -653' TVDSS). So, the entire most likely receptor interval contains some methane gas. The shallowest oil show encountered in Alpine 1 was a poor show observed between 2,980' and 3,080' - However, h description easured depth (from about -2,940' to 3,040 TVDSS). t e of this show note does c p not mention oil staining; the show was noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining is found in the description of a fair oil show that occurs from 4,025' to 4,080' measured depth (about - 3,985' to -4,040 TVDSS), which is about 1,475 true vertical feet below the most likely receptor beds for the injected material. The shallowest oil show encountered in Nuiqsut 1 was a fair show observed between 3,990' and 4,070' measured depth (from about - 3,930' to - 4,010' TVDSS, or about 1,420' below the most likely receptor beds in CD2 -468). The description of this show mentions free oil in the wet sample at 4,080' measured depth (- 4,020' TVDSS). So, near Drill Site CD2, the most likely receptor interval does not contain potentially commercial hydrocarbons. The chart presented in Figure 6, below, provides an estimate of the subsurface volume around CD2 -468 that will be affected by the proposed annular disposal operations. There are about 25' of porous siltstone, sandy siltstone and sandstone beds within the most likely receptor interval that are open to the wellbore, • • CD2 -468 July 17, 2012 Note to File Page 5 of 6 according to a count using the gamma ray curve from CD2 -468. Porosity well logs were run across this interval in Nuiqsut 1, CD2 -32, and Alpine 1, which are located 3 miles southwest, ''A mile east, and 1 -1/2 miles southeast, respectively. Inspection of the density porosity measurements in those three offset wells suggests an average porosity of about 27% for the siltstone, sandy siltstone, and sandstone beds. Based on these values, and assuming piston -like displacement of native formation fluids, the proposed additional annular injection activities will directly affect the receptor beds only to a radius of about 150' from the wellbore, as indicated on Figure 5, below. The nearest wellbores with open annuli are CD2 -02, CD2 -09, CD2 -76 and CD2 -72, which are about 370', 1100', 1100', and 1300' away, respectively, at the depth of the surface casing shoe and the most likely receptor interval (Figure 6). Injection of an additional 45,000 barrels of drilling waste may impact CD2 - 72, but properly cemented surface casing and the thick, upper confining strata will prevent migration of drilling wastes out of zone. Injected Fluid vs Affected Radial Distance CD2 -468 Wellbore (assumes 25' aggregate injection zone thickness and 27% porosity) 300 250 m `0 0 200 - -- -- E 0 0 U 150 -- -- -- _ a 72 100 - -- -- -- 0 0 50 -- -- - -- 0 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Amount of Injected Fluid (barrels) Figure 5. Radial Distance Potentially Impacted by CD2 -468 Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD2. The open annulus that will be used for disposal of the additional drilling wastes lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. • • CD2 - 468 July 17, 2012 Note to File Page 6 of 6 - 3000 4000 CD2 468 �, -4000 -5011 Annulus € -3500 y X500 CD2 76 - 00 1/4 mile AOR -4000 . ,,, . 4°- - 4506 , A \ -3000 \ ,, -3000 � - ;�� 0 35 10 ` . -2 CD')-468 CD2 -09 -7000; � �. CD2 72 0 CD2 02 7.388 S 0v ' ',5500 ` -2500 5000 . - 0 - :\ . - 2000 --4500 000 - 4006 ,- - .2I _ _ A Surface Casing Shoe '' ! 00 ON ,1500 V Figure 6. Nearest Wells that are Potentially Impacted by CD2 -468 Injection (The green - colored triangles represent surface casing shoes in nearby wells, and the yellow - colored rectangle represents the shallower portion of the open annulus in CD2 -468.) I recommend approval of this request to dispose of additional drilling wastes in well CRU CD2 -468 to a maxi o um of 70,000 barrels. � I'. /Z_ Steve Da te vies Senior Petroleum Geologist • • Rob Stinson Supervising Drilling Engineer P.O. Box 100360 Anchorage, AK 99510 (907) 263 -4449 (phone) c onocophill j ps rob .d.stinson @conocophillips.com July 18, 2012 Hand Delivered RECEIVE Commissioner Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission auk_ i $ 2012 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 pQGCC Subject: Supplemental Information Application for Annular Disposal of Drilling Waste on well CD2 -468 and CD2 -76 Request to move Muds and Cutting from CD1 to CD2 Dear Chairman Seamount: ConocoPhillips Alaska has recently submitted annular disposal applications on wells CD2 -468 and CD2 -76. This letter provides supplemental information on the subject applications and justification for taking drilling muds and cuttings from CD1 to CD2 for annular injection. For the current drilling program on CD1, CD1 -15 was identified as the well that CPA was going to use for annular disposal of muds and cutting. Initial injectivity testing on this well showed that it could be a viable candidate. However when CPA rigged up on CD1 -15 for annular disposal, annular injection could not be established with an injection pressure at the maximum allowable shoe pressure. This resulted in a detailed annular injection evaluation for all the available wells on CD1. Annular injection has not been utilized on CD1 since 2004. CD1 -15 and CD1 -48 are the most recent wells drilled and completed on CD1 after 2004, however annular injection could not be established on these wells. Attachment 1 is an annular injection summary spreadsheet which was used to evaluate annular injection candidates on CD1. This spreadsheet summarizes the annular injection volumes on CD1 by well and calculates the surface casing shoe separation from the current well CPA is drilling (CD1 -22) and the distance to other surface casing shoe on CD1 pad. This spreadsheet was used to identify which CD1 wells additional injectivity tests would be conducted on. The two key criteria utilized when choosing candidate wells for the test was: 1. The surface casing shoe is at least 500' away from CD1 -22 surface casing shoe, which is the well will be drilled. 2. The initial surface casing shoe LOT is at least 0.5 pound higher than the annular LOT equivalent mud weight. • • Base on the criteria, the wells chosen and tested were: CD1 -21 CD1 -30 CD1 -39 CD1 -18 CD1 -07 CD1 -38 CD1-26 CD1-25 CD1-30 CD1 -04 CD1 -23 CD1 -45 CD1 -34 CD1 -16 CD1 -42 CD1 -12 CD1 -05 CD1 -40 CD1 -14 CD1 -03 CD1 -37 CD1 -44 CD1 -48 CD1 -31 CD1 -09 Injectivity tests were conducted so that the maximum allowable surface casing shoe pressure would not be exceeded. Unfortunately, none of the tests show good injection behavior. Attachment II is a few representative injectivity test plots for reference. Since no annular injection wells were found on CD1. CPA reviewed annular injection wells on CD2. Both CD2 -468 and CD2 -76 where found to have good annular injectivity. As a result CPA is requesting permission from AOGCC to haul muds and cutting from CD1 to CD2 for annular disposal for the interim period until our new Class injection well, CD1 -01A is sidetracked and completed. CPA plans to finish the well Doyon 19 is currently drilling CD1 -22A. The next well planned is a side track on CD1 -01A and is being proposed as a new Class 1 injection well for CD1. Once CD1 -01A is completed and permitted as a Class 1 disposal well CPA will use this well as our primary muds and cutting disposal well and we will not have to move muds and cuttings from CD1 to CD2 for annular disposal. CD1 -19A is the Class 1 disposal well that has been used on CD1 for muds and cutting disposal. Unfortunately the tubing was recently compromised between the straddle packers set a crossed the Alpine sands. Plans to fix CD1 -19a are being reviewed. These plans have been complicated recently by a wireline fish in the well. WD -02 is a Class 1 injection well located on the Alpine pad. CPA relies on this well for injecting /disposing treated waste water and other Class 1 fluids from Alpine Operations. Alpine is a zero discharge facility and does not have an NPDES permit to discharge treated waste water. As a result CPA does not want to put solids down WD -02 and risk plugging this well off. This has been the standard for Alpine operations ever since WD -02 was drilled. If you have any questions regarding this supplemental information, please contact me at 263 -4449 or Weifeng Dai, Senior Engineer at 263 -4324. Sincerely, Rob Stinson Supervising Drilling Engineer SURFACE CASING SHOE SEPARATION FROM CD1 -22 CD1 -22 X Y Surface Casing Shoe ASP 4 Coordinates: 385890.63 5975753.63 uistance from Surface csg. Details @ Ann Vol Object Surface csg. Shoe Y Surface Surface Wells AOGCC Permit # Permit Date (bbls) End Date well* Shoe X Coord. Coord. TVD FIT /LOT Ann LOT Comments CD1 -01 y 339 -116 7/12/1999 383 386000.88 5976120.23 2364 15 15.4 Not a candidate CD1 -02 y 626 386406.59 5976107.32 2398 16 16.7 Not a candidate, questionable surface casing FIT CD1 -03 y 300 -005 1/13/2000 870 385744.09 5976611.32 2370 15.8 15.1 Test failed CD1 -04 y 1232 386800.96 5976584.44 2377 15.7 13.9 Test failed CD1 -05 y 300 -022 1/27/2000 926 386752.76 5976091.39 2387 16 15 Test failed CD1 -06 y 1404 387261.90 5976054.67 3090 16 15.7 Not a candidate CD1 -07 y 304 -047 2/19/2004 1494 387324.34 5975332.78 2362 16.9 13.2 Test failed CD1 -08 y 304 -382 11/1/2004 2123 387783.06 5974790.61 2343 16.2 15.3 Test failed CD1 -09 y 300 -163 6/22/2004 1540 387400.42 5976058.56 2790 15.99 13.7 Test failed • CD1 -10 y 322 386080.76 5976013.75 2403 15.9 15.7 Not a candidate CD1 -11 2025 387540.43 5974579.42 2363 18.1 15.6 Test failed CD1 -12 1557 387039.60 5974702.41 2347 15.2 13.8 Test failed CD1 -13 y 399 -121 7/19/1999 457 386333.24 5975867.57 2387 15.6 15.6 Not a candidate CD1 -14 2240 388120.50 5975539.11 2366 16 15.1 Test failed CD1 -15 y 1449 387230.46 5976306.05 2394 16.6 14.6 Permitted, but fail to inject CD1 -16 y 399 -213 11/2/1999 805 386666.50 5975539.37 2399 15.9 14.2 Test failed CD1 -17 y 536 386386.08 5975549.67 2385 15.24 16 2000 well CD1 -18 y 1030 386303.66 5974809.97 2354 18 15.2 Test failed CD1 -19 y 399 -064 4/20/1999 1157 386182.40 5976873.16 2393 14.6 Class I Disposal Well CD1 -20 y 1457 386803.35 5974618.03 18 15.7 Test failed CD1 -21 y 304 -009 1/12/2004 32000 1123 385033.54 5976479.08 2391 16 14.8 Test failed CD1 -22 y 0 385890.63 5975753.64 3110 CD1 -23 y 399 -141 8/5/1999 1625 387499.21 5975525.36 2398 13.6 N/A Test failed CD1 -24 1124 387001.62 5975585.79 2390 13.4 11.9 Not a candidate due to low FIT CD1 -25 y 300 -102 4/17/2000 33587 1108 386816.46 5975145.40 2398 16 14.8 Test failed CD1 -26 y 996 386511.26 5974974.98 2389 15.9 14.5 Test failed CD1 -27 y 300 -058 3/22/2000 972 386148.85 5974816.28 2366 16 15.2 Not a candidate due to communication between IA and OA CD1 -28 y 111 385780.25 5975747.82 2372 16 15.7 Not a candidate CD1 -229 y 1887 386239.91 5973899.61 2385 15.6 14.5 Test failed CD1 -30 y 1162 384814.85 5976193.13 2387 16 14.8 Test failed CD1 -31 y 300 -263 848 385054.61 5975893.22 2378 15.2 14.5 Test failed CD1 -32 y 399 -245 1138 384754.69 5975829.24 2413 15.2 15.5 Not a candidate CD1 -33 y 138 385796.34 5975652.73 2430 15.8 16.3 Not a candidate ID CD1 -34 y 300 -133 5/8/2000 378 505 385543.31 5975386.66 2361 16 14.2 Test failed CD1 -35 y 399 -086 5/21/1999 317 270 385634.65 5975667.79 2388 15.7 16.7 Not a candidate CD1 -36 y 399 -260 1/3/2000 713 385189.14 5975626.47 2406 15.3 15.5 Not a candidate CD1 -37 y 399 -162 8/27/1999 32587 1120 385828.32 5974635.64 2409 15.5 15.1 Test failed CD1 -38 y 300 -051 2/29/2000 1287 385516.01 5974522.02 2376 16.1 15.6 Test failed CD1 -39 y 399 -181 9/10/1999 861 385568.87 5974954.54 2388 15.5 15.1 Test failed CD1-40 y 399 -101 6/11/1999 1654 385005.59 5974356.58 2392 16 15.4 Test failed CD1 -41 y 300 -104 4/24/2000 707 385231.03 5975499.87 2394 15.2 15.4 Not a candidate CD1 -42 y 399 -261 1/3/2000 1364 384596.37 5975321.88 2384 15.3 14.7 Test failed CD1 -43 y 300 -241 9/20/2000 1428 384753.45 5974889.55 2386 16 16 Not a candidate CD1 -44 y 300 -146 5/31/2000 31928 2115 384506.22 5974155.17 2375 15.5 14.8 Test failed CD1 -45 y 299 -233 11/17/1999 1351 384726.63 5975067.43 2385 16 14.2 Test failed CD1 -46 y 304 -381 10/22/2004 1663 385970.99 5974092.50 2362 15.5 15.3 Not a candidate CD1 -48 y 1857 385856.15 5973896.95 2396 15.40 14.20 Test failed * Lateral distance in feet, between surface casing shoes, in the X -Y plane Note that this sheet is not the definitive record. ` . , PRESSURE INTEGRITY TEST . � L CONOCOPHILLIPS Alaska, ' 'Date: Name: CD1-21 Rig: 7U3C2012 Pump Rate: Drilling Supervisor: l D. Mickey |�umm � r -[-- � L_- �____� 'Pump ~~~ ~~ �~. ~ � aanus ! �N� � �� 0�8 om/mm | �� Type of Test Leak Off Test for Disposal xdcv�� |�� �un�p�gdmxnm :annulus. / �r ~ - ' ^ - ~"" | ~ ' Casing Test Pressure Umte8,ityTest ----�--� Hole Size: 9-7/8 |=' Casing Shoe Depth | h Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:| |Ft 271O.O|Ft-K4D| lJ�S�'�|F�TVO_ 8376.01R-MD |�724�� U Bb|n psi Min n | psi Bbls psi Min psi - �_ �� _ Casinq Size and Description: | y's�^»o#/���oarc / 0 0 810 0.00 1110 Chanqes for Annular Adequacy Test P�ssun*|ntephtvTost 1 0.5 850 0.25 1100 Enter outercasing shoe test results in comments Mud Weight: ( ` 7 ppg 2 1 920 0.50 1080 Casing description references outer casing string. Inner casing OD: 70 3 1.5 1020 1.00 10 Hole Size is that drilled below outer casing. ` 4 2 1060 1.50 1046111/ Use estimated TOO for Hole Depth. 5 . 2.5 1100 2.00 1010 Enter inner casing OD at right. Desired PIT EMW: - 5 ppg 6 3 11i`/ 250 1 00 3.5 1138 3.00 990 Estimates for Test: 1089 psi 1 '�b��� � 7 . � �� 8 3.50 980 - -- EyN�/= ff Geok~opreeeure + lMud VVeight= -- 1138 1p|Ti5Secon6 9 4.00 970 +6.7 0l>52xTVQ 0.052 x 2379 Shut-in Pressure, psi 10 4.50 970 | |�N���a%2718 Ft-MD Ft-TVD) 15.9 | 1100 15 5.00 970 1500 ---�-----�---�-- ---------- --� ---- ' 20 5.50 970 '__'_ ___-____--- - ---�--------' - | 25 6.00 070 . 30 0.50 070 --�---- - '---- ------- - -----' ------� 7.00 'rO 7.50 970 --------' ---- 8U0 97O 8�50� lmm -'- -------- -------- \ma ---- 970 ---------'---'-- ------ ------' --------------' 0.80 870 m n ----' - - ------- -'------'- -------- ---� '--------�---1--- 9.50 970 cr) --- --' -- '-- - --- --- - '- • --'�--� ' 1O�O0� 970 re __� _--- __� ___-_____ __��____- __ __.- _ _ �m� .. ="- ________-_______-__�____�-_____--___ . _____`___ __..` _________. -�---- --- -- j o ` / ^ o , e ^ s " 0 5 10 m 20 25 30 Barrels Shut-In time Minutes Volume Volume Volume Volume ='dr•• CASING TEST -In- LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back _ _ 0.0 Bb|o Bb|s 3.5 Bb\s Bb|o Comments: 9 5/8 casing s oo~ = 6.0 ppg Do not exceed 1138 psi with diesel cun-21 Annular Lu/ o/-1.3'12 Summary • ' , ^ PRESSURE CONOCOPH0K-L8PS Alaska, Inc. � | | ' Well Name: CD1-34 | | Ryg:} | Little Red Services 'Date: � 7/13/2012 � Volume Input Pump Rate: _ Drilling Supervisor: | »Ho«jinQ |Pump avn�� "V. ( au��r . 'V ! V.5 cmymm l Nr | - ' — ---- -- -------- - ' '---- '� � | Type ofTet' | mmukou�xOff T�tunompo�lm�«o�v III Pumping down !annulus. / • � Test � ^ � ^ i Test ' --- ' | ! � � Casing e� noasure nte�rty Hole Size: *1/2" |V Casing Shoe | Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF] IFt 2,433 kt'K»D| 2. I P�yWD | {i Bbls psi Min psi Bbls psi Min psi |"�� ` —- � | � Casing Size .. 36#/Ft / 0 0 840 (} 11�V � Changes for Annular Adequacy Test Pressure |mteor|tvTms1 . 1 0.5 860 1 1180� • outer casing shoe test results in comments Mud Weight: 6. 2 11 880 2 1180 Description references outer casing string. Inner casing OD: 7.0 In. . 3 1.5 980 3 1160 3izo is that drilled below outer oaoing. b 4 2 930 ____4 ' �~ �mn0edTO�fnrHo|eD*pUx� . _ , 5 2.5 980 5 115�= Emm,inner casing 0Donhqht' Desired PIT EMW: 15.5 ppg . 6 3 980 6 1155 Estimates for Test: 1070 psi O.Bbb|m 7 3.5 1040 7 1155 � `~| 8 4 1080 8 1155 �� ��������� EMW = Leak-off Pressure + Mud Weight = 661 PIT 15 Second 9 4.5 1140 9 1155 + 6.8 , 0.052 x TVD Q�52u 2365 Shut-in Pressure, psi 10 4.6 11OU� 10 1155 ������ at 2433 Ft-MD (2365 Ft-TVD) 12.2 1160 15 5.5 15 1150 . 1 5 0 0 �----� --------- ----��—' ----- ---------- ---- 20 6 20 1150 --�-' - -----'---- ---- ------- ' 25 6.5 25 1145 ' 30 7 30 1140 | 7.5 mke • 1 • = 8 --------'� ---'-- | -- ! ----'-----'' ---- - . / 8.5 woo -------' -'----'---�----- ' ---� -------------- . tll - -----------''- ' --� Q�5 ' -------- ------------�' - -- 10 ------- --�--------- ---' --- ---- --'-----� -- :�N� ill IX i 2[ ---'--- --''--------� -'--- --' ---------- --�--- ��r • 500 - __--____-__ _ ____- _ , � � . ' - '------ ------ — - -- '---- - --'-------- . ���`������ �������������. --- -- - --- �---�- - 0 | � ` u 2 4 6 o 10 12 14 16 0 5 10 `, 20 25 30 Volume Volume Volume Volume Barrels Shut�nhn,e. Minutes / =mn=o^a/mo —e— Le*x'orprsnr 0 PIT Point Pumped Bled Back Pumped Bled Bank | U�n �bis |�b1s 10.0 Bb|o |Bb|u Comments: '� - `" casing shoe LOT �� � ���.'----- ----' - ---- --------------- � LRS hot oil unit Do not exceed 1160 psi with diesel PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD1-48 Rig: No rig on well 'Date: 1 7/16/2012 1 Volume Input Pump Rate: Drilling Supervisor: 1 D. Mickey Pump used Other - See Comments yr 1 Barrels 1r Bbls/Strk ° Itr 1 0.5 Bbl/min 1 1/ ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy i V' Pumping down annulus. Ill' Casing Test Pressure Integrity Test Hole Size: 1 8-3/4" ' ". Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:1 IFt 3,160 (Ft-MD I 2,3961Ft-TVD 3,190IFt-MD 1 2,411 iFt-TVD Bbls psi Min psi Bbls psi Min psi - Casing Size and Description: 9-5/8" 36#/Ft 3-55 BTC 1» 0 0 560 0 1090 Changes for Annular Adequacy Test Pressure Inte • r , it Test 1 0.1 660 1 1080 outer casing shoe test results in comments Mud Weight: 6.8 ppg 2 0.2 740 2 1075 Description references outer casing string. Inner casing OD: & In. 3 0.3 840 3 1070 size is that drilled below outer casing. 4 0.4 940 LIIIINIO 'itimated TOO for Hole Depth. 5 0.5 1090 5 1070 Enter inner casing OD at right Desired PIT EMW: 15.5 ppg 6 6 1070 Estimates for Test: 1084 psi ##$##/#/# 7 7 1065 iv Vi 8 8 1060 _ EMW = Leak-off Pressure + Mud Weight = 860 + 6 8 PIT 15 Second 9 9 1060 . 0.052 x TVD 0.052 x 2396 Shut-in Pressure, psi 10 10 1060 EMW at 3160 Ft-MD (2396 Ft-TVD) = 13.7 1080 15 15 1500 . _ 20 20 25 25 - — ---- -- 30 30 _ ___ __________ _. _ _ __ 1000 tu __S.__ _. _ _ ____ _ __ __ ____ _ . _ _ . _ . U3 _ co , w tz 500 • a. — _ _ _ . ____ _ _ _ _ - - - _ - 0 0 1 0 5 10 15 20' 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume sodumeCASING TEST -.1111— LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls Bbls 0.5 Bbis Bbls Comments: Used Little "ed's Hot Oil Truck for pumping Diesel Original 9 5/8" shoe LOT = 15.4 ppg Do not exceed 1090 psi with diesel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208 -180 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil El Gas ❑ WAG 111 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final 0 310 -404 12/17/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal tt drilling mud, completion occurred `°`� 2U12 • fluids, formation fluids and any necessary water added Previous 462* 462 totals (bbls): 2010 / 4th 0 0 15* 15 0 2011 / 1st 22311 100 0 22411 20 1/3/2011 2/6/2011 CD2 -77 2011 / 2nd 0 0 0 0 0 2011 / 3rd 0 0 0 0 0 2011 / 4th 0 0 0 0 0 • Total Ending Report is due on the 20th Volume 22311 100 477 22888 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes and injectivity test volumes only 1 hereby certify that the foregoing is tr and correct to the best of my knowledge. Signature: C Date: /'(G 0- QL Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 ABDM JAN 0 9 Form 10 -423 Rev. 2/2004 l - INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA �d -1 ®�0�4 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL Alaska Oif & Gas Gan G ®m Anchorage 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208-180 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil • Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -404 12/17/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 462* 462 • totals (bbls): 2010 / 4th 0 0 15* 15 0 2011 / 1st 22311 100 0 22411 20 1/3/2011 2/6/2011 CD2 -77 2011 / 2nd 0 0 0 0 0 2011 /3rd 0 0 0 0 0 Total Ending Report is due on the 20th Volume 22311 100 477 22888 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the • Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances =.. 4 E .yl"k_ 6 2011 Description(s): *freeze protect volumes and injectivity test volumes only • I hereby certify that the foregoing is true,and correct to the best of my knowledge. Signature: ',i4.— C!. ` Date: /r? (C ( 1; t Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 R8DMS OCT 14 2t1 'N INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208 -180 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 111 or Final ❑ 310 -404 12/17/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and ill any necessary water added Previous 462* 462 totals (bbls): 2010 / 4th 0 0 15* 15 0 2011 / 1st 22311 100 0 22411 20 1/3/2011 2/6/2011 CD2 -77 2011 / 2nd 0 0 0 0 0 2011 / 3rd Total Ending Report is due on the 20th Volume 22311 100 477 22888 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances JUL 4 ZO'i t Description(s): * freeze protect volumes and injectivity test volumes only "A I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /"'* -C�‘,... Date: Z[ / G ati " Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 208-180 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD2 -468 2. Address: 4b. Well Status: Oil © Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50- 103-20587 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation © or Final ❑ 310 -404 12/17/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and • any necessary water added Previous 462* 462 totals (bbls): 2010 / 4th 0 0 15* 15 0 2011 / 1st 22311 100 0 22411 20 1/3/2011 2/6/2011 CD2 -77 2011 / 2nd 2011 / 3rd Total Ending Report is due on the 20th • Volume 22311 100 477 22888 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. , 12. Remarks and Approved Substances 504 APR 1 2O ! t Description(s): *freeze protect volumes and injectivity test volumes only I hereby certify that the foregoing is and correct to the best of my knowledge. /� Q Signature: , t. . Date: 4,11 6 6 4 Printed Name: f G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate r SEAN PARNELL, GOVERNOR C ON SER VA T ION ��SKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIISSIO„ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. AA DEC 2 0 Z01 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Oil Pool, CD2 -468 0 Sundry Number: 310 -404�� Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above- referenced well. Please note that any disposal into the surface/ production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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, Daniel T. Seamount, Jr. Chair DATED this] ; day of December, 2010 Encl. ConocoPhillips Alaska, Inc. r Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conocmc hi I I i ps Telephone 907 - 276 -1215 December 6, 2010 Alaska Oil and Gas Conservation Commission 333 West 7 h Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilline Waste on well CD2 -468 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2 -468 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The anticipated start date for annular disposal operations on CD2 -468 is Jan 06, 2011. Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form �-► 2. Pressure Calculations for Annular Disposal F-0 IVED 3. Summary of wells on Pad 4. Plan View of Adjacent Wells DEC 0 9 20101 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job Alaska U4 :LOS cons. I on 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 10 -3/4" x 7 -5/8" casing annulus. ✓ 11. List of Wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within I /4 mile radius at AOGCC: CD2 -02, CD2 -09 13. Incremental information regarding remaining wells within 1 /4 mile radius: CD2 -76 14. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (13.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (17.9 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Nina Anderson at 265 -6403; Liz Galiunas can also be reached by calling 265 -6247. Sincerely, Nina Ande son Sharon Allsup -Drake ATO -1530 Drilling Engineer cc: CD2 -468 Well File Chip Alvord ATO -1577 kA STATE OF ALASKA \11' * RECE ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 9 2010 ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ►aska Q4 & Gas COns• C O ffWS" 1. Operator 3. Permit to Drill Name: 208 -180 ConocoPhillips Alaska 4. API Number: 50- 103- 20587 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2 - 468 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: Torok and Seabee formation, shale, siltstone and sandstone CD2 - 02, CD2 - 09, CD2 - 76 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1911' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 462 bbls Dec 2008 densities range from diesel to 12# /gal 2222 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act 16. Estimated start date: of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added 6- Jan -11 water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ❑ FIT Records w /LOT Graph Q Surf. Casing Cementing Data El Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 1 Signature: 41 Title: Printed Phone Name: Chip Alvord Number: 265 -6120 12/7/2010 Commission Use Onl Conditions of approval: LOT review and approval: Subsequent form requi. : f " �Z1 Approval number: �� 1 APPROVED BY Approved by: f - °` COMMISSIONER THE COMMISSIO Date: 1 flo nnic MAI Form 10 -403AD Rev. 6/2004 1 ,,(& ON REVERSE V owSubmit in Duplicate 17zje4 Annulus Disposal Transmittal Form - Well CD2 -468 AOGCC Regulations, 20 AAC 25.080 1 IDesignation of the well or wells to receive drilling wastes: CD2 -468 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15- 1999) 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. Maximum volume to be pumped is 35,000 bbls. i 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and di sposal operations is 2222 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated pressure of disposal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD2 -77 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) V-1- t.o - Jm os Well CD2 -468 Assumptions Date 12/6/2010 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft ' I I' iIIIIVIiII Header Pressure (for wells on gas lift) 1,000 psi Maximum Fluid Density o avoid Burst of Surface Cas g {� Pburst85% — PHydrostatic + PApplied - PFormation ll'lllilllll 3,043 = ( 2,387 * 0.052 * MW,, ) + 1500 ( 0.4337 * 2,387 ) o.. I i MWmax = 20.77112 ppg �� Il l l l i lp l ' ; I a 2,387 TVD Surface Casing String Size 10.75 in pVil'l Weight 45.5 ppf Grade L 80 eni P o 3 580 � r burst100 p � P Pburst85% 3,043 Psi r Depth of Shoe 2,387 ft FIT/LOT @ Shoe 17.9 ppg or 2,222 psi t FTT/LOT for Annulus 13.9 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 8,954' MD 3,741' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% — PHydrostatic + PApptied PGasGradient - PHeader 4,072 =( 3,741 * 0.052 * MW )+ 1,500 - (0.0700 * 3,741) - 1,000 MW... = 19.7056 ppg 3.5 "Tubing 2nd Casing String Size 7.625 in 4,513 TVD Weight 29.7 ppf Grade L 80 Pcollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 3,741 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe P. allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable — ( 2,387 * .052 * 17.9 ) Pmax allowable — 2,222 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". SURFACE CASING SHOE SEPARATION FROM C132 -468 CD2 -468 X I Y Surface Casing Shoe ASP 4 Coordinates: 369193.601 5976400.42 Distance from Surface csg. Details @ Ann. Object Shoe X Surface csg. Wells AOGCC Permit # Permit Date Source well Vol. * * ** Start Date End Date well* Coord. Shoe Y Coord. CD2 -01 y 3939 373114.47 5976019.06 CD2 -02 368 369431.33 5976119.22 CD2 -03 Included T5F1 371040.60 5976495.42 CD2 -05 y 0 2870 370258.601 5973735.40 CD2 -06 y NA 0 2447 371610.81 5976018.45 CD2 -07 y NA 0 3027 372218.06 5976287.95 CD2 -08 372655.88 5975603.76 CD2 -09 304 -362 9/30/2004 418 113 370318.00 5976239.00 CD2 -10 y 304-289 7/30/2004 CD2 -09, CD2 -56 30703 8/27/2004 10/15/2004 2637 371800.58 5976006.36 CD2 -11 y 1912 370835.25 5975420.76 CD2 -12 y 303 -365 12/12/2003 CD2 -57, CD2 -31 32000 5/15/2004 6114/2004 2107 371071.29 5975445.60 CD2 -13 y 3519 372658.78 5975785.31 CD2 -14 y 301 -288 10/9/2001 CD2 -45, CD2 -47, CD2 -32 31073 11/13/2001 3/5/2002 3336 372202.471 5974960.87 CD2 -15 y 301 -308 11/6/2001 CD2 -50, CD2 -25, CD2 -44 31652 3/6/2002 9/2112002 2166 370832.001 5974984.02 CD2 -16 y 3642 372460.34 5974790.01 CD2 -17 y 302 - 122 4/10/2002 CD- 48, CD2 -08 18181 5/29/2002 2/712003 3121 371774.00 5974645.00 C132 - 18 y 1799 369825.76 5974716,05 CD2 -19 y 303- 083 4128/2003 CD2 -58, CD2 -52 31337 5/19/2003 6/27/2003 3537 372284.88 5974681.33 CD2 -20 y 304-288 7/30/2004 452 2349 371366.14 5975507.11 CD2 -21 y 1579 370286.77 5975261:48 CD2 -22 y 302 -274 9/20/2002 CD2 -08, CD CD2 51 31253 2/7/2003 3/16/2003 3091 371678.61 5974562.30 CD2 -23 y 303 -080 4128/2003 CD2 -18, CD2 -55, CD2 -06 32000 9/4/2003 1/1/20041 2254 371013.171 5975070.46 CD2 -33 ( +A &B), CD2 -39, CD2 -14, CD2 -24 y 301 -186 7113/2001 CD2 -15 33999 7/16/2001 10/9/2001 2209 370630.11 5974721.81 CD2 -25 y NA 3075 371594.001 5974479.00 CD2 -26 y 302 -068 3/4/2002 CD2 -44, CD2 -29, CD2 -13 29626 9/7/2002 10/17/2002 3193 371798.521 5974554.55 CD2 -27 y 304 -226 6/23/2004 CD2 -53, CD2 -05, CD2 -09 32000 7/9/2004 8/27/2004 5091 373046.071 5973071.83 CD2 -28 y 3387 372139.801 5974728.95 CD2 -29 y 303 -249 8/25/2003 CD2 -06, CD2 -30, CD2 -27 29036 10/8/2003 11/19/2003 3772 372652.441 5974896.02 CD2 -30 y NA 0 3069 370473.521 5973610.96 CD2 -31 v NA 0 2049 369824.37 5974451 30 CD2 -32 y 302- 119 4/30/2002 CD2 -19, CD241, CD2 -23 31113 6/14/2002 7/23/2002 2970 371295.61 5974302.38 CD2 - 33'13*** y 2692 370155.64 5973886.23 CD2 -34 y 302 -069 3/4/2002 CD2 -13, CD2 -37 22842 10/17/2002 11/28/2002 3264 371803.06 5974439.79 CD2 -35 ** y 3925 372312.31 5974017.68 CD2 -36 y 303 -365 12/1212003 CD2 -43, CD2 -31, CD2 -57 32000 12/31/2003 7/9/2004 3906 371848.22 5973535.38 CD2 -37 y 1 4252 371569.79 5972874.47 CD2 -38 I y 303 -082 4128/2003 CD2 -40, CD2 -30 30011 7/28/2003 9/4/20031 4040 372033.86 5973527.13 CD2 -39 y 301 -281 10/9/2001 CD2 -15, CD2 -47, CD2 -44 29945 10/10/2001 9/1612002 4198 372350.611 5973633.17 CD2 -40 y NA 0 3000 370691.67 5973801.44 CD2 -404 y 307 -154 5/8/2007 CD2 -72 6764 5/14/2007 5/31/2007 1922 370646.55 5975142.76 CD2 -41 y 303 - 081 4/28/2003 CD2 -20, CD2- 55,CD2 -43 32000 6/27/2003 7/28/2003 3817 371990.58 5973802.52 CD2 -42 y 301 -140 6/1/2001 CD2 -24, CD2- 33, CD2 -33A, CD2 -15 33 6/1/2001 10/10/2001 3070 371098.46 5973992.48 CD2 -43 - Arch I IIIII IIIIII11111111 ; 3111 ' i 370344.04 7 7 597052a-6 CD2 -44 y 3516 372034.57 5974328.53 CD2 -45 y 301 -345 12/13/2001 CD2 -49, CD2 -17 22991 1/2012002 2/19/2002 4387 372765.13 5973853.74 CD2 -46 y 302 -273 9120/2002 CD2 -51, CD2 -12 31864 4/15/2003 5/19/2003 3259 371694.80 5974310.85 CD2 -47 y 301 -322 12/3/2001 CD2 -34, CD2 -26 27349 12/17/2001 1/20/2002 3715 371231.72 5973294.19 CD2 -48 y 302 -275 9/20/2002 CD2 -28, CD2 -35a, C132 -45, CD2 -08 32000 12/10/2002 2/4/2003 3611 371631.74 5973736.14 CD2 -49 y 302 -070 3/4/2002 CD2 -50, CD2 -46, CD2 -22 27960 4/22/2002 5/28/2002 3113 371252.38 5974065.93 CD2 -50 y 1302-121 4130/2002 1 CD2 -41, CD2- 19, CD2 -16, CD2 -38 32000 7/24/2002 9/7/2002 3291 371665.21 5974227.65 CD2 -51 y 303 -312 10/28/2003 CO2 -07, CD2 -10 31769 11/19/2003 12/24/2003 49301 373114.02 5973411.81 CD2 -52 y NA 1 4400 372637.61 5973661.63 CD2 -53 y 304 -361 9130/2004 CD2 -56, CD2 -54, CD2 -02 26072 10/3/2004 8/5/2005 5372 372896.67 5972509.19 CD2 -54 y NA 0 3140 369991.09 5973363.59 CD2 -55 y 3739 371118.23 5973194.84 CD2 -56 v 305 -307 10/11/2005 CD2 -404 11167 5/7/2006 5/23/2006 3416 369875.93 5973053.08 CD2 -57 y 305 -238 8/17/2005 CD2 -01 19181 8/22/2005 9/12/2005 5272 372537.05 5972324.37 CD2 -58 y I NA 4740 372102.03 5972657.80 CD2 -59 ! 2395 369650-94F 5974049 85' CD2 -60 y 4564 371269.33 5972336.05 CD2 -75, CD2 -464, CD2 -466, CD2 - CD2 -72 y 308 -153 4/28/2008 463 26564 5/3/2008 7/6/2008 1411 369745.64 5975101.63 CD2 -75 v 308 -213 718/2008 CD2465,CD2 -470 10645 8/22/2008 10/30/2008 3200 369536,59 5973218.56 Ga A °n 0118 CD2 - 4831 ,D2 packed) 0011 11 1H18 X917 - 720111.96 I III11 59"4 CD2 46v r Arct packed :.... :. r� X372243 59 a ''l 11454)4 CD2 -465 ed , "IIIIUIIIVIIV - 1' IVIWIu I'. 3 11154 I11III 976521'"19: I ul CD2 -466 308 -294 10/23/2009 CD2 -73 15523 - 7/26/2009 11/112009 1658 37068418 5977125.90 CD2 -467 y 308 -295 1012012008 'CD2 -468, CD2 -73, CD2 -469 18892 11110/2008 1/10/2009 2369 370335A61 5974325.43 CD2 - 468 n 0 369193.60 5976400' CD2 -469 n 3035 369453.78 5973376.17 CD2 47Q r '; Altac SCI( � Vh IIINIIg II 1 �y IIII� 4173922.61 CD2 -73 n 1421 369210.81 5974979.59 CD2 -74! n 1801 369260.37 5974601.12' CD2 -78 n 2712 369256.11 5973689.42 CD2 -76 n 111 370 74.881 5975712.70 CD2 -77 n 9 371551.00 5972301.20 C132 468 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 17 07, December 02 i Name TVDSS +N / -S +E / -W Northing Easting Shape • CD2- 468wp05 Heel 4015.00 7149.13 - 5021.24 5981146.52 1506465.35 Point - Quarter Mile View CD2- 468wp05 Toe 4015.00 14555.85 - 3625.65 5988527.53 1507988.09 Point '1 O QO GO Gp , , G p , L 09 CD2 '466 CD ?'g65 CD2- 4500 r CD2 469 16Q CD2 -468 Gp � V G Q0 i GOB; Oti16 G 3750 . 3000 , 10 -3/4" x 13 -1/ " O Gp'L LO ti + 10 3/4" X 250 y 10- "x13 -1/2" � CD2 -09 �. Z CD2 -02 4" CD2 -76 o 500 CD2 -72 2" 750 0 � CD2 -73 9 -5/8" 12- G �9 X10 -3/4" 10/4" x 13 -112" " x 13 -T12 9 -5/8" x 12 -1/4 _- -- 10/4' a 0 0 -5250 -4500 -3750 -3000 - 2250 -1500 -750 0 750 West( -) /East( +) (750 Win) Casing OR Tubing OR Drilling Detail Well: C132 -468 10 314" 45.5# L -8U BTC =M Cas /n Date: 12/5/2008 Rig: Doyon 19 ConocoPhilh s p Alaska, lnc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 To + String or To of Flan e I. I RKB to Landing Ring 36.65 FMC 10 3/4" Casing Hanger 2.15 36.65 Jts 100 to 111 12 Jts 10 3/4 ", 45.5 #, L -80, BTC -M Casing 478.54 38.80 10 3/4" Tam Port Collar 2.98 517.34 As 3 to 99 97 As 110 3/4 ", 45.5 #, L -80, BTC -M Casing 3906.27 520.32 10 3/4" Hallibutron Super Seal Float Collar 1.21 4426.59 As 1 to 2 2 As 10 3/4 ", 45.5 #, L -80, BTC -M Casing 82.86 4427.80 10 3/4" Ray Oil Tools Float Shoe Silver Bullet 2.25 4510.66 4512.91 10 3/4" Casing shoe @ 4513' MD / 2387' TVD 4512.91 13 1/2" hole TD. 4525' MD /2390' TVD 4512.91 4512.91 4512.91 4512.91 RAN 62 BOWSPRING CENTRALIZERS - 4512.91 1 per 't on Jt #1 - #12 (stop ring on Jt #1 & 2 4512.91 Every other 't from jts # 14 thru # 96 4512.91 One each on 'ts.# 98,99, & 100 4512.91 Every other jt. f/ 102 to 108 & 109 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 4512.91 Remarks: Up Wt 170K Dn Wt 112K Block Wt 75K Supervisors: D. Mickey / J. Browning Cement Detail Report CD2 -468 String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/2/2008 00:00 Dement Details FF * Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/7/2008 15:30 12/7/2008 19:30 CD2 -468 Comment Cement 10 3/4" Csg as follows: Rig Pumped 50 bbls WBM w/ Nut Plug as Marker, 40 Bbls Biozan w/ Nut Plug, Switched to Dowell and pumped 5 bbls water. Pressure Tested Lines to 3,500 psi. Dropped Btm Plug and Pumped 50 bbls MudPush @ 10.5 ppg at 6 BPM & 482 Psi -Mixed & pumped 615 bbls Lead Slurry (ASL) @ 10.7 PPG @ 6.5 BPM @ 320 Psi ( *Observed Nut Plug Marker @ Shakers w/ 600 Bbls Lead Pumped then Pumped Down Surge Can) Pumped 57 Bbls of 15.8 PPG Tail Slurry (Class G w/ Additives) @ 4.5 BPM at 530 Psi. Dropped Top Plug w/ 20 bbls Water f/ Dowell. Switched Over to Rig Pumps & Displaced Cmt w/ 401 Bbls 10.0 ppg Water Based Mud. Displaced @ 6.5 BPM for First 390 bbls Then Slowed to 3.5 BPM @ 600 Psi for 11 Bbls, Bumped Plug w/ 1100 Psi (Pre Bump Pressure600 Psi ) Check float (held OK) CIP @ 1930 Hrs. Had Full Circulation Throughout Job w/ 300 bbls 10.7 PPG Cement Returns to Surface. Reciprocated Pipe While Circulating & Landed Casing at start of pumping tail slurry due to Loss of Down Weight- Full Returns Thorughout Cement Job. Cement Sta es Sta e # 1 4 ;, IN . Description jObjective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement I Cement Surface Casing 1 37.0 4,525.0 Yes 300.0 Yes Yes Q (start) (bbi /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 534.0 600.0 No 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Full Returns Throughout Job - 300 Bbls Lead Cement to Surface - Plugs Bumped and Held Cement Fiulds & ° . Fluid: Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 0.0 0.0 1 1 90.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Additives Additive Type Concentration Conc Unit label A . Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 0.0 0.0 1 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 1 37.0 3,880.0 755 G 615.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.57 20.50 10.70 Additives Additive Type Concentration Conc Unit label Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) class Volume Pumped (bbl) Tail Cement 3,880.0 4,525.0 280 G 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 12/312010 Daily Drilling Report ecurity Level: AK Development CD2 -468 Report Number: 6 1 6 0 FRig: DOYON 19 Report Date: 12/7/2008 7 7 7- 77777 W E Ty .:. NetwoWID # Tatat AFE +Sup 10239757 10,220,999 t00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 468 Development QANNIK 5.03 6.0 0.00 4,525.0 4,525.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,901.95 1 103,254.85 529,212.88 1 1,744,827.78 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) 7Projected Job End Date 12/2/2008 12/2/2008 28.24 28.79 - 0.55 1 12/30/2008 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 4,512.9ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE w/ AOGCC Insp. Jeff Jones as Witness N/D Surface Riser - N/U & Test BOPE - Drill 20' New Hole - Perform FIT t/ 18 PPG - Displace to LSND - Drill 9 7/8" Hole Last 24hr Summary Conitnue to Wash Down 10 3/4" Casing f/ 1799'- 4513' MD - Stopped to Circulate Hole Clean @ 2,402 - 2731' and 3,260' MD - Land Casing @ 4513' MD - Circ and Condition Mud for Cementing - Cement Casing w/ 10.7 PPG ASL Lead and 15.8 PPG Class G Tail Cement (300 Bbls ASL Lead Returned to Surface) - Conduct Casing Test t/ 3050 Psi f/ 30 Minutes (good) - R/D Cement Head and Casing Handling Tools - Remove Mouse Hole and N/D Surface Riser Lost 128 Bbls to Hole in Previous 24 Hours - Total Losses for Casing Job 325 Bbls General Remarks Weather Head Count No Accidents and No Spills - 17 / WC - 36 / Clear / Wind ESE @ 9 Mph 49.0 Supervisor Tdke Don Mickey, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Lo x� t. Stmt End Dur Time ttepFh Star! Depkh End Time Time (hrs) Phew', DR Code t' Aitivit bode P T X ,° Trbl Code trt Mass (tiKB� (ftlf$� €3peratidn N; 00:00 02:00 2.00 SURFAC CASING RNCS P 1,799.0 2,402.0 Cont. Running 10 3/4" 45.5# L -80 BTCM csg f/ 1799' to 2402' (60 jts total in hole) Washing casing down @ 3.5 bbls /min @ 400 psi - Hole taking fluid while pumping 02:00 02:45 0.75 SURFAC CASING CIRC P 2,402.0 2,402.0 Circ btms up @ 2402'- ICP 4 bbls /min @ 420 psi - FCP 5 bbls /min @ 460 psi Hole taking fluid while pumping 02:45 04:00 1.25 SURFAC CASING RNCS P 2,402.0 2,731.0 Cont. RIH w/ csg f/ 2402' to 2731'(69 jts total in hole) - washing casing down @ 4 bbls /min @ 400 psi w/ diminished returns Hole taking fluid while pumping 04:00 04:45 0.75 SURFAC CASING CIRC P 2,731.0 2,731.0 Circ btms up - ICP 4 bbls /min_@ 460 psi FCP 4 bbls @ 309 psi Hole taking fluid while pumping 04:45 06:45 2.00 SURFAC CASING RNCS P 2,731.0 3,260.0 Cont. RIH w/ csg f/ 2731' to 3260' (76jts total in hole) washing down casing @ 4 bbls /min @ 430 psi Hole taking fliud while pumping 06:45 07:30 0.75 SURFAC CASING CIRC P 3,260.0 3,260.0 Est. Circ & circ hole - ICP 4 bbls /min @ 430 psi - FCP 4 bbls /min @ 370 psi Hole taking fliud while pumping Latest BOP Test Data t}ate r. Comment r Page 1/3 Report Printed: 12/312010 M ecurity Level: AK Development Daily Drilling Report CD2 -468 Report Number: 6 4j 0 FRig: DOYON 19 Report Date: 12/7/2008 Time Lo = y Start E our lime € €7Wh start Ek p h Enc ,, :., Tme Time thrs Phase C�Cade Aat Ay::Cade P-T -x. TrbtCade TrblCYass. ©peration 07:30 12:00 4.50 SURFAC CASING RNCS P 3,260.0 4,513.0 Cont. RI w/ csg f/ 3260' to 4476' (111 jts total in hole - Made up Tam PC @ jt # 99 ) washing down casing @ 4 bbls /min @ 560 psi - MU hanger & landing jt. Land casing on FMC fluted hanger on landing ring w/ float shoe @ 4513'& float collar @ 4426'- Tam PC @ 517'- PU wt 170 SO wt 112 Hole taking fluid while pumping 12:00 12:30 0.50 SURFAC CASING OTHR P 4,513.0 4,513.0 LD fill up tool - Blow down TD - RU cement head & lines 12:30 15:15 2.75 SURFAC CEMENT CIRC P 4,513.0 4,513.0 Establish circ - Circ and condition hole & mud for cement job - ICP 2.2 bbls /min @ 420 psi- FCP 350 psi @ 6 BPM 15:15 15:30 0.25 SURFAC CEMENT SFTY P 4,513.0 4,513.0 PJSM on Surface Cement Job 15:30 19:30 4.00 SURFAC CEMENT DISP P 4,513.0 4,513.0 Cement 10 3/4" Csg as Follows: ig Pumped 50 bbls WBM w/ Nut Plug as Marker, 40 Bbls Biozan w/ Nut Plug, Switched to Dowell and Pumped 5 bbis Water. Pressure Tested Lines to 3,500 Psi. Dropped Btm Plug and Pumped 50 bbls Mud Push @ 10.5 ppg at 6 BPM & 482 Psi -Mixed & Pumped 615 bbls Lead Slurry (ASL) @ 10.7 PPG @ 6.5 BPM @ 320 Psi ('Observed Nut Plug Marker @ Shakers w/ 600 Bbls Lead Pumped then Pumped Down Surge Can) Pumped 57 Bbls of 15.8 PPG Tail Slurry (Class G w/ Additives) @ 4.5 BPM at 530 Psi. Dropped Top Plug w/ 20 bbls Water f/ Dowell. Switched Over to Rig Pumps & Displaced Cmt w/ 401 Bbls 10.0 ppg Water Based Mud. Displaced @ 6.5 BPM for First 390 bbls Then Slowed to 3.5 BPM @ 600 Psi for 11 Bbls, Bumped Plug w/ 1100 Psi (Pre Bump Pressure600 Psi ) Check float (held OK) CIP @ 1930 Hrs. Had Full Circulation Throughout Job w/ 300 bbls 10.7 PPG Cement Returns to Surface. Reciprocated Pipe While Circulating & Landed casing at start of pumping tail slurry due to Loss of Down Weight- Full Returns Throughout Cement Job. 19:30 20:15 0.75 SURFAC CASING DHEQ P 4,513.0 4,513.0 R/U and Perform Casing Test - Pumped 6.4 Bbls @ 8 SPM t/ Pressure Build of 3050 Psi - Held 3050 Psi f/ 30 Minutes 20:15 22:00 1.75 SURFAC CEMENT PULD P 4,513.0 4,525.0 PJSM R/D & UD Cement Equipment, 10 3/4" Elevators, Bales, Landing Joint and Mouse Hole - Clean 2" Demco Valves 22:00 00:00 2.00 SURFAC 1 WELCTL NUND P 4,525.0 4,525.0 PJSM - UD Surface Riser, N/D Starting Head, Service IBOP Page 2/3 Report Printed: 1213/2010 ecurity Level: AK Development Daily Drilling Report CD2 -468 Report Number: 6 Rig: DOYON 19 Report Date: 1217/2008 Mutt Check Data YP Cale Gel (1 Get (tom) Gel (30m}- hkTHP t Density Temp Solids, Carr, Type Depth (ftKB }. Oens'',(Iblgal) Uis (slat) Ptt Calc (cp) (Ibf /100ft') (tbU1 (lbfli00ft'} (IbfhlQOdt�} , MBT(Ibrobl} On 9min) pH Spud Mud 4,525.0 10.00 26.0 21.0 83.0 107.0 120.000 25.0 8.3 10.0 In` ctiari Fluid Fluid Source From Lease',(hbi }; , Destination Vendor Manifest Number p Nate Diesel CD2 -468 5.0 CD2 -467 Injectivity Test Water Based Mud CD2 -468 825.0 CD2 -467 Drilling Mud 'Wellbores Wellbore Name Wellbore API/UWI CD2 - 468 501032058700 Section Size (in) ActTop (ftKB) Act: Btm (ftKB) End Qata' COND1 18 37.0 114.0 SURFAC 131/2 114.0 4,525.0 12/212008 12/5/2008 INTRM1 97/8 4,525.0 10,632.0 12/9/2008 12/13/2008 PROD1 63/4 10,632.0 17,850.0 12/18/2008 12/26/2008 Casing Strin s ., lHE Stting�PD Ming Wt fl Casmg Description F(un Date 0 (Itisltt) String Grade Set Depth (ftKB °: _ Carr meat SURFACE 12/7/2008 103/4 45.50 L -80 4,512.9 Ran 111 Joints and 62 Centralizers - TAM Port Collar @ 517' MD Cerrtertt y Surface Casing Cement - Started 12/7/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD2 - 468 SURFACE, 4,512.9ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 37.0 4,525.0 4 534.0 Fluid class :: Amount (sacks) =_ V (bbl) DensWth /gate Yield (ft'Esac k Est Top fftKB) EstBtrn (ftKB) Pre Flush 90.0 10.00 0.0 0.0 Pre Flush 50.0 10.50 0.0 0.0 Lead Cement G 755 615.0 10.70 4.57 37.0 3,880.0 Tail Cement G 280 50.0 15.80 1.17 3,880.0 4,525.0 Pressure Test Data .... Item Tested Date ". Pres (psi) Faiietl Cotnmern SURFACE, 4,512.9ftKB 12/7/2008 3,050.0 No Pumped 6.4 BUS @ 8 SPM t/ Pressure Build of 3050 Psi - Held 3050 Psi f/ 30 Minutes Page 3/3 Report Printed: 121312010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 -468 Rig: Doyon 19 Date: 12/9/2008 Volume Input Volume /Stroke Pum Rate. Drilling Supervisor: Mickey /Browning Pump used: #1 Mud pump Strokes 0.1000 Bbls /Strk 8.0 Strk/min Type of Test: Other - See Comments 1 W Pumping down drillpipe. Casing Test Pressure I tegrity Test Hole Size: 13 1/2^ Casing Shoe Depth Hole Depth Pumping Shut -in Pum in Shut -in RKB -CHF: 36.6 Ft 4,513 Ft -MD 2,387 Ft -TVD 4,545 -MD 2,397 Ft -TVD Strks si Min si Strks si Min si Casino Size and Description: io s /4" 45.5 # /Ft L -80 BTC 6 260 0 3050 1 10 0 1020 Casing Test Pressure Inte a rilyTest 8 400 1 3050 2 40 0.25 1020 Mud Weight: 10.0 ppg Mud Weight: 9.8 ppg 1? 5 50 ' 2 3050 3 100 0.5 1000 Mud 10 min Gel: 107.0 Lb /100 Ft2 Mud 10 min Gel: 42.0 Lb /100 Ft2 12 600 3 3050 4 150 1 960 Test Pressure: 3,000 psi Rotating Weight: 140,000 Lbs 141 7001 4 3050 51 200 1.5 930 Rotating Weight: 125,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 16 780 5 3050 61 250 21 920 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 18 875 6 3050 7 320 2.5 91 Estimates for Test: 4.6 bbls Estimates for Test: 1018 si 1.6 bbls 20 950 7 3050 8 400 3 90 IV 22 1010 8 3050 9 460 3.5 900 EMW = Leak -off Pressure + Mud Weight 1000 +98 PIT 15 Second 24 1100 9 3050 10 520 4 900 0.052 x TVD 0.052 x Shut -in Pressure, psi 26 1225 10 3050 11 580 4.5 890 EMW at 4513 Ft -MD (2387 Ft -TVD) 17.9 1020 28 127' 15 3050 12 620 5 880 3500 Lost 0 psi during test, held 30 1350.: 20 3050 13 680 5.5 880 100% of test pressure. 32 1400' 25 3050 14 720 6 880 3000 34 I 30 3050 15 760 6.5 880 777 T6 1650 1'6! 800 7 880 38 1750 7777 840 7.5 880 2500 77f 1820';$ 880 81 875 w 42 1950' 19 900 8.5 875 IX 2000 44 2550 20' 940 9 875 U) 46 25 21 970 9.5 870 21: N Ar 48 7 M5 22 1000 10 860 a 1500 1... 2300' 23 1020 52 2450 24 1000 t umN,, 2550 25 66 26 500 58 2750 27 60 ' 2875 28 62' 2950 29 ° 641 3050 30 0 1 2 3 4 5 6 7 0 5 10 15 20 25 30 - Barrels Shut-in time, Minutes Volume Volume Volume Volume �d'CASING TEST --&—LEAK -OFF TEST O PIT Point Pump Bled Back Pum ed Bled Back 6.4 Bb s Bbls 3.0 Bb Is Bbls Comments: Tested 10 3/4" csg after bumping plug to 3000 psi for 30 mins. i i CD2 -468 7.625" Intermediate Casing Well: CD2 -468 7 518" 29.7 PPf L -80 BTC -M Date: 12/15/2008 ConocoPhdlips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 .......... ................. ........................ ............................ .............. ......... ........................ ............................ .............. ......... ........... ................. ........................ ............................ .............. .......... ............................ .............. ......... ........... ................. ........................ .................. . ......... .............. ......... ........... ................. ........................ ............................ To of Strip or To of Flange .............. y .. .... ...... Do on 19 RKB to Lower lock down 34.40 FMC Gen V Hanger 3.30 34.40 As 3 to 247 245 Jts 1 7 5/8" 29.7# L -80 BTCM Csg 10494.01 37.70 Halliburton Float Collar 1.03 10531.71 Jts 1 to 2 2 Jts 7 5/8" 29.7# L -80 BTCM Csg 85.351 10532.74 Silver Bullet Float Shoe 2.10 10618.09 10620.19 10620.19 10620.19 10 3/4" Shoe @ 4,513' MD/2,387' TVD 10620.19 10620.19 10620.19 10620.19 9 7/8" Hole TD @ 10,632' MD / 4,077' TVD 10620.19 7 5/8" Shoe @ 10,620' MD / 4,076' TVD 10620.19 10620.19 Total Centralizers - 60 Tandem Rise & 53 straight blade 10620.19 30 - 7 5/8" Stop Rings on middle of 't. #'s 1 -30 10620.19 Tandem Rise centralizer two per 't on 'ts # 1 -30 10620.19 Straight blade centralizer on 'ts # 143, 144, & 145 Across 10 3/4" Shoe 10620.19 Straight blade centralizer one per 't on every other joint f/ # 147 to # 245 10620.19 10620.19 10620.19 10620.19 10620.19 260 joints in shed - 247 total 'ts. to run 10620.19 Last 13 jts. Stay out 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 10620.19 Remarks: Up Wt 255 K Dn Wt 128 K Block Wt 75 K Supervisors: David Burley/ Jeff Browning Cement Detail Report CD2 -468 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 12/2/2008 00:00 ;... :. Cement details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/16/200818:3 0 12/16/2008 20:45 CD2 -468 Comment Cemented casing as follows, pumped 3 bbls CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbls of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbls (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 464 bbls of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out job with full returns. Checked floats and held. Calc TOC @ 8,954' MD/3,705' TVD. Cefnent Stages Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Tail Cement 8,954.0 10,620.0 No Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 5 730.0 1,200.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented casing as follows, pumped 3 bbls CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbls of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbls (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 464 bbls of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out job with full returns. Checked floats and held. Calc TOC @ 8,954' MD/3,705' TVD. Dement Fluids & Additives $ ; Fluid r .:. Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1 8 ,954.0 10,620.0 463 G 96.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant - D065 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) S002 0.8 %BWOC I I I Page 1/1 Report Printed: 12/3/2010 S ecurity Level: AK Development Daily Drilling Report CD2 -468 Report Number: 15 Rig: DOYON 19 Report Date: 12116/2008 AFE Type AtetvrorkflD # Tatal AF±aup 10239757 10,220,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 468 Development QANNIK 14.03 15.0 0.00 10,632.0 10,632.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,572.19 1 335,586.95 633,403.19 1 3,939,208.88 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/2/2008 12/2/2008 28.24 30.44 - 2.20 1/1/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 10,620.2ftKB Ops and Depth @ Morning Report 24hr Forecast LID 5" DP out of the derrick Fin LD 5" DP, MU Cleanout BHA & single in 4" DP, Drill out shoe track & 20' new hole, FIT, POOH & test BOPE Last 24hr Summary Phase 3 condition lifted @ 04:30 Hrs. Cont. to RIH with 7 5/8" csg & landed same @ 10,620'. Circ & cond mud then cemented csg with full returns, CIP @ 20:45 hrs with est. TOC @ 8,954'. RU & tested 7 5/8" csg to 3,500 psi for 30 min. RD cmt head & landing jt. Installed packoff & tested same to 5,000 psi. General Remarks Weather Head Count No Accidents and No Spills 6 Deg, WC -11, Partly Cloudy, Wind E@ 11 50.0 mph 57T SUpervrsrar :. Tale t :: T .: Dave Burley, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Lo', t Start I End I Our Time Depth Start: • Depth End Tirne Time (hrs) Phase Op Cade Activity Cade 1� T x '' Trht Cade Trhl Class. (ftKS� [EtItB)',� ry operatirns 00:00 04:30 4.50 INTRM1 CASING WOW T Waiting Wait on 4,062.0 4,062.0 Wait On Weather - Phase 3, circ hole at Weather 4 bpm at 280 psi. NOTE: Phase 3 was lifted at 04:30 hrs. 04:30 08:00 3.50 INTRM1 CASING RNCS P 4,062.0 6,635.0 Cont. RIH w/ 7 5/8" csg f/ 4,062 to 6,635' (155 jts total) 08:00 08:45 0.75 INTRM1 CASING CIRC P 6,635.0 6,635.0 Circ btms up at 6,635' staging pump rate up to 7 bpm at 640 psi, st wt up 175K, do wt 120K 08:45 11:30 2.75 INTRM1 CASING RNCS P 6,635.0 8,823.0 Cont. RIH from 6,635' to 8,823'. (206 jts total) 11:30 13:00 1.50 INTRM1 CASING CIRC P 8,823.0 8,823.0 Circ btms up staging pump rate up to 6.5 bpm at 680 psi and hole appeared to have taken approx. 20 bbls, slowed rate to 5 bpm at 450 psi with no add.. losses. St wt up 215K, do wt 125K 13:00 15:30 2.50 INTRM1 CASING RNCS P 8,823.0 10,620.0 Cont. RIH with 7 5/8" csg from 8,823' to 10,582', MU FMC hanger and landed csg at 10,620' and fit collar at 10,532' with no problems. PU wt 255K, SO wt 128K. Ran a total of 247 jts of 7 5/8 ", 29.7 #, L -80, BTCM csg, total including float equip and hanger 10,585.79'. Ran 60 Tandem rise cent, 30 stop rings and 53 straight blade cent. per well plan. 15:30 16:00 0.50 INTRM1 CEMENT RURD P 10,620.0 10,620.0 RD Franks fill up tool and MU Dowell cement head. 16:00 18:30 2.50 INTRM1 CEMENT CIRC P 10,620.0 10,620.0 Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm at 320 psi to 7 bpm at 600 psi, cond. mud to 10.0 ppg. in and out with 15 YP. St wt up 235K, do wt 125K. Held PJSM on - cement job while circ hole. Latest BOP Test Data -yz ,..Date Camrtterit' - .. 12/8/2008 Test BOPE - Annular to 250 & 2500 psi - Pipe rams - blind rams - choke manifold valves - kill & choke line valves - TD IBOP's - Page 112 Report Printed: 12/3/2010 IIII Security Level: AK Development -, = Daily Drilling Report CD2 -468 Report Number: 15 Rig: DOYON 19 Report Date: 12/16/2008 Time Lo Start End I Our Time :. Depth Start Depth Erin Time Time (firs) Phase t7p Cade ,, Activity Cade P T x Trbl Gade TEfit GEass '$ v ftta fflKS} operatiais 18:30 21:00 2.50 INTRM1 CEMENT DISP P 10,620.0 10,620.0 Cemented casing as follows, pumped 3 bbls CW 100, pressure tested lines to 4,000 psi, fin. pumping 27 bbls (30 total) of CW 100 at 8.3 ppg, ave 4.2 bpm at 500 psi., Dropped btm plug then pumped 30 bbls of MudPush at 12.5 ppg, ave. 2.5 bpm and 350 psi.. Mixed and pumped 96 bbls (463 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 4.8 bpm, ICP at 775 psi, FCP 540 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 464 bbls of 10.0 ppg LSND mud, ave. 7 bpm, ICP 350 psi, max press. 730 psi, with 13 bbls left, slowed to 3.5 bpm at 480 psi. Bumped plug to 1,200 psi. CIP @ 20:45 hrs. Reciprocated csg thru out job with full returns. Checked floats and held. Calc TOC @ 8,954' MD/3,705' TVD. 21:00 22:00 1.00 INTRM1 CASING DHEQ P 10,620.0 10,620.0 RU and tested casing to 3,500 psi for 30 min. 22:00 23:00 1.00 INTRM1 CASING RU P 10,620.0 10,620.0 RD cmt head, landing jt and long bales. 23:00 00:00 1.00 INTRM1 CASING OTHR P 10,620.0 10,620.0 Pulled thin walled wear bushing and installed 7 5/8" packoff, tested same to 5,000 psi for 10 min. Mud Check Data.:. :� YPCale GeLftOsy Gel(lom) ost {30m} ttTHPiIt OansityTamp Salid�,Carc. Type Depth (ftKB) Dens lb/gal) v s (sfgt) PVCalc (cp ) ', (W11100ft') ;: fI4fl100fl'} (lhfllooft'T , (01100tt MBT, (tbml) (mlk3fltnin) pH I ( °la} LSND 10,635.0 10.00 41 13.0 15.0 7.0 9.0 11.000 0.0 0.0 0.0 Injection Fluid Fluid Sauce From Lease (bbl) Restinahan' Vendor w Van lest Number ?:. x' Nate 0.0 Wellbore Name Wellbore API /UWI CD2 -468 501032058700 Section size (in) Act;Top (RKB) Act Btm (ttKB) 1 Start Date ! End,Date- COND1 18 37.0 114.0 SURFAC 131/2 114.0 4,525.0 12/2/2008 12/5/2008 INTRM1 97/8 4,525.0 10,632.0 12/9/2008 12/13/2008 PROD1 63/4 10,632.0 17,850.0 12/18/2008 12/26/2008 Cement t :. Intermediate Casing Cement - Started @ 12/16/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD2 - 468 I INTERMEDIATE, 10,620.2ftKB Stg No, Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 8,954.0 10,620.0 4 730.0 Fluid Class Amount(sacks) U (bbl) ( (Vgal) Yield ("Sack) EstTap {RKB} Est Bt ftKB) Tail Cement IG 1 4631 96.01 15.801 1.171 8,954.01 10,620.0 Preigid Test Data Item Tested Date Prey (psi) Failed?__ INTERMEDIATE, 10,620.2ftK13 12/16/2008 3,500.0 No Tested 7 5/8" csg to 3,500 psi for 30 min. Page 2/2 Report Printed: 12/312010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 -468 Rig: Doyon 19 Date: 12117f2008 Volume input Pump Rate: Drilling Supervisor: - D a vid Burley f Peter V�riistan Purrwp used: Cement Unit Barrels Bbls /Strk 75i Bbl /min Type of Test Annulus Leak Off Test for Disposal Adequacy [ ' : W � Pumping down annulus. 1W Casin g Test Pressure I egrity Test Hole Size: 9 - 7/$" Casing Shoe Depth Hole Depth Pumping Shut -in Pum pinq Shut -in RKB-CHF:j 33.01R I 4513.(1 Ft -MD 2387.0 Ft -TVD X3954.0 Ft -MD 13705.01 Ft -TVD Bbls si Min psi Bbls psi Min psi Casing Size and Description: 10 -3 /4" 45.5 # /Ft L -80 BTC 0 0 96 0.00 369 Chan es for Annular Adeauacy Test Pressure Inte ri Test 1 02 212 0.15 349 Enter outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 Q.4 222 0.30 338 Casing description references outer casing string. Inner casing OD: 7.6 In. 3 0.6 243 1.00 333 Hole Size is that drilled below outer casing. 4 0.8 263 1.50 328 Use estimated TOC for Hole Depth. 5 1 283 2.00 318 Enter inner casing OD at right. Desired PIT EMW: 15.5 ppg 6 1.2 313 2.50 31 Estimates for Test: 683 psi 0.9 bbis 7 1.4 333 3.00 31 • 8 1.6 354 3.50 313 EMW = Leak -off Pressure +Mud Weight = 485 + 10 PIT 15 Second 9 1.03 369 4.00 308 0.052 x TVD 0.052 x 2387 Shut -in Pressure psi 10 2 394 4.50 308 EMW at 4513 Ft -MD (2387 Ft -TVD) = 3.9 349 15 2.2 410 5.00 303 20 2.4 424 5.50 303 25 2.6 444 6.00 30 30 2.8 460 6.50 298 100 0 3 470 7.00 298 3.2 485 7.50 298 3.4 490 8.001 293 750- 16 495 8.501 293 18 505 9.00 293 4 515 9.50 293 4.5 495 10.00 293 w 500 `/YO 5 439 a '(� I Z P� 5.5 444 6 444 250 3 439 7 434 7.5 429 0 8 424 0 1 2 3 4 5 6 7 8 9 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume - TEST 0-LEAK -OFF TEST O PIT Point Pumped Bled Back Pump Bled Back 0.0 Bbls Bbls 8.0 Bbls Bbls Comments: 10 3/4" casing shoe - LOT to 17.9 ppg Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: DD2 -463 Rig: D oyon 19 Date: 11/2812010 Volume Input P mp Rate: Drilling Supervisor: Don Mickey Pump used: Other - see Corn Barrels 750131 Bbls /strk 0.75 Bbl /min Type of Test Annulus Leak Off Test for Disposal Adequacy Pumping down annulus. Casin Test Pressure l tea ritv Test Hole Size: 9 -7/8" 1 v Casing Shoe Depth I Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 34.21 Ft I 4513.0 Ft -MD 2387.OlFt-TVDI 1 10652.0 Ft -MD 4079.0 Ft -TVD Bbls psi Min p si Bbls psi Min psi Casing Size and Description: 7 -5/8° 29.7 # /Ft L -80 BTC -MOD 0 0 0 0.00 650 Chan es for Annular Adequacy Test Pressure Inte aritvTest 1 0.5 100 0.25 600 Enter outer casing shoe test results in comments Mud Weight: 6.6 ppg 2 1 400 0.50 810 Casing description references outer casing string. Inner casing OD: 7.6 In. 3 1.5 900 1.00 800 Hole Size is that drilled below outer casing. 4 2 1070 1.501 790 Use estimated TOC for Hole Depth. 5 3 1050 2.00 790 Enter inner casing OD at right. Desired PIT EMW: 18.0 ppg 6 4 1000 2.50 79 Estimates for Test: 1415 psi 1.1 bbls 7 5 1 000 3.00 79 8 6 1150 3.50 790 EMW = Leak -off Pressure + Mud Weight = 900 + 6.6 PIT 15 Second 9 7 1125 4.00 790 0.052 x TVD 0.052 x 2387 Shut -in Pressure psi 10 8 1125 4.50 790 EMW at 4513 Ft -MD 2387 Ft -TVD = 13.9 800 15 9 1125 5.00 790 1500 20 10 1125 5.50 25 11 1300 6.00 ` 30 12 1300 6.50 13 1300 7.00 14 1300 7.50 15 1300 8 00 1000 W 8.50 M 9 00 9.50 w ,(&" 10 00 .. a 500 0 0 2 4 6 8 10 12 14 16 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume �1hCASING TEST M LEAK -OFF TEST O PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls "' Bbls 15.0 Bbls 17777pbls Comments: Injectivity Test w/ Little red Summary Tom .and Sha�iraan; You have requested tQ; c� spdse of 'r�ew- product." c�:ean u fluids :fzo#n the' routine .. .. • _ ,. ., , : _. ....:. ...: mixing of: :mud and "cemen� a't - Al pito: as well as the = clean; up fluids aresul.tiing from: , cleanang out the tan;�s. at the mud plat in- preparatiozi toz wing, :oil base mud:: The: Gonimssiori' had prev� ous�y ar�proved da sposzng of the rieyt product" dear►` up ... Eluxas vxa arnulai disposal .at cD.1.. pari; to• the - edlogica3. sett na :aG alpine,, Class 1-. and :.Class 2 d sposal,:opL ons limited Ph° lixps' :gxadecessor-,.• AZCb dad :esLabshed the :lmztata+�n of posal options Lo. Lhe Eomm� ssion's sate action arch am =31ar disposal eras approved as the:: ... . •. .. .. ., ,. _ ... :. ., � . oxaerJcal- and dnVironme_Tita1 alternative: 3r! .these requests Lhe ;waste Clu ck a:e:.no = •di zferent tba previously approved are the result o the ongog development actzvit es at r�lsuie The CoYnmsssaoners have autb ---zed me to send you tlz_s message $y copy at .email,,, Phillips is.; A to dispose .of cl.ean::up flauds.:as: c3escriY3ec1 'in Yom': Please: call Q2. any ,ques Uons 'P9in Maunder. P�;: >Sr': Petro7.'euni,;Exigxneer r=1T P`:'E11V cbord. W r4te >:?�eaY;2Ir, $faiirder, > =noted in 'rlie aLtsbbed email-, . Tom 1Kanson: prevkQur.iy requested: > autnor� zatiot to dj spose of uevr product clea-i uo fields such as Cement > rirsate,, and - mud and prine pi rLZSes Lrom mix�ir oi�erations via annular > 1n,ecCiop �r permattea =R�e] is at the -,1`oine CD2 arzll 51te as • noted below: AQGCC apFroved such::clisposal aE _tie'(CD 1 �7xi11 Sate zirx X399; based pn kne:. y. integral rela.t3orisYiip the inud'_m5xanq. Lae�lity and the •:on.si- te drillIn > Phi112ps would liktr to contanuang pursuing this reque t Significant clean:: > out a tanks at the mucl mixing facility must gccur an prepgzration to the > teapoxary use; of oil based mud od ts pruc at ?alpine =n Jibe comxm months � :slie soL�,;ariniia�.a : disposal •as.•an option :for tank r�.nse fluids and: > siinilar.wastss would gxeatiy faczlxta.e;thks process; (Typacally, rQUtzne: rinses a`re beiiefacially reused however, Er ere is a',concexn about the > pdtentsa� quantity o£: 1uld that cquTi.`}e •generated,u+ ink tlu; large scale:: > clean ocess : ) , > Tanks at the ,mud mixing= facs:l•ty may coma. ei t}aer ne =,:::and used mud •. products 'ihoug ranse's, ,in concacC ;with : used praducts be 2n�ectecl in > the pernlill2d class TT disnasal V1e11 (CD1 . ranses of nw products would �: pcSenLlally be r4�,'tQd to. the cla d� sposal k1e31 (tn� 02 } , where hare: > a . 3T CU managing solads contend The class I well is a cry tical > lifeline for facal'ty infrastructure: b6.= the disposal J;ocatacn for all doinestac ef£lueat, and it i S :a° pr3 ority to- prevent; 'compro!r xs.e to.: this > d'sposaY facsllCy: Annular: disposal _dresents a pre£esredvaste management: > ;aTternat Ue : in tii s,:;case- > fitak you 07 ve-y much for your cos�zdrat3oil o this xegtxest Please dd nat > k�esitate La contact me or my alternate via email or phony ;at t�) 67A 4200 if you' have questions or need ;addzt ova: iri .6r.mation. ' "$hanr�n Donne33y > :13pine AV- it C�ora4iriaL'ar > - Forc+raxcled by.. ALP �v CnQxdIPPCO an :11'!. �2 }0•T �:2 SU .PM:� = = = -� MP •Eay.'Coorat > z ., °P 3 ` T0. L.o::E riauricler�aciiniri..s:: ..:a?c.us cc :.. . > SuU�ect Request to In3ectr�Cemezat .R�,nsace at:.. Dear ICI= Maunder, T.h0ectzon of cement r�tsate and clean un': flwds £rom > "d"" and, brine, nuXnc�., operatons::a:t..tne: `Alpue mud plant facility into approved disposal >. s�pexations tics granted . by phe; 'Ai�as7ca Oa 1:And Gas Corisertrai ion Comt�i3ssiOii > (.OGCC. }. =n Elie Fiarch 17,. 1999 letter from AOGC C Lo Doug Chester' of P,l�CO Al�s}ca, Inc r rarnt phillzps Alaska, Ync tP }_ The ; approval vtae g anted tq. specxxcally fpr Alpine Drx�7 Sites eDl and aatnoriiea volumes up to,, >: 3S 000'•barreTs� through the annulGr sn�(ce',' rcquest, that this approval be ex`ended to dr =llittg 4 opexat�.orts at �1p�.n�.; > �r =11 Site C: 2 Gemeht itu xanct operatzozs zox settzzig stxi�face conductors > will be taking place at 'the Grznd and Inject facility which 1s currently > attachea the dr�llitzg rig at CD2 Upon comalacxon of the ceinenkzzig in, 5 of the `conductors; :the 11ne and `m� x-ing tank vr3 ]3,., "ave to..xie :r rued' and'::tlie: > rina :te• dispesed vx" PA2 request ,appova to zn j ect t7aas zxi sa>re, and._ > otherlean tip -troi; the.: mud end brave mixing opaexations, :intG . an3uzl. > sgacc ..o:f approued �i�elis located at 'Dr =11 .Sate CD2 > I:f ybU. have anyuesta on p� base cgntact -me Gt 6 ?0 4200: Ton::lranson A]p � e.:;Field Environmental Co plaance• �totn�tauRdervcf Details for CD2 -76 CD2 -176 Surface Casing Well: D2m176- F= _ ,_af Date: 10 12i2009 ConocoPhllips Rig: Doyon 19 Alaska; Inc; Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Tod �r:r�g: or "l°i EI. Do on 19 RKB to landing Ring 36.50 FMC Gen V 10 3/4" Casing Hanger 2.18 36.50 Jts 3 to 82 80 Jts 10 -3/4" 45.5 ppf L -80, BTC -m casing 3268.31 38.68 Halliburton "Sure Seal II" Float Collar 1.20 3306.99 Jts 1 to 2 2 Jts 10 -3/4" 45.5 ppf L -80 BTC -m casing 72.13 3308.19 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 3380.32 3382.62 3382.62 3382.62 3382.62 3382.62 13 1/2" Hole to 3393' MD / 2391 TVD 3382.62 10 3/4" Casing Shoe @ 3382' MD / 2386 TVD 3382.62 3382.62 3382.62 90 Joints in Pipe Shed - Ran 82 / Last 8 jts. out 3382.62 3382.62 1 Bowspiing Centralizer per Joint 1 -12, then Every Other Joint 14 -80 3382.62 Total 47 Bows rin s - Two Stop Collars 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 Remarks: Average MU torque = 8600 Up Wt 202 K Drifted pipe w/ plastic rabbit 9.88" OD Dn Wt. 135 K Used Run N Seal dope. Block Wt 80 K Supervisors: David Burley / Granville Rizek Cement Detail Report CD2 -76 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/18/2009 08:00 Cemenfi Details.... -` Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/22/2009 12:15 10/22/2009 17:00 CD2 -76 Comment Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. Bottom seal on cement head would not stay in seal groove - required several attemps to install head. Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm 1350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Cemented 10 3/4" casing as follows: Rig pumped 99 bbls of 10.0 ppg mud with nut plug marker followed with 33 bbis of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbis of FW, tested lines to 2500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.2 bpm at 180 psi. Mixed & pumped 428 bbls (526 sxs) 10.7 ppg lead slurry at 4.57 yield (ASL) ave. 7.2 bpm at 266 to 136 psi. Observed nut plug marker at shakers w/ 410 bbis lead slurry pumped (pumped down surge can, 428 bbls total) Switched to tail slurry and pumped 57.6 bbls (276 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave. 5.5 bpm at 160 psi. Dropped top plug w/ 20 bbls fresh water f/ Dowell. Switched to rig pumps & displaced cement w/ 297 bbis 10.0 ppg mud ave. 7.8 bpm, ICP 230, FCP 700 psi, slowed pump to 4 bpm at 520 psi (for the last 7 bbis of displacement) Bumped plug to 1,050 psi. Checked floats OK, CIP @ 1457 hours. Had full circulation throughout job w/ 139 bbis of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger. Blow down cement line Rig down cement head and line - Rd casing elevators - LD landing joint - Change out casing bails with Drill pipe bails Cement Sta es' Stage 0: P Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Cement Surface casing 1 36.5 3,393.0 No 1 139.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? I Stroke (ft) Rotated? I Pipe RPM (rpm) 7 4 7 520.0 1,050.0 Yes 11.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. Bottom seal on cement head would not stay in seal groove - required several attemps to install head. Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Cemented 10 3/4" casing as follows: Rig pumped 99 bbis of 10.0 ppg mud with nut plug marker followed with 33 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbis of FW, tested lines to 2500 psi. Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.2 bpm at 180 psi. Mixed & pumped 428 bbis (526 sxs) 10.7 ppg lead slurry at 4.57 yield (ASL) ave. 7.2 bpm at 266 to 136 psi. Observed nut plug marker at shakers w/ 410 bbls lead slurry pumped (pumped down surge can, 428 bbis total) Switched to tail slurry and pumped 57.6 bbis (276 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave. 5.5 bpm at 160 psi. Dropped top plug w/ 20 bbis fresh water f/ Dowell. Switched to rig pumps & displaced cement w/ 297 bbis 10.0 ppg mud ave. 7.8 bpm, ICP 230, FCP 700 psi, slowed pump to 4 bpm at 520 psi (for the last 7 bbls of displacement) Bumped plug to 1,050 psi. Checked floats OK, CIP @ 1457 hours. Had full circulation throughout job w/ 139 bbis of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger. Blow down cement line - Rig down cement head and line - Rd casing elevators - LD landing joint - Change out casing bails with Drill pipe bails Cement. F(uids &Additives Fluidiff . . Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud w/ nut plug 99.0 marker Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water w/ 33.0 nut plug marker Yield (ft' /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.60 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 12/3/2010 a Cement Detail Report CD2 -76 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/1812009 08:00 Cement Ftuds & Additives Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid ' y Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead 36.5 2,883.0 526 ASL 428.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.79 23.89 10.70 Additives Additive Type Concentration Conc Unit label D065 0.5 %BWOC Additive Type Concentration Conc Unit label S001 Accelerator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.6 %BWOC Additive Type Concentration Conc Unit label D079 Extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 Extender 50.0 %BWOC Additive Type Concentration Conc Unit label D044 Freeze Suppressent 9.0 %BWOW Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail 2,883.0 3,393.0 276 G w/ add's 57.6 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label D907 0.188 %BWOC Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 212 Report Printed: 12/3/2010 M ecurity Level: AK Development Daily Drilling Report CD2 -76 * * , Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 SEE Type NetworkllD # Total AFE +Sup ., 10265149 11,154, 000.00 Wellbore Well Type Field Name DFS (days) IDOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 -76 Development ALPINE 3.88 1 5.0 0.00 3,393.0 3,393.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 17, 994.59 70,490.71 849,208.59 1,663,099.11 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10118/2009 10/25/2009 34.99 34.01 0.98 11/21/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,382.6ftKB Ops and Depth @ Morning Report 24hr Forecast Picking up/ make up/ stand back 5" drill pipe. Continue to PU /Make up/ standback 5" drill pipe, test BOPE, finish PU 5" drill pipe, MU BHA #2, single in the hole to tag FC @ 3307', test casing. Last 24hr Summary Run 10 -3/4" 45.5 ppf L -80 BTC -m casing, tagged an obstruction @ 909'. Engage Frank's fillup tool and circulate jt # 23 and #24 down to 980'. Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 1835' Qt # 45), circulate 140 bbls (bottom's up +), continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3340' at #82). Make up FMC hanger and landing joint, land casing @ 3382', rig down Frank's fillup tool, rig up Dowell cementing head, circulate and condition mud and hole for cement. Lower YP f/ 70 to 19. Hold PJSM. Cement casing w/ Dowell Schlumberger, full returns, 139 bbls 10.7 ppg ASL lead cement to surface, bumped plug to 1050 psi, floats held, CIP @ 1457 hrs.- see time breakdown 12:15hrs to 1500 hrs. Rig down cement equipment, nipple down riser, nipple up FMC Alpine II wellhead, verify alignment, test metal to metal seal to 1000 psi f/ 10 minutes. Nipple up BOPE equipment. Pre job safety meeting on picking up 5" drill pipe and standing back in the derrick. Pick up 72 jts of 5" drill pipe /stand back in the derrick, lubricate rig, continue to pickup 9 more joints of drill pipe. General Remarks Weather Head Count No Spills - No Accidents 27 Deg, WC 14, Wind E @ 16 Mph, vis 10 46.0 mile Supervisor Tdfe. Dave Burley, y Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Lo Start End t)Ur =, ' Time a Depth Start Depth End' Time Timex . ,(trrsj Phase k7p Cade `_ AcflvityCiiiie P T x Tetrl Gtsde TrbtG @ass. (ftKe ) f8 s ,. ' s° Opeiat 00:00 01:00 1.00 SURFAC CASING RNCS P 0.0 106.0 Run 10 -3/4" 45.5 ppf L -80 BTC -m casing: Install bow spring on stop 8' above the shoe and on the box of jt # 1, baker lock joint #2, install centralizer on stop 10' below box, bakerlock/ makeup float collar joint w/ centralizer on box of joint #3, bakerlock pin of joint #4. Stab Frank's fillup tool into box of jt #4, then circulate 40 bbls of mud to clear air and check float equipment while still in the conductor. 01:00 02:45 1.75 SURFAC CASING RNCS P 106.0 909.0 Continue to run casing observing makeup mark. Torque casing to 8600 It Ibs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Apply Bow spring centralizers on every box to jt #12, then every other box to jt # 80. Ran casing to jt # 23 plus 10' of jt # 24 in the hole, tagged an obstruction (Taking 20k weight) @ 909'. 02:45 03:30 0.75 SURFAC CASING CIRC P 909.0 980.0 Engage Frank's fillup tool and circulate jt # 23 and #24 down. Pumping 5 bpm w/ 250 psi and 29% flow. PU wt 120k, SO wt 105k. Circulated 180 bbls (3 BU). Latest BOP Test Data Date Ciamment Page .115 Report Printed: 12/312010 d Imecurity Level: AK Development Daily Drilling Report CD2 -76 Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 Time Lo r Stale End our Time E3epth Stan; y �keptkr Er�d Time Time (ors) Phase Op Code Rctivity Code P -T -iG Trbl Code TrW Class. (ftKB RIEI ': 'bp�rdtixzn 03:30 05:00 1.50 SURFAC CASING RNCS P 980.0 1,835.0 Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Run from jt #25 tojt #45. 05:00 05:30 0.50 SURFAC CASING CIRC P 1,835.0 1,840.0 Engage Frank's fillup tool and circulate jt # 45. Stage pumps up from 2 bpm w/ 270 psi and 17% flow out to 6 bpm w/ 380 psi and 31 % flow out. PU wt 141 k, SO wt 120k. Circulated 140 bbls ( BU plus). After circulating PU 140k, SO 130k. 05:30 07:45 2.25 SURFAC CASING RNCS P 1,840.0 3,340.0 Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer. Run from jt # 46 to jt # 82. 07:45 08:00 0.25 SURFAC CASING RNCS P 3,340.0 3,382.6 Make up FMC hanger w/ landing joint. Run in the hole and land on the hanger. PU wt 202, SO wt 135k. 08:00 09:30 1.50 SURFAC CEMENT RURD P 3,382.6 3,382.6 Rig down Franks' fillup tool. Rig up Dowell/Schlumberger cementing head. Bottom seal on cement head would not stay in seal groove - required several attemps to install head. 09:30 12:15 2.75 SURFAC CEMENT CIRC P 3,382.6 3,382.0 Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Page 2/5 Report Printed: 12/3/2010 M ecurity Level: AK Development Daily Drilling Report CD2 -76 Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 S #art End Our Time Depth Start Depth End Time Time {hrs) Phase. O#z`Code Ae #iveyCade #' F Trbl Cade TrbtEfass. fftKB) (BKB7 OperaBar w,. 12:15 15:00 2.75 SURFAC CEMENT CMNT P 3,382.0 3,382.0 Cemented 10 3/4" casing as follows: Rig pumped 99 bbls of 10.0 ppg mud with nut plug marker followed with 33 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 2500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.2 bpm at 180 psi. Mixed & pumped 428 bbls (526 sxs) 10.7 ppg lead slurry at 4.57 yield (ASL) ave. 7.2 bpm at 266 to 136 psi. Observed nut plug marker at shakers w/ 410 bbls lead slurry pumped (pumped down surge can, 428 bbls total) Switched to tail slurry and pumped 57.6 bbls (276 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave. 5.5 bpm at 160 psi. Dropped top plug w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 297 bbls 10.0 ppg mud ave. 7.8 bpm, ICP 230, FCP 700 psi, slowed pump to 4 bpm at 520 psi (for the last 7 bbls of displacement) Bumped plug to 1,050 psi. Checked floats OK, CIP @ 1457 hours. Had full circulation throughout job w/ 139 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger. 15:00 16:30 1.50 SURFAC CEMENT CMNT P 3,382.0 0.0 Blow down cement line - Rig down cement head and line - Rd casing elevators - LD landing joint - Change out casing bails with Drill pipe bails 16:30 18:00 1.50 SURFAC DRILL NUND P 0.0 0.0 Nipple down riser, remove FMC slip lock casing head 18:00 19:15 1.25 SURFAC DRILL NUND P 0.0 0.0 Nipple up FMC Alpine Gen II wellhead. Alignment verified by Rig Supervisor Granville Rizek and FMC rep Rob Wells. Test metal to metal seal to 1000 psi for 10 min. Witness of test by Rig supervisor Granville Rizek and FMC rep Rob Wells. 19:15 20:30 1.25 SURFAC DRILL NUND P 0.0 0.0 Nipple up BOPE stack. Tighten clamp on 1" 5M wellhead. Attatch drain lines. 20:30 20:45 0.25 SURFAC DRILL SFTY P 0.0 Pre job safety meeting prior to rigging up to pick up " drill pipe. 20:45 21:00 0.25 SURFAC DRILL RURD P 0.0 0.0 Rig up to pick up 5" drill pipe from the pipe shed and stand back in the derrick via the mouse hole. 21:00 21:15 0.25 SURFAC DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up 5' drill pipe. Page 3/5 Report Printed: 12/3/2010 ecurity Level: AK Development Daily Drilling Report w CD2 -76 Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 Time Lo Start End our Time Depth Start Depth End TimB" ,Time (hrs} Phase Op Code Activity Cade P -T-X Trbl Gade'. Trbl Class. ORS) (ftKBk .' `'V Operation 21:15 23:00 1.75 SURFAC DRILL PULD P 0.0 0.0 Pickup and rabbit 5' "5' and "G drill pipe to 2.85'. Stand back in the derrick. A total of 72 jts picked up. 23:00 23:30 0.50 SURFAC DRILL SVRG P 0.0 0.0 Service rig. 23:30 00:00 0.50 SURFAC DRILL PULD P 0.0 0.0 Continue to pickup and rabbit 5" "S" and "G" drill pipe to 2.85'. Stand back in the derrick. A total of 9 jts picked up. Injection Fluid x3�° Fluid Source From Lease' (bbl , Destination Vendor Manifest Number Note ' Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329516 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329513 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329511 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329510 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329509 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329515 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329512 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329514 f/ CD2 -176 We[lbores Wellbore Name Wellbore API /UWI CD2 - 76 501032060300 Seetian Size ('m Act Top (ftitB; `Act.Btm [ftKB�' Start Date End Date' �... COND1 19 37.0 114.0 SURFAC 131/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRM1 97/8 3,393.0 12,675.0 10/24/2009 111212009 PROD1 63/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Page 4/5 Report Printed: 12/3/2010 M ecurity Level: AK Development Daily Drilling Report CD2 -76 Report Number: 5 Rig: DOYON 19 Report Date: 10122/2009 Casing Strin � s String OD string wt Casing Description Run Date (in) (lbs/tt) string Grade set Depth (WRY Comment SURFACE 10/22/2009 103/4 45.50 L -80 3,382.6 Run 10 -3/4" 45.5 ppf L -80 BTC -m casing: Install bow spring on stop 8' above the shoe and on the box of jt # 1, baker lock joint #2, install centralizer on stop 10' below box, bakerlock/ makeup float collar joint w/ centralizer on box of joint #3, bakerlock pin of joint #4. Stab Frank's fillup tool into box of jt #4, then circulate 40 bbls of mud to clear air and check float equipment while still in the conductor. Continue to run casing observing makeup mark. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Apply Bow spring centralizers on every box to jt #12, then every other box to jt # 80. Ran casing to jt # 23 plus 10' of jt # 24 in the hole, tagged an obstruction (Taking 20k weight) @ 909'. Engage Frank's fillup tool and circulate jt # 23 and #24 down. Pumping 5 bpm w/ 250 psi and 29% flow. PU wt 120k, SO wt 105k. Circulated 180 bbls (3 BU). Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Run from jt # 25 to jt # 45. Engage Frank's fillup tool and circulate jt # 45. Stage pumps up from 2 bpm w/ 270 psi and 17% flow out to 6 bpm w/ 380 psi and 31 % flow out. PU wt 141 k, SO wt 120k. Circulated 140 bbls ( BU plus). After circulating PU 140k, SO 130k. Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Run from jt # 46 to jt # 82. Make up FMC hanger w/ landing joint. Run in the hole and land on the hanger. PU wt 202, SO wt 135k. Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. A total of 47 bow spring centralizers and two stop rings were run. Circ and cond. mud for cementing, reciprocate pipe, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Had full circulation throughout cement job w/ 139 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger at 1430 hrs. Cement Surface Casing Cement - Started 10/22/2009 Type Wellbore Cemented String Cement Evaluation Results casing I CD2 - 76 SURFACE, 3,382.6ftKB Stg No. Description Top( B) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.5 3,393.0 4 ' 520.0 Fluid Class 'Amount (sacks) 5/ (bbl) Density (lb /gal) ; t Yield (ft$ /sack) Esf T©p (#tKB} Est Btm MKBY} W ? Mud w/ nut plug marker 99.0 10.00 Viscosified Water w/ nut plug marker 33.0 8.60 Mud Push II 50.0 10.50 Lead ASL 526 428.0 10.70 4.79 36.5 2,883.0 Tail G w/ add's 276 57.6 15.80 1.16 2,883.0 3,393.0 Page 5/5 Report Printed: 12/3/2010 i PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 176 Rig: Doyon '19 Date: 101214/2009 Volume Input Volume /Stroke P p Rate: Drilling Supervisor: Dave BUrleyl Granville Rice k Pump u sed: #2 Mud Pump qw Strokes 0.1000 Bbls /Strk 7.00 Strk/min � Type of Test: Casing Shoe Test LOT /FIT Lw Pumping down annulus and DP. IV Casin g Test Pressure I teg rity Test Hole Size: 9 -7/8" Casing Shoe Depth Hole Depth Pumping Shut -in Pum ping Shut -in RKB -CHF: I 36.5 Ft 1 338:2.6 Ft-MDj 23 36.4 Ft -TVD 341,3.1) Ft -MD 123981 Ft -TVD Strks psi Min psi Strks psi Min psi Casina Size and Description: 10 -3/4° 45.5 # /Ft L -80 BTC 0 0 0 3530 0 0 0.00 1030 Casina Test Pressure Inte rit Test 2 110 1 3525 1 30 0.25 1020 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 4 270 2 3525 2 90 0.50 1020 Mud 10 min Gel: 51.0 Lb /100 Ft2 Mud 10 min Gel: 40.0 Lb /100 Ft2 6 430 3 3525 3 160 1.00 990 Test Pressure: 3530.0 psi Rotating Weight: 124000.0 Lbs 8 625 4 3525 4 240 1.501 950 Rotating Weight: 124000.0 Lbs Blocks /Top Drive Weight: 74000.0 Lbs 10 800 5 3125 5 320 2.00 92 Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 910 6 3525 6 390 2.50 8 Estimates for Test: 4 bbls Estimates for Test: 1042 psi 1.2 bbls 1111 1010 7 3525 7 4601 3.00 870 • • '16 '1125 8 3525 8 520 3.50 850 EMW = Leak -off Pressure + Mud Weight = 870 + 9.6 PIT 15 Second 18 1240 9 3125 9 570 4.00 840 0.052 x TVD 0.052 x 2386 Shut -in Pressure, psi 20 1375 10 5525 10 620 4.501 820 EMW at 3382.62 Ft -MD (2386.37 Ft -TVD) = 16.6 ppg 1020 22 1495 15 7525 11 670 5.001 810 4000 Lost 25 psi during test, held 24 1621 20 3520 '12 710 5.50 800 99.3° of test pressure. 26 1 760 25 13505 13 °x'50 6.00 790 3500' + *_�' -k. 2 1900 30 3101 1-11 810 6.50 790 3C) 2050 15 870 7.00 (80 3000 32 2200 16 890 7.50 760 34 2360 17 920 8.00 750 w 2500 36 2525 '18 950 8.50 1 381 2690 19 980 9.00 '750 0) 2000 40 2850 201 1000 9.50 740 w 42 30'5 1 [CJ30 10.00 t4Cl Q. 1500 44 3200 22 1050 46 3'360 1000 48 3130 500 "Or0i Min 0 0 1 2 3 4 5 6 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume CASING TEST LEAK -OFF TEST O PIT Point Pumped Bled Back Pum ed Bled Back 4.8 Bbls 1, jBbIs 1 2.2 Bbls Bbls Comments: CD2 -176 Surface LOT- FIT.xis Summary C132 -176 Intermediate Casing wen: C 2 -176 7 -5/ " 2 .7 f -80 BTC-m Cash Date: 1;3 v Cano illip Rig: Dmor 1 aim; Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 ........................ ........... ...... ....... ........................ ........... ................. .......... .. ............... .. .. ... .. o.r : �n`e _.......... _ Do on 19 RKB to Lower Lockdown Screws 7 5/8 ", 29.7 #, L -80, BTCM Casing CUTOFF JOINT 3.33 34.08 its 186 to 29 114 its 7 5/8" 29.7# L -80 BTCM Casing 4865.12 37.41 TAM Port Collar 2.10 4902.53 its 163 to 18E 23 its 7 5/8" 29.7# L -80 BTCM Casing 973.25 4904.63 Halliburton Stage Collar 2.38 5877.88 its 4 to 162 159 its 7 5/8" 29.7# L -80 BTCM Casing 6825.89 5880.26 Halliburkon Baffle Collar 1.36 12706.15 its 3 to 3 1 its 7 5/8" 29.7# L -80 BTCM Casing 43.07 12707.51 Haniburton Float Collar wl By -pass baffle on top .97 12750.58 its 1 to 2 2 its 17 5/8" 29.7# L -80 BTCM Casing 87.02 12751.55 Silver Bullet Float Shoe 2.14 12838.57 Bottorn of Shoe ----- - - > > >> 12840.71 12840.71 10 3/4" Shoe 3,382' MD 12840.71 9 7/8" Hole TD @ 16548' MD 12840.71 7 5/8" Shoe @ 12840.71' MID / 6119' TVD 12840.71 12840.71 Total of 34 Tandem Rise Centralizers; Jts 1 -30, 162 -163, 185 -186 12840.71 Total of 34 Stop Rings w/ Bowspring Centralizers 12840.71 Total of 19 Hydro Form Centralizers on As 203 -221 12840.71 12840.71 Note: Set Casing in Emergency Slips Due to Differential Sticking 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 405 jts in pipe shed 1300 jts to run 12840.71 12840.71 Remarks: Casing drifted with 6.750" Teflon Drift Up Wt 325 K Use Jet IubeRun & Seal pipe doe Dn Wt 160 K Average MU torque 8500 ft/lbs Block Wt 74 K Supervisors: Dave Burley / Jeff Browning Cement Detail Report CD2 -76 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 10/18/2009 08:00 Cement Details .. Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/11/2009 09:30 11/11/200922:45 CD2 - 76 Comment Cement Intermediate Casing in Two Stages - (1) 61 Bbls (2) 44 Bbls Cemer►t Sta es :. Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Primary 11,840.0 12,841.0 Yes Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? I Pipe RPM (rpm) 2 1 4 4 400.0 1,000.0 No I No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 12,707.5 Drill Bit Comment Pump 60.7 Bbls 15.9 PPG Class G w/ Additives Cr *i tem i�luids #IR Additi Ves Fi id ;x r Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount( acks) Class Volume Pumped (bbl) Tail Cement 1 11,840.0 12,840.0 295 G 60.7 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 15.80 8.00 Additives Additive Type Concentration Conc Unit label Sta e # 2 :.., Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Isolate Reservoir Secondary 5,078.0 5,880.0 No Yes No Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 4 4 47.0 400.0 No I No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 44 Bbls of 15.9 PPG Class G w/ Additives Through Stage Collar @ 5,878' MD Ftiiid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1 5,078.0 5,878.0 210 G 43.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 15.60 4.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/3/2010 l [I PL a Security Level: AK Development o� r Daily Drilling Report CD2 -76 Report Number: 25 Rig: DOYON 19 Report Date: 11/11/2009 <, /GfiE;Typa Network/ID # Total AFE +Sup 10265149 11,154,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 76 Development ALPINE 1 23.88 25.0 0.00 16,548.0 16,548.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,695.46 906,962.69 166,526.46 6,461,876.68 Actual Stan. Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10/18/2009 10/25/2009 34.99 41.55 -6.56 11/28/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 12,840.7ftK6 Ops and Depth @ Morning Report 24hr Forecast Allowing Well to Exhale (.5 BPH Currently) Cut Casing - L/D 5" DP - P/U 4" DP - Test BOPE Last 24hr Summary Continue to Circulate and Condition Mud Lowering Mud Weight to 11.6 PPG While Working the Casing Pulling Up to 200K Over and Setting Down to Block Weight - R/U and Cement First Stage w/ 60.7 BBIs of 15.9 PPG Class G - Close Pipe Rams Due to Breathing and WOC - Open HES Stage Collar, CBU and Cement 2nd Stage Through Collar w/ 44 Bbls of 15.9 PPG Class G Cement - Close Stage Collar and Pipe Rams - WOC General Remarks Weather Head Count No Spills - No Accidents 7 Deg, WC -16, Blowing Snow, Wind ENE @ 51.0 28 Mph Supervisor Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer start End 4u€ ' Time [3epth Start Depth End Time Time (hrs) Phase Op Cade Activity Code F=� X Trbl Code Trbl Class . (ft } pperatiorr 00:00 04:30 4.50 INTRM1 CASING CIRC T Stuck Pipe Differentially 12,844.0 12,844.0 Circulate & Cond Mud to Lower MW to Stuck 11.6 f/ 11.8 PPG -Work Pipe Up & Down Pulling to 550K w/ Pumps Off and 420K w/ Pumps @ 3 BPM the Setting Down to Block Weight - No Effect - Well Breathing w/ Pumps Off 04:30 07:30 3.00 INTRM1 CASING CIRC T Stuck Pipe Differentially 12,844.0 12,844.0 Circulate 3 bpm / 280 psi with 11.6 ppg Stuck mud wt. in & out - Continue working stuck pipe to 420k PUW with pumps on and Staging up to 550K PUW with pumps off - slacking off to block wt. - No Movement 07:30 07:45 0.25 INTRM1 CASING SFTY T Stuck Pipe Differentially 12,844.0 12,844.0 PJSM - on laying down casing Stuck 07:45 08:45 1.00 INTRM1 CASING PULD T Stuck Pipe Differentially 12,844.0 12,844.0 Lay down joint #301 - lay down fill up tool Stuck - blow down top drive 08:45 09:30 0.75 INTRM1 CEMENT RURD P 12,844.0 12,844.0 Rig up cement head and lines - establish circulation - 3 bpm / 270 psi Latest BOP Test Data elate Comment r.. 11/712009 lWitness of Test Waived by AOGCC Inspector Grimaldi Page 1/3 Report Printed: 12/3/2010 M ecurity Level: AK Development Daily Drilling Report CD2 -76 Report Number: 25 Rig: DOYON 19 Report Date: 11/11/2009 Time og NO Start End _tier Time Depth Start Depth End Time Trme hrs1 Phase 4Q Up Cade Aativi y Cade P T -x 7rbt Cade Tr61 t Iasi #ftKBa (ftISB] :. Speration ' 09:30 13:30 4.00 INTRM1 CEMENT CMNT P 12,844.0 12,844.0 Line up to cementers - pumped 4 bbls of CW100 - test lines to 4000 psi - continue pumping CW100 20 bbls total - Pumped 47 bbls of 12.5 ppg MudPush @ 4 bpm / 420 psi - shut down bled lines and cement head - load 1st stage top plug in head - pumped out plug with last 5 bbls of Mudpush - 52 bbls total - Pumped 295 sxs G cement w/ adds. (60.7 bbls) @ 4 bpm 447 - 211 psi - dropped top plug - Dowell displaced with 20 bbls of FW - switch to rig pumps and displaced with 11.6 ppg mud @ 4 bpm / 300 - 240 psi for first 485 bbls increased rate to 5 bpm (25 bbls of MudPush around shoe) 320 - 540 psi - slowed rate to 3.5 bpm @ 400 psi for last 4 bbls pumped (total 562 bbls mud) - bumped plug to 1000 psi - CIP @ 1312 hours - Full returns while cementing - Observed well breathing - shut in well with pipe rams @ 1315 hours to avoid potential contamination of cement. Checked floats, held. Blow down cement lines - Install gauge on casing and monitor pressures - SICP 5 psi, SI annulus pressure 35 psi. Cemented casing with shoe @ 12,844', FC @ 12,751', Baffle Collar @ 12,706', stage Collar @ 5878' and port Colar @ 4902' 13:30 19:30 6.00 INTRM1 CEMENT WOC T Stuck Pipe Differentially 12,844.0 12,844.0 Close Rams - Wait On Cement - Stuck Monitor Annular/ Casing Pressures - Initail Annular / Casing Pressure = 25 / 5 Psi - Final Annular / Casing Pressure 30 / 160 Psi 19:30 21:00 1.50 INTRM1 CEMENT CIRC P 12,844.0 12,844.0 Pressure Up Casing t/ 3650 Psi and Shift Open HES Stage Collar - CBU @ 4 BPM w/ 290 Psi 21:00 22:45 1.75 INTRM1 CEMENT CMNT P 12,844.0 12,844.0 Perform 2nd Stage Cement as Follows: Dowell Pumped 20 Bbls CW 100 @ 4 BPM, 22 Bbls of Mud Push @ 4 BPM, 44 Bbls of 15.9 PPG Class G Cement @ 4 BPM, Drop HES "Closing" Plug, Pump 20 bbls Fresh Water - Displace Cement w/ 248 Bbls of Mud - Plug on Seat at 2,480 Strokes - Pressure Up Casing t/ 2380 Psi - Collar Closed & Pressure Held @ 2340 Psi f/ 3 Minutes - CIP @ 2245 hrs - Calculated TOC 4,729' MD - 95% of Volume Pumped During Cement Job Returned (101 of 106 Bbls) i 22:45 00:00 1.25 INTRM1 CEMENT WOC T Stuck Pipe Differentially 1 12,844.0 12,844.0 Close Pipe Rams - Wait on Cement Stuck Page 2/3 Report Printed: 12/3/2010 Iplpp lRecurity Level: AK Development 7 ; °- Daily Drilling Report CD2 -76 Report Number: 25 Rig: DOYON 19 Report Date: 11/11/2009 Mud check Data. _. YP Cale Gel (14s) Get (14m) .:Gel( 34m) F HTHP Fiat '' , Density Temp Solids, C4FF:, Type Depth (ftKB) Dens', (lbfgal) V s (s /qt} PV Calc (cp} €Ibfii144jt'} (IbU)W4W) (lbrt144ft') :" (1b814E MBT',(tbtbbl) €In } ! s. }{ pH (T) 4 } LSND w/ 16,548.0 11.60 46 15.0 23.0 10.0 15.0 19.000 21.0 9.3 19.0 Inhybicol Wellbores _ Wellbore Name Wellbore API /UWI CD2 -76 501032060300 Section Size (in) Act Top (ftKH) AetBtm (WRI. Sham Date End Date COND1 19 37.0 114.0 SU RFAC 131/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRM1 97/8 3,393.0 12,675.0 10124/2009 11/2/2009 PROD1 63/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Casing Strips String OD String UVtt = Casing Description _ Run date _ (in), (lbs(ft) String Grade Set Depth (fttCfi Co [arnent� .i INTERMEDIATE 11/11/2009 75/8 29.70 L -80 12,840.7 Changed drilling zone, backed up & sidetracked out window @ 12675' Cement ` ', Intermediate Casing Cement - Started 11/11/2009 Type Wellbore Cemented String Cement Evaluation Results casing CD2 - 76 INTERMEDIATE, 12,840.7ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbll... P (final) (psi) 1 Intermediate Casing Cement 11,840.0 12,841.0 4 400.0 Fluid Ctass Amount (sacks)" V (bbl) Densyty {[b /gall .? ° Yield (ft,lsaek) FEst TQp €ftKB} ,( Est Bt m (tlCl Tail Cement G 295 60.7 15.80 1.16 11,840.01 12,840.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Isolate Reservoir 5,078.0 5,880.0 4 47.0 Fluid kat Class Amount (sacks) I V(bbl) V(bbi) jr YieCct(#t *lsaok) Est T ©p {ftKB) s . : Est Btm (ftKB} Tail Cement G 210 43.0 15.601 1.161 5,078.01 5,878.0 I Page 3/3 Report Printed: 1213/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 -176 Rig: Doyon 19 Date: 11/12/2009 Volum Input Pump Rate: Drilling Supervisor: D. Burley/ J. Browning Pump used: Cement Unit Barrels Bbls /strk 0.T Bbl /min Type of Test: Annulus Leak Off Test for Disposal Adequacy 'W Pumping down USE LIST Casin Test Pressure I tegrity Test Hole Size: USE PICK LIST Casing Shoe Dept Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: I 34.0 Ft 112,840 jFt-MDj 6,118 Ft -TVD 5 ,078 Ft -MD i 3,094 Ft -TVD Bbls psi Min psi Bbls psi Min s Casing Size and Description: 10 -3/4° 45.5 # /Ft L -80 BTC 0 0 =30' 0 11 Chan es for Annular Ade uac Test Pressure Inte grilyTest 1 02 77 0.25 121' uter casing shoe test results in comments Mud Weight: 11.6 ppg 2 0':4 217! 0.5 101 Description references outer casing string. Inner casing OD: 7.6 In. 3 0.6 77723f 1 =86' ize is that drilled below outer casing. 4 0.8 243 1.5 81 timated TOC for Hole Depth. 5 1 253 2 76' Enter inner casing OD at right Desired PIT EMW: 14.0 ppg 6 1 !2 263' 2.5 Estimates for Test: 764 psi 2.6 bbls 777777 7 77: 14 273' 3 71 EMW = Leak -off Pressure + Mud Weight = 296 + 11.6 PIT 15 Second 9 1.8 28$ ' 4 66' 0.052 x TVD 0.052 x 6118 Shut -in Pressure, psi 10 2 8$ 4.5 66 EMW at 12840 Ft -MD (6118 Ft -TVD) = 12.5 121 15 25 298' 5 66' 500 20 3 303' 5.5 61' 25 3!5 303' 6 61' 30 4 $03' 6.5 6:1 415 303 61' 7.5 56' 5 5 7773t 8 ... 56. w 6 31$' 8.5 56' 6 6 308' 9 °; 51 N 7 303 9.5 51 w 10 777 a 0 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30'" Barrels Shut -In time, Minutes Volume Volume Volume Volume �111 CASING TEST (LEAK -OFF TEST O PIT Point Pumped Bled Back Pum ed Bled Back 0.0 BbI s 1 Bbis 1 7.0 Bbls Bbis Comments: Note to File CD2 -468 (208- 180...310 -404) Colville River Unit (Qannik) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD2 -466). -- 10 %" Surface casing was cemented to surface. No problems were reported. Approximately 300 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 22% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 12/09/08, the pressure slope rises smoothly to —16.2 EMW and continues at a slightly shallower slope to 17.9 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 16.6 EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems are reported drilling the intermediate hole. The 7 -5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. - -An injectivity test down 10 -3/4" x 7 -5/8" annulus was conducted on 12/17/08. Pressure steadily increases until the break at 13.9 EMW. The pressure declined with additional pumping to 13.5 EMW. During the observation period, the pressure declined to 12.3 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. -- On the most recent LOT performed on 11/28/10 the pressure rises smoothly to a 15.5 ppg EMW and then continues on a shallower slope to a max of 15.9 EMW. After breaking over the stabilized pumping plateau is about 16.5 ppg EWM. Pumping pressure increased slightly during continued injection .... Still under the surface shoe LOT of 17.9 ppg EMW- --There are only 3 wells within % mile radius of CD2 -468. The surface shoe of CD2 -02 is closest, about 368' distant. CD2 -09 is 1136' and CD2 -76 is 1118' distant. AD was recommended for CD2 -09 in 2004. There are no identified issues with any of the proximal wells. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. */ C7&wa Sr. Petroleum Engineer AOGCC December 16, 2010 G:\AOGCC\ Common \tommaunder \Well Infonnation\By Subject\Annular Disposal \101215 -CD2- 468.doc Note to File CRU CD2 -468 (PTD 2081800) December 14, 2010 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the 7 -5/8" casing within well CD2 -468. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10 -3/4" surface casing shoe is set in this well at about 4,513' measured depth ( "MD;" - 2,335' true vertical depth subsea, or "TVDSS "), near the base of a 500 -foot thick shale and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone, sandy siltstone, and sandstone open to the annulus surrounding the 7 -5/8" casing within this well to accept the proposed injected fluids. 3. The lower confining strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of less than 100' from the wellbore. Discussion CPAI's application was utilized along with records from nearby wells Nuiqsut 1 and Alpine 1. The discussion that follows is based on those records and well logs from Nuiqsut 1, Colville River Unit (CRU) CD2 -33, CD 2 -467, CD 2 -32, and Alpine 1. An index map is provided in Figure 1, below. The C132 -468 development well was drilled to the Qannik Oil Pool within the Colville River Unit. ConocoPhillips intends to dispose of drilling wastes utilizing an open annulus within C132 -468 that extends downward from the 10 -3/4" surface casing shoe, which is set at about 4,513' measured depth, or (- 2,333' TVDSS), to the top of cement for the 7 -5/8" casing string, which is estimated to lie at about 8,695' MD (- 3,376' TVDSS). This annulus begins within Section 35 of TI IN, R4E, Umiat Meridian (UM), and it extends into Section 34 of TI IN, R4E, UM. It lies more than 3 miles from the current boundary of the CRU. The section of open annulus that will most likely accept the injected waste fluids (the most likely receptor interval) is a portion of the Seabee formation that extends from 4,710' to 5,005' MD (- 2,405' and - 2,509' TVDSS; see Figure 2, below). This interval contains numerous 1- to 8 -foot thick beds of siltstone, sandy siltstone and sandstone that are separated by mudstone and shale. The aggregate thickness of the siltstone, sandy siltstone and sandstone beds open to the annulus is about 25'. On the well log recorded in C132 -468 December 14, 2010 Note to File Page 2 of 5 02468 CD2 -468 U2-06 +: 02 -02 �- -- -. .. ..... .CD2 C �D2 -03 65 � D208 CD241 C 47 0221 Q. CD �Li 02-10 II I CO2 - 2 27 CD�20 CD2 -13 A 3 CD274 C.D2 -73 f 02 -12 CD 04 0246 A TO 0 C1 Area of Review _ D11 CRU C132-468 Annulus 1s2 Cf CD2S8 7 � Q (D2 -I8 CD275 GtYt ne PF- D2 y 1 L1'D2,29 CD2 1'02 -94 CD226 ,& Surface Casing Shoe 233 Figure 1. Index Map (The path of the cross - section shown on Figure 3 is highlighted with red; the wells drilled to the Qannik Oil Pool are depicted with blue lines; all remaining Colville River Unit wells are depicted with gray lines and symbols; and gray squares represent governmental sections that typically measure 1 mile on each side.) from CD2 -468, the gamma ray curve suggests the presence of a prominent siltstone bed at the shoe of the 10 -3/4" surface casing. This apparent siltstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 10 -3/4" casing shoe consist of shale, claystone, with only minor amounts of siltstone (see Figure 3, below). The 10 -3/4" surface casing shoe lies near the base of a 500 -foot thick interval that is dominated by shale and mudstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 40 -foot thick zone of claystone and mudstone that is also continuous throughout the area. This interval, which lies between about 5,212' and 5,357' measured depth (- 2,572' and - 2,612' TVDSS), and two similar, underlying strata will provide lower confinement for injected wastes. In vicinity of Drill Site CD2, the base of permafrost occurs at about - 1,200' TVDSS, which is about 1,200' shallower than the top of the most likely receptor interval. Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine 1 is an exploratory well located about 1 -1/2 miles southeast of the likely receptor interval. In Alpine 1, methane was first encountered at 760' measured depth (about -720' TVDSS), and it was CD2 -468 December 14, 2010 Note to File Page 3 of 5 Correlation Depth Resis Porosity OR <MD ResD(RPD) RHOS 10 API 24 0 .2 OHMM 2 .65 GJCC 2. TVDSS> R and - Sit - Shale - -- —_..._ ow Poro 2 OHMM SP(NIA) TVD ResS(RPS) NPOR 100 10 .2 OFMM 2 <MD _ DTCP(NIA) 70 A 2400 U pp er 4600 Confining 0 Strata 4700 -2400 Most Likely Receptor 4800 Interval for 10 Disposed 4900 Fluids �- 5000 ` 5100 5200 5300 -2600 Lower 5400 Confining —0 Strata 5500 \\4 5600 -2700 5700 5800 5900 Figure 2. CD2 -468 Well Log Displaying Affected Intervals CD2 -468 December 14, 2010 Note to File Page 4 of 5 1980250 2081800 2020290 1941720 � W 501032025300 16891 ft 501032058700 1316 ft 501032041100 4309 ft 501032021100 � � "r ARCO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK ARCO NUIQSUT 1 COLVILLE RIV UNIT CD2468 COLVILLE RIV UNIT CD2 -32 ALPINE 1 1512 FSL 1457 FWL 2197 FNL 1904 FEL 1885 FNL 1525 FEL 1468 FSL 2246 FWL TWP: 11 N - Range: 4 E - Sec. 5 TWP: 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 1 Upp _ Confining - 2000 .. _ Strata -2000 _ - 10 -3/4" Casing Shoe _ - _ ost ` - _ - l.; ON -2500 _ - receptor ° -2500 s m lilterval�. 1,ower �. `� ' � Annulus _ Confining available -3000 Strata for ' _ - _ 3000 " 4 disposal injection -3500 _ - _ - _ - -3500 Cement Top _ -4000 TD =7650 TD =17850 w 7[)-11720 TD-7500 -4000 Figure 3. Structural Cross - section from Nuiqsut 1 to Alpine 1 encountered in significant quantities (more than 1% methane in air, or 50 units) at 1,155' measured depth (about - 1,015' TVDSS. In Nuiqsut 1, located about 3 miles southwest of CD2 -468, methane gas was first encountered at 710' measured depth ( -653' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil show encountered in Alpine 1 was a poor show observed between 2,980' and 3,080' measured depth (from about - 2,940' to - 3,040' TVDSS. However, the description of this show note does not mention oil staining; the show was noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining is found in the description of a fair oil show that occurs from 4,025' to 4,080' measured depth (about - 3,985' to -4,040 TVDSS), which is about 1,475 true vertical feet below the most likely receptor beds for the injected material. The shallowest oil show encountered in Nuiqsut 1 was a fair show observed between 3,990' and 4,070' measured depth (from about - 3,930' to - 4,010' TVDSS, or about 1,420' below the most likely receptor beds in CD2 -468). The description of this show mentions free oil in the wet sample at 4,080' measured depth (4,020' TVDSS). So, near Drill Site CD2, the most likely receptor interval does not contain potentially commercial hydrocarbons. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD2 -468 that will be affected by the proposed annular disposal operations. There are about 25' of porous siltstone, sandy siltstone and sandstone beds within the most likely receptor interval that are open to the wellbore, CD2 -468 December 14, 2010 Note to File Page 5 of 5 according to a count using the gamma ray curve from CD2 -468. Porosity well logs were run across this interval in Nuigsut 1, CD2 -32, and Alpine 1, which are located 3 miles southwest, '/ mile east, and 1 -1/2 miles southeast, respectively. Inspection of the density porosity measurements in those three offset wells suggests an average porosity of about 27% for the siltstone, sandy siltstone, and sandstone beds. Based on these values, and assuming piston -like displacement of native formation fluids, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 100' from the wellbore, as indicated below. Injected Fluid vs Affected Radial Distance CD2 -468 Wellbore (assumes 25' aggregate injection zone thickness and 27% porosity) 300 -___ - _ __ _ _ -_ -_ I 250 I i 0' 0 a m 200 E 0 w m v m 150 p A M 100 v d d 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 5. Radial Distance Potentially Impacted by CD2 -468 Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD2. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I commend approval of this annular disposal project. Steve Davies Senior Petroleum Geologist
