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212-182
Originated: Delivered to:8-Apr-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 CASSIN-01 50-103-20663-00 90771196Greater Mooses ToothTubing Punch Record Field- Final 1-Mar-22 0 123CASSIN-01 is located in a federal oil and gas unit. Only with respect to the CASSIN-01 Well Data,PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells.Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC).212-182T36454Meredith GuhlDigitally signed by Meredith Guhl Date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bbls 15.8# Gas Tight Cement Thru retainer/ 7 bbls sqz'd into perfs -600 psi 135$([SORUDWLRQ%HDU7RRWK8QLW 32%R[$QFKRUDJH$. 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" # $ %& ' (() * + , - ((). -* ! # %& ' (() * , ((). -* /0/ 0 0 0 101 -0-2 34 % " 5 06 7 8 % 606 0 '0. 9 4 ' % 0%% , 04 / : -0-2 34 % 5 "0"! %# 8% 2 " .*;< =( 2>8 ? * * 2 == 4 + % :2 % / :, 4 *4; 3*-1885@: 4 * %2 3()5 !" # # $$ $%& % '( ) ! ##A &#,@ *-188 % A &#,@ 2 & A &#,%2 :% A &#, 6 3. , 4= +5 B B8 < < 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Monday, March 7, 2022 12:56 PM To:Applehans, Aaron (Fairweather, LLC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Wiese, Tyson M; Conklin, Amy A Subject:RE: MIT-T Test Report Cassin #1 Attachments:2022-0304_MITP_Cassin-1.xlsx Revised report attached. Changed well name from Scout to Cassin; moved witness info to Notes since AOGCC did not witness. Added Sundry # to Notes Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Applehans, Aaron (Fairweather, LLC) <Aaron.Applehans@contractor.conocophillips.com> Sent: Saturday, March 5, 2022 5:38 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: MIT‐T Test Report Cassin #1 Have a good weekend, Thank you, Aaron Applehans Drilling/Wells Supervisor 907‐982‐1790 Appleha@conocophillips.com Some people who received this message don't often get email from aaron.applehans@contractor.conocophillips.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 212-182 Type Inj N Tubing 125 3100 3090 3085 Type Test P Packer TVD 5045 BBL Pump 0.6 IA 750 800 800 800 Interval O Test psi 3000 BBL Return 0.6 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips NPRA Exploration/Bear Tooth Unit Cassin #1 Aaron Applehans 03/04/22 Notes:Sundry 321-327 MIT-T post cement retainer set with 2 bbls cement on top. Witness waived by Adam Earl (AOGCC); witnesed by Allie Schoessler (BLM) Cassin #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0304_MITP_Cassin-1 J. Regg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y Samantha Carlisle at 1:10 pm, Jul 01, 2021 321-327 Tyson Wiese Digitally signed by Tyson Wiese Date: 2021.07.01 12:49:32 -08'00' AOGCC inspection is required after cutoff and before any remedial cementing. X X AA-081754 X SFD 7/1/2021 10-407 DSR-7/1/21 -00 SFD 7/1/2021 VTL 8/4/21 SFD 7/1/2021 dts 8/5/2021 JLC 8/5/2021 Jeremy Price Digitally signed by Jeremy Price Date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" ,% , 7 ,71 ' /# %#81 # $ !%& $ %' %( )* # $ %& $ %' %( /#, 9#,#(#+ :7#,0 , 7 , ' /,-8 + * -;<,:%- 7 ,!=! /#, - ") G ") =G +) D-*+=) 1 H; D 2 A ) * ?E 0*4++$% * ,<=0$9*$=6 ) &3I5*5<$<)D* $9*$= &3I5*55+<9<)D* ,<= &3I5*5$+<)D ") =G <+) D" D 22 ! ?6* 9-+5=8,<= &3I5*5+$)D ") =$G ,$) D-*+=) 1 )2 7 2 ,) D-*+=) 1 A ) ) !"# $% $ & '() *+,- --% $ $ ./0*- 1 2 ) ?"@( ") = 4+5% $ ./ 678 () *+$ 4955% - $ ./'71 2 ) 1 : ; 49-% < 1 ' )6 )3 27 & -455$% , +5 5 ' ) --= " " -45% + $ ./0," " &> =$ -45-% 9 $ ./01'"1 2 ) ?"@( -45% 5 $ ./ 678 () *+$ -4<$% $ ./" &> ") &')A ))2 -45% $ ) B -4--% $ $ ./0," " &> = -4$$% $ ./01'"1 2 ) ?"@( -4$+% -$ ./ 678 () *+$ -4% < $ ./" &> ") &')A ))2 -4++% , $ ) B -4-$$% + $ ./0," " &> = -4-9+% 9 $ ./01'"1 2 ) ?"@( -4<-<% 5 $ ./8(() *+$ -4<+-% $ ./ ))' '!C7 @ 3 -4,5$% C)) " D G ") = I$9" I4-55 ") = I<$2 " 32 I45-5 F I*= ") =$I2 52 " I4555 D & 7# $ %< ' - + ( + * # $ %& $ !%< 7 # $"!%< +=#22 >0 $!!%< Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,253.0 4/9/2013 CASSIN 1 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: GLV C/O, Open SLV, Set Plug & BPV 5/3/2013 CASSIN 1 osborl Casing Strings Casing Description CONDUCTOR Insulated 24" OD (in) 16 ID (in) 15.25 Top (ftKB) 68.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 27.8 Set Depth (ftKB) 2,378.4 Set Depth (TVD) … 2,378.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 25.1 Set Depth (ftKB) 6,507.3 Set Depth (TVD) … 6,500.7 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-M Tubing Strings Tubing Description UPPER TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.0 Set Depth (ft… 5,010.0 Set Depth (TVD) (… 5,003.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.0 23.0 0.00 HANGER FMC TUBING HANGER (made up to a 3' pup) 3.980 57.7 57.7 0.04 XO Reducing Crossover, 4-1/2" 12.6#/ft Box x 3-½" 9.3#/ft, EUE 8rd Pin 3.500 525.2 525.2 0.59 NIPPLE CAMCO DS NIPPLE w/2.875" NO GO PROFILE 2.875 4,900.0 4,893.6 1.05 NIPPLE HES "X" NIPPLE w/2.813" PROFILE 2.813 5,003.3 4,996.8 0.83 LOCATOR 80-40 GBH-22 LOCATOR (5.5' space out) 2.990 5,004.5 4,998.1 0.82 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY WITH 1/2 SHOE 3.000 Tubing Description LOWER TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 4,997.7 Set Depth (ft… 5,704.0 Set Depth (TVD) (… 5,697.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,997.7 4,991.3 0.87 SLEEVE BAKER HR LINER SETTING SLEEVE 5.000 5,010.9 5,004.4 0.78 NIPPLE BAKER RS NIPPLE 4.250 5,013.7 5,007.3 0.76 SBR BAKER 80-40 (4") SEAL BORE 4.250 5,044.9 5,038.5 0.54 PACKER BAKER PREMIER PACKER 2.870 5,163.3 5,156.9 0.30 NIPPLE HES "X" NIPPLE w/2.812" Profile 2.812 5,209.8 5,203.4 0.28 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable, 2" Ball Seat (OPEN 4/17/2013) 2.780 5,254.9 5,248.5 0.27 BLAST JT Blast Joint, 3-½" 9.3#, L-80, EUE (Blast Joint Assy #2) 2.897 5,323.2 5,316.8 0.47 PACKER 3-1/2" x 7" Baker Premier Packer # 2. 2.870 5,441.2 5,434.8 0.27 NIPPLE HES "X" NIPPLE w/2.812" Profile 2.812 5,487.5 5,481.0 0.26 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable, 1.875" Ball Seat (CLOSED 4/10/2013, BUT NOT HOLDING - OPEN FOR FLOWBACK) 2.780 5,532.7 5,526.2 0.25 BLAST JT Blast Joint, 3-½" 9.3#, L-80, EUE (Blast Joint Assy #1) 2.897 5,597.6 5,591.1 0.26 PACKER 3-1/2" x 7" Baker Premier Packer # 1. 2.870 5,685.2 5,678.7 0.38 NIPPLE HES "XN" NIPPLE w/2.75" Profile 2.750 5,703.2 5,696.7 0.41 SOS BALL SEAT SHEAROUT SUB for 1" OD ball~5000 psi shear required 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,900.0 4,893.6 1.05 PLUG 2.81" XX PLUG ASSY (LOCK, EQ SUB, FIL EXT & END CAP/OAL=47.5") SET IN NIPPLE 4/22/2013 0.000 5,354.0 5,347.6 0.50 PLUG WRP PLUG 4/17/2013 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,258.0 5,273.0 5,251.6 5,266.6 CASSIN, CASSIN 1 3/24/2013 IPERF 5,535.0 5,550.0 5,528.6 5,543.6 BLACKBURN, CASSIN 1 3/24/2013 IPERF 5,710.0 5,725.0 5,703.6 5,718.6 SANFORD, CASSIN 1 3/24/2013 IPERF Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 4/6/2013 5,610.0 5,825.0 0.0 0.00 0.00 2 FRAC 4/6/2013 5,158.0 5,373.0 0.0 0.00 0.00 3 FRAC 4/6/2013 5,435.0 5,610.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,840.0 4,833.6 1.08 CAMCO MMG 1 1/2 GAS LIFT DMY BK 0.000 0.0 4/22/2013 2 4,950.9 4,944.5 1.04 CAMCO Espinag e 1 GAS LIFT GAUG E 0.000 0.0 3/27/2013 3 5,103.5 5,097.0 0.34 CAMCO MMG 1 1/2 GAS LIFT GAUG E 0.000 0.0 3/27/2013 4 5,381.8 5,375.3 0.42 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 4/16/2013 5 5,656.0 5,649.5 0.32 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 4/16/2013 Notes: General & Safety End Date Annotation 4/22/2013 NOTE: BPV SET VERTICAL, CASSIN 1, 6/30/2021 8:53:05 AM Vertical schematic (actual) PRODUCTION; 25.1-6,507.3 IPERF; 5,710.0-5,725.0 FRAC; 5,610.0 Gauge Mandrel; 5,656.0 PACKER; 5,597.6 IPERF; 5,535.0-5,550.0 FRAC; 5,435.0 Gauge Mandrel; 5,381.8 PLUG; 5,354.0 PACKER; 5,323.2 FRAC; 5,158.0 IPERF; 5,258.0-5,273.0 Gauge Mandrel; 5,103.5 PACKER; 5,044.9 Gauge Mandrel; 4,950.9 PLUG; 4,900.0 GAS LIFT; 4,840.0 SURFACE; 27.8-2,378.3 Cement Squeeze; 2,263.0 ftKB NIPPLE; 525.2 CONDUCTOR Insulated 24"; 68.0-108.0 NAK EXPLOR KB-Grd (ft) Rig Release Date CASSIN 1 ... TD Act Btm (ftKB) 6,520.0 Well Attributes Field Name Wellbore API/UWI 501032066300 Wellbore Status EXPLOR Max Angle & MD Incl (°) 6.25 MD (ftKB) 2,846.36 WELLNAME WELLBORECASSIN 1 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Notes: General & Safety End Date Annotation 3/27/2013 NOTE: MANDREL #2 SOLID GAUGE MANDREL 3/27/2013 NOTE: ALL MANDRELS ARE SIDE POCKET MANDRELS VERTICAL, CASSIN 1, 6/30/2021 8:53:06 AM Vertical schematic (actual) PRODUCTION; 25.1-6,507.3 IPERF; 5,710.0-5,725.0 FRAC; 5,610.0 Gauge Mandrel; 5,656.0 PACKER; 5,597.6 IPERF; 5,535.0-5,550.0 FRAC; 5,435.0 Gauge Mandrel; 5,381.8 PLUG; 5,354.0 PACKER; 5,323.2 FRAC; 5,158.0 IPERF; 5,258.0-5,273.0 Gauge Mandrel; 5,103.5 PACKER; 5,044.9 Gauge Mandrel; 4,950.9 PLUG; 4,900.0 GAS LIFT; 4,840.0 SURFACE; 27.8-2,378.3 Cement Squeeze; 2,263.0 ftKB NIPPLE; 525.2 CONDUCTOR Insulated 24"; 68.0-108.0 NAK EXPLOR CASSIN 1 ... WELLNAME WELLBORECASSIN 1 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Dear Commissioner Price, Due to low oil prices, budget constraints, and a need to minimize nonessential remote work considering spiking COVID-19 cases statewide, Conocophillips Alaska, Inc. is revising our winter 2021 ice road scope of work. Our initial plan was to execute the following P&A’s: x Lookout 1 x Scout 1 x Cassin 1 x Cassin 6 As has been discussed with AOGCC staff, we now propose to perform the following P&A’s instead, staying closer to infrastructure, in 2021: x Lookout 1 x 1M-17 x Well 28243-1 (for Exxon) With that change, we expect to perform the following P&A’s in 2022: x Scout 1 x Cassin 1 x Cassin 6 The Scout 1 well is overdue for its 5-year suspended well inspection under 20 AAC 25.110(e) because of last year’s early ice road exit due to measures taken to project against the COVID-19 pandemic. We do not believe that deferral of inspection until 2022 would present a safety or environmental risk. For the reasons described above, we seek modification of the inspection deadline for this well to May 31, 2022, as allowed under 20 AAC 25.110(n). Thank you for your consideration, Sincerely, Shon Robinson Manager, AK Wells Shon Robinson Alaska Wells Manager 700 G Street, ATO (99501) P. O. 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goy G6doe-a ConocoPhillips %2-3025 TRANSMITTAL FROM: Sandra D. Lemke,AT00340 TO: Meredith Guhl ConocoPhillips Alaska, Inc. State of Alaska, AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Cassin 1 Permit: 212-182-0 DATE: 7/26/2016 Transmitted: North Slope, NPRA, Alaska Cassin 1 (501032066300) CD/digital data SCANNED 2 , Cassin 1 FRS MRIL REV1.las *The information provided hereunder by ConocoPhillips Alaska, Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke(dCOP.com CC: Cassin 1 -e-transmittal well folder Recei•t: ✓�'`�- Q Date: (2-G, /1 . , fAK/IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 w, rt. Z I 2- 182 • • CAMOCOPhillipS TRANSMITTAL Rl& FROM: Sandra D. Lemke, AT00340 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC • P.O. Box 100360 333 W. 7th Ave, Suite TOD—rte Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 07/20/2016 Transmitted: GO� � � North Slope, NPRA, Alaska Cassin 1 (501032066300) Via email \ALB Espionage gauge-well test/pressure data; multiple test dates; 4 .csv files and 1 .xls file. *The information provided hereunder by ConocoPhillips Alaska, Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@COP.com CC: Cassin 1 -e-transmittal well folder Date: l Receipt: �l G–�l I �j `+$ . AK/IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 , STATE OF ALASKA ALAJ,.A OIL AND GAS CONSERVATION COMM,,6ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed Suspend r Perforate E Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend Well Inspect 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory 212-182 3.Address6.API Number Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20663-00 7.Property Designation(Lease Number): 8.Well Name and Number: FED AKAA081754 Cassin 1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Wildcast/Exploration 11.Present Well Condition Summary: Total Depth measured 6520 feet Plugs(measured) 5163, 4900 true vertical 6513 feet Junk(measured) None Effective Depth measured 6419 feet Packer(measured) 0 true vertical 6413 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse Conductor 80 16 108 108 0 0 Surface Casing 2350 9.625 2378 2378 0 0 Production casing 6482 7 6507 6500 0 0 SCANNED , , RECEIVED Perforation depth: Measured depth: 5258-5273, 5568-5550, 5710-5725 UI 2 9 2015 True Vertical Depth: 5251-5266, 5528-5543, 5703-5719 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 5010 MD, TVD Packers&SSSV(type,MD,and ND) 3 Baker Premier packers-5044 MD&5038 TVD, 5313 MD&5316 TVD, &5597 MD&5591 TVD No SSSV 12 Stimulation or cement squeeze summary: NA Intervals treated(measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 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 p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. Oil r Gas r VVDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP p SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt' NA Contact MJ Loveland/Martin alters Email n1878( conocophilllips.com Printed Name MJ Loveland Title WI Project Supervisor Signature / Phone:695-7043 Date-7/?"///3- _ 7,,L f. 17d.i Form 10-404 Revised 5/2015 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 26, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Cassin 1 (PTD 212-182) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Cassin 1 (PTD 212- 182). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well continues to be held for future development of the area. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Cassin 1 Field/Pool: Wild Cat/ Exploration Permit#(PTD): 212-182 API Number: 50-103-20663-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 3/28/2013 Surface Location: 1106 FSL1502 FWL Section: 28 Township: 12N Range: 1W Nearest active pad or road: Alpine CD5 Meridian: UM Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Tundra Pad or location surface: Clean Tundra Location cleanup needed: None Pits condition: NA Surrounding area condition: Clean Tundra Water/fluids on pad: Ground water in various puddles Discoloration, Sheens on pad, pits or water: no sheens on any water Samples taken: NA Access road condition: NA- Helicopter Photographs taken (#and description): Aerial ground shots Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Well head covered in chicken wire and bird barrier Valves appeared to be in good condition but were not accessible to cycle due to chicken wire. Cellar description, condition, fluids: Water in cellar no sheen Rat Hole: NA Wellhouse or protective barriers: Bird Barrier with chicken wire Well identification sign: None Tubing Pressure (or casing if no tubing): Not taken as gage was not accessible due to bird barrier Annulus pressures: VOA=20 psi, IA not Accessible -due to bird barrier Wellhead Photos taken (#and description): Photo of tree and bird barrier Work Required: None Operator Rep (name and signature): Jim Holley, Matt Miller, MJ Loveland AOGCC Inspector: Waived (Matt Herrera) Other Observers: Dave McKnight Inspection Date: 7/25/2015 AOGCC Notice Date: 7/16/15 & 7/23/15 Time of arrival: 930 Time of Departure: 945 Site access method: Helicopter NAK CASSIN 1 ConocoPII1.fillips '' V`'5. Well Attributes Max Angle&MD ITD � �I Wellbore APUUWI Field Name Well Status Incl("I MD(MB) Act Btm(ftKB) aS , i,,,,,..,.6;,lp; 501032066300 NORTH ALASKA TIGHT HOLE EXPLOR 6.25 2,846.36 6520.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date """Well Conan:VERTICAL-CASSIN 1,51320137:37:04 AM SSSV:NIPPLE Last WO: Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6253.0 4/9/2013 Rev Reason:GLV C/O,Open SLV,Set Plug&BPV osborl 5/3/2013 HANGER,23 Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 I 15.250 68.0 108.0 108.0 62.50 H-40 WELDED Insulated 24" Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String_.String Top Thrd i- SURFACE 95/8 8.835 27.8 2,378.3 2,378.2 40.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(L.Set Depth(TVD)...String Wt..String_.String Top Thrd PRODUCTION 7 6.276 25.1 6,507.3 6,500.7 26.00 L-80 BTC-M I Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)_.String Wt...String...String Top Thrd CONDUCTOR UPPER TUBING 31/2 2.992 23.0 5,010.0 5003.6 9.30 L-80 EUE Insulated 2448• Completion Details Top Depth NIPPLE,525uEs (TVD) Top Incl Noml... Top(ftKB) (RKB) r) Item Description Comment ID(in) 23.0 23.0 -0.01 HANGER FMC TUBING HANGER(made up to a 3'pup) 3.980 57,7 57.7 0.04 XO Reducing Crossover,4-1/2"12.6#/ft Box x 314"9.3#/ft,EUE 8rd Pin 3.500 525.2 525.2 1.09 NIPPLE CAMCO DS NIPPLE w2.875"NO GO PROFILE 2.875 SURFACE, 4,900.0 4,893.6 1.05 NIPPLE HES"X"NIPPLE w/2.813"PROFILE 2.813 28-2.378 5,003.3 4,996.8 0.40 LOCATOR 80-40 GBH-22 LOCATOR(5.5'space out) 2.990 5,004.51 4,998.11 0.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY WITH 1/2 SHOE 3.000 GAS LIFT, _ ` 4,840 __- Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ;.: LOWER TUBING 31/2 2.992 4,997.7 5,704.0 5,697.6 9.30 L-80 EUE It Int Completion Details NIPPLE,4,900 '%/ Top Depth PLUG,1:91 'y (TVD) Top Incl Nomi... Top(ftKB) (MB) (") Item Description Comment ID(in) 4,997.7 4,991.3 0.41 SLEEVE BAKER HR LINER SETTING SLEEVE 5.000 Er Gauge Mandrel5,010.9 5,004.4 0.40 NIPPLE BAKER RS NIPPLE 4.250 4,951 1_ 5,013.7 5,007.3 0.40 SBR BAKER 80-40(4")SEAL BORE 4.250 5,044.9 5,038.5 0.38 PACKER BAKER PREMIER PACKER 2.870 SLEEVE,4,s96 I. 5,163.3 5,156.9 0.01 NIPPLE HES"X"NIPPLE w2.812"Profile 2.812 LOCATOR, SEAL n,00 3 ,. .. . 5,209.8 5,203.4 0.14 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,2"Ball Seat(OPEN 4/172013) 2.780 5,005 5,254.9 5,248.5 0.27 BLAST JT Blast Joint,3-Y"9.3#,L-80,EUE(Blast Joint Assy#2) 2.897 NIPPLE,5,011 ill 5,323.2 5,316.8 0.47 PACKER 3-12"x 7"Baker Premier Packer#2. 2.870 SBR.5.014 it.....it 5,441.2 5,434.8 0.27 NIPPLE HES"X"NIPPLE w/2.812"Profile 2.812 5,487.5 5,481.0 0.26 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,1.875"Ball Seat(CLOSED 2.780 PACKER,5,045 4/10/2013,BUT NOT HOLDING-OPEN FOR FLOWBACK) MC 5,532.7 5,5262 0.10 BLAST JT Blast Joint,3-l/"9.3#,L-80,EUE(Blast Joint Assy#1) 2.897 Gauge Mandrel, 5,597.6 5,591.1 0.22 PACKER 3-1/2"x 7"Baker Premier Packer#1. 2.870 5,103 5,685.2 5,678.7 0.38 NIPPLE HES"XN"NIPPLE w/2.75"Profile 2.750 it 5,703.2 5,696.7 0.41 SOS BALL SEAT SHEAROUT SUB for 1"OD baIF 5000 psi shear required 2.992 NIPPLE,5,163 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IL Top Depth MI (TVD) Top Incl EL t Top(ftKB) (ftKB) (") Description Comment Run Date ID(in) FRAC PORT, 4,900.0 4,893.6 1.05 PLUG 2.81"XX PLUG ASSY(LOCK,EQ SUB,FIL EXT&END 4/22/2013 0.000 5,210 W"` ( CAP/OAL=47.5")SET IN NIPPLE IIIF- 5,354.0 5,347.6 0.33 PLUG WRP PLUG 4/17/2013 0.000 IPERF, . FR2ACITiR758� MI p a- Perforations&Slots K. Shot Top(TVD) Btm(TVD) Dens I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ink- Type Comment 5258.0 5,273.0 5,251.6 5,266.6 CASSIN, 3/24/2013 IPERF PACKER,5,323 CASSIN 1 5,535.0 5,550.0 5,528.6 5,543.6 BLACKBURN, 3/24/2013 IPERF PLUG,5,354 CASSIN 1 n 11 5,710.0 5,725.0 5,703.6 5,718.6 SANFORD, 3/24/2013 IPERF CASSIN 1 Gauge Mandrel, 5,382 L Stimulations&Treatments I Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) NIPPLE,5,441 IRKS) (ftKB) (ftKB) MR) Date Comment_ 5,158.0 5,373.0 5,151.6 5,366.6 FRAC 4/6/2013 FRAC the Sanford,Blackbum,and Cassin I formations,placing 90,370#,100,551#,and FRAC PORT, I- 119,022#proppant,respectively.Utilized shifting 5.,487 - sleeve system to open and isolate zones dropping I 2.000"and 2.125"balls between the three formation FRAC,5,435 Istages. Pumped 3604-bbl total sluny volume,25# I x-link gel with linear gel flushes,309,943#total 16/20 IPERF, I® CarboLite(100%design). 5,5355,550all IL I i. Mandrel Details I Top Depth Top Pod I s... (TVD) not OD Valve Latch Dice TRO Run PACKER.5,598 -, 'I N...Top(ftKB) (ftKB) r) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 1 .!1 1 4,840.0 4,833.6 1.05 CAMCO MMG 1 12 GAS LIFT DMY BK 0.000 0.0 4/22/2013 L 2 4,950.9 4,944.5 1.04 CAMCO Espinage 1 GAS LIFT GAUGE 0.000 0.0 3/27/2013 Gauge Mandrel, { 3 5,103.5 5,097.0 0.32 CAMCO MMG 1 12 GAS LIFT GAUGE 0.000 0.0 3/27/2013 5,656 ] 4 5,381.8 5,375.3 0.33 CAMCO MMG 1 12 GAS LIFT OPEN 0.000 0.0 4/162013 NIPPLE,5,885 5 5,656.01 5,649.5 0.32 CAMCO MMG 1 12 GAS LIFT OPEN 0.000 0.0 4/162013 X SOS,5,703 FRAC,5,610ts IPERF, 5,710-5.725 al PRODUCTION, TD4. 25.6,6,520,507 NAK CASSIN 1 • ConocoPhillips ... w� Alaska,Inc. KB-Grd(ft) Rig Release Date Well Canfib:VERTICAL-CASSIN 1 5132013 7:37;04 AM Schematic-Actual HANGER,23 Stimulations&Treatments Bottom Min Top Mao Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (88(B) (ftKB) (ftKB) Type Date Comment 5,435.0 5,610.0 5,428.6 5,603.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin I formations,placing 90,370#,100,551#,and 119,022#proppant,respectively.Utilized shifting — I sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation CONDUCTOR Insulated 24•, stages. Pumped 3604-bbl total slurryvolume,25# x-link gel with linear gel flushes,309,943#total 16/20 CarboLite(100%design). 68-108 5,610.0 5,825.0 5,603.6 5,818.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin NIPPLE,525 formations,placing 90,370#,100,551#,and 119,022#proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation stages.Pumped 3604-bbl total slurry volume,25# x-link gel with linear gel flushes,309,943#total 16/20 SURFACE, CarboLite(100%design). 28-2,378 Notes:General&Safety GAS LIFT, End Date Annotation 4,845 I 3/27/2013 NOTE:MANDREL#2 SOLID GAUGE MANDREL 3/27/2013 NOTE:ALL MANDRELS ARE SIDE POCKET MANDRELS NIPLUG'4 _ 4/22/2013 NOTE:BPV SET /� 11- Z Gauge Mandrel, 4,951 I SLEEVE,4,998 LOCATOR, 5,43 k. SEAL ASSY, ....... 5.555 NIPPLE,5,011 SBR,5,014 PACKER,5.045 Gauge Mandrel, 5,103 NIPPLE,5,163 1. FRAC PORT, 5,210 IPERF, 5,258-5,273 FRAC,5,158 I - PACKER,5,323 NE air. PLUG,5,364 Mir Gauge Mandrel, 5,382 (t BE I NIPPLE,5,441 IE- 1� `L FRAC PORT, ` 5,487 I� FRAC,5,435 5,5355 PE.55RF0, BE -... JC IL PACKER,5.598 Gauge Mandrel, 5,658 NIPPLE,5,885 I... SOS,5,703 FRAC,5,610 PERF,ERP. 5,710-5,725 i PRODUCTION, 255,507 - w TO,6,520 i CASSIN •• • li HARRISON BAY LOCATED WITHIN PROTRACTED SECTION 28, T. 12 N., R. 1 W. "''"" UMIAT MERIDIAN, ALASKA ------ 1106' FSL 1502' FWL Y AREA tre fir,#4+/. NAD83 Datum NAD27 Datum � �r 1, % ,% N 70°21'38.6" N 70°21'39.9" I• - - , ti W 152°09'49.6" W 152°09'38.2" + �� `' 1 4% . ;: ASPC ZN5 ASPC ZN56- !FTrt� (Y) 5,984,784 (Y) 5,985,068 - w 'P14 , (x) 1,866,432 (X) 726,412 � VICINITY MAP a � O Z Z v N N N \cC P PO ��M1�5 0 0 O d 1J • \--- P L -1111, 01R CASSIN #1\ '� 1502' 10 % H ---c,,pc; /\ 0 \0 0- 2 0 200 .)0III o, SCALE IN FEET O V, 500.0 0(P 0 o \J iri 0 is z ,0,00 00 2i N N I m 1106' X w Q S Li 0 ( \ in SEC. 28, T 12 N., R 1 W. O SEC. 33, T 12 N., R 1 W. / O 'Z N W z Q Z REVISION 2 13 z 3 KU U K P I K 2012-2013 NPR-A EXPLORATION CASSIN#1 ca PROPOSED ICE PAD CONFIGURATION a .. ALPINE, ALASKA rte+ 0 139E.51st.Ave.•A,ohorage,Alaska 99503•(907)27318330 DATE: 01/09/2013 DRAWN BY: AG SHEET: 1 OF 2 0 Alpine On, (907)8]0.4]39 0 Alpine Survey Office SCALE: 1"=200' CHECKED BY: DB W.O. No: 12-08-05-1 a ` Cassin 1 PTD 2 .-182 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska i . ' . n" p coin" ,1 r 4 \ \ -- --- .....,') m. aq 1/4 A � T n co U .� c � � O co •L - 0 � Q 0 ( O o_ .- U0 � oc- o r CL x c4 o o o 0o � oo5U Uco O o ,44s � . . �'L Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cQJ a - 1 gca Well History File Identifier Organizing(done) p(iwo-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: /dor Items: /Maps: ZWP aX yscale Items: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: c.J Date: _ 0 /s/ u • Project Proofing BY: 41:12. _ Date: Jr' 1st h� �- 9 Scanning Preparation 1 C) x 30 = 3 ©O + (p = TOTAL PAGES 3 d 6 (Count does not include cover sheet) BY: diElb Date: a • s' /s/ r r f Production Scanning Stage 1 Page Count from Scanned File: 3 0 (Count does include cover sheet) 7 Page Count Matches Number in Scanning Preparation: V.ES NO BY: CD Date: Lf/c297/S' /s/ r r l p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 411) NO TOTAL PAGES: q� Digital version appended by: redith Michal Date: i//s 0 /(S /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3, ..3 Scanning is complete at this point unless rescanning is required. 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CD mlz 7 Cco V1n c) rn N Z Z > D D w CI fa 0 0 1 o Release of Confidential Data Coversheet Well Name: CASSIN 1 PTD: 212-182 E-Set: 22392, 22564, 22565, 23025, 23026, 23297, 23298, 25154, 25426, 25596 ✓ Physical data labeled with PTD, E-Set# Conf. entry: Various ✓ Import CD data to RBDMS via GeoLogs tab V Confidential (incomplete)entry in Well Data List notes /Import to DigLogs via E-Set tab //Scan labeled data /Apply OCR text recognition L5",Save to Well Log Header Scans CV New"complete" entry in Well Data List notes Logged by: Meredith Guhl Fully logged: 4 / 29 / 2015 Guhl, Meredith D (DOA) From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Tuesday, April 28, 2015 12:28 PM To: Guhl, Meredith D (DOA) Cc: Brown, David W. Subject: Status of Cassin 1 and Cassin 6 AOPA is aware these wells will release shortly. We applied for tax credits on these wells so are aware they will release under the 25 month confidentiality parameters. Land Manager David Brown confirmed this to me today. I know you were waiting on a response from drilling, but David Brown's response is definitive. Thanks for checking with me when I did my data delivery this morning. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com 1 ConocoPhilli s TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,ATO3-346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7'h Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 04/22/2015 Transmitted: J North Slope, NPRA, Alaska cCassin 1 (501032066300) Ii 1 Color print each _Cassin 1, Halliburton WaveSonic Semblance Analysis; processed 3/1912013 2Z 5 io 5 tl }I� f IpIff 11 *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan,and e-mail to Sandra.D.Lemke6iCOP.com CC: Cassin 1 -e-transmittal well folder RECEIVED Receipt: ('("-�y Date: APR 22 2015 AK/1T-Technical Data ManagenAgLi1tQchillips I Anchorage, Alaska I Ph: 907.265.6947 Guhl, Meredith D (DOA) From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Tuesday, April 21, 2015 11:35 AM To: Guhl, Meredith D (DOA) Subject: FW: Cassin 1, PTD 212-182, Data required Attachments: Cassin 1 Rotary Core Descriptions_cor.pdf; Cassin 1-AOGCC_RSWCdescr WatersPET.doc Onshore exploration Manager Renee Hannon has release Cassin 1 and Cassin 6 from Confidential status. Please find attached the Waters Rotary SWC descriptions. We are working on printing a color copy of the Semblance log which I will hand deliver to AOGCC when its ready to go. Attached is the transmittal for the RSWC description data. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, April 16, 2015 12:39 PM To: Lemke, Sandra D Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: [EXTERNAL]Cassin 1, PTD 212-182, Data required Hi Sandra, I just completed a pre-release review of the data submitted for Cassin 1. I only found two items that were missing. 1. A paper copy of the Halliburton Wavesonic Semblance Analysis log (electronic file: CONOCO_PHILLIPS_CASSIN_1_SEMBLANCE_220_6475.tif) 2. A digital copy of the Rotary Core Descriptions as supplied by Waters Petroleum Advisors(geologists Doug Waters and Rick Liotta) per 20 AAC 25.071. Because the well is still confidential until April 29, please supply the digital copy of the rotary core descriptions on a CD with the copy of the log listed above. Please provide the two items by April 28, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov 1 Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 0! a-/82- �559 <7 ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 04/21/2015 Transmitted: North Slope, NPRA, Alaska Cassin 1 (501032066300) digital data via email Cassin 1, Rotary SWC Descriptions, Waters Petroleum 5210-6194 and (.pdf format) *The information provided hereunder by ConocoPhillips Alaska, Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). 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I only found two items that were missing. 1. A paper copy of the Halliburton Wavesonic Semblance Analysis log(electronic file: CO N OCO_PHILLIPS_CASS I N_1_SE M BLAN C E_220_6475.tif) 2. A digital copy of the Rotary Core Descriptions as supplied by Waters Petroleum Advisors(geologists Doug Waters and Rick Liotta) per 20 AAC 25.071. Because the well is still confidential until April 29, please supply the digital copy of the rotary core descriptions on a CD with the copy of the log listed above. Please provide the two items by April 28, 2015. If you have any questions, please contact me. 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U ao45 a t m aa) a) m aa) E oa 0yOQ0 0 a) O o a 00 D _ c d 0 d 0 I U 0 a 0 M O 9 c Na O 00 M N co O a. co Z to N Q eq 0 OI b v = 0 3 z F. a J_ p V U Z 0 iii rN J co 0 C Q N 0 a v CL J W Ce a 0 U W z J V V O Z 0 Q E N 7 a to O coM C o C O a) N a pp 0 o Q a _M O 2 co N W N M id N 0 Q U o Q o z o 0 E co z 3 M L co 1 N > m CO H e N 3 N N N cc D CV 0 2 co A U a_+ (7 a • 0 E O a 0 Guhl, Meredith D (DOA) From: Decker, Paul L (DNR) Sent: Tuesday, April 07, 2015 10:46 AM To: Guhl, Meredith D (DOA) Cc: Shellenbaum, Diane P (DNR) Subject: RE: Cassin 1, PTD 212-182, Due for Release 4/28/2015 Meredith, The Division of Oil and Gas has not received a request for extended confidentiality on the subject well. Thank you, -Paul Paul L.Decker,Petroleum Geologist Acting Director Alaska Division of Oil&Gas 550 W.7th Ave,Ste.1100 Anchorage,AK 99501 (907)269-7493 paul.deckerPalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Department of Natural Resources(DNR),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the DNR is aware of the mistake in sending it to you,contact Paul Decker at(907) 269-8791 or paul.decker@alaska gov From: Guhl, Meredith D (DOA) Sent: Monday, April 06, 2015 9:04 AM To: Decker, Paul L (DNR) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Cassin 1, PTD 212-182, Due for Release 4/28/2015 Hello Paul, Has extended confidentiality been requested for Cassin 1, PTD 212-182, due for release after 4/28/2105? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, April 06, 2015 9:04 AM To: Decker, Paul L (DNR) Cc: Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: Cassin 1, PTD 212-182, Due for Release 4/28/2015 Hello Paul, Has extended confidentiality been requested for Cassin 1, PTD 212-182, due for release after 4/28/2105? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.Rov. 1 -k2-‘4:g2 2542 , RECEIVED ConocoPhiliaps FEB 1 8 2015 TRANSMITTAL AOGCC CONFIDENTIAL DATA DATA LOGGED 2/L /2015 FROM: Sandra D. Lemke, AT00340 TO: Makana Bender M.K.BENDER ConocoPhillips Alaska, Inc. State of Alaska, AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Cassin 1 Permit: 212-182-0 DATE: 1/27/2015 Transmitted: these files constitute the final datasets of geotechnical data due to the AOGCC on the Cassin 1 well North Slope, NPRA, Alaska Cassin 1 (501032066300) Confidential under AS43.55.025 CD/digital data 1 folder(2 .xls files) swi NMR Raw Data 1 folder(2 subfolders) JPEG LOW Res; TIFF high Res; plug end trims 1 folder(1 xls, 1 ppt) SWC photomicrograph descriptions and SWC photomicrograph images Explanation-arrangement of data in Point count files from Sample project(.doc) Te Swi NMR version 2 (.xls) TE Swi (.xls) Combined rotary core data 7-8-2013 (.xlsx) Grain size data (all samples) 8/2013 (.xls) Point Count data (all samples) 8/2013 (.xls) (see detailed file name index attached) *The information provided hereunder by ConocoPhillips Alaska, Inc., as Operator of the Bear Tooth Unit("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@COP.com CC: Cassin 1 -e-transmittal well folder ,o-e4tte: 7-4)74 -a - (</IT-Technical Dath Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 . • . . , , • 0._ 1'. IT ,..... . . . • • 00 . ,..,............, ',.9 :,,,'.:•::::•:'' ._.. 2:..t';,,,,•: o• = 0 0 0 ai ,S. 0 O 0 0 0 0 = ' Cr, n n n n n to -9 Lg .,.:4 O 0000 M 0 •-=. iZri ' f. '' -0 "IM -1:7 -0 -13 q F;• 7 3 1 4, . :.-_..• =_ :::,_.:,....: =.: __ 12 0 D.- . . -= -i5 -5 -5 -6 r's• — 1 — , 1--; vi 4., ,..4 4., ,..4 Q CU -ID z 1 0 -... .0 _ n n n n n ,-, -,- c ..1 0 Di CU Ea CU DJ ',..., '..-• up — c.', - in vi ...,1 4.1 vi al 41 1 PO I , 5 0 0 0 0 . = Di -Ti c) co co co '"V -, — 9_. Fa i i i 2, 3 , .i Q PI . rlo ri- m a, al Cr. ri- . 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' • •"-- ' . • AP CP -0.... .1....3 lst '"1„.. ....I KJ ....I ,r-.. CO Ka 1.1.1 tp 1...n u.:i 01 CO 'A A A A A A :;:, • • .31141 03• g0. 03 03 03 cP .... . ....... . , •— ,e' -.•;W! •`P-".• : . -1.:.&: 1. I !..-.a r 0� V CO iel;p s 501032Ogg300) Gassin 1 . 212'1 8 2-0 Exploration pern it Cono°PhiipAlaska Data AOGGC copy Subraittal CD 1 01 1 JanuaN 27,2p15 u A-,` -0Ypv-' sands-- Management Sandi 6947 eQConocophaiPs•com l Data 907. - Renk DSR-Division of iand Sandra. Submittal Well Data G&G Data vi res), 'Technicalhi and l0 end trim Photos(hi tions, final deliverables and d�ombined rotary R RDW Plu h images p otomiTeSS?N�R version sire and point e data,all sample grain core es count 4-t--&ee, Ccpi 2_5\5`-1 ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 74'Ave, Suite 100 ED Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE; Cassin 1 DEC 11 2014 Permit: 212-182-0 DATE: 12/09/2014 AOGCC Transmitted: I North Slope, NPRA, Alaska n Cassin 1 (501032066300) pn CD /digital data 8 Sample analysis, petrographic data,frac report, well tests,Whole Oil Geochem, PVT analysis/report; i; 8 folders, 3 .xls files, 3 word dor, 1 .pdf 11 Detailed files index list attached to this transmittal. i *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke000P.com CC: Cassin 1 -e-transmittal well folder Receipt; 122 ` / • /k , ,.c -: + A IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907265.6.94/ ifo Pc r �q o I� bc '1e Pc "lC .e MITI r • r y in 0 D 1^ O o < V K Q 0 0 70 O < r, f o ? 7C n v, 3 a n c o m o n .?, o n o Ia tp- 1 3 0 •o n C N C n -a' 4 p J 7r F C� O �' N 7 7 n 0 7 a Tr n N 3 0 o M n ID �+ a n 7 a d M a N f^ 7 7 y, w o n D o v3 O `1 N 1n I, 4- 0, I n Lc, l Lc, _. .. 1GLG ,y1, I 7- n n n n n n n n n n n vI n n n O O 0 n n N n a a a a ^ a a 0, ^' -0 C -D L1 N , N 4� N N 1H - V1 N N_ 8 8 8 7 7 7 7 0 7 7 7 3 7 7 7 r+ a+ r+ r N r N N V F+ 1--, N 1-4 N C C C r� I� IN 1� 1 IW rN 1� r� a, O o S tt ,o 0 3 v = = 0, 004 x _, b, S o n n » n w 0 0 5 n X v'' ° • ' n T -(se n 1� m v� V 03 mo < F p i i n j� N S 1 n o c a a a. v, C O x w Af0 a ?. m 0o CO 0 n v 33 A `'. - a 0, n 7 }0,S }0,S S S c a IS 0 01 N 'd 0 S a p 6 O © cSn 6, j n' '- r" r., % a W W .. 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O 00 a) a ' Q. 01 co N - ID a 0 -o in y v no -o 0 5„ K S nn 7 i- n S S > T T T 7.1 .. n n 0 0 n' n� 0 n' n' 0 0 0 T 0 O 0 o Ts -o o .0 !.0 O O 6 o 0 o 0 n 0 0 0 tel m m 0 0 0 , C a a a O O O a a • a a n' r' 6" a a s N N, n :'ry '',N n T ,a„ v m r r r Iv W '0.+ r V, w 8 u' i- w `8' E `oo, w 7C 7C 7C 7C 7[ 7474 7C 7r 7C 7C CO CO co co 03 co i co co 07 07 03 r /. 1 aNad No O 0`t.'n'9 v o 3=n r cots an 1. % am C n m G Q 0 ^ 3 l' 3 IT -*` \ �� 3 7. zilaa-t) H )1 a. i 0) N woo 04- 0.'" -s', , W ,...• W. V' N O Q -21 Ca SD Sts STATE OF ALASKA 'l ALASKA OIL AND GAS CONSERVATION COMMI.,0ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon t— Repair w ell 1— Rug Perforations (— Perforate (i Other fi Remote Site Alter Casing (— Pull Tubing (— Stimulate- Frac WaiverInspection f-- E Time Extension J`" Change Approved Program I_Operat. Shutdown f— Stimulate-Other E Re-enter Suspended Well f- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory r 212-182 3.Address: 6.API Number: Stratigraphic f— Service P. O. Box 100360,Anchorage, Alaska 99510 (` 50-103-20663-00 7. Property Designation(Lease Number): 8.Well Name and Number: AKAA081754 Cassin 1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Wildcat/Exploration 11.Present Well Condition Summary: RECEIVED Ii Total Depth measured 6520 feet Plugs(measured) 5354' OCT 3 0 2014 true vertical 6513 feet Junk(measured) none AOGCC Effective Depth measured 6419 feet Packer(measured) 5045, 5323, 5598 true vertical 6413 feet (true vertical) 5039, 5317, 5591 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2350' 9.625" 2378' 2378' Production 6482' 7" 6507' 6501' Perforation depth: Measured depth: 5258-5273, 5535-5550, 5710-5725 True Vertical Depth: 5252-5267, 5529-5544, 5704-5719 Tubing(size,grade,MD,and TVD) 3.5, L-80, 5704 MD, 5700 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 5045 MD and 5039 TVD PACKER- BAKER PREMIER PACKER @ 5323 MD and 5317 TVD PACKER-BAKER PREMIER PACKER @ 5598 MD and 5591 TVD NIPPLE-CAMCO DS NIPPLE @ 525 MD and 525 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory I✓ Development I Service E Stratigraphic I 16.Well Status after work: Oil I— Gas 1— WDSPL I— Daily Report of Well Operations XXX GSTOR I— VVINJ I- WAG f— GINJ I— SUSP 1' SPLUG E 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: none Contact Tom McKay (, 263-4980 Email Tom.W.McKayconcophillips.com Printed Name Tom McKay Title Principal Drilling Engineer Signature477AA,,...., 980 Email Tom 263-4980 Date Form 10-404 Revised 10/2012 6141 ///aVef Submit Original Only/01 � \\ ei �y R�$C S OCT 3 1 2(114 NieffiWED OCT 30 2014 ConocoPhillips X00 Box 100360 Alaska 99510-0360 October 29, 2014 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Well Inspection 10-404 Sundry Cassin #1 (Exploratory Test) Surface Location: 1106' FSL, 1502' FWL, Sec 28,T12N-RO1W, UM X=726,412 &Y=5,985,068 ASP5 NAD27 Target Location: 998' FSL, 1594' FWL, Sec 28,T12N-RO1W, UM Bottom Hole Location: 102' FSL, 1578' FWL, Sec 28,T12N-RO1W, UM Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a status update for the field inspections of the Cassin #1 location performed on various dates in 2013/2014 as required by 20 AAC 25.110. Please find attached the following information: • The following inspections have occurred since the well was suspended in May of 2013: o Stickpicking took place at Cassin #1  from 7/4-7/7/2013 and again on 7/22/2013 at Cassin #6- no anomalies noted. o Downhole gauges were read on 7/19/2013 and again on 7/28/2014- no anomalies noted. o The NSB inspected the Cassin locations on 8/31/2013, but did not land-flyover only. • In addition the BLM performed surface inspections at the Cassin #1 location on 9/21/2013 and again on 9/3/2014- inspection reports attached. • The"as-built"plat. • Aerial photographs taken on 8/27/2013 and email reporting no anomalies. • The wellbore status has not changed since filing the 10-407 Sundry. • The 10-404 Sundry Sin erely, . A"'7 om Brass e d Consultant Drilli g Engineer for ConocoPhillips cc: CONFIDENTIAL—Cassin #1 Well File REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 2/23/13 CZ GD TB ISSUED PER K130003ACS 2 2/24/13 CZ GD TB UPDATED PER K130003ACS � •1 HARRISON BAY_ AkeZ,NOTES: l� _ RIVER �� �a' ,..=:A "�' UNI Ni, i 1. BASIS OF COORDINATES:OPUS SOLUTION ° SRO QCT .n -t �°� .) OF GPS STATIC OBSERVATIONS 2/11/2013. 2. COORDINATES ARE NAD83,ALASKA STATE SI r >i. \ PLANE ZONE 5. 11 -cY WO . .d �id►.L2- ,�. 3. ELEVATIONS ARE CONVERTED FROM OPUS NAVD88 ' IF" IF 0' ,: ,„ Al, ;It `D + .i j� s TO B.P.M.S.L.VERTICAL DATUM.(-3.5'±DIFF.) ° a"' 4. DISTANCES ARE TRUE. ALL DISTANCES ° ( !1'lin `1 0 M K c `' ,f 0 • +' 4 ` AND ELEVATIONS ARE IN US SURVEY FEET. �" a 1M� WII 11 ;y GACA r{A �ij; r>2 5. DATE OF SURVEY 2/22/2013. ►‘y'u l ° 1 4 ++ h �" 1 ,*11O � OQ �o s C3 o Q i 161 KUUKPIKo ° � I j DOSES # f?t:1111��'�« t p �f Qit74:2 ;,I o� • • LLC • UNIT 011:7 Cdr e 4It.4c 1 139E.51st Ave.•Anchorage./Cake 99503•(907)273-1830 I ,'� NPine Office (907)670-4739 V `• e) Ott . i #.' ° a - f ,z,...Alpine Survey Office Vicinity Map NOT TO SCALE PREVAILING WIND CASSIN 1 Z2LOCATED WITHIN PROTRACTED SECTION 28, T. 12 N., R. 1 W. Z Z \GE P PO \\1JZ5 o GU�P jGs UMIAT MERIDIAN, ALASKA 1105' FNL 1502' FEL CV N C'' ,pop GND ELEV. = 71.2 BPMSL 1-- 1.- ICE PAD ELEV. = 74.1' BPMSL of % TOP OF COND. ELEV. = 74.28' BPMSL N N NAD83 Datum NAD27 Datum c3 do / `Lo ui " In `\� N 70°21'38.598" N 70°21'39.902" W 152°09'49.601" W 152°09'38.175" 1502' ASPC ZN5 ASPC ZN5 200 (Y) 5,984,783.988 (Y) 5,985,067.782 id 0M (X) 1,866,431.991 (X) 726,411.844 R\C�P' -5CASSIN #1 N 0.0 0. 0 0_ 0 6000 o LCMF E -0 .13d ``,, N 13 1105' a j> 9 n(,,tP tP 0 • • 200 • • • SCALE IN FEET SEC. 28, T 12 N., R 1 W. SEC. 33, T 12 N., R 1 W. )IIPV !ALPINE MODULE:APO() UNIT: AP C.noc.Phillips CASSIN 1 EXPLORATORY WELL CONDUCTOR Alaska, Inc. AS-BUILT LOCATION CADD FILE NO. DRAWING NO: I PART: REV: 12-12-15-1A 2/23/13 CE—AP00-1118 1 OF 1 1 2 Brassfield, Tom (So!sten XP) Subject: FW: Pictures of Cassin locations From: 2L Pad Co-Man Sent: Tuesday, August 27, 2013 6:35 AM To: Brassfield, Tom J Subject: Pictures of Cassin locations Tom, Here are some overhead pictures I took of the two Cassin locations, they are really clean. Jim Cassi 1.JPG Cassin 6.JPG CassintII.JPG Cassin 1!II.JPG Drilling Special Projects Dave Chapman/Russ Bybee/Jim Holley Office: 659-7318 Dave Cell: 659-0535 Jim Cell: 943-1035 Russ Cell; 232-0907 1 } j % ulco / 0 CO \ ? . / \ } ` I d c C k 7 _ C Ca = -..c7;. 4. 2 . LI Ce. < • c y. < C / OCa : " o c C = e 60 as y» c c w , 9 - 4 2 2 Cu Ea • n ? 1 12 tl: E L c o ID c o LI L. . ,@ _ ¥ o o - > 3«© � S c, E � « � � o L m E \ y ..,. :2, c � O x . :,. y < . o au ' 2\ « . U •- c 9 / \:/. % : . Aw to ..c \ . . .roi . » . < . . . : \- . . . . . t '• .r , " ' 4 , , fr$ , ,4 , fr ..»". j . P •, '''''• .c 2 03 ; .: , ' ' 1 1 1 • 6 E— 6 03 — CD M .L,'. • , '--r. f Itt(31 • A (.3.. f„.. LL ..= CL •- • .3: h 0 .L....f. o_ a :15 0 = = 0 • a ri C. 43 .C71 CU ÷E. ....r.' 4:' ct>. rj fY3 Li c) ,,...= u... •,_,.. ID (#) 0, s..... = „, 0 -8 c Lt: CD „c 43 • C tl. 0 X C ID 4 i BLM Arctic Field Office Surface Inspection ConocoPhillips Alaska, Inc. Cassin 1 N70°21.720 W152° 09.949 September 3, 2014 A surface inspection of the Cassin 1 well site was conducted on August 26, 2014, by Donna Wixon,Natural Resource Specialist with the Bureau of Land Management(BLM)Arctic Field Office. Cassin 1 was drilled during the 2013/2014 winter season(see Figure 1 USGS Topographic map for the well location). From the air,the former winter ice pad location is now barely discernible from the surrounding tundra(Photos 1 and 6). The vegetation on the pad has improved greatly from the 2013 summer inspection. That inspection found the pad location quite prominent, as a large brown area of dead vegetation. The vegetation has turned to fall colors and cotton grass is plentiful (Photo 2, 3 and 4). Many of the scuffed tussocks have vegetation sprouting(Photo 7, 8 and 9). The powdered area noticed in July 2013 is no longer visible (Photo 1 and 6). The only debris present on the well pad site was a single, small piece of wood(Photo 9),which would have been easy to miss in 2013. The wellhead and cellar are securely covered with plastic sheeting(Photos 2 to 5), as required by the Arctic Field Office stipulations. The plastic sheeting appears to have more bird droppings present(Photo 2 and 6) than in 2013,which could indicate perching by birds. There are no visible tears in the sheeting. The well head and cellar are intact, and no standing water is present. Overall,the site appears to be in good condition with no issues requiring action. r , J ra Photo 1: Northern Aerial View of Cassin 1 Well Site Cassin 1 Aug 26, 2014 Surface Inspection Page 1 of 7 • • 08 26 2014 00 :,40 Photo 2: Cassin 1 Wellhead and cotton grass d •, amu, x�" J _ ..-.. � <. 3;,€ .4.;r., • 0 n A Cassin 1 Aug 26, 2014 Surface Inspection Page 2 of 7 Photo 3: Cassin 1 Well Cellar and vegetation • • • F F x {xi Photo 4: Cassin 1 Wellhead Cassin 1 Aug 26, 2014 Surface Inspection Page 3 of 7 i ,f , i i 1 i 1 ..r `x ! . ,.0 F I.l fid • , ,. y w. ;fir 1 ; r A��.',.�'^ �,,w,. ♦� , ' • 08. 26 . 2014 00. 44 Photo 5: Cassin l Wellhead Cassin 1 Aug 26, 2014 Surface Inspection Page 4 of 7 _. _,T.,,I„.,,,:,,.::,;,,,o.,i,;.4.03.,,,,,...?,,i‘,.;,,:,:i,r,J,:i:,,,,,t?,,,,,,.,,,t,:,,,t,!,;;;31.:c7:::,,,,, ..,,, ,,, ,‘,. _____...iiiiiiiii40...„,r'', .;''',,,',''' ZIT'',''':-'''' ,.., , ' 08 26 2014 00 55 Photo 6:Northeastern Aerial of Cassin 1 a �, �� a � r . -, gid + t ,.".--1 :.-',,-,,,,,,,,v,--,. f -w40. - r t "'" ` , ii„ 4 HM '3 :' d ~r , i g ,'r. 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'L;°r ' ..."d •r: � : Photo7: Vegetation at Cassin I former ice pad Cassin 1 Aug 26, 2014 Surface Inspection Page 5 of 7 • ` ii. f }fes rpta' 1 ,yW m r ,gyp �a elle 1Xs�t ' < ,�, .y.i .�' .._ ... a: Photo 8: Cassia 1, scuffed tussocks with vegetation I IP ir 4 ' It ^ � l, t 's1' r , tli4LI{ \ I ! t.!;.•...,..,'4:!; _y - I J` ,io-� T� 9 6x' r- ' iiiitt 44 .^ .x ,r .t ` : ;•:,.. a ' yA !fl 6w 1'',,, ?.� i ,.', ` A<xIvIr rsc'u4 ' o�P �'"i '"..d I - • ,!*7`,:;...,02 " .ke 4-� '', ' ,�' f..7",, , y.. ,i _'—' J + - 'y .q • �3ta r -;--!....,..4u: ��^ ,m • ' ' ` r-Si':-74-:-.w:,..,-..1,:.. a4 r i 'y / r .& ��'a1 Y`" " a r .��ti , ' �1 \ d t 'aw 'a. 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( - • '. � �f -yX Is: '‘'''''''''i*:,1� ts •tiAt. !•,� yt 4'41"44,,,,t(- -- ‘' s` --4::40*. \ ' y '4�yP: ite-" / Li� .x , � ' (t > iS ' :e `4�•” «• a ;''*:. it).v, _ t,% `F �A +'jy. ,`,/,...,...„.4-...... ..P '114--- , 1 .� ly1.a / ,44p, t - L.,‘"..:441t, K y� ",le• ;,J2a i ;, 1 ,«, r °1 - ' 7 f:d ,v$. it "T 7 � � ) r) f cx • ti , \ .. �<. ` •v ' .n.g , , ` sz \ �'at � f 4. : ...:‘,-4,-;,...1, . ted * i �...is Cassin 1 Aug 26, 2014 Surface Inspection Page 6 of 7 Photo 9: Cassin 1 Former ice pad site with remnant piece of wood -, AN Kalikpik HARRISON NAT,R.i OUAORAMLF. /f .•- DAPANTIAEHI OF THE I7R101 OEOIAOICAL BURVM I.F F.N1.!(fO1SOR.PW� 7--" 'if s',t e ?- 1r'y,P„r.i \---7 7.,.,, !9 i �.viz , ... 7 ,, 1 A� s N 39yn` 1.jy __ J n .y% t- • \}�, rad .:.�� �, 0 7 Y .. d `-_`•'"� a go 4 q y t4 t . •i'''.+1*.\•V-tss•-•,‘",ti•\.. " j(ll _��_�t Li. c l �r j.t.44•' � f ,b$ °ie�, x',P • my '. I i. i 1 � t i- nn H [ iryF 1 oCassm I i r 9' � I J i • f,,. , r. t A 1 1. _, RFa l� � +� + t,._ F t :� out;r- 1r ' i2 Conoco Mld ' _ . . ' r V P a 3 '. I. it''' i r. 14`� - ' ` x� -A } .' !•^ i at' a +44,11 T.-Y-11.1 M s`- c w , yi1A '"• o Moose s Tooth C j� = r t». Carbon a ..... r 'Harrison Bay 8-4 63K;AK';Scale:1'=2.067Mi 3.327Mt 10,916Ft,1 Mi=0.484",1 cm m 1,31OMt Figure 1: Harrison Bay B-4 Alaska Map showing the location of Cassin 1 and Cassin 6 Cassin 1 Aug 26, 2014 Surface Inspection Page 7 of 7 BLM Arctic Field Office Surface Inspection ConocoPhillips Alaska, Inc. Cassin 1 N70°21.720 W152° 09.949 September 21, 2013 A surface inspection of the Cassin 1 well site was conducted on the afternoon of July 16, 2013, by Donna Wixon,Natural Resource Specialist with the Bureau of Land Management(BLM)Arctic Field Office. The site is visible from the air as a large rectangular brown area, an indication of dead vegetation(Photos 1 and 2). BLM was notified that the operator(Conoco)had conducted their stick picking activities prior to the inspection. However,upon arriving at the site it appeared that while stick picking had occurred,they had left piles on the pad to retrieve at a later date. The piles were viable from the air(Photos 1 and 2). Dead vegetation is prevalent(Photos 1-5, 9-12) resulting from the winter ice pad compressing the vegetation on the pad area, however, some green vegetation is sprouting(Photos 5 and 6). There is a visible difference between vegetation on the pad and vegetation off the pad area(Photo 10). The vegetation near the wellhead is starting to green up (Photo 7 and 8). The tops of the tussocks for the most part seem to be intact. As I walked around I did find small bits of trash,pieces of sticks,which I picked up and put in the trash pile. There was also a gasket of some kind on the tundra(Photo 4),which I placed by the trash pile (Photo 5). There was an area about 8 foot by 4 foot wide that had what looked like some sort of a powdery substance (Photo 3) on the surface at the eastern edge of the pad. There were a couple of cigarette butts on the ground(Photo 12). The wellhead and cellar are securely covered with plastic sheeting (Photos 7 and 8), as required by the Arctic Field Office stipulations. The plastic sheeting has a very small amount of bird droppings present, which could indicate perching by birds. There is no standing water present near the wellhead and no evidence of trenching. The cellar is in good condition. The site was overflown on August 29, 2013 to verify that the trash had been removed, but no photos were taken. The white,powdery substance that was visible during the earlier inspection was not visible during the overflight. The site appears to be in good condition with no issues requiring action. Cassin 1 2013 Surface Inspection Page 1 of 8 Powdery Substance Trash Piles Cassin 1 Wellhead ,,4 j Ye4 . Photo 1: Northeast aerial photo of Cassin 1 L , %. Photo 2:Northwest aerial view of Cassin 1 Cassin 1 2013 Surface Inspection Page 2 of 8 , r v '^ i. ' .r *fir t:'? .i53k a ,,• 1, .r. .;;).?..,',41:,o ° a " a ti arm'• -,,,,470-L,.. ef s _.---...fr.---- .' ' � i z{ .: t � t��� i r �•• �r rsz xr � .� � rN"y3 ¢ 4# y � � k;� > � Wz ��rrtrt ! n - .. • 4 .i. t v !• i + \, . � .,, ,„,i ,„ . £'' w f ;C4e.i ' „S ;.4- x ' s, 7,4 ),,,\, .),..4:---. *s c �r ..fiv i ftr r �N ^1. /� ` - F ,ap � , ; `,lf, .r ' Vt , - ....i.,_,,,,„,..„,, Sk :f ` ' 1p t ,,,, n":xl �t=,; i, , 1� i*`, r' 0.. 'i` ,,- { ,,r + R �,4. 4 ., rz ,r -, 7 ky � i ' � s' h '„ Vm,..-G ^r< It' lam, r�*rt , 6 fI ° `35e y ...,,iii- ;vf' 4 q 44'''''';'.0 '+.of ,W, :"..7-,` -''.`2":"-:i.:=!!"4,,-..i.1'y , { t7 tik, ‘i.! 5' 1 b ,,Y V Tis ..-,%;,,--, -,.,,:,,r "+, / „....„,,,...e,,` 't.•.;‘,. y� ”' ``l€ rkw a * ♦ +',�:y l -44 k7r ffi r 6 >.�=':•.:'<';'^».-'''''..:,..."-; w, 04 *r' Ri � 4 r �1 ...a."Attzyg ''r T.� pii...' "'C�tarEyb r•.^,e+'1 11 '.( t^ 4} .5,0 , s,'lra.. ... � '' i„. ..,iEIY .:R -. Photo 3: Powdery Substance at Cassin 1 • S, S. „n .,-....!;,-,..,7':' fir .o.ti ,c J • •�,a.. rF.>...:�- kr .-:„•7"--,7‘ n: r..+.:`. ..-4, ,#iy.. +w"' - „ !,- .s r a .,any , ,.,� ..140....,: ,a'95°. r. { + w r`+*4#rr � ,4r. a t"'•p9 ?1". Y "' ''' r , _ kms A'. - �� t x a '° , -s ... ° ", >' ..7:-.4 's�k. w4 44 ,asyt a4,` . 0 - 7yQ9Aa rt•'-'' b 4."'-.14,11".1='. X44 �,,, , .,,: >; ,.s)Y!'fr 3Ft. , I f ` s. �. ' *wa cAAr r vex ) +r.. ':,:-.4,- -.4-•,...--,..'.4,7: d{N Ms, rr '' ` ,,,4'.^". 7, i s� ,41a a y.f r . Ir ‘V:''''' r`"'''''''''"7-t.. z,,,,..-4,,,,, .474;:44'mN'JL^ 3 :1`..'1,-i� f' -. k -,•+u x``44 1'� 4 ii Y'� bh»E..:. 7. • .rh. .r \ y 'a'l ,....".475- l'F . , i }:kw•\ A ' t"'_` :i• arly '-',..,7; t vf� -r*1`.. _ k..-C ^��,�y+�k'' ` `Y:. �.: ^.4t ! } ) ,'� +�+_ :,' CJS ` ti : ' ` .• - t r ytr ,, ',"If �.1 .$�" R V .+ani `, 1 � 4.-......r,,::' _ r r r s " h T '''.5 y • "4,"'t �t ' A` -y-,,....--.- --- i� ` � -t u;a � t .K ✓ - r `+ y w :,, q a ti K' Photo 4: Dormant Tundra,broken stakes and gasket at Cassin 1 Well Site Cassin 1 2013 Surface Inspection Page 3 of 8 :*•,14-„ xa„ " w. ' "3 +* - 'r :, •F `-d� ,axon^ i n { „Ara . 1,17,. i w' 1:,✓ �� �"'"x, .. _„ Photo 5: Scuffed tussocks, trash and well head at the Cassin 1 Well Site. • • x ic 201'i 04 '20 Photo 6: Greening vegetation and wellhead at Cassin 1 Cassin 1 2013 Surface Inspection Page 4 of 8 ill i N / N p Y � t it ,l O N • CO qr— I sl0 x'.0, \,,,,..,,,,N,.1,., , : ti It s xs` , IL. _ •p rte' ti y P '-47.::-4'''..„1.-: ,4„:‘,...- it '.r w ► ZT ry , &/s 4 h --1' 'iiiF ;it 7- x�'p ✓:Y*.. :•,'-'":,/p y 4 �s: r�k ,,,ry 11-, w\.� Photo 7: Cassin 1 cellar, scuffed tussocks with greening vegetation. Cassin 1 2013 Surface Inspection Page 5 of 8 /10 fl f 07 . 16 . 2013 04 : 22 i J�jJ.-- Photo 8: Cassin 1 Wellhead secured with plastic sheeting. Cassin 1 2013 Surface Inspection Page 6 of 8 ✓"i.. Yom.'�� a r.'. _ .. - .. - E ..5 [ r � 3 � � tiT � Y F YH . Photo 9: View of the Southwest portion of the pad. x � w - 0716 . 2413 044.4, 4401111116q4 - Photo 10: Distant Green is located off the Cassin 1 pad area. 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'4,-;" ." ;z�eP i r ts;-v - -' r"_�4k e,1�•e. ; ` .. aY y >, k '•r' • f ,`; y�.,y - nr a 3' ,hn! .•ra>, ey ...r r`fd!io B .x `=+ivs i' +.Y r \ M r '�: l''I t''. a �d ,� i.r �. n` r q ao 1� r,� A �':-k,-A• .. a k r AI 94q '�,:,7•44,444. b,Y � �`�� .�-. ".",�A'4�F'- :,C ca... • Photo 12: Cigarette Butt and broken stakes. Cassin 1 2013 Surface Inspection Page 8 of 8 Z1 Z- 132 23Z 7- RECEIVED ConocoPhillips SEP 0 4 2013 TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 09/04/2013 Transmitted: North Slope, NPRA, Alaska Cassin 1 (501032066300) CD /digital data and hardcopy print nal well report; mud logging data, Cassin 1, Canrig, 03/13/2013; distributed 8/22/2013; Table of contents, Equipment and crew, general well files, geological data, pressure/formation strength data, drilling data, Show reports, daily reports. Log prints: Formation Log (MD)/Formation Log (IVO), LWD Combo Log(D),`CWD Combo Log (TVD), gas ration log (MD), gas ratio log (TVDr, drilling dynamics(MD), drilling dynamics (TVD); /CD 1 contains daily reports, DML data,final well report, las files, log pdf files, log tiff files, show reports, CD 2 contains sample cuttings photos 2250-6480' and 'The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.LemkeCaaCOP.com CC: Cassin 1 -e-transmittal well folder Receipt: 12/......../A/L4 Date: ( ) '7:1 AK/IT-Technical Data Management I ConocoPhillips J Anchorage, Alaska I Ph: 907265.6947 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, August 21, 2013 4:29 PM To: 'Lemke, Sandra D' Cc: Elgarico, Richard E; Okland, Howard D (DOA); Bettis, Patricia K(DOA); Heusser, Heather A (DNR); Clifton, Sean C (DNR); rebecca.isbell@anadarko.com Subject: RE: Final Logs -- Cassin#1 & Cassin #6 Sandra, AOGCC understands that the well log plots and digital data delivered for Cassin 1 and Cassin 6 are final, composite data for archival purposes that were inadvertently marked as being"Field" copies. These plots and digital data satisfy AOGCC's well log reporting requirements for Cassin 1 and Cassin 6. To prevent confusion in the future, please ask your vendor to avoid using the term "Field" when labeling final, composite plots and digital data for distribution to AOGCC. Please contact me if you have further questions. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Wednesday, August 21, 2013 3:40 PM To: Davies, Stephen F (DOA); Heusser, Heather A (DNR); Clifton, Sean C (DNR); rebecca.isbell@anadarko.com Cc: Elgarico, Richard E Subject: FW: Final Logs -- Cassin #1 &Cassin #6 Halliburton has provided COP with a detailed verification that logs previously marked and distributed in June and July to agencies and a well partner on Cassin 1 and Cassin 6 are final deliverables. Please consider the e-mail below as the definitive verification that the Halliburton logs delivered for Cassin 1 and Cassin 6 that are marked `FIELD' are indeed the final composited logs. Delivery of other data types for these two wells are ongoing. Thank You for your patience on confirming the status of these logs. If you have any additional questions, please call or e-mail me. Please also provide a confirmation return e-mail that you have received and approve of the final status of the Halliburton logs delivered to you to date. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,ATO 340 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.corn 1 From: Christopher Gullett [mailto:Chris.Gullett@Halliburton.com] Sent: Wednesday, August 21, 2013 1:31 PM To: Lemke, Sandra D Cc: Matthew Cook; Elgarico, Richard E; Smith, Kent W Subject: [EXTERNAL]RE: Final Logs -- Cassin #1 & Cassin #6 To Whom it may concern, Regarding the open hole well logs for both the Cassin#1 and Cassin #6, all logs marked *FIELD COPY* are marked so to indicate that they represent the raw field data just as it was recorded in the well. This does not indicate that there will be any future log or *FINAL COPY* to replace it. Other logs that were submitted include or use the information from the field copies to create or calculate new models and data, but are not replacement data for the field copy. For example, a MRIAN log is a product log using the field inputs from a MRIL log. Even though the MRIL log is marked *FIELD COPY*, the processed MRIAN log in no way changes the MRIL log. In all examples of both Cassin wells, every log marked *FIELD COPY* is the final revision of itself and marked as such to distinguish between actual recorded well data and computed modeling product log data. In the case of both Cassin #1 and Cassin #6, please accept all log copies marked *FIELD DATA* as the final composited data. No revisions are to be made to any log submitted with the *FIELD DATA* mark. Examples: WSTT(Field Data) =>Semblance and Anisotropy(Computed Data) MRIL(field data) => MRIAN (computed data) GEM/CSNG (field data)=> FAME (computed data) Please contact me if there any further clarification is needed Thanks, Chris Gullett Technical Professional—Log Analyst Halliburton Wireline and Perforating Anchorage, AK Mobile: 907-350-8453 Office: 907-273-3527 2 Ferguson, Victoria L (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Wednesday,July 10, 2013 8:31 AM To: Ferguson,Victoria L(DOA) Cc: Lee, David L Subject: change of status for Cassin 1 Follow Up Flag: Follow up Flag Status: Flagged Ms. Ferguson — ConocoPhillips sent the completion report to AOGCC for well Cassin 1 with a status of"Other". This is an oversight and the status should be "Suspended". We sent in a 10-403 Application for Sundry to suspend this well on 4/29/2013 and received approval on 5/7/2013 (sundry#313-206). How can we make this correction on the completion report to show"suspended" status? Thank you, Sharon 907-263-4612 1 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) 23 ZS` Sent: Thursday, July 11, 2013 5:29 PM To: 'Lemke, Sandra D' Cc: Bettis, Patricia K(DOA); Okland, Howard D (DOA) Subject: Cassin 1 Well Log Information Hi Sandra, I noticed today that many of the well log plots received for the Cassin 1 exploratory well are marked as being field copies. In 2004, after discussions with BP, ARCO/ConocoPhillips and others,the reporting period required by AS 31.05.303(d)(2)(B) was lengthened to 90 days for well logs and associated digital data to give operators and vendors sufficient time to compile single, composite well log plots and associated electronic files from all field runs. At that time, the operators agreed that 90 days was sufficient to allow generation of archival-quality, composite log plots, electronic image files, and data files. So,field copies are not sufficient to meet AOGCC's reporting requirements. Please submit final, composite well log plots and associated electronic image and digital data files for Cassin 1 and for all future ConocoPhillips wells and well branches. Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 RECEIVED JUL 0 9 2013 ConocoPhillips AOGCC TRANSMITTAL 2- Z CONFIDENTIAL DATA �� FROM: Sandra D. Lemke, AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave, Suite 100 2 ' Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 07/09/2013 Transmitted: North Slope, NPRA, Alaska Cassin 1 (501032066300) CD /digital data uburtorl a+grtai • ` _'_ XRMI, MRIL, RDT,CAST-M/CBL-M/ACE, WaveSonic, GEM/CSNG ,!liburton hardcopy prints- 1 each _XRMI, MRIL, RDT,CAST-M/CBL-M/ACE, WaveSonic, GEM/CSNG 'Al digital data- 1 DVD 7. 3 Y2_ BH-63452 EP Core Data 6-7-13_partial.xlsx(rotary swc P&P-8 samples) BH-63452 Rotary Core Data 6-28-13.xlsx(rotary SWC_P&P full set) ALL_GC_BH-63452_RSWC_Geochem 130627.xls (SWC geochem analysis) BH-63452_SEM descriptions_RSWC_proprietary.doc BH-63452_SEM_Images.zip BH-63452rXRD.xlsx(x-ray diffraction data) CS2 Extract GC_RSWC Geochem.zip(Extract geochem) lsotech Mudgas Isotope_revised_Job21250.xls (revised analysis) lsotech Mudgas Isotope_revised_Job21250.pdf(revised analysis) *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.LemkenaCOP,com CC: Cassin 1 -e-transmittal well folder Receipt: ALV Date: 7 �'• �� i1 AK/IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 G.L.Alvord �; ,v Alaska Drilling Manager ' �,fz f Drilling&Wells / 3 P.0.Box 100360 y L Anchorage,AK 99510-0360 ConocoPhillips AOGCC Phone: 907-265-6120 June 4, 2013 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for Cassin 1 Dear Commissioner: Attached for your review is the revised completion report for Cassin 1. Included in this package is the summary of daily operations, a schematic, final directional surveys, rotary core description summary, detail of testing rates and volumes, and a sampling summary. If you have any questions, please feel free to call me at anytime. Sincerely, 4 e. G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/DL/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . 'i;t 'J ',1i; WELL COMPLETION ORRECOMPLETIOuNREPORT IAND I,ky -acs la.Well status: Oil SPLUG ❑ Gas ❑ ❑ Plugged ❑ Abandoned ❑ en20AAC 25.10520AAC 25.110 a^'" 1`1Development ❑ Exploratory 2GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other C No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name. 5.Date Comp,Susp, 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband March 28,2013 212-182/313-072 ` 3 Address 6.Date Spudded: 13 API Number P.0.Box 100360,Anchorage,AK 99510-0360 March 3,2013 50-103-20663-00• 4a Location of Well(Governmental Section): 7.Date TD Reached 14 Well Name and Number Surface. 1106'FSL, 1502'FWL,Sec.28,T12N,RO1W, UM March 13,2013 Cassin 1 ' Top of Productive Horizon: 8. KB(ft above MSL): 102'RKB 15 Field/Pool(s) 998'FSL, 1594'FWL,Sec.28,T12N, RO1W, UM GL(ft above MSL): 74'AMSL Wildcat Total Depth: 9 Plug Back Depth(MD+TVD)• 102'FSL, 1578'FWL,Sec.28,T12N, RO1W,UM 6419'MD/6413'ND Exploration 4b Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+ND) 16 Property Designation Surface: x-726412 y- 5985068 Zone-5 6520'MD/6513'ND ADL AKAA081754. TPI: x-726507 y- 5984963 Zone-5 11.SSSV Depth(MD+ND): 17.Land Use Permit. Total Depth. x- 726521 y- 5984067 Zone-5 nipple @ 525'MD/525'ND 953096 18.Directional Survey Yes Q • No❑ 19.Water Depth,if Offshore: 20 Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1088'MD/1088'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22.Re-drill/Lateral Top Window MD/TVD XRMI/Sonic/GEM/SGR/CCL not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 28" 108' 28' 108' 24" 24 bbls AS I 9 625" 40# L-80 28' _ 2378' 28' 2378' 12.25" 277 bbls LiteCRETE,74 bbls Class G 7" 26#/29# L-80/P-110 25' 6507' 255' 6501' 8.5" 52.2 bbls Class G 24.Open to production or injection? Yes ✓❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number)- SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 5704' 5045'MD/ 5039'ND,5323'MD/5317'TVD, 5258'-5273'MD 5252'-5267'ND 5598'MD/5591'ND 5535'-5550'MD 5529'-5544'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC 1 5710-5725'MD 5704'-5719'ND Was hydraulic fracturing used during completion? Yes E No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED surface casing shoe squeeze from 2263'-2308' 15 bbls AS I 5258-5273 119022#of 16/20 carbolite 5535-5550 100551#of 16/20 carbolite 5710-5725 90370#of 16/20 carbolite 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) April 10,2013 flowing well test-gas lift assisted Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/10-22/2013 238 hours Test Period--> 1808 5530 _ 2323 24-128/64ths 3059 scf/bbl Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(torr) Press 160 psi 680 psi 24-Hour Rate-> 182 ` 558 234 ' 42 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired'? Yes ❑✓ No ❑ If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071 formations cored. Cassin Blackburn Sanford for summary of lithology,see attached report RBDMS JUN 11 2013 •Form 10-407 Revised 10/2012 , ' L �I . CONTINUED ON REVERSE ?Kb 411(4 IS Submit original only 29 GEOLOGIC MARKERS(List all formations and m. .s encountered) 30. FORMATION TESTS NAME MD TVD Well tested? Q Yes ❑ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summanzmg test results. Attach separate sheets to this form,if .Permafrost-Bottom 1088' 1088' needed,and submit detailed test information per 20 AAC 25 071 K-5 Marker 1618' 1618' A downhole fluid and pressure sampling tool(RDT)was run Nanushuk 2586' 2585' on 3/15/2013 and obtained fluid samples from 5711'MD. Torok 3881' 3875' 4100 cc reservoir fluid was recovered. Pressure was measured •Cassin 5160' 5156' at 2503 psi. Oil gravity was 42.8 API and GOR was 1246 scf/bbl. •Cassin Base 5295' 5289' See the attached spreadsheet for details of all sampling and Wickersham 5418' 5412' measurement attempts. Wickersham Base 5432' 5426' The Blackburn and Sanford zones were flow tested comingled •Blackburn 5495' 5489' from 4/10-16/2013 and produced 1320 bbls oil and 1274 bbls •Blackburn Base 5604' 5597' water. Production logs during the test indicate contributions of •Sanford 5667' 5660' 25%Blackburn and 75%Sanford. The Cassin zone was tested •Sanford Base 5752' 5745' from 4/17-22/2013 and produced 488 bbls oil and 1049 bbls Brown 6052' 6046' water. Detailed testing rates and volumes can be found in the Brown Base 6205' 6199' attached spreadsheet. Formation at total depth: Brown 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,rotary core description summary,detail of testing rates and volumes,and sampling summ 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. 1 Contact: David Lee @ 263-3741 Email. David.L.Lee@conocophillips com Printed Name G. L.Alvord` Title Alaska Drilling Manager Signature (�-alL- Phone 265-6120 Date 614142.f INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 At NAK CASSIN 1 ConocoOR Phillips -4 Well Attributes Max Angle&MD TD Wellbore APWWI Field Name Well Status incl(") MD(ftKB) Act Btm(ftKB) 501032066300 NORTH ALASKA TIGHT HOLE EXPLOR 6.25 2,846.36 6,520.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date w.nconhipVERn9A` CA5s1y �Ii12D13e:41.54AM SSSV:NIPPLE Last WO: Schemalk-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,253.0 4/9/2013 Rev Reason:NEW EXPLORATION WELL(tight hole) 05500 4/9/2013 HANGER,23 Gaing Strings Casing InsulatedDe Description24" String 0... String ID...Top(ftKB) set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15250 68.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 95/8 8.835 27.8 2,378.3 2,378.2 40.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 25.1 6,507.3 6,500.7 26.00 L-80 BTC-M iii I Tubing Strings Tubin Description String0... String ID...Top(ttKB) SetDe th(f...Set Depth(TVD)...StringWt...String...String Top Thrd UPPER TUBING 13 1/2 I 2.992 I 23.0 I 5,010.0 I 5,003.6 I 9.30 I L-80 I EUE CONDUCTOR Insulated24., Completion Details 68-108 Top Depth NIPPLE,525 I (TVD) Top not Rood... Top(ftKB) (R103) (") Item Description Comment ID(In) I 23.0 23.0 -0.01 HANGER FMC TUBING HANGER(made up to a 3'pup) 3.980 57.7 57.7 0.04 XO Reducing Crossover,4-1/2"12.6#/ft Box x 3-Va"9.3#/ft,EUE 8rd Pin 3.500 525.2 525.2 1.09 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO PROFILE 2.875 SURFACE, I I 4,900.0 4,893.6 1.05 NIPPLE HES"X"NIPPLE w12.813"PROFILE 2.813 28-2,378 5,003.3 4,996.8 0.40 LOCATOR 80-40 GBH-22 LOCATOR(5.5'space out) 2.990 j 1 5,004.5 4,998.1 0.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY WITH 1/2 SHOE 3.000 GAS LIFT, 4.000 I TubingDescription String 0... 'StringID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String To Thrd LOWER TUBING 3 1/2 2.992 I 4,997.7 ret I 5,697.6 l 9.30 I L-80 I EUE Completion Details NIPPLE,4,900 -CI I.. Top Depth I (TVD) Top Incl No(is) Top(ftKB) (ftKB) (") Item Description Comment ID(in) 4,997.7 4,991.3 0.41 SLEEVE BAKER HR LINER SETTING SLEEVE 5.000 Gauge Mandrel, r 5,010.9 5,004.4 0.40 NIPPLE BAKER RS NIPPLE 4.250 4,951 5,013.7 5,007.3 0.40 SBR BAKER 80-40(4")SEAL BORE 4.250 5,044.9 5,038.5 0.38 PACKER BAKER PREMIER PACKER 2.870 SLEEVE,4.998 5,163.3 5,156.9 0.01 NIPPLE HES"X"NIPPLE w/2.812'Profile 2.812 LOCATOR, 5,003�VV�VVII I 5,209.8 5,203.4 0.14 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,2"Ball Seat(OPEN 4/17/2013) 2.000 SEAL ASSY, li 5,005 ff 5,254.9 5,248.5 0.27 BLAST JT Blast Joint,3-Va"9.3#,L-80,EUE(Blast Joint Assy#2) 2.897 NIPPLE,5,011 I L 5,323.2 5,316.8 0.47 PACKER 3-1/2"x 7"Baker Premier Packer#2. 2.870 SBR,5,014 I 5,441.2 5,434.8 0.27 NIPPLE HES"X"NIPPLE w/2.812'Profile 2.812 5,487.5 5,481.0 0.26 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,1.875"Ball Seat(CLOSED 1.875 PACKER,5.049 _ 4/10/2013,BUT NOT HOLDING) i� 5,532.7 5,526.2 0.10 BLAST JT Blast Joint,3-Va"9.3#,L-80,EVE(Blast Joint Assy#1) 2.897 Gauge Mandrel, { 5,597.6 5,591.1 0.22 PACKER 3-12"x 7'Baker Premier Packer#1. 2.870 5.103 5,685.2 5,678.7 0.38 NIPPLE HES"XN"NIPPLE w/2.75"Profile 2.750 _ 5,703.2 5,696.7 0.41 SOS BALL SEAT SHEAROUT SUB for 1"OD ball-5000 psi shear required 2.992 NIPPLE,5,183 1.1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) FRAC PORT, {e a I 5,354.0 5,347.6 0.33 PLUG WRP PLUG 4/17/2013 0.000 5.210 Perforations&Slots PERF, Shot 5.25es,273� L I Top(TVD) Btm(TVD) Dens j FRAC,5,158 [_(___I Top(ftKB) Btm(BBB) (ftKB) (ftKB) Zone Date (ah.. Type Comment 5,258.0 5,273.0 5,251.6 5,266.6 3/24/2013 IPERF 5,535.0 5,550.0 5,528.6 5,543.6 3/24/2013 IPERF PACKER,5,323 --_- 5,710.0 5,725.0 5,703.6 5,718.6 3/24/2013 (PERF Stimulations&Treatments Bottom PLUG,5.354 - Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) PIKES) (ftKB) Type Date Comment Gauge Mandrel, {- 5,158.0 5,373.0 5,151.6 5,366.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin 5,382 formations,placing 90,370#,100,551#,and 119,022#proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation NIPPLE,5.441 stages.Pumped 3604-bbl total slurry volume,25# x-link gel with linear gel flushes,309,943#total 16/20 CarboLite(100%design). FRAC PORT,5.487 (a a I FRAC,5,435 Illir Ile PERI - 5,535-8,55F,0_' ibi Mandrel Details _ Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run PACKER,5,598 �_ N...Top(ftKB) (ftKB) ("1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... alt 1 4,840.0 4,833.6 1.05 CAMCO MMG 1 12 GAS UFT OV BK 0.188 0.0 4/10/2013 Shear _ 2 4,950.9 4,944.5 1.04 CAMCO Espinage 1 GAS LIFT GAUGE 0.000 0.0 3/27/2013 Gauge Mandrel, 3 5,103.5 5,097.0 0.32 CAMCO MMG 1 12 GAS LIFT GAUGE 0.000 0.0 3/27/2013 5.555 4 5,381.8 5,375.3 0.33 CAMCO MMG 1 12 GAS LIFT OPEN 0.000 0.0 4/16/2013 NIPPLE,5,885 i 5 5,656.0 5,649.5 0.32 CAMCO MMG - 1 12 GAS LIFT OPEN 0.000 0.0 4/16/2013 ME SOS,5,703 ex. FRAC,5,810 ERE, PERF, M . 5.710-5,725 PRODUCTION, 254,507N TD,8,520 '' a. : NAK CASSIN 1 ConocoPhillips PU Alaska.Inc. ro Gamilwi ps - ---_-' - KB-Grd(ft) Rig Release Date •Wet ConrqVERTICAL-CASSIN I,4/1920138:41:54 AM Schematic-Actual HANGER,23 Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftK0) (M(8) (ftKB) (ftK8) Type Date Comment 5,435.0 5,610.0 5,428.6 5,603.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin formations,placing 90,370#,100,551#,and 119,022#proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping I 2.000"and 2.125"balls between the three formation stages.Pumped 3604-bbl total slurry volume,25# CONDUCTOR x-link gel with linear gel flushes,309,943#total 16/20 Insulated 24•, CarboLite(100%design). 68-108 NIPPLE,525 it I 5,610.0 5,825.0 5,603.6 5,818.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin formations,placing 90,370#,100,5514,and 119,022#proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125'balls between the three formation stages.Pumped 3604-bbl total slurry volume,25# x-link gel with linear gel flushes,309,943#total 16/20 SURFACE, II I CarboLite(100%design). 282,378 Notes:General&Safety LIFT, End Date Annotation GAS 4,asa - 3/27/2013 NOTE:MANDREL#2 SOLID GAUGE MANDREL 3/27/2013 NOTE:ALL MANDRELS ARE SIDE POCKET MANDRELS NIPPLE,4,900 Gauge Mandrel, 1 4,951 SLEEVE,4,998 LOCATOR, 5,003 SEAL ASSY, M 5,SY, NIPPLE,5,011 'I _ 500,5,014 PACKER,5,045 __ - - Gauge Mandrel_ _ 5,103 111 NIPPLE,5,163 Il FRAC PORT, 5,210 {■ 8 I IPERF,5,258 I I� 5,58 1 J FRAC,RAC,5,158 ! Mil Ur PACKER,5,323 MIS PLUG,5,354 - a Gauge Mandrel, 5,382 II NIPPLE,5,441 - , FRAC PORT, 5,487 I e e' FRAC,5,435 L 5,53IPER 0 - 1 JJ __ --- PACKER,5.598 .. Gauge Mandrel, 5,658 NIPPLE.5,685 .r. SOS,5.703 FRAC,5,610 IPERF, ill MI5,710-5,725 PRODUCTION, 0.6,520 4. _ 25 6,507 Time Log & Summary ConocoPhillips Wellview Web Reporting Report Well Name: CASSIN 1 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 2/17/2013 12:00:00 PM Rig Release: 3/21/2012 12:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02/17/2013 24 hr Summary Rig maintenance,Work orders,clean rig,work on top drive stand jump,clean and inspect mud pumps, clean pits in rock washer,c/o oil in drawworks 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Clean&clear rig floor,work on top drive stand jump, MP-2's,clean under floor,flush mud pumps,clean suction manifolds, inspect valves and seats,work on drawworks c/o oil, clean mezzinine,clean pits in rock washer. 02/18/2013 Rig Maintenance, MP@2's,work on top drive,grease crown, inspect derrick, change valves in rock washer, gease and inspect skate,remove riser f/pits. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue working on MP2's work on mud pumps,scrub rig, repair washed out demco valves in rock washer, work on stand jump on top drive, ispect derrick,grease crown , grease skate, remover riser f/pit 6 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Continue working on MP2"s,clean rig,work on pit risers, continue working on valves in rockwasher 02/19/2013 Continue rig maintenance,work on shakers,Top Drive,Mud pumps, Riser in pits,valves in rock washer, pumps in rock washer, clean A-legs and work on bridge crane hoses. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T PJSM,Continue Cleaning rig, repair riser cable,assemble pumps, clean under drawworks,continue fabricating riser for pit#6. 12:00 00:00 12.00 0 0 MIRU MOVE MOB T PJSM,C/O rails on shakers,clean A-Legs on rig floor, Inspect Top Drive, Moblize spare parts from pump room to parts van.Work on pumps in rock washer room,paint new riser in pits, Fix bridge crane hoses in cellar. Test hydraulic moving system. 02/20/2013 Continue working on maintenance,Wash and clean walls in pipe shed and rig floor, Install rizer in pits, rebuild top end on test pump, Rebuild valves in rockwasher. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue cleaning rig floor, Pump room, Inspect mud cleaner, Install rizer in pit.prep cellar for move, Rebuild 3"demco valves in rockwasher, Scrud walls in pipe shed,assemble tools and diverter bolts, bagged oily waste for shipment,cleean around hydraulic pumps, rebuild top end on test pump,work on rig alarms. Page 1 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Continue to work on rig alarms, scrub choke manifold,clean#3 air compressor,clean filters on#3 air compressor, Finish welding riser on pit 6, Disasemble pump#2 in rock washer and inspect impellar,clean walls in pits and cattle chute. 02/21/2013 Continue working on maintenance, Inventory parts on rig,C/O needle valves on test manifold,C/O rubber mounts on shaker#2. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue cleaning rig, Inventory parts for rig floor, Pump room,and Motor room, Inspect discharged Demco valves in rockwasher, C/O leaking needle valve on test maniflod, Change out rubber mounts on shaker #2 12:00 00:00 12.00 0 0 MIRU MOVE MOB P PJSM, Fix handle on pipe shed, clean pit suctions, R/D skate.Thaw out cellar box, R/D choke line,Prep rig for move,Test hydraulic moving system. 02/22/2013 Continue working on maintenance, prep for move, clean out vac tank,cellar tank,freeze protect test pump, Change over to 5"on iron roughneck, mud bucket,dog collar,check air pressure on rig tires,clean out pollution pan&cellar box, Blow down rig water lines.Vac off water out of rockwasher. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T PJSM,Clean rig, MP2s,Clean out vac tank,cellar tank, Freeze protect test pump,pressure washer, washing machine, chip up ice in pump room, Service all 1502 valves, X-O's, clean&inspect air slips,fuel rig. 12:00 00:00 12.00 0 0 MIRU MOVE MOB T PJSM,Clean out pollution pan& cellar box, Blow down rig water,vac off water in rockwasher, Prep iron roughneck for 5"dp, Mud Bucket and dog collar, check rig tires air pressure. 02/23/2013 Disconnect Gycol line,water lines&remove handy berms around rockwasher, Blow down rig,disconnect steam&air lines,Weather has shut down possible rig move, Reconnect steam and electrical lines up and turn steam back on. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM, Prep-rig for move, remove and disconnect glyco lines and water lines, remove handy berm from rock washer. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM, Blow down steam, disconnect air and service lines between complexs, Move out pipeshed heater. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM, On weather hold. Hook steam lines&electrical lines back up and take on water and fuel. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM, Continue weather hold,send steam through rig. Page 2 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/24/2013 24 hr Summary Organize parts cabinets&tool boxes,scrub dog house&electricans room. C/O tong dies, repair camlocks on service connects,cont.working on MP2's. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM,Coninue organizing Parts cabinets and tool boxes. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,Scrub doghouse and electricans room while waiting on weather. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,Change out tong dies, repair camlocks on service connects. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM,held table top H2S&Diverter drills with After Action Reviews, continue cleaning rig and working on MP2's. 02/25/2013 Continue rig cleaning and welding repairs, remove tioga heater ducting on side of pipe shed,stairs and landing off pipe shed for move.Work on MP2's. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM,Work on MP2's,Scrub boiler room. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,work on MP2's and clean snow off stairways,plumb steam lines to centrifugal room,fuel camp, clean out air compressor radiator, service centrifuge pumps,inspect cam locks and install new safety wires where needed. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue cleaning, Remove pipe shed Tioga heater duct ing, stairs&landing on pipe shed ODS, Repair cracks on Iron roughneck, Fix trough gates in pits, Repair 3"valve on possum belly jet line, Clean boiler room. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue cleaning rig, Held Table Top Drills and discussions, work on MP2's,generate HRW's. 02/26/2013 Clean rig, Held Table top drills, Clean off snow from arctic entry,stairways,off load water from rig tank, Blow down steam and disconnect lines and unplug electrical lines. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM, Scrub rig walls and equipment, Held Table Top Drills with rig crew, 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,Cleaning rig, C/O packing on steam valve, complete HRW's, Shovel out arctic entery, clean snow off stairways, Off load water from rig tank. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue cleaning rig,At 13:40 hrs held Diverter&Spill drill till 14:12 hrs,All notifications were made. Function test jacking systems,shovel snow around complex's, PJSM om rigging down. 18:00 21:00 3.00 0 0 MIRU MOVE MOB T PJSM, Blow down steam lines and disconnect,switch to cold starts, unplug electrical lines. Page 3 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Move out pipe sheds and modules off well and spot at G-pad,Move sub off well and stage for move to Cassin# 1. 02/27/2013 Move complex's rockwasher,boiler, pits and motor complex's to Cassin#1, Round trip for sub and pipe sheds and made it to guard shack on ice road @ midnite. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move Rockwasher, Boiler, Motor& pit complex's F/1 R-Pad T/Cassin# 1. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Continue moving complexes to Cassin#1, Return with Peak trucks to 1R-Pad and move sub and pipe sheds to Cassin#1 well.(Made it to the guard shack @ midnite.) 02/28/2013 Move sub and pipe sheds to Cassin#1 From 1 R-pad,Spot Sub and lay hurculite and mats,Spot pipe sheds, spot pits, pumps, motor and boiler complexes, Hook interconnects and turn on steam. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move Sub and pipe sheds From 2L Pad to Midway camp. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Continue moving sub and pipe sheds to Cassin#1 14:00 15:00 1.00 0 0 MIRU MOVE MOB P Spot sub over wellhead, Unload pipe shed and lay hurculite and lay mats for pipe shed and power pack,spot pipe sheds. 15:00 21:00 6.00 0 0 MIRU MOVE MOB P Spot Pits, pumps, motors and boiler complexes,spot roch washer. 21:00 00:00 3.00 0 0 MIRU MOVE RURD P Hook up steam,gylco,water and air service connects, lower stairs on all complexes,work on rig acceptence list,turn on steam. 03/01/2013 Rigging up, Rig move completed to Cassin#1,Accepted rig @ 18:00 hrs, 3/1/2013 00:00 12:00 12.00 0 0 MIRU MOVE RURD P PJSM,Continue working on rig acceptance check list, Berm Rockwasher, rig and sub.Trim herculite,set stairways,assemble mud pumps and pit room mud lines, lower skate rail, Lay camp matts and herculite. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P PJSM,Continue working on rig acceptance list, R/U pits,pump room, berm sub, lay matts& herculite for camp and shop, winterize cellar area, rig up pipe shed satirs, herculite and set Tioga heater, geronmio line,Test gas alarms. Rig acceptted @ 18:00 hrs,3-1-2013 18:00 00:00 6.00 0 0 MIRU MOVE RURD P PJSM, N/U diverter,take on 10.0 ppg spud mud, un-load pipe shed, set site control shack. 03/02/2013 Load shed with 5"dp, Perform diverter and accumulator test,test waived by Chuck Scheve, P/U dp&stand back in derrick, Mobilize tool and BHA to rig floor, Helded Pre-Sud with crews, Hook up communications to CanRig unit, Held diverter shallow gas drill&AAR with crews, M/U BHA#1. Page 4 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:45 8.75 0 0 SURFA( DRILL OTHR P PJSM, P/U Mouse hole, Load shed with 90 jts of 5"dp and 3 Flex DCs, Check accumulators bladders, N/D small section of diverter line,Total lenght from sub door is 105', Spot and set CanRig unit,Spot rock washer cutting tank, Perform diverter and accumulator test, Diverter test waived by Chuck Scheve, System pressure=299 psi, pressure after closing=1800 psi,200 psi attained= 38 sec, Full pressure obtained=210 sec, Five bottles avg.=2100 psi, Time for knife valve open= 12 sec, Hydrill to close=20 sec. 08:45 09:00 0.25 0 0 SURFA( DRILL SFTY P PJSM on picking up dp and standing back into derrick. 09:00 12:00 3.00 0 0 SURFA( DRILL OTHR P P/U 5"dp and rack ak into derrick. 12:00 12:15 0.25 0 0 SURFA( DRILL OTHR P PJSM on P/U on dp. 12:15 13:45 1.50 0 0 SURFA( DRILL OTHR P Finish P/U 5"dp and stand back into derrick. 13:45 14:15 0.50 0 0 SURFA( DRILL PULD P PJSM,Mobilize 12-1/4"bit to rig floor and strap 5"hwtdp in pipe shed. 14:15 15:30 1.25 0 0 SURFA( DRILL OTHR P P/U 5"hwtdp and jars and stand back into derrick. 15:30 15:45 0.25 0 0 SURFA( DRILL OTHR P Clean&clear rig floor,PJSM on beaver slide operations, Mobilize tools and equipment to rig floor. 15:45 17:30 1.75 0 0 SURFA( DRILL SVRG P PJSM,service Top Drive, Drawworks, Iron roughneck and COM. 17:30 18:45 1.25 0 0 SURFA( DRILL SFTY P Pre-sud meeting with Co. Reps. and service crews on location. 18:45 21:30 2.75 0 0 SURFA( DRILL OTHR P Hook up communications with CanRig unit,clean rig. 21:30 23:00 1.50 0 0 SURFA( DRILL SFTY P PJSM and held Diverter shallow gas Drill,Well Secured in 1 min 15 sec. Rig crew arrived at muster area in 3 mins,All truck drivers and after doing a head count 11 mins total for drill. Held after action review with all. 23:00 00:00 1.00 0 0 SURFA( DRILL PULD P PJSM,and Make up Sperry BHA# 1. 03/03/2013 Flood lines and found fluid leaking out weep hole, N/D diverter line&knife valve and found it was placed in wrong direction,Change direction of valve and N/U diverter line and tested good, Spud in @ 3:57 AM, 3/3/2013, Drill F/108'MDT/854'MD,TVD=854' 00:00 00:15 0.25 0 108 SURFA( DRILL PULD P PJSM,M/U BHA as per Sperry. 00:15 00:30 0.25 108 108 SURFA( DRILL OTHR P Flood lines and conductor,Observed Luid coming out of weep hole on diverter line.Shut down and drain stack and Top Drive. 00:30 00:45 0.25 108 108 SURFA( DRILL RGRP T PJSM on N/D knife valve. Page 5 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:30 2.75 108 108 SURFA( DRILL RGRP T N/D knife valve,observed knife valve in wrong direction,turned knife valve to correct direction and N/U line and valve back up. 03:30 03:45 0.25 108 108 SURFA( DRILL OTHR P Flood conductor and lines,Test to 3500 psi,Good. 03:45 09:15 5.50 108 408 SURFA( DRILL DRLG P Drill F/108' T/408'TVD-408', ART-4.35,Jar hrs-0.0, BIT HRS-4.35, PUW-160,SOW-48, ROT WT-91, TQ-1K,TQ off-1K,WOB-12-15K,70 RPM,430 GPM,600 PSI 09:15 09:30 0.25 408 408 SURFA( DRILL CIRC P CBU @ 40 gpm,495 psi. 09:30 10:00 0.50 408 42 SURFA( DRILL TRIP P Blow down Top Drive and lines. POOH F/408'T/42' 10:00 10:15 0.25 42 42 SURFA( DRILL SFTY P PJSM on M/U the rest of 8"BHA 10:15 12:00 1.75 42 102 SURFA( DRILL PULD P M/U Surface BHA to 102'MD 12:00 12:15 0.25 102 102 SURFA( DRILL SFTY P PJSM on M/U BHA with new crew. 12:15 14:15 2.00 102 207 SURFA( DRILL PULD P Finish M/U BHA, Up load MWD data, P/U Flex DCs, SPT MWD @ 450 gpm 720 psi. 14:15 15:15 1.00 207 408 SURFA( DRILL OTHR P Madd Pass F/207'MDT/408'MD @ 250'-300'/Hr,with 440 gpm 720 psi. 15:15 18:00 2.75 408 576 SURFA( DRILL DRLG P Drill F/408' T/576'TVD-576', ART-1.8,AST=.23,ADT=2.03,Jar hrs-2.03, BIT HRS-6.87, PUW-68 K, SOW-72 K, ROTWT-70 K,TQ-.5 K, TQ off-1 K,WOB-10-15 K, 70 RPM 430GPM 600 PSI 18:00 20:30 2.50 576 708 SURFA( DRILL DRLG P Drill F/576' T/708'TVD-708', ART-1.79,AST=0.0,ADT= 1.79,Jar hrs-3.82, BIT HRS-8.66, PUW-70 K, SOW-73 K, ROTWT-72 K,TQ-.2 K, TQ off-1.5 K,WOB-8-10 K,80 RPM 500 GPM 1000 PSI, ECD=10.65 ppg 20:30 21:00 0.50 708 708 SURFA( DRILL CIRC P P/U off btm and change shaker screens and Rock washer over load, Circ @ 60 gpm and work dp. 21:00 00:00 3.00 708 854 SURFA( DRILL DRLG P Drill F/708' T/854'TVD-854', ART-2.12,AST=0.0,ADT=2.12,Jar hrs-5.94, BIT HRS-10.31, PUW-75 K, SOW-77 K, ROTWT-77 K,TQ-.1.5 K,TQ off-1 K,WOB-10-12 K, 80 RPM 500 GPM 1100 PSI, ECD= 10.85 ppg. 03/04/2013 Drill F/1232'T/2334'MD TVD=2334'and wait on Geologist,drill 50 more feet to 2384'MD TVD=2384'and CBU sample for Geologist. Page 6 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 854 1,224 SURFA( DRILL DRLG P Drill F/854 T/1224'TVD-1223', ART-4.96,AST=0.0,ADT=4.96,Jar hrs-11.07, BIT HRS-15.44, PUW-81 K, SOW-85 K, ROTWT-85 K,TQ-.3 K,TQ off-1 K,WOB-15-17 K,80 RPM 500 GPM 1125 PSI, ECD= 10.82 ppg. 06:00 12:00 6.00 1,224 1,550 SURFA( DRILL DRLG P Drill F/1224 T/1550'TVD-1550', ART-4.02,AST=0.0,ADT=4.02,Jar hrs-15.09, BIT HRS-19.46, PUW-86 K,SOW-88 K, ROTWT-90 K,TQ-.2 K,TQ off-1 K,WOB-15-17 K, 80 RPM 532 GPM 1450 PSI, ECD= 10.82 ppg. 12:00 18:00 6.00 1,550 2,000 SURFA( DRILL DRLG P Drill F/1550 T/2000'TVD-2000', ART-4.73,AST=0.0,ADT=4.73, Jar hrs-19.82, BIT HRS-24.19, PUW-96 K, SOW-97 K, ROTWT- 97 K,TQ-.2 K,TQ off-1 K, WOB-15-17 K, 80 RPM 530 GPM 1440 PSI, ECD= 11.13 ppg. 18:00 22:00 4.00 2,000 2,334 SURFA( DRILL DRLG P Drill F/2000 T/2334'TVD-2334', ART-3.51,AST=0.0,ADT=3.51, Jar hrs-23.33, BIT HRS-27.70, PUW-102 K, SOW-105 K, ROTWT- 105 K,TQ-.2 K,TQ off- 1 K, WOB-15-17 K, 80 RPM 530 GPM 1550 PSI, ECD= 11.11 ppg. 22:00 22:30 0.50 2,334 2,334 SURFA( DRILL CIRC P Wait on Geologist to disccuss with town for casing point, Rotate and work pipe @ 550 gpm 1575 psi,60 RPM 22:30 23:00 0.50 2,334 2,384 SURFA( DRILL DRLG P Drill F/2334 T/2384'TVD-2384', ART-.49,AST=0.0,ADT=.49,Jar hrs-23.82, BIT HRS-28.19, PUW- 102 K,SOW-105 K, ROTWT-105 K,TQ-.2 K,TQ off- 1 K,WOB-15-20 K, 80 RPM 545 GPM 1550 PSI, ECD= 11.15 ppg. 23:00 00:00 1.00 2,384 2,384 SURFA( DRILL CIRC P CBU for Geologist and samples @ 60 rpm, 545 gpm, 1550 psi 03/05/2013 Drilled to TD @ 2388'MD TVD-2388'.CBU X 3. Make wiper trip to 671', no tight hole. Run back to bottom @ 2388'and circulate hole clean. POOH and L/D BHA. Rig up casing tools. Run 9-5/8"casing to 1311'and circulate casing volume plus 10 bbls.Cont running 9-5/8"casing to 2378'. 00:00 00:15 0.25 2,384 2,384 SURFA( DRILL CIRC P PJSM,Cont to wait on Geologist, Rot @ 60 RPM's w/1 K Tq. Pump @ 545 GPM=1550 PSI. 00:15 00:30 0.25 2,384 2,388 SURFA( DRILL DRLG P Drill f/2384't/2388'.TVD=2388'. Pump @ 600 GPM=1780 PSI,80 RPM's w/2K Tq. P/U=102K,S/O= 105K, ROT=105K, 80%flow. 00:30 01:45 1.25 2,388 2,388 SURFA( CASING CIRC P CBU X 3,pumped weighted sweep after 1st BU @ 600 GPM= 1750 PSI, 80%flow,60 RPM's w/1K Tq.Shoot survey. 01:45 02:15 0.50 2,388 2,334 SURFA( CASING OWFF P POOH to 2334'. Blow down top drive and monitor well,static. Page 7 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:15 03:30 1.25 2,334 671 SURFA( CASING TRIP P POOH on elevators to 671',good trip no tight hole observed.Strapped pipe in derrick.Actual displacement= 16.66 bbls,Calculated displacement=14.04 bbls. 03:30 04:45 1.25 671 2,388 SURFA( CASING TRIP P RIH to 2388'.washed down the last 50'@ 4 BPM=550 PSI w/no rotary. No fill observed on bottom.Actual displacement=11.65 bbls, Calculated displacement=14.04 bbls. 04:45 07:45 3.00 2,388 2,388 SURFA( CASING CIRC P Established circulation,observed flowline packing off with clay balls. Slowed pumps down and worked pipe until clays balls cleaned up. Circulated hole clean @ 600 GPM=1800 PSI,60 RPMs. SIMOPS, P/U casing tools. 07:45 08:15 0.50 2,388 2,334 SURFA( CASING OWFF P POOH to 2334'. Blow down top drive and monitor well,static. 08:15 09:30 1.25 2,334 671 SURFA( CASING TRIP P POOH f/2334'to 671'on elevators, good trip.Actual displacement= 30.09 bbls,Calculated displacement=27.28 bbls. 09:30 10:45 1.25 671 155 SURFA( CASING TRIP P PJSM,stand back 5 stands of HWDP w/Jars. L/D 3 Flex collars and 1 Stab.Clean clay off of the rig floor. 10:45 12:00 1.25 155 155 SURFA( CASING PULD P Plug into MWD and download tools as per Halliburton rep. 12:00 12:15 0.25 155 155 SURFA( CASING SFTY P Hold PJSM on L/D BHA and handling BHA in the pipe shed. 12:15 13:15 1.00 155 0 SURFA( CASING PULD P L/D BHA as per Halliburton rep. Drain and flush motor and break bit. 13:15 13:45 0.50 0 0 SURFA( CASING OTHR P Clean and clear rig floor. Grade bit, 1-1-ER-A-E-1-NO-TD 13:45 14:00 0.25 0 0 SURFA( CASING SFTY P Hold PJSM on rigging up to run 9-5/8"casing. 14:00 16:30 2.50 0 0 SURFA( CASING RURD P Rig up to run 9-5/8"surface casing and install 1502 on diverter spool. 16:30 16:45 0.25 0 0 SURFA( CASING SFTY P Hold PJSM on running 9-5/8"casing. 16:45 20:30 3.75 0 1,311 SURFA( CASING RNCS P Run 9-5/8"casing as per detail. M/U shoe track and test floats,good test. Cont RIH t/1311'P/U=68K,S/O= 64K. 20:30 21:15 0.75 1,311 1,311 SURFA( CASING CIRC P Circulate casing volume plus 10 bbls. Stage pumps up from 2 BPM=100 PSI,48%flow, 3 BPM=200 PSI,4 BPM=220 PSI, 5 BPH=275 PSI. P/U=81K, 5/0=76K. 21:15 00:00 2.75 1,311 2,378 SURFA( CASING RNCS P Cont to run 9-5/8"casing as per detail. M/U pups and joint#53. P/U hanger and landing joint. P/U=120K, S/O=104K.Actual displacement= 23.8 bbls, Calculated displacement= 36.6 bbls, lost 12.8 bbls. Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/06/2013 24 hr Summary Conditioned spud mud for cement job. Pumped 277 bbls of lead and 74 bbls of tail cement, 130 bbls of good cement returned to surface.After plug bumped observed cement falling in annulus. Began to N/D diverter and gas bubbles where observed in annulus. Monitor well then N/D diverter. Find TOC @ 106',78'below ground level. M/U 3/4"top job pipe and RIH. Pump 16 bbls of AS1 cement, cement 6'below hanger. 00:00 00:30 0.50 2,378 2,378 SURFA( CEMEN'RURD P PJSM, R/D Franks fill up tool. Install cement head and rig up to circulate through cement line. 00:30 02:45 2.25 2,378 2,378 SURFA( CEMEN"CIRC P Circulate and condition mud for cementjob,YP= 18. Stage pumps 9 P P up from 2 BPM=225 PSI tp 6 BPM= 325 PSI w/60%flow. P/U=120K, S/O=105K. 02:45 03:00 0.25 2,378 2,378 SURFA( CEMEN'SFTY P Hold PJSM on pumping cement. Discuss working high hi h pressure lines and proper fluid transfer procedures. 03:00 03:45 0.75 2,378 2,378 SURFA( CEMEN-CMNT P Prime up cement unit and pressure test lines t/1000/3700 PSI. 03:45 06:15 2.50 2,378 2,378 SURFA( CEMEN-CMNT P Cement surface casing as follows, pumped 47 bbls of 10.2 ppg MudPush II,drop bottom plug,pump 277.5 bbls of 11.0 ppg ALC lead cement,74.6 bbls of 15.8 ppg G blend tail cement and 5 bbls of H2O. Drop top plug and displace cement with 9.9 ppg thin spud mud for 1670 strokes. Bumped plug and pressred up to 1100 PSI, held for 5 min. Bleed off pressure and check floats,good. Casing shoe @ 2378.35'.After bumping plug observed cement in 9-5/8"by conductor annulus fall out of site. 06:15 08:15 2.00 SURFA( CEMEN"RURD P Rig down cement head and landing joint. Flush surface riser and work venter on diverter system. annular pre y 08:15 08:30 0.25 SURFA(WHDBO SFTY P Hold PJSM on nipple down diverter system. 08:30 09:30 1.00 SURFA( CEMEN'NUND P Started to nipple down diverter and observed bubbles coming from backside. Decision made to stop nipple down and monitor well. Observed 40 LEL. 09:30 12:45 3.25 SURFA(CEMEN-OWFF T Pick up one stand of drill pipe. Monitor well.SIMOPS,clean casing tools off rig floor.Clean mud pits and rock washer. Pick up 3 joints of 1" pipe for top job. 12:45 13:30 0.75 SURFA(CEMEN-CMNTT Attempt to run 1"pipe in annulus, pipe would not go though the hanger. Clean top of hager and try again, no succuss. Decision made to nipple down diverter system. 13:30 13:45 0.25 SURFA(CEMEN-SFTYT Hold PJSM on nipple down diverter system. Page 9 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 17:15 3.50 SURFA(WHDBO NUND T Nipple down diverter,adapter spool and diverter spool. Remove diverter pipe and clean. Clean and clear tools and equipment.Attempt to run 1" pipe in annulus,tool joint on 1"pipe would not pass though flutes on hanger. Ran plumbob down annulus and tagged cement @ 78'down from ground level. 17:15 20:30 3.25 SURFA( CEMEN-RURD T Make up 80'of 3/4"pipe for top job. Heat water to 70°and rig up SLB cement equipment. Mob wellhead equipment to cellar area and rig down long bails. L/D raiser and take on 9.8 ppg Kla-shield mud into pits. 20:30 20:45 0.25 SURFA( CEMEN-SFTYT Hold PJSM on cementing. 20:45 22:15 1.50 SURFA( CEMEN-CMNT T Pump top job as per SLB. Batch up cement and blow air though lines. Pump water to flush to clean out annulus followed by 16 bbls of 15.7 ppg AS1 cement.Observed 15.4 ppg cement at surface. Cement dropped slightly then held with TOC 6'below hanger. 22:15 00:00 1.75 SURFA( CEMEN-RURD T Clean out cement from cellar box and monitor cement status in annulus.Cont to rig up floor to test BOPE. 03/07/2013 N/U wellhead and test seals t/1000 PSI f/10 min. N/U BOPE and install check valve in kill line. R/U and test BOPE t/250/3500 PSI.Test all rams and valves for 10 min each as per BLM reg. BLM rep Justin Miller witnessed test.AOGCC rep Lou Grimaldi waived witness of test. Pick up 5"drill pipe and stand back in derrick. M/U motor and bit.Weather turned into phase III,shut down and wait in weather to improve. 00:00 00:15 0.25 SURFA( CEMEN"OTHR T Observed cement in annulus, still holding 6'below ground level after 30min. 00:15 01:30 1.25 SURFA(WHDBO NUND P PJSM, Nipple up wellhead equpiment and test metal to metal seals for 1000 psi for 10 min,good. 01:30 07:30 6.00 SURFA(WHDBO NUND P Nipple up adapter flange and BOP stack. Install check valve on kill line. 07:30 08:00 0.50 SURFA(WHDBO RURD P Pick up test plug,wear bushing and running tool. 08:00 08:15 0.25 SURFA(WHDBO SFTY P Hold PJSM on testing BOPE. Discuss working around high pressure lines, place signage in proper location and using good communication. 08:15 10:30 2.25 SURFA(WHDBO BOPE P Fill stack with water,flange leaking. Retighten bolts on stack. Rig up to test BOPE. Page 10 of 23 Time Logs Date From T. Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 16:00 5.50 SURFA(WHDBO BOPE P Test BOPE to 250/3500 PSI.Test #1:Top pipe rams,manual kill line valve,CV 1, 12,13 and 14. Test#2: Upper IBOP,HCR kill,CV 9 and 11. Test#3: Lower IBOP,CV 5,8 and 10. Test#4: Dart valve,CV 4,6,7 and kill line check valve. Test#5:Floor valve. Test#6: HCR choke. Test#7: Manual choke and HCR kill. Test #8:Annular preventer. Test#9: Lower pipe rams. Test#10: Blind rams and CV 3.System pressure= 2950 PSI,pressure after closing= 1800 PSI.200 PSI attained after 34 seconds and full pressure attained after 3:17.Nitrogen bottles average= 2150 PSI.AOGCC inspector Lou Grimaldi waved witness of test. BLM rep Justin Miller witnessed the test. 16:00 17:15 1.25 SURFA(WHDBO BOPE P Rig down testing equipment and set wear bushing. Blow down top drive, choke and kill lines, 17:15 17:45 0.50 SURFA( RIGMNT SVRG P Inspect swivel packing and tighten/grease. 17:45 18:00 0.25 SURFA( CEMEN"SFTY P Hold PJSM on picking up 5"drill pipe via mouse hole. 18:00 21:00 3.00 SURFA( CEMEN"PULD P Pick up 60 joints of 5"drill pipe and stand back in derrick.Lay down 4 joints of HWDP and 8"Jars.Pick up 6-3/4"Jars and stand back. 21:00 21:15 0.25 SURFA(CEMEN"PULD P Clean and clear rig floor. 21:15 21:30 0.25 SURFA( CEMEN-SFTY P Hold PJSM on picking up BHA. 21:30 22:00 0.50 SURFA( CEMEN'PULD P Make up bit to Sperry mud motor. 22:00 00:00 2.00 SURFA( CEMEN-OTHR T Hold PJSM,discuss phase III weather operations.Shut down and wait on phase III weather.Scrub and clean around rig.Work on small indoor projects. 03/08/2013 Cont to wait on Phase III weather.M/U BHA and load sources.Shallow hole test MWD tools,good. RIH picking up 5"drill pipe.CBU,test surface casing to 3000 PSI for 30 min,good.Wash down to TOC @ 2293'. Drill out shoe track and 20'of new hole.Attempt to perform FIT/LOT,leak off—310 psi, 12.2 ppg LOT.CBU and treat mud to POOH and squeeze cement. 00:00 10:30 10.50 SURFA( CEMEN"OTHR T Hold PJSM,wait on phase III weather to improve.Work on small indoor projects. 10:30 10:45 0.25 SURFA( CEMEN"SFTY P Hold PJSM on making up BHA. 10:45 12:30 1.75 0 125 SURFA( CEMEN"PULD P Make up Sperry BHA#3, mud motor and MWD tools. 12:30 15:15 2.75 125 125 SURFA( CEMEN"DHEQ P Upload MWD tools,problems Uploading tools. Break connection and trouble shoot MWD tools. Plug back into tools and upload tools as per Halliburton rep. Page 11 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 15:30 0.25 125 125 SURFA( CEMEN-PULD P Pick up nucular sources from beaver slide. 15:30 16:00 0.50 125 125 SURFA(CEMEN-SFTY P Hold PJSM on loading nucular sources,dicussed proper hand placement and crews first day back from days off. 16:00 16:45 0.75 125 600 SURFA(CEMEN-PULD P Load sources and cont.to pick up BHA. 16:45 17:30 0.75 600 600 SURFA( CEMEN"DHEQ P Shallow hole test tools, pump @ 500 GPM=1425 PSI. Blow down top drive. 17:30 18:45 1.25 600 2,082 SURFA( CEMEN-PULD P Run in the hole picking up 5"drill pipe to 2082'. 18:45 19:00 0.25 2,082 2,082 SURFA( CEMEN SFTY P Hold PJSM on testing 9-5/8"40 ppf L-80 surface casing. 19:00 19:45 0.75 2,082 2,082 SURFA( CEMEN"CIRC P Rig up and CBU @ 2082'for casing test. Pump @ 220 GPM=575 PSI. P/U=87K, S/O=85K. 19:45 20:15 0.50 2,082 2,082 SURFA( CEMEN'PRTS P Test 9-5/8"40 ppf L-80 surface casing to 3000 PSI for 30 min.record on chart.Good test. 20:15 21:15 1.00 2,082 2,293 SURFA(CEMEN'WASH P Rig down testing equipment.Wash and ream down f/2082'to 2293'. 21:15 00:00 2.75 2,293 2,345 SURFA( CEMEN'DRLG P Drill out shoe track f/top of FC @ 2293'to 2345'.TVD=2345'.ART= 1.75,ADT= 1.75.Jar hrs.= 1.75, Bit hrs=1.75. P/U=93K, S/0=96K, ROT=97K,Tq=3K. ECD=10.3 ppg, Flow 64%@ 515 GPM=1500 PSI. 03/09/2013 Drill out shoe track and 20'of new hole to 2408'.Attempt to perform FIT/LOT, leak off—310 psi, 12.2 ppg LOT. CBU and treat mud. POOH and stand back MWD tools, L/D motor and bit. P/U 3-1/2"cement string and RIH on 5"DP.Tag bottom @ 2408'and swap mud system. Pump MudPush, 15 bbls of AS1 cement and MudPush. POOH above cement and Circ S/S. Perform hesitation squeeze, squeezed 4.8 bbls of cement before pressure held @ 600 PSI. POOH. 00:00 01:15 1.25 2,345 2,388 SURFA( CEMEN-DRLG P PJSM, Cont to drill shoe track f/ 2345'to 2388'. 01:15 01:45 0.50 2,388 2,408 SURFA( CEMEN-DRLG P Drill 20'of new hole to 2408'. Bit hrs= 3.12,Jar hrs=3.12. 01:45 02:15 0.50 2,408 2,408 SURFA( CEMEN"CIRC P Circulate and condition mud for FIT/LOT, pump @ 515 GPM=1500 PSI,40 RPM w/1K Tq, P/U=93K, S/O=96K, ROT=97K. 02:15 02:30 0.25 2,408 2,316 SURFA( CEMEN-RURD P Stand back one stand of drill pipe and rig up for FIT/LOT. 02:30 03:15 0.75 2,316 2,316 SURFA( CEMEN"LOT P Perform FIT/LOT, pumped @ 7 spm, once pressure reached 600 PSI dropped straight off to 200 PSI.Shut down and look for leak on surface equipment. No leaks found. Pressure back up pumping @ 7 spm and started injecting mud @ 310 PSI, pumped.6 bbl after leak off and held for 10 min., pressure leaked off to 120 psi. Pressure test all surface lines,good. LOT=12.2 ppg EWM Page 12 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:30 0.25 2,316 2,316 SURFA( CEMEN"PRTS P Pressure test all surface lines to ensure results of LOT are accurate, good test. 03:30 04:00 0.50 2,316 2,316 PROD1 CEMEN-CIRCT Circulate and condition mud @ 125 GPM-225 PSI,wait on orders from town. 04:00 04:30 0.50 2,316 2,316 PROD1 CEMEN"CIRC T Obtain slow pump rates and rig down testing equipment. 04:30 05:15 0.75 2,316 2,316 PROD1 CEMEN"CIRC T Circulate and condition mud to POOH, add Bicarb and Citric to mud. Pump @ 515 GPM= 1500 PSI,40 RPM w/1KTq. 05:15 05:45 0.50 2,316 2,316 PROD1 CEMEN-OWFF T Monitor well,static. Blow down top drive. 05:45 06:15 0.50 2,316 600 PROD1 CEMEN"TRIP T POOH to 600'.Actual displacement= 17.04 bbls,Calculated displacement=14.82 bbls. 06:15 06:45 0.50 600 220 PROD1 CEMEN-TRIPT Stand back 3 stands of HWDP and jars. 06:45 07:00 0.25 220 155 PROD1 CEMEN"OWFF T Stand back 1 stand HWDP and flex collars. BHA actual displacement= 13.41 bbls, 14.96 bbls. 07:00 07:15 0.25 155 155 PROD1 CEMEN-SFTY T Hold PJSM on removing sources. 07:15 07:45 0.50 155 155 PROD1 CEMEN"PULD T Remove sources and send down beaver slide. 07:45 09:00 1.25 155 155 PROD1 CEMEN-PULD T Download MWD tools as per Halliburton rep. 09:00 09:30 0.50 155 0 PROD1 CEMEN-PULD T Stand back MWD in derrick. Lay down stab, motor and bit as per Halliburton rep. 09:30 10:15 0.75 0 0 PROD1 CEMEN"OWFF T Monitor well,static.Clean and clear rig floor. 10:15 10:45 0.50 0 0 PROD1 CEMEN"SVRG T Service rig. 10:45 13:30 2.75 0 0 PROD1 CEMEN"OTHR T Mobilize 3-1/2"L-80 EUE tubing to rig for cement job. Mix black water pill for cement job. 13:30 15:00 1.50 0 0 PROD1 CEMEN"PULD T Load pipe shed with 3-1/2"EUE tubing,drift and tally. 15:00 15:45 0.75 0 0 PROD1 CEMEN"RURD T Pick up tongs from beaver slide and rig up to RIH w/3-1/2"tbg. 15:45 16:45 1.00 0 471 PROD1 CEMEN"PUTB T PJSM,pick up mule she and 15 joints of 3-1/2"L-80 EUE tbg. 16:45 17:15 0.50 471 471 PROD1 CEMEN"RURD T Make to XO and C/O elevators. 17:15 18:15 1.00 471 2,408 PROD1 CEMEN"TRIP T RIH with 5"drill pipe f/471'to 2408'. Tag up and set down 3K. P/U=71K, S/O=73K.Actual displacement= 16.4 bbls,Calculated displacement= 16.2 bbls. 18:15 18:45 0.50 2,403 2,403 PROD1 CEMEN-PULD T Lay down 1 single and pick up 10' pup joint. 18:45 19:45 1.00 2,403 2,403 PROD1 CEMEN"DISP T PJSM, Displaced mud to a sacrificial mud system to perform cement job. Displaced to a 9.8 ppg powervis/bar mud system. Pumped @ 5 BPM=200 PSI. Page 13 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 2,403 2,403 PROD1 CEMEN-COND T Top wash pit#5 and load with mud of Vac truck. 20:45 21:00 0.25 2,403 2,403 PROD1 CEMEN"SFTY T Hold PJSM on cementing. 21:00 22:15 1.25 2,403 2,403 PROD1 CEMEN"CMNT T SLB pump 5 bbls of water through bleeder and shut in. Pressure test lines to 600/3500 PSI. Pump 15 bbls of 12.0 ppg MudPush II, 15 bbls of 15.7 ppg AS1 cement and 4.2 bbls of 12.0 ppg MudPush II. Displaced with rig pumps for 298 strokes. 22:15 22:30 0.25 2,403 2,046 PROD1 CEMEN"TRIP T UD 10'pup joint and pick up single. POOH to 2046'. 22:30 23:00 0.50 2,046 2,046 PROD1 CEMEN"CIRC T Drop nerf wiper ball and circulate surface to surface @ 6 BPM=250 PSI 23:00 00:00 1.00 2,046 2,046 PROD1 CEMEN-SQEZ T Close pipe rams and perform hesitation squeeze as follows. Pump @ 10 spm,pressure built to 550 psi then broke over, injected 3 bbls @ 300 PSI,shut well in for 10 minutes. Pressure dropped from 300 PSI to 200 PSI. Pumped 1.5 bbls,pressure broke over @ 450 PSI and injected @ 350 PSI.Shut well in for 10 minutes, pressure dropped from 300 PSI to 225 PSI. Pumped.3 bbls, pressured up to 600 PSI.Shut well in for 10 minutes. Pressure drop from 600 PSI to 500 PSI.Attempted to pump,well pressured up to 600 PSI before stroke counter would read any strokes. Shut well in for 10 minutes. Pressure dropped from 600 PSI to 550 PSI. Squeezed a total of 4.8 bbls of cement. 03/10/2013 RIH w/clean out BHA to 2136',wash down to 2319'.CBU,cont to wash and ream down to 2367'.Set down 10K on cement,wash and ream down to 2408'and drill 10'of new hole to 2418'.CBU and perform FIT to 14.3 ppg EMW. POOH and UD clean out BHA.Make up 8-1/2"drilling BHA. RIH and swap mud system to 9.8 ppg KlaShield mud. Drill ahead f/2418'to 2919'TVD=2913'. ROP @ 125 FPH. ECD=10.92 ppg. 00:00 00:15 0.25 2,046 2,046 SURFA( CEMEN"OWFF T Monitor well,static.SIMOPS, rig down cement line. 00:15 01:00 0.75 2,046 450 PROD1 CEMEN"TRIP T POOH f/2046'to 450'.Actual displacement= 15.05 bbls, Calculated displacement=14.84 bbls. 01:00 01:15 0.25 450 450 PROD1 CEMEN"RURD T Change over to 3-1/2"handling tools. 01:15 02:00 0.75 450 0 PROD1 CEMEN'PULD T Lay down 15 joints of 3-1/2"EUE tbg. 02:00 03:00 1.00 0 0 PROD1 CEMEN"OTHR P Day light savings time change. 03:00 03:45 0.75 0 376 PROD1 CEMEN-PULD T PJSM, make up clean out BHA as per Halliburton rep. 03:45 04:30 0.75 376 2,136 PROD1 CEMEN'TRIP T RIH with clean out BHA to 2136'. Actual displacement=23.1 bbls, Calculated displacement=22.96 bbls. Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 04:45 0.25 2,136 2,319 PROD1 CEMEN-WASH T Wash and ream f/2136'to 2319'. Pump @ 515 GPM=850 PSI,40 RPM w/1 KTq. 04:45 05:30 0.75 2,319 2,319 PROD1 CEMEN-CIRCT CBU, pump @ 525 GPM=875 PSI, 60%flow,40 RPM w/1K Tq. 05:30 05:45 0.25 2,319 2,367 PROD1 CEMEN-WASH T Wash down f/2319'to 2367'. Pump @ 450 GPM=800 PSI,40 RPM. Turn off rotary and slow pump to 150 GPM, set down 10K on cement. 05:45 06:00 0.25 2,367 2,408 PROD1 CEMEN"WASH T Wash and ream f/2367'to 2408'. Pump @ 515 GPM=850 PSI,40 RPM w/1 KTq. 06:00 07:15 1.25 2,408 2,418 PROD1 CEMEN"DRLG T Drill 10'of new hole for FIT. Drill f/ 2408'to 2418'. Pump @ 550 GPM=1250 PSI,62%flow,80 RPM w/2 K Tq. P/U=85K,S/0=86K, ROT=84K. 07:15 07:45 0.50 2,418 2,312 PROD1 CEMEN"CIRC T Stand back one stand and CBU for FIT. 07:45 08:00 0.25 2,312 2,312 PROD1 CEMEN-RURD T Rig up for FIT and blow down top drive. 08:00 08:15 0.25 2,312 2,312 PROD1 CEMEM LOT T Perfrom FIT to 14.3 ppg EMW,good FIT. 08:15 08:30 0.25 2,312 2,312 PROD1 DRILL OWFF T Monitor well,static. Rig down FIT equipment. 08:30 09:15 0.75 2,312 376 PROD1 DRILL TRIP T POOH f/2313'to 376'.Actual displacement=23.1 bbls, Calculated displacement=23.74 bbls. 09:15 09:45 0.50 376 0 PROD1 DRILL PULD T Stand back 4 stands HWDP and jars. L/D clean out BHA as per Halliburton rep. 09:45 10:00 0.25 0 0 PROD1 DRILL PULD T Clean and clear rig floor. 10:00 10:15 0.25 0 0 PROD1 DRILL SFTY T Hold PJSM on making up 8-1/2" drilling BHA. 10:15 12:45 2.50 0 225 PROD1 DRILL PULD T Make up BHA#5 as per Halliburton rep. 12:45 14:00 1.25 225 225 PROD1 DRILL DHEQ T Plug into MWD tools and upload. 14:00 14:45 0.75 225 225 PROD1 DRILL PULD T PJSM,load sources into MWD tools. 14:45 15:00 0.25 225 600 PROD1 DRILL PULD T Cont to pick up BHA. 15:00 15:30 0.50 600 600 PROD1 DRILL DHEQ T Shallow hole test tools,good. 15:30 16:00 0.50 600 2,360 PROD1 DRILL TRIP T RIH f/600'to 2360'.Actual displacement=29.21 bbls, Calculated displacement=28.3 bbls. 16:00 16:15 0.25 2,360 2,388 PROD1 DRILL WASH T Wash down f/2360'to 2388'pump @ 500 GPM= 1050 PSI. 16:15 16:30 0.25 2,388 2,418 PROD1 DRILL SRVY P Log well f/2388'to 2418'. 16:30 17:00 0.50 2,418 2,418 PROD1 DRILL DISP P PJSM, Displace well to 9.8 ppg KLASHIELD mud system. Page 15 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 2,418 2,915 PROD1 DRILL DRLG P Drill ahead,drilled f/2418'to 2915', TVD=2913'.ART=3.81,AST=.67, ADT=4.48,Total jars hrs=5.36, Total bit hrs=4.48, Pump @ 650 GPM=1900 PSI flow 73%,70 RPM w/1-3K Tq, 1 K off. ECD= 10.92 ppg EMW. P/U=105K, S/O= 106K, ROT=105K. 03/11/2013 Drilled ahead f/2915'to 4447'.TVD=4441'.ADT= 16.64 hrs.Avg ROP=120 FPH, ECD= 11.0 ppg 00:00 06:00 6.00 2,915 3,378 PROD1 DRILL DRLG P Drilling f/2915'to 3378'.TVD=3374', ART=4.26,AST=0,ADT=4.26,Jar hrs=9.62, Bit hrs=8.74. P/U=115K, 5/0= 115K, ROT=119K.Tq on=2K, off= 1K, Pump @ 625 GPM= 1975 PSI w/80%flow. ECD=10.97 ppg WOB=2-5K, 80 RPM,Holding ROP to 125 FPH. 06:00 12:00 6.00 3,378 3,716 PROD1 DRILL DRLG P Drilling f/3378 to 3716'.TVD=3710', ART=3.66,AST=.3,ADT=3.96,Jar hrs=16.82 Bit hrs= 15.82. P/U=120K,S/O=120K, ROT=123K. Tq on=2K,off=1K, Pump @ 625 GPM=2050 PSI w/80%flow. ECD= 11.07 ppg WOB=2-5K,80 RPM, Holding ROP to 125 FPH. 12:00 18:00 6.00 3,716 4,119 PROD1 DRILL DRLG P Drilling f/3716'to 4119'.TVD=4113'. ART=4.07,AST= .48,ADT=4.65, Jars hrs=20.47, Bit hrs=20.47. P/U= 127K, S/O=127K, ROT= 129K.Tq on= 1-3K, off= 1K. ECD= 11.07 ppg. Pump @ 635 GPM=2125 PSI w/78%flow.WOB=3-7K, hold ROP @ 125 FPH. 18:00 00:00 6.00 4,119 4,447 PROD1 DRILL DDRL P Drilling f/4119'to 4447'.TVD=4441'. ART=3.42,AST=.35,ADT=3.77, Jars hrs=25.24, Bit hrs=24.24. P/U= 133K,S/O= 133K, ROT= 136K.Tq on=2-4K,off=1K. ECD= 10.91 ppg. Pump @ 644 GPM= 2250PS1 w/78%flow.WOB=3-10K, hold ROP @ 125 FPH. 03/12/2013 Drilled ahead f/4447'to 5045',TVD=5036'.Circulate HiVis sweep around and OWFF.Make wiper trip to 2361', no tight hole. RIH t/4955',wash last stand to bottom. Drilled f/5408'. TVD=5401'.ADT= 11.23 00:00 06:00 6.00 4,447 4,789 PROD1 DRILL DRLG P Drilling f/4447'to 4795'.TVD=4789'. ART=4.31,AST=0,ADT=4.31,Jar hrs=29.55, Bit hrs=28.55. P/U= 140K,S/O= 139K, ROT=141K, 80 RPM,Tq on=5-8K,off= 1K. Pump @ 640 GPM=2350 PSI,78%flow, WOB=5-8K. Page 16 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:30 3.50 4,789 5,045 PROD1 DRILL DRLG P Drilling f/4795'to 5045'.TVD=5036'. ART=2.71,AST=.15,ADT=2.86, j Jar hrs=32.41, Bit hrs=31.41. P/U= 144K, S/0=144K, ROT=148K. 80 RPMs,Tq on=1-3K, off= 1K, Pump @ 635 GPM=2350 PSI,78%flow, ECD= 10.96,WOB=5-7K. 09:30 10:15 0.75 5,045 5,045 PROD1 DRILL CIRC P Pump HiVis sweep around and circulate until hole cleaned up. Pump @ 640 GPM=2200 PSI,78%flow, 80 RPM w/1.5K. 10:15 10:30 0.25 5,045 5,045 PROD1 DRILL OWFF P Monitor well,static. 10:30 12:15 1.75 5,045 2,361 PROD1 DRILL TRIP P POOH f/5045'to 2361'.Good trip, no tight hole observed.Actual displacement=17 bbls, Calculated displacement=15.6 bbls. 12:15 13:00 0.75 2,361 2,361 PROD1 DRILL CIRC P CBU @ 600 GPM=1675 PSI, blow down top drive. 13:00 13:15 0.25 2,361 2,361 PROD1 RIGMN1SFTY P Hold PJSM on slip and cut drilling line. Discussed hand safety and using proper PPE when handling drilling line. 13:15 14:30 1.25 2,361 2,361 PROD1 RIGMN7 SLPC P Hang blocks,slip and cut 59'of drilling line. 14:30 15:15 0.75 2,361 2,361 PROD1 RIGMNTSVRG P Service rig. 15:15 17:30 2.25 2,361 4,955 PROD1 DRILL TRIP P PJSM, RIH f/2361'to 4955'.Good trip, no tight hole observed.Actual displacement=20.02 bbls, Calculated displacement=22.5 bbls. 17:30 17:45 0.25 4,955 5,045 PROD1 DRILL WASH P Wash and ream f/4955'to 5045', pump @ 630 GPM= 1700 PSI. 17:45 18:00 0.25 5,045 5,045 PROD1 DRILL CIRC P CBU @ 5048', pump @ 630 GPM= 1700 PSI. 18:00 00:00 6.00 5,045 5,408 PROD1 DRILL DRLG P Drilling f/5048'to 5408',TVD=5401'. ART=3.74,AST=.32,ADT=4.06, Jar hrs=39.59, Bit hrs=35.47, P/U= 150K, S/0=148K, ROT=151K, 80 RPMs,Tq= 1-3K,off=1K, Pump @ 641 GPM=2375 PSI,78%flow ECD= 11.01 ppg,WOB 1-5K. 03/13/2013 Drilled ahead f/5408'to TD at 6520',6513 TVD.Circulate HV sweep,3 BU and OWFF. Start making the wiper trip, at 5950'midnight, no tight hole observed. 00:00 06:00 6.00 5,408 5,692 PROD1 DRILL DRLG P Drill f/5408'to 5692'.TVD=5685' 'ART=4.88,AST=O,ADT=4.88,Jars hrs=44.47, Bit hrs=40.35. P/U= 156K,5/0=155K, ROT=160 K. 80 RPMs Tq on=3K, off=1.5K. Pump @ 642 GPM=2380 PSI,75%flow, ECD= 10.67 ppg,WOB=1-3K.Hold ROP @ 70 FPH to allow mud loggers to catch 10'samples. Page 17 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 12:00 6.00 5,692 5,950 PROD1 DRILL DRLG P Drill f/5692'to 5950'.ND=5943' ART=4.79,AST=0,ADT=4.79,Jars hrs=49.26, Bit hrs=45.14. P/U= 163K,S/O=159K, ROT=163 K.80 RPMs Tq on=2-3K,off=1.5K.Pump @ 642 GPM=2380 PSI,72%flow, ECD=10.67 ppg,WOB=3-5K. Hold ROP @ 70 FPH to allow mud loggers to catch 10'samples. 12:00 18:00 6.00 5,950 6,342 PROD1 DRILL DRLG P Drill f/5950't/6342',ND=6335' ART=5.2,AST=0,ADT=5.2,Jars hrs=54.46, Bit hrs=50.34,. P/U=172k,S/O=167k,ROT=172k, TQ on=2-7k,2k off.80 rpm,ECD 10.81 ppg @ 650 gpm/2625 psi, 71%flow.Vary ROP from 50-120 fph per geo/mudloggers. 18:00 21:00 3.00 6,342 6,520 PROD1 DRILL DRLG P Drill f/6342't/TD-6520'MD,6513' ND.ART=2.23,AST=0,ADT=2.23. Jar hrs 56.69, Bit hrs 52.57. P/U=175k,S/0=172k, ROT= 174k. TQ on=2-7k,2k off.80 rpm, ECD 10.79 ppg @ 645 gpm/2625 psi, 72%flow.SPR's @ TD w/9.8 ppg. 21:00 22:15 1.25 6,520 6,520 PROD1 EVALWE CIRC P Pump high vis sweep,circulate 3 x BU @ 630 gpm,2475 psi. 22:15 22:30 0.25 6,520 6,520 PROD1 EVALWE OWFF P Monitor well-static 22:30 00:00 1.50 6,520 6,520 PROD1 EVALWE WPRT P POOH on elevators f/6520'MD t/ 5950',calc disp 7.8 bbl,actual 11.22 bbl. 03/14/2013 Complete wiper trip, perform MAD pass per plan. POOH on elevators,hole in good condition. Remove sources,download data and L/D BHA.Begin testing BOPE to 250/3500 PSI,AOGCC rep John Crisp witnessed test. PROD1 EVALFN WPRT P 00:00 01:00 1.00 5,950 2,361Held PJSM and POOH f/5950'to shoe @ 2361'MD. Hole fill good, calc 26.52,actual 31.96 bbl. 01:00 01:15 0.25 2,361 2,361 PROD1 EVALFN OWFF P Monitor well at shoe for flow-Static 01:15 03:00 1.75 2,361 6,435 PROD1 EVALFN WPRT P RIH f/2361'MD to 6435'MD, Fill pipe every 20 stds.Calc displacement 34.32 bbl,actual 31.96 bbl 03:00 03:15 0.25 6,435 6,520 PROD1 EVALFN WPRT P Precautionary wash and ream f/ 6435'to 6520'@ 640 gpm,2425 psi, 73%flow,80 rpm&2k TQ. 03:15 04:30 1.25 6,520 6,520 PROD1 EVALFN CIRC P CBU x 3 @ 640 gpm,2425 psi,73% flow,80 rpm&2k TQ. 04:30 04:45 0.25 6,520 6,437 PROD1 EVALFN OWFF P Rack one stand back,pull f/6520'to 6437'MD and monitor well,static. 04:45 05:00 0.25 6,437 6,220 PROD1 EVALFN TRIP P POOH f/6437'MD to 6220'MD 05:00 12:00 7.00 6,220 5,257 PROD1 EVALFN SRVY P Perform MAD pass @ 293 gpm,800 psi,60 RPM @ 1.5k TQ, 100-120 fpm,4 intervals.6220'-6087', 5864'-5717',5689'-5537',5394-5257'. Page 18 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 5,257 2,352 PROD1 EVALFN TRIP P PJSM and POOH f/5257'to2352' MD @ 100 fpm/6000 fph,good hole fill. 14:00 14:15 0.25 2,352 2,352 PROD1 EVALFN OWFF P Monitor well at surface shoe, static, very slight drop. 14:15 15:00 0.75 2,352 600 PROD1 EVALFN TRIP P Continue POOH f/2352'to HWDP @ 600'. 15:00 15:15 0.25 600 600 PROD1 EVALFN OWFF P Monitor well at HWDP,static,very slight drop. 15:15 15:30 0.25 600 230 PROD1 EVALFN TRIP P Stand back HWDP and Jars in Derrick. 15:30 16:00 0.50 230 137 PROD1 EVALFN PULD P Held PJSM, laid down NM flex collars in pipe shed. 16:00 16:30 0.50 137 137 PROD1 EVALFN PULD P Held PJSM, removed sources. 16:30 18:30 2.00 64 64 PROD1 EVALFN PULD P Plug in and download tools 18:30 20:15 1.75 64 0 PROD1 EVALFN PULD P Continue UD BHA Calc displacement 52.32 bbl,actual 56.8 bbl. 20:15 20:45 0.50 0 0 PROD1 EVALFN PULD P Clean and clear rig floor 20:45 21:45 1.00 0 0 PROD1 WHDBO BOPE P Drain stack,pull wear bushing. 21:45 22:15 0.50 0 0 PROD1 WHDBO SEQP P Set test plug and R/U to test BOPE 22:15 22:45 0.50 0 0 PROD1 WHDBO SFTY P PJSM on testing BOPE 22:45 00:00 1.25 0 0 PROD1 WHDBO BOPE P Test BOPE to 250/3500 PSI.Test #1:Top rams,kill line check valve, CV 1,12, 13 and 14.Test#2: Upper IBOP, HCR kill, CV 9 and 11. AOGCC inspection John Crisp witnessed test. 03/15/2013 Complete testing of BOPE,witness by AOGCC rep John Crisp. R/D test equip, PJSM and R/U Halliburton wireline. M/U RDT run tools and RIH.Commence RDT logging run. 00:00 02:30 2.50 0 0 PROD1 WHDBO BOPE P Continue testing BOPE t/250/3500 psi 5 min ea. Lower IBOP,Manual Kill, C.V.#5,#8,#10, Dart valve, C.V.#4,#6,#7. Floor valve,C.V.#2. HCR Choke, Manual choke valve, Annular preventer, Lower pipe rams, Blind rams, C.V#3.Accumulator test: System pressure=2900 psi, pressure after closing all rams=1800 psi.Achieved 200 psi in 35 sec. Full pressure achieved in 215 seconds. 5 bollte average 2050 psi. H2S sensor #5 failed,changed out rain head and recalibrated, re-tested OK.Testing witnessed by AOGCC John Crisp. 02:30 03:15 0.75 0 0 PROD1 WHDBO BOPE P Drain stack, R/D test equipment, blow down kill line, choke line and choke. Install wear bushing. 03:15 03:30 0.25 0 0 PROD1 EVALFN SFTY P PJSM on R/U wire 03:30 05:00 1.50 0 0 PROD1 EVALFN RURD P Load and prep Halliburton tools for P/U 05:00 06:45 1.75 0 0 PROD1 EVALFN RURD P R/U Halliburton wireline equipment Page 19 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:45 09:45 3.00 0 0 PROD1 EVALFN RURD P M/U Wireline tools as per Halliburton rep. 09:45 00:00 14.25 0 0 PROD1 EVALFN ELOG P RIH and wireline RDT log.Work on MP2's,tighten drag chain in mud pits. Load pipe shed with P-100 7" casing and work on cleaning threads and strapping.Send out Sperry tools. 03/16/2013 Complete RDT logging run, POOH and L/D tools. Send fluid samples to lab per geo.M/U 8.5"Cleanout assy and RIH to 6520'CBU and POOH. R/U and RIH w/HES E-Line HRSCT-A tools. Inspected P100 pipe OK. 00:00 12:00 12.00 PROD1 EVALFN ELOG P PJSM-Continue running E-line RDT log. Clean P-110 casing for inspection. 12:00 13:45 1.75 PROD1 EVALFN ELOG P PJSM-POOH and L/D logging tools. Recover samples for shipping per Geo. 13:45 14:15 0.50 PROD1 EVALFN PULD P Clean and clear rig floor. 14:15 18:30 4.25 0 6,300 PROD1 EVALFN TRIP P Pick up cleanout assy, bit,sub, float, HWDP and Jars. RIH to 6300' MD filling pipe every 20 stands. Actual displacement=53.81 bbls, Calculated displacement=58.78 bbls. 18:30 19:00 0.50 6,300 6,520 PROD1 EVALFN WASH P Wash and ream f/6300'to 6520'. Pump @ 620 GPM= 1600 PSI. 19:00 20:00 1.00 6,520 6,520 PROD1 EVALFN CIRC P CBU X 3, pump @ 610 GPM=1600 PSI,40 RPMs w/1.5K Tq. P/U=162K, S/O=157K, ROT=151K. 20:00 20:15 0.25 6,520 6,520 PROD1 EVALFN OWFF P Monitor well,static. 20:15 20:45 0.50 6,520 6,028 PROD1 EVALFN TRIP P PJSM, POOH f/6520'to 6028'. Pump 12 bbl dry job @ 210 GPM= 500 PSI. 20:45 22:30 1.75 6,028 2,322 PROD1 EVALFN TRIP P POOH f/6028'to 2322'.Actual displacement=33.89 bbls, Calculated displacement=34.02 bbls. 22:30 23:00 0.50 2,322 2,322 PROD1 EVALFN CIRC P CBU @ 480 GPM=700 PSI. 23:00 23:30 0.50 2,322 2,322 PROD1 EVALFN OWFF P Monitor well,static. 23:30 00:00 0.50 2,322 PROD1 EVALFN TRIP P Blow down top drive. 03/17/2013 Cont. POOH w/clean out BHA. RIH on E-Line with HES HRSCT(side wall core)and Sonic/XRMI tools. 00:00 01:00 1.00 2,322 0 PROD1 EVALFN TRIP P PJSM,cont.to POOH f/2322'to surface.Actual displacement=24.4 bbls,Calculated displacement= 22.55 bbls. 01:00 01:30 0.50 0 0 PROD1 EVALFN OWFF P Clean and clear rig floor. Monitor well on trip tank,static. 01:30 02:45 1.25 0 0 PROD1 EVALFN RURD P PJSM, rig up HES E-Line and make up HRSCT tools. 02:45 17:00 14.25 0 0 PROD1 EVALFN ELOG P Logging with HRSCT(side wall core) tool. Cut 60 core samples. SIMOPS, swap out man rider winch and set to 300 lbs.Work on MP2's. Page 20 of 23 Time Logs Date From To Dur S_Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 PROD1 EVALFN PULD P PJSM, lay down HRSCT tools and pipe shed. Prep Wave Sonic tools in shed. 18:00 19:00 1.00 0 0 PROD1 EVALFN ELOG P PJSM,pick up Sonic Wave/XRMI HES E-Line tools. 19:00 00:00 5.00 0 0 PROD1 EVALFN ELOG P RIH on E-Line with Sonic/XRMI tool. SIMOPS, clean under drawworks, inspect and clean brake bands and linkage. 03/18/2013 Logging w/Sonic/XRMI tools.C/O logging tools to MRIUGEM/SGR tools. HES logging tool failure,trouble shoot and C/O tools. Log well w/MRIL/GEM/SGR tools. R/D E-Line and M/U clean out BHA. RIH w/clean out BHA to 5936'. 00:00 03:00 3.00 0 0 PROD1 EVALFN ELOG P PJSM, cont logging on HES E-Line w/Sonic/XRMI tools. 03:00 04:45 1.75 0 0 PROD1 EVALFN PULD P PJSM, lay down Wave Sonic/XRMI logging tools. Remove sources. 04:45 05:15 0.50 0 0 PROD1 EVALFN PULD P PJSM,make up MRIUGEM/SGR. Logging run#4. 05:15 07:00 1.75 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line. E-Line had tools failure, POOH w/E-Line. 07:00 07:30 0.50 0 0 PROD1 EVALFN ELOG T Change out HES E-line capacitor. 07:30 08:00 0.50 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line,test capacitor. Capacitor failed test, POOH. 08:00 09:15 1.25 0 0 PROD1 EVALFN ELOG T Trouble shoot HES E-Line tools. 09:15 10:30 1.25 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line,test tools.Tools failed test, cont.to trouble shoot tools. No go, POOH w/HES E-Line. 10:30 13:00 2.50 0 0 PROD1 EVALFN ELOG T Trouble shoot E-Line head.Change out magnet and make up new MRIUGEM/SGR tools. 13:00 18:15 5.25 0 0 PROD1 EVALFN ELOG P RIH w/HES E-Line.Test tools,good. Log well w/MRIL/GEM/SGR tools as per plan. 18:15 19:00 0.75 0 0 PROD1 EVALFN RURD P PJSM, L/D HES logging tools and rig down E-Line. 19:00 19:30 0.50 0 0 PROD1 EVALFN PULD P Clean and clear floor,prep to P/U BHA. 19:30 00:00 4.50 0 0 PROD1 EVALFN TRIP P PJSM,make up bit,bit sub,float HWDP and jars. RIH f/377'to 5936' filling pipe every 20 stands. P/U= 140K,S/O= 142K.Actual displacement=51 bbls, Calculated displacement=52.48 bbls. 03/19/2013 RIH with clean out BHA to 6520'MD,CBU X 3, BROOH to 6306'MD,Monitor well and POOH, LID BHA, Drain&flush stack, C/O ram to 7"and test same, R/U and run 7"casing to 2384'MD and CBU at shoe. 00:00 00:30 0.50 6,491 6,520 PROD1 EVALFN REAM P PJSM, Continue RIH T/6491'MD, P/U single wash&reasm T/6502' MD,500 gpm, 1250 psi,40 RPM, TQ=3 K, Soft fill F/6510'T/6520', P/U=157 K, S/O=146 K, Calc= 4.75 bbls,Actual=4.68 bbls. 00:30 02:15 1.75 6,520 6,520 PROD1 EVALFN CIRC P CBU X 3,with 610 gpm, 1625 psi,40 RPM,TQ=2.5 K. Page 21 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:15 04:00 1.75 6,520 6,306 PROD1 EVALFN REAM P BROOH,rack back stand every hr with 310 gpm,650 psi,40 RPM,TQ= 2.5 K to 6306'MD. 04:00 08:45 4.75 6,306 0 PROD1 CASING TRIP P PJSM,Monitor well, install rubber and POOH on elevators,Monitor well at shoe and hwtdp,UD BHA,Calc _56.6 bbls,Actual=62.2 bbls. 08:45 09:30 0.75 0 0 PROD1 CASING OWFF P Monitor well while clearing and cleaning rig floor.(Static) 09:30 10:30 1.00 0 0 PROD1 CASING OTHR P PJSM,Drain&flush stack,Pull wear ring. 10:30 12:00 1.50 0 0 PROD1 CASING OTHR P PJSM,Change out top set of rams to 7" 12:00 13:15 1.25 0 0 PROD1 CASING OTHR P Continue changing out rams to 7". 13:15 14:00 0.75 0 0 PROD1 CASING OTHR P PJSM,R/U and test 7"rams to 250/ 3500 psi for 10 min and chart same. 14:00 14:15 0.25 0 0 PROD1 CASING OTHR P Rig down test equipment. 14:15 17:30 3.25 0 0 PROD1 CASING RNCS P PJSM, Rig up to run 7"casing 17:30 22:45 5.25 0 2,384 PROD1 CASING RNCS P PJSM, Run 7"casing,baker lock, Float shoe, Float collar,test floats, install Bow spring centralizers on first three joints with stop rings&one centralizer every other joint to Joint 36,fill every 10 joints to 2384' 22:45 00:00 1.25 2,384 2,384 PROD1 CASING CIRC P CBU @ 2384'MD @ shoe with 4 bpm=400 psi, P/U=98 K,S/0=78 K,Calc=24.6 bbls,Actual=20.95 bbls. 03/20/2013 Finished running 7"casing,Circ&cond mud for cement,Cement as per program and bumped plug,CIP @ 15:40 hrs,L/D casing tools, Install 7"packoff and test same to 5000 psi,CIO rams and test doors. 00:00 01:30 1.50 2,384 3,369 PROD1 CASING RNCS P RIH with 7"casing F/2378'T/3369' MD, P/U= 115 K,S/0=92 K. 01:30 02:15 0.75 3,369 3,369 PROD1 CASING CIRC P CBU @ 3369'MD,2.5 bpm with 500 psi. 02:15 03:30 1.25 3,369 4,316 PROD1 CASING RNCS P RIH with 7"casing F/3369'T/4316' MD, P/U=140 K,S/O=120 K. 03:30 04:15 0.75 4,316 4,316 PROD1 CASING CIRC P CBU @ 4316'MD,3 bpm with 625 psi. 04:15 05:30 1.25 4,316 5,390 PROD1 CASING RNCS P RIH with 7"casing F/4316'T/5390' MD.P/U=170 K,S/O=145 K. 05:30 06:30 1.00 5,390 5,390 PROD1 CASING CIRC P CBU @ 5390'MD,3 bpm with 650 psi. 06:30 07:45 1.25 5,390 6,415 PROD1 CASING RNCS P RIH F/5390'T/6415'MD,M/U 5'pup &14.65'pup,M/U one full joint, Calc=40.3 bbls,Actual=35.7 bbls. 07:45 08:45 1.00 6,415 6,507 PROD1 CASING RNCS P M/U hanger with landing joint. Brk circ andf land hanger and shoe @ 6507'MD. 08:45 09:45 1.00 6,507 6,507 PROD1 CASING CIRC P CBU with franks fill up tool,3 bpm with 500 psi. 09:45 10:30 0.75 6,507 6,507 PROD1 CASING OTHR P L/D Franks tool, Blow down Top Drive and M/U cement head. 10:30 12:00 1.50 6,507 6,507 PROD1 CEMEN"CIRC P Circ and cond mud,4 bpm with 625 psi. Page 22 of 23 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:00 13:45 1.75 6,507 6,507 PROD1 CEMEN-CIRC P Cont.circ and cond mud, P/U= 195 K,S/O=165 K. 13:45 14:00 0.25 6,507 6,507 PROD1 CEMEN"SFTY P PJSM for cement job. 14:00 15:45 1.75 6,507 6,507 PROD1 CEMEN'CMNT P Shut down pumps, line up to SLB, pump 5 bbls CW 100,test lines to 3500 psi,bleed off&pump 20 bbls CW 100,shut down and blend mud push, pump 40 bbls of 11.5 ppg mud push,drop drop btm plug with 52.2 bbls of 15.8 ppg cement,dropdrop top plug with 20 bbls of water,shut down and swap over to rigand displace with 223 bbls 9.6 ppg mud at 6 bpm with 200 psi,land hanger, FCP=900 psi,bumped plug @ 2229 stks, pressured up to 1700 psi for 5 mins, bleed off and check floats, good. 15:45 17:30 1.75 0 0 PROD1 CEMEN'OTHR P R/D casing equipment and UD landing joint. 17:30 19:30 2.00 0 0 PROD1 CEMEN-OTHR P Install pack off and run in lock downs. 19:30 20:15 0.75 0 0 PROD1 CEMEN-OTHR P test pack off to 250/5000 psi for 5 mins each. 20:15 21:45 1.50 0 0 PROD1 CEMEN-OTHR P PJSM,Change out rams F/7"T/ 3.5"X 6.00"VBRs 21:45 22:15 0.50 0 0 PROD1 CEMEN-OTHR P PJSM, Held table top drill, R/U to freeze protect well. 22:15 23:00 0.75 0 0 PROD1 CEMEN'BOPE P PJSM, R/U to test top rams with 4" test joint. 23:00 00:00 1.00 0 0 PROD1 CEMEN-BOPE P Test Top Rams to 250/3500 psi and chart same for 10 mins. Page 23 of 23 Time Log & Summary ConocoPhillips Wel!view Web Reporting Report Well Name: CASSIN 1 Rig Name: DOYON 141 Job Type: INITIAL COMPLETION Rig Accept: 3/21/2013 12:01:00 AM Rig Release: 3/28/2013 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/21/2013 24 hr Summary L/D test 4"joint&R/D test equipment, R/U and perform LOT on OA, Flush with 75 bbls water followed by 70 bbls of diesel, R/U and lay down 5"dp from derrick,slip&cut drlg line,C/O saver subs, Load shed with 4"dp and strap same, M/U clean out BHA and RIH with picking up 4"dp. 00:00 00:15 0.25 0 0 COMPZ CEMEN"BOPE P R/D test equipment,drain stack, L/D test joint. 00:15 00:45 0.50 0 0 COMPZ CEMEN"LOT P R/U and perform LOT on OA, (9-5/8 X 7) 00:45 02:00 1.25 0 0 COMPZ CEMEN'OTHR P Flush OA with 75 bbls of water @ 2 bpm with 275 psi, FCP=350 psi. 02:00 03:00 1.00 0 0 COMPZ CEMEN-FRZP P PJSM, R/U Little Red and test lines to 2000 psi, pump 75 bbls diesel for freeze protection do 9-5/8"X 7", ICP=800 psi, FCP=400 psi at 2 bpm. 03:00 09:00 6.00 0 0 COMPZ CEMEN'PULD P PJSM, L/D 5"dp via mouse hole. 09:00 09:30 0.50 0 0 COMPZ CEMEN-OTHR P Set 6-3/4"ID wear bushing and L/D mouse hole. 09:30 11:00 1.50 0 0 COMPZ CEMEN-SLPC P PJSM,Slip and cut drilling line, service Top Drive and drawworks. 11:00 12:00 1.00 0 0 COMPZ CEMEN`OTHR P Change Top Drive over to 4"saver sub 12:00 14:00 2.00 0 0 COMPZ CEMEN'OTHR P PJSM,C/O saver sub bell guide and grabber dies. 14:00 17:15 3.25 0 0 COMPZ CEMEN OTHR P Load shed with 207 joint of 4'dp, strap same load BHA,while continue cleaning pits. 17:15 00:00 6.75 0 5,264 COMPZ CEMEN'TRIP P PJSM,M/U clean out BHA,single in the hole with 4"dp to 5043'Rotate and ream x 3 with 80 RPM,Tq= 1.5 K, P/U=103 K, S/O= 101 K. Continue single in F/5043'T/5264' Calc=29.5 bbls,Actual=29.0 bbls. 03/22/2013 Clean out at each pert and packer interval while RIH, drlg stringer&cement down to 6419'MD, CBU, R/U and test 7"casing to 3500 psi,Good, Blow down lines and continue cleaning pits for filtered brine swap, Flush all lines and equipment out,clean pits again, Mix spacers and pump, reverse out Pickle fluid with 300 bbls water. 00:00 02:30 2.50 5,264 6,335 COMPZ CEMEN'COCF P PJSM, RIH and clean up perf& packer depths by Recip&Rot X 3 at each interval @ 5268',-5273', 5322', 5535'-5550',5599',5710'-5725', RIH to 6335'MD, P/U=120 K,S/0=115 K. 02:30 03:30 1.00 6,335 6,419 COMPZ CEMEN'COCF P Drlg cement stringers and cement F/ 6335' T/6419'MD,with 6 bpm, 1000 psi,40 RPM,WOB=3-10 K,Tq=1.5 K. Page 1 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 6,419 6,419 COMPZ CEMEN'CIRC P CBU @ 6419'MD 6 bpm, 1000 psi, 40 rpm,Tq=1.5 K. 04:00 05:00 1.00 6,419 6,419 COMPZ CEMEN"PRTS P R/U and test 7"casing to 3500 psi, record on chart for 30 min(Good) 05:00 05:30 0.50 6,419 6,419 COMPZ WELLPF PRTS P R/D Test equipment and Blow down lines. 05:30 11:00 5.50 6,419 6,419 COMPZ WELLPF OTHR P Continue cleaning mud pits,C/O 4" gate valve on#2 mud pump. 11:00 12:00 1.00 6,419 6,419 COMPZ WELLPF OTHR P Take on 150 bbls water in pit 6 to mix cleaning pill. 12:00 15:45 3.75 6,419 6,419 COMPZ WELLPF OTHR P PJSM,Continue mixing cleaning pill, flush all pit lines,manifolds,mud cleaning equipment,pumps,and kill line. 15:45 21:30 5.75 6,419 6,419 COMPZ WELLPF OTHR P Re-clean pits,build 35 bbl Hi Vis spacer in pill pit,move to pit#4 and build#2 25 bbl Hi-Vis spacer. 21:30 22:00 0.50 6,419 6,419 COMPZ WELLPF SFTY P PJSM,on displacement of brine with all involved, (Crew and truck drivers) 22:00 00:00 2.00 6,419 6,419 COMPZ WELLPF CIRC P Displace well as per-MI procedure, pumped 25 hi-vis sweep followed by deepclean,69 bbls water,line up and reverse 250 of 300 bbls of water, P/U=105 K,8/0=105 k,200 gpm with 500 psi. 03/23/2013 Build 100 bbl hi-vis spacer and wait on brine truck from Alpine,pump phase two as per-MI plan,shut down and clean under shakers,NTUs=22.7,POOH and UD BHA, R/U and test BOPE,R/D same, install wear ring. Nipple up shooting flange on stack. 00:00 04:00 4.00 6,419 6,419 COMPZ WELLPF OTHR P PJSM, Build 100 bbls of spacer wash in pit#5,wait on brine truck from Alpine,clear rig floor of unecessary tools. 04:00 07:15 3.25 6,419 6,419 COMPZ WELLPF CIRC P PJSM, Pump Phase 2 displacement, displace well per-plan @ 5 bpm with 450 psi while reciprocating&rotating string. P/U=115 K,S/0=112 K,80 RPM,Tq=2.7 K. 07:15 09:15 2.00 6,419 6,419 COMPZ WELLPF OTHR P Shut down pumps,clean under shakers&troughs,pump adittional 38 bbls and check NTUs=22.7 with 9.0 ppg brine. 09:15 12:00 2.75 6,419 705 COMPZ WELLPF TRIP P PJSM, UD 2 joints dp,POOH T/ 705, P/U=115 K,S/0=112 K, Calc=32.4 bbls,Actual=34.4 bbls. 12:00 12:15 0.25 705 705 COMPZ WELLPF SFTY P PJSM,on POOH&UD BHA. 12:15 12:30 0.25 705 0 COMPZ WELLPF PULD P POOH&UD BHA 12:30 12:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM on R/U BOP testing equipment. 12:45 14:00 1.25 0 0 COMPZ WELLPF BOPE P R/U testing equipment for BOP test. 14:00 14:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM,testing BOPE. Page 2 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 21:15 7.00 0 0 COMPZ WELLPF BOPE P Test with 4"test joint.Test#1=Top Rams,Valves 1, '12, 13, 14 and manual kill.Test#2=Upper IBOP, HCR kill,valves 9,11 and 3.Test# 3=Lower IBOP,valves 5, 8,and 10, kill line check valve.Test#4=Dart valve,valves 4,6,7 and 5.Test#5= Floor valves,valves 2 and 6.Test# 6=HCR choke.Test#7=Manual choke, HCR kill,valve 8.Test#8= Annular.Test#9=Lower pip rams. Test#10=Blind rams.valve 3. System pressure 3000 psi, pressure after closing 1700 psi,200 psi attained=52 sec, Full pressure attained 206 sec. Nitrogen avg. 1975 psi.Test with 3.5"test joint, upper rams, lower rams,and annular preventer. (State Rep.Chuck Scheve waived witness of test) 21:15 22:00 0.75 0 0 COMPZ WELLPF BOPE P PJSM, R/D test equipment,set wear ring, blow down lines. 22:00 22:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on N/U shooting flange 22:15 00:00 1.75 0 0 COMPZ WELLPF OTHR P N/D riser&riser adapter, Prep API ring goove for shooting flange. 03/24/2013 Finished N/U of shooting flange, PJSM, R/U wire line, PT riser&lubricator to 2000 psi, Run CBL, UD logging tools,replace riser with lubricator and retest to 2500 psi, Made three runs,all on depth and all shots fired, POOH and R/D E-line, N/U down shooting flange and N/U riser and flowline. PJSM and P/U clean out BHA. 00:00 01:00 1.00 0 0 COMPZ WELLPF OTHR P PJSM,Continue N/U shooting flange. 01:00 02:30 1.50 0 0 COMPZ PERF ELOG P PJSM, R/U wire line and P/U tools. 02:30 03:30 1.00 0 0 COMPZ PERF ELOG P M/U wire line tools, (Cast) 03:30 04:15 0.75 0 0 COMPZ PERF ELOG P Pressure test shooting flange, lubricator head to 2000 psi and record on chart. 04:15 08:30 4.25 0 6,419 COMPZ PERF ELOG P RIH with CBL tool and log run, POOH. 08:30 09:30 1.00 0 0 COMPZ PERF ELOG P PJSM, L/D CBL tools. 09:30 11:00 1.50 0 0 COMPZ PERF PERF P PJSM, Replace 7'riser with 5" lubricator on BOP stack. 11:00 12:00 1.00 0 0 COMPZ PERF PERF P PJSM, load guns into pipe shed. 12:00 13:15 1.25 0 0 COMPZ PERF PERF P PJSM,M/U perf gun run#1, pressure test lubricator to 2500 psi and chart for 10 min. 13:15 14:30 1.25 0 5,725 COMPZ PERF PERF P RIH with perf guns run#1 @ 5710'- 5725'and fire guns, No pressure, gain or loss observed. 14:30 15:30 1.00 0 0 COMPZ PERF PERF P R/D spend guns and M/U run#2, Pressure test lubricator to 2500 for 5 min. 15:30 16:45 1.25 0 5,535 COMPZ PERF PERF P RIH with perf gun run#2, Fire guns on depth @ 5535'-5550', POOH, No pressure,gain or loss observed. Page 3 of 8 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:45 17:30 0.75 0 0 COMPZ PERF PERF P R/D spent guns, M/U run#3, pressure test lubricator to 2500 psi for 5 min. 17:30 18:45 1.25 0 5,273 COMPZ PERF PERF P RIH with perf gun run#3, Fire guns on depth @ 5258'-5273', POOH, No pressure,gain or loss observed.All shots fired. 18:45 19:00 0.25 0 COMPZ PERF SFTY P PJSM, Rigging down e-line. 19:00 20:00 1.00 0 0 COMPZ PERF PERF P Rig down E-line 20:00 20:15 0.25 0 0 COMPZ WELLPFSFTY P PJSM on N/D shooting flange and N/U riser. 20:15 22:30 2.25 0 0 COMPZ WELLPF OTHR P N/D shooting flange, N/U riser adapter and riser, clear floor strap tools and B/D kill line. 22:30 22:45 0.25 0 0 COMPZ WELLPFSFTY P PJSM,on HRC M/U BHA 22:45 00:00 1.25 0 0 COMPZ WELLPF PULD P M/U De-burring BHA run 03/25/2013 M/U cleanout BHA and complete de-burring run.CBUX2 clean brine in well. M/U lower completion per Completion eng and service reps. Run in on 4"DP,correlate with Eline. 00:00 00:45 0.75 0 COMPZ WELLPF PULD P PJSM-Continue picking up De-Burring cleanout assy. 00:45 03:15 2.50 0 5,207 COMPZ WELLPF TRIP P RIH t/1214'MD, P/U Well Patroller, continue RIH t'5207'MD on 4"DP. P/U=105k, S/0=105k, Calc bbl =35.4,Actual bb1=35.4. 03:15 06:15 3.00 5,207 5,865 COMPZ WELLPF CIRC P Break circ @ 5207'Establish Circ and Rot parameters,2 bpm 100 psi, 80 RPM,TQ 2-3k, Polish f/ 5207'-5742'MD. Ream thru perfs 5268'-5273',5535'-5550',5710-5725' 3 X up and down. Continue ream t15865'. Rot wt. 108k, P/U=112k, S/0=112k. 06:15 06:45 0.50 5,865 5,207 COMPZ WELLPF OWFF P Monitor well, POOH t/5207'MD. P/U-112k,S/O-112k.Calc bbl=3.8, Actual bbl=4.1. 06:45 07:45 1.00 5,207 5,207 COMPZ WELLPF CIRC P CBU X 2 @ 5207'MD,5 bpm @ 510 psi. 07:45 08:15 0.50 5,207 5,207 COMPZ WELLPF OWFF P B/D Top Drive, Monitor well(Static), Drop 2"OD Rabbit on wire. 08:15 12:00 3.75 5,207 0 COMPZ WELLPF TRIP P PJSM-POOH L/D BHA.Actual bb1=37.6,Calc bb1=35.4 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM-Clean and clear rig floor. R/U Tubing equipment. 12:15 13:15 1.00 0 0 COMPZ RPCOM RURD P R/U 3-1/2"Tools and equipment, mob tools to the rig floor. 13:15 15:45 2.50 0 714 COMPZ RPCOM RCST P M/U 3-1/2"Lower completion assy per Baker,SLB and Completion Engineer. 15:45 16:00 0,25 714 714 COMPZ RPCOM SFTY P PJSM-Tripping in with Completion assy. 16:00 20:00 4.00 714 5,718 COMPZ RPCOM TRIP P RIH w/4"DP to 5715', P/U=107k, S/0=106k Calc bbl= ,Actual bbl= 20:00 20:30 0.50 5,718 5,718 COMPZ RPCOM CIRC P Circulate 70 bbls,(Pipe Volume)at 3 bpm with 300 psi. Page 4 of 8 .. ._._.____. .. Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:30 21:00 0.50 5,718 5,718 COMPZ RPCOM SFTY P PJSM R/U Halliburton Eline, RA/CCL 21:00 23:15 2.25 5,718 5,718 COMPZ RPCOM ELOG P R/U HES E-Line, PT lubricator to 2500 psi for 10 min. 23:15 00:00 0.75 5,718 5,718 COMPZ RPCOM ELOG P RIH with GR/CCL logging tool and correlate setting depth. 03/26/2013 Finish correlation and put packers on depth, R/D e-line,drop 1"ball&test lines to 4000 psi, Ball did not seat, dropped 1.5"ball and did not seat, Call out HES slick line, R/U and test lubricator to 3500 psi, RIH with LIB, discuss with town to run Ball&Rod on slick line,worked ball&rod through upper frac sleeve and chased ball on seat, Pressured up to 3500 psi with packer on depth and charted same, bleed off and R/U and test IA to 1500 psi for 15 min. good. 00:00 00:45 0.75 5,718 5,718 COMPZ RPCOM ELOG P PJSM,Continue running wire line, GR/CCL for corelation to set packers on depth. 00:45 02:15 1.50 5,718 5,718 COMPZ RPCOM ELOG P PJSM, R/D HES wire line and lubricator. 02:15 03:00 0.75 5,718 57,018 COMPZ RPCOM OTHR P Drop 1"ball, R/U circulating lines and test to 4000 psi.good. 03:00 04:00 1.00 5,718 5,704 COMPZ RPCOM CIRC P P/U 14'and put packers on depth, pump @ 2 bpm with 200 psi, pumped 100 bbls and attempt to surge pressure to seat ball with no luck. 04:00 04:15 0.25 5,704 5,710 COMPZ RPCOM CIRC T Reverse circulate 10 bbls at 2 bpm and 100 psi. 04:15 04:45 0.50 5,704 5,704 COMPZ RPCOM CIRC T Break circ down dp and pumpe 25 bbls @ 4 bpm with 500 psi,ball did not seat, reduce pump rate to 2 bpm 180 psi and call town. 04:45 05:30 0.75 5,704 5,704 COMPZ RPCOM CIRC T Drop 1-1/2"ball and pump down @ 2 bpm 180 psi, P/U=108K, S/O= 108K, pumped 100 bbls and did not seat ball.Called town. 05:30 07:00 1.50 5,704 5,704 COMPZ RPCOM OTHR T R/D circulating lines and blow down kill line.Call town to discuss options. 07:00 07:30 0.50 5,704 5,704 COMPZ RPCOM CIRC T M/U Top Drive and establish circ @ 2 bpm 180 psi, Rotate 25 RPM,Tq= 1 K,pump 20 bbls with no luck on seating ball,shut down and blow down TD. 07:30 08:30 1.00 5,704 5,704 COMPZ RPCOM CIRC T Dump one vis cup of polymer down dp and R/U and place pipe on depth, break circ. @ 2 bpm with 150 psi and pumped 80 bbls with no luck. 08:30 12:00 3.50 5,704 5,704 COMPZ RPCOM OTHR T R/D and blow down circulating equipment and wait on slick line trunck from Alpine. 12:00 14:45 2.75 5,704 5,704 COMPZ RPCOM OTHR T PJSM,wait on slick line and clean rig. 14:45 15:45 1.00 5,704 5,704 COMPZ RPCOM OTHR T L/D Top single and P/U 10.02'& 9.50'pup jts and set slips with packers on depth to make up lubricator. 15:45 16:00 0.25 5,704 5,704 COMPZ RPCOM SFTY T PJSM with slick Line crew on rigging up. Page 5 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:45 2.75 5,704 5,704 COMPZ RPCOM SLKL T Position truck and R/U wire line and lubricator and test lubricator to 3500 psi. 18:45 20:00 1.25 5,704 5,704 COMPZ RPCOM SLKL T RIH with slike line and Lead Impression Block,Tagged up on shear out valve @ 5704'MD, P/U 2' with slick line and attempt to pressure up with packers on depth, No Go. 20:00 21:00 1.00 5,704 5,704 COMPZ RPCOM SLKL T POOH with wire line, inspect LIB, Looks like ball is on seat,Consult engineer decision made to run Ball& rod down on slick line. 21:00 21:30 0.50 5,704 5,704 COMPZ RPCOM SLKL T M/U Ball&Rod on wire line, PT lubricator to 3500 psi. 21:30 22:30 1.00 5,704 5,704 COMPZ RPCOM SLKL T PJSM with Halliburton crew change, RIH with ball rod to 5103'MD tagged up on Frac sleeve attempt to circ rod through @ 3 bpm 350 psi,chase ball to bottom and on seat with Ball& Rod. 22:30 00:00 1.50 5,704 5,704 COMPZ RPCOM PRTS P Ball seated, and pressured up to 3500 psi and set packers on depth with 3500 psi for 30 min,charted, Bleed pressure and R/U to test IA. 03/27/2013 Test IA to 1500 psi, R/D slick line,Release from packers, POOH with dp, Flush stack, R/U to run TBG, RIH W/TBG and Fiber Optic control line,Confirmed No-Go,Circ inhibited brine, Space out with pups and Change over to 4 1/2"handling equipment. 00:00 00:30 0.50 5,704 5,704 COMPZ RPCOM PRTS P PJSM,test IA to 1500 psi for 15 mins and record on chart. 00:30 01:30 1.00 5,704 5,704 COMPZ RPCOM SLKL P PJSM, R/D slick line unit. 01:30 01:45 0.25 5,704 4,992 COMPZ RPCOM PRTS P P/U single,set down 16 K, P/U observed 5 K overpull set back down 16 K, P/U over 5 K, not released, M/U Top Drive and pressure up to 3000 psi,set down 20 K, Observed release from packer assembly,P/U wt to 97 and bleed off. 01:45 02:30 0.75 4,992 4,892 COMPZ RPCOM OWFF P Monityor well, L/D 3 joints dp and 2 pups. 02:30 03:00 0.50 4,892 3,868 COMPZ RPCOM TRIP P POOH to 3868'MD, Calc=28.0 bbls, Actual=30.5 bbls. 03:00 04:00 1.00 3,868 3,868 COMPZ RPCOM SVRG P Service drawworks and rig 04:00 06:30 2.50 3,868 0 COMPZ RPCOM TRIP P Continue POOH, L/D running tool and clear floor. 06:30 07:00 0.50 0 0 COMPZ RPCOM OTHR P Drain stack and pull wear ring. 07:00 07:45 0.75 0 0 COMPZ RPCOM OTHR P R/U and flush stack with 9 bpm 390 psi. 07:45 10:00 2.25 0 0 COMPZ RPCOM RCST P PJSM, R/U casing equipment, P/U SLB spooler and rig up sheave and fiber optic line. 10:00 12:00 2.00 0 75 COMPZ RPCOM RCST P PJSM, RIH with 3.5"TBG to 75'MD, M/U fiber optic to solid guage mandrel and test to 5000 psi for 15 min. Page 6 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 75 75 COMPZ RPCOM RCST P PJSM, Run completion with control line.Continue M/U fiber optic line and test. 12:15 20:15 8.00 75 4,946 COMPZ RPCOM RCST P RIH with 3.5"TBG as per detail, P/U 4 space joint,Calc= 17.7 bbls, Actual=17.5, P/U=69K, S/O=70K. 20:15 21:00 0.75 4,946 4,962 COMPZ RPCOM RCST P M/U Circ. head on jt#160. 21:00 21:15 0.25 4,962 4,962 COMPZ RPCOM CIRC P Space out and circ @ lbpm inhibited brine down with 80 psi and increased to 280 psi when stung into PBR. 21:15 22:00 0.75 4,962 4,962 COMPZ RPCOM PULD P Space out and locate in PBR, set down 20 K to confirm No-Go location. 22:00 22:45 0.75 4,962 4,962 COMPZ RPCOM CIRC P Circ 145 bbls of inhibited brine,shut down and pump 45 bbl of uninhibited brine 22:45 23:30 0.75 4,962 4,962 COMPZ RPCOM PULD P LID 3joints, P/U 2.40',4.18', 10.14' and 10.16'pup joints X-Over to 4.5" IBTM 23:30 00:00 0.50 4,962 4,962 COMPZ RPCOM OTHR P C/O handling equipment to 4.5". 03/28/2013 M/U fiber optic and land hanger,test same,PT do IA to 1000 psi,Monitor well,test TBG 3500 psi bleed down 2000&Pressure up IA 3500 psi, dump and shear out valve,set 2-way check and test to 2500 psi, and in direction of flow 2500 below,N/D BOP, N/U adapter&tree,test to 5000 psi, Pull 2-way and pump 70 bbls diesel and let u-tube,set BPV&secure tree, L/D 4"dp from derrick, R/D for move. (Rig Released @ 24: 00 hrs 3/28/2013) 00:00 01:00 1.00 4,962 4,962 COMPZ RPCOM RCST P PJSM,M/U 1 joint of 4.5"TBG,M/U hanger with landing joint with circ x-over. 01:00 01:30 0.50 4,962 4,962 COMPZ RPCOM OTHR P M/U fiber optic line to hanger and test to 5000 psi. 01:30 02:15 0.75 4,962 5,010 COMPZ RPCOM RCST P Land hanger and RILDS, clear floor. 02:15 03:30 1.25 5,010 5,010 COMPZ RPCOM PRTS P R/U and PT down IA to 1000 psi for 10 min and chart the lower seals. Monitor well. 03:30 04:30 1.00 5,010 5,010 COMPZ RPCOM PRTS P Test 3.5"TBG to 3500 psi, 15 min and chart, Bleed psi down to 2000 psi and pressure up to 3500 on IA for 15 min and dump TBG psi and shear out DCR-1 valve. 04:30 05:00 0.50 5,010 5,010 COMPZ RPCOM PULD P R/D Circ equipment, back out landing joint,set 2-way check valve. 05:00 06:00 1.00 5,010 5,010 COMPZ RPCOM PULD P Install landing joint, PT down on 2-way check to 2500 psi and chart, R/U and test 2-way check from below in direction of flow and hanger seals to 2500 psi and chart 06:00 07:00 1.00 5,010 5,010 COMPZ RPCOM OTHR P Blow down and R/D circ lines and suck out stack. 07:00 08:45 1.75 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/D BOP stack. 08:45 10:00 1.25 5,010 5,010 COMPZ RPCOM NUND P N/U, Install S.B.M.S. in TBG hanger, Install&test fiber optic line through port on spool. 10:00 12:00 2.00 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/U Adapter flange&tree. Page 7 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/U tree. 13:00 14:45 1.75 5,010 5,010 COMPZ RPCOM OTHR P R/U scaffoldingin cellar,Continue N/U tree,test bonnet flange to 5000 psi for 10 min.Witnessed, SIM-OPS R/U hard lines and hoses for freeze protection. 14:45 16:45 2.00 5,010 5,010 COMPZ RPCOM PRTS P R/U test equipment to tyest tree, test lubricator and tree to 5000 psi for 10 min,charted and pull 2-way check valve. 16:45 18:00 1.25 0 0 COMPZ RPCOM FRZP P PJSM, Pump 70 bbls of diesel for freeze protection @ 1.4 bpm 200 psi, 1.5 bpm with 450 FCP. SIM-OPS, PJSM lay down 4"dp via mouse hole. 18:00 18:30 0.50 0 0 COMPZ RPCOM OTHR P Blow down freeze protection lines, Put IA&TBG in communications to u-tube. 18:30 20:30 2.00 0 0 COMPZ RPCOM PULD P Coninue laying down 4"dp from derrick via mouse hole. 20:30 22:00 1.50 0 0 COMPZ RPEQP1 OTHR P Blow down u-tube lines and rig down, set BPV, install blanking flanges on OA, IA and tree,secure well. (OA=100 psi, IA=0 psi,TBG=0 psi.) Disconnect outside choke line and clean Polution pan,clean cellar box. 22:00 23:15 1.25 0 0 COMPZ RPCOM PULD P Continue laying down 4"dp. 23:15 00:00 0.75 0 0 COMPZ MOVE RURD P Prep for rig move. (Rig released at 24:00 hrs 3/28/2013) Page 8 of 8 Time Log & Summary ConocoPhillips Wel/view Web Reporting Report Well Name: CASSIN 1 Rig Name: Job Type: TEST-LOG-PROFILE Rig Accept: Rig Release: Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04/02/2013 24 hr Summary Started Expro well site generator. Erected 90'flare. Lay secondary containment liner for gas line to flare. Hooched in sand trap. Rig up 3"1502 hardline from wellhead to choke. Framed in hooch for secondary tanks. Borough inspectors visited the site and found the pad in good order. 00:00 00:00 24.00 COMPZ FLOWT RURD P Rig up Expro well test equipment, flow back tanks and well intervention tanks. 04/03/2013 All flow back lines laid in place, sparge,sand,gas to flare and tank tackle lines. Routed electrical cables. Lost generator diesel driver on 4 phase separator unit ordered replacement. Notified BLM of intent to stimulate well on Friday as per Sundry approval. SLB fracture equipment staged over containment. SLB tanks connected via manifold and under heat. 00:00 00:00 24.00 COMPZ FLOWT RURD P All flow back lines laid in place, sparge,sand,gas to flare and tank tackle lines. Routed electrical cables. Lost generator diesel driver on 4 phase separator unit ordered replacement expect portable backup unit to arrive tomorrow mid morning. Notified BLM of intent to stimulate well on Friday as per Sundry approval. Hooked up power to well site envirovac and turned on heat. SLB fracture equipment staged over containment. SLB tanks connected via manifold and under heat. 04/04/2013 Rigged up poly flow air lines to ESD stations,grounded all equipment, removed two secondary storage tanks and added one new tank. Completed frac rig up less stinger and began heating frac tanks. 00:00 05:45 5.75 COMPZ FLOWT RURD P Rig up poly flow line air system to ESD stations. Ground all equipment to the wellhead. Marry up electrical cables in neat bundles,clear walking and working surfaces of trip hazards. 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. Page 1 of 12 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:45 07:15 0.50 COMPZ FLOWT RURD P Inspected enviro vac, heaters on and functioning. Ordered out water, issues with trucking supply,down on drivers, ETA Friday midday for functonal enviro vac. Full C&D dumpster swapped out for empty. Two empty bins on location. 07:15 07:45 0.50 COMPZ FLOWT RURD P Inspected secondary tanko and atigun tank numbers CTU-05 and 1804 respectively. Both tanks have weir inplace with no flow through and no way to empty 3/4 of the tank capacity less a hose over the top. Ordered replacement 400 bbl tank from Kuparuk stock. 07:45 08:15 0.50 COMPZ FLOWT RURD P Installed T,gauge, and valve to SSV hydraulic actuator. Pumped open SSV with enerpack and installed fusible cap. 08:15 09:15 1.00 COMPZ FLOWT RURD P Installed stick built scaffolding on well house roof for access to stinger tree saver. 09:15 12:00 2.75 COMPZ FLOWT RURD P SLB stimulation crew continuing to rig up fracture equipment. Spot relief tank, GORY, and FracCat. 12:00 13:00 1.00 COMPZ FLOWT RURD P Wells support crew installed 2 1/4"x 2"1502 integral flange on inner annulus companion valve and installed back side treating line. 13:00 16:00 3.00 COMPZ FLOWT RURD P Rigged down tank tackle to 2 secondary flow back tanks with weir, lowered revetment walls and removed tanks from location. Spotted one replacement tank in revetment and re installed tank tackle/berm walls. 16:00 17:45 1.75 COMPZ FLOWT RURD P Air test separator vessel(low pressure test). 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 18:15 23:15 5.00 COMPZ FLOWT RURD P Continue to rig up EXPRO well test equipment, LRS heating tanks, Wells support pressure testing support treating iron. 04/05/2013 Hooked up generator power to heater and 4 phase separator unit. Air tested all surface lines from well to tanks. Wrapped all lines in blankets. 00:00 05:45 5.75 COMPZ FLOWT RURD P Depthed all gauge tanks and set tops. Page 2 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. Need to focus on turning in RIR cards as numbers have been low. Pinch points when wrapping lines in blankets. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 10:45 4.00 COMPZ FLOWT RURD P Lay out line blankets to wrap surface lines. Contacted Doyon 141 rig electrician and walked down job to get power to heater and 4 phase separator. Rigged down and staged envirovac generator in separator containment near 4 Phase generator. Applied heat to switch gear and cables.waiting for electrician to return to tie in equipment.. 10:45 11:00 0.25 COMPZ FLOWT RURD P Updated BLM(Justin Miller)with regard to changed stimulation schedule via e-mail and sat phone message per sundry stipulation. 11:00 14:00 3.00 COMPZ FLOWT RURD P Complete frac rig up including stinger. 14:00 17:45 3.75 COMPZ FLOWT RURD P Doyon 141 electrician returned and wired line heater to 25 kw 208 VAC gen set and 4 phase test separator to 35 kw 3 phase 480 VAC. 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 18:15 20:45 2.50 COMPZ FLOWT RURD P Low pressure air test all surface lines from well head to tank farm. Blow air through riser to return tanks to ensure open flow path. Found frozen riser in tank#25 rain for rent tiger tank,added heat to line. 20:45 00:00 3.25 COMPZ FLOWT RURD P Raise stack on heater unit and quick test same. Unit ready for glycol addition to bath and fuel then test fire. Replace transmitter on coreolis gas meter and test same. 4"Daniel meter on scrubber stack ops checked. 04/06/2013 Performed fracturing stimulation treatment on exploration well Cassin 1. Fracced the Sanford, Blackburn,and Cassin formations,placing 90,370#, 100,551#,and 119,022#proppant, respectively. Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation stages. Pumped 3604-bbl total slurry volume,25#x-link gel with linear gel flushes,309,943#total 16/20 CarboLite (100%design). Freeze protected well with 26-bbl diesel. 00:00 05:45 5.75 COMPZ FLOWT RURD P Rig up well test equipment Page 3 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil. li Pressure and high activity on front side of well house. Expro to stay out of SLB work zone. Gauge installed on Epro well line to monitor during frac for any pressure bypass of double block isolation. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:45 2.00 COMPZ FLOWT RURD P Frac crew on location. Three heaters down over the night. Borrowing heaters from Expro to cover PCM and misc frozen valves. SLB warming equipment. On Expro side, two rental truck dead, COP pickup dead, newly installed 38 KW gen set hooked to 4 phase test separator down, low oil alarm,three heaters down and two light plants. Called out Peak mechanic and nonmobile equipment mechanic. 08:45 09:30 0.75 COMPZ FLOWT RURD P Frac wells supervisor on location. Hold pre job with Cassin-1 fuelers, ACS,and Expro. Frac pumps started and warming up. BLM (Justin Miller)on location to witness stimulation. Lost all communication at Canning river camp. 09:30 10:30 1.00 COMPZ FLOWT RURD P Frac pre job safety meeting 10:30 11:30 1.00 COMPZ FLOWT RURD P Frac PT to 7000 psi/4000 psi back side(LRS)and start job. Road to Doyon 141 to use phones to contact telecom support. Make necessary notifications. 11:30 16:30 5.00 COMPZ FLOWT RURD P Off loaded N2 racks from DTH and staged on site. Telecom support on location diagnosing problem. Fiber optic/copper conductor line crossing pad from telecom hut to Canning river camp was compromised by a loader strike approx 3 weeks ago. Lines were exhumed, repaired and reburied. It appears as if the fiber line has failed. Suspect splice repair. Switched comms to copper conductor line. Comms back on approx 4:30 pm. 16:30 17:45 1.25 COMPZ FLOWT RURD P Frac complete all three stages pumped as designed with flush. monitor pressures 30 minutes and begin to rig down. Page 4of12 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed pressure test procedure, simops with SLB stimulation crew and LRS hot oil. 18:15 20:45 2.50 COMPZ FLOWT RURD P SLB rigging down alley for CT access in the morning. 20:45 00:00 3.25 COMPZ FLOWT RURD P Expro-LRS pressure test well to tanks @ 1000 psi,well to heater 3000 psi with diesel. 04/07/2013 Removed remaining stimulation equipment from pad, rigged up CT unit and milled on first frac ball seat @ 5209 ft RKB. Tagged second port at 5487 ft started milling. unit pump pressure unit malfunctioned. POOH for night. 00:00 05:45 5.75 COMPZ FLOWT RURD P load test separator and well test surface lines with Diesel. Start pressure test,found leaks. Pump out of diesel, released to refill. 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil. CTU unit safe work zone. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:45 2.00 COMPZ FLOWT RURD P Alipne ASCR on location to remove frac relief tanks and misc equipment. Staged waiting on frac crew. 08:45 11:30 2.75 COMPZ FLOWT RURD P Frac crew back on location picked up some remainging equipment. CTU crew on site, unit staged at Midway camp. CTU crew walked down well site and left to retrieve CTU. 11:30 13:30 2.00 COMPZ FLOWT RURD P Frac crew and CTU crew moving frac equipment. Hard line crew pressure testing returns lines. 13:30 17:00 3.50 COMPZ FLOWT RURD P RU CTU#5 MU MHA#1 Pull test 30k. PIT MHA 250/3500 psi to well. Verify fluid path and pt 250/4000 psi. 17:00 18:00 1.00 COMPZ FLOWT RURD P 5,100 ft Wt Ck, 12k RIH 1.5k Tag up on frac port at 5200 ft ctmd. PUH pump 1.5 bpm slick diesel,CT 2200, WH 500 psi 18:00 21:45 3.75 COMPZ FLOWT RURD P Mill on Frac port multiple stalls. Down on pumps, run dry through FracPORT no problem. Continue to RIH to second FracPORT at 5477 ft ctmd(5487 ft RKB)flag pipe. Start milling at 5475 ft ctmd WOB.5k mill to 5475.7 ft unit pressure gauge malfunctioning. 21:45 23:15 1.50 COMPZ FLOWT RURD P POOH,freeze protect surface lines, secure well, lay down for night. 04/08/2013 Milled thru bottom FracPORT at 5,487-ft RKB. RIH w/2"JSN to 6,300-ft RKB,575-ft below bottom perforations 2.813"CMD-SSD open at 5,209-ft and 5,487-ft RKB. Ready for Slicklne. 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on coil crew to return Page 5 of 12 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB CTU unit and their safe work zone. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P Waiting on coil crew to return. 08:30 09:00 0.50 COMPZ FLOWT RURD P Coil crew travel from midway camp to Cassin#1. Inspect location,start equipment. 09:00 09:45 0.75 COMPZ FLOWT RURD P PJSM RU CTU#5. Breakdown MHA #1 to install stabilizer above motor. 09:45 10:15 0.50 COMPZ FLOWT RURD P Wait on Baker to arrive with stabilizer from Prudhoe and XO's from Alpine. 10:15 11:04 0.82 COMPZ FLOWT RURD P MU MHA#2 test 250/3500 psi to well,verify fluid paths to tanks,P/T surface equipment 250/4000 psi. 11:04 11:59 0.93 COMPZ FLOWT RURD P RIH w/Mha#2, RIW 1.5k. 11:59 13:59 2.00 COMPZ FLOWT RURD P 5100 ft Wt Ck 13k RIW 1k, no problem thru SSD at 5209 ft RKB, tag up at 5,479 ft, Up wt 13.2k, on-line 1.5 bpm,CT 2000,WH 5000. Start milling at 54777.7 ft ctmd,CT 2180,WOB.5k,stall at 5477.8 ctmd,time mill to same,PUH shut down pumps,dry tag at 5,479 ft ctmd,time mill CT 2000,WH 600. 13:59 16:14 2.25 COMPZ FLOWT RURD P Multiple stalls at 5477.8 ft ctmd, • PUH shut down pump,close choke, dry tag at 5479 ft PU on line 1.5 bpm,CT 2000,WH 625,time mill through FracPORT,PU off line on the pump,close choke,drift lower CMD-SSD no problem. 16:14 16:24 0.17 COMPZ FLOWT RURD P RIH and tag XN nipple at 5677 ft ctmd(5685-RKB)flag pipe. 16:24 17:09 0.75 COMPZ FLOWT RURD P POOH pumping min rate,CT 1190. WH 800. 17:09 18:28 1.33 COMPZ FLOWT RURD P On surface brake down MHA, mill shows a little wear on the outside edge only reheaded to to SLB equipment,pull test,MU BHA#3,to well,PT equipment 250/4000. 18:28 19:18 0.84 COMPZ FLOWT RURD P RIH w/BHA#3 pumping 10 bbl gelled diesel sweep.5 bpm,CT 1000,WH 750. 19:18 19:38 0.34 COMPZ FLOWT RURD P 5000 ft Wt Ck 11k,CT 1075,WH 750,RIW 2.5k 19:38 20:12 0.58 COMPZ FLOWT RURD P At 5685 ft corrected depth to flag, reduce rate to minimum,RIH 90 fpm, CT 800,WH 500, RIW 5k.getting pick up weights every 100ft,slack off 2k at 6298 ft MD(573 ft below bottom perf)PU online 2 bpm,gelled diesel up and around the coil. 20:12 21:16 1.08 COMPZ FLOWT RURD P POOH chasing gel out of tubing, slow down across GLM's. Page 6 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:16 22:40 1.41 COMPZ FLOWT RURD P On surface,pump 26 bbls for freeze protect, 1:1 returns throughout job, RD CTU#5,secure well, release equipment,stage unit on pad for night. 22:40 23:25 0.75 COMPZ FLOWT RURD P Travel to Midway camp for night,will return in AM to road unit to Alpine. 04/09/2013 Move out CTU#5,MURU SL unit 770.Tagged bottom @ 6253'SLM. Attempted to close frac sleeves @ 5210 and 5488'RKB. In Progress. 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on SL crew to return 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting w/Expro Crew. Discussed walking an working surfaces,simops with HEs S/L unit and their safe work zone, reported spill at Repsol Q6. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P Waiting on coil crew to return. 08:30 09:00 0.50 COMPZ FLOWT RURD P Coil crew travel from midway camp to Cassin#1. Check in, inspect location,move unit off pad to Alpine. 09:00 09:30 0.50 COMPZ FLOWT RURD P Wait on SL and hot oil units to travel from Alpine. 09:30 10:45 1.25 COMPZ FLOWT RURD P PJSM, RU SL#770 and LRS hot oil pump. 10:45 11:45 1.00 COMPZ FLOWT RURD P JSSM,SIMOPS w Expro, RU .125' wire and 2.125" TS-RS,QC,3',3',QC,OJ,QC,LSS,QC. LRS PT@ 2500 psi. 11:45 13:00 1.25 COMPZ FLOWT RURD P RIH w/2.26"Cent,2"DD Bailer(M/S Flapper)S/D @ 6253 SLM. Tap DN. Pull small bind. POOH. 13:00 14:45 1.75 COMPZ FLOWT RURD P RIH w/2.81"42 BO(S/R up), DBL FM,2.77'-Ring to 5190'SLM (5210 RKB)Engaged sleeve. pull 600#over bind. Holding solid. Unable to close spangs w/o falling through sleeve. Make short runs @ sleeve to engage progressively harder. Pull through after 5 hits. Unable to re-engage sleeve w/multiple passes through sleeve. Continue to RIH to sleeve @ approx 5466'SL. Unable to engage after multiple passes through. POOH. Re engaged sleeve at @ 5190'SLM. Work as before until pull through. Unable to re-engaged w/ multiple passes. POOH. Pin not sheared. Page 7of12 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:45 17:30 2.75 COMPZ FLOWT RURD P RIH w 3.5"BL-Brush,4280(diff S/R up), DBL FM,2.77"G-ring to 5190 SLM(5210 RKB)pass through sleeve,then engage sleeve. Repeat 2 times, begin small spang licks then work up to 600#over OJ licks. Pulled through after 3 licks @ 600# over. Unable to re-engage. RIH to sleeve @ 5488' RKB. Unable to engage after multiple passes. POOH. Pin worked but not sheared. 17:30 20:00 2.50 COMPZ FLOWT RURD P RIH w/3.5"BL-BRUSH,4260 (DIFFERENT S/R UP), DBL FM, 2.77"G-RING TO 5190'SLM (5210' RKB) PASS THRU SLV. THEN ENGAGE SLV. REPEAT 2 TIMES. BEGIN SMALL SPANG LICKS THEN WORK UP TO 600#OVER OJ LICKS.PULLED THRU AFTER 3 LICKS @ 600#OVER. UNABLE TO RE-ENGAGE. RIH TO SLV @ 5488' RKB. UNABLE TO ENGAGE AFTER MULTIPLE PASSES. POOH. PIN WORKED BUT NOT SHEARED. 20:00 21:00 1.00 COMPZ FLOWT RURD P RIH w/3.5", BL-BRUSH,42B0(S/R, UP) AND 2.77"G-RING TO LOWER SLV @ 5470'SLM(5488'RKB) UNABLE TO ENGAGE SLV AFTER MULTIPLE PASSES. PUH. DID NOT ENGAGE UPPER SLV. POOH. PIN NOT SHEARED. 21:00 22:45 1.75 COMPZ FLOWT RURD P RIH w/3.5"BL-BRUSH,4260(POS, UP, STEEL) AND 2.77"G-RING TO LOWER SLV @ 5470'SLM(5488' RKB) UNABLE TO ENGAGE. PUH. TO UPPER SLV @ 5190' SLM(5210'RKB) UNABLE TO ENGAGE. POOH. PIN SHEARED. 22:45 00:00 1.25 COMPZ FLOWT RURD P RIH w/ 3.5"BL-BRUSH,4260 (POS, UP, STEEL)AND 2.77" G-RING TO LOWER SLV @ 5470' SLM(5488'RKB) PASS DN THRU SLV. UNABLE TO ENGAGE IN EITHER DIRECTION. PUH TO UPPER SLV @ 5190'SLM(5210' RKB) PULL UP THRU SLV EASILY. SET DN IN SLV. TAP DN LIGHTLY. STAYED ENGAGED. PULL 500# OVER OJ LICK. PULLED FREE. RIH AND S/D AGAIN. PULLED 400#OVER OJ LICK. PULLED FREE. POOH. 00:00 01:00 1.00 COMPZ FLOWT RURD P BEGIN LDFN, INSPECT AREA, PJSM, GO TO CAMP. Page 8 o f12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/10/2013 24 hr Summary SET CATCHER @ 5685'RKB. PULLED DV AND SET OV(5/16")@ 4840'RKB. VERIFIED SLV @ 5210' RKB IS CLOSED AND SLV @ 5488'RKB IS NOT HOLDING. PULLED CATCHER @ 5685'RKB. BLEED PRESSURE FROM WELL TO TANKS, START UNLOADING THE IA WITH N2 @ 200 SCF/m 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on SL crew to return 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting w/Expro Crew. Discussed walking an working surfaces,simops with HEs S/L unit and their safe work zone, reported spill at Repsol Q6. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P PHONE CONFERENCE w/CWG REPS,SYNC, PU CPU/WELL FILE, GO TO LOCATION/INSPECT. 08:30 09:00 0.50 COMPZ FLOWT RURD P JSSM,SIMOPS w/EXPRO, RU .125"WIRE AND 2.125" TS=RS,QC,3',3',QC,KJ,5',QC,KJ,5',Q C,KJ,LSS,QC.(29'-2") LRS PT @ 2500 PSI. 09:00 10:15 1.25 COMPZ FLOWT RURD P RIHw/3.5"GSAND2.72"x21.5" BAIT SUB,2.77"G-RING TO XN @ 5664'SLM(5685'RKB) MAKE MULTIPLE PASSES THRU BOTH FRAC SLV's AND 5250'SLM. NO FLOW DETECTED. SET CATCHER IN XN @ 5664'SLM(5685'RKB) POOH. 10:15 11:45 1.50 COMPZ FLOWT RURD P ADD OJ's. RIH w/3.5"OM-1 AND 1.625"JD TO STA#1 @ 4822'SLM (4840'RKB) LATCH DV. POOH. 11:45 12:45 1.00 COMPZ FLOWT RURD P DROP OJ's. RIH w/3.5"OM-1 AND RK LATCH ON 1.5"OV(5/16")TO STA#1 @ 4822'SLM(4840'RKB) SET OV. BLEED IA f/350-0 PSI. SHEAR OFF. POOH. 12:45 15:15 2.50 COMPZ FLOWT RURD P RIH w/3.5"D&D HOLEFINDER (COLLER STOP)TO 5504'SLM (BELOW LOWER SLV) SET D&D PUMP 1 BBL. NO CHANGE. PUH TO 5460'SLM(ABOVE LOWER SLV) PUMP 0.2 BBLS. INCREASED TBG f/700 TO 1300 PSI. HOLDING SOLIDLY. BLEED DN. POOH. Page 9 of 12 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:15 16:45 1.50 COMPZ FLOWT RURD P TS=RS,QC,3',3',QC,KJ,5',QC,KJ,3',Q C,OS,QC,KJ,LSS,QC(33'0") RIH w/42B0(S/R, UP)DBL FM,3'x 1.875", BL-BRUSH,42B0(POS, UP) RS (ZEROED @ UPPER 42B0) TO LOWER SLV @ 5470'SLM(5488' RKB) PASS THRU SLV MULTIPLE TIMES @ DIFFERENT SPEEDS. 1ST VERY SLOW PASS PULLED @ 550#OVER. REMAINING PASSES WERE @ 300#OVER. NO DEFINATE ENGAGEMENT. PUH. UNABLE TO PULL THRU 5232'SLM. ATTEMPT TO PULL THRU MULTIPLE TIMES. BEGIN PUMPING. NO CHANGE OTHER THAN INCREASED WT. SHUT PUMP DN. PULL THRU w/o BOBBLE. POOH. PIN OF S/R KEYS SLIGHTY WORKED. PIN OF POS KEYS SHEARED. 16:45 18:15 1.50 COMPZ FLOWT RURD P RIH w/3.5"D&D HOLEFINDER (COLLER STOP)TO 5504'SLM (BELOW LOWER SLV) SET D&D PUMP 2 BBL. @ 3/4 BBLS/MIN TGB INCREASED f/700-.800 PSI. SHUT PUMP DN. PUH TO 5460' SLM(ABOVE LOWER SLV) PUMP 0.2 BBLS. INCREASED TBG f/700 TO 1300 PSI. HOLDING SOLIDLY. BLEED DN. POOH. 18:15 19:15 1.00 COMPZ FLOWT RURD P ADD OJ's. RIH w/3.5"GR TO 5664' SLM(5685'RKB) LATCH CATCHER. POOH. WALK WELLHEAD TO FLARE AND TANKS INSPECT LINES AND EQUIPMENT WITH BOTH DAY AND NIGHT EXPRO CREW SUPERVISORS. 19:15 20:00 0.75 COMPZ FLOWT RURD P BEGIN RD, INSPECT AREA, CHECK w/CWG REP. TRAVEL TO ALPINE, END TICKET, DOWNLOAD,TURN IN PAPERWORK. 20:00 22:00 2.00 COMPZ FLOWT RURD P SLB N2 PUMPERS ON LOCATION, PRE JOB, CHECK IN, RU, PT @3000 PSI. hOLD PREJOB SAFETY MEETING WITH SLB AND EXPRO IN TANK FARM HOOCH. SLB TANKER 53'2600 GAL PRE COOL DOWN, POST COOL DOWN, 52"2642 GAL N2. HALLIBURTON TANKER ON LOCATION AND OFF LOADING INTO SLB 22:00 23:00 1.00 COMPZ FLOWT PRDT P OPEN WELL TO CLOSED CHOKE. SLOWLY WORK CHOKE OPEN TO 40/64 ths. T/I/0=26/0/0 Page 10 of 12 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 COMPZ FLOWT PRDT P SLB N2 ONLINE WITH BOOSTER PUMP ONLY TO THE IA FOR 2 MINUTES,SLOWLY RAISE RATE TO 200 SCF. INITIAL T/I/O= 19/344/0, FINAL @ MIDNIGHT T/I/O =31/590/0 TUBING TEMP 54 F. 04/11/2013 Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed traps and pinch points. 06:15 06:45 0.50 COMPZ FLOW- PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT P Flow well to tanks 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/12/2013 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed traps and pinch points. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks. Top off SLB N2 pumper,dispatch empty 6500 gal tanker to Deadhorse to refill. SLB pump 2794 gal N2 @ 0655. 08:00 09:00 1.00 COMPZ FLOWT PRDT P Developed aweep at a valve requiring the well be shut in at the wing to bleed pressure in order to isolate valve. Repositioned N2 unit while well S/I to accommodate E-line logging unit crane. Replace weeping valve. 09:00 12:00 3.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks, 16:00 16:30 0.50 COMPZ FLOWT PRDT P Slowed N2 lift rate to allow time for transport to return to location and off load. 16:30 20:00 3.50 COMPZ FLOWT PRDT P Increase lift rate to target. Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/13/2013 Log Production profile. Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks Page 11 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew&HES E-line Crew. Discussed Simops,slick surfaces, communication. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Rig up HES E-line, RIH and log production profile. 08:00 12:00 4.00 COMPZ FLOWT PRDT P Log production profile. 12:00 16:00 4.00 COMPZ FLOWT PRDT P Log production profile. 16:00 20:00 4.00 COMPZ FLOWT PRDT P Log production profile. 20:00 00:00 4.00 COMPZ FLOWT PRDT P RD HES E-line. Shut in N2 Pump momentarily and shut down deck engine to check oils. Restarted pump and opened up to inner annulus. Resumed pumping N2. 04/14/2013 Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed,slick surfaces,planned demob, increased temperatures,melting pad. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/15/2013 Flow well to tanks,SLB Oil Phase collected well bore fluid samples. 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed, upcoming well work,manager visit, planned demob,increased temperatures,melting pad. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks rigged up Oil Phase 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks took oil phase samples 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks took 5 gal dead crude samples. 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks Page 12 of 12 ,.r.w.. ° 8 n « 3 & ^ 3 R ^ 8 S a S a ; S 3 « 3 « n T « ^ N « « « gym ^ . . . nna . . s � ' oao rvrvsaa . s . � nnse � 3 � ' 0n ao 0. •>,•w•s • , « a a n ^ • a s 7 a a s ry n a a 8 a a ,, = ww• +>l.M ry ry ry « ry « ^ ^ 3 ^ a S . . . . n n n S . 3 e 3 ,. ry « ry « . . 3 . . . 0 , R .. 3 .. ^ ^ ^ .. .. .. 3 8 8 0 0 0 8 8 8 8 8 0 0 « a n x .. a 9 8 9 5 5 9 8 « « 8 ^ a 8 ^ ^ ^ . . « 8 . 8 7 n a E ^ „ 8 . 8 9 8 . ^ « 8 « « 5 ox.x3 i.•o 8 3 3 9 3• a 3 no ? 8 8 8 8 8 8 3 S 3 S R R R « A A R R S 3 " ' " ^ ^ .. .. .. « « « R ^ ^ a ^ ^ ^ a ^ S 3 3 n n n n n n n n S . . 3 U 1 YOD i000000 . 0 . 0000000000 - 0000000000000000 - 00 - 0000000000 - 0000 : t, In+...M .7 , :, ; ! r, ,,, ':,. ; ! 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O �UO^9. `m 0. x,sa...n:+mexaaaa'a'meawv'°",P; Pt\ \.v�V U eTYep d u.w.anw4+ < - 5228.10 11:38 5 1 2709.04 B 0.5/5 126.7 0.5/5 0.5/5 0.5/10 2336.50 0.2/2 1941.21 2335.40 2706.91 X 5227.00 12:05 6 2 2705.90 B 1/10 0.5/5 2344.36 2706.15 X 5229.00 12:23 7 3 2707.50 B 1/10 1490.00 2329.50 0.5/5 1463.00 2327.49 0.5/5 1473.00 2326.80 0.5/5 1473.00 2326.40 127.4 2707.06 X 5237.00 12:46 8 4 2711.80 B 1/10 2711.40 5238.00 12:50 9 5 2712.04 B 1/10 1531.00 0.5/5 1770.00 2329.10 0.5/5 1773.00 2328.30 0.5/5 1782.90 2327.90 127.8 2711.47 X 5257.00 13:20 10 6 2724.00 B 1/10 1800.00 5/5 2721.50 5258.00 13:30 11 7 2721.80 B 1/10 1535.00 0.5/5 1476.91 2367.40 127.7 0.5/5 1716.90 2365.07 0.5/5 1740.99 2363.40 127.8 2721.24 X 5275.00 14:15 12 8 2732.10 B 1/10 1808.97 2730.50 X 5275.67 14:24 13 9 2730.80 B 1/10 1791.61 _ 2730.72 X 5429.00 14:34 14 10 2824.60 B 1/10 1800.18 0.5/5 1900.01 129.7 2813.21 X 5509.00 14:45 15 11 2861.00 B 0.5/5 2186.29 131.2 1/10 1969.82 1/10 1718.96 131.5 2850.79 X 5522.00 15:05 16 12 2859.50 B 0.5/9 1776.20 132.0 0.5/10 1762.40 132.2 2857.03 X 2 0.5/5 5529.00 15:45 17 13 2862.04 B 1/10 132.5 2860.70 5549.00 16:00 18 14 2875.00 0 2/10 2600.00 133.0 2/10 2090.00 2/10 1840.00 2594.66 136.5 2/10 1834.00 2585.00 2/10 1575.00 2567.50 135.5 2869.02 X 5700.00 17:10 19 15 2959.43 _ 0 1/20 1071.00 2516.66 1/20 1030.00 2516.00 1/20 1066.00 2520.10 135.9 1/20 1049.00 2520.10 2947.18 X 5710.00 17:42 20 16 2953.50 0 1/20 0.5/20 2/5 1891.00 2585.00 2951.90 2/10 2114.00 2503.10 137.2 2/20 2220.00 2502.50 137.3 1832.00 X 2127.00 2128.00 1/20 2498.60 138.9 2950.70 16-Mar-13 5716.00 7:05 22 18 2954.75 0 1/20 2503.80 139.6 1/20 1858.53 2954.40 X 5715.00 7:17 23 19 2953.56 0 1/20 1913.36 139.8 2953.81 1/20 1848.98 5723.00 7:28 24 20 2959.85 0 1/20 1/20 2/10 2/10 1837.20 140.1 2958.42 5724.00 7:35 25 21 2958.76 0 1/20 1832.19 140.3 2957.80 X 6075.00 8:05 28 22 3138.20 0 1/20 2028.26 147.6 3139.94 X 6082.00 8:13 29 23 3144.20 0 1/20 2554.20 146.9 X 1/20 2251.27 1/20 2228.47 1/20 2511.292 3143.24 6126.00 8:36 30 24 3172.01 0 1/20 2882.20 146.8 1/20 2554.81 2880.40 1/20 2537.362 2843.51 147.1 1/20 2526.03 2839.50 1/20 2527.74 2837.37 1/20 2525.74 2835.30 3165.20 X 5257.00 10:00 31 25 2722.00 0 1/20 1967.38 131.5 1/20 1834.62 2369.70 1/20 1994.80 2368.70 2721.28 X 5239.00 10:18 32 26 2709.90 0 1.5/20 2013.90 131.6 1/20 1983.19 2333.25 1/20 1992.18 2330.60 1/20 2013.73 2329.80 131.9 2711.50 X 5229.00 10:37 33 27 2704.75 0 1.5/20 2023.16 132.2 1/20 1991.18 2337.90 2/20 1712.03 2334.80 2/20 1659.86 2333.30 132.6 2706.30 X PRE-TEST READINGS PROBE DATE TIME FILE SET HYD PADS d HYD PT DRAW FORM QGS MOB 1 MOB 2 BUBBLE HYD MOBILITY DEPTH # # (INITIAL) (RNOL) DOWN PRES TEMP (prepump) (postpump) POINT (FINAL) F o a 15-Mar-13 001-001 10:16 1 � DOWNLs A° 5228.10 11:38 5 1 2709.04 B 0.5/5 126.7 0.5/5 0.5/5 0.5/10 2336.50 0.2/2 194121 2335.40 2706.91 X 5227.00 12:05 6 2 2705.90 B 1/10 0.5/5 2344.36 2706.15 X 5229.00 12:23 7 3 2707.50 B 1/10 1490.00 2329.50 0.5/5 1463.00 2327.49 0.5/5 1473.00 2326.80 _ 0.5/5 1473.00 2326.40 127.4 2707.06 X 5237.00 12:46 8 4 2711.80 B 1/10 2711.40 /1111 5238.00 12:50 9 5 2712.04 B 1/10 1531.00 0.5/5 1770.00 2329.10 0.5/5 1773.00 2328.30 0.5/5 1782.90 2327.90 127.8 2711.47 X 5257.00 13:20 10 6 2724.00 B 1/10 1800.00 _ 5)5 2721.50 1111 5258.00 13:30 11 7 2721.80 B 1/10 1535.00 0.5/5 1476.91 2367.40 127.7 0.5/5 1716.90 2365.07 0.5/5 1740.99 2363.40 127.8 272124 X 5275.00 14:15 12 8 2732.10 B 1/10 1808.97 2730.50 X 5275.67 14:24 13 9 2730.80 B 1/10 1791.61 2730.72 X 5429.00 14:34 14 10 2824.60 B 1/10 1800.18 _ _ 0.5/5_ 190001 129.7 2813.21 X 5509.00 14:45 15 11 2861.00 B 0.5/5 2186,29 131.2 1/10 1969.82 1/10 1718.96 131.5 2850.79 X ■ 5522.00 15:05 16 12 2859.50 B 0.5/9 177620 132.0 0.5/10 1762,40 1322 2857.03 X 2 0.5/5 5529.00 15:45 17 13 2862.04 B 1/10 132.5 2860.70 5549.00 16:00 18 14 2875.00 0 2/10 260000 133.0 2/10 2090.00 2/10 1840.00 2594.66 136.5 2/10 1834.00 2585.00 2/10 1575.00 2567.50 135.5 2869.02 X 5700.00 17:10 19 15_ 2959.43 0 1/20 1071.00 2516.66 1/20 1030.00 2516.00 1/20 1066.00 2520.10 135.9 1/20 1049.00 2520.10 2947.18 X 5710.00 17:42 20 16 2953.50 0 1/20 0.5/20 iiim1891.00 2585.00 2951.90 2/10 2114.00 2503.10 137.2 2/20 222000 2502.50 137.3 1832.00 X 2127.00 2128.00 1/20 2498.60 138.9 2950.70 16-Mar-13 5716.00 7:05 22 18 2954.75 0 1/20 2503.80 139.6 1/20 1858.53 2954.40 X 5715.00 7:17 23 19 2953.56 0 1/20 1913.36 139.8 2953.81 1/20 1848,98 5723.00 7:28 24 20 2959.85 0 1/20 _ 1/20 2/10 2/10 183720 140.1 2958.42 5724.00 7:35 25 21 2958.76 0 1/20 1832.19 140.3 2957.80 X x a 6075,90 27 6075.00 8:05 28 22 3138.20 0 1/20 2028.26 147.6 3139.94 X 6082.00 8:13 29 23 3144.20 0 1/20 2554.20 146.9 X 1/20 2251.27 1/20 2228.47 1/20 2511.292 3143.24 6126.00 8:36 30 24 3172.01 0 1/20 2882.20 146.8 1/20 2554.81 2880.40 1/20 2537.362 2843.51 147.1 _ 1/20 2526.03 2839.50 1/20 2527.74 2837.37 I 1/20 2525.74 2835.30 3165.20 X )ECR 5257.00 10:00 31 25 2722.00 0 _ 1/20 1967.38 131.5 1/20 1834.62 2369.70 1/20 1994.80 2368.70 2721.28 X 5239.00 10:18 32 26 2709.90 0 1.5/20 2013.90 131.6 1/20 1983.19 2333.25 1/20 1992.18 2330.60 1/20 2013.73 2329.80 131.9 2711.50 X 5229.00 10:37 33 27 270475 0 1.5/20 2023.16 132.2 1/20 1991.18 2337.90 2/20 1712.03 2334.80 2/20 1659.86 2333.30 132.6 2706.30 X 6. _ U E _ v N = E E c g Yp co z w € E . t Y fn L Q F J _ £ E.E I g $ f6 ~O z a t; Q W w m E Q' _ v 2 N c 'g E E 8 E E E E E S S E E E E E E" E v £ E EE E E° E E .EEE El E E E E E E n E N f— � cwiow 8c 888 888888 888 c8 8 L'818'E 88 88 8 8v88A888Ec 888888881 8u a >_ . c= E o = e=e - e° c. u v.� = = -v 8-==z c n _u _ °'-v 8 =s N vjv v� "t ' vvv-v - u a vv = vn v1 vv v 1a'°�' vvv f gg7 'a 1- 11ArTIff L m o o O o O O O O 0 O O U O O O O o 00000 SS c o C o_U 2 2 2'' o f 2.o,2 2 2 g U a c o f 1 4 t _ .N .-6". 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Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASPS TVD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Project North Alaska ASP5,Alaska Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 05 Using geodetic scale factor Well Cassin#1 Well Position +N/-S 0.00 ft Northing: 5,985,067.77 ft Latitude: 70°21'39.902 N +El-W 0.00 ft Easting: 726,411.83 ft Longitude: 152°9'38.176 W Position Uncertainty 0.00 ft Wellhead Elevation: 0.00 ft Ground Level: 74.10 ft Wellbore Cassin#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 2/28/2013 18.99 80.71 57,541 Design Cassin 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.60 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 27.60 0.00 0.00 115.99 Survey Program Date 3/29/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 131.61 2,378.35 Cassin 1(Cassin#1) MWD MWD-Standard 03/04/2013 2,378.35 6,451.25 Cassin 1(Cassin#1) MWD MWD-Standard 03/04/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (1100) (ft) Survey Tool Name 27.60 0.00 0.00 27.60 -74.10 0.00 0.00 5,985,067.77 726,411.83 0.00 0.00 UNDEFINED 131.61 0.14 50.80 131.61 29.91 0.08 0.10 5,985,067.86 726,411.93 0.13 0.05 MWD(1) 222.66 0.39 53.97 222.66 120.96 0.33 0.44 5,985,068.12 726,412.26 0.27 0.25 MWD(1) 315.97 0.39 42.69 315.97 214.27 0.75 0.91 5,985,068.55 726,412.72 0.08 0.49 MWD(1) 402.28 0.42 39.61 402.27 300.57 1.21 1.31 5,985,069.03 726,413.10 0.04 0.64 MWD(1) 492.59 0.38 51.42 492.58 390.88 1.65 1.75 5,985,069.48 726,413.54 0.10 0.85 MWD(1) 591.42 1.02 133.40 591.41 489.71 1.25 2.65 5,985,069.11 726,414.44 1.05 1.83 MWD(1) 683.67 0.92 128.75 683.64 581.94 0.23 3.82 5,985,068.12 726,415.65 0.14 3.34 MWD(1) 777.78 0.85 135.26 777.74 676.04 -0.74 4.90 5,985,067.18 726,416.76 0.13 4.73 MWD(1) 867.76 0.92 132.97 867.71 766.01 -1.71 5.90 5,985,066.25 726,417.78 0.09 6.05 MWD(1) 961.60 0.90 127.42 961.54 859.84 -2.67 7.04 5,985,065.32 726,418.95 0.10 7.50 MWD(1) 1,054.30 0.83 129.90 1,054.23 952.53 -3.54 8.13 5,985,064.48 726,420.07 0.09 8.86 MWD(1) 1,146.75 0.95 127.91 1,146.67 1,044.97 -4.44 9.25 5,985,063.61 726,421.21 0.13 10.26 MWD(1) 3/29/2013 12:30:31 PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASPS TVD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (') r) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 1,239.71 0.83 128.81 1,239.62 1,137.92 -5.34 10.38 5,985,062.75 726,422.37 0.13 11.67 MWD(1) 1,330.46 0.81 128.83 1,330.36 1,228.66 -6.15 11.39 5,985,061.97 726,423.41 0.02 12.94 MWD(1) 1,419.02 0.96 134.38 1,418.91 1,317.21 -7.06 12.41 5,985,061.09 726,424.45 0.19 14.25 MWD(1) 1,518.05 0.93 134.34 1,517.92 1,416.22 -8.21 13.58 5,985,059.98 726,425.65 0.03 15.80 MWD(1) 1,613.64 0.89 131.69 1,613.50 1,511.80 -9.24 14.69 5,985,058.98 726,426.79 0.06 17.25 MWD(1) 1,701.66 0.72 132.32 1,701.51 1,599.81 -10.07 15.61 5,985,058.18 726,427.74 0.19 18.44 MWD(1) 1,795.10 0.67 123.48 1,794.95 1,693.25 -10.77 16.50 5,985,057.51 726,428.65 0.13 19.55 MWD(1) 1,887.40 0.88 127.68 1,887.24 1,785.54 -11.50 17.51 5,985,056.81 726,429.68 0.24 20.78 MWD(1) 1,981.16 0.76 126.97 1,980.99 1,879.29 -12.31 18.58 5,985,056.03 726,430.77 0.13 22.09 MWD(1) 2,073.01 0.61 115.19 2,072.83 1,971.13 -12.89 19.51 5,985,055.49 726,431.72 0.22 23.18 MWD(1) 2,165.26 0.61 127.72 2,165.08 2,063.38 -13.39 20.34 5,985,055.00 726,432.57 0.14 24.15 MWD(1) 2,256.71 0.66 114.91 2,256.52 2,154.82 -13.91 21.20 5,985,054.51 726,433.44 0.16 25.15 MWD(1) 2,310.78 0.65 110.63 2,310.59 2,208.89 -14.15 21.77 5,985,054.29 726,434.02 0.09 25.77 MWD(1) 2,379.81 0.60 134.30 2,379.61 2,277.91 -14.54 22.40 5,985,053.91 726,434.66 0.38 26.50 MWD(2) 2,475.46 0.63 122.49 2,475.26 2,373.56 -15.18 23.20 5,985,053.31 726,435.48 0.14 27.50 MWD(2) 2,567.16 2.48 127.72 2,566.92 2,465.22 -16.66 25.19 5,985,051.88 726,437.52 2.02 29.95 MWD(2) 2,659.31 3.90 131.04 2,658.92 2,557.22 -19.94 29.13 5,985,048.73 726,441.55 1.55 34.92 MWD(2) 2,752.00 6.01 139.98 2,751.26 2,649.56 -25.72 34.63 5,985,043.11 726,447.23 2.42 42.40 MWD(2) 2,846.37 6.25 141.68 2,845.09 2,743.39 -33.54 40.99 5,985,035.49 726,453.82 0.32 51.55 MWD(2) 2,939.20 6.19 140.99 2,937.38 2,835.68 -41.39 47.28 5,985,027.83 726,460.34 0.10 60.64 MWD(2) 3,030.90 6.01 140.87 3,028.56 2,926.86 -48.96 53.42 5,985,020.46 726,466.71 0.20 69.47 MWD(2) 3,119.65 5.90 141.29 3,116.83 3,015.13 -56.12 59.20 5,985,013.47 726,472.70 0.13 77.81 MWD(2) 3,213.25 6.00 142.15 3,209.93 3,108.23 -63.74 65.21 5,985,006.04 726,478.94 0.14 86.55 MWD(2) 3,303.48 6.04 141.14 3,299.66 3,197.96 -71.16 71.09 5,984,998.80 726,485.03 0.13 95.08 MWD(2) 3,396.76 5.89 142.00 3,392.43 3,290.73 -78.75 77.11 5,984,991.39 726,491.29 0.19 103.83 MWD(2) 3,492.80 6.02 142.35 3,487.95 3,386.25 -86.62 83.22 5,984,983.71 726,497.63 0.14 112.77 MWD(2) 3,586.43 5.99 142.36 3,581.07 3,479.37 -94.38 89.20 5,984,976.14 726,503.85 0.03 121.54 MWD(2) 3,679.88 4.76 137.34 3,674.11 3,572.41 -101.09 94.81 5,984,969.60 726,509.65 1.41 129.52 MWD(2) 3,770.29 3.30 134.77 3,764.29 3,662.59 -105.68 99.20 5,984,965.15 726,514.18 1.63 135.48 MWD(2) 3,863.02 3.11 133.17 3,856.88 3,755.18 -10928 102.93 5,984,961.66 726,518.01 0.23 140.41 MWD(2) 3,957.55 1.45 131.85 3,951.33 3,849.63 -111.83 105.69 5,984,959.19 726,520.85 1.76 144.01 MWD(2) 4,050.76 1.21 142.08 4,044.51 3,942.81 -113.40 107.17 5,984,957.67 726,522.38 0.36 146.03 MWD(2) 4,141.21 0.51 199.42 4,134.95 4,033.25 -114.53 107.63 5,984,956.55 726,522.87 1.14 146.94 MWD(2) 4,235.14 1.27 283.28 4,228.88 4,127.18 -114.69 106.47 5,984,956.36 726,521.72 1.40 145.97 MWD(2) II� 4,327.35 1.35 284.01 4,321.06 4,219.36 -114.19 104.43 5,984,956.80 726,519.66 0.09 143.91 MWD(2) 4,416.53 1.38 282.07 4,410.22 4,308.52 -113.71 102.36 5,984,957.22 726,517.58 0.06 141.84 MWD(2) 4,512.48 1.33 284.92 4,506.14 4,404.44 -113.18 100.15 5,984,957.68 726,515.36 0.09 139.62 MWD(2) 4,604.27 1.23 290.53 4,597.91 4,496.21 -112.56 98.20 5,984,958.24 726,513.39 0.17 137.60 MWD(2) 4,695.12 1.03 293.24 4,688.74 4,587.04 -111.90 96.54 5,984,958.85 726,511.70 0.23 135.81 MWD(2) 4,788.69 1.11 287.23 4,782.29 4,680.59 -111.30 94.90 5,984,959.40 726,510.05 0.15 134.08 MWD(2) 3/29/2013 12:30:31 PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASPS TVD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: 'True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,877.84 1.05 326.74 4,871.43 4,769.73 -110.36 93.62 5,984,960.30 726,508.75 0.82 132.52 MWD(2) 4,974.10 1.04 321.87 4,967.67 4,865.97 -108.93 92.60 5,984,961.70 728,507.68 0.09 130.98 MWD(2) 5,069.52 0.36 23.51 5,063.09 4,961.39 -107.98 92.19 5,984,962.64 726,507.24 0.97 130.18 MWD(2) 5,162.03 0.30 41.23 5,155.59 5,053.89 -107.53 92.46 5,984,963.10 726,507.50 0.13 130.24 MWD(2) 5,254.17 0.27 79.93 5,247.73 5,146.03 -107.31 92.83 5,984,963.33 726,507.87 0.21 130.47 MWD(2) 5,344.70 0.53 55.06 5,338.26 5,236.56 -107.03 93.39 5,984,963.62 726,508.41 0.34 130.85 MWD(2) 5,435.96 0.27 70.07 5,429.52 5,327.82 -106.72 93.94 5,984,963.95 726,508.95 0.30 131.21 MWD(2) 5,529.84 0.25 60.88 5,523.40 5,421.70 -106.54 94.32 5,984,964.14 726,509.33 0.05 131.48 MWD(2) 5,621.66 0.26 70.42 5,615.22 5,513.52 -106.37 94.69 5,984,964.32 726,509.70 0.05 131.74 MWD(2) 5,715.24 0.43 73.10 5,708.79 5,607.09 -106.20 95.23 5,984,964.51 726,510.23 0.18 132.14 MWD(2) 5,807.52 0.35 86.51 5,801.07 5,699.37 -106.08 95.84 5,984,964.64 726,510.83 0.13 132.64 MWD(2) 5,900.16 0.51 70.41 5,893.71 5,792.01 -105.93 96.51 5,984,964.82 726,511.50 0.21 133.18 MWD(2) 5,994.96 0.49 69.54 5,988.51 5,886.81 -105.64 97.29 5,984,965.12 726,512.27 0.02 133.75 MWD(2) 6,088.91 0.49 6629 6,082.45 5,980.75 -105.34 98.03 5,984,965.45 726,513.00 0.03 134.29 MWD(2) 6,181.08 0.49 82.10 6,174.62 6,072.92 -105.13 98.79 5,984,965.68 726,513.75 0.15 134.87 MWD(2) 6,267.08 0.80 82.15 6,260.61 6,158.91 -105.00 99.74 5,984,965.84 726,514.70 0.36 135.67 MWD(2) 6,366.68 1.51 84.82 6,360.19 6,258.49 -104.78 101.74 5,984,966.12 726,516.69 0.71 137.37 MWD(2) 6,451.25 1.74 85.60 8,444.73 6,343.03 -104.59 104.13 5,984,966.39 726,519.07 0.27 139.43 MWD(2) 6,520.00 1.74 85.60 6,513.45 6,411.75 -104.43 106.21 5,984,966.61 726,521.15 0.00 141.24 PROJECTED to TD 3/29/2013 12:30:31PM Page 4 COMPASS 2003.16 Build 69 Page 1 of 1 Okland, Howard D (DOA) From: Okland, Howard D (DOA) Sent: Wednesday, May 29, 2013 9:44 AM To: 'Chip.Alvord@cop.com' Cc: Bettis, Patricia K(DOA); Davies, Stephen F (DOA); Colombie, Jody J (DOA) Subject: Incomplete 10-407 Well Completion Report for Cassin 1 Dear Mr. Alvord, The AOGCC received on April 29, 2013 the Form 10-407 "Well Completion Report"for the Cassin 1 well. As submitted, the report is incomplete, see 20AAC 25.071. The purpose of Form 10-407 is to provide a concise, two page summary for AOGCC's well records. Entries such as"Not available"or"To be sent under subsequent report" or"N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form for Cassin 1, please submit-within 15 days-a revised copy of this Form 10-407 that contains the following data: Box 27: Production test information including total production for the test period, choke size, gas/oil ratio, flowing tubing pressure, casing pressure, calculated BOPD, MCFGD, BWPD, and oil gravity. Box 28: Core Data information. On the revised Form 10-407, list the formations and intervals cored and briefly summarize the lithology and presence of oil, gas or water. If additional space is needed, submit separate sheets with the revised form. When laboratory analyses are completed, submit detailed descriptions, photographs and, including core analysis determinations, if any, of porosity, permeability, and fluid saturations as specified in 20 AAC 25.071. Box 29: On the revised Form 10-407, include all formations and geologic markers that were presented on the planned wellbore schematic drawing submitted by ConocoPhillips in support of the Cassin 1 Permit to Drill application. Include the actual measured and true vertical depths for each of these formations and geologic markers. Box 30: A list of intervals and formation tested and briefly summarize test results. Submit copies of all: 1. Drill stem test and production test data and charts; and 2. Geochemical and formation fluid analyses obtained. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. These requirements can be accessed on the Internet at: Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu0l.legis.state.ak.us/cgi-bin/folioisa.dll/stattx07/query=31!2E05! 2E030/doc/{t13554}. Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu0l.legis.state.ak.us/cgi-bin/folioisa.dll/aac/query=[JUMP:'20+aac+25! 2E0701/doc/{@ 1}?firsthit If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1235 or at howard.okland@alaska.gov. Sincerely, Howard Okland Geologic Assistant AOGCC 5/29/2013 RECEIVED ConocoPhillips MAY 2 2 2013 TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 1 Permit: 212-182-0 DATE: 05/22/2013 Transmitted: North Slope, NPRA, Alaska Cassin 1 (501032066300) CD / digital data alliburton digital ,?A..c--(0 -I ✓Digital graphic logs; digital log data; logged 3/14/2013; ROP/DGR/EWR/ALD/CTN 2"&5" MD and TVD; XBAT 2"&5" MD and TVD; XCAL 2"and 5" MD only; logs presented in CGM/DLIS+LAS, EMF, PDF and TIFF formats. Halliburton hardcopy color prints: DGR/EWR/ALD/STN/XBAT 2&5"MD&TVD; ROP/DGR/EWR/ADL/CTN repeat 2&5" MD and TVD; ROP/DGR/XCAL/MAD 5"&2" MD only PAI digital data h c-6. ✓ Sperry Sun Waveform (.dlis) ✓Halliburton Semblance digits and images (.emf, .las, .pdf, .tif) /Halliburton NAD27_NAD83 definitive directional survey data (zip.pdf& .txt) ./ BLM-approved APD(.pdf) mud gas isotope report- ISOTECH, Job 21250 in .pdf and .xls formats +/ Expro well test 1 (4-10-13 to 4-16-13)(.pdf) ✓ Expro well test 2 (4-17-13 to 4-22-13) (.pdf) +r Weatherford Rotary SWC laser grain size graphs_Job 63452 (zip/.pdf) __ 'Weatherford Laser grain size Stats and Summary 5213-6125' and (.xlsx) *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("Conocop;::dips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sari a,D.Lemket 'OP.;cain CC: Cassin 1 -e-transmittal well folder Receipt: (316---1- 14/.,,.,-,Q_ Date: 7, N� 1, 3 a,.w AK/1T-Technical Data Management.1 ConocoRtaps.1 Anchorag4.Alaska-1.Ph:.90Z265.6947 X I — 18A w�:���'�s THE STATEOil ����I�i� Alaska and Gas °fl`1LASKA Conservation Commission • 4,_,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue ,, "'pv Anchorage, Alaska 99501-3572 ALAS Main. 907.279.1433 Fax: 907 276.7542 Mick Davasher Senior Wells Engineer GQ la- 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, Cassin 1 Sundry Number: 313-206 Dear Mr. Davasher: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, � � �- Cathy P/Foerster Chair DATED this 1�ti day of May, 2013. Encl. STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COM 31ON 441-1•0/• � APPLICATION FOR SUNDRY APPROVALS �' 20 AAC 25.280 1.Type of Request: Abandon [ Rug for Redrill r Perforate New Pool r Repair w ell I-`" Change Approved Program r- Suspend (✓ Plug Perforations r Perforate r Pull Tubing [ Time Extension r Operational Shutdown E Re-enter Susp.Well r Stimulate r Alter casing r 1 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development f-. Exploratory (;i. 212-182 3 Address: 6.API Number: Stratigraphic r- Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20663-00• 7.If perforating, hat/ 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No (N Cassin 1• 9.Property Designation(Lease Number): 10.Field/Pool(s). AKAA081754 • Wildcat/Exploration 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): • 6520 '6513 •6419' •6413' '5354' none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2350' 9.625" 2378' 2378' Production 6482 7" 6507' 6501' RECEIVED APR 302013 OTs s/7/13 AOG CC Perforation Depth MD(ft):, Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5258-5273,5535-5550,5710-5725 5252-5267,5529-5544,5704-5719 3.5 L-80 5704 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER , 5045'MD,5039'TVD PACKER-BAKER PREMIER PACKER • 5323'MD,5317'ND PACKER-BAKER PREMIER PACKER • 5597'MD,5591'ND NIPPLE-CAMCO 'DS'NIPPLE •525'MD,525'TVD 12.Attachments: Description Summary of Proposal Si 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch I— Exploratory I� Stratigraphic r Development E Service r' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/29/2013 Oil r" Gas r- WDSPL I— Suspended Ro- la.Verbal Approval: Date. `/'.'x•13 VVINJ r- GINJ r- WAG r Abandoned 1- Commission Representative. C)i 5-1,....p,.--L GSTOR P SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mick Davasher @ 265-6870 Email. Mick.J.Davasheraconcophillips.com Printed Name Mick Davasher 4 Title: Senior Wells Engineer Signature f Phone:265-6870 Date /2,9/20/3 Commission Use Only Sundry Number:51 3 -2 (ôConditions of approval: Notify Commission so that a representative may witnessII Plug Integrity rt/ BOP Test P Mechanical Integrity Test r Location Clearance E RBDMS MAY - 8101 Other: Spacing Exception Required? Yes ❑ No 12r-V Sbsequent Form Required: `Q—go 7- (-0//,) V ) )*>1' COM sSI APPROVEDPCnaBY Approved by: f ✓n pi vcd application r valltl tori 11 mNonths from thTc tlate oTlapproval. Date: 5 - 7 - /3 Form 10-403(Revised 10/2012) O n I Gi Submit Form and Att �ts �plicate Cassin #1 Sundry Application Cassin#1 is an exploration well that was drilled in the spring of 2013.The well targeted the Cassin, Blackburn, and Sanford formations. We intend to temporarily suspend the well. The well will be left temporarily suspended with a pressure tested plug in the tubing at 4900', kill weight fluid, and a pressure tested wellhead (with both master and swab valves). A permanent downhole pressure/temperature gauge will continue to monitor the reservoir pressure following the well test of the Cassin formation for an extended pressure build up test.The data will be retrieved via a surface data acquisition dongle over the summer period by helicopter. Job Objective: Temporarily suspend Cassin#1. Procedure: Post well testing well work to suspend Cassin#1 1. Rig up slickline and pressure test PCE. 2. Set catcher below the gas lift mandrel at 5103' MDRT. 3. RIH and pull 1.5" spartek side pocket memory pressure gauge at 5103' MD.This gauge was run in during the completion and was set for a sample every 5 seconds. There will be a lot of data on the gauge so take your time downloading it. 4. Pull catcher sub. 5. RIH and set 2.813"XX plug in the upper completion X nipple at 4900' MD. 6. RIH and set catcher sub on XX plug at 4900' MD. 7. Pull 1.5" OV in upper completion side pocket mandrel at 4840' MD. 8. Circulate^'100 bbl of inhibited 9.8 ppg kill weight brine fluid with^'70 bbl of diesel (2000'column from surface)to suspend and freeze protect the well respectively. Put tubing and inner annulus into communication and allow freeze protect fluid to U-tube into tubing. 9. RIH and set a 1.5" Dummy Valve in upper completion side pocket mandrel at 4840'MDRT. 10. Pressure test tubing to 2500psi for 30 minutes.Chart and record test. 11. Pressure test Inner Annulus to 2500psi for 30 minutes. Chart and record test. 12. Retrieve catcher sub at 4900' MD. 13. Rig down Slickline. 14. Install surface BPV in tubing hanger. !—? Vie ply TA 5 ti M< J.�..._ Current Well Schematic Cassin #1 Nov' Suspension ConocoPhillips Completion Schematic Final Alaska BPV Conductor(Drivenl: / C i 1 FilhUpper Completion I9.1216"Conductor 108' i 1)Tubing Hanger 23.01' • 2)3-%"DS Camco Landing Nipple(2.875"Profile) 525.2' • i n 2 3)344"KBMG Mandrel with 1.5"Dummy Valve 4840.0' .00 4)344"X Nipple(2.815'10) 4900.0' • production Tubina; • 5)3-%"Smart Gauge Mandrel(with Electronic Quartz Gauge) 4950.9' 3 W,9.3#L-80,EUE 8RD R2 • 6)GBH-22 Seal Assembly and Locator 5003.3' i Lower Completion rl 7)Liner Setting Sleeve,RS Nipple and 4"Seal Bore Sub 4997.7' 8)3 4" x 7"Premier Hydraulic Retrievable Packer 5044.9'• -9.8 ppg Kill weight fluid � � Y -2000'freeze protect fluid 3 r 9)344" KBMG Gauge Mandrel 5103.4' i 10)3-%"X Nipple(2.813"ID) 5163.3' i 5 11)3-%"Frac Sleeve 5209.8' 12)3-%"Blast Joints/Blast Ring 5254.9' Surface Casino: ik 13)3-W x 7"Premier Hydraulic Retrievable Packer 5323.2' 9-5/8",40#,L-80,BTC 14)3-Y"KBMG Gauge Mandrel 5381.8' Set @ 2493'MD/2493'TVD 15)3-%"X Nipple(2.813"ID) 5441.2' 16)3-'W Frac Sleeve 5487.5' 17)3-%"Blast Joints/Blast Ring 5532.7 18)3-W x 7"Premier Hydraulic Retrievable Packer 5597.6'• 1.5"Dummy Valve installed 19)3-%"KBMG Gauge Mandrel 5656.0' 20)3-W XN Nipple(2.813"ID) 5685.2' $ 21)3-''/z'Ball Shear Sub with WL-Entry 5703.2' XX plug installed� at 4900' jam. 3 5 'A u'hilitetillil�di(j 25Q!s 4�j 4 Notes; "--• 1)Frac Sleeve was milled to 2.78"OD mill 2)A XX plug was installed on X-Nipple profile above Smart Gauge(4900') 5 3)All Frac Sleeves are opened.(Bottom sleeve could not be closed). 4)wireline retrievable bridge plug set at 5354' 7 6 8 5)A BPV was installed on the tubing hanger. 9 ® 10 f 11 � Wireline Retrievable hell Cassin Sand Peforations -._ • Plug @ 5,258'-5,273'(15) ( e• C� 12 ` _` " « set at 5354'and tested to _. - 2500psi(Good)-between 13 packer and gauge mandrel 1a } ® 15 Blackburn Sand Peforations . 16 PrimaryBarriers: @ 5,535'-5,550'(15') ( -'- 17 : % 1)XX plug at 4900' MDRT 18 +- 2) 3-'/"Tubing wili/Mitime 19 3) Dummy valve at 4840' MDRT ® 20 Sanford Sand Peforations " r`:" 2, =-r"-:-.'_ ` Secondary Barriers: •@ 5,710'-5,725(15') _ _ = =- 1) Kill weight Brine 2) BPV production Casino: 7",26.00#,L-80,BTC-Mod Set @ 6507.5'MD Schwartz, Guy L (DOA) From: Davasher, Mick J <Mick.J.Davasher@conocophillips.com> Sent: Friday, May 03, 2013 10:06 AM To: Schwartz, Guy L(DOA) Subject: RE:Cassin#1 Suspension Attachments: Cassin-1 MITT-MILIA 04-30-13.pdf;Cassin -1 MITT- MITIA.xls Guy, The main reason we did not P&A the well is because Cassin 1 encountered paying quantities of hydrocarbons as shown by the production well test. A permanent pressure gauge is installed downhole and is being used to gather long term pressure data during the suspended period. This data is critical to aid in evaluation of the reservoir to plan for future development. I have attached the pressure tests that were conducted on the IA and tubing. How do I update the submitted sundry? Regards, Mick Mick Davasher 907-265-6870 (office) From: Schwartz, Guy L(DOA) [maittoguy_schvaartz a alaska.gov] Sent: Tuesday, April 30, 2013 9:49 AM To: Davasher, Mick J Cc: Regg,James B(DOA) Subject: [EXTERNAL]RE: Cassin #1 Suspension Mick, You have verbal approval to proceed with the pressure testing portion of the sundry request. Notify inspectors as we discussed with the email notification process. Guidance Bulletin 10-01A. I would still like additional supporting documentation on the future utility of the wellbore as per 20 AAC 25.110(a)(2) and future plans for its use before approving the suspend status. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Davasher, Mick J [mailto.Mick,J.Dfavasheraconocophillipc: com] Sent: Monday, April 29, 2013 6:48 PM To: Schwartz, Guy L(DOA) Subject: Cassin #1 Suspension Guy, We did not get a chart from the pressure test when we set the plug.There is a window for us to get out there and do the test tomorrow(potentially Wednesday morning by the time scaffold gets erected) before the ice road has its river crossings cut.The sundry will be with you tomorrow morning. I have attached how the well has been suspended (this will be included in the Sundry). I will be in touch in the morning to see if you require more or have questions. Regards, Mick Mick Davasher Senior Wells Engineer ConocoPhillips Alaska, Inc 700 G Street,ATO-2052 Anchorage AK 99501 907-265-6870(office) 907-223-8074(mobile) nic:1_rtavasnerrf.concccpnIJfps L,cn; 7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reag(d)alaska.00v. doa.aogcc.crudhoe.bay@alaska.gov phoebe.brooksllbalaska coy tom.maunderatalaska.aov OPERATOR: ConocoPhillips Alaska Inc. FIELD/UNIT/PAD: Exploration/Cassin-1 DATE: 04/30/13 OPERATOR REP: Perry Klein AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Cassin-1 Type Inj. N TVD 5,039' Tubing 600 2,800 2,700 2,680 Interval 0 P.T.D.212-1820 Type test P Test psi 2500 Casing 450 490 490 490 P/F Pass Notes: Required for Sundry to suspend well OA 0 50 50 50 Well Cassin-1 Type Inj. N ND 5,039' Tubing 650 800 800 800 Interval 0 P.T.D.212-1820 Type test P Test psi 2500 Casing 420 2,950 2,900 2,900 P/F Pass Notes:Required for Sundry to suspend well OA 50 50 50 50 Well Type Inj. ND Tubing Interval - P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Type Inj ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling Waste M=Annulus Mondonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test dunng Workover W=Water D=Differential Temperature Test 0=Other(descnbe in notes) Form 10-426(Revised 06/2010) Casein-1 MITT-MITIA xis , . oMR •,0;0 i•0 0,/0 ol 1 rejyr M 1,1 I.7 i•••.„,..._ , ° li 40.1°M• Ammmw=mimmeinvelie.,4%,, lookeij. / i ..ferMorer_____=______Arar 4411•110 •11*4 _ e,tr%00.1.11%1Assw...171. 1•.... ,414 . 0 le .......W............. 4.....4.7 cit, _.i. .0===.,..,„„,,„, 41„4\„„,, rr• 4' � " ', AA° A "or tifil i IQPari-t---44* * ** ,‘N\\` / 0, _ - r.....e.... w 4/4 / - //4 ore *s4 . . 0.1: li tit 400 , 40 .......... i „pee 0 00 • � 1 �II '�i � �� rwd ° �ij; nIN' a � Nt 1atammotv+ ,,, imumplimp„„,, �� a iHtltl %Mi s 0 .4.• poopio semi ,,, os= 4*-17,==.0 st, N. 40/amos 41 .;■..._1 111114111rm".0.MB I JO, / 411111i...1110.111411.11=0...110111 IP 01 10 ftirralaw1=MAIMpll „500% NA .,_ ite,..„,„,,,,..„=„mil.0.2 0 / .1,407:411.11ftir 411=MOIlli 44111.411 ....V.0.011.leilMIMMINIO N74441141%b,, 441441/1 114. 11:11P, AtialiredMIWIMO 79 14, 4*, Nreli",Mill..111 1M/ . .411411411\111447 Alirlitriff 1.1.1 et al //100000 I.I irl 0- gig is.,1.0,1 , �Np f4 i an•--"".111174M110001 ; 'W 2b �$P� 1�js THE STATE Alaska Oil and Gas • °fAAL ASK Conservation Commission �wh GOVERNOR SEAN PARNELL 333 West Seventh Avenue O D Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax' 907.276.7542 Ty Senden Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 a Anchorage, AK 99510 Re: Exploratory, Cassin 1 Sundry Number: 313-072 Dear Mr. Senden: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P.'Foerster Chair — DATED this Z� day of March, 2013. Encl. 875 3 114 .0753 Z / D STATE OF ALASKA ' AL :A OIL AND GAS CONSERVATION COMP ION FEB 12 2013 APPLICATION FOR SUNDRY APPROVALS AOGCC AAC 25.280 AOGCC 1.Type of Request: Abandon E Plug for Redrill j— Perforate New Fool (— Repair w ell r Change Approved Program E Suspend I— Plug Perforations E Perforate I— Rill Tubing ("' Time Extension E ye. Operational Shutdown E Re-enter Susp.Well r I1 elStimulate I✓ • Alter casing I— Other: 3 �r'o�r�st I-✓ ��'6 2.Operator Name: 4.Curr d t Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory I✓ • 212-182 - 3.Address: 6.API Number: '"" Stratigraphic Service I— P. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20663-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I— NO W Cassin 1 • 9.Property Designation(Lease Number): 10.Field/Pool(s): AA081754. Wildcat ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): -Re p' na na na none none Casing Length Size MD TVD Burst Collapse CONDUCTOR $p 1G0 3b SURFACE '.�3? 5.SC. N .2378 `1�``1 PRODUCTION .2'16 8 65 0 7 :in ivmdcji. y039 y035 .11a Perforation DepthMMD ft)6 Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): 5 -5273 5t/o-575to none 3.S as ,C-30 -Pa na Packers and SSSV Type: r Packers and SSSV MD(ft)and TVD(ft) sw Packerb no SSSV -5-041115321i 5S-7 7- 31/� 12.Attachments: Description Summary of Proposal IV 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch Exploratory l Stratigraphic l— Development EService r14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil I— Gas 1-- WDSPL 1--- Suspended 1"' 16.Verbal Approval: Date: WINJ imm" GINJ r WAG I— Abandoned 1 Commission Representative: GSTOR E SPLUG 1- 17. "17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden @ 265-1544 Email: R.Tyler.Senden@conocophillips.com_ Printed Na e \ T,_Send=L Title: Staff Wells Engineer Phone:265-1544 Date Signature ` ' �,� \\� 4111 l3 \ Commission Use Only Sundry Number:315 -07Z. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 1 BOP Test E Mechanical Integrity Test I— Location Clearance 1--- Other: Other: ROAMS 41410 /0 2A Spacing Exception Required? Yes ❑ No Subsequent Form Required: - Lf0 1,4)e-ft ?el--1--) APPROVED BY Approved by: -2 (�fi� COMMISSIONER THE COMMISSION Date:3 -Z`1— 13 O R G t epresentatiapplication is valid for 12 months from the date of approval. rIfxi 1b/2j012) e—_ 2-,.r 3 s Sybmit Flom and Attachments in Duplicate a "rj (.. /2y//. -4.t 7� Cassin #1 Sundry Application Cassin #1 is an exploration well that will be drilled in the spring of 2013. The well will target the Cassin, Blackburn, and Sanford formations. We intend to perform a 3 stage fracture treatment targeting the three formations respectively. The treatment will be performed utilizing a shifting sleeve system and place approximately 300,000#'s of 16/20 CarboLite proppant. Job Objective: Fracture the Cassin, Blackburn, and Sanford formations, perform post job evaluation and discuss any discrepancies from the planned treatment design. Procedure: Schlumberger Pumping Services: (Exploration 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 and the BLM. 4. This well does NOT need a dispensation. 5. Ensure that the ConocoPhillips Stimulation manual and all relevant SLB standards • are complied with at all times during the fracturing operation. 6. MIRU 8 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. 3600 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). Seawater can either be hauled from ALP or you may substitute (with prior approval from Mike Martin/SLB) freshwater from a nearby lake. This will require Schlumberger to make 6% KCl on location and will need another proprietary additive provided by SLB. 7. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 8. MIRU Stinger Tree Saver Equipment and PT as required. 9. MIRU SLB Frac Equipment capable of 20 BPM, with a minimum of 1 stand-by pump, primed and pressure tested. See appendix for pumping equipment layout. 10. The Maximum allowable surface pressure is 6000 psi. The Maximum predicted treating pressure is 2956 psi. Set the nitrogen PRV @ 5700 psi (95% of the MAWP). 11. PT Surface lines to 6,500 psi using a pressure test fluid. 12. Test IA Pop off system to ensure lines are clear and all components are functioning/ properly. 13. Pressure up and maintain 2,500 psi on the IA. 14. Open Wellhead and displace PT fluid with gelled water. 15. SD for 5 minutes. 16. Pump the 300 bbl breakdown stage (30# linear gel, WF130) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. 17. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 18. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 19. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of —3000 psi. Stage 1 • 280 bbls YF125ST Pad • 80 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 200 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 320 bbls YF125ST w/4 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 15 bbls YF125ST Spacer • Drop AA" Ball - Stage 2 • 208 bbls YF125ST Pad • 72 bbls YF125ST additional pad for ball on seat. • 80 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 200 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 320 bbls YF125ST w/4 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 7 ppa 16/20 Carbolite • 15 bbls YF125ST Spacer • Drop BB" Ball K Stage 3 • 194 bbls YF125ST Pad • 86 bbls YF125ST additional pad for ball on seat. • 80 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 200 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 320 bbls YF125ST w/4 ppa 16/20 Carbolite • 100 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 20 bbls of cross-linked fluid (YF125ST), 20 bbls of linear fluid (WF130) and 20 bbls of freeze protect • Total Sand: Approx. 304,000 lbs 16/20 Carbolite Material Requirements: • 3600 bbls Seawater (inclusive of bottoms) • 2961 bbls of YF125ST • — 304089 lbs. 16/20 Carbolite • 10 bbls of freeze protect fluid 20. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 21. Bleed off IA pressure, down to approx. 700 psi, or recommended. 22. RDMO SLB Equipment. Freeze protect the tubing and wellhead if not able to complete following the flush. 23. Well is ready for Post Frac well prep for and for flowback (Slickline and CTU). 24. Initial flowback fluids will be taken to disposal well but after well cleans up produced hydrocarbons will be taken to the Alpine field and sold down the sales line as exploration oil. Cement Evaluation of Cassin #1 and wells within 1/4 mile of Cassin #1 Cassin #1: A cement bond log will be performed on the Cassin #1 well during the completion stage. This bond log is intended to confirm our ability to isolate the hydrocarbon zone when the well is suspended. We will also use these results of the bond log to evaluate the quality of the cement prior to the frac. Summary Based on engineering evaluation of the well referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. This is a remote exploration well and all records indicate there are no other wells within a 1/4 mile radius. Frac Simulations Cassin Sand Initial Fracture Top TVD 5372.6 ft Initial Fracture Bottom TVD 5472.6 ft Propped Fracture Half-Length. 166.0 ft EOJ Hyd Height at Well 172.6 ft Average Propped Width 0.230 in Average Gel Concentration 438.3 lb/mgal Average Gel Fluid Retained Factor 0.46 Net Pressure 441 psi Efficiency 0.444 Effective Conductivity 12879 md.ft Effective Fcd 5.2 Max Surface Pressure 2731 psi (estimate could be +/- 200 psi) Blackburn Sand Initial Fracture Top TVD 5662.5 ft Initial Fracture Bottom TVD 5772.5 ft Propped Fracture Half-Length_ 145.3 ft EOJ Hyd Height at Well 184.7 ft Average Propped Width 0.234 in Average Gel Concentration 544.5 lb/mgal Average Gel Fluid Retained Factor 0.43 Net Pressure 451 psi Efficiency 0.481 Effective Conductivity 10978 md.ft Effective Fcd 5.0 Max Surface Pressure 2846 psi (estimate could be +/- 200 psi) Sanford Sand Initial Fracture Top TVD 5877.5 ft Initial Fracture Bottom TVD 6099.4 ft Propped Fracture Half-Length. 86.2 ft EOJ Hyd Height at Well 223.2 ft Average Propped Width 0.288 in Average Gel Concentration 713.4 lb/mgal Average Gel Fluid Retained Factor 0.38 Net Pressure 469 psi Efficiency 0.501 Effective Conductivity 10115 md.ft Effective Fcd 7.8 Max Surface Pressure 2956 psi (estimate could be +/- 200 psi) Current Well Schematic Conductor Drivei): 16"Condictor 108' 7L Adi &in Upper Completion MD TVD „Tubing Hanger 2)3-W DS Camco Landing Nipple(2.875"Profile) 2 3)344"KBMG Mandrel with 1"DCK-2 Sheared valve 4)3-'4"X Nipple(2.813"ID) Production 8Tubinu: 5)3-'r4"Smart Gauge Mandrel(with Electronic Quartz Gauge) 3'/",9.3#L-80,EUE 8RD R2 6)GBH-22 Seal Assembly and Locator Lower Completion 7)Liner Setting Sleeve,RS Nipple and 4"Seal Bore Sub 8)3-14"x T Premier Hydraulic Retrievable Packer 9)3-s"KBMG Gauge Mandrel wth 1"OD Gauge(Wireline retrievable) 10)344"X Nipple(2.813"ID) Re-closb Surface Casino: 12)3'h"Blast Joantle Frac s 1 Blast Ring e with 2"ball seat C Q ii)9-5/8",40#,L-80,BTC Set @ 2493'MD 12493'TVD 13)3-i4'x 7"Premier Hydraulic Retrievable Packer 14)3-i4"X Nipple(2.813"ID) 15)3-'4"KIN G Gauge Mandrel wth 1"OD Gauge(Wireline retrievable) 16)3-'h"Re-closable Frac Sleeve wth 1.875"ball seat ( 44) 17)3-',4"Blast Joints I Blast Ring 18)3-'A"x 7"Premier Hydraulic Retrievable Packer 3 19)3-'r4"XN Nipple(2.813'ID) 20)3-s"KBMG Gauge Mandrel with 1"OD Gauge(Wireline retrievable) TOC+1-xxxx'lull IXXxx'TVD ii. 4 21)3-s"Ball Shear Sub with WL-Entry 500'above thetop Zone - — 5 7 :4 6 8 9 S 10 11 Casein Sand Perorations - : @ 5,395'—xxxx'(XX') .. `. c 12 1`0> .) l 3 13 C.. e 14 15 Blackburn Sand Perorations 16 @ 5,665'—X,XXX'(XX') .--- .. rZ .. 17 ^ �1 1 • 18 04 19„ _ _ _ 20 Sanford Sand P rforations ��`-- T 21 >+ � � > @ X,XXX'—6,040'((X') Production Casino Alle 7",26.00#,L-80,BTC-Mod Set @ 6500'MD 16500'TVD Pump Schedule JI= Y ' 8 ' ' t 4 A # A t t x , , e i } 'n 7 I ! : A 4 - Y Y 4 4 4 F 4 1 n # 4LA 7E • .we!x. ,4 4 }.. 4 A r! 4 4 r.x 4 a A na 4 tai i.>K.! 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' RECEIVED STATE OF ALASKA APR 2 9 2013 • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND Lt CC la.Well Status: Oil 11Z PGas CJ SPLUG LiPlugged Li Abandoned Suspended [ , lb.Well Class: (�7 Gj.`4't3 20AAC 25.105 20AAC 25.110 Development LI Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other , No.of Completions: Service ❑ Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' or Aband.: March 28,2013 ' 212-182/313-072 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 3,2013 50-103-20663-00 _.' 4a.Location of Well(Governmental Section): 7.Date TD Reached: ,� 14.Well Name and Number: Surface: 1106'FSL, 1502' FWL, Sec.28,T12N, RO1W, UM March 13, 2013 Cassin 1 `'' Top of Productive Horizon: 8. KB(ft above MSL): 102'RKB 15.Field/Pool(s): 998'FSL, 1594'FWL, Sec.28,T12N, RO1W, UM GL(ft above MSL): 74'AMSL Wildcat Total Depth: 9.Plug Back Depth(MD+TVD): 102'FSL, 1578'FWL, Sec. 28,T12N, RO1W, UM 6419'MD/6413'TVD Exploration 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): L, 16.Property Designation: Surface: x-726412 y- 5985068 Zone-5 6520'MD/6513'TVD ADL AKAA081754 TPI: x-726507 y- 5984963 Zone-5 11.SSSV Depth(MD+TVD): 17.Land Use Permit: N.-- Total Total Depth: x- 726521 y- 5984067 Zone-5 nipple @ 525'MD/525'TVD 953096 18.Directional Survey: Yes ❑ No Li 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1088'MD/1088'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD XRMI/Sonic/GEM/SGR/CCL / G SL_ / f ffecc not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" _62.58# H-40 28" 108' 28' 108' 24" 24 bbls AS I 9.625" 40# L-80 28' 2378' 28' 2378' 12.25" 277 bbls LiteCRETE, 74 bbls Class G 7" 26#/29# L-80/P-110 25' 6507' 255' 6501' 8.5" 52.2 bbls Class G 24.Open to production or injection? Yes U No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 5704' 5045'MD/ 5039'TVD,5323'MD/5317'TVD, 5258'-5273'MD 5252'-5267'TVD ✓ COMKEncfi 5598'MD/5591'TVD 5535'-5550'MD 5529'-5544'TVD DA1' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 5710-5725'MD 5704'-5719'TVD ZIZILZ Was hydraulic fracturing used during completion? YesI I No❑✓ j@ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED .. _ cement plug from 2263'-2308' 15 bbls AS I 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable flowing well test-gas lift assisted Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/10-22/2013 238 hours Test Period--> not available not available _ not available various not available Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. n/a not available 24-Hour Rate-> not available not available not available not available 28. CORE DATA Conventional Core(s)Acquired? Yes LL No pi Sidewall Cores Acquired? Yes ✓ No LJ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. TO BE SENT UNDER SUBSEQUENT REPORT Form 10-407 Revised 10/2012 FtBDSIS APR 2 9 Z01 �� CONTINUED ON REVERSE S"'. Lo 13 Submit original only 'l`b gl``'ti .‘, 29 GEOLOGIC MARKERS(List all formations and m. ,encountered) 30 FORMATION TESTS NAME MD TVD Well tested? El Yes Q✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1088' 1088' needed,and submit detailed test information per 20 AAC 25 071. Cassin 5160' 5156' Cassin Base 5295' 5289' Blackburn 5495' 5489' Blackburn Base 5604' 5597' Sanford 5667' 5660' Sanford Base 5752' 5745' N/A Formation at total depth: Brown 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true a9dcorrect o the best of my knowledge. Contact: David Lee @ 263-3741 c'Gv`'l Email: David.L.Lee@conocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature / , �/� Phone 265-6120 Date 44Z4120 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 NAK CASSIN 1 ConocoPhillips ill" Well Attributes Max Angle&MD TD Alaska It u: Wellbore APUUWI Field Name Well Status Incl(°) MD(ftK8) Act Blot(ftKB) 501032066300 NORTH ALASKA TIGHT HOLE EXPLOR 6.25 2,846.36 6,520.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •••Well Confp:VERTICAL-CASSIN 14'19,20138.41.54 AM SSSV:NIPPLE Last WO: Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,253.0 4/9/2013 Rev Reason:NEW EXPLORATION WELL(tight hole) osborl 4/9/2013 HANGER,23 `n Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd CONDUCTOR 16 15.250 68.0 108.0 108.0 62.50 H-40 WELDED •cInsulated 24" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd SURFACE 95/8 8.835 27.8 _ 2,378.3 2,378.2 40.00 L-80 BTCM r Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 25.1 6,507.3 6,500.7 26.00 L-80 BTC-M r Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR UPPER TUBING 3 1/2 I 2.992 I 23.0 I 5,010.0 I 5,003.6 I 9.30 I L-80 I EUE Ing"ted24 Completion Details 08 Top Depth NIPPLE,525 (TVD) Top Incl Nomi... Top(ftKB) (555) 1") Item Description Comment ID(in) 23.0 23.0 -0.01 HANGER FMC TUBING HANGER(made up to a 3'pup) 3.980 57.7 57.7 0.04 XO Reducing Crossover,4-1/2"12.6#/ft Box x 3-1/2"9.38/ft,EUE 8rd Pin 3.500 525.2 525.2 1.09 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO PROFILE 2.875 SURFACE, II II 4,900.0 4,893.6 1.05 NIPPLE HES"X"NIPPLE w/2.813"PROFILE 2.813 28-2,378 5,003.3 4,996.8 0.40 LOCATOR 80-40 GBH-22 LOCATOR(5.5'space out) 2.990 5,004.5 4,998.1 0.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY WITH 1/2 SHOE 3.000 GAS LIFT, _ . 4,840 _ , Tubing Description ' 0... String ID...Top(ftKB) Set Depth It... Depth(TVD)...String Wt...String...String Top Thrd LOWER TUBING 13 1/2 I 2.992 I 4,997.7 I 5,704.0 ISet 5,697.6 I 9.30 I L-80 I EUE Completion Details NIPPLE,4,900 - f' I• Top Depth _ (TVD) Top Incl Nomi... Top(ftKB) (RKB) (°) Item Description Comment ID(In) 4,997.7 4,991.3 0.41 SLEEVE BAKER HR LINER SETTING SLEEVE 5.000 Gauge Mandrel, _ 5,010.9 5,004.4 0.40 NIPPLE BAKER RS NIPPLE 4.250 4,951 5,0137 5,007.3 0.40 SBR BAKER 80-40(4")SEAL BORE 4.250 5,044.9 5,038.5 0.38 PACKER BAKER PREMIER PACKER 2.870 SLEEVE,4,998 5,163.3 5,156.9 0.01 NIPPLE HES"X'NIPPLE w/2.812"Profile 2.812 LOCATOR, 5,003\\vv\\ 5,209.8 5,203.4 0.14 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,2"Ball Seat(OPEN 4/17/2013) 2.000 SEAL ASSY, 5,005 5,254.9 5,248.5 0.27 BLAST JT Blast Joint,3-'/:"9.3#,L-80,EUE(Blast Joint Assy#2) 2.897 NIPPLE,5,011 5,323.2 5,316.8 0.47 PACKER 3-1/2"x 7'Baker Premier Packer#2. 2.870 Sun,5,014 ( 5,441.2 5,434.8 0.27 NIPPLE HES"X"NIPPLE w12.81T Profile 2812 5,487.5 5,481.0 0.26 FRAC PORT PACKER PLUS FRAC SLEEVE Drillable,1.875"Ball Seat(CLOSED 1.875 PACKER,5,045 4/10/2013,BUT NOT HOLDING) 5,532.7 5,526.2 0.10 BLAST JT Blast Joint,3-%"9.3#,L-80,EUE(Blast Joint Assy#1) 2.897 Gauge Mand103rel, 5,597.6 5,591.1 0.22 PACKER 3-1/2"x 7"Baker Premier Packer#1. 2.870 5, 5,685.2 5,678.7 0.38 NIPPLE HES"XN"NIPPLE w/2.75"Profile 2.750 5,703.2 5,696.7 0.41 SOS BALL SEAT SHEAROUT SUB for 1"OD ball-5000 psi shear required 2.992 NIPPLE,5,163 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth " (TVD) Top Incl Top(too) (ftKB) I°) Description Comment Run Date .ID(in) FRAC 1:31;;r6 is e 5,354.0 5,347.6 0.33 PLUG WRP PLUG 4/17/2013 0.000 _ Perforations&Slots (PERF. Shot 5.25135,273\ [ Top(TVD) Btm(TVD) Dens FRAC,5.158 f L IM Top(RKB)Btm(MB) (RKB) (ftKB) Zone Date ah... ( Type Comment 1 5,258.0 5,273.0 5,251.6 5,266.6 3/24/2013 IPERF LIMN 5,535.0 5,550.0 5,528.6 5,543.6 3/24/2013 IPERF PACKER,5,323 5,710.0 5,725.0 5,703.6 5,718.6 3/24/2013 IPERF Stimulations&Treatments PLUG,5,354 -- -PM Bottom Min Top Mao Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment Gauge Mandrel, 5,158.0 5,373.0 5,151.6 5,366.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin 5,362 formations,placing 90,370#,100,551#,and II 119,022#proppant,respectively.Utilized shifting ✓ sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation NIPPLE,5.441III stages. Pumped 3604-bbl total slurry volume,25# x-link gel with linear gel flushes,309,943#total 16/20 CarboLite(100%design). FRAC PORT, -{e e I 5,487 FRAC.5,435 `- 5,535-5,550 l 1 ow Mandrel Details 1 .;'. Top Depth Top Port S... (TVD) Incl OD Valve Latch Size TRO Run PACKER,5,598 --__ N...Top(ftKB) (RKB) F) Make Model (in) Sem Type Type (in) (psi) Run Date Com... 1 4,840.0 4,833.6 1.05 CAMCO MMG 1 1/2 GAS LIFT OV BK 0.188 0.0 4/10/2013 Shear M' MIK 2 4,950.9 4,944.5 1.04 CAMCO Espinage 1 GAS LIFT GAUGE 0.000 0.0 3/27/2013 Gauge Mandrel, i 3 5,103.5 5,097.0 0.32 CAMCO MMG 1 1/2 GAS LIFT GAUGE 0.000 0.0 3/27/2013 5•656 4 5,381.8 5,375.3 0.33 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 4/16/2013 NIPPLE,5,685 !L 5 5,656.0 5,649.5 0.32 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 4/16/2013 ill SOS,5.703 FRAC,5,610 PERF, No5,7105,725 PRODUCTION, 258.507"N TD,6,520 AL An NAK CASSIN 1 ConocoPhillips Alaska,Ir 1r: KB-Grd(ft) Rig Release Date •••Well Conrq'.VERTICAL-CASSIN 1 41192013 8'.41:54 AM Schemmattic��-Actual HANGER,23 Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (RKB) (RKB) (RKB) (WB) Type Date Comment 5,435.0 5,610.0 5,428.6 5,603.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin formations,placing 90,370#,100,551#,and 119,022#proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation % stages. Pumped 3604-bbl total slurry volume,25# CONDUCTOR x-link gel with linear gel flushes,309,943#total 16/20 Insulated 24•. CarboLite(100%design). 68-108 NIPPLE.525 ) (. 5,610.0 5,ffi5.0 5,603.6 5,818.6 FRAC 4/6/2013 FRAC the Sanford,Blackburn,and Cassin formations,placing 90,3704,100,5514,and 119,0224 proppant,respectively.Utilized shifting sleeve system to open and isolate zones dropping 2. staagges. Pumped 360nd 2.125" 4-bbl total slurry alls between the three volume,25n # x-link gel with linear gel flushes,309,9434 total 16/20 SURFACE, ■ ■ CarboLite(100%design). 26-2,378 Notes:General&Safety GAS LIFT, End Date Annotation 4,840 { 3/27/2013 -NOTE:MANDREL#2 SOLID GAUGE MANDREL 3/27/2013 NOTE:ALL MANDRELS ARE SIDE POCKET MANDRELS NIPPLE.4.900 -- I. Gauge Mandrel, 4,951 • SLEEVE,4,998 LOCATOR, 5,003�VV�VVII ,— SEAL ASSY, 5.005 NC NIPPLE,5,011 ' SBR,5,014 MIL PACKER,5.045 Gauge Mandrel, 5.103 NIPPLE,5.163 101 11111 FRAC PORT, (e e 5,210 IPERF, 5,2585,273 FRAC,5,158 Mr PACKER.5.323 PLUG.5,354 --- - Gauge Mandrel, 5,382 NIPPLE,5,441 FRAC PORT, 5.487 11111111 FRAC,5,435 )p IPERF, L ( 5,5355,550 J -- MIN PACKER,5,598 Gauge Mandrel, 5.656 NIPPLE,5,685 ( SOS,5,703 ,— FRAC,5,610 IPERF, 5,7105,725 PRODUCTION, 25-6,507 TD,6,520 ConocoPhiIIips Time Log & Summary Wel!view Web Reporting Report Well Name: CASSIN 1 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 2/17/2013 12:00:00 PM Rig Release: 3/21/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/17/2013 24 hr Summary Rig maintenance,Work orders, clean rig,work on top drive stand jump, clean and inspect mud pumps,clean pits in rock washer,do oil in drawworks 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Clean&clear rig floor,work on top drive stand jump, MP-2's,clean under floor,flush mud pumps, clean suction manifolds, inspect valves and seats,work on drawworks c/o oil, clean mezzinine, clean pits in rock washer. 02/18/2013 Rig Maintenance, MP@2's,work on top drive,grease crown, inspect derrick,change valves in rock washer, gease and inspect skate, remove riser f/pits. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue working on MP2's work on mud pumps,scrub rig, repair washed out demco valves in rock washer, work on stand jump on top drive, ispect derrick,grease crown, grease skate, remover riser f/pit 6 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Continue working on MP2"s,clean rig,work on pit risers, continue working on valves in rockwasher 02/19/2013 Continue rig maintenance,work on shakers,Top Drive, Mud pumps, Riser in pits,valves in rock washer, pumps in rock washer,clean A-legs and work on bridge crane hoses. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T PJSM,Continue Cleaning rig, repair riser cable, assemble pumps,clean under drawworks,continue fabricating riser for pit#6. 12:00 00:00 12.00 0 0 MIRU MOVE MOB T PJSM, C/O rails on shakers, clean A-Legs on rig floor, Inspect Top Drive, Moblize spare parts from pump room to parts van.Work on pumps in rock washer room, paint new riser in pits, Fix bridge crane hoses in cellar. Test hydraulic moving system. 02/20/2013 Continue working on maintenance,Wash and clean walls in pipe shed and rig floor, Install rizer in pits, rebuild top end on test pump, Rebuild valves in rockwasher. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue cleaning rig floor, Pump room, Inspect mud cleaner, Install rizer in pit. prep cellar for move, Rebuild 3"demco valves in rockwasher,Scrud walls in pipe shed, assemble tools and diverter bolts, bagged oily waste for shipment, cleean around hydraulic pumps, rebuild top end on test pump,work on rig alarms. Page 1 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Continue to work on rig alarms, scrub choke manifold, clean#3 air compressor, clean filters on#3 air compressor, Finish welding riser on pit 6, Disasemble pump#2 in rock washer and inspect impellar, clean walls in pits and cattle chute. 02/21/2013 Continue working on maintenance, Inventory parts on rig,C/O needle valves on test manifold,C/O rubber mounts on shaker#2. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Continue cleaning rig, Inventory parts for rig floor, Pump room,and Motor room, Inspect discharged Demco valves in rockwasher, C/O leaking needle valve on test maniflod, Change out rubber mounts on shaker #2 12:00 00:00 12.00 0 0 MIRU MOVE MOB P PJSM, Fix handle on pipe shed, clean pit suctions, R/D skate.Thaw out cellar box, R/D choke line,Prep rig for move,Test hydraulic moving system. 02/22/2013 Continue working on maintenance, prep for move, clean out vac tank, cellar tank,freeze protect test pump, Change over to 5"on iron roughneck, mud bucket,dog collar, check air pressure on rig tires,clean out pollution pan&cellar box, Blow down rig water lines.Vac off water out of rockwasher. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T PJSM,Clean rig, MP2s, Clean out vac tank, cellar tank, Freeze protect test pump, pressure washer, washing machine, chip up ice in pump room,Service all 1502 valves, X-O's, clean&inspect air slips,fuel rig. 12:00 00:00 12.00 0 0 MIRU MOVE MOB T PJSM,Clean out pollution pan& cellar box, Blow down rig water,vac off water in rockwasher, Prep iron roughneck for 5"dp, Mud Bucket and dog collar,check rig tires air pressure. 02/23/2013 Disconnect Gycol line,water lines&remove handy berms around rockwasher, Blow down rig,disconnect steam&air lines,Weather has shut down possible rig move, Reconnect steam and electrical lines up and turn steam back on. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM, Prep-rig for move, remove and disconnect glyco lines and water lines, remove handy berm from rock washer. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM, Blow down steam, disconnect air and service lines between complexs, Move out pipeshed heater. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,On weather hold. Hook steam lines&electrical lines back up and take on water and fuel. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue weather hold,send steam through rig. Page 2 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/24/2013 24 hr Summary Organize parts cabinets&tool boxes,scrub dog house&electricans room.C/O tong dies, repair camlocks on service connects,cont.working on MP2's. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM,Coninue organizing Parts cabinets and tool boxes. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,Scrub doghouse and electricans room while waiting on _weather. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,Change out tong dies, repair camlocks on service connects. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM, held table top H2S&Diverter drills with After Action Reviews, continue cleaning rig and working on MP2's. 02/25/2013 Continue rig cleaning and welding repairs, remove tioga heater ducting on side of pipe shed,stairs and landing off pipe shed for move.Work on MP2's. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM,Work on MP2's,Scrub boiler room. 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,work on MP2's and clean snow off stairways, plumb steam lines to centrifugal room,fuel camp, clean out air compressor radiator, service centrifuge pumps, inspect cam locks and install new safety wires where needed. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM, Continue cleaning, Remove pipe shed Tioga heater duct ing, stairs&landing on pipe shed ODS, Repair cracks on Iron roughneck, Fix trough gates in pits, Repair 3"valve on possum belly jet line, Clean boiler room. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue cleaning rig, Held Table Top Drills and discussions, work on MP2's,generate HRWs. 02/26/2013 Clean rig, Held Table top drills, Clean off snow from arctic entry,stairways,off load water from rig tank, Blow down steam and disconnect lines and unplug electrical lines. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T PJSM, Scrub rig walls and equipment, Held Table Top Drills with rig crew, 06:00 12:00 6.00 0 0 MIRU MOVE MOB T PJSM,Cleaning rig, C/O packing on steam valve,complete HRWs, Shovel out arctic entery, clean snow off stairways, Off load water from rig tank. 12:00 18:00 6.00 0 0 MIRU MOVE MOB T PJSM,Continue cleaning rig,At 13:40 hrs held Diverter&Spill drill till 14:12 hrs,All notifications were made. Function test jacking systems,shovel snow around complex's, PJSM om rigging down. 18:00 21:00 3.00 0 0 MIRU MOVE MOB T PJSM, Blow down steam lines and disconnect,switch to cold starts, unplug electrical lines. Page 3 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Move out pipe sheds and modules off well and spot at G-pad, Move sub off well and stage for move to Cassin# 1. 02/27/2013 Move complex's rockwasher,boiler, pits and motor complex's to Cassin#1, Round trip for sub and pipe sheds and made it to guard shack on ice road @ midnite. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move Rockwasher, Boiler, Motor& pit complex's F/1 R-Pad T/Cassin# 1. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Continue moving complexes to Cassin#1, Return with Peak trucks to 1 R-Pad and move sub and pipe sheds to Cassin#1 well. (Made it to the guard shack @ midnite.) 02/28/2013 Move sub and pipe sheds to Cassin#1 From 1 R-pad, Spot Sub and lay hurculite and mats, Spot pipe sheds, spot pits, pumps, motor and boiler complexes, Hook interconnects and turn on steam. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move Sub and pipe sheds From 2L 'Pad to Midway camp. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Continue moving sub and pipe sheds to Cassin#1 14:00 15:00 1.00 0 0 MIRU MOVE MOB P Spot sub over wellhead, Unload pipe shed and lay hurculite and lay mats for pipe shed and power pack,spot pipe sheds. 15:00 21:00 6.00 0 0 MIRU MOVE MOB P Spot Pits,pumps, motors and boiler complexes,spot roch washer. 21:00 00:00 3.00 0 0 MIRU MOVE RURD P Hook up steam,gylco,water and air service connects, lower stairs on all complexes,work on rig acceptence list,turn on steam. 03/01/2013 Rigging up, Rig move completed to Cassin#1,Accepted rig @ 18:00 hrs,3/1/2013 00:00 12:00 12.00 0 0 MIRU MOVE RURD P PJSM,Continue working on rig acceptance check list, Berm Rockwasher, rig and sub.Trim herculite,set stairways,assemble mud pumps and pit room mud lines, lower skate rail, Lay camp matts and herculite. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P PJSM,Continue working on rig acceptance list, R/U pits, pump room, berm sub, lay matts& herculite for camp and shop, winterize cellar area, rig up pipe shed satirs, herculite and set Tioga heater, geronmio line,Test gas alarms. Rig acceptted @ 18:00 hrs,3-1-2013 18:00 00:00 6.00 0 0 MIRU MOVE RURD P PJSM, N/U diverter,take on 10.0 ppg spud mud, un-load pipe shed,set site control shack. 03/02/2013 Load shed with 5"dp, Perform diverter and accumulator test test waived by Chuck Scheve, P/U dp&stand back in derrick, Mobilize tool and BHA to rig floor, Helded Pre-Sud with crews, Hook up communications to CanRig unit, Held diverter shallow gas drill&AAR with crews, M/U BHA#1. Page 4 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:45 8.75 0 0 SURFAt DRILL OTHR P PJSM, P/U Mouse hole, Load shed with 90 jts of 5"dp and 3 Flex DCs, Check accumulators bladders, N/D small section of diverter line,Total lenght from sub door is 105', Spot and set CanRig unit,Spot rock washer cutting tank, Perform diverter and accumulator test, Diverter test waived by Chuck Scheve,System pressure=299 psi, pressure after closing=1800 psi,200 psi attained= 38 sec, Full pressure obtained=210 sec, Five bottles avg.=2100 psi, Time for knife valve open= 12 sec, Hydrill to close=20 sec. 08:45 09:00 0.25 0 0 SURFA( DRILL SFTY P PJSM on picking up dp and standing back into derrick. 09:00 12:00 3.00 0 0 SURFA( DRILL OTHR P P/U 5"dp and rack ak into derrick. 12:00 12:15 0.25 0 0 SURFA( DRILL OTHR P PJSM on P/U on dp. 12:15 13:45 1.50 0 0 SURFA( DRILL OTHR P Finish P/U 5"dp and stand back into derrick. 13:45 14:15 0.50 0 0 SURFAt DRILL PULD P PJSM, Mobilize 12-1/4"bit to rig floor and strap 5"hwtdp in pipe shed. 14:15 15:30 1.25 0 0 SURF/NC DRILL OTHR P P/U 5"hwtdp and jars and stand back into derrick. 15:30 15:45 0.25 0 0 SURFAt DRILL OTHR P Clean&clear rig floor, PJSM on beaver slide operations,Mobilize tools and equipment to rig floor. 15:45 17:30 1.75 0 0 SURFA( DRILL SVRG P PJSM,service Top Drive, Drawworks, Iron roughneck and COM. 17:30 18:45 1.25 0 0 SURFA( DRILL SFTY P Pre-sud meeting with Co. Reps.and service crews on location. 18:45 21:30 2.75 0 0 SURFA( DRILL OTHR P Hook up communications with CanRig unit,clean rig. 21:30 23:00 1.50 0 0 SURFA( DRILL SFTY P PJSM and held Diverter shallow gas Drill,Well Secured in 1 min 15 sec. Rig crew arrived at muster area in 3 mins,All truck drivers and after doing a head count 11 mins total for drill. Held after action review with all. 23:00 00:00 1.00 0 0 SURFA( DRILL PULD P PJSM,and Make up Sperry BHA# 1. 03/03/2013 Flood lines and found fluid leaking out weep hole, N/D diverter line&knife valve and found it was placed in wrong direction,Change direction of valve and N/U diverter line and tested good,Spud in @ 3:57 AM, 3/3/2013, Drill F/108'MD T/854'MD,TVD=854' 00:00 00:15 0.25 0 108 SURFA( DRILL PULD P PJSM, M/U BHA as per Sperry. 00:15 00:30 0.25 108 108 SURFA( DRILL OTHR P Flood lines and conductor,Observed Luid coming out of weep hole on diverter line.Shut down and drain stack and Top Drive. 00:30 00:45 0.25 108 108 SURF/NC DRILL RGRP T PJSM on N/D knife valve. Page 5 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:30 2.75 108 108 SURFA( DRILL RGRP T N/D knife valve,observed knife valve in wrong direction,turned knife valve to correct direction and N/U line and valve back up. 03:30 03:45 0.25 108 108 SURFA( DRILL OTHR P Flood conductor and lines,Test to 3500 psi,Good. 03:45 09:15 5.50 108 408 SURFA( DRILL DRLG P Drill F/108' T/408'TVD-408', ART-4.35,Jar hrs-0.0, BIT HRS-4.35, PUW-160, SOW-48, ROT WT-91, TQ-1K,TQ off-1K,WOB-12-15K,70 RPM,430 GPM,600 PSI 09:15 09:30 0.25 408 408 SURFA( DRILL CIRC P CBU @ 40 gpm,495 psi. 09:30 10:00 0.50 408 42 SURFA( DRILL TRIP P Blow down Top Drive and lines. POOH F/408'T/42' 10:00 10:15 0.25 42 42 SURFA( DRILL SFTY P PJSM on M/U the rest of 8"BHA 10:15 12:00 1.75 42 102 SURFA( DRILL PULD P M/U Surface BHA to 102'MD 12:00 12:15 0.25 102 102 SURFA( DRILL SFTY P PJSM on M/U BHA with new crew. 12:15 14:15 2.00 102 207 SURFA( DRILL PULD P Finish M/U BHA, Up load MWD data, P/U Flex DCs, SPT MWD @ 450 gpm 720 psi. 14:15 15:15 1.00 207 408 SURFA( DRILL OTHR P Madd Pass F/207'MDT/408'MD @ 250'-3007 Hr,with 440 gpm 720 psi. 15:15 18:00 2.75 408 576 SURFA( DRILL DRLG P Drill F/408' T/576'TVD-576', ART-1.8,AST=.23,ADT=2.03,Jar hrs-2.03, BIT HRS-6.87, PUW-68 K, SOW-72 K, ROTWT-70 K,TQ-.5 K, TQ off-1 K,WOB-10-15 K,70 RPM 430GPM 600 PSI 18:00 20:30 2.50 576 708 SURFA( DRILL DRLG P Drill F/576' T/708'TVD-708', ART-1.79,AST=0.0,ADT= 1.79,Jar hrs-3.82, BIT HRS-8.66, PUW-70 K, SOW-73 K, ROTWT-72 K,TQ-.2 K, TQ off-1.5 K,WOB-8-10 K,80 RPM 500 GPM 1000 PSI, ECD=10.65 ppg 20:30 21:00 0.50 708 708 SURFA( DRILL CIRC P P/U off btm and change shaker screens and Rock washer over load, Circ @ 60 gpm and work dp. 21:00 00:00 3.00 708 854 SURFA( DRILL DRLG P Drill F/708' T/854'ND-854', ART-2.12,AST=0.0,ADT=2.12,Jar hrs-5.94, BIT HRS-10.31, PUW-75 K, SOW-77 K, ROTWT-77 K,TQ-.1.5 K,TQ off- 1 K,WOB-10-12 K,80 RPM 500 GPM 1100 PSI, ECD= 10.85 ppg. 03/04/2013 Drill F/1232'T/2334'MD TVD=2334'and wait on Geologist,drill 50 more feet to 2384'MD TVD=2384'and CBU sample for Geologist. Page 6 of 23 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 06:00 6.00 854 1,224 SURFA( DRILL DRLG P Drill F/854 T/1224'TVD-1223', ART-4.96,AST=0.0,ADT=4.96,Jar hrs-11.07, BIT HRS-15.44, PUW-81 K,SOW-85 K, ROTWT-85 K,TQ-.3 K,TQ off-1 K,WOB-15-17 K,80 RPM 500 GPM 1125 PSI, ECD= 10.82 ppg• 06:00 12:00 6.00 1,224 1,550 SURFA( DRILL DRLG P Drill F/1224 T/1550'TVD-1550', ART-4.02,AST=0.0,ADT=4.02,Jar hrs-15.09, BIT HRS-19.46, PUW-86 K, SOW-88 K, ROTWT-90 K,TQ-.2 K,TQ off-1 K,WOB-15-17 K, 80 RPM 532 GPM 1450 PSI, ECD= 10.82 ppg. 12:00 18:00 6.00 1,550 2,000 SURFA( DRILL DRLG P Drill F/1550 T/2000'TVD-2000', ART-4.73,AST=0.0,ADT=4.73, Jar hrs-19.82, BIT HRS-24.19, PUW-96 K, SOW-97 K, ROTWT- 97 K,TQ-.2 K,TQ off-1 K, WOB-15-17 K, 80 RPM 530 GPM 1440 PSI, ECD= 11.13 ppg. 18:00 22:00 4.00 2,000 2,334 SURFA( DRILL DRLG P Drill F/2000 T/2334'TVD-2334', ART-3.51,AST=0.0,ADT=3.51, Jar hrs-23.33, BIT HRS-27.70, PUW-102 K, SOW-105 K, ROTWT- 105 K,TQ-.2 K,TQ off-1 K, WOB-15-17 K,80 RPM 530 GPM 1550 PSI, ECD= 11.11 ppg. 22:00 22:30 0.50 2,334 2,334 SURFA( DRILL CIRC P Wait on Geologist to disccuss with town for casing point, Rotate and work pipe @ 550 gpm 1575 psi,60 RPM 22:30 23:00 0.50 2,334 2,384 SURFA( DRILL DRLG P Drill F/2334 T/2384'TVD-2384', ART-.49,AST=0.0,ADT=.49,Jar hrs-23.82, BIT HRS-28.19, PUW- 102 K,SOW-105 K, ROTWT-105 K,TQ-.2 K,TQ off-1 K,WOB-15-20 K,80 RPM 545 GPM 1550 PSI, ECD= 11.15 ppg. 23:00 00:00 1.00 2,384 2,384 SURFA( DRILL CIRC P CBU for Geologist and samples @ 60 rpm, 545 gpm, 1550 psi 03/05/2013 Drilled to TD @ 2388'MD TVD-2388'.CBU X 3. Make wiper trip to 671', no tight hole. Run back to bottom @ ✓ 2388'and circulate hole clean. POOH and LID BHA. Rig up casing tools. Run 9-5/8"casing to 1311'and circulate casing volume plus 10 bbls.Cont running 9-5/8"casing to 2378'. 00:00', 00:15 0.25 2,384 2,384 SURFA( DRILL CIRC P PJSM, Cont to wait on Geologist, Rot @ 60 RPM's w/1K Tq. Pump @ 545 GPM=1550 PSI. 00:15 00:30 0.25 2,384 2,388 SURFA( DRILL DRLG P Drill f/2384't/2388'.TVD=2388'. Pump @ 600 GPM=1780 PSI,80 RPM's w/2K Tq. P/U=102K, S/O= 105K, ROT= 105K, 80%flow. 00:30 01:45 1.25 2,388 2,388 SURFA( CASING CIRC P CBU X 3, pumped weighted sweep after 1st BU @ 600 GPM= 1750 PSI, 80%flow, 60 RPM's w/1K Tq. Shoot survey. 01:45 02:15 0.50 2,388 2,334 SURFA( CASING OWFF P POOH to 2334'. Blow down top drive and monitor well, static. Page 7 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 03:30 1.25 2,334 671 SURFA( CASING TRIP P POOH on elevators to 671',good trip no tight hole observed. Strapped pipe in derrick.Actual displacement= 16.66 bbls, Calculated displacement= 14.04 bbls. 03:30 04:45 1.25 671 2,388 SURFA( CASING TRIP P RIH to 2388'.washed down the last 50'@ 4 BPM=550 PSI w/no rotary. No fill observed on bottom.Actual displacement= 11.65 bbls, Calculated displacement=14.04 bbls. 04:45 07:45 3.00 2,388 2,388 SURFA( CASING CIRC P Established circulation,observed flowline packing off with clay balls. Slowed pumps down and worked pipe until clays balls cleaned up. Circulated hole clean @ 600 GPM=1800 PSI,60 RPMs. SIMOPS, P/U casing tools. 07:45 08:15 0.50 2,388 2,334 SURFA( CASING OWFF P POOH to 2334'. Blow down top drive and monitor well,static. 08:15 09:30 1.25 2,334 671 SURFA( CASING TRIP P POOH f/2334'to 671'on elevators, good trip.Actual displacement= 30.09 bbls,Calculated displacement=27.28 bbls. 09:30 10:45 1.25 671 155 SURFA( CASING TRIP P PJSM,stand back 5 stands of HWDP w/Jars. L/D 3 Flex collars and 1 Stab.Clean clay off of the rig floor. 10:45 12:00 1.25 155 155 SURFA( CASING PULD P Plug into MWD and download tools as per Halliburton rep. 12:00 12:15 0.25 155 155 SURFA( CASING SFTY P Hold PJSM on L/D BHA and handling BHA in the pipe shed. 12:15 13:15 1.00 155 0 SURFA( CASING PULD P L/D BHA as per Halliburton rep. Drain and flush motor and break bit. 13:15 13:45 0.50 0 0 SURFA( CASING OTHR P Clean and clear rig floor.Grade bit, 1-1-ER-A-E-1-NO-TD 13:45 14:00 0.25 0 0 SURFA( CASING SFTY P Hold PJSM on rigging up to run 9-5/8"casing. 14:00 16:30 2.50 0 0 SURFA( CASING RURD P Rig up to run 9-5/8"surface casing and install 1502 on diverter spool. 16:30 16:45 0.25 0 0 SURFA( CASING SFTY P Hold PJSM on running 9-5/8"casing. 16:45 20:30 3.75 0 1,311 SURFA( CASING RNCS P Run 9-5/8"casing as per detail. M/U shoe track and test floats,good test. Cont RIH t/1311'P/U=68K, SIO= 64K. 20:30 21:15 0.75 1,311 1,311 SURFA( CASING CIRC P Circulate casing volume plus 10 bbls. Stage pumps up from 2 BPM=100 PSI,48%flow, 3 BPM=200 PSI,4 BPM=220 PSI, 5 BPH=275 PSI. P/U=81K, S/O=76K. 21:15 00:00 2.75 1,311 2,378 SURFA( CASING RNCS P Cont to run 9-5/8"casing as per detail. M/U pups and joint#53. P/U hanger and landing joint. P/U=120K, S/O= 104K.Actual displacement= 23.8 bbls, Calculated displacement= 36.6 bbls, lost 12.8 bbls. Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/06/2013 24 hr Summary Conditioned spud mud for cement job. Pumped 277 bbls of lead and 74 bbls of tail cement, 130 bbls of good cement returned to surface.After plug bumped observed cement falling in annulus. Began to N/D diverter and gas bubbles where observed in annulus. Monitor well then N/D diverter. Find TOC @ 106',78'below ground level. M/U 3/4"top job pipe and RIH. Pump 16 bbls of AS1 cement, cement 6'below hanger. 00:00 00:30 0.50 2,378 2,378 SURFA( CEMEN-RURD P PJSM, RID Franks fill up tool. Install cement head and rig up to circulate through cement line. 00:30 02:45 2.25 2,378 2,378 SURFA( CEMEN•CIRC P Circulate and condition mud for cement job,YP= 18. Stage pumps up from 2 BPM=225 PSI tp 6 BPM= 325 PSI w/60%flow. P/U= 120K, S/O=105K. 02:45 03:00 0.25 2,378 2,378 SURFA( CEMEN-SFTY P Hold PJSM on pumping cement. Discuss working around high pressure lines and proper fluid transfer procedures. 03:00 03:45 0.75 2,378 2,378 SURFA( CEMEN"CMNT P Prime up cement unit and pressure test lines t/1000/3700 PSI. 03:45 06:15 2.50 2,378 2,378 SURFA( CEMEN-CMNT P Cement 477 bbsurface casing10.2 2as follows, (4" • ed P P of0Pp MudPush II,drop bottom plug, pump 277.5 bbls of 11.0 ppg ALC lead cement, 74.6 bbls of 15.8 ppg G blend tail cement and 5 bbls of H2O. Drop top plug and displace cement with 9.9 ppg thin spud mud for 1670 strokes. Bumped plug and pressred up to 1100 PSI, held for 5 min. Bleed off pressure and check floats,good. Casing shoe @ 2378.35'.After bumpinc pllu_g_observed cement in _ 9.5/8"by,condt.ctor annulus fall out of site. 06:15 08:15 2.00 SURFA( CEMEN•RURD P Rig down cement head and landing joint. Flush surface riser and work annular preventer on diverter system. 08:15 08:30 0.25 SURFA(WHDBO SFTY P Hold PJSM on nipple down diverter system. 08:30 09:30 1.00 SURFA(CEMEN-NUND P Started to nipple down diverter and observed bubbles coming from backside. Decision made to stop nipple down and monitor well. Observed 40 LEL. 09:30 12:45 3.25 SURFA( CEMEN"OWFF T Pick up one stand of drill pipe. Monitor well. SIMOPS,clean casing tools off rig floor.Clean mud pits and rock washer. Pick up 3 joints of 1" pipe for top job. 12:45 13:30 0.75 SURFA( CEMEN"CMNT T Attempt to run 1"pipe in annulus, pipe would not go though the hanger. Clean top of hager and try again, no succuss. Decision made to nipple down diverter system. 13:30 13:45 0.25 SURFA( CEMEN•SFTY T Hold PJSM on nipple down diverter system. Page 9 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 17:15 3.50 SURFA(WHDBO NUND T Nipple down diverter,adapter spool and diverter spool. Remove diverter pipe and clean. Clean and clear tools and equipment.Attempt to run 1" pipe in annulus,tool joint on 1"pipe would not pass though flutes on hanger. Ran plumbob down annulus and tagged cement @ 78'down from ground level. 17:15 20:30 3.25 SURFA( CEMEN'RURD T Make yp 80'of 3/4"pipe for top iob. Heat water to 70°and rig up SLB cement equipment. Mob wellhead equipment to cellar area and rig down long bails. L/D raiser and take on 9.8 ppg Kla-shield mud into pits. 20:30 20:45 0.25 SURFA( CEMEN"SFTY T Hold PJSM on cementing. 20:45 22:15 1.50 SURFA( CEMEN-CMNT T Pump top job as per SLB. Batch up cement and blow air though lines. Pump water to flush to clean out annulus followed by 16 bbls-_of 15.7 ppg AS1 cement.Observed 15.4 ppg cement at surface.Cement dropped slightly then held with TOC 6'below hanger. 22:15 00:00 1.75 SURFA( CEMEN-RURD T Clean out cement from cellar box and monitor cement status in annulus. Cont to rig up floor to test BOPE. 03/07/2013 N/U wellhead and test seals U 1000 PSI f/10 min. N/U BOPE and install check valve in kill line. R/U and test ,BOPE U_250/3500 PSI.Test all rams and valves for 10 min each as per BLM reg. BLM rep Justin Miller ----------- witnessed test.AOGCC rep Lou Grimaldi waived witness of test. Pick up 5"drill pipe and stand back in derrick. M/U motor and bit.Weather turned into phase III,shut down and wait in weather to improve. 00:00 00:15 0.25 SURFA( CEMEN"OTHR T Observed cement in annulus,still holding 6'below ground level after 30min. 00:15 01:30 1.25 SURFA(WHDBO NUND P PJSM, Nipple up wellhead equpiment and test metal to metal seals for 1000 psi for 10 min,good. 01:30 07:30 6.00 SURFA(WHDBO NUND P Nipple up adapter flange and BOP stack. Install check valve on kill line. 07:30 08:00 0.50 SURFA(WHDBO RURD P Pick up test plug,wear bushing and running tool. 08:00 08:15 0.25 SURFA(WHDBO SFTY P Hold PJSM on testing BOPE. Discuss working around high pressure lines, place signage in proper location and using good communication. 08:15 10:30 2.25 SURFA(WHDBO BOPE P Fill stack with water,flange leaking. Retighten bolts on stack. Rig up to test BOPE. Page 10 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 16:00 5.50 SURFA(WHDBO BOPE P Test BOPE to 250/3500 PSI.Test #1:Top pipe rams, manual kill line valve,CV 1, 12,13 and 14. Test#2: Upper IBOP, HCR kill,CV 9 and 11. Test#3: Lower IBOP,CV 5,8 and 10. f,t7C Test#4: Dart valve,CV 4,6,7 and kill line check valve. Test#5: Floor valve. Test#6: HCR choke. Test#7: Manual choke and HCR kill. Test #8:Annular preventer. Test#9: Lower pipe rams. Test#10: Blind rams and CV 3. System pressure= 2950 PSI, pressure after closing= 1800 PSI.200 PSI attained after 34 seconds and full pressure attained after 3:17. Nitrogen bottles average= 2150 PSI.AOGCC inspector Lou Grimaldi waved witness of test. BLM rep Justin Miller witnessed the test. 16:00 17:15 1.25 SURFA(WHDBO BOPE P Rig down testing equipment and set wear bushing. Blow down top drive, choke and kill lines, 17:15 17:45 0.50 SURFA( RIGMNT SVRG P Inspect swivel packing and tighten/grease. 17:45 18:00 0.25 SURFA( CEMEN'SFTY P Hold PJSM on picking up 5"drill pipe via mouse hole. 18:00 21:00 3.00 SURFA( CEMEN'PULD P Pick up 60 joints of 5"drill pipe and stand back in derrick. Lay down 4 joints of HWDP and 8"Jars. Pick up 6-3/4"Jars and stand back. 21:00 21:15 0.25 SURFA( CEMEN'PULD P Clean and clear rig floor. 21:15 21:30 0.25 SURFA( CEMEN-SFTY P Hold PJSM on picking up BHA. 21:30 22:00 0.50 SURFA( CEMEN'PULD P Make up bit to Sperry mud motor. 22:00 00:00 2.00 SURFA( CEMEN'OTHR T Hold PJSM,discuss phase III weather operations. Shut down and wait on phase III weather. Scrub and clean around rig.Work on small indoor projects. 03/08/2013 Cont to wait on Phase III weather. M/U BHA and load sources.Shallow hole test MWD tools,good. RIH picking up 5"drill pipe.CBU,test surface casing to 3000 PSI for 30 min,good.Wash down to TOC @ 2293'. �O"I Drill out shoe track and 20'of new hole.Attempt to perform FIT/LOT, leak off—310 psi, 12.ppg LOT.CBU and treat mud to POOH and squeeze cement. 00:00 10:30 10.50 SURFA( CEMEN"OTHR T Hold PJSM,wait on phase III weather to improve.Work on small indoor projects. 10:30 10:45 0.25 SURFA( CEMEN'SFTY P Hold PJSM on making up BHA. 10:45 12:30 1.75 0 125 SURFA( CEMEN"PULD P Make up Sperry BHA#3, mud motor and MWD tools. 12:30 15:15 2.75 125 125 SURFA( CEMEN-DHEQ P Upload MWD tools, problems Uploading tools. Break connection and trouble shoot MWD tools. Plug back into tools and upload tools as per Halliburton rep. Page 11 of 23 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:15 15:30 0.25 125 125 SURFA(CEMEN"PULD P Pick up nucular sources from beaver slide. 15:30 16:00 0.50 125 125 SURFA(CEMEN"SFTY P Hold PJSM on loading nucular sources,dicussed proper hand placement and crews first day back from days off. 16:00 16:45 0.75 125 600 SURFA( CEMEN-PULD P Load sources and cont.to pick up BHA. 16:45 17:30 0.75 600 600 SURFA( CEMEN-DHEQ P Shallow hole test tools, pump @ 500 GPM=1425 PSI. Blow down top drive. 17:30 18:45 1.25 600 2,082 SURFA(CEMEN-PULD P Run in the hole picking up 5"drill pipe to 2082'. 18:45 19:00 0.25 2,082 2,082 SURFA(CEMEN"SFTY P Hold PJSM on testing 9-5/8"40 ppf L-80 surface casing. 19:00 19:45 0.75 2,082 2,082 SURFA( CEMEN"CIRC P Rig up and CBU @ 2082'for casing test. Pump @ 220 GPM=575 PSI. P/U=87K, S/O=85K. 19:45 20:15 0.50 2,082 2,082 SURFAC CEMEN-PRTS P Test 9-5/8"40 ppf L-80 surface casing to 3000 PSI for 30 min. record on chart.Good test. 20:15 21:15 1.00 2,082 2,293 SURFA( CEMEN'WASH P Rig down testing equipment.Wash and ream down f/2082'to 2293'. 21:15 00:00 2.75 2,293 2,345 SURFA( CEMEN"DRLG P Drill out shoe track f/top of FC @ 2293'to 2345'.TVD=2345.ART= 1.75,ADT= 1.75.Jar hrs.=1.75, Bit hrs=1.75. P/U=93K,S/O=96K, ROT=97K,Tq=3K. ECD=10.3 ppg, Flow 64%@ 515 GPM= 1500 PSI. 03/09/2013 Drill out shoe track and 20'of new hole to 2408'.Attempt to perform FIT/LOT, leak off—310�si 12.2 ppq LOT. CBU and treat mud. POOH and stand back MWD tools, UD motor and bit. P/U 3-1/2"cement string and RIH on 5"DP.Tag bottom @ 2408'and swap mud system. Pump MudPush, 15 bbls of AS1 cement and MudPush. POOH above cement and Circ S/S. Perform hesitation squeeze,squeezed 4.8 bbls of cement before pressure held @ 600 PSI. POOH. 00:00 01:15 1.25 2,345 2,388 SURFA( CEMEN-DRLG P PJSM,Cont to drill shoe track f/ 2345'to 2388'. 01:15 01:45 0.50 2,388 2,408 SURFA( CEMEN"DRLG P Drill 20'of new hole to 2408'. Bit hrs= 3.12,Jar hrs=3.12. 01:45 02:15 0.50 2,408 2,408 SURFA( CEMEN-CIRC P Circulate and condition mud for FIT/LOT, pump @ 515 GPM=1500 PSI,40 RPM w/1K Tq, P/U=93K, S/O=96K, ROT=97K. 02:15 02:30 0.25 2,408 2,316 SURFAC CEMEN-RURD P Stand back one stand of drill pipe and rig up for FIT/LOT. 02:30 03:15 0.75 2,316 2,316 SURFA( CEMEN-LOT P Perform FIT/LOT,pumped @ 7 spm, once pressure reached 600 PSI dropped straight off to 200 PSI. Shut down and look for leak on surface equipment. No leaks found. Pressure back up pumping @ 7 spm and started injecting mud @ 310 PSI, pumped.6 bbl after leak off and held for 10 min., pressure leaked off to 120 psi. Pressure test all surface lines,good. LOT= 12.2 ppg EWM Page 12 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:30 0.25 2,316 2,316 SURFA( CEMEN-PRTS P Pressure test all surface lines to ensure results of LOT are accurate, good test. 03:30 04:00 0.50 2,316 2,316 PROD1 CEMEN"CIRC T Circulate and condition mud @ 125 GPM-225 PSI,wait on orders from town. 04:00 04:30 0.50 2,316 2,316 PROD1 CEMEN"CIRC T Obtain slow pump rates and rig down testing equipment. 04:30 05:15 0.75 2,316 2,316 PROD1 CEMEN-CIRCT Circulate and condition mud to POOH, add Bicarb and Citric to mud. Pump @ 515 GPM= 1500 PSI,40 RPM w/1K Tq. 05:15 05:45 0.50 2,316 2,316 PROD1 CEMEN"OWFF T Monitor well,static. Blow down top drive. 05:45 06:15 0.50 2,316 600 PROD1 CEMEN"TRIP T POOH to 600'.Actual displacement= 17.04 bbls, Calculated displacement=14.82 bbls. 06:15 06:45 0.50 600 220 PROD1 CEMEN"TRIP T Stand back 3 stands of HWDP and jars. 06:45 07:00 0.25 220 155 PROD1 CEMEN"OWFF T Stand back 1 stand HWDP and flex collars. BHA actual displacement= 13.41 bbls, 14.96 bbls. 07:00 07:15 0.25 155 155 PROD1 CEMEN"SFTY T Hold PJSM on removing sources. 07:15 07:45 0.50 155 155 PROD1 CEMEN"PULD T Remove sources and send down beaver slide. 07:45 09:00 1.25 155 155 PROD1 CEMEN-PULD T Download MWD tools as per Halliburton rep. 09:00 09:30 0.50 155 0 PROD1 CEMEN-PULD T Stand back MWD in derrick. Lay down stab, motor and bit as per Halliburton rep. 09:30 10:15 0.75 0 0 PROD1 CEMEN-OWFF T Monitor well,static. Clean and clear rig floor. 10:15 10:45 0.50 0 0 PROD1 CEMEN"SVRG T Service rig. 10:45 13:30 2.75 0 0 PROD1 CEMEN"OTHR T Mobilize 3-1/2"L-80 EUE tubing to rig for cement job. Mix black water pill for cement job. 13:30 15:00 1.50 0 0 PROD1 CEMEN"PULD T Load pipe shed with 3-1/2"EUE tubing,drift and tally. 15:00 15:45 0.75 0 0 PROD1 CEMEN"RURD T Pick up tongs from beaver slide and rig up to RIH w/3-1/2"tbg. 15:45 16:45 1.00 0 471 PROD1 CEMEN"PUTB T PJSM,pick up mule she and 15 joints of 3-1/2"L-80 EUE tbg. 16:45 17:15 0.50 471 471 PROD1 CEMEN"RURD T Make to XO and C/O elevators. 17:15 18:15 1.00 471 2,408 PROD1 CEMEN-TRIPT RIH with 5"drill pipe f/471'to 2408'. Tag up and set down 3K. P/U=71K, S/O=73K.Actual displacement= 16.4 bbls,Calculated displacement= 16.2 bbls. 18:15 18:45 0.50 2,403 2,403 PROD1 CEMEN-PULD T Lay down 1 single and pick up 10' pup joint. 18:45 19:45 1.00 2,403 2,403 PROD1 CEMEN-DISP T PJSM, Displaced mud to a sacrificial mud system to perform cement job. Displaced to a 9.8 ppg powervis/bar mud system. Pumped @ 5 BPM=200 PSI. Page 13 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 2,403 2,403 PROD1 CEMEN"COND T Top wash pit#5 and load with mud of Vac truck. 20:45 21:00 0.25 2,403 2,403 PROD1 CEMEN-SFTY T Hold PJSM on cementing. 21:00 22:15 1.25 2,403 2,403 PROD1 CEMEN-CMNT T SLB pump 5 bbls of water through bleeder and shut in. Pressure test lines to 600/3500 PSI. Pump 15 bbls of 12.0 ppg MudPush II, 15 bbls of 15.7 ppg AS1 cement and 4.2 bbls of 12.0 ppg MudPush II. Displaced with .rig pumps for 298 strokes. 22:15 22:30 0.25 2,403 2,046 PROD1 CEMEN-TRIP T L/D 10'pup joint and pick up single. POOH to 2046'. 22:30 23:00 0.50 2,046 2,046 PROD1 CEMEN-CIRC T Drop nerf wiper ball and circulate surface to surface @ 6 BPM=250 .PSI 23:00 00:00 1.00 2,046 2,046 PROD1 CEMEN"SQEZ T Close pipe rams and perform hesitation squeeze as follows. Pump @ 10 spm, pressure built to 550 psi then broke over, injected 3 bbls @ 300 PSI, shut well in for 10 minutes. Pressure dropped from 300 PSI to 200 PSI. Pumped 1.5 bbls, pressure broke over @ 450 PSI and injected @ 350 PSI. Shut well in for 10 minutes, pressure dropped from 300 PSI to 225 PSI. Pumped.3 bbls, pressured up to 600 PSI.Shut well in for 10 minutes. Pressure drop from 600 PSI to 500 PSI.Attempted to pump,well pressured up to 600 PSI before stroke counter would read any strokes. Shut well in for 10 minutes. Pressure dropped from 600 PSI to 550 PSI. Squeezed a total of 4.8 bbls of cement. 03/10/2013 RIH w/clean out BHA to 2136',wash down to 2319'.CBU,cont to wash and ream down to 2367'. Set down 10K on cement,wash and ream down to 2408'and drill 10'of new hole to 2418'.CBU and perform FIT to 14.3 ppg EMW. POOH and L/D clean out BHA. Make up 8-1/2"drilling BHA. RIH and swap mud system to 9.8 ppg KlaShield mud. Drill ahead f/2418'to 2919'TVD=2913'. ROP @ 125 FPH. ECD=10.92 ppg. 00:00 00:15 0.25 2,046 2,046 SURF/NC CEMEN-OWFF T Monitor well,static.SIMOPS, rig down cement line. 00:15 01:00 0.75 2,046 450 PROD1 CEMEN"TRIP T POOH f/2046'to 450'.Actual displacement=15.05 bbls, Calculated displacement= 14.84 bbls. 01:00 01:15 0.25 450 450 PROD1 CEMEN"RURD T Change over to 3-1/2"handling tools. 01:15 02:00 0.75 450 0 PROD1 CEMEN-PULD T Lay down 15 joints of 3-1/2"EUE tbg. 02:00 03:00 1.00 0 0 PROD1 CEMEN-OTHR P Day light savings time change. 03:00 03:45 0.75 0 376 PROD1 CEMEN-PULD T PJSM, make up clean out BHA as per Halliburton rep. 03:45 04:30 0.75 376 2,136 PROD1 CEMEN-TRIPT RIH with clean out BHA to 2136'. Actual displacement=23.1 bbls, Calculated displacement=22.96 bbls. Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:301 04:45 0.25 2,136 2,319 PROD1 CEMEN'WASH T Wash and ream f/2136'to 2319'. Pump @ 515 GPM=850 PSI,40 RPM w/1 K Tq. 04:45 05:30 0.75 2,319 2,319 PROD1 CEMEN-CIRC T CBU, pump @ 525 GPM=875 PSI, 60%flow,40 RPM w/1K Tq. 05:30 05:45 0.25 2,319 2,367 PROD1 CEMEN'WASH T Wash down f/2319'to 2367'. Pump @ 450 GPM=800 PSI,40 RPM. Turn off rotary and slow pump to 150 GPM,set down 10K on cement. 05:45 06:00 0.25 2,367 2,408 PROD1 CEMEN'WASH T Wash and ream f/2367'to 2408'. Pump @ 515 GPM=850 PSI,40 RPM w/1 KTq. 06:00 07:15 1.25 2,408 2,418 PROD1 CEMEN'DRLG T Drill 10'of new hole for FIT. Drill f/ 2408'to 2418'. Pump @ 550 GPM=1250 PSI,62%flow, 80 RPM w/2 K Tq. P/U=85K,S/O=86K, ROT=84K. 07:15 07:45 0.50 2,418 2,312 PROD1 CEMEN'CIRC T Stand back one stand and CBU for FIT. 07:45 08:00 0.25 2,312 2,312 PROD1 CEMEN'RURD T Rig up for FIT and blow down top drive. 08:00 08:15 0.25 2,312 2,312 PROD1 CEMEN'LOT T Perfrom FIT to 14.3 ppg EMW,good FIT. 08:15 08:30 0.25 2,312 2,312 PROD1 DRILL OWFF T Monitor well,static. Rig down FIT equipment. 08:30 09:15 0.75 2,312 376 PROD1 DRILL TRIP T POOH f/2313'to 376'.Actual displacement=23.1 bbls,Calculated displacement=23.74 bbls. 09:15 09:45 0.50 376 0 PROD1 DRILL PULD T Stand back 4 stands HWDP and jars. L/D clean out BHA as per Halliburton rep. 09:45 10:00 0.25 0 0 PROD1 DRILL PULD T Clean and clear rig floor. 10:00 10:15 0.25 0 0 PROD1 DRILL SFTY T Hold PJSM on making up 8-1/2" drilling BHA. 10:15 12:45 2.50 0 225 PROD1 DRILL PULD T Make up BHA#5 as per Halliburton rep. ✓ 12:45 14:00 1.25 225 225 PROD1 DRILL DHEQ T Plug into MWD tools and upload. 14:00 14:45 0.75 225 225 PROD1 DRILL PULD T PJSM, load sources into MWD tools. 14:45 15:00 0.25 225 600 PROD1 DRILL PULD T Cont to pick up BHA. 15:00 15:30 0.50 600 600 PROD1 DRILL DHEQ T Shallow hole test tools,good. 15:30 16:00 0.50 600 2,360 PROD1 DRILL TRIP T RIH f/600'to 2360'.Actual displacement=29.21 bbls, Calculated displacement=28.3 bbls. 16:00 16:15 0.25 2,360 2,388 PROD1 DRILL WASH T Wash down f/2360'to 2388'pump @ 500 GPM= 1050 PSI. 16:15 16:30 0.25 2,388 2,418 PROD1 DRILL SRVY P Log well f/2388'to 2418'. 16:30 17:00 0.50 2,418 2,418 PROD1 DRILL DISP P PJSM, Displace well to 9.8 ppg KLASHIELD mud system. Page 15 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 2,418 2,915 PROD1 DRILL DRLG P Drill ahead,drilled f/2418'to 2915' , TVD=2913'.ART=3.81,AST= .67, ADT=4.48,Total jars hrs=5.36, Total bit hrs=4.48, Pump @ 650 GPM=1900 PSI flow 73%,70 RPM w/1-3K Tq, 1 K off. ECD=10.92 ppg EMW. P/U=105K,S/O= 106K, ROT=105K. 03/11/2013 Drilled ahead f/2915'to 4447'.TVD=4441'.ADT= 16.64 hrs.Avg ROP=120 FPH, ECD=11.0 ppg 00:00 06:00 6.00 2,915 3,378 PROD1 DRILL DRLG P Drilling f/2915'to 3378'.TVD=3374', ART=4.26,AST=0,ADT=4.26,Jar hrs=9.62, Bit hrs=8.74. P/U=115K, SIO= 115K, ROT= 119K.Tq on=2K, off= 1K, Pump @ 625 GPM=1975 PSI w/80%flow. ECD= 10.97 ppg WOB=2-5K, 80 RPM,Holding ROP to 125 FPH. 06:00 12:00 6.00 3,378 3,716 PROD1 DRILL DRLG P Drilling f/3378 to 3716'.TVD=3710', ART=3.66,AST=.3,ADT=3.96,Jar hrs= 16.82 Bit hrs= 15.82. P/U=120K,SIO=120K, ROT= 123K. Tq on=2K,off= 1K, Pump @ 625 GPM=2050 PSI w/80%flow. ECD= 11.07 ppg WOB=2-5K, 80 RPM, Holding ROP to 125 FPH. 12:00 18:00 6.00 3,716 4,119 PROD1 DRILL DRLG P Drilling f/3716'to 4119'.TVD=4113'. ART=4.07,AST= .48,ADT=4.65, Jars hrs=20.47, Bit hrs=20.47. P/U= 127K,S/O=127K, ROT= 129K.Tq on=1-3K, off= 1K. ECD= 11.07 ppg. Pump @ 635 GPM=2125 PSI w/78%flow.WOB=3-7K, hold ROP @ 125 FPH. 18:00 00:00 6.00 4,119 4,447 PROD1 DRILL DDRL P Drilling f/4119'to 4447'.TVD=4441'. ART=3.42,AST=.35,ADT=3.77, Jars hrs=25.24, Bit hrs=24.24. ✓ P/U= 133K,S/O= 133K, ROT= 136K.Tq on=2-4K,off= 1K. ECD= 10.91 ppg. Pump @ 644 GPM= 2250PSI w/78%flow.WOB=3-10K, hold ROP @ 125 FPH. 03/12/2013 Drilled ahead f/4447'to 5045',TVD=5036'. Circulate HiVis sweep around and OWFF.Make wiper trip to 2361', no tight hole. RIH t/4955,wash last stand to bottom. Drilled f/5408'. TVD=5401'.ADT= 11.23 00:00 06:00 6.00 4,447 4,789 PROD1 DRILL DRLG P Drilling f/4447'to 4795'.TVD=4789'. ART=4.31,AST=0,ADT=4.31,Jar hrs=29.55, Bit hrs=28.55. P/U= 140K,S/O=139K, ROT=141K,80 RPM,Tq on=5-8K,off= 1K. Pump @ 640 GPM=2350 PSI, 78%flow, WOB=5-8K. Page 16 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:30 3.50 4,789 5,045 PROD1 DRILL DRLG P Drilling f/4795'to 5045'.TVD=5036'. ART=2.71,AST=.15,ADT=2.86, Jar hrs=32.41, Bit hrs=31.41. P/U= 144K,S/O=144K, ROT=148K.80 RPMs,Tq on=1-3K,off= 1K, Pump @ 635 GPM=2350 PSI,78%flow, ECD= 10.96,WOB=5-7K. 09:30 10:15 0.75 5,045 5,045 PROD1 DRILL CIRC P Pump HiVis sweep around and circulate until hole cleaned up. Pump @ 640 GPM=2200 PSI,78%flow, 80 RPM w/1.5K. 10:15 10:30 0.25 5,045 5,045 PROD1 DRILL OWFF P Monitor well, static. 10:30 12:15 1.75 5,045 2,361 PROD1 DRILL TRIP P POOH f/5045'to 2361'. Good trip, no tight hole observed.Actual displacement=17 bbls, Calculated displacement=15.6 bbls. 12:15 13:00 0.75 2,361 2,361 PROD1 DRILL CIRC P CBU @ 600 GPM=1675 PSI, blow down top drive. 13:00 13:15 0.25 2,361 2,361 PROD1 RIGMN1SFTY P Hold PJSM on slip and cut drilling line. Discussed hand safety and using proper PPE when handling drilling line. 13:15 14:30 1.25 2,361 2,361 PROD1 RIGMNT SLPC P Hang blocks,slip and cut 59'of drilling line. 14:30 15:15 0.75 2,361 2,361 PROD1 RIGMNT SVRG P Service rig. 15:15 17:30 2.25 2,361 4,955 PROD1 DRILL TRIP P PJSM, RIH f/2361'to 4955'.Good trip, no tight hole observed.Actual displacement=20.02 bbls, Calculated displacement=22.5 bbls. 17:30 17:45 0.25 4,955 5,045 PROD1 DRILL WASH P Wash and ream f/4955'to 5045', pump @ 630 GPM= 1700 PSI. 17:45 18:00 0.25 5,045 5,045 PROD1 DRILL CIRC P CBU @ 5048', pump @ 630 GPM= 1700 PSI. 18:00 00:00 6.00 5,045 5,408 PROD1 DRILL DRLG P Drilling f/5048'to 5408',TVD=5401'. ART=3.74,AST=.32,ADT=4.06, Jar hrs=39.59, Bit hrs=35.47, P/U= 150K,S/O=148K, ROT=151K,80 RPMs,Tq= 1-3K, off= 1K, Pump @ 641 GPM=2375 PSI,78%flow ECD=11.01 ppg,WOB 1-5K. 03/13/2013 Drilled ahead f/5408'to TD at 6520',6513 TVD. Circulate HV sweep, 3 BU and OWFF. Start making the wiper trip,at 5950'midnight, no tight hole observed. 00:00 06:00 6.00 5,408 5,692 PROD1 DRILL DRLG P Drill f/5408'to 5692'.TVD=5685' ART=4.88,AST=O,ADT=4.88,Jars hrs=44.47, Bit hrs=40.35. P/U= 156K,S/O= 155K, ROT=160 K. 80 RPMs Tq on=3K,off= 1.5K. Pump @ 642 GPM=2380 PSI, 75%flow, ECD= 10.67 ppg,WOB= 1-3K. Hold ROP @ 70 FPH to allow mud loggers to catch 10'samples. Page 17 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 5,692 5,950 PROD1 DRILL DRLG IP Drill f/5692'to 5950'.TVD=5943' ART=4.79,AST=0,ADT=4.79,Jars hrs=49.26, Bit hrs=45.14. P/U= 163K,S/O= 159K, ROT=163 K.80 RPMs Tq on=2-3K,off=1.5K. Pump @ 642 GPM=2380 PSI,72%flow, ECD=10.67 ppg,WOB=3-5K. Hold ROP @ 70 FPH to allow mud loggers to catch 10'samples. 12:00 18:00 6.00 5,950 6,342 PROD1 DRILL DRLG P Drill f/5950'U 6342',TVD=6335' ART=5.2,AST=0,ADT=5.2,Jars hrs=54.46, Bit hrs=50.34,. P/U=172k, S/O=167k, ROT=172k, TQ on=2-7k,2k off. 80 rpm, ECD 10.81 ppg @ 650 gpm/2625 psi, 71%flow.Vary ROP from 50-120 fph per geo/mudloggers. 18:00 21:00 3.00 6,342 6,520 PROD1 DRILL DRLG P Drill f/6342't/TD-6520'MD,6513' TVD.ART=2.23,AST=0,ADT=2.23. Jar hrs 56.69, Bit hrs 52.57. P/U=175k, 5/0= 172k, ROT= 174k. TQ on=2-7k,2k off.80 rpm, ECD 10.79 ppg @ 645 gpm/2625 psi, 72%flow.SPR's @ TD w/9.8 ppg. 21:00 22:15 1.25 6,520 6,520 PROD1 EVALWE CIRC P Pump high vis sweep,circulate 3 x BU @ 630 gpm,2475 psi. 22:15 22:30 0.25 6,520 6,520 PROD1 EVALWE OWFF P Monitor well-static 22:30 00:00 1.50 6,520 6,520 PROD1 EVALWE WPRT P POOH on elevators f/6520'MD t/ 5950',calc disp 7.8 bbl, actual 11.22 bbl. 03/14/2013 Complete wiper trip, perform MAD pass per plan. POOH on elevators, hole in good condition. Remove sources,download data and UD BHA. Begin testing BOPE to 250/3500 PSI,AOGCC rep John Crisp witnessed test. _ 00:00 01:00 1.00 5,950 2,361 PROD1 EVALFN WPRT P Held PJSM and POOH f/5950'to shoe @ 2361'MD. Hole fill good, calc 26.52,actual 31.96 bbl. V 01:00 01:15 0.25 2,361 2,361 PROD1 EVALFN OWFF P Monitor well at shoe for flow-Static 01:15 03:00 1.75 2,361 6,435 PROD1 EVALFN WPRT P RIH f/2361'MD to 6435'MD, Fill pipe every 20 stds. Calc displacement 34.32 bbl,actual 31.96 bbl 03:00 03:15 0.25 6,435 6,520 PROD1 EVALFN WPRT P Precautionary wash and ream f/ 6435'to 6520'@ 640 gpm,2425 psi, 73%flow,80 rpm&2k TQ. 03:15 04:30 1.25 6,520 6,520 PROD1 EVALFN CIRC P CBU x 3 @ 640 gpm,2425 psi,73% flow, 80 rpm&2k TQ. 04:30 04:45 0.25 6,520 6,437 PROD1 EVALFN OWFF P Rack one stand back, pull f/6520'to 6437'MD and monitor well,static. 04:45 05:00 0.25 6,437 6,220 PROD1 EVALFN TRIP P POOH f/6437'MD to 6220'MD 05:00 12:00 7.00 6,220 5,257 PROD1 EVALFN SRVY P Perform MAD pass @ 293 gpm,800 psi,60 RPM @ 1.5k TQ, 100-120 fpm,4 intervals.6220'-6087', 5864'-5717',5689'-5537',5394'-5257'. Page 18 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 5,257 2,352 PROD1 EVALFN TRIP P PJSM and POOH f/5257'to2352' MD @ 100 fpm/6000 fph,good hole fill. 14:00 14:15 0.25 2,352 2,352 PROD1 EVALFN OWFF P Monitor well at surface shoe,static, very slight drop. 14:15 15:00 0.75 2,352 600 PROD1 EVALFN TRIP P Continue POOH f/2352'to HWDP @ 600'. 15:00 15:15 0.25 600 600 PROD1 EVALFN OWFF P Monitor well at HWDP,static,very slight drop. 15:15 15:30 0.25 600 230 PROD1 EVALFN TRIP P Stand back HWDP and Jars in Derrick. 15:30 16:00 0.50 230 137 PROD1 EVALFN PULD P Held PJSM, laid down NM flex collars in pipe shed. 16:00 16:30 0.50 137 137 PROD1 EVALFN PULD P Held PJSM, removed sources. 16:30 18:30 2.00 64 64 PROD1 EVALFN PULD P Plug in and download tools 18:30 20:15 1.75 64 0 PROD1 EVALFN PULD P Continue L/D BHA Calc displacement 52.32 bbl, actual 56.8 bbl. 20:15 20:45 0.50 0 0 PROD1 EVALFN PULD P Clean and clear rig floor 20:45 21:45 1.00 0 0 PROD1 WHDBO BOPE P Drain stack,pull wear bushing. 21:45 22:15 0.50 0 0 PROD1 WHDBO SEQP P Set test plug and R/U to test BOPE 22:15 22:45 0.50 0 0 PROD1 WHDBO SFTY P PJSM on testing BOPE 22:45 00:00 1.25 0 0 PROD1 WHDBO BOPE P Test BOPE to 250/3500 PSI.Test #1:Top rams, kill line check valve, CV 1,12, 13 and 14.Test#2: Upper IBOP, HCR kill, CV 9 and 11. AOGCC inspection John Crisp witnessed test. 03/15/2013 Complete testing of BOPE,witness by AOGCC rep John Crisp. R/D test equip, PJSM and R/U Halliburton wireline. M/U RDT run tools and RIH. Commence RDT logging run. 00:00 02:30 2.50 0 0 PROD1 WHDBO BOPE P Continue testing BOPE t/250/3500 psi 5 min ea. Lower IBOP, Manual Kill,C.V.#5,#8,#10, Dart valve, ✓ C.V.#4,#6,#7. Floor valve, C.V.#2. HCR Choke, Manual choke valve, Annular preventer, Lower pipe rams, Blind rams,C.V#3.Accumulator test: System pressure=2900 psi, eoe pressure after closing all rams=1800 f,/� psi.Achieved 200 psi in 35 sec. Full �//� pressure achieved in 215 seconds. 5 bollte average 2050 psi. H2S sensor #5 failed, changed out rain head and recalibrated, re-tested OK.Testing witnessed by AOGCC John Crisp. 02:30 03:15 0.75 0 0 PROD1 WHDBO BOPE P Drain stack, R/D test equipment, blow down kill line,choke line and choke. Install wear bushing. 03:15 03:30 0.25 0 0 PROD1 EVALFN SFTY P PJSM on R/U wire 03:30 05:00 1.50 0 0 PROD1 EVALFN RURD P Load and prep Halliburton tools for P/U 05:00 06:45 1.75 0 0 PROD1 EVALFN RURD P R/U Halliburton wireline equipment Page 19 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 09:45 3.00 0 0 PROD1 EVALFN RURD P M/U Wireline tools as per Halliburton rep. 09:45 00:00 14.25 0 0 PROD1 EVALFN ELOG P RIH and wireline RDT log.Work on MP2's,tighten drag chain in mud pits. Load pipe shed with P-100 7" casing and work on cleaning threads and strapping. Send out Sperry tools. 03/16/2013 Complete RDT logging run, POOH and L/D tools. Send fluid samples to lab per geo.M/U 8.5"Cleanout assy and RIH to 6520'CBU and POOH. R/U and RIH w/HES E-Line HRSCT-A tools. Inspected P100 pipe OK. 00:00 12:00 12.00 PROD1 EVALFN ELOG P PJSM-Continue running E-line RDT log. Clean P-110 casing for inspection. 12:00 13:45 1.75 PROD1 EVALFN ELOG P PJSM-POOH and L/D logging tools. Recover samples for shipping per Geo. 13:45 14:15 0.50 PROD1 EVALFN PULD P Clean and clear rig floor. 14:15 18:30 4.25 0 6,300 PROD1 EVALFN TRIP P Pick up cleanout assy, bit,sub, float, HWDP and Jars. RIH to 6300' MD filling pipe every 20 stands. Actual displacement=53.81 bbls, Calculated displacement=58.78 bbls. 18:30 19:00 0.50 6,300 6,520 PROD1 EVALFN WASH P Wash and ream f/6300'to 6520'. Pump @ 620 GPM= 1600 PSI. 19:00 20:00 1.00 6,520 6,520 PROD1 EVALFN CIRC P CBU X 3, pump @ 610 GPM=1600 PSI,40 RPMs w/1.5K Tq. P/U=162K,S/O= 157K, ROT=151K. 20:00 20:15 0.25 6,520 6,520 PROD1 EVALFN OWFF P Monitor well,static. 20:15 20:45 0.50 6,520 6,028 PROD1 EVALFN TRIP P PJSM, POOH f/6520'to 6028'. Pump 12 bbl dry job @ 210 GPM= 500 PSI. 20:45 22:30 1.75 6,028 2,322 PROD1 EVALFN TRIP P POOH f/6028'to 2322'.Actual displacement=33.89 bbls, Calculated displacement=34.02 bbls. 22:30 23:00 0.50 2,322 2,322 PROD1 EVALFN CIRC P CBU @ 480 GPM=700 PSI. 23:00 23:30 0.50 2,322 2,322 PROD1 EVALFN OWFF P Monitor well,static. 23:30 00:00 0.50 2,322 PROD1 EVALFN TRIP P Blow down top drive. 03/17/2013 ✓ Cont. POOH w/clean out BHA. RIH on E-Line with HES HRSCT(side wall core)and Sonic/XRMI tools. 00:00 01:00 1.00 2,322 0 PROD1 EVALFN TRIP P PJSM,cont.to POOH f/2322'to surface.Actual displacement=24.4 bbls, Calculated displacement= 22.55 bbls. 01:00 01:30 0.50 0 0 PROD1 EVALFN OWFF P Clean and clear rig floor. Monitor well on trip tank, static. 01:30 02:45 1.25 0 0 PROD1 EVALFN RURD P PJSM, rig up HES E-Line and make up HRSCT tools. 02:45 17:00 14.25 0 0 PROD1 EVALFN ELOG P Logging with HRSCT(side wall core) tool.Cut 60 core samples. SIMOPS, swap out man rider winch and set to 300 lbs.Work on MP2's. Page 20 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 PROD1 EVALFN PULD P PJSM,lay down HRSCT tools and pipe shed. Prep Wave Sonic tools in shed. 18:00 19:00 1.00 0 0 PROD1 EVALFN ELOG P PJSM, pick up Sonic Wave/XRMI HES E-Line tools. 19:00 00:00 5.00 0 0 PROD1 EVALFN ELOG P RIH on E-Line with Sonic/XRMI tool. SIMOPS,clean under drawworks, inspect and clean brake bands and linkage. 03/18/2013 Logging w/Sonic/XRMI tools.C/O logging tools to MRIL/GEM/SGR tools. HES logging tool failure,trouble shoot and C/O tools. Log well w/MRIUGEM/SGR tools. R/D E-Line and M/U clean out BHA. RIH w/clean out BHA to 5936'. 00:00 03:00 3.00 0 0 PROD1 EVALFN ELOG P PJSM,cont logging on HES E-Line w/Sonic/XRMI tools. 03:00 04:45 1.75 0 0 PROD1 EVALFN PULD P PJSM, lay down Wave Sonic/XRMI logging tools. Remove sources. 04:45 05:15 0.50 0 0 PROD1 EVALFN PULD P PJSM,make up MRIUGEM/SGR. Logging run#4. 05:15 07:00 1.75 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line. E-Line had tools failure, POOH w/E-Line. 07:00 07:30 0.50 0 0 PROD1 EVALFN ELOG T Change out HES E-line capacitor. 07:30 08:00 0.50 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line,test capacitor. Capacitor failed test, POOH. 08:00 09:15 1.25 0 0 PROD1 EVALFN ELOG T Trouble shoot HES E-Line tools. 09:15 10:30 1.25 0 0 PROD1 EVALFN ELOG T RIH w/HES E-Line,test tools.Tools failed test,cont.to trouble shoot tools. No go, POOH w/HES E-Line. 10:30 13:00 2.50 0 0 PROD1 EVALFN ELOG T Trouble shoot E-Line head. Change out magnet and make up new MRIUGEM/SGR tools. 13:00 18:15 5.25 0 0 PROD1 EVALFN ELOG P RIH w/HES E-Line.Test tools,good. Log well w/MRIUGEM/SGR tools as per plan. 18:15 19:00 0.75 0 0 PROD1 EVALFN RURD P PJSM, L/D HES logging tools and rig down E-Line. 19:00 19:30 0.50 0 0 PROD1 EVALFN PULD P Clean and clear floor,prep to P/U BHA. 19:30 00:00 4.50 0 0 PROD1 EVALFN TRIP P PJSM, make up bit,bit sub,float HWDP and jars. RIH f/377'to 5936' filling pipe every 20 stands. P/U= 140K,S/O=142K.Actual displacement=51 bbls,Calculated displacement=52.48 bbls. 03/19/2013 / RIH with clean out BHA to 6520'MD, CBU X 3, BROOH to 6306'MD, Monitor well and POOH, UD BHA, Drain&flush stack,C/O ram to 7"and test same, R/U and run 7"casing to 2384'MD and CBU at shoe. 00:00 00:30 0.50 6,491 6,520 PROD1 EVALFN REAM P PJSM,Continue RIH T/6491'MD, P/U single wash&reasm T/6502' MD, 500 gpm, 1250 psi,40 RPM, TQ=3 K, Soft fill F/6510'T/6520', P/U= 157 K, S/O=146 K,Calc= 4.75 bbls,Actual=4.68 bbls. 00:30 02:15 1.75 6,520 6,520 PROD1 EVALFN CIRC P CBU X 3,with 610 gpm, 1625 psi,40 RPM,TQ=2.5 K. Page 21 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 04:00 1.75 6,520 6,306 PROD1 EVALFN REAM P BROOH, rack back stand every hr with 310 gpm,650 psi,40 RPM,TQ= 2.5 K to 6306'MD. 04:00 08:45 4.75 6,306 0 IPROD1 CASING TRIP P PJSM, Monitor well,install rubber and POOH on elevators, Monitor well at shoe and hwtdp, UD BHA, Calc= 56.6 bbls,Actual=62.2 bbls. 08:45 09:30 0.75 0 0 PROD1 CASING OWFF P Monitor well while clearing and cleaning rig floor. (Static) 09:30 10:30 1.00 0 0 PROD1 CASING OTHR P PJSM, Drain&flush stack, Pull wear ring. 10:30 12:00 1.50 0 0 PROD1 CASING OTHR P PJSM,Change out top set of rams to 7" 12:00 13:15 1.25 0 0 PROD1 CASING OTHR P Continue changing out rams to 7". 13:15 14:00 0.75 0 0 PROD1 CASING OTHR P PJSM, R/U and test 7"rams to 250/ 3500 psi for 10 min and chart same. 14:00 14:15 0.25 0 0 PROD1 CASING OTHR P Rig down test equipment. 14:15 17:30 3.25 0 0 PROD1 CASING RNCS P PJSM, Rig up to run 7"casing 17:30 22:45 5.25 0 2,384 PROD1 CASING RNCS P PJSM, Run 7"casing, baker lock, Float shoe, Float collar,test floats, install Bow spring centralizers on first three joints with stop rings&one centralizer every other joint to Joint 36,fill every 10 joints to 2384' 22:45 00:00 1.25 2,384 2,384 PROD1 CASING CIRC P CBU @ 2384'MD @ shoe with 4 bpm=400 psi, P/U=98 K, S/0=78 K, Calc=24.6 bbls,Actual=20.95 bbls. 03/20/2013 Finished running 7"casing,Circ&cond mud for cement,Cement as per program and bumped plug, CIP @ 15:40 hrs, UD casing tools, Install 7"packoff and test same to 5000 psi, C/O rams and test doors. 00:00 01:30 1.50 2,384 3,369 PROD1 CASING RNCS P RIH with 7"casing F/2378'T/3369' MD, P/U= 115 K,S/0=92 K. 01:30 02:15 0.75 3,369 3,369 PROD1 CASING CIRC P CBU @ 3369'MD,2.5 bpm with 500 psi. 02:15 03:30 1.25 3,369 4,316 PROD1 CASING RNCS P RIH with 7"casing F/3369'T/4316' MD, P/U= 140 K, S/0= 120 K. 03:30 04:15 0.75 4,316 4,316 PROD1 CASING CIRC P CBU @ 4316'MD, 3 bpm with 625 psi. 04:15 05:30 1.25 4,316 5,390 PROD1 CASING RNCS P RIH with 7"casing F/4316'T/5390' MD. P/U= 170 K, S/0= 145 K. 05:30 06:30 1.00 5,390 5,390 PROD1 CASING CIRC P CBU @ 5390'MD, 3 bpm with 650 psi. 06:30 07:45 1.25 5,390 6,415 PROD1 CASING RNCS P RIH F/5390'T/6415'MD,M/U 5'pup &14.65'pup, M/U one full joint, Calc=40.3 bbls,Actual=35.7 bbls. 07:45 08:45 1.00 6,415 6,507 PROD1 CASING RNCS P M/U hanger with landing joint. Brk circ andf land hanger and shoe @ 6507'MD. 08:45 09:45 1.00 6,507 6,507 PROD1 CASING CIRC P CBU with franks fill up tool, 3 bpm with 500 psi. 09:45 10:30 0.75 6,507 6,507 PROD1 CASING OTHR P L/D Franks tool, Blow down Top Drive and M/U cement head. 10:30 12:00 1.50 6,507 6,507 PROD1 CEMEN-CIRC P Circ and cond mud,4 bpm with 625 I psi. Page 22 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:45 1.75 6,507 6,507 PROD1 CEMEN-CIRC P Cont.circ and cond mud, P/U= 195 K, SIO= 165 K. 13:45 14:00 0.25 6,507 6,507 PROD1 CEMEN'SFTY P PJSM for cement job. 14:00 15:45 1.75 6,507 6,507 PROD1 CEMEN-CMNT P Shut down pumps, line up to SLB, pump 5 bbls CW 100,test lines to ,i 3500 psi, bleed off&pump 20 bbls 1 CW 100,shut down and blend mud Ci push,pump 40 bbls of 11.5 ppg mud *GNI push,drop drop btm plug with 52.2 bbls of 15.8 ppg cement,dropdrop P 9 topplug with 20 bbls of water,shut down and swap over to rigand displace with 223 bbls 9.6 ppg mud at 6 bpm with 200 psi, land hanger, FCP=900 psi, bumped plug @ 2229 stks, pressured up to 1700 psi for 5 ill mins, bleed off and check floats, good. 15:45 17:30 1.75 0 0 PROD1 CEMEN-OTHR P R/D casing equipment and L/D landing joint. 17:30 19:30 2.00 0 0 PROD1 CEMEN-OTHR P Install pack off and run in lock downs. 19:30 20:15 0.75 0 0 PROD1 CEMEN-OTHR P test pack off to 250/5000 psi for 5 mins each. 20:15 21:45 1.50 0 0 PROD1 CEMEN-OTHR P PJSM,Change out rams F/7"T/ 3.5"X 6.00"VBRs 21:45 22:15 0.50 0 0 PROD1 CEMEN-OTHR P PJSM, Held table top drill, R/U to freeze protect well. 22:15 23:00 0.75 0 0 PROD1 CEMEN-BOPE P PJSM, R/U to test top rams with 4" test joint. 23:00 00:00 1.00 0 0 PROD1 CEMEN'BOPE P Test Top Rams to 250/3500 psi and chart same for 10 mins. Page 23 of 23 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: CASSIN 1 Rig Name: DOYON 141 Job Type: INITIAL COMPLETION Rig Accept: 3/21/2013 12:01:00 AM Rig Release: 3/28/2013 12:00:00 AM Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 03/21/2013 24 hr Summary L/D test 4"joint&R/D test equipment, R/U and perform LOT on OA, Flush with 75 bbls water followed by 70 bbls of diesel, R/U and lay down 5"dp from derrick,slip&cut drlg line,C/O saver subs, Load shed with 4"dp and strap same, M/U clean out BHA and RIH with picking up 4"dp. 00:00 00:15 0.25 0 0 COMPZ CEMEN"BOPE P R/D test equipment,drain stack, L/D test joint. 00:15 00:45 0.50 0 0 COMPZ CEMEN"LOT P R/U and perform LOT on OA,(9-5/8 X 7) 00:45 02:00 1.25 0 0 COMPZ CEMEN"OTHR P Flush OA with 75 bbls of water @ 2 bpm with 275 psi, FCP=350 psi. 02:00 03:00 1.00 0 0 COMPZ CEMEN"FRZP P PJSM, R/U Little Red and test lines to 2000 psi, pump 75 bbls diesel for freeze protection do 9-5/8"X 7", ICP=800 psi, FCP=400 psi at 2 bpm. 03:00 09:00 6.00 0 0 COMPZ CEMEN"PULD P PJSM, L/D 5"dp via mouse hole. 09:00 09:30 0.50 0 0 COMPZ CEMEN-OTHR P Set 6-3/4"ID wear bushing and L/D mouse hole. 09:30 11:00 1.50 0 0 COMPZ CEMEN"SLPC P PJSM, Slip and cut drilling line, service Top Drive and drawworks. 11:00 12:00 1.00 0 0 COMPZ CEMEN-OTHR P Change Top Drive over to 4"saver sub 12:00 14:00 2.00 0 0 COMPZ CEMEN"OTHR P PJSM,CIO saver sub bell guide and grabber dies. 14:00 17:15 3.25 0 0 COMPZ CEMEN-OTHR P Load shed with 207 joint of 4'dp, strap same load BHA,while continue cleaning pits. 17:15 00:00 6.75 0 5,264 COMPZ CEMEN"TRIP P PJSM,M/U clean out BHA,single in the hole with 4"dp to 5043'Rotate and ream x 3 with 80 RPM,Tq= 1.5 K, P/U=103 K, S/0= 101 K. Continue single in F/5043'T/5264' Calc=29.5 bbls,Actual=29.0 bbls. 03/22/2013 Clean out at each perf and packer interval while RIH,drlg stringer&cement down to 6419'MD, CBU, R/U and test 7"casing to 3500 psi, Good, Blow down lines and continue cleaning pits for filtered brine swap, Flush all lines and equipment out,clean pits again, Mix spacers and pump, reverse out Pickle fluid with 300 bbls water. 00:00 02:30 2.50 5,264 6,335 COMPZ CEMEN"COCF P PJSM, RIH and clean up perf& packer depths by Recip&Rot X 3 at each interval @ 5268',-5273', 5322', 5535-5550', 5599',5710'-5725', RIH to 6335'MD, P/U=120 K,SIO= 115 K. 02:30 03:30 1.00 6,335 6,419 COMPZ CEMEN"COCF P Drlg cement stringers and cement F/ 6335' T/6419'MD,with 6 bpm, 1000 psi,40 RPM,WOB=3-10 K,Tq= 1.5 K. Page 1 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 6,419 6,419 COMPZ CEMEN'CIRC P CBU @ 6419'MD 6 bpm, 1000 psi, 40 rpm,Tq= 1.5 K. 04:00 05:00 1.00 6,419 6,419 COMPZ CEMEN'PRTS P R/U and test 7"casing to 3500 psi, record on chart for 30 min(Good) 05:00 05:30 0.50 6,419 6,419 COMPZ WELLPF PRTS P R/D Test equipment and Blow down lines. 05:30 11:00 5.50 6,419 6,419 COMPZ WELLPF OTHR P Continue cleaning mud pits,C/O 4" gate valve on#2 mud pump. 11:00 12:00 1.00 6,419 6,419 COMPZ WELLPF OTHR P Take on 150 bbls water in pit 6 to mix cleaning pill. 12:00 15:45 3.75 6,419 6,419 COMPZ WELLPF OTHR P PJSM, Continue mixing cleaning pill, flush all pit lines, manifolds, mud cleaning equipment, pumps,and kill line. 15:45 21:30 5.75 6,419 6,419 COMPZ WELLPF OTHR P Re-clean pits, build 35 bbl Hi Vis spacer in pill pit, move to pit#4 and build#2 25 bbl Hi-Vis spacer. 21:30 22:00 0.50 6,419 6,419 COMPZ WELLPF SFTY P PJSM,on displacement of brine with all involved, (Crew and truck drivers) 22:00 00:00 2.00 6,419 6,419 COMPZ WELLPF CIRC P Displace well as per-MI procedure, pumped 25 hi-vis sweep followed by deepclean,69 bbls water, line up and reverse 250 of 300 bbls of water, P/U= 105 K,SIO=105 k,200 gpm with 500 psi. 03/23/2013 Build 100 bbl hi-vis spacer and wait on brine truck from Alpine, pump phase two as per-MI plan,shut down and clean under shakers, NTUs=22.7, POOH and L/D BHA, R/U and test BOPE, R/D same, install wear ring. Nipple up shooting flange on stack. 00:00 04:00 4.00 6,419 6,419 COMPZ WELLPF OTHR P PJSM, Build 100 bbls of spacer wash in pit#5,wait on brine truck from Alpine, clear rig floor of unecessary tools. 04:00 07:15 3.25 6,419 6,419 COMPZ WELLPF CIRC P PJSM, Pump Phase 2 displacement, displace well per-plan @ 5 bpm with 450 psi while reciprocating&rotating string. P/U=115 K, S/O= 112 K, 80 RPM,Tq=2.7 K. 07:15 09:15 2.00 6,419 6,419 COMPZ WELLPF OTHR P Shut down pumps,clean under shakers&troughs, pump adittional 38 bbls and check NTUs=22.7 with 9.0 ppg brine. 09:15 12:00 2.75 6,419 705 COMPZ WELLPF TRIP P PJSM, L/D 2 joints dp, POOH T/ 705, P/U= 115 K,S/O= 112 K, Calc=32.4 bbls,Actual=34.4 bbls. 12:00 12:15 0.25 705 705 COMPZ WELLPF SFTY P PJSM,on POOH&L/D BHA. 12:15 12:30 0.25 705 0 COMPZ WELLPF PULD P POOH&L/D BHA 12:30 12:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM on R/U BOP testing equipment. 12:45 14:00 1.25 0 0 COMPZ WELLPF BOPE P R/U testing equipment for BOP test. 14:00 14:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM,testing BOPE. Page 2 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 21:15 7.00 0 0 COMPZ WELLPF BOPE P Test with 4"test joint.Test#1=Top Rams,Valves 1, '12, 13, 14 and manual kill.Test#2=Upper IBOP, HCR kill,valves 9,11 and 3.Test# 3=Lower IBOP,valves 5,8, and 10, kill line check valve.Test#4=Dart valve,valves 4,6,7 and 5.Test#5= Floor valves,valves 2 and 6.Test# 6= HCR choke.Test#7=Manual choke, HCR kill,valve 8.Test#8= Annular.Test#9=Lower pip rams. Test#10=Blind rams.valve 3. System pressure 3000 psi, pressure after closing 1700 psi,200 psi attained=52 sec, Full pressure attained 206 sec. Nitrogen avg. 1975 psi.Test with 3.5"test joint, upper rams,lower rams,and annular preventer.(State Rep.Chuck Scheve waived witness of test) 21:15 22:00 0.75 0 0 COMPZ WELLPF BOPE P PJSM, R/D test equipment,set wear ring, blow down lines. 22:00 22:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on N/U shooting flange 22:15 00:00 1.75 0 0 COMPZ WELLPF OTHR P N/D riser&riser adapter, Prep API ring goove for shooting flange. 03/24/2013 Finished N/U of shooting flange, PJSM, R/U wire line, PT riser&lubricator to 2000 psi, Run CBL, L/D logging tools, replace riser with lubricator and retest to 2500 psi,Made three runs,all on depth and all shots fired, POOH and R/D E-line, N/U down shooting flange and N/U riser and flowline. PJSM and P/U clean out BHA. 00:00 01:00 1.00 0 0 COMPZ WELLPF OTHR P PJSM,Continue N/U shooting flange. 01:00 02:30 1.50 0 0 COMPZ PERF ELOG P PJSM, R/U wire line and P/U tools. 02:30 03:30 1.00 0 0 COMPZ PERF ELOG P M/U wire line tools,(Cast) 03:30 04:15 0.75 0 0 COMPZ PERF ELOG P Pressure test shooting flange, lubricator head to 2000 psi and record on chart. 04:15 08:30 4.25 0 6,419 COMPZ PERF ELOG P RIH with CBL tool and log run, J CW POOH. 08:30 09:30 1.00 0 0 COMPZ PERF ELOG P PJSM, L/D CBL tools. 09:30 11:00 1.50 0 0 COMPZ PERF PERF P PJSM, Replace 7'riser with 5" lubricator on BOP stack. 11:00 12:00 1.00 0 0 COMPZ PERF PERF P PJSM, load guns into pipe shed. 12:00 13:15 1.25 0 0 COMPZ PERF PERF P PJSM, M/U perf gun run#1, pressure test lubricator to 2500 psi and chart for 10 min. Pi"( 13:15 14:30 1.25 0 5,725 COMPZ PERF PERF P RIH with pert guns run#1 @ 5710'- 5725'and fire guns, No pressure, gain or loss observed. 14:30 15:30 1.00 0 0 COMPZ PERF PERF P R/D spend.guns and M/U run#2 Pressure test lubricator to 2500 for 5 min. 15:30 16:45 1.25 0 5,535 COMPZ PERF PERF P RIH with pert gun run#2, Fire guns on depth @ 5535' 6550', POOH, No pressure,gain or loss observed. Page 3 of 8 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 16:45 17:30 0.75 0 0 COMPZ PERF PERF P R/D spentt_ uns,_M/U_run#3, __ pressure test lubricator to 2500 psi for 5 min. 17:30 18:45 1.25 0 5,273 COMPZ PERF PERF P RIH with pert gun run#3, Fire guns on depth @ 5258'-5273', POOH, No pressure,gain or loss observed.All shots fired. 18:45 19:00 0.25 0 COMPZ PERF SFTY P PJSM, Rigging down e-line. 19:00 20:00 1.00 0 0 COMPZ PERF PERF P Rig down E-line 20:00 20:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on N/D shooting flange and N/U riser. 20:15 22:30 2.25 0 0 COMPZ WELLPF OTHR P N/D shooting flange, N/U riser adapter and riser,clear floor strap tools and B/D kill line. 22:30 22:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM,on HRC M/U BHA 22:45 00:00 1.25 0 0 COMPZ WELLPF PULD P M/U De-burring BHA run 03/25/2013 M/U cleanout BHA and complete de-burring run.CBUX2 clean brine in well. M/U lower completion per Completion eng and service reps. Run in on 4"DP,correlate with Eline. 00:00 00:45 0.75 0 COMPZ WELLPF PULD P PJSM-Continue picking up De-Burring cleanout assy. 00:45 03:15 2.50 0 5,207 COMPZ WELLPF TRIP P RIH t/1214'MD, P/U Well Patroller, continue RIH t'5207'MD on 4"DP. P/U=105k, S/0=105k, Calc bbl =35.4,Actual bbl=35.4. 03:15 06:15 3.00 5,207 5,865 COMPZ WELLPF CIRC P Break circ @ 5207'Establish Circ and Rot parameters,2 bpm 100 psi, 80 RPM,TQ 2-3k, Polish f/ 5207-5742'MD. Ream thru perfs 5265-5273',5535-5550', 5710-5725' 3 X up and down.Continue ream t15865'. Rot wt. 108k, P/U=112k, S/O=112k. 06:15 06:45 0.50 5,865 5,207 COMPZ WELLPF OWFF P Monitor well, POOH U 5207'MD. P/U-112k, S/O-112k.Calc bbl=3.8, Actual bbl=4.1. 06:45 07:45 1.00 5,207 5,207 COMPZ WELLPF CIRC P CBU X 2 @ 5207'MD,5 bpm @ 510 psi. 07:45 08:15 0.50 5,207 5,207 COMPZ WELLPF OWFF P B/D Top Drive, Monitor well(Static), Drop 2"OD Rabbit on wire. 08:15 12:00 3.75 5,207 0 COMPZ WELLPF TRIP P PJSM-POOH UD BHA.Actual bbl=37.6,Calc bbl=35.4 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM-Clean and clear rig floor. R/U Tubing equipment. 12:15 13:15 1.00 0 0 COMPZ RPCOM RURD P R/U 3-1/2"Tools and equipment, mob tools to the rig floor. 13:15 15:45 2.50 0 714 COMPZ RPCOM RCST P M/U 3-1/2"Lower completion assy per Baker, SLB and Completion Engineer. 15:45 16:00 0.25 714 714 COMPZ RPCOM SFTY P PJSM-Tripping in with Completion assy. 16:00 20:00 4.00 714 5,718 COMPZ RPCOM TRIP P RIH w/4"DP to 5715', P/U=107k, S/0=106k Calc bbl= ,Actual bbl= 20:00 20:30 0.50 5,718 5,718 COMPZ RPCOM CIRC P Circulate 70 bbls,(Pipe Volume)at 3 bpm with 300 psi. Page 4 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 5,718 5,718 COMPZ RPCOM SFTY P PJSM R/U Halliburton Eline, RA/CCL 21:00 23:15 2.25 5,718 5,718 COMPZ RPCOM ELOG P R/U HES E-Line, PT lubricator to 2500 psi for 10 min. 23:15 00:00 0.75 5,718 5,718 COMPZ RPCOM ELOG P RIH with GR/CCL logging tool and correlate setting depth. 03/26/2013 Finish correlation and put packers on depth, R/D e-line, drop 1"ball&test lines to 4000 psi, Ball did not seat, dropped 1.5"ball and did not seat,Call out HES slick line, R/U and test lubricator to 3500 psi, RIH with LIB, discuss with town to run Ball&Rod on slick line,worked ball&rod through upper frac sleeve and chased ball on seat, Pressured up to 3500 psi with packer on depth and charted same, bleed off and R/U and test IA to 1500 psi for 15 min.good. 00:00 00:45 0.75 5,718 5,718 COMPZ RPCOM ELOG P PJSM, Continue running wire line, GR/CCL for corelation to set packers on depth. 00:45 02:15 1.50 5,718 5,718 COMPZ RPCOM ELOG P PJSM, R/D HES wire line and lubricator. 02:15 03:00 0.75 5,718 57,018 COMPZ RPCOM OTHR P Drop 1"ball, R/U circulating lines and test to 4000 psi.good. 03:00 04:00 1.00 5,718 5,704 COMPZ RPCOM CIRC P P/U 14'and put packers on depth, pump @ 2 bpm with 200 psi, pumped 100 bbls and attempt to surge pressure to seat ball with no luck. 04:00 04:15 0.25 5,704 5,710 COMPZ RPCOM CIRC T Reverse circulate 10 bbls at 2 bpm and 100 psi. 04:15 04:45 0.50 5,704 5,704 COMPZ RPCOM CIRC T Break circ down dp and pumpe 25 bbls @ 4 bpm with 500 psi, ball did not seat, reduce pump rate to 2 bpm 180 psi and call town. 04:45 05:30 0.75 5,704 5,704 COMPZ RPCOM CIRC T Drop 1-1/2"ball and pump down @ 2 bpm 180 psi, P/U= 108K, S/O= 108K, pumped 100 bbls and did not seat ball. Called town. 05:30 07:00 1.50 5,704 5,704 COMPZ RPCOM OTHR T R/D circulating lines and blow down kill line. Call town to discuss options. 07:00 07:30 0.50 5,704 5,704 COMPZ RPCOM CIRC T M/U Top Drive and establish circ @ 2 ✓ bpm 180 psi, Rotate 25 RPM,Tq= 1 K, pump 20 bbls with no luck on seating ball, shut down and blow down TD. 07:30 08:30 1.00 5,704 5,704 COMPZ RPCOM CIRC T Dump one vis cup of polymer down dp and R/U and place pipe on depth, break circ. @ 2 bpm with 150 psi and pumped 80 bbls with no luck. 08:30 12:00 3.50 5,704 5,704 COMPZ RPCOM OTHR T R/D and blow down circulating equipment and wait on slick line trunck from Alpine. 12:00 14:45 2.75 5,704 5,704 COMPZ RPCOM OTHR T PJSM,wait on slick line and clean rig. 14:45 15:45 1.00 5,704 5,704 COMPZ RPCOM OTHR T UD Top single and P/U 10.02'& 9.50'pup jts and set slips with packers on depth to make up lubricator. 15:45 16:00 0.25 5,704 5,704 COMPZ RPCOM SFTY T PJSM with slick Line crew on rigging up. Page 5 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:45 2.75 5,704 5,704 COMPZ RPCOM SLKL T Position truck and R/U wire line and lubricator and test lubricator to 3500 psi. 18:45 20:00 1.25 5,704 5,704 COMPZ RPCOM SLKL T RIH with slike line and Lead Impression Block,Tagged up on shear out valve @ 5704'MD, P/U 2' with slick line and attempt to pressure up with packers on depth, No Go. 20:00 21:00 1.00 5,704 5,704 COMPZ RPCOM SLKL T POOH with wire line, inspect LIB, Looks like ball is on seat, Consult engineer decision made to run Ball& rod down on slick line. 21:00 21:30 0.50 5,704 5,704 COMPZ RPCOM SLKL T M/U Ball&Rod on wire line, PT lubricator to 3500 psi. 21:30 22:30 1.00 5,704 5,704 COMPZ RPCOM SLKL T PJSM with Halliburton crew change, RIH with ball rod to 5103'MD tagged up on Frac sleeve attempt to circ rod through @ 3 bpm 350 psi,chase ball to bottom and on seat with Ball& Rod. 22:30 00:00 1.50 5,704 5,704 COMPZ RPCOM PRTS P Ball seated, and pressured up to 3500 psi and set packers on depth with 3500 psi for 30 min,charted, Bleed pressure and R/U to test IA. 03/27/2013 Test IA to.1500psi, R/D slickIine,Release from packers POOH with dp,Flush stack, R/U to run,TBG, RIH W/TBG and Fiber Optic control line,Confirmed No-Go,Circ inhibited brine,Space out with pups and Change over to 4 1/2"handling equipment. 00:00 00:30 0.50 5,704 5,704 COMPZ RPCOM PRTS P PJSM,test IA to 1500 psi for 15 mins and record on chart. 00:30 01:30 1.00 5,704 5,704 COMPZ RPCOM SLKL P PJSM, R/D slick line unit. 01:30 01:45 0.25 5,704 4,992 COMPZ RPCOM PRTS P P/U single,set down 16 K, P/U observed 5 K overpull set back down 16 K, P/U over 5 K, not released, M/U Top Drive and pressure up to 3000 psi,set down 20 K,Observed release from packer assembly, P/U wt to 97 and bleed off. 01:45 02:30 0.75 4,992 4,892 COMPZ RPCOM OWFF P Monityor well, L/D 3 joints dp and 2 pups. 02:30 03:00 0.50 4,892 3,868 COMPZ RPCOM TRIP P POOH to 3868'MD, Calc=28.0 bbls, Actual=30.5 bbls. 03:00 04:00 1.00 3,868 3,868 COMPZ RPCOM SVRG P Service drawworks and rig 04:00 06:30 2.50 3,868 0 COMPZ RPCOM TRIP P Continue POOH, L/D running tool and clear floor. 06:30 07:00 0.50 0 0 COMPZ RPCOM OTHR P Drain stack and pull wear ring. 07:00 07:45 0.75 0 0 COMPZ RPCOM OTHR P R/U and flush stack with 9 bpm 390 psi. 07:45 10:00 2.25 0 0 COMPZ RPCOM RCST P PJSM, R/U casing equipment, P/U SLB spooler and rig up sheave and fiber optic line. 10:00 12:00 2.00 0 75 COMPZ RPCOM RCST P PJSM, RIH with 3.5"TBG to 75'MD, M/U fiber optic to solid guage mandrel and test to 5000 psi for 15 min. Page 6 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 75 75 COMPZ RPCOM RCST P PJSM, Run completion with control line.Continue M/U fiber optic line and test. 12:15 20:15 8.00 75 4,946 COMPZ RPCOM RCST P RIH with 3.5"TBG as per detail, P/U 4 space joint, Calc= 17.7 bbls, _Actual= 17.5, P/U=69K,S/0=70K. 20:15 21:00 0.75 4,946 4,962 COMPZ RPCOM RCST P M/U Circ. head on jt#160. 21:00 21:15 0.25 4,962 4,962 COMPZ RPCOM CIRC P Space out and circ @ lbpm inhibited brine down with 80 psi and increased to 280 psi when stung into PBR. 21:15 22:00 0.75 4,962 4,962 COMPZ RPCOM PULD P Space out and locate in PBR,set down 20 K to confirm No-Go location. 22:00 22:45 0.75 4,962 4,962 COMPZ RPCOM CIRC P Circ 145 bbls of inhibited brine,shut down and pump 45 bbl of uninhibited brine 22:45 23:30 0.75 4,962 4,962 COMPZ RPCOM PULD P UD 3 joints, P/U 2.40',4.18', 10.14' and 10.16'pup joints X-Over to 4.5" .IBTM 23:30 00:00 0.50 4,962 4,962 COMPZ RPCOM OTHR P C/O handling equipment to 4.5". 03/28/2013 M/U fiber optic and land hanger,test same,PT do IA to 1000 psi, Monitor well,test TBG 3500 psi bleed down 2000&Pressure up IA 3500 psi,dump and shear out valve,set 2-way check and test to 2500 psi,and in direction of flow 2500 below,N/D BOP, N/U adapter&tree,test to 5000 psi, Pull 2-way and pump 70 bbls diesel and let u-tube,set BPV&secure tree, L/D 4"dp from derrick, R/D for move. (Rig Released @ 24:00 hrs 3/28/2013) 00:00 01:00 1.00 4,962 4,962 COMPZ RPCOM RCST P PJSM,M/U 1 joint of 4.5"TBG, M/U hanger with landing joint with circ x-over. 01:00 01:30 0.50 4,962 4,962 COMPZ RPCOM OTHR P M/U fiber optic line to hanger and _test to 5000 psi. 01:30 02:15 0.75 4,962 5,010 COMPZ RPCOM RCST P Land hanger and RILDS, clear floor. 02:15 03:30 1.25 5,010 5,010 COMPZ RPCOM PRTS P R/U and PT down IA to 1000 psi for 10 min and chart the lower seals. Monitor well. 03:30 04:30 1.00 5,010 5,010 COMPZ RPCOM PRTS P Test 3.5"TBG to 3500 psi, 15 min and chart, Bleed psi down to 2000 psi and pressure up to 3500 on IA for 15 min and dump TBG psi and shear out DCR-1 valve. 04:30 05:00 0.50 5,010 5,010 COMPZ RPCOM PULD P R/D Circ equipment, back out landing joint, set 2-way check valve. 05:00 06:00 1.00 5,010 5,010 COMPZ RPCOM PULD P Install landing joint, PT down on 2-way check to 2500 psi and chart, R/U and test 2-way check from below in direction of flow and hanger _seals to 2500 psi and chart 06:00 07:00 1.00 5,010 5,010 COMPZ RPCOM OTHR P Blow down and R/D circ lines and suck out stack. _ 07:00 08:45 1.75 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/D BOP stack. 08:45 10:00 1.25 5,010 5,010 COMPZ RPCOM NUND P N/U, Install S.B.M.S. in TBG hanger, Install&test fiber optic line through port on spool. 10:00 12:00 2.00 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/U Adapter flange&tree. Page 7 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 5,010 5,010 COMPZ RPCOM NUND P PJSM, N/U tree. 13:00 14:45 1.75 5,010 5,010 COMPZ RPCOM OTHR P R/U scaffoldingin cellar, Continue N/U tree,test bonnet flange to 5000 psi for 10 min.Witnessed,SIM-OPS R/U hard lines and hoses for freeze protection. 14:45 16:45 2.00 5,010 5,010 COMPZ RPCOM PRTS P R/U test equipment to tyest tree, test lubricator and tree to 5000 psi for 10 min,charted and pull 2-way check valve. 16:45 18:00 1.25 0 0 COMPZ RPCOM FRZP P PJSM, Pump 70 bbls of diesel for freeze protection @ 1.4 bpm 200 psi, 1.5 bpm with 450 FCP. SIM-OPS, PJSM lay down 4"dp via mouse hole. 18:00 18:30 0.50 0 0 COMPZ RPCOM OTHR P Blow down freeze protection lines, Put IA&TBG in communications to u-tube. 18:30 20:30 2.00 0 0 COMPZ RPCOM PULD P Coninue laying down 4"dp from derrick via mouse hole. 20:30 22:00 1.50 0 0 COMPZ RPEQP1OTHR P Blow down u-tube lines and rig down, set BPV, install blanking flanges on OA, IA and tree,secure well. (OA=100 psi, IA=0 psi,TBG=0 psi.) Disconnect outside choke line and clean Polution pan, clean cellar box. 22:00 23:15 1.25 0 0 COMPZ RPCOM PULD P Continue laying down 4"dp. 23:15 00:00 0.75 0 0 COMPZ MOVE RURD P Prep for rig move. (Rig released at 24:00 hrs 3/28/2013) V Page 8 of 8 ConocoPhillips Time Log & Summary iti'el?view Web Reporting Report Well Name: CASSIN 1 Rig Name: Job Type: TEST-LOG-PROFILE Rig Accept: Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/02/2013 24 hr Summary Started Expro well site generator. Erected 90'flare. Lay secondary containment liner for gas line to flare. Hooched in sand trap. Rig up 3" 1502 hardline from wellhead to choke. Framed in hooch for secondary tanks. Borough inspectors visited the site and found the pad in good order. 00:00 00:00 24.00 COMPZ FLOWT RURD P Rig up Expro well test equipment, flow back tanks and well intervention tanks. 04/03/2013 All flow back lines laid in place,sparge,sand,gas to flare and tank tackle lines. Routed electrical cables. Lost generator diesel driver on 4 phase separator unit ordered replacement. Notified BLM of intent to stimulate well on Friday as per Sundry approval. SLB fracture equipment staged over containment. SLB tanks connected via manifold and under heat. 00:00 00:00 24.00 COMPZ FLOWT RURD P All flow back lines laid in place, sparge,sand,gas to flare and tank tackle lines. Routed electrical cables. Lost generator diesel driver on 4 phase separator unit ordered replacement expect portable backup unit to arrive tomorrow mid morning. Notified BLM of intent to stimulate well on Friday as per Sundry approval. Hooked up power to well site envirovac and turned on heat. SLB fracture equipment staged over containment. SLB tanks connected via manifold and under heat. 04/04/2013 Rigged up poly flow air lines to ESD stations,grounded all equipment, removed two secondary storage tanks and added one new tank. Completed frac rig up less stinger and began heating frac tanks. 00:00 05:45 5.75 COMPZ FLOWT RURD P Rig up poly flow line air system to ESD stations. Ground all equipment to the wellhead. Marry up electrical cables in neat bundles,clear walking and working surfaces of trip hazards. 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. Page 1 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:15 0.50 COMPZ FLOWT RURD P Inspected enviro vac, heaters on and functioning. Ordered out water, issues with trucking supply,down on drivers, ETA Friday midday for functonal enviro vac. Full C&D dumpster swapped out for empty. Two empty bins on location. 07:15 07:45 0.50 COMPZ FLOWT RURD P Inspected secondary tanko and atigun tank numbers CTU-05 and 1804 respectively. Both tanks have weir inplace with no flow through and no way to empty 3/4 of the tank capacity less a hose over the top. Ordered replacement 400 bbl tank from Kuparuk stock. 07:45 08:15 0.50 COMPZ FLOWT RURD P Installed T,gauge,and valve to SSV hydraulic actuator. Pumped open SSV with enerpack and installed fusible cap. 08:15 09:15 1.00 COMPZ FLOWT RURD P Installed stick built scaffolding on well house roof for access to stinger tree saver. 09:15 12:00 2.75 COMPZ FLOWT RURD P SLB stimulation crew continuing to rig up fracture equipment. Spot relief tank,GORY, and FracCat. 12:00 13:00 1.00 COMPZ FLOWT RURD P Wells support crew installed 2 1/4"x 2"1502 integral flange on inner annulus companion valve and installed back side treating line. 13:00 16:00 3.00 COMPZ FLOWT RURD P Rigged down tank tackle to 2 secondary flow back tanks with weir, lowered revetment walls and removed tanks from location. Spotted one replacement tank in revetment and re installed tank tackle/berm walls. 16:00 17:45 1.75 COMPZ FLOWT RURD P Air test separator vessel(low pressure test). 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 18:15 23:15 5.00 COMPZ FLOWT RURD P Continue to rig up EXPRO well test equipment, LRS heating tanks, Wells support pressure testing support treating iron. 04/05/2013 Hooked up generator power to heater and 4 phase separator unit. Air tested all surface lines from well to tanks. Wrapped all lines in blankets. 00:00 05:45 5.75 COMPZ FLOWT RURD P Depthed all gauge tanks and set tops. Page 2 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. Need to focus on turning in RIR cards as numbers have been low. Pinch points when wrapping lines in blankets. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 10:45 4.00 COMPZ FLOWT RURD P Lay out line blankets to wrap surface lines. Contacted Doyon 141 rig electrician and walked down job to get power to heater and 4 phase separator. Rigged down and staged envirovac generator in separator containment near 4 Phase generator. Applied heat to switch gear and cables.waiting for electrician to return to tie in equipment.. 10:45 11:00 0.25 COMPZ FLOWT RURD P Updated BLM(Justin Miller)with regard to changed stimulation schedule via e-mail and sat phone message per sundry stipulation. 11:00 14:00 3.00 COMPZ FLOWT RURD P Complete frac rig up including stinger. 14:00 17:45 3.75 COMPZ FLOWT RURD P Doyon 141 electrician returned and wired line heater to 25 kw 208 VAC gen set and 4 phase test separator to 35 kw 3 phase 480 VAC. 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil and reinforced reporting procedure and PPE expectations. 18:15 20:45 2.50 COMPZ FLOWT RURD P Low pressure air test all surface lines from well head to tank farm. Blow air through riser to return tanks to ensure open flow path. Found frozen riser in tank#25 rain for rent tiger tank, added heat to line. 20:45 00:00 3.25 COMPZ FLOWT RURD P Raise stack on heater unit and quick test same. Unit ready for glycol addition to bath and fuel then test fire. Replace transmitter on coreolis gas meter and test same. 4"Daniel meter on scrubber stack ops checked. 04/06/2013 fl("4/. Performed fracturing stimulation treatment on exploration well Cassin 1. Fracced theSanford, Blackburn,and , -444 Cassin formations,placing 90,370#, 100,551#, and 119,022#proppant, respectively. Utilized shifting sleeve system to open and isolate zones dropping 2.000"and 2.125"balls between the three formation stages. Pumped 3604-bbl total slurry volume,25#x-link gel with linear gel flushes, 309,943#total 16/20 CarboLite (100%design). Freeze protected well with 26-bbl diesel. 00:00 05:45 5.75 COMPZ FLOWT RURD P Rig up well test equipment Page 3 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil. Pressure and high activity on front side of well house. Expro to stay out of SLB work zone. Gauge installed on Epro well line to monitor during frac for any pressure bypass of double block isolation. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:45 2.00 COMPZ FLOWT RURD P Frac crew on location. Three heaters down over the night. Borrowing heaters from Expro to cover PCM and misc frozen valves. SLB warming equipment. On Expro side, two rental truck dead,COP pickup dead, newly installed 38 KW gen set hooked to 4 phase test separator down, low oil alarm,three heaters down and two light plants. Called out Peak mechanic and nonmobile equipment mechanic. 08:45 09:30 0.75 COMPZ FLOWT RURD P Frac wells supervisor on location. Hold pre job with Cassin-1 fuelers, ACS, and Expro. Frac pumps started and warming up. BLM (Justin Miller)on location to witness stimulation. Lost all communication at Canning river camp. 09:30 10:30 1.00 COMPZ FLOWT RURD P Frac pre job safety meeting 10:30 11:30 1.00 COMPZ FLOWT RURD P Frac PT to 7000 psi/4000 psi back side(LRS)and start job. Road to Doyon 141 to use phones to contact telecom support. Make necessary notifications. 11:30 16:30 5.00 COMPZ FLOWT RURD P Off loaded N2 racks from DTH and staged on site. Telecom support on location diagnosing problem. Fiber optic/copper conductor line crossing pad from telecom hut to Canning river camp was compromised by a loader strike approx 3 weeks ago. Lines were exhumed, repaired and reburied. It appears as if the fiber line has failed. Suspect splice repair. Switched comms to copper conductor line. Comms back on approx 4:30 pm. 16:30 17:45 1.25 COMPZ FLOWT RURD P Frac complete all three stages pumped as designed with flush. monitor pressures 30 minutes and begin to rig down. Page 4 of 12 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 17:45 18:15 0.50 COMPZ FLOWT RURD P Night safety&operations meeting. Discussed pressure test procedure, simops with SLB stimulation crew and LRS hot oil. 18:15 20:45 2.50 COMPZ FLOWT RURD P SLB rigging down alley for CT _access in the morning. 20:45 00:00 3.25 COMPZ FLOWT RURD P Expro-LRS pressure test well to tanks @ 1000 psi,well to heater 3000 psi with diesel. 04/07/2013 Removed remaining stimulation equipment from pad, rigged up CT unit and milled on first frac ball seat @ 5209 ft RKB. Tagged second port at 5487 ft started milling. unit pump pressure unit malfunctioned. POOH for night. _ 00:00 05:45 5.75 COMPZ FLOWT RURD P load test separator and well test surface lines with Diesel. Start pressure test,found leaks. Pump out of diesel, released to refill. 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB stimulation crew and LRS hot oil. CTU unit safe work zone. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:45 2.00 COMPZ FLOWT RURD P Alipne ASCR on location to remove frac relief tanks and misc equipment. Staged waiting on frac crew. 08:45 11:30 2.75 COMPZ FLOWT RURD P Frac crew back on location picked up some remainging equipment. CTU crew on site, unit staged at Midway camp. CTU crew walked down well site and left to retrieve CTU. 11:30 13:30 2.00 COMPZ FLOWT RURD P Frac crew and CTU crew moving frac equipment. Hard line crew pressure testing returns lines. 13:30 17:00 3.50 COMPZ FLOWT RURD P RU CTU#5 MU MHA#1 Pull test 30k. P/T MHA 250/3500 psi to well. Verify fluid path and pt 250/4000 psi. 17:00 18:00 1.00 COMPZ FLOWT RURD P 5,100 ft Wt Ck, 12k RIH 1.5k Tag up on frac port at 5200 ft ctmd. PUH pump 1.5 bpm slick diesel,CT 2200, WH 500 psi 18:00 21:45 3.75 COMPZ FLOWT RURD P Mill on Frac port multiple stalls. Down on pumps, run dry through FracPORT no problem. Continue to RIH to second FracPORT at 5477 ft ctmd(5487 ft RKB)flag pipe. Start milling at 5475 ft ctmd WOB.5k mill to 5475.7 ft unit pressure gauge malfunctioning. 21:45 23:15 1.50 COMPZ FLOWT RURD P POOH,freeze protect surface lines, secure well, lay down for night. 04/08/2013 Milled thru bottom FracPORT at 5,487-ft RKB. RIH w/2"JSN to 6,300-ft RKB,575-ftbelow bottom perforations 2.813"CMD-SSD open at 5,209-ft and 5,487-ft RKB. Ready for Slicklne. 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on coil crew to return Page 5 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting. Discussed walking an working surfaces,simops with SLB CTU unit and their safe work zone. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P Waiting on coil crew to return. 08:30 09:00 0.50 COMPZ FLOWT RURD P Coil crew travel from midway camp to Cassin#1. Inspect location,start equipment. 09:00 09:45 0.75 COMPZ FLOWT RURD P PJSM RU CTU#5. Breakdown MHA #1 to install stabilizer above motor. 09:45 10:15 0.50 COMPZ FLOWT RURD P Wait on Baker to arrive with stabilizer from Prudhoe and XO's from Alpine. 10:15 11:04 0.82 COMPZ FLOWT RURD P MU MHA#2 test 250/3500 psi to well,verify fluid paths to tanks, P/T surface equipment 250/4000 psi. 11:04 11:59 0.93 COMPZ FLOWT RURD P RIH w/Mha#2, RIW 1.5k. 11:59 13:59 2.00 COMPZ FLOWT RURD P 5100 ft Wt Ck 13k RIW 1k, no problem thru SSD at 5209 ft RKB, tag up at 5,479 ft, Up wt 13.2k, on-line 1.5 bpm, CT 2000,WH 5000. Start milling at 54777.7 ft ctmd,CT 2180,WOB.5k,stall at 5477.8 ctmd,time mill to same, PUH shut down pumps,dry tag at 5,479 ft ctmd,time mill CT 2000,WH 600. 13:59 16:14 2.25 COMPZ FLOWT RURD P Multiple stalls at 5477.8 ft ctmd, PUH shut down pump,close choke, dry tag at 5479 ft PU on line 1.5 bpm, CT 2000,WH 625,time mill through FracPORT, PU off line on the pump, close choke,drift lower CMD-SSD no problem. 16:14 16:24 0.17 COMPZ FLOWT RURD P RIH and tag XN nipple at 5677 ft ctmd(5685-RKB)flag pipe. 16:24 17:09 0.75 COMPZ FLOWT RURD P POOH pumping min rate,CT 1190. WH 800. 17:09 18:28 1.33 COMPZ FLOWT RURD P On surface brake down MHA, mill shows a little wear on the outside edge only reheaded to to SLB equipment, pull test, MU BHA#3,to well, PT equipment 250/4000. 18:28 19:18 0.84 COMPZ FLOWT RURD P RIH w/BHA#3 pumping 10 bbl gelled diesel sweep.5 bpm, CT 1000,WH 750. 19:18 19:38 0.34 COMPZ FLOWT RURD P 5000 ft Wt Ck 11k, CT 1075,WH 750, RIW 2.5k 19:38 20:12 0.58 COMPZ FLOWT RURD P At 5685 ft corrected depth to flag, reduce rate to minimum, RIH 90 fpm, CT 800,WH 500, RIW 5k.getting pick up weights every 100ft, slack off 2k at 6298 ft MD(573 ft below bottom perf)PU online 2 bpm,gelled diesel up and around the coil. 20:12 21:16 1.08 COMPZ FLOWT RURD P POOH chasing gel out of tubing, slow down across GLM's. Page 6 of 12 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:16 22:40 1.41 COMPZ FLOWT RURD P On surface, pump 26 bbls for freeze protect, 1:1 returns throughout job, RD CTU#5,secure well, release equipment,stage unit on pad for night. 22:40 23:25 0.75 COMPZ FLOWT RURD P Travel to Midway camp for night,will return in AM to road unit to Alpine. 04/09/2013 Move out CTU#5, MURU SL unit 770.Tagged bottom @ 6253'SLM. Attempted to close frac sleeves @ 5210 and 5488'RKB. In Progress. 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on SL crew to return 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting w/Expro Crew. Discussed walking an working surfaces,simops with HEs S/L unit and their safe work zone, reported spill at Repsol Q6. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P Waiting on coil crew to return. 08:30 09:00 0.50 COMPZ FLOWT RURD P Coil crew travel from midway camp to Cassin#1. Check in, inspect location, move unit off pad to Alpine. 09:00 09:30 0.50 COMPZ FLOWT RURD P Wait on SL and hot oil units to travel from Alpine. 09:30 10:45 1.25 COMPZ FLOWT RURD P PJSM, RU SL#770 and LRS hot oil pump. 10:45 11:45 1.00 COMPZ FLOWT RURD P JSSM,SIMOPS w Expro, RU.125' wire and 2.125" TS-RS,QC,3',3',QC,OJ,QC,LSS,QC. LRS PT@ 2500 psi. 11:45 13:00 1.25 COMPZ FLOWT RURD P RIH w/2.26"Cent,2"DD Bailer(M/S Flapper)S/D @ 6253 SLM. Tap DN. Pull small bind. POOH. 13:00 14:45 1.75 COMPZ FLOWT RURD P RIH w/2.81"42 BO(S/R up), DBL FM,2.77'-Ring to 5190'SLM(5210 RKB) Engaged sleeve. pull 600#over bind. Holding solid. Unable to close spangs w/o falling through sleeve. Make short runs @ sleeve to engage progressively harder. Pull through after 5 hits. Unable to re-engage sleeve w/multiple passes through sleeve. Continue to RIH to sleeve @ approx 5466'SL. Unable to engage after multiple passes through. POOH. Re engaged sleeve at @ 5190'SLM. Work as before until pull through. Unable to re-engaged w/ multiple passes. POOH. Pin not sheared. Page 7 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 17:30 2.75 COMPZ FLOWT RURD P RIH w 3.5"BL-Brush,4280(diff S/R up), DBL FM,2.77"G-ring to 5190 SLM(5210 RKB)pass through sleeve,then engage sleeve. Repeat 2 times,begin small spang licks then work up to 600#over OJ licks. Pulled through after 3 licks @ 600# over. Unable to re-engage. RIH to sleeve @ 5488' RKB. Unable to engage after multiple passes. POOH. Pin worked but not sheared. 17:30 20:00 2.50 COMPZ FLOWT RURD P RIH w/3.5"BL-BRUSH,42BO (DIFFERENT S/R UP), DBL FM, 2.77"G-RING TO 5190'SLM(5210' RKB) PASS THRU SLV. THEN ENGAGE SLV. REPEAT 2 TIMES. BEGIN SMALL SPANG LICKS THEN WORK UP TO 600#OVER OJ LICKS. PULLED THRU AFTER 3 LICKS @ 600#OVER. UNABLE TO RE-ENGAGE. RIH TO SLV @ 5488' RKB. UNABLE TO ENGAGE AFTER MULTIPLE PASSES. POOH. PIN WORKED BUT NOT SHEARED. 20:00 21:00 1.00 COMPZ FLOWT RURD P RIH w/3.5", BL-BRUSH,4260(S/R, UP) AND 2.77"G-RING TO LOWER SLV @ 5470'SLM(5488'RKB) UNABLE TO ENGAGE SLV AFTER MULTIPLE PASSES. PUH. DID NOT ENGAGE UPPER SLV. POOH. PIN NOT SHEARED. 21:00 22:45 1.75 COMPZ FLOWT RURD P RIH w/3.5"BL-BRUSH,4260(POS, UP,STEEL) AND 2.77"G-RING TO LOWER SLV @ 5470'SLM(5488' RKB) UNABLE TO ENGAGE. PUH. TO UPPER SLV @ 5190' SLM(5210' RKB) UNABLE TO ENGAGE. POOH. PIN SHEARED. 22:45 00:00 1.25 COMPZ FLOWT RURD P RIH w/ 3.5"BL-BRUSH,4260 (POS, UP, STEEL)AND 2.77" G-RING TO LOWER SLV @ 5470' SLM(5488' RKB) PASS DN THRU SLV. UNABLE TO ENGAGE IN EITHER DIRECTION. PUH TO UPPER SLV @ 5190'SLM(5210' RKB) PULL UP THRU SLV EASILY. SET DN IN SLV. TAP DN LIGHTLY. STAYED ENGAGED. PULL 500# OVER OJ LICK. PULLED FREE. RIH AND S/D AGAIN. PULLED 400#OVER OJ LICK. PULLED FREE. POOH. 00:00 01:00 1.00 COMPZ FLOWT RURD P BEGIN LDFN, INSPECT AREA, PJSM, GO TO CAMP. Page 8 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/10/2013 24 hr Summary SET CATCHER @ 5685' RKB. PULLED DV AND SET OV(5/16")@ 4840'RKB. VERIFIED SLV @ 5210' RKB IS CLOSED AND SLV @ 5488'RKB IS NOT HOLDING. PULLED CATCHER @ 5685'RKB. BLEED PRESSURE FROM WELL TO TANKS,START UNLOADING THE IA WITH N2 @ 200 SCF/m 00:00 05:45 5.75 COMPZ FLOWT RURD P Wait on SL crew to return 05:45 06:15 0.50 COMPZ FLOWT RURD P Morning safety&operations meeting w/Expro Crew. Discussed walking an working surfaces,simops with HEs S/L unit and their safe work zone, reported spill at Repsol Q6. 06:15 06:45 0.50 COMPZ FLOWT RURD P Morning Wells Group Operations call in meeting. 06:45 08:30 1.75 COMPZ FLOWT RURD P PHONE CONFERENCE w/CWG REPS,SYNC, PU CPU/WELL FILE, GO TO LOCATION/INSPECT. 08:30 09:00 0.50 COMPZ FLOWT RURD P JSSM,SIMOPS w/EXPRO, RU .125"WIRE AND 2.125" TS=RS,QC,3',3',QC,KJ,5',QC,KJ,5',Q C,KJ,LSS,QC. (29'-2") LRS PT @ 2500 PSI. 09:00 10:15 1.25 COMPZ FLOWT RURD P RIH w/3.5"GS AND 2.72"x 21.5" BAIT SUB,2.77"G-RING TO XN @ 5664'SLM(5685'RKB) MAKE MULTIPLE PASSES THRU BOTH FRAC SLV's AND 5250'SLM. NO FLOW DETECTED. SET CATCHER IN XN @ 5664'SLM(5685'RKB) POOH. 10:15 11:45 1.50 COMPZ FLOWT RURD P ADD OJ's. RIH w/3.5"OM-1 AND 1.625"JD TO STA#1 @ 4822'SLM (4840'RKB) LATCH DV. POOH. 11:45 12:45 1.00 COMPZ FLOWT RURD P DROP OJ's. RIH w/3.5"OM-1 AND RK LATCH ON 1.5"OV(5/16")TO STA#1 @ 4822'SLM(4840'RKB) SET OV. BLEED IA f/350-0 PSI. SHEAR OFF. POOH. 12:45 15:15 2.50 COMPZ FLOWT RURD P RIH w/3.5"D&D HOLEFINDER (COLLER STOP)TO 5504'SLM (BELOW LOWER SLV) SET D&D PUMP 1 BBL. NO CHANGE. PUH TO 5460'SLM(ABOVE LOWER SLV) PUMP 0.2 BBLS. INCREASED TBG f/700 TO 1300 PSI. HOLDING SOLIDLY. BLEED DN. POOH. Page 9 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:45 1.50 COMPZ FLOWT RURD P TS=RS,QC,3',3',QC,KJ,5',QC,KJ,3',Q C,OS,QC,KJ,LSS,QC(33'0") RIH w/42B0(S/R, UP)DBL FM, 3'x 1.875", BL-BRUSH,42B0(POS, UP) RS (ZEROED @ UPPER 4260) TO LOWER SLV @ 5470'SLM(5488' RKB) PASS THRU SLV MULTIPLE TIMES @ DIFFERENT SPEEDS. 1ST VERY SLOW PASS PULLED @ 550#OVER. REMAINING PASSES WERE @ 300#OVER. NO DEFINATE ENGAGEMENT. PUH. UNABLE TO PULL THRU 5232'SLM. ATTEMPT TO PULL THRU MULTIPLE TIMES. BEGIN PUMPING. NO CHANGE OTHER THAN INCREASED WT. SHUT PUMP DN. PULL THRU w/o BOBBLE. POOH. PIN OF S/R KEYS SLIGHTY WORKED. PIN OF POS KEYS SHEARED. 16:45 18:15 1.50 COMPZ FLOWT RURD P RIH w/3.5"D&D HOLEFINDER (COLLER STOP)TO 5504'SLM (BELOW LOWER SLV) SET D&D PUMP 2 BBL. @ 3/4 BBLS/MIN TGB INCREASED f/700-. 800 PSI. SHUT PUMP DN. PUH TO 5460' SLM(ABOVE LOWER SLV) PUMP 0.2 BBLS. INCREASED TBG f/700 TO 1300 PSI. HOLDING SOLIDLY. BLEED DN. POOH. 18:15 19:15 1.00 COMPZ FLOWT RURD P ADD OJ's. RIH w/3.5"GR TO 5664' SLM(5685' RKB) LATCH CATCHER. POOH. WALK WELLHEAD TO FLARE AND TANKS INSPECT LINES AND EQUIPMENT WITH BOTH DAY AND NIGHT EXPRO CREW SUPERVISORS. 19:15 20:00 0.75 COMPZ FLOWT RURD P BEGIN RD, INSPECT AREA, CHECK w/CWG REP. TRAVEL TO ALPINE, END TICKET, DOWNLOAD,TURN IN PAPERWORK. 20:00 22:00 2.00 COMPZ FLOWT RURD P SLB N2 PUMPERS ON LOCATION, PRE JOB,CHECK IN, RU, PT @3000 PSI. hOLD PREJOB SAFETY MEETING WITH SLB AND EXPRO IN TANK FARM HOOCH. SLB TANKER 53'2600 GAL PRE COOL DOWN, POST COOL DOWN, 52"2642 GAL N2. HALLIBURTON TANKER ON LOCATION AND OFF LOADING INTO SLB 22:00 23:00 1.00 COMPZ FLOWT PRDT P OPEN WELL TO CLOSED CHOKE. SLOWLY WORK CHOKE OPEN TO 40/64 ths. T/I/0=26/0/0 Page 10 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 COMPZ FLOWT PRDT P SLB N2 ONLINE WITH BOOSTER PUMP ONLY TO THE IA FOR 2 MINUTES,SLOWLY RAISE RATE TO 200 SCF. INITIAL T/I/O= 19/344/0, FINAL @ MIDNIGHT T/I/O =31/590/0 TUBING TEMP 54 F. 04/11/2013 Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed traps and pinch points. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT P Flow well to tanks 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/12/2013 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed traps and pinch points. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks. Top off SLB N2 pumper,dispatch empty 6500 gal tanker to Deadhorse to refill. SLB pump 2794 gal N2 @ 0655. 08:00 09:00 1.00 COMPZ FLOWT PRDT P Developed aweep at a valve requiring the well be shut in at the wing to bleed pressure in order to isolate valve. Repositioned N2 unit while well S/I to accommodate E-line logging unit crane. Replace weeping valve. 09:00 12:00 3.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks, 16:00 16:30 0.50 COMPZ FLOWT PRDT P Slowed N2 lift rate to allow time for transport to return to location and off load. 16:30 20:00 3.50 COMPZ FLOWT PRDT P Increase lift rate to target. Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/13/2013 Log Production profile. Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks Page 11 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew&HES E-line Crew. Discussed Simops,slick surfaces, communication. _ 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Rig up HES E-line, RIH and log production profile. 08:00 12:00 4.00 COMPZ FLOWT PRDT P Log production profile. 12:00 16:00 4.00 COMPZ FLOWT PRDT P Log production profile. 17[�" 16:00 20:00 4.00 COMPZ FLOWT PRDT P Log production profile. 20:00 00:00 4.00 COMPZ FLOWT PRDT P RD HES E-line. Shut in N2 Pump momentarily and shut down deck engine to check oils. Restarted pump and opened up to inner annulus. Resumed pumping N2. 04/14/2013 Flow well to tanks 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed, slick surfaces, planned demob, increased temperatures, melting pad. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks °") • 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks 04/15/2013 Flow well to tanks, SLB Oil Phase collected well bore fluid samples. 00:00 05:45 5.75 COMPZ FLOWT PRDT P Flow Well to tanks 05:45 06:15 0.50 COMPZ FLOWT PRDT P Morning safety&operations meeting w/Expro Crew. Discussed, upcoming well work, manager visit, planned demob, increased temperatures, melting pad. 06:15 06:45 0.50 COMPZ FLOWT PRDT P Morning Wells Group Operations call in meeting. 06:45 08:00 1.25 COMPZ FLOWT PRDT T Flow well to tanks 08:00 12:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks rigged up Oil Phase 12:00 16:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks took oil phase samples 16:00 20:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks took 5 gal dead crude samples. 20:00 00:00 4.00 COMPZ FLOWT PRDT P Flow well to tanks Page 12 of 12 • �gf ' ConocoPhillips (Alaska) Inc. -Expl North Alaska ASP5 Cassin Cassin #1 API : 501032066300 111 Sperry Drilling Services Definitive Survey Report 29 March, 2013 11 g.t ,y i11 E� NI RS ...NNNNIII ft HALLIIBURTONE AP„at Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASP5 TVD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Project North Alaska ASP5,Alaska Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 05 Using geodetic scale factor Well Cassin#1 Well Position +N/-S 0.00 ft Northing: 5,985,067.77 ft Latitude: 70°21'39.902 N +E/-W 0.00 ft Easting: 726,411.83 ft Longitude: 152°9'38.176 W Position Uncertainty 0.00 ft Wellhead Elevation: 0.00 ft Ground Level: 74.10ft Wellbore Cassin#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°l (nT) BGGM2012 2/28/2013 18.99 80.71 57,541 Design Cassin 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.60 Vertical Section: Depth From(ND) +N/-S +El-W Direction (ft) (ft) (ft) (°) 27.60 0.00 0.00 115.99 Survey Program Date 3/29/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 131.61 2,378.35 Cassin 1(Cassin#1) MWD MWD-Standard 03/04/2013 2,378.35 6,451.25 Cassin 1(Cassin#1) MWD MWD-Standard 03/04/2013 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 27.60 0.00 0.00 27.60 -74.10 0.00 0.00 5,985,067.77 726,411.83 0.00 0.00 UNDEFINED 131.61 0.14 50.80 131.61 29.91 0.08 0.10 5,985,067.86 726,411.93 0.13 0.05 MWD(1) 222.66 0.39 53.97 222.66 120.96 0.33 0.44 5,985,068.12 726,412.26 0.27 0.25 MWD(1) 315.97 0.39 42.69 315.97 214.27 0.75 0.91 5,985,068.55 726,412.72 0.08 0.49 MWD(1) 402.28 0.42 39.61 402.27 300.57 1.21 1.31 5,985,069.03 726,413.10 0.04 0.64 MWD(1) 492.59 0.38 51.42 492.58 390.88 1.65 1.75 5,985,069.48 726,413.54 0.10 0.85 MWD(1) 591.42 1.02 133.40 591.41 489.71 1.25 2.65 5,985,069.11 726,414.44 1.05 1.83 MWD(1) 683.67 0.92 128.75 683.64 581.94 0.23 3.82 5,985,068.12 726,415.65 0.14 3.34 MWD(1) 777.78 0.85 135.26 777.74 676.04 -0.74 4.90 5,985,067.18 726,416.76 0.13 4.73 MWD(1) 867.76 0.92 132.97 867.71 766.01 -1.71 5.90 5,985,066.25 726,417.78 0.09 6.05 MWD(1) 961.60 0.90 127.42 961.54 859.84 -2.67 7.04 5,985,065.32 726,418.95 0.10 7.50 MWD(1) 1,054.30 0.83 129.90 1,054.23 952.53 -3.54 8.13 5,985,064.48 726,420.07 0.09 8.86 MWD(1) 1,146.75 0.95 127.91 1,146.67 1,044.97 -4.44 9.25 5,985,063.61 726,421.21 0.13 10.26 MWD(1) 3/29/2013 12:30:31PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASPS ND Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,239.71 0.83 128.81 1,239.62 1,137.92 -5.34 10.38 5,985,062.75 726,422.37 0.13 11.67 MWD(1) 1,330.46 0.81 128.83 1,330.36 1,228.66 -6.15 11.39 5,985,061.97 726,423.41 0.02 12.94 MWD(1) 1,419.02 0.96 134.38 1,418.91 1,317.21 -7.06 12.41 5,985,061.09 726,424.45 0.19 14.25 MWD(1) 1,518.05 0.93 134.34 1,517.92 1,416.22 -8.21 13.58 5,985,059.98 726,425.65 0.03 15.80 MWD(1) 1,613.64 0.89 131.69 1,613.50 1,511.80 -9.24 14.69 5,985,058.98 726,426.79 0.06 17.25 MWD(1) 1,701.66 0.72 132.32 1,701.51 1,599.81 -10.07 15.61 5,985,058.18 726,427.74 0.19 18.44 MWD(1) 1,795.10 0.67 123.48 1,794.95 1,693.25 -10.77 16.50 5,985,057.51 726,428.65 0.13 19.55 MWD(1) 1,887.40 0.88 127.68 1,887.24 1,785.54 -11.50 17.51 5,985,056.81 726,429.68 0.24 20.78 MWD(1) 1,981.16 0.76 126.97 1,980.99 1,879.29 -12.31 18.58 5,985,056.03 726,430.77 0.13 22.09 MWD(1) 2,073.01 0.61 115.19 2,072.83 1,971.13 -12.89 19.51 5,985,055.49 726,431.72 0.22 23.18 MWD(1) 2,165.26 0.61 127.72 2,165.08 2,063.38 -13.39 20.34 5,985,055.00 726,432.57 0.14 24.15 MWD(1) 2,256.71 0.66 114.91 2,256.52 2,154.82 -13.91 21.20 5,985,054.51 726,433.44 0.16 25.15 MWD(1) 2,310.78 0.65 110.63 2,310.59 2,208.89 -14.15 21.77 5,985,054.29 726,434.02 0.09 25.77 MWD(1) 2,379.81 0.60 134.30 2,379.61 2,277.91 -14.54 22.40 5,985,053.91 726,434.66 0.38 26.50 MWD(2) 2,475.46 0.63 122.49 2,475.26 2,373.56 -15.18 23.20 5,985,053.31 726,435.48 0.14 27.50 MWD(2) 2,567.16 2.48 127.72 2,566.92 2,465.22 -16.66 25.19 5,985,051.88 726,437.52 2.02 29.95 MWD(2) 2,659.31 3.90 131.04 2,658.92 2,557.22 -19.94 29.13 5,985,048.73 726,441.55 1.55 34.92 MWD(2) 2,752.00 6.01 139.98 2,751.26 2,649.56 -25.72 34.63 5,985,043.11 726,447.23 2.42 42.40 MWD(2) 2,846.37 6.25 141.68 2,845.09 2,743.39 -33.54 40.99 5,985,035.49 726,453.82 0.32 51.55 MWD(2) 2,939.20 6.19 140.99 2,937.38 2,835.68 -41.39 47.28 5,985,027.83 726,460.34 0.10 60.64 MWD(2) 3,030.90 6.01 140.87 3,028.56 2,926.86 -48.96 53.42 5,985,020.46 726,466.71 0.20 69.47 MWD(2) 3,119.65 5.90 141.29 3,116.83 3,015.13 -56.12 59.20 5,985,013.47 726,472.70 0.13 77.81 MWD(2) 3,213.25 6.00 142.15 3,209.93 3,108.23 -63.74 65.21 5,985,006.04 726,478.94 0.14 86.55 MWD(2) 3,303.48 6.04 141.14 3,299.66 3,197.96 -71.16 71.09 5,984,998.80 726,485.03 0.13 95.08 MWD(2) 3,396,76 5.89 142.00 3,392.43 3,290.73 -78.75 77.11 5,984,991.39 726,491.29 0.19 103.83 MWD(2) 3,492.80 6.02 142.35 3,487.95 3,386.25 -86.62 83.22 5,984,983.71 726,497.63 0.14 112.77 MWD(2) 3,586.43 5.99 142.36 3,581.07 3,479.37 -94.38 89.20 5,984,976.14 726,503.85 0.03 121.54 MWD(2) 3,679.88 4.76 137.34 3,674.11 3,572.41 -101.09 94.81 5,984,969.60 726,509.65 1.41 129.52 MWD(2) 3,770.29 3.30 134.77 3,764.29 3,662.59 -105.68 99.20 5,984,965.15 726,514.18 1.63 135.48 MWD(2) 3,863.02 3.11 133.17 3,856.88 3,755.18 -109.28 102.93 5,984,961.66 726,518.01 0.23 140.41 MWD(2) 3,957.55 1.45 131.85 3,951.33 3,849.63 -111.83 105.69 5,984,959.19 726,520.85 1.76 144.01 MWD(2) 4,050.76 1.21 142.08 4,044.51 3,942.81 -113.40 107.17 5,984,957.67 726,522.38 0.36 146.03 MWD(2) 4,141.21 0.51 199.42 4,134.95 4,033.25 -114.53 107.63 5,984,956.55 726,522.87 1.14 146.94 MWD(2) 4,235.14 1.27 283.28 4,228.88 4,127.18 -114.69 106.47 5,984,956.36 726,521.72 1.40 145.97 MWD(2) 4,327.35 1.35 284.01 4,321.06 4,219.36 -114.19 104.43 5,984,956.80 726,519.66 0.09 143.91 MWD(2) 4,416.53 1.38 282.07 4,410.22 4,308.52 -113.71 102.36 5,984,957.22 726,517.58 0.06 141.84 MWD(2) 4,512.48 1.33 284.92 4,506.14 4,404.44 -113.18 100.15 5,984,957.68 726,515.36 0.09 139.62 MWD(2) 4,604.27 1.23 290.53 4,597.91 4,496.21 -112.56 98.20 5,984,958.24 726,513.39 0.17 137.60 MWD(2) 4,695.12 1.03 293.24 4,688.74 4,587.04 -111.90 96.54 5,984,958.85 726,511.70 0.23 135.81 MWD(2) 4,788.69 1.11 287.23 4,782.29 4,680.59 -111.30 94.90 5,984,959.40 726,510.05 0.15 134.08 MWD(2) 3/29/2013 12:30:31PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Cassin#1 Project: North Alaska ASPS TVD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Site: Cassin MD Reference: Cassin#1 @ 101.70ft(D141(74.1+27.6)) Well: Cassin#1 North Reference: True Wellbore: Cassin#1 Survey Calculation Method: Minimum Curvature Design: Cassin 1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°l (1 (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 4,877.84 1.05 326.74 4,871.43 4,769.73 -110.36 93.62 5,984,960.30 726,508.75 0.82 132.52 MWD(2) 4,974.10 1.04 321.87 4,967.67 4,865.97 -108.93 92.60 5,984,961.70 726,507.68 0.09 130.98 MWD(2) 5,069.52 0.36 23.51 5,063.09 4,961.39 -107.98 92.19 5,984,962.64 726,507.24 0.97 130.18 MWD(2) 5,162.03 0.30 41.23 5,155.59 5,053.89 -107.53 92.46 5,984,963.10 726,507.50 0.13 130.24 MWD(2) 5,254.17 0.27 79.93 5,247.73 5,146.03 -107.31 92.83 5,984,963.33 726,507.87 0.21 130.47 MWD(2) 5,344.70 0.53 55.06 5,338.26 5,236.56 -107.03 93.39 5,984,963.62 726,508.41 0.34 130.85 MWD(2) 5,435.96 0.27 70.07 5,429.52 5,327.82 -106.72 93.94 5,984,963.95 726,508.95 0.30 131.21 MWD(2) 5,529.84 0.25 60.88 5,523.40 5,421.70 -106.54 94.32 5,984,964.14 726,509.33 0.05 131.48 MWD(2) 5,621.66 0.26 70.42 5,615.22 5,513.52 -106.37 94.69 5,984,964.32 726,509.70 0.05 131.74 MWD(2) 5,715.24 0.43 73.10 5,708.79 5,607.09 -106.20 95.23 5,984,964.51 726,510.23 0.18 132.14 MWD(2) 5,807.52 0.35 86.51 5,801.07 5,699.37 -106.08 95.84 5,984,964.64 726,510.83 0.13 132.64 MWD(2) • 5,900.16 0.51 70.41 5,893.71 5,792.01 -105.93 96.51 5,984,964.82 726,511.50 0.21 133.18 MWD(2) 5,994.96 0.49 69.54 5,988.51 5,886.81 -105.64 97.29 5,984,965.12 726,512.27 0.02 133.75 MWD(2) 6,088.91 0.49 66.29 6,082.45 5,980.75 -105.34 98.03 5,984,965.45 726,513.00 0.03 134.29 MWD(2) 6,181.08 0.49 82.10 6,174.62 6,072.92 -105.13 98.79 5,984,965.68 726,513.75 0.15 134.87 MWD(2) 6,267.08 0.80 82.15 6,260.61 6,158.91 -105.00 99.74 5,984,965.84 726,514.70 0.36 135.67 MWD(2) 6,366.68 1.51 84.82 6,360.19 6,258.49 -104.78 101.74 5,984,966.12 726,516.69 0.71 137.37 MWD(2) 6,451.25 1.74 85.60 6,444.73 6,343.03 -104.59 104.13 5,984,966.39 726,519.07 0.27 139.43 MWD(2) 6,520.00 1.74 85.60 6,513.45 6,411.75 -104.43 106.21 5,984,966.61 726,521.15 0.00 141.24 PROJECTED to TD • • • 3/29/2013 12.30:31 PM Page 4 COMPASS 2003.16 Build 69 • Bettis, Patricia K (DOA) From: Senden, R. Tyler[R.Tyler.Senden@conocophillips.com] Sent: Friday, March 29, 2013 12:48 PM To: Bettis, Patricia K(DOA) Subject: Cassin #1 10-403.xls Attachments: Cassin #1 10-403.xls Patricia, Let me know if this is adequate. I don't have ALL of the data as it is in transit from the rig that moved off the well last night. Thank you! Ty Senden 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate Q Alter Casing❑ Other: ❑ 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory Q Development ❑ 212-182 3.Address: -6.Stratigraphic ❑ Service ❑ API Number: PO BOX 100360,Anchorage,AK 99510 50-103-20663-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Cassin#1 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10. Field/Pool(s): AA081754 Wildcat 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6520 6419 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 80 80 Surface 2376 9.56" 2378 Intermediate 4039 7" 4039 Production 2468 7" 6507 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5258-5273;5535-5550;5710-5' 3.5" L-80 5703 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) (3)Premier Retrievable/None 5044;5323;5597 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 4/2/2013 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ty Senden @ 265-1544 or 982-3996 Email r.tvler.sendenna.COP.com Printed Name Ty Senden Title Staff Wells Engineer 3/29/13 Signature Phone 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: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Schwartz, Guy L (DOA) From: Senden, R.Tyler <R.Tyler.Senden@conocophillips.com> Sent: Thursday, March 28, 2013 4:05 PM To: Schwartz, Guy L(DOA) FID Subject: Cassin Frac Sundry Attachments: IA Chart Test for Cassin#1.pdf L 1 Guy, Please find the attached production casing cement report and the charted MIT-IA of the production casing. 3/20/13: Shut down pumps,line up to SLB,pump 5 bbls CW 100,test lines to 3500 psi,bleed off&pump 20 bbls CW 100,shut down and blend mud push,pump 40 bbls of 11.5 ppg mud push,drop drop btm plug with 52.2 bbls of 15.8 ppg cement,dropdrop top plug with 20 bbls of water,shut down and swap over to rigand displace with 223 bbls 9.6 ppg mud at 6 bpm with 200 psi,land hanger, FCP=900 psi,bumped plug @ 2229 stks,pressured up to 1700 psi for 5 mins,bleed off and check floats,good. Let me know if there is anything else you need from me before approving the 403. Thanks! Ty Senden ConocoPhillips Alaska, Inc. 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It / /,..4.47,,awrommol 0. `••-- te/I/ .'W ,..v... .„..,...............,.......„. ,...,v„,117,__,04,_,..z.....,,=.. „,,,,i, , -40.,„„, ,,,,...49.-0---srarO ,00 .._44....-wir ...„....wool,-• 1.000--.0 / <11 \illiLIIIIIIIIP7417.141.111.AFIMFANNEMMOV100:10 IP,414110101•00.140..9......, AA .611:•••••railli le.°/ 0444iiior •w 5t - 1 Schwartz, Guy L (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Monday, March 25, 2013 8:29 AM To: Schwartz, Guy L(DOA); 'wsvejnoh@blm.gov' Cc: Allsup-Drake, Sharon K;Alvord, Chip; Brassfield, Tom J; Soria, Dora I;Jolley, Liz C Subject: Weekly Update for Week of March 18 - March. 24 - Cassin#1 - 212182 Good morning, here is the weekly update for Doyon 141 that is out at the Cassin location: March 18–Log well with XRMI/Sonic/GEM/SGR, lay down XRMI/Sonic/GEM/SGR and pick up MRIL logging assembly and log well. Lay down MRIL logging tools and RIH with clean out assembly. March 19–RIH with clean out assembly and circulate bottoms up. Pull out of hole,lay down BHA,drain and flush BOP stack. Change out VBR to 7" Rams and test. Rig up and run 7"casing to 2384',circulate bottoms up. March 20–Finish running casing,circulate and condition mud for cementing. Rig up cementers and pump 52.2 bbl of class G cement. Lay down casing tools and install 7" pack off and pressure test to 5000psi. Change 7" rams back to VBR and test. March 21–Lay down 4"test joint and rig down test equipment. Rig up and perform LOT on OA,flush with 75bb1 of water followed by 70bbl of diesel to freeze protect. Lay out 5" DP from derrick,slip and cut drilling line. Load shed with 4" DP and strap. Make up clean out BHA and RIH while picking up 4" DP. March 22–Clean out at each perf and packer interval with clean out BHA,clean out cement stringers to 6419',circulate bottoms up and test casing to 3500psi for 30min. Clean pits in preparation for filtered brine swap. Flush all lines and equipment out. Mix spacers and pump spacers and pickling fluid. Reverse out pickle fluid with 300bbls or water. March 23–Build 100bb1 hi vis spacer and pump spacer and brine as per MI plan. POOH and lay down clean out BHA and test BOP. Install wear ring and nipple up shooting flange. March 24–Finish nippling up shooting flange, rig up wire line, pressure test riser to 2000psi. Run CBL and lay dowiklogging tools. Replace riser with lubricator and retest to 2500psi,perforate well with 3 runs, all on depth and all shots fired. OOH and rig down e-line, nipple down shooting flange. Nipple up riser and flowline. Pick up clean out de-burring BHA and RIH. If you have any questions please let me know. 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NPRA Exploration Program Cassin #1 MOC to Casing Design MOC Prepared by: MOC Reviewed by: David Lee Tom Brassfield Senior Drilling Engineer Staff Drilling Engineer MOC Reviewed by: MOC Reviewed by: Dadang Kurnia Kerry Freedman Staff Completion Engineer Principal Completion Engineer APPROVED BY: CONCURRED BY: Liz Jolley Chip Alvord Supervising Drilling Engineer Drilling Manager Cassin#1 —NPRA Exploration Page 1 of 3 MOC to Casing Design(3/14/2013) . ConocoPhillips Background Design In the success case of Cassin#1,the well will be required to be cased and completed in preparation to perforations, fracturing and testing. There are three target sands in Cassin#1: Cassin(top), Blackburn (middle) and Sandford (bottom). These three sands will be completed selectively in order to frac and test individually. The initial casing design called for the production section to be cased from TD to surface with 7" L80, 26# BTCM casing with the casing being cemented from TD to 500ft above the Cassin sand. The lower completion will consist of 3-1/2"tubing with three production packers and two frac sleeves placed between packers. A cement bond log(CAST-M)will be run in conjunction with the completion operation to ensure the top of cement and bond log through the zones. The three packers will be set in good quality cement behind the 7"casing. The Upper completion will consist of 3-1/2"tubing with seal assembly that sting in to the top packer seal bore. The following are the current planned depths: • TD—6520' MD • Production packer depths—5853' MD, 5484' MD, 5203' MD (from bottom to top) The original design for the 7" casing was based upon an assumed maximum fracture treating pressure of 5000psi. The frac screen out load is the highest load to be exerted on the 7"casing and when 5000 psi was used for this load the actual design safety factors passed the COP design standards. Need for Change Since Cassin#1 is an exploratory well there is uncertainty with the frac treating pressures. The initial 5000psi that was chosen for a maximum treating pressure has now been changed to 6000 psi to allow for this uncertainty and to give ConocoPhillips the best chance of 3 successful fracs. With the increased maximum treating pressure to 6000 psi, the actual design safety factors for the 7" L80 26# BTCM casing fall below the COP design standards,meaning a change to the design is required. Summary of Proposed Changes The current 7" L80 26"BTCM casing from TD to surface is going to be changed to: 1. 7" P110 29"BTCM casing from TD to 5100' MD (100' above top production packer) 2. 7"L80 26" BTCM casing from 5100' to surface Changing the casing from 26# L80 to 29# P110 across the interval that is going to potentially see the new 6000psi frac screen out load(TD to 5100'), changes the actual design safety factors so that they pass the COP design standards. Cassin#1 —NPRA Exploration Page 2 of 3 MOC to Casing Design(3/14/2013) a*,- Ailz.41.)D Conoch liii s p Risks of Change Changing the casing design creates new risks, the risks and risk mitigations are documented below: Running order of casing—Now that the casing design consists of two different strengths of casing there is a risk of picking the casing up in the wrong order. To mitigate this, the P110 casing that is to be picked up first will be loaded into the pipe shed last so that it is on the top of the pile and therefore will have to be picked up first. This procedure will be reviewed with the supervisor. Metallurgy/H2S—P110 pipe is a higher strength pipe but with higher strength comes greater susceptibility to H2S since it is so much harder. Cassin#1 is in an area this is normally not sour service based on offset wells. The well has reached TD and no H2S was encountered making P110 appropriate for use. Inspection of Pipe—The P110 pipe that is travelling to location was purchased new in June 2012. The pipe has been stored since then in Fairbanks. When the pipe gets to location all joints will be drifted and all threads inspected prior to being picked up to be run in the hole. The P110 pipe had a cold temp Charpy test done at-50 F and the results passed ensuring the pipe is suitable for artic conditions. Also, all associated mill certs have been received with the new pipe. Cassin#1 —NPRA Exploration Page 3 of 3 MOC to Casing Design(3/14/2013) d«SStn*( Regg, James B (DOA) From: Doyon 14 Tool Pusher[n1416@conocophillips.com] ?c 3/Z6//3 Sent: Sunday, March 24, 2013 7:27 AM r To: DOA AOGCC Prudhoe Bay Subject: Cassin 1 BOP test 3/23/13 Attachments: Cassin 1 BOP test 3-23-13.xls; D141_4 inch.pdf; D141_4 inch -part2.pdf; D141_3.5 inch.pdf Only one failure. Manual Kill line valve leaked on the initial test. Functioned, serviced, and retested same. Retested good. 1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regqaalaska.gov AOGCC.Insbectors aC�alaska.gov phoebe.brooksalaska.gov Contractor: Doyon Rig No.: 141 DATE: 3/23/13 Rig Rep.: John Piper Rig Phone: 670-4966 Rig Fax: 670-4990 Operator: Conoco Phillips _ Op. Phone: 670-4963 Op. Fax: 670-4983 Rep.: Guy Whitlock E-Mail n1334@conocophillips.com Well Name: Cassin#1 PTD# 2121820 • Operation: DrIg: Workover: Explor.: X Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250/3500 - Annular: 250/3500' Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P - Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P • PTD On Location P - Hazard Sec. P Ball Type 1 P - Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper _ 0 NA Trip Tank P - P - Annular Preventer 1 13 5/8'" P - Pit Level Indicators P P #1 Rams 1 3 1/2"X 6" P - Flow Indicator P P - #2 Rams 1 BLINDS P - Meth Gas Detector P - P - #3 Rams 1 2 7/8"X 5" P H2S Gas Detector P P - #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8"x 5K P - Inside Reel valves 0 NA HCR Valves 2 3 1/8"x 5K P Kill Line Valves 1 3 1/8"x 5K FP ✓ Check Valve 1 3 1/8"x 5K P ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P ' CHOKE MANIFOLD: Pressure After Closure 1700 - P Quantity Test Result 200 psi Attained 52 P - No. Valves 14 P - Full Pressure Attained 206 , P Manual Chokes I P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P - Nitgn. Bottles(avg): 5 btls @ 1975 psi CH Misc 0 P - ACC Misc 0 NA Test Results Number of Failures: 1 Test Time: 7.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested with 4" & 3W test joints. Tested Rams, choke valves, and Annular 250/3500. All tests were held 5 minutes each. Manual Kill Line valve leaked. Functioned, serviced, and retested. Retested good. 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 3/22/13 • Time 1500 Witness Test start 14:15 PM - Finish 21:15 PM Form 10-424 (Revised 03/2013) Cassin 1 BOP test 3-23-13.xls • HR. ��30 M. I1i 11 t0/ 7 0io4le Wi _.:.mss r011'1//0 I0' °Al1l. 00000__•i,0_o0 10•1-_1 0- _1„.1i1_010°„-/of,..I. .,1:010..A-1111#1.1=11=.1-1.S1-N...Ii1—,N.1■m,WM.•,=,..:I•,1N.1.7 / 0 - WI7 ,1..b.•7'i. f '�' .. 11 I I1,1°0IW1/.i17%r .;„,4.4 ,,N o‘",., .N1„1\c1/4 1.‘11\101\11\ //; 0i -, .. . _ „0„0 o, 01 .14••1•,„•1,,N•11111-•z rejl�i 11111i \E �� O CO* i _ ,--• p -Cr) ', A., i yj,/ ' / 0001 0111111=111ingar , 0 \ 00 110 .0111111rallrre..1111144•41Witt* \,..,,\-'' s'‘•-• \ ,--. 'i 1/4 o\ \\, <4 \ 4 m ' - =--r 11 ,0001671.11111 00:111111406.4 \ 4 40 oirSrliaxio4 -.4044 \ \” "' 4 . , // ' . 0 , //, 804MMIpit .4 : - z , ,44011•0.9 . 410,w , �0 \ ' _ O Z m I_ o Hil adw f O i 1 , r:. \ , il -1111*,,,, Po. - • ,,,, ,, „.5.,67..,:,:0:01 ::*/ o`- �\\ ** - - `T/�/ "� 00 . 0\ _.. - r X / 0 \\, \ \ . 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O oo�oo a ` .- bs'nN.1 I i it;to --. - . , , -.-- 6000 -'SSP : ", ' W.„' . / • , I. ! •• 5000 �, 4I' ; . • , 4 A0p0 1 �4 - f N 13000 ,-• ..,,. 41*IIP --__. ----- 2600 - = 4tiap i% •�1` AM 11011111%%imimim:-0-- - 14 SV Pr-f Z1Zj$Z.0 3/3 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 19, 2013 2:29 PM To: 'Lee, David L' Cc: Bettis, Patricia K(DOA); 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)' Subject: RE:Cement Top Justification for Cassin 1 (PTD 212-182) David, We have reviewed the OH logs/ mud log and concur that there are no significant hydrocarbon zones in the referenced depths of 2430' and 2588' md. You have approval to continue with the approved cementing plan and bring the TOC to 500ft above the Cassin sand. These upper zones ( Colville and Nanushuk) near the surface casing do not need to be isolated with cement. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Lee, David L [mailto:David.L.LeeAconocophillip' .com] Sent:Tuesday, March 19, 2013 12:28 PM To: Schwartz, Guy L(DOA) Subject: RE: Cement Top Justification for Cassin 1 (PTD 212-182) as requestedlog Guy, here is the mud from surface to TD and the LWD data. Let me know if you need anything else. DL From: Schwartz, Guy L(DOA) [niailto:guy sc i vyartz t,aiaska.gov] Sent: Tuesday, March 19, 2013 11:25 AM To: Lee, David L Cc: Davies, Stephen F(DOA); Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: Cement Top Justification for Cassin 1 (PTD 212-182) David, Please send the Mud log and actual OH logs ASAP. Thanks . Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 1 907-793-1226 office From: Lee, David LRidlitO.Davicl,L.i_c:t aconoco llWi ,5.(_Oill Sent: Tuesday, March 19, 2013 10:10 AM To: Schwartz, Guy L(DOA) Cc: Hyden, Brittney B; Alvord, Chip; Jolley, Liz C; Brassfield, Tom 3; Smith, Kent W Subject: Cement Top Justification for Cassin 1 Morning Guy, When drilling the Cassin#1 location,mud loggers observed shows at 2430'(Colville group)and at 2588'(Nanushuk). The attached slides show the description of the shows and the justification why ConocoPhillips does not believe that these zones are significant hydrocarbon bearing zones. Since we do not consider them significant hydrocarbon bearing zones ConocoPhillips does not plan to cover these zones with cement. Our planned cement top is to be 500'above the Cassin sand. The Cassin sand top came in at 5207', making our planned cement top at 4707'. Please let us know if you are ok with this plan as the cement job should be getting pumped sometime this evening. Also,if you need anything else just let me know. Thanks David 2 ow _ V77:I0 0'VW f it ll'rP u, CO 0 0i1 1 28'00 2700 26'00 2500 240p co, illoiliht_ 11) 4i 7Aihi.k.,,,,„a, adll. ii V) ri) ,:, . ,4_, 73 Z O CD o s .-. i _... O Q 0r 1 O 01 4 Iit U P I Ig , c t7c M'I 72M Cl. � o 0 f r ti �..� n aq w O C , oCD • • • • • N • • • • N z o 0 0 o 0 0 o 0 n- = fD * O , N Q = m UJ fD 0 (Ao O D cn —s (D C 0) ets O N el- O x A 0) O r ( N, A C CD -0 O+ N' 0) -. N -0 :• N �O -j .1. .D V !-+ O r-r n V 7C- Q. 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Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 19, 2013 11:13 AM To: 'Lee, David L';wsvejnoh@blm.gov Cc: Alvord, Chip;Jolley, Liz C; Brassfield,Tom J Subject: RE:Casing Design Change for Cassin#1 pro 24z - I52- David, The change from L80 to P110 casing for the lower section of the well completion does not significantly change the completion geometry. The change is approved by the AOGCC and will be noted in the wellfile. I am assuming you are not basing the burst rating for the casing to include any support from the cement behind it and using P110 will definitely give you more breathing room. The sundry for the frac (313-072) already specified a max treating pressure of 6000 psi. I am holding on to the fracture stimulation sundry until the casing is set and I get a CBL/ MIT report on the completion. I can turn it around very quickly once I have that info. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Lee, David L [n ailto_David.LLee: conocophiilips.corn] Sent:Tuesday, March 19, 2013 10:23 AM To: Schwartz, Guy L(DOA); wsvejnoh a.bim.gov Cc: Alvord, Chip; Jolley, Liz C; Brassfield,Tom J Subject: Casing Design Change for Cassin #1 Morning Guy and Wayne, Attached please find the Management of Change document explaining the casing design change that ConocoPhillips is making to the production casing string on Cassin#1. We will be running the 7"casing this afternoon so please let us know if you have any issues with the casing design change. Also,if you need any further information please let me know. Thanks David Lee 1 0 m� i 0 m 3 PRL JRE o P3 N Z 0 II n N to n o 0 o a o 0 o r m N po �? to 3 O o 0 0 0 0 0 o co mi I m -tea `° n o' I m 7 3 -°a o c 5 z 0 CD i` * 0 0 of a C 0 - =. CA _ � U — � u, to ,�-1,, x W C m () N N ( N . o cn L 1 V < 3 rt CC) m m ap 3. O N z CO . 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CO CO CO Ca w c,., Q 3 1 C �C) co O O 0 0 CD 0 0 0 0 0 CD O cn 0 \ C Cl) X N NJ 01 01 (P 01 01 01 (P 01 ' E7 - (P O O O O O O O O O O ,-,•Nr ET C x0 R ' r o -4 c o rncr, A co N -- (n c - < ��33 c 0 n_ f[ I WAD -0 = C 44 1�l NCD � v e r, - (0 0 v N U • , O co -.1\ C -4 CD C �� \ 3 co St , `O 1 tho (A OCOCOODOJvO) OCP CP AA CoW W NNS X000 � � � A. 0 0 0 0 0 0 0 0 0 0 0 0 000 O O O O O O (PO 0 5' N C V co a 3 0 w .. _______ et fa LONE 11KICK TOLERANCE SURFACE CASING SEAT p MAX PPG KICK TO SHUT-IN WITHOUT FRACTURING CASING SEAT MAX PPG = (EMW test- MW) x TVD shoe-TVD well* _( 12.0 - 9.8 ) x 2,378' ÷ 6,500' = 0.80 ppg *Formula from IADC Certified Well Control School Kill Sheet ,n Kick Analysis Criteria Casing Depth: 2,378' (TVD shoe) EMW test: 12.0 #/gal Mud Weight @ TD: 9.8 #/gal (MW) TD: 6,500' (TVD well) 1.L- Checking The Calculation: Shut In Casing Pressure 0.80 x 0.052 x 6,500' = 272 psi Hydrostatic At Shoe 9.8 x 0.052 x 2,378' = 1212 psi Total Pressure on Shoe 1211.83 + 272 = 1484 psi Gradient on Shoe 1484 - 2,378' = 0.624 psi/ft Equivalent Mud Weight @ Shoe 0.624 0.052 = 12.0 ppg CdSS I Regg, James B (DOA) From: Doyon 141 Company Man [n1334@conocophillips.com] Sent: Thursday, March 07, 2013 6:47 PM �7 To: DOA AOGCC Prudhoe Bay \\e/r510(3 Subject: Doyon 141 BOP Test charts Attachments: BOPE Test 3-7-13.pdf; BOPE Form 03-07-2013.xls Attached are copies of the test charts for the BOP test conducted on Cassin 1 on 3-7-13 as requested. Thanks, Dave Doyon 141 Drilling Supervisors Larry Hill/Dave Coates/ Scott Heim 907-670-4963 Office 907-670-4976 Doghouse n1334@conocophillips.com E Mail 1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION '305 BOPE Test Report Submit to: iim.reggCa�alaska.qov AOGCC.Insoectors(a�alaska.gov phoebe.brooksa,alaska.gov Contractor: Doyon Rig No.: 141 DATE: 3/7/13 Rig Rep.: John W. Piper Rig Phone: 670-4966 Rig Fax: 670-4990 Operator: Conoco Phillips Op. Phone: 6704963 Op. Fax: 670-4983 Rep.: Larry Hill E-Mail n1334@conocophillips.com Well Name: Cassin#1 - PTD# 2121820 • Operation: DrIg: Workover: Explor.: X Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 - Annular: 250/2500 - Valves: 250/3500 _ MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P - Well Sign P • Upper Kelly 1 P - Housekeeping: P Drl. Rig P - Lower Kelly 1 P - PTD On Location P , Hazard Sec. P . Ball Type 1 P - Standing Order Posted P , Misc NA Inside BOP 1 P - FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P - P Annular Preventer 1 13 5/8" P - Pit Level Indicators P , P - #1 Rams 1 3 1/2"X 6" P - Flow Indicator P _ P _ #2 Rams 1 BLINDS P - Meth Gas Detector P - P - #3 Rams 1 2 7/8"X 5" P - H2S Gas Detector P - P - #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8"X 5K P - Inside Reel valves 0 NA HCR Valves 2 3 1/8"X 5K P - Kill Line Valves 1 3 1/8"X 5K P Check Valve 1 3 1/8"X 5K P ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2950 - P ' CHOKE MANIFOLD: Pressure After Closure 1800 P Quantity Test Result 200 psi Attained 34 - P - No. Valves 14 P - Full Pressure Attained 197 - P - Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P - Nitgn. Bottles (avg): 5 Blts. 2150 psi. CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 ✓ Test Time: 5.5 'Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.lnspectors@alaska.gov Remarks: Justin Miller with BLM Witness the test. Tested with 5"test jt. 250/3500 Rams and valves, Tested annular 250/2500. All test were held 10 mintues ea. 24 HOUR NOTICE GIVEN YES X NO Waived By Lou Grimaldi Date 3/3/13 Time 19:25 Witness Test start 10:30 Finish 14:00 '( & i krrACt-fEA 10-424 (Revised 03/2013) 2013-0307_BOP_Doyon141_Cassin-1.xlsx 11Lat\t41 - Ck--%n Vit 30 M. 2(z iSw �- PI I/3 5o 0M • � ��+. `SSM. W 1 g 1 iNV••i••0 0 ro./00. 1.°121•wirA•i•••.•pa in mi i.a ra I.1.I.I 1.111 I I.I Vird.,m 1 i i m i i 1 4 p'.I•I I.1 i i•wa.41.1%11. 11P431.441 I 414,14 11111111g 1 li NI go III1A . 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IIIIN1t1N�� o �4 �i 11 14 ,. 1 n ill �� ♦, ego ♦ I � I � �� ' I,�111���to\ 00„." 1 �� Ill are•moo(,),070, 1/0" St \ ♦ � t 1110 Orsz= . / 01/ moi ♦ / 1 _.,44.137,40,..7-.....„,....v„?,k. ,\,... 4,., ... ..„7„:„.„...............poo 000°. 111;ifter,AVM m=1/11011 _., 4\41111Iii 1711111re MIIM IN jr=minol:(1)( iiiii" 411 .4111iiiimr AIMMININEW=ligigilial /Ad°\. ',,,,,„:7411, 4,........w ......atergiovioW z 11.11 '1.-4•0114°111.' 0,....'"•= 0,1: 001. IIF..1 - 111woit OF ,,w��\\1%%%sem THE STATE Alaska Oil and Gas = � °fALAS :A .,,�„� _ Conservation Commission '-�t _ __ GOVERNOR SEAN PARNELL wk 333 West Seventh Avenue O , �. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Wildcat Field, Wildcat Pool, Cassin#1 ConocoPhillips Alaska, Inc. Permit No: 212-182 Surface Location: 1106' FSL, 1502' FWL, SEC. 28,T12N,R1W, UM Bottomhole Location: 1106' FSL, 1502' FWL,SEC. 28,T12N, R1W, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 7---2PLL'Dit,L-- Cathy P. F erster Chair dk— DATED this �D day of January,2013. cc: Department of Fish&Game,Habitat Section w/o encl.(via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA AU OIL AND GAS CONSERVATION COMMIE ."1 PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑, . Lateral ❑. Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑., • ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory ❑., - - Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Bond No. 5952)SO ,1111°` 5752570 Cassin#1 ' - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 700 G Street ATO15-1552 MD. 6500' ' TSD: 6500' ' 4a. Location of Well(Governmental Section): \p ' 7.Property Designation(Lease Number): Wildcat Surface: Sec.28,T12N-R1W• Ulyllt}i ` \� ; AA 081754 j/ Top of Productive Horizon: 36,'fr.---57.,) /5-0.2- F�i_- 8 Land Use Permit: 13.Approximate Spud Date: Sec.28,T12N-R1W• 953096 2/15/2013' Total Depth: t/,eY. Liar ( 1,4%""( 9.Acres in Property: 14.Distance to Nearest Prope • Z Sec.28,T12N-R1W• j. ib.13 5600 acres '`( -Wmlles tlbol� 4b.Location of Well(State Base Plane Coordinates-NAD 27): S 1il""'�e 10.KB Elevation above MSL:118 • feet 15.Distance to Nearest Well Open Surface' x-234,064.76 y-5,986,368.01 Zone-Same-ag'sur aace GL Elevation above MSL: 88 • feet to Same Pool: None 7'-6.41/Z S`�f-�5 '� AD /•/o./3 16.Deviated wells:N/A. Kickoff depth: feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 Q51 3ol,�geU Maximum Hole Angle' degrees Downhole: 2590 psi Surface: j5 1:01-1/ S 111 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 24" 16" 63# H40 Welded 108' Surf Surf 108' 108' Pre-Installed 12 1/4" 9 5/8" 40# L80 BTCM 2488' Surf Surf 2488' 2488' 758 sks of IiteCrete and 351 sks of class'G' 8 1/2" 7" 26# L80 BTCM 6500' Surf Surf 6500' 6500' 258 sks of Class'G' • 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft). Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface RECEIVED Intermediate Production NOV l 8 2012 Liner Perforation Depth MD(ft): Perforation Depth ND(ft). /►OGCC 20. Attachments: Property Plat 2 . BOP Sketch ❑ Drilling Program Q• Time v.Depth Plot ❑ Shallow Hazard Analysis' Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑, - 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: Date I 22. I hereby certify that the foregoing is true and correct. David Lee 263-3741 Contact David.l.lee@conocophillips corn Email Printed Name Chip Alvord Title Drilling Manager 1 Signature A_C . A Phone 265-6120 Date 21(2-10. I 2-- Commission Commission Use Only Permit to Drilln API Number: Permit Approval' I Ii d4,0 1d_ See cover letter for other Number: oC J `2 iv, 50-(03- a 06(03 -00-Oo Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: ii 3-COO f5 4 6 P �s t� Samples req'd: Yes 0 No❑ Mud log req'd:Yes[�j No❑ ,' Vilee--k. 1-1),-;1(t •,-....-.),.....1.,,v-..7 -1'o Cps-n��Ss.r4J2S measures: Yes [►� No❑ Directional svy req'd:Yes❑ No Q �J` �� Ts Spacing exception req'd: Yes❑ No p' Inclination-only svy req'd:Yes j' No❑ r ' f G w`�� �r r4�.-L:L �T4ht '�'� £ __r,aw z . I APPROVED BY Approved by: �-.�-- COMMISSIONER THE COMMISSION Date:/ -/b 1 Y /' 3 ,_ { Q ! Submit Form and Form 10-401(Rev�d 10/2012) This permit is valid for 24 months from'the date of approval(20 AAC 25.005(g)) ttaacc mets in Duplicate \�' w 1- 0 0 0 d J V �S Q -28 07 O Q — ,st a_ N 0 dO O 00G0N 8 a � > ` ;o aoC m .� IT, o] o N O 0 E N E O -1 - N -79 o) ,- I _ INH y Vd N Oy J N d C E C - 'aci to E I c7,z"- y.9 v o dU aoo.c II oca pp . F 0- o' v i-- J nA C K 0?0 m. C C m ac' E 0 oco 'iii 'i0 i•'i•i•.•i ..•p••••l IN 4E ♦ • a)tu ° .N . U) t CU t ••••• • • 1111.4441 e y N N - d m d a ° a x u 11 _ 0 to = o 0 U fo Co O o co0 co 0 v t U a + ° x o d. o m 0 o < o U o o m _2 ♦ _1N v ♦ • v 03 8 0 CO 1 s v o 0 O N 0 1S3 8 ° N Zo Et Eo co c- 03 O in on Lc, '0 2Nr fo co -o cnA ll N {Co C o cO Nco co b co S 5 w c . 2 Y w N 41) N CO 0 o] Z 0 [� CO 1- 4 ., 7 i u RECEIVED ConocoPhillips NOV 282012 Post Office Box 100360 AOGCC Anchorage,Alaska 99510-0360 November 15, 2012 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Cassin #1 Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory well Cassin#1. This vertical delineation well will be drilled off an ice road/ pad originating from 2L Pad using Doyon Rig 141. The objective of this well is to confirm the presence of the Cassin, Blackburn and Sanford sands, penetrate them, and then conduct an evaluation program. A Geopressure and Shallow Hazards analysis was undertaken in preparation for drilling this well. As indicate in the attachments, the drilling program calls for drilling 12-1/4"surface hole to approx. 2488' MD/TVD, followed by an 8-1/2" production hole section to approx. 6500' MD/ TVD which will penetrate all the potential sands. The evaluation program in the production hole section of Cassin#lwill consist of obtaining RDT fluid samples in the targeted sands, followed by a wireline logging program. The well will then be cased, completed and each of the sands will be perforated, fractured, stimulated and flow tested individually to gather data on inflow performance and fluid properties. After the testing has been completed the well will be suspended in accordance to the regulations. The planned spud date for Cassin#1 is February 15, 2013. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact myself at(907) 263-3741. Sincerely, David Lee Senior Drilling Engineer Appli for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 Permit It — Cassin #1 66 it Application for Permit to Drill Document , MaxWell t�lpxirnize Well VQIur Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(? 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10. Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11. Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 12. Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13. Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 Cassin#1 APD Prepared by:David Lee Page 1 of 7 P, Printed:27-Nov-12 L) L I Appli for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15. Attachments 7 Attachment 1:Location Maps 7 Attachment 2:Directional Plan 7 Attachment 3:Drilling Hazards Summary 7 Attachment 4: Cement Summary 7 Attachment 5:Shallow Hazard and Pore Pressure Conclusions 7 Attachment 5:Seismic Analysis 7 Attachment 6: Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as Cassin#1. This will be an exploratory delineation well 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (2)a plat identiffing the properly and the property's owners and showing (A)the coordinates of the proposed location of the well at the sunface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for tins state as maintained by the National Geodetic Survey m the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth•and(D)other information required by 20 AAC 25 050(b); Location at Surface ' 1106' FSL, 1503' FWL, Sec 28,Twn 12 N,Rg 1 W NAD 27 RKB Elevation 118'AMSL Northings: 5,986,368.03 Eastings: 234,064.76 Pad Elevation 88'AMSL • Location at Top of Productive Interval 1106' FSL, 1503' FWL,Sec 28,Twn 12 N,Rg 1 W #1 (Cassin) NAD 27 Measured Depth, RKB: 5,395' Northings: 5,986,368.03 Eastings: 234,064.76 Total Vertical Depth, RKB: 5,395' Total Vertical Depth, SS: 5,307' Location at Top of Productive Interval 1106' FSL, 1503'FWL,Sec 28,Twn 12 N,Rg 1 W #2(Blackburn) NAD 27 Measured Depth, RKB: 5,665' Northings: 5,986,368.03 Eastings: 234,064.76 Total Vertical Depth, RKB: 5,665' Total Vertical Depth, SS:_ 5,577' Location at Top of Productive Interval 1106'FSL, 1503'FWL, Sec 28,Twn 12 N,Rg 1 W #3(Sanford) NAD 27 Measured Depth, RKB: 5,840' Northings: 5,986,368.03 Eastings: 234,064.76 Total Vertical Depth, RKB: 5,840' Total Vertical Depth, SS: 5,752' Location at Total Depth 1106' FSL, 1503' FWL, Sec 28,Twn 12 N,Rg 1 W • Cassin#1 APD Prepared by:David Lee Page 2 of 7 '`1 l '" ►. P Printed:27-Nov-12 ..f . ore � L4 . Appl' for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 NAD 27 Measured Depth, RKB: 6,500' • Northings: 5,986,368.03 Eastings: 234,064.76 Total Vertical Depth, RKB: 6,500' • Total Vertical Depth, SS: 6,412' Plats showing the Ice Pad Configuration and Proposed Ice Pad and Ice Road Route are included. NOTE: Location coordinates on maps are in NAD 83. Please refer to Attachment 1: Ice Pad Configuration&Proposed Ice Pad and Ice Road route Requirements of 20 AAC 25.050(b) If a well is to he intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat.drawn to a suitable scale,showing the path of the proposed wellbore,Including all adjacent wellhores within 200 feet of any portion of the proposed well; Application is for vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore. Please refer to Attachment 2: Directional Plan. and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. N/A—Application is for a vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(e)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application• (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; Expect normal with possible light overpressure(1268 psi)starting at top of Nanushuk section at 2568' TVD. Equivalent Mud Weight @ Nanushuk= 1268 psi/(2568'*.052)=9.5 ppg Equivalent Mud Weight @ Cassin Sand =2385 psi/(5395'*.052)=8.5 ppg Equivalent Mud Weight @ Blackburn Sand =2500 psi/(5665'*.052)=8.5 ppg Equivalent Mud Weight @ Sanford Sand =2590 psi/(5840'*.052)=8.5 ppg The maximum potential surface pressure(MPSP)while drilling Cassin#1 is calculated using the predicted 2,590 psi reservoir pressure,a 0.11 psi/ft gas gradient and Sanford sand top TVD of 5840' ft. MPSP =FPP—(0.11 x TVD) MPSP = 2590—(0.11 x 5840) = 1948 psi (B)data on potential gas zones, The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking, Cassin#1 APD Prepared by:David Lee Page 3 of 7 r Printed:27-Nov-12 Appl' for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 3:Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the follotiring items,except for an item already on file with the commission and identified in the application• (5)a description of the procedure for conducting formation integrity tests.as required under 20 AAC 25.030(0, Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. Cassin#1 APD Prepared by:David Lee Page 4 of 7 Printed:27-Nov-12 Appl" I for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application• (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted finer,pre perforated liner,or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Pre-installed 16 24 62.5 H-40 Welded 108 Surf 108/108 Cemented to Surface with 9 5/8 12 1/4 40 L-80 BTCM 2488 Surf 2488/2488 760 sks Arctic LiteCRETE Lead 11.09 ppg, i 355 sks Tail Slurry'G'15.8 ppg Cement Top planned @ 4895'MD/4895' 7 8 1/2 26 L-80 BTCM 6500 Surf 6500/6500 ND. Cemented w/ 260 sks Class"G"15.8 ppg Please refer to Attachment 4: Cement Summary 7. Diverter System Information Requirements of 20 AAC 25.005('c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application. (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application• (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using water based mud systems having the following properties: Surface 108'—2488' Mud Type Density(ppg) 10.0" 1/ Funnel Viscosity(seconds) Yield Point(cP) 40-80 API Fluid Loss(ml/30min) NC—< 10 Chlorides(mg/1) <1000 pH 8.5—9.5 Production 2488'—6500' Mud Type K -ld Density(ppg) 9.8 _ Low Shear Rate Yield Point(LSYP) - • (lb/100 ft^2) API Fluid Loss(m1.30min) <6 pH 9.5— 10.0 Drill Solids(% V/V) <7 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Cassin#1 APD Prepared by:David Lee Page 5 of 7 = Printed:27-Nov-12 App' i for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(t): A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this V well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an iter:already on file with the commission and identified in the application• (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a), A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig.or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(h), N/A-Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Pernut to Drill must be accompanied by each of the following items,except for an item already on file irdli the comnussion and identified in the application (12)evidence showing that the requirements of 20 AAC 25.025(Bondinglhave been met. Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program for Cassin#1 is listed below. J 1. MIRU Doyon 141 on Cassin#1 conductor•� 1 sc I 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and drill vertical 12-1/4"hole to the 9 5/8" surface casing point(2488' MD/2488' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 9 5/8"40#L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if re�c uired to , g bring cement to surface. /----- 1/04-:-r-Lt 1 re-- ^r_ 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE,install 3-1/2"x 6"VBR's, test to 250/3500 psi. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform FIT up to 16.0 ppg EMW FIT . (minimum acceptable 13.5 ppg EMW) 9. Drill vertical 8 1/2"hole to 6500' MD/6500'TVD. Run MWD/LWD logging tools in drill string as required • for directional monitoring and formation data gathering. Cassin#1 APD Prepared by:David Lee ' Page 6 of 7 vni '' Printed:27-Nov-12 1 �"7 b-. 1t i : f Appf i for Permit to Drill,Well Cassin#1 Saved:27-Nov-12 10. POOH with DP and stand back. R/U and run wireline logs. 11. Perform wiper trips as hole conditions dictate between logging runs. r„a/ ra 12. POOH and R/D wireline. Close blind RAMS,change 3-1/2"x 6"VBR's to 7"RAMS,test to 250/3500 psi. RU and run 7"26#L-80 BTCM casing to 6500'MD/6500'TVD and cement. ,, 13. Change upper pipe RAMS f/7"to 3-1/2"x 6"VBR's,freeze protect well. 14. P/U BOP test equipment. Test BOPE to 3,500psi.Record the results.Test 3-1/2"x 6"VBR's to 250/3500 psi. 15. LD 5"DP and PU 4"DP with casing scrapping BHA. 16. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results. 17. Perform casing scrapper run and displace casing to filtered brine. 18. POOH with DP and stand back,L/D BHA, 19. R/U and perform CBL,L/D CBL tools 20. R/U and perform Eline perforating,R/D Eline perforating 21. R/U Deburring BHA and perform deburring run on DP,rack back DP and L/D deburring BHA Set_ 22. R/U lower completion and RIH on DP,drop balls to set packers. ;o� Co rn/ 23. Test top packer,release setting tool and POOH and lay out DP. ' el- 24. RIH with upper completion and land tubing hanger and pressure test tubing hanger to 5000psi and two way check valve to 3500psi. 25. N/D BOP and rig down and move out rig. 26. After Rig is off location well fracturing and testing will commence. �� P Please refer to Attachment 6: Well Schematic. �r+ 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) . An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the conwussion and identified in the application: (14)a general description of how the operator plans to dispose of drilling niud and cuttings and a statement of whether the operator intends to request autliarcat,on under 20 AAC 25 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II ' disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary • storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. A cuttings pit will be constructed on location as a secondary plan for cuttings disposal in the event that Phase 2 or 3 • weather conditions prevents the hauling of fluids off location to disposal facilities. 15. Attachments Attachment 1:Location Maps Attachment 2:Directional Plan Attachment 3:Drilling Hazards Summary Attachment 4: Cement Summary Attachment S:Shallow Hazard and Pore Pressure Conclusions Attachment 5:Seismic Analysis Attachment 6: Well Schematic Cassin#1 APD Prepared by:David Lee Page 7 of 7 Printed:27-Nov-12 t Running Lower Completion Procedure 1. Strap and record the dimensions (ID, OD, and Length) of each piece of equipment prior to RIH. 2. Rabbit all 3-1/2" tubing with 2.867" teflon drift. 3. Pick up lower completion NOTE: Ensure that pipe dope is applied to the pin only. Jet Lube Run-n-seal for EUE connection. 4. After the first packer is picked up, do not exceed 90 seconds per stand to prevent surging. 5. Record P/U and SIO weight of lower completion after making up the liner setting sleeve. 6. TIH with the lower completion on 4" DP to position the upper most Premier packer NOTE: Install the Halliburton RA sub after running the 1st stand of DP. 7. R/U the Halliburton E-line unit and PCE 8. Strip the E-line through the PCE and test the line for continuity. 9. M/U the Gamma Ray logging tool and pull the string into the lubricator. 10. M/U the PCE to the TIW. 11. Close the TIW and pressure test the PCE to 3,500 psi for 10 minutes. 12. Bleed of the test pressure and open the TIW. 13. RIH, and locate the RA tag in the DP. Log while pulling out of hole and correlate the perforation depths using the Gamma Ray signature, the RA tags in the 7" casing and the Tie-in-Log for reference. 14. Correlate the correct depth for the production packer. 15. POOH and R/D the E-line equipment. 16. Adjust the lower completion assembly depth as per the correlation requirements. 17. When the CPAI representative and Baker Hughes Supervisor are in agreement that the packers are on depth, set the slips. 18. R/U circulating sub and pressure test all lines to the rig floor to 5,000 psi. 19. With the lower completion assembly in place and the DP full, break circulation to ensure there is no restriction. 20. Break the line at the TIW valve and drop a 1" steel setting-ball. Allow sufficient time for the ball to gravitate to seat. NOTE: Caliper the ball before dropping it to make absolutely sure it is the correct size! 21. When ball reaches the seat, perform a low-pressure tubing test of 500 psi. If pressure cannot be maintained, reverse circulation may be required to clear ball seat of debris. If pressure still cannot be maintained, consult with the BHI Supervisor and the Completion Engineer for the appropriate action. 22. With the ball on seat, pressure up on the tubing slowly to 2,500 psi. Hold pressure at 2,500 psi for 5 minutes and then pressure up to 4,000 psi in 500 psi increments holding the pressure for 5 minutes at each increment. 23. Bleed the tubing pressure to zero and perform a 20,000 lbs pull test on the production packer to ensure the packer slips have engaged the casing. 24. Pressure test the IA to 1,000 psi and hold for 5 minutes to test the top of the packer. 25. Bleed the IA pressure to zero. 26. Slack off 20,000 lbs and pressure up the tubing to 2,700 psi to hydraulically release the setting tool. 27. P/U to insure the setting tool has released from the setting sleeve. NOTE: If the setting tool does not release hydraulically, slack off and initiate the mechanical release by rotating 1/4 turns to the left at the tool. 28. After confirming the setting tool has released, flow test the well for 30 minutes prior to TOH with the DP and setting tool and L/D same. Running Upper Completion Procedure 1. Hold a safety meeting with the rig crews and all contractors to ensure that the driller and workers in the pipe shed understand the order of installation and how to communicate clearly if there are problems. 2. Change Top Pipe Rams for running tubing completion. Pull wear bushing. Test pipe rams to 250 psi Lo and 4000 psi Hi. Install running tubing bushing. 3. Pull wear bushing. Make up wash tool. Jet wash to clean around the tubing hanger area to ensure no debris 4. MU 3-1/2" Tubing Hanger(FMC) to the TH Running tool and Landing Join. LD same. Note: Drift all the 3-1/2"Tubing with 2.867"Teflon drift. Discuss the importance of drifting all tubing and history or effects of not drifting. Note: Verify that all completion components have been function and pressure tested as appropriate. Ensure dimensions of each component are recorded on the completion tally. 5. Run the completion per the Upper Completion Running Order Table. NOTE: Tubing dope is applied to the pin only. Jet Lube Run'n'seal for the EUE connection. NOTE: Properly make up connection as per make-up specs NOTE: The KBMG Mandrel No.2 (from top) will have DCK2 valve pinned for 2500 psi sheared (casing to tubing sheared) installed and pressure tested prior to arriving on location. The KBMG Mandrel No.1 and 3 will have Dummy valve pre-installed. NOTE Do not exceed 90 ft/min. 6. Make up Schlumberger Solid Gauge Mandrel as per Schlumberger procedure. NOTE: Make up single way plug to TEC-wire as to SLB procedure. Connect to NDPG gauge and pressure test connection (5 min @ 5000 PSI). Check gauge is functioning electrically with Uniconn panel. NOTE: Discuss with Company Reps should the cable be compromised electrically during the installation. If the gauge loses signal while running in hole, the string may be pulled back to find the problem and splice the cable if necessary. NOTE: RIH clamping TEC-wire at every joint. Use Cannon installation tools. NOTE: The driller and rig crew need to ensure that the down hole cable is not damaged. NOTE: Avoid setting Slips on cable; slow down while setting slip, the hole cover is removed before going down after making up cable protector. NOTE: During the running of the tubing Schlumberger hands will be on the drill floor at all times. 7. Lower upper completion string until an indication is seen on surface that indicates that the seals are entering the seal bore, then pick-up 10 ft. 8. Make up string into Top Drive and prepare to displace the well to 9.0ppg kill weight hrine 9. Displace well to kill weight KCI brine and corrosion inhibition taking all returns back to the mud pits. Place inhibited brine between the upper packer and the GLM with the nr.K-2 S()V es follows. • Pump—200 bbls of uninhibited kill weight brine annulus above the GLM no.2. • Pump—90 bbls of inhibited kill weight brine (w/2% CRW-13). This will place inhibited brine in the annulus from the seal assembly to above the GLM No.2 at 5,000 MD. Note: This volume included excess of 10 bbls of calculated volume. 1(1 Monitor the well for 30 minutes to onnfirm the well is static 11. After displacement is complete sting into Seal Bore Extension (SBE) as follows: • Slowly sting into Seal Bore Extension with pumps circulating down the drill pipe at—1 BPM, looking for pressure increase as seals enter SBE. Record surface pressure. Shut down pumps and open bleeder. Do not exceed 10 bbls of pump down to keep the area between packer and second mandrel filled with the inhibited brine. • Slack off to completely insert seal assembly to fully located position. • Mark pipe for calculating space out. 12. Space out with tubing pups to leave locator 5 feet above fully located position. Make up the tubing hanger assembly to the last joint of tubing and orient the completion so the hanger matches up with the centering guide in the tubing bowl. Make up feed through downhole gauge TEC wire as per Schlumberger procedure. Pressure test swagelok fitting on tubing hanger TEC-wire ports to 5000 psi. Chart pressure records. 13. Sting back into SBE (without pumping), land tubing hanger with landing joint A, and Run in Lock Down Screws. Leave landing joint A in place. 14. Pressure test annulus to 1000 psi (do not exceed 2500 psi to avoid shearing DCK-2) to confirm SBE seals are stabbed in. Bleed down annulus. Leave landing joint A in place. 15. Observe well for 30 minutes to confirm that the well is static. 16. Drop ball and rod. Leave landing joint A in place. 17. Pressure test the tubing to 4000 psi for 30 minutes. Chart test. Bleed tubing pressure to 2,000 psi. Pressure test the 4-1/2"x 9-5/8" annulus to 3500 psi for 30 minutes. Chart test. Record pressure tests on MIT forms. Leave landing joint A in place. 18. While keeping pressure on the annulus, bleed down tubing to shear the DCK-2 valve (DCK-2 is set to shear at 2500 psi casing to tubing differential). Bleed tubing and annulus down to 0 psi. 19. Pull and lay down landing joint A. Install 2-way check into tubing hanger. Install landing joint B. 20. Pressure test upper hanger seals(250 psi for 5 minutes, 5000 psi for 10 minutes). (:hart tP.sts 21. Pressure up inner annulus to 3500 psi to test two way check from below(direction of flow) and tubing hanger from below(direction of flow). Chart tests. These pressure tests are required to consider the two-way check and lower hanger seals as mechanical barriers tested in the direction of flow per the COP Well Control Manual. 22. Bleed off pressure on annulus. 23. Pull and lay down landing joint B. 24. Flush stack to clean up if needed. 25. Observe well for 30 minutes to confirm that the well is static. 26. The Company Man will verify the following barriers are present before ND BOP stack: 1) Kill weight fluid in tubing, 2) Kill weight fluid in inner annulus, 3)Two way check in tubing hanger, pressure tested from below, and 4)Tubing hanger pressure tested from below. 27. ND BOPE. NU tree and adapter. Note: Carefully lower the tree with tubing bonnet not to damage the tubing hanger neck. 28. Pressure test the flange connection through the test port located on the tubing bonnet flange to 5,000 psi for 10 minutes. This will test the upper hanger seals from below and the lower hanger seals from above. 29. Rig up lubricator and pull two way check valve. 30. Riq up manifold & hard lines to tubing &annulus. 31. Freeze protect well by pumping annulus(150 bbl)of diesel (±2000 ft TVD). Put tubing and annulus into communication across choke manifold and allow diesel to percolate on the annulus. • 4-1/2"tubing capacity=0.01522 bbl/ft • 4-1/2"tubing x 9-5/8"casing annulus capacity= 0.0562 bbl/ft • Total volume=2,100' MD (2,000'TVD)x(0.01522 + 0.0562) bbl/ft= 150 bbls 32. Shut in well & Riq down lines. 33. Rig up Lubricator&set BPV. 14. SPeurP well 35. Lay down drill pipe& prepare rig for rig. 36. Turn well over to operations via handover form. NOTE: Handover Form must be filled out, signed by all involved parties (Drilling, Wells, & Production), scanned, & posted. Following through on this critical detail will ensure a reliable resource for the Production Engineer to reference during the planning & execution of post rig work. 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Y 0 1e1 V" \iI 101 II-5000 I8-541 /0262391 22.75. /// 1 15778 inm, _ !it d_` '' N A2 i TOOL JOINT 943• — 4=1;%4,4::' '� !0274.6 m I mi 1231,9 mm1 u VAL-5000 MODEL 120 CV ` TEST PORT m', 'r r 0 Is 6.00' f 45.7 mml 12.0' ilffd 143,,8 m1 —�ns2.1 mml(:,=-. - uod.e mm1 —,74.00'--T mm11.57• � 1446.3 mml r 2 O ri '.6.391101,6 mm: 10162.0 nml 010.31• 010.04' i 10261,9 0W 10.75,3 Atm, 16'00 CASING SNORT BOWL PROTECTOR COMBINATION CPPER BOWL F'R T•CASING TEST PLUG CND 935.30 CASING 9-280-402 BOWL PROTECTOR RUN111NG TOOL 48-261-503 `-7'OB CASING r 3Y•OD TUBING 11-5000 THROUGH BORE SYSTEM �........ filll 16 X 9 5/8 X 7 X 3 1/2 122 1319,7immt 25.0 =1A1 !641,35mm1 ITEM II PART NUMBER II DESCRIPTION I 7LIII: a. PI T6068 LANDING RING „ 12I888-0005 2 P176070 CSG HANGERItll3 P176063 CASING HEAD ASSEMBLYIllp4 P176075 TBG RD ASSY 1a1i5 P123277-0002 COG NCR A55Y kjil [�6 12-150-016 PACKOFF ASSY Ii P176120 TOG NCR A55Y 8 P120192-0002 ADAPTER ASSY 9 90-120-566 GV ASSY 6 CASING 10 25-051-394 TEE ASSY INVERTER• HEAD ASSY,IS SL IP-LOC Bio II _02-698-177 ADAPTER ASSY WI FS SEALS 8 21-1/4 211 12 12-090-184 9% C-21 NGR FI G.O.W/ONE 2'IP OUTLET - P125578-0001 0 17 P118334-0005 BELL NIPPLE 14 12-093-112 7 C-21 HGF REFAAragAIITOBi0 0 _O '" 12010100 0 • ��- '"gym 11-5000 COMPLETION rl•y1/W N __=:-.--:-...7-T 16 0 9% X O 3'/, w6'PT QT _ice�1.�.:- CASING PROGRAM ww:v . 01100002760 0 I__*' I CASSIN #1 HARRISON DAY . LOCATED WITHIN PROTRACTED -t�'� SECTION 28, T. 12 N., R. 1 W. 7`2.T. UMIAT MERIDIAN, ALASKA __I__-- -74 PROJECT I I 1106' FSL 1502' FWL I AREA L NAD83 Datum NAD27 Datum .4— — T I- I N 70°21'38.6' N 70°21'39.9" ' V./d I ALPIN W 152°09'49.6" W 152°09'38.2" -i- j ASPC ZN5 ASPC ZNS I _ < � --� (Y) 5,984,784 (Y) 5,985,068 -1-. � (X) 1,866,432 (X) 726,412 __ N 19 - F I _ ---TI--i- PREVAILING VICINITY MAP WIND 3 3 Z2 r `n z LnN N N n oos ai 05 J\ E R r 0 NN \C.-Pp0 U) N in 0oJANEoY� w 14.1 0 v '0 Y.:- '-',- - _ 1-- JJ W -1,),f 1502' - H- lolkI I- 200 t- 0 -J \ R(G�, Mi Z P p,,\"‘ 0 200 ao RSG CASSIN #1 0_ ■ ■ ■ 0 oo, SCALE IN FEET o - . w 0A- Z ZO o 500 O O N O J. >I 0 p0000 �c" hi N 1n m 1106' 1- x w O S Q d w U —I tr) SEC. 28, T 12 N., R 1 W. O SEC. 33, T 12 N., R 1 W. 1 I O I N C.-_l M Q Z REVISION 3 o Q KUUKPIK 2012-2013 NPR-A EXPLORATION < CASSIN#1 (=i PROPOSED ICE PAD CONFIGURATION A ALPINE, ALASKA a all IMIIIII U 139E.51st.Ave,•Anchorage,Alaska99503•(907)273LL833000 DATE: 01/15/2013 DRAWN BY: AG SHEET: 1 OF 2 0 Alpine Office (907)870-4739 H Alpine Survey Office SCALE: 1'=200' CHECKED BY: DB W.O. No: 12-08-05-1 N I ter CASSIN #1 LOCATED WITHIN PROTRACTED 1 HARRISON BAY SECTION 28, T. 12 N., R. 1 W. rq UMIAT MERIDIAN, ALASKA � 1106' FSL 1502' FWL 1 PROJECT . � AREA � NAD83 Datum _ a!1GL��;i/t _` N 70°21'38.6" //� 1 [: ♦rte, W 152°09'49.6" riff ll � si: E� AS PC ZN4 IBIR%fJ-i%�Jizmi �, (��' •e ,,.;,,. (Y) 5,986,110 �t"�ar'�►„ff1 � ?�lrdi -\:; (X) 1,374,097 k ' i 'Intlf�' `` , � . ,„. _i 3 3 VICINITY MAP ft ce zZ N N 1— i_ N N ID N 005 20 cn N \CE PPO o ra I ,M��S` 3 -./p0 1. - 1so2' $ .CASSIN #1\ ', 71` id -z. 200 / 0 No oC4 / o, 0 • 200 •• • •� SCALE IN FEET O �4. o o. 500 Q ‘Li 0 10•000( E S� N 1106' j> SEC. 28, T 12 N., R 1 W. SEC. 33, T 12 N., R 1 W. / r \ /i KU U K P I K 2012-2013 NPR-A EXPLORATION CASSIN#1 Ji : PROPOSED ICE PAD CONFIGURATION s -I€°_- ALPINE, ALASKA _ 139 E.51st.Ave.•Anchorage,Alaska 99503.(907)273-11933 DATE: 11/08/12 DRAWN BY: AG SHEET: 1 OF 2 Alpine Dlfxe (907)670-4739 Alpine Survey Office SCALE: 1”=200' CHECKED BY: DB W.O. No: 12-08-05-1 ill 0 433I ai l Q 0 r' Q�� ! q R W LJ w 3 ON ca — * t)./... 001111112 l IOV�>Q ,V ,� �� ��, QCa Om Q OD N ,\ C• �l , Ct�k ca._ 07 J W 0 H= N V 2Ivc1vf)08 V-11dN 1 •!Y c\ ; Z Y;0 � oJw w r `�` \ �\alr arfy i Z jam X Q z '� / _ '� Y W LJ a 3 0 Y _J Q 'fs7 8� p, r7 o v d z arty q `-, d O N E, 0 U U spa P: 0 I ^ n Z n x z rJy U Co MU O J xwF > r1 `i z� o N<4i U s • �a .0‘,1 co gm _m ir ,<Ii)c."...14 io a. ^ WSJ l W 3 m 1ft, :E : Y 2 i ; Y gua \. ,, 84a arty x gar E,> 1, as a/ Czl / W s/ a/ t,Acry� 9/ t/ arty ©J �,1J' 6/ N �a 1 < I o A2JVONf1O9 rlP . r N . 1N3W33UOV 0 O 3SIl QN`d-I>IIdN(lf1>I �a/f 0 l \ 0 L'� fir �_ \� C W y4 d \ O Z_ Q~ Q o U Q ee\ $s //c50 ` O Q a/ri ' 1e N LA ed cc • 0 a \a . r m /r rl _. - rQW 0 1 y ` �� . R'M W U , UO " cv o scl. ''.._, 0 E a x G ae ra. {�\ar?/y 9�\a/r ? W U l V a Wcv m Be f 2 a M co .5't„,,\ / \ n a \ /. co \a 110J �cu el c� e\a/ r ,7 .- 7; !..);..4,voi OM4j ` 'l/t2J30V3lI30V3111"1LL L S0-80-ZL :3 OWN ONIMVNO OVOO1fV (ct:60) ZLit L/Ol :31V0 ONIllOId HALLIBURTON Project: North Alaska ASP5 WELLDETAIS: Pan:Cassia#1 North American Datum 1983 Alaska Zone 5 • ryDrilling•ervicM Site: Cassin Ground Level: 88.00 SperWell: Plan: Cassin #1 +N/-S+Et-W Northing Easting Latittude Longitude Slot Wellbore: Cassin #1 0.00 0.00 5986110.00 1374096.85 70°21'38.602 N 156°9'49.609 W Plan: Cassin#1 (WP01) REFERENCE INFORMATION Co-ordinate WE)Reference:Well Plan:Cassin#1,True North 0- 0 Vertical(TVD)Reference:WELL @ 88.00ft(Original Well Elev) Measured Depth Reference:WELL @ 88.0011(Original Well Elev) Calculation Method:Minimum Curvature 250- FORMATION TOP DETAILS 500- TVDPath TVDssPath MDPath Formation 1088.00 1000.00 1088.00 Base Perm 1608.00 1520.00 1608.00 K-5 750- 2581.00 2493.00 2581.00 Nanushuk/K3 3878.00 3790.00 3878.00 Torok 5384.00 5296.00 5384.00 Cassin Sand 1000- 1000 5657.00 5569.00 5657.00 Blackburn Sand 5875.00 5787.00 5875.00 Sandford Sand 1250- Base Perm 1500- 1750- K-5 2000- 2000 2250- 2500- 95/8"-- Start 4100.00 hold at 2488.00 MD 2750-- Nanushuk/K3 - CASING DETAILS MD TVD TVDSS Name Size Hole Size 3000- 3000 2488.00 2488.00 2400.00 9 5/8" 9-5/8 12-1/4 p - 6588.00 6588.00 6500.00 7" 7 8-1/2 co 3250- 1 3500- v 3750- E 8) F cu 4000- Torok 4000 4250- 4500.J'. 4750- 5000- 5000 5250- 5500- Cassin Sand 5750- Blackburn Sand 6000- Sandford Sand 6000 6250- 6500- I 7"---- 6588 6750- - Cassin#1 (WP01) 7000- TII n n 1� �II � II � II IjIlllllllll111 f�III IIIIIIIIIIIIIIIIIIII IIIIIII II II �IIIIIIIIIIII IIIIIIIIIIIIII -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 Vertical Section at 0.00° (800 ft/in) ConocoPhillips Alaska U 1\ ConocoPhillips (Alaska) Inc. -Expl North Alaska ASP5 Cassin Plan: Cassin #1 Cassin #1 Plan: Cassin #1 (WP01) Standard Proposal Report 24 August, 2012 HAI-L!BURTDN Sperry Drilling Services ; 4111111111111111 i , Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#1 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: WELL @ 88.00ft(Original Well Elev) Project: North Alaska ASPS MD Reference: WELL @ 88.00ft(Original Well Elev) Site: Cassin North Reference: True Well: Plan:Cassin#1 Survey Calculation Method: Minimum Curvature• Wellbore: Cassin#1 Design: Cassin#1(WP01) Project North Alaska ASPS,Alaska Map System: US State Plane 1983 System Datum: Mean Sea Level • Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 5 - Using geodetic scale factor Site Cassin Site Position: Northing: 5,986,110.00ft Latitude: 70°21'38.602 N From: Map Easting: 1,374,096.85 ft Longitude: 156°9'49.609 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -2.04° Well Plan:Cassin#1 Well Position +N/-S 0.00 ft Northing: 5,986,110.00 ft Latitude: 70°21'38.602 N +EI-W 0.00 ft Easting: 1,374,096.85 ft Longitude: 156°9'49.609 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 88.00 ft Wellbore Cassin#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 8/24/2012 17.50 80.36 57,476 Design Cassin#1 (WP01) Audit Notes: Version: Phase: PLAN Tie On Depth: 0.00 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (ft) (ft) (ft) (0) 0.00 0.00 0.00 0.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°I (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 0.00 0.00 0.00 0.00 -88.00 0.00 0.00 0.00 0.00 0.00 0.00 2,488.00 0.00 0.00 2,488.00 2,400.00 0.00 0.00 0.00 0.00 0.00 0.00 6,588.00 0.00 0.00 6,588.00 6,500.00 0.00 0.00 0.00 0.00 0.00 0.00 8/24/2012 10:54:46AM Page 2 COMPASS 2003.16 Build 69 Q0 . IL. Halliburton -Sperry HALL.IBURTON Standard Proposal Report a 5e !VTAlaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#1 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: WELL @ 88.00ft(Original Well Elev) • ''Project: North Alaska ASP5 MD Reference: WELL @ 88.00ft(Original Well Elev) #Site: Cassin North Reference: True Well Plan:Cassin#1 Survey Calculation Method: Minimum Curvature • Wellbore: Cassin#1 `Design: Cassin#1(WP01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -88.00 0.00 0.00 0.00 0.00 -88.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 100.00 0.00 0.00 100.00 12.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 200.00 0.00 0.00 200.00 112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 300.00 0.00 0.00 300.00 212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 400.00 0.00 0.00 400.00 312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 500.00 0.00 0.00 500.00 412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 600.00 0.00 0.00 600.00 512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 700.00 0.00 0.00 700.00 612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 800.00 0.00 0.00 800.00 712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 900.00 0.00 0.00 900.00 812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,000.00 0.00 0.00 1,000.00 912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,088.00 0.00 0.00 1,088.00 1,000.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Base Perm 1,100.00 0.00 0.00 1,100.00 1,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,608.00 0.00 0.00 1,608.00 1,520.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 K-5 1,700.00 0.00 0.00 1,700.00 1,612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,100.00 0.00 0.00 2,100.00 2,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,200.00 0.00 0.00 2,200.00 2,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,300.00 0.00 0.00 2,300.00 2,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,400.00 0.00 0.00 2,400.00 2,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,488.00 0.00 0.00 2,488.00 2,400.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 9 518" 2,500.00 0.00 0.00 2,500.00 2,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,581.00 0.00 0.00 2,581.00 2,493.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Nanushuk/K3 2,600.00 0.00 0.00 2,600.00 2,512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,700.00 0.00 0.00 2,700.00 2,612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,800.00 0.00 0.00 2,800.00 2,712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 2,900.00 0.00 0.00 2,900.00 2,812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,000.00 0.00 0.00 3,000.00 2,912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,100.00 0.00 0.00 3,100.00 3,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,200.00 0.00 0.00 3,200.00 3,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,300.00 0.00 0.00 3,300.00 3,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,400.00 0.00 0.00 3,400.00 3,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,500.00 0.00 0.00 3,500.00 3,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,600.00 0.00 0.00 3,600.00 3,512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 8/24/2012 10:54:46AM Page 3 COMPASS 2003.16 Build 69 ....._. ._....... Halliburton -Sperry HALLIBURTON Standard Proposal Report +„gym men,uw w1nam.„..._ Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#1 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: WELL @ 88.00ft(Original Well Elev) Project: North Alaska ASP5 MD Reference: WELL @ 88.00ft(Original Well Elev) Site: Cassin North Reference: True Well: Plan:Cassin#1 Survey Calculation Method: Minimum Curvature Wellbore: Cassin#1 Design: Cassin#1(WP01) , Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,612.00 3,700.00 0.00 0.00 3,700.00 3,612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,800.00 0.00 0.00 3,800.00 3,712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 3,878.00 0.00 0.00 3,878.00 3,790.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Torok 3,900.00 0.00 0.00 3,900.00 3,812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,000.00 0.00 0.00 4,000.00 3,912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,100.00 0.00 0.00 4,100.00 4,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,200.00 0.00 0.00 4,200.00 4,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,300.00 0.00 0.00 4,300.00 4,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,400.00 0.00 0.00 4,400.00 4,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,500.00 0.00 0.00 4,500.00 4,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,600.00 0.00 0.00 4,600.00 4,512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,700.00 0.00 0.00 4,700.00 4,612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,800.00 0.00 0.00 4,800.00 4,712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 4,900.00 0.00 0.00 4,900.00 4,812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,000.00 0.00 0.00 5,000.00 4,912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,100.00 0.00 0.00 5,100.00 5,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,200.00 0.00 0.00 5,200.00 5,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,300.00 0.00 0.00 5,300.00 5,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,384.00 0.00 0.00 5,384.00 5,296.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Cassin Sand 5,400.00 0.00 0.00 5,400.00 5,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,500.00 0.00 0.00 5,500.00 5,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,600.00 0.00 0.00 5,600.00 5,512.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,657.00 0.00 0.00 5,657.00 5,569.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Blackburn Sand 5,700.00 0.00 0.00 5,700.00 5,612.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,800.00 0.00 0.00 5,800.00 5,712.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 5,875.00 0.00 0.00 5,875.00 5,787.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 Sandford Sand 5,900.00 0.00 0.00 5,900.00 5,812.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,000.00 0.00 0.00 6,000.00 5,912.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,100.00 0.00 0.00 6,100.00 6,012.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,200.00 0.00 0.00 6,200.00 6,112.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,300.00 0.00 0.00 6,300.00 6,212.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,400.00 0.00 0.00 6,400.00 6,312.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,500.00 0.00 0.00 6,500.00 , 6,412.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 6,588.00 0.00 0.00 6,588.00 6,500.00 0.00 0.00 5,986,110.00 1,374,096.85 0.00 0.00 7" 8/24/2012 10:54:46AM Page 4 COMPASS 2003.16 Build 69 C) n1rs , 1 ,. 1 1,, 1 b 5 1 Halliburton -Sperry HALLIBURTO"' Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#1 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: WELL @ 88.00ft(Original Well Elev) Project: North Alaska ASP5 MD Reference: WELL @ 88.00ft(Original Well Elev) Site: Cassin North Reference: True Well: Plan:Cassin#1 Survey Calculation Method: Minimum Curvature Wellbore: Cassin#1 Design: Cassin#1(WP01) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,488.00 2,488.00 9 5/8" 9-5/8 12-1/4 6,588.00 6,588.00 7" 7 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 1,088.00 1,088.00 Base Perm 0.00 3,878.00 3,878.00 Torok 0.00 5,384.00 5,384.00 Cassin Sand SAND 0.00 5,875.00 5,875.00 Sandford Sand SAND 0.00 1,608.00 1,608.00 K-5 0.00 2,581.00 2,581.00 Nanushuk/K3 0.00 5,657.00 5,657.00 Blackburn Sand SAND 0.00 1/ 8/24/2012 10:54:46AM Page 5 COMPASS 2003.16 Build 69 1 r, 110 Li ilk 1 C1itL__ Cassin #1 Drilling Hazards Summary 12 1/4" Hole/9 5/8" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Shallow Gas Pressure Anomalies Low Shallow hazard study has noted that there are no . significant shallow hazards. Follow best practices and increase mud weight if needed. Mudloggers will be logging interval. Gravel/Sand Sloughing/Clay Moderate Increase mud weight/viscosity,High viscosity sweeps. Sections Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Washouts/Hole Sloughing Low Cool mud temperatures,minimize circulating times when possible Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 8 1/2" Hole/7" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling to casing point. Pump and rotate out on trips as a last resort. Abnormal Pressure in Nanuhuk - Moderate 9 5/8"surface casing is set 80' above zone. Once surface • casing is drilled out follow mud weight schedule and so not fall behind. Stripping Drills,Shut-in Drills,PWD Tools,Increase mud weight as needed. Ensure adequate kick tolerance Abnormal pressure in zone of Low Use PWD to monitor hole. Follow mud weight schedule interest as needed. Per shallow hazard study and offset well data, anticipate normal pressure Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. mm Attachment 3 Drilling Hazards Summary R v 1. e doc n p Prepared by David Lee I t, i P I Page 1 of 1 Cassin 1 Schlumberger CemCADE Preliminary Job Design 9 5/8" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client:COP Revision Date: November 2,2012 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 250%excess in the permafrost and 50% excess below the Location:Anchorage,AK Phone:(907)263-4207 permafrost. The top of the tail slurry is designed to be at-1688' MD. Mobile:(907)223-8916 email:jhouston2@slb.com Lead Slurry Minimum pump time: -211 min. (pump time plus 120 min.) Arctic LiteCRETE +Adds- 1.90ft3/sk 0.7632 ft3/ft x(108')x 1 (0%excess) =I 83 ft3 0.3132 ft3/ft x(1088'-108')x 3.5(250% excess)= 1075 ft3 0.3132 ft3/ft x(1688'-1088')x 1.5(50%excess)= 282 ft3 83 ft3+ 1075 ft3+282 ft3= 1440 ft3 1440 ft3/ 1.90 ft3/sk= 758 sks(760) Previous Csg. Tail Slurry Minimum pump time: -170 min. (pump time plus 120 min.) < 16",65#casing 15.8 ppg Class G +adds- 1.17ft3/sk at 108'MD 0.3132 ft3/ft x(2488'-1688')x 1.5(50%excess)= 376 ft3 0.4256 ft3/ft x 80'(Shoe Joint)= 34 ft3 376 ft3+34 ft3= 410 ft3 410 ft3/1.17 ft3/sk= 351 sks(360) BHST= 156°F, Estimated BHCT= 119°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 6.0 50.0 8.3 8.3 ALC Surface Lead 6.0 256.2 42.7 51.0 Surface Tail 5.0 73.0 14.6 65.6 < Top of Tail Cement at Pause 0.0 0.0 3.0 68.6 -1688 MD Fresh Water 5.0 5.0 1.0 69.6 Pause 0.0 0.0 5.0 74.6 Mud 8.0 165.0 20.6 95.2 Mud 3.0 12.6 4.2 99.4 < 9 5/8",40#casing in 12-1/4"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv< 14, Ty<25. TD at 2488'MD (2488'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv=22-28, Ty= 30-38 Centralizers: As per COP program *Mark of Schlumberger ORIGINAL Cassin 1 Schlumberger CemCADE Preliminary Job Design 7" Intermediate Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client:COP Revision Date: November 2,2012 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40%excess. The top of the tail slurry is designed to be Location:Anchorage,AK Phone:(907)263-4207 at-4895' MD. Mobile:(907)223-8916 email:jhouston2©slb.com Tail Slurry Minimum pump time: -195 min. (pump time plus 120 min.) 15.8 ppg Class G + 0.2% D46+0.3% D65+0.4% D167 + retarder as needed- 1.17ft3/s k 0.12681 ft3/ft x(6500'-4895')x 1.40(40%excess)= 285 ft3 0.2148 ft3/ft x 80' (Shoe Joint)= 17 ft3 285 ft3+ 17 ft3= 302 ft3 Previous Csg. 302 ft3/ 1.17 ft3/sk= 258 sks < 9 5/8",40.#casing at 2488'MD Round up to 260 sks BHST= 156°F, Estimated BHCT= 119°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 6.0 25.0 4.2 4.2 MUDPUSH II 6.0 40.0 6.7 10.9 Intermediate Tail Slurry 5.0 53.8 10.8 21.7 Pause 0.0 0.0 3.0 24.7 Fresh Water 5.0 5.0 1.0 25.7 Pause 0.0 0.0 5.0 30.7 Mud 6.0 230.6 38.4 69.1 < Top of Cement at Mud 3.0 10.0 3.3 72.4 -4895'MD MUD REMOVAL Expected Mud Properties: 10.0 ppg, Pv< 14,Ty<25. , ii < 7",26#casing in 8-1/2"OH Spacer Properties: 11.0 ppg MudPUSH* II, Pv=22-28, Ty= 30-38 Centralizers: As per COP program TD at 6500'MD (6500'TVD) Mark of Schlumberger 11 1 ORIGiNtL Cassin #1 Shallow Hazard and Pore Pressure Conclusions November 12, 2012 Executive Summary ConocoPhillips Alaska Inc. (COP) intends to drill exploration well Cassin #1 in February 2013. As part of the well planning process, COP contracted with Fusion Petroleum Technologies Inc. (Fusion) of Houston, Texas to perform geopressure prediction on 42 mit of 3D seismic data from the NPRA Merge 3D seismic survey and evaluate the down-hole pore pressure regime at the Cassin #1 location (Figure 1). The pressure interpretation was based on local well control and seismic interval velocities. The results of the shallow hazards and pore pressure analysis indicated that the proposed well location contains no significant hazards that would require any change in the proposed location. Several zones of possible low saturation gas have been identified which should be drilled with care. Cassin Proposed Drilling Locations . Proposed Cassis Well Locations 0:16;12 as of May 16, 2012 Location t;;,Cap AKSP 4 FEET X Y Lat. Lon. — j w 1'370 t. CC 0 350808123 -152.162:4 ..!,f,:, —_ '\/_' —_..._... . ...—.� -- /-... 13P1c '�CC - sb15J4'1t -,52 102:5512E? -,F. 137 F .e:CC 5.234 76 ._ J!2,cC,i -- -I 1"3555':.:: !fiI CC 73.374E52271 -152.214323;,5 1353 7 4.CC $3210$55 3 .5535 ---------�-- 'e ocrria —_.��__. ! 1350. : G2W2 CC 3 371535�6e '.,1!,n137.:. • -3.4.1 .5'45322 CC S55270 -15172;154735 E ' _CC 2315250231 -152.1076 x443 tacewe� ,_ c C^_C:.CC T3.42572530 -152146x41.03 twmF7 1.... 10 'S'S' ?: nti7152.CC 72.302102503 -/52.051125560 r4°'1an' 1 Hazard Survey Area` �� 1r D. Wooert t -42 sq.miles " ` E ~ � p taEaer t I a'/ v l f>I._ ,,.,, ,. 1 d'h„ ,.\ ?. t--- a I'�` I Alaska Sear Tooth Um i l `mow CM4Ee Wells-Surface Hole Location 4, ,..-- -- F1nlae;3 lxdfcna B :ee]tl:es Wt I. 1.-K1.,_ RIM CM 1=71 :A.?Frcr<:t]•\tl-?:aV:v'.'a: I . — �.. ..�. —M1-Srtemf i I E LiCs,stre ! t IMte GF er !NA?eQ1'4Er 3 dine Anil 4 FIoSSCCd_FM :, _ FfO, arswst P W _ t3tCc Manses Yasc_Eagrg.IS.4'E 35f.tr tooth Unit ~ raft rt nng 0000 ' C.V.'S Ap1Sat ,5-..CCM { :• V 4d^.JD L 993a C t U'tt rt,iYs>< U r '`e" ?J'_E rca-c j`'..'^' rnrF:e l..,._ [dui'D`Tdt•..'I_Ar wr�C.Y1_1:!S r'. 2AE tn - - 152=15W '- .. 151,4r.,•, IP 1':.::: • Figure 1: Location map of Shark Tooth area and area of interest for hazard study Project Description Fusion utilized REVELTM, a proprietary software product, for residual velocity analysis to refine the input gathers and velocity field, provided by ConocoPhillips, for pressure prediction. Continuous velocity data at every CDP location were generated, and used to calibrate for pressure using the control well location. Pressures were then predicted in 3D across the prospective area using the GEOPRESSTM tool, another Fusion proprietary software product. Attributes were generated for pore pressure (PP), pore pressure gradient (PPG), overburden pressure (OB), overburden gradient (OBG), fracture pressure (FP), fracture pressure gradient (FPG) and effective stress (ES) along the Cassin #1 wellbore. Shallow hazards interpretation was also performed around the proposed well location in the seismic volume, and detailed hazard maps for a series of shallow features were generated. The control well for this project was the West Fish Creek#1 well (WFC) drilled by Husky in 1977. Figure 2 shows the area of interest with the J Att05 Cassin#1 Shallow Hazard.doc t Prepared by"Kent Smith&David L. Lee WFC and proposed wells and line of section for seismic panels reported by Fusion. Fusion generated fluid and fracture pressure models for Cassin locations 1, 3, 6 and 8. z. 1375904 : a w 1 - .. /+: PDL_9 r�,% r` / / / Cassm POL_1O f/ // jJrr� . r ..}4,a Cain . Ca,', DI 6. '0,rs / t I Jf Cassn_ 5393740• / ' �i'''' 4 i / �r / // / r �roLs I /r �6h►.I/ 1 1 J• 9 t s.,. POL_2 /c4,11 ft' / r1;11111%4p / jI, 11111%14*,, , i, r�r • Figure 2: Area of interest for hazard study showing wells used for calibration and 42 mi2 seismic volume. Red line is line of section for figure 5. Cross line 10715 is not shown in this document. Conclusions The fluid and fracture pressure models derived from the control well was applied to the interval velocity volume and used to generate fluid and fracture pressure models for the Cassin #1 proposed location. Also, 3-D data volumes of fluid pressure, effective stress, fracture pressure, overburden and their gradients were prepared. Figure 3 presents the predicted down-hole pressures in the Cassin #1 well. Att05_Cassin#1 Shallow Hazard.doc Prepared by"Kent Smith&David L. Lee ORIGINAL Pressure Gradient Data(ppg) ° 10.00 1200 1400 +K.DD 1° 2 J PPG OBG Top Nanushuk — 2440' ( OL) 7,3 _ 0� • G. +'• u 0 • • • Top Cassin Sand — 5345' (BGL) 4 F�^ I TD — 6560' (BGL) Mme,..• -r„e Figure 3: Pressure regime along Cassin #1 well bore. Fracture Gradient in orange, Overburden Gradient in Black and most likely Pore pressure in solid blue. A suggested mud weight by Fusion is shown in Green. Shallow hazards analysis of the study area reveals that the Cassin 1 location is the most benign of the four locations examined by Fusion. The pore pressures are essentially hydrostatic except for one zone where the pressures are slightly elevated between 3000 to 4500 feet. The mud program reflects this ✓ pressure prognosis. The final well prognosis for the Cassin #1 is shown on the ThinMANTM pseudo- impedance sections for arbitrary line A- A' (Figure 4). Figure 4 displays the depths to each of the mapped shallow zones noted with depths relative to sea level as determined from the REVELTM time- depth conversion. Inspection of Figure 4 shows the base of permafrost will be encountered at about 509 to 590 feet (based on seismic velocities) and the base of possible hydrates at approximately 1,011 feet below sea level. Zone 1 through 4 gas hazards will be encountered from just below the base of hydrate to a maximum depth of 1695 feet. These zones are most likely coarser, silty sediments containing low saturation gas. Att05_Cassin#1 Shallow Hazard.doc Prepared by"Kent Smith&David L. Lee ORIGINAL c..a004,044 a.L.+ 10<la4]j I.,...p•LI cr.-+.a„__ 010 4• d, •+----1:053. IJIr'r'---'.p .1.11—Ml r—►nom.--.*MI.--io.--i$if—tea �+ A, tib n 1i et S �1QZA Itt: MAI 9:0140 ?171iA/ �7i20 N 10.3:'0 I t(LO 14.0 IM]l.° 1011.1 1c&m 1 y.:,,, 11!11 k ,I1 tt,r01,l'4 11'7 1, 91141, i.9,4`TV 1 k i, • ova s.k*j l;s1 k )lis`y.tv i e11 ! illl:,kki V` I':. t, I 6k I '' 11 1 11 $.k11 ��a ,i ,, ti 1r 1 '',! 1 6I.. ° fir.kir 1 lE` !� f i t ti l .,4 hiss iC 143 f ,, da)1 1 1,1'111 .1` e' dr ti 1 ,��{k� f� 500ft(MSLj C t ' 4 SZ 1 , �%q�i,,411'!V$ 1('AO,t i�� 1,y 1,4 I 'S �y.l>,,k,„y'� i-. x-$. i OM A Ms k ii{tr1 [!1 �'�A1 1111 i Y I I-1 it :t4"40° �” 1 ow 1 t (1 4.+ 4T4441/441A,‘ i 441111. t 1 bl „ 1 Y d) N 1 Cess o.. { w; . 1�W 1 1� j iy� < �r r 3 Citl 1a 'Ulo(��d1 .^.�� y I����tff�k('( Oji i '�•�i Iii � � k � (�r� t'�141.1F( Ii�1 � ''o°1bz. .1.11 4,ask I yyy''' ! !) X111 ( .04 t+. 1°'''"'i �..{ 1t t e.4 ,.ifl�ra��1! "�ti 1q��r� F�� 1et4.11, Q li�'��1 l5�� I�� 4 ND 4Onr r 1 i _., 'I T 1 aorl i i} ¢¢te.�rr( I r� y� r ,4, ,. . + i 4 . 1,f t1 + i 1 _,,. i 1 -"'1k1rh ` 1i�f,,oe 1 ,ti( \5t(.lti, : P( ii,''' - t •!`1�Ii h 112 °3 'w"r ' t• • !+' r - 11/l jil'1`3.11e�ki r`'' I Wive1 !qt • i, iro"'( X .,,r+11( v 3 k Ill 1 1 t ,! 1 °t a .,i 4 D , 11 `"" ,t l i' '1 441 ,h so, - k,0 ''R1 � !I �Ati 4".‘ . I 173 Jo��?' aat ,,+ '"iV 1` I N� Y I r 1t � ���+ °{ t .17 Illt 9 4. N ,.. �t anti• tt , ,, .errs 1 it I l'it q / 4 11 AC*�J, * + 14t) �,, Iii I .; I it t E 41 { �t i 1�� t 0 1 p #t, 1 ,q d a,°� I ' „P i (a� I. ,,k iM, I < 4 ,. i1w4, Al ' q F s-11E1.2E!V VA. l'1..,Iia311210.(....MAT.NO 10061.1i-l*1111Pdt.i.u1..:.Fnal50,11,Pon,i-1,.1,..i - ---- ------ Figure 4: ThinManTM impedance section for arbitrary line A-A' In summary, Fusion has identified several zones in the shallow Cassin #1 well which should be monitored for gas influx while drilling. These four zones are at 1220-feet, 1422-feet 1490-feet and 1695- feet. It should be noted that these zones are most likely coarser, silty zones containing at most low saturation gas. While not viewed as a "hazard" these zones should be drilled with care and monitored for gas influx while drilling. Pore pressure and fracture gradient along the well bore has also been calculated and the results show a benign pressure gradient near hydrostatic. The Fusion evaluation shows the Cassin #1 location contains no significant drilling hazards which would prompt moving the location. . Att05_Cassin#1 Shallow Hazard.doc Prepared by"Kent Smith&David L. Lee ORIGINI\ L Bettis, Patricia K (DOA) From: Lee, David L [David.L.Lee@conocophillips.com] Sent: Wednesday, January 09, 2013 2:19 PM To: Bettis, Patricia K(DOA) Subject: Coordinates for Cassin 1 and Cassin 6 Attachments: 12-08-05-1_Ice Pad Exhibits_002 Rev2.pdf; 12-08-05-1_Ice Pad Exhibits_001 Rev2.pdf Hey Patricia, please find the attached updated ice pad maps for Cassin 1 and Cassin 6 to reference the correct zone. Thanks for catching this and please let me know if you need anything else. Thanks David Lee 1 1y--;2' N CASSIN #1 HARRISON BAY LOCATED WITHIN PROTRACTED SECTION 28, T. 12 N., R. 1 W. UMIAT MERIDIAN, ALASKA PROJECT 1106' FSL 1502' FWL AREA NAD83 Datum NAD27 Datum i,— — _',-; 1 ' , N 70°21'38.6" N 70°21'39.9" I � W 152°O9'49.6" W 152°09'38.2" 17,411A 7 1N ASPC ZN5 ASPC ZN5 -� (Y) 5,984,784 (Y) 5,985,068 w n � I (X) 1,866,432 (X) 726,412 Ica,uT� Imo- 1 _ , r VICINITY MAP 3 3 Ir O ' ZZ NN N N05 \�E P PO L\M\�5 s0) 0 U y o k-- ED - o 0 M('-! J =iO� — P .Q _CASSIN #1\ _- 1502' 1� H 0 \ 0 J 11Z 0 200 ap• 4 ■ ■ o, II ■ ■ o, SCALE IN FEET O �6 0, 50°'° �d- O O vo J iti i Lu 'S, oz 0 00 00 ,n N N I CD H to 1106' x Lu 0 C Q o_ Lu U_ I SEC. 28, T 12 N., R 1 W. O SEC. 33, T 12 N., R 1 W. I co 0 I N W I Q z REVISION 2 c z 3 KU U K P I K 2012-2013 NPR-A EXPLORATION a CASSIN#1 c t 'al,' PROPOSED ICE PAD CONFIGURATION a 1' s 1... ALPINE, ALASKA 139E.5'st.Ave..Anchorage.Alaska 99503•(907)273-11.8300 DATE: 01/09/2013 DRAWN BY: AG SHEET: 1 OF 2 Alpine 070e (907)670-4739 D Alpine Survey Office SCALE: 1°=200' CHECKED BY: DB W.O. No: 12-08-05-1 a Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 11, 2013 9:46 AM To: 'David.I.lee@conocophillips.com' Subject: RE: Cassin#1 (PTD 212-182) David, The completion details are very general... please send a more detailed procedure on how you are running the tubing ... lower completion which includes freeze protect, testing tubing and IA to appropriate pressures ( 3500 psi min). Assume rig is leaving site and then moving in frac equipment for the stimulations. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday,January 11, 2013 9:20 AM To: 'David.I.Iee@conocophillips.com' Subject: Cassin #1 (PTD 212-182) David, Please provide a plot map showing rig layout on pad including diverter routing. Also , need vendor supplied wellhead and production tree schematics. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1/11/2013 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME Cs►n I PTD# Development Service X Exploratory Stratigraphic Test Non-Conventional Well FIELD: L'--y/"7 rPOOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter ADD-ONS CHECK (OPTIONS) WHAT TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals _ through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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(n c� c.) c.) c.) a w a w o CO CO c) N 2 a s co co ci VI °- r O N M V (C) (O CO 0) O N M V CC) (0 n CO 0) O N M V (O (O I� CO 0) EO .-- N CO V CC) CO CO 0) .- .- N N N N N N N N N N M M M M M M M M M M O N M N a) cc 0 Y O N O C /6 N CO N CO .L...\.1 U o _ / IX N O a a 0)0 1 w c ° N a J N c ai a) O o W aIQ < a w < C 0 a s 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT MUDLOGGING DATA CASSIN #1 Provided by: Approved by: Brittney Hyden Compiled by: Joshua Dubowski Kent Smith Harry E. Bleys Distribution Date: 8/22/2013 T.D. Date: 03/13/2013 Cassin #1 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW................................................................................................2 1.1 Equipment Summary......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS.....................................................................................................................................3 2.1 Well Summary................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Additional Comments......................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Mudlog Summary............................................................................................................................7 3.2.1 Colville Group (Conductor at 108’ MD)....................................................................................7 3.2.2 Nanushuk ................................................................................................................................7 3.2.3 Torok .......................................................................................................................................8 3.2.4 Cassin Sand and Shale...........................................................................................................9 3.2.5 Blackburn Sand and Shale....................................................................................................10 3.2.6 Sanford Sand and Shale .......................................................................................................11 3.2.7 Brown Sand to TD .................................................................................................................12 3.3 Connection Gases ........................................................................................................................13 3.4 Trip (Wiper) Gases.......................................................................................................................13 3.5 Sampling Program / Sample Dispatch..........................................................................................14 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................15 4.1 Pore pressure evaluation..............................................................................................................15 4.2 Quantitative Methods....................................................................................................................16 5 DRILLING DATA..................................................................................................................................17 5.1 Survey Data ..................................................................................................................................17 5.2 Bit Record.....................................................................................................................................19 5.3 Mud Record ..................................................................................................................................20 6 SHOW REPORTS ...............................................................................................................................21 7 DAILY REPORTS ................................................................................................................................22 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD Combo Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Well Data on CD/ROM Cassin #1 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator ( Mounted in possum belly) Flame ionization total gas & chromatography. - 0 - Effective Circulating Density (ECD) From Sperry-Sun 2731’ to TD Hook Load / Weight on bit Totco WITS Feed - 0 - Mud Flow In Derived from Strokes/Minute and Pump Output - 0 - Mud Flow Out Totco WITS Feed - 0 - Mudlogging unit computer system HP Compaq Pentium 4 (X2, DML & Rigwatch) - 0 - Mudlogging unit DAC box In-unit data collection/distribution center - 0 - Pit Volumes, Pit Gain/Loss Totco WITS Feed - 0 - Pump Pressure Totco WITS Feed - 0 - Pump stroke counters Totco WITS Feed - 0 - Totco Well Monitoring Components Totco computer networked in Mudlogging Unit - 0 - Rate of penetration Totco WITS Feed - 0 - RPM Totco WITS Feed - 0 - Torque Totco WITS Feed - 0 - 1.2 Crew Unit Type : Steel Arctic Unit Number : ML056 Mudloggers Years *1 Days *2 Sample Catcher Years Days Joshua Dubowski 5 19 Dean Kekaualua 5 15 Harry Bleys 13 19 Steve Franzen 5 15 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Cassin #1 3 2 WELL DETAILS 2.1 Well Summary Well: Cassin 1 API Index #: 50-103-20663-00-00 Field: NPR-A Surface Coordinates: 70º 21' 38.602" North; -152º 09' 49.604" West Borough: North Slope Primary Target Depth: 5,160’ MD/ 5,154’ TVD State: Alaska TD Depth: 6,520’ MD/ 6,513’ TVD Rig Name / Type: Doyon 141, Arctic Triple Suspension Date: N/A Primary Target: Cassin, Blackburn and Sanford Sands Unit Bear Tooth Unit Spud Date: March 3, 2013 Ground Elevation: 74’ AMSL Completion Date: N/A RT Elevation: 102’ AMSL Completion Status: Testing Secondary Target: Depth: N/A Classification: Exploration TD Date: 3/13/2013 TD Formation: Lower Torok Days Testing: N/A Days Drilling: 7 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Coring Casing/ Liner MD (ft) TVD (ft) LOT (ppg) 12.25” 2388’ -2286’ Colville 10.0 0.65 - 9.625” 2378’ 2378’ 14.3 8.5” 6520’ -6411’ Lower Torok 9.8 1.74 2.3 Additional Comments Cassin #1, approximately 3.25 miles northwest of the West Fish Creek 1 (WFC1) well, is the first well planned to drill during the 2012-2013 exploration season within the Bear Tooth Unit (BTU). WFC1 was drilled in the winter of 1977 and reached a TD of 11,427’ MD. WFC1 drilled a 290-foot gross section zone of very fine-grained sand in the Lower Brookian Torok section which exhibited hydrocarbon shows. WFC1 is interpreted to have penetrated the outer fringe of a turbidite channel and lobe complex originating from a shelf boundary to the west. Cassin #1 will target similar turbidite sands that are delineated by AVO anomalies observed on reprocessed 3D seismic data as found in WFC1. Pending positive results from Cassin #1, the well will be tested, and a delineation well (Cassin #6) will be subsequently drilled in the 2012-2013 season. Cassin #1 4 2.4 Daily Activity Summary March 1, 2013 Rig and camps continue to rig up. N/U Diverter. March 2, 2013 Mudlogging Unit rigged up and operational; gas sampling system calibrated and tested. P/U 5” DP and racked back. Picking up BHA at report time. March 3, 2013 P/U BHA. Flood lines and conductor. Observe fluid coming out of weep hole on diverter line. Troubleshoot and fix problem with knife valve. Flood conductor and lines, test to 3500 psi (good). Drill to 408’ and POOH. P/U Directional BHA and RIH and drill to 708’. P/U off bottom to change out shaker screens then drill to 858’ at report time. March 4, 2013 Drilled ahead from 858’ to 2384’. Waiting on TD confirmation from geologist at report time. March 5, 2013 Drilled to TD at 2388’. CBU, pump sweep, CBU 2x’s. POOH to 2334’ and monitor(static). Continue POOH to 671’ then RIH to 2388’. Flow line packing off with clay, worked pipe until hole circulated clean. POOH to 2334’ and monitor (static). POOH and L/D BHA. R/U and run 9 5/8” casing. March 6, 2013 R/U cementing equipment and cement casing. R/D cement equipment and N/D diverter system. Notice bubbles coming from backside. Decision made to pick up a stand of DP and monitor well (observed 40 ppm LEL). Monitor well while waiting on decision. P/U 3 joints of 1” DP and attempt to run in. Would not go, clean top of hanger and attempt again, no go. N/D diverter and attempt to run 1” pipe into annulus but too large. Use 3/4" pipe for cement top job and cement. Rig up for BOP test. March 7, 2013 Finish nippling up BOP stack and test (good). R/D testing equipment and R/U floor for drilling. P/U 60 joints of DP and 8” jars. Begin M/U BHA until phase 3 was called. Currently waiting on weather. March 8, 2013 Weather cleared and P/U BHA. Single into hole w/45 joints to 2082’ Perform casing test. Begin drilling out cement. March 9 2013 Drilled out shoe track to 2408’ and CBU. Perform LOT, test failed. Test surface equipment, test good. Circulate and condition mud while waiting on orders. POOH and wait on 3.5” EUE pipe. Load and P/U 3.5” tubing and RIH. Displace to 9.8. Pump cement and begin hesitation squeeze. March 10, 2013 Finished hesitation squeeze and POOH. L/D 15 joints of 3.5” EUE round tubing. P/U cleanout BHA and RIH. Tag cement at 2367’ and CBU. Drill to 2418’ and perform LOT to 14.3 EMW. POOH and pick up directional BHA, RIH and drill to 2959’ at report time March 11, 2013 Drilled from 2959’ to 4478’ Cassin #1 5 March 12, 2013 Drilled from 4478’ to 5044’ and made a short trip to the shoe. Run back to bottom and continue drilling ahead to 5428’. March 13, 2013 Drilled from 5428’ to TD at 6520’. CBU 3X and begin short trip to the shoe. March 14, 2013 POOH to 2361’ and monitor (static). RIH to 6435’, wash and ream to 6520’ and CBU 3x. POOH to 6437’ and monitor (static). POOH to 6220’. Mad pass 6220’-6087’, 5864’-5717’, 5689’-5537’, 5394’-5257’. POOH to 2352’ and monitor (static). POOH to 600’ and monitor (static). L/D BHA, pull wear bushing, set test plug and R/U to test BOP’s. Testing BOP’s at report time. March 15, 2013 Finish testing BOP’s then R/D testing equipment. R/U wireline equipment and run wireline. March 16, 2013 Finish RDT wireline and L/D tools. P/U cleanout BHA and RIH to 6520’ and CBU 3x. Monitor well (static). POOH to 2322’ and monitor hole (static). CBU, B/D top drive and continue to POOH. March 17, 2013 POOH and L/D BHA. R/U wireline tools and run wireline. March 18, 2013 Finish running wireline and R/D wireline tools. P/U cleanout BHA and RIH. March 19, 2013 Continue to RIH and CBU 3x. POOH on elevators and pull wear bushing. Change out rams to 7” and test BOP’s. R/U casing equipment and run 7” casing. Cassin #1 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops refer to provisional picks by the town geologist. PROGNOSED COP TOPS FORMATION MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) 16” Casing -- -- 108 -6 Base Permafrost 1088 -1000 -- -- K5 Marker 1603 -1515 1618 -1516 9 5/8” Casing -- -- 2378 -2276 Nanushuk/K3 2568 -2480 2586 -2484 Torok 3880 -3792 3881 -3773 Cassin Sand 5395 -5307 5160 -5052 Cassin Base -- -- 5295 -5187 Wickersham -- -- 5418 -5310 Wickersham Base -- -- 5432 -5324 Blackburn Sand 5665 -5577 5495 -5387 Blackburn Base -- -- 5604 -5496 Sanford Sand 5840 -5752 5667 -5558 Sanford Base -- -- 5752 -5644 Brown Sand -- -- 6052 -5944 Brown Base -- -- 6205 -6097 TD 6500 -6,412 6520 -6411 Cassin #1 7 3.2 Mudlog Summary 3.2.1 Colville Group (Conductor at 108’ MD). 108’ to 2586’ MD / 108’ to 2585.305’ TVD / (-6’ to -2484’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 301 1.3 92.6 26 0 2.8 The Cassin #1 well started at 108’ MD in the Colville group. It contained three formation markers; the base of the permafrost at 1088’ MD / (-1000’ SSTVD). The K5 marker at 1618’ MD/ (-1515.52’ SSTVD), and the top of the Nanushuk/K3 marker at 2586’ MD/(-2484’ SSTVD). The overall formation’s composition included clay, claystone, sand, and traces of siltstone. This continued to 2388’ MD; the first TD casing point (C.P.) at 2378’ MD/ (-2276 SSTVD). After casing point the compositional mixture included claystone and sand with a trace of silt in the claystone. At 2420’ MD a large sand appeared mixed with siltstone. It exhibited a mild weak yellow fluorescence at the beginning of the sand increase; 2388 MD to 2450 MD, than a pale white fluorescence from 2550’ MD through 2586’ MD. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 736 0 0 0 0 0 0 0 0 2571 26.6 5388.485 4.064 0 0 0 0 0 3.2.2 Nanushuk 2586’ to 3881’ MD / 2585.305’ to 3875.937’ TVD / (-2484’ to -3773’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 326.4 2.1 104.7 83 2 13.2 The top of the Nanushuk began at 2586’ M.D. and continued to the top of the Torok at 3881’ MD The top of the sequence began with a sand-siltstone that ran from 2586’ MD to 2830’ MD. It was a medium gray to light medium gray colored sand that was unconsolidated. It’s grain size ranged from upper to lower fine to upper very fine on the grain size chart. The sands were moderate to well sorted, and sub-angular to sub-rounded, with a moderate to high sphericity. The overall sands were dominated by translucent quartz. It was well worked and had high textural maturity. The sandy-siltstone clasts displayed a weak to soft easily crushed low induration and graded towards a claystone. The clasts of sand-siltstone were crumbly and fell apart when sheared. They had a dull to earthy luster, with a earthy to irregular fracture. The texture was rough silty to gritty. Small pin head free oil drops were in evidence in the sand samples. A moderate odor was experienced from the samples, In the pits a strong to moderate odor were noticed. Cassin #1 8 There was a pale to medium brown staining on the quartz grains and it produced an instantaneous bright white cut with a short lived bright white fast streaming cut. It was very weak. A pale blue residual ring, and a moderate to pale yellowish white fluorescence were seen under black light on some clasts of sand- siltstone. There was a very weak pale blue fluorescence on the remaining sample. The sands pinched out and siltstone remained to 3180’ MD where large massive beds of claystone appeared and ran to the top of the Torok at 3881’ MD interbedded with siltstone. Siltstone was medium gray to dark medium gray color. The siltstone clasts were poorly indurated, and were lumpy to clumpy with moderate adhesion. They exhibited a crumbly to pulverulent tenacity with an earthy to irregular fracture. They had a tabular cuttings habit; and an earthy dull luster. There was trace amounts of carbonaceous shales found in the siltstone samples. A fluorescence on <5% of clasts were found. The claystones had gray to medium gray to dark gray color with black hues; The claystone clasts had a malleable to firm tenacity, with irregular to rounded blocky cuttings. A smooth to gritty texture with entrained silt, and the claystone had a thick massive structure. The claystone clasts released water quickly when disturbed. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 2573’ 18.7 3771.745 0 0 0 0 0 0 2584’ 54 10911.901 9.783 0 0 0 0 0 2589’ 69 16024.066 14.9 0 0 0 0 0 2854’ 28 6442.096 0 0 0 0 0 0 3820’ 81.8 14893.115 727.885 132.954 0 0 0 0 3830’ 83 15209.794 791.353 103.798 0 0 0 0 3875’ 29.5 4912.992 317.261 84.8720 55.6060 0 0 0 3.2.3 Torok 3881’ to 5160’ MD / 3875.937’ to 5154.318’ TVD (-3773’ to -5052’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 298 2.3 94 65 1 12 This interval was composed primarily of claystone and siltstone beds with trace amount of sands and low gas. The siltstone in this interval was light gray to dark gray in color, malleable to crumbly tenacity with irregular to Cassin #1 9 blocky fracture and rounded flaky cuttings. The overall texture is smooth to clayey to silty with a dull to earthy luster. There was also and occasional moderately indurated dark gray siltstone observed in the samples. The claystones were dark medium gray to medium gray with blackish hues and poor to no induration. The samples displayed an earthy to dull luster with a crumbly to malleable to pulverulent tenacity. The fracture was typically irregular to blocky to earthy and had a clayey to silty texture. There was a trace amount of sand in most of the samples. Overall the sand is quartz dominated, lower fine to upper very fine grained with well to moderate sorting and high to moderate sphericity and is sub rounded to sub angular. Fluorescence in this section was possibly corrupted due to the mud additive Lube 776 and calcite which both fluorescence. The samples commonly displayed <5% fluorescence with no cut or odor. Rare weak yellowish green cut In places and only one notable gas peak at the end of the interval. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5196 65 12727 1192 403 30 49 3 0 3.2.4 Cassin Sand and Shale 5160’ to 5495’ MD / 5154.318’ to 5489.455’ TVD / (-5052’ to -5387’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 267 1 73 212 7 32 The Cassin sand was made up of sand and sandstone with the lower section between the Blackburn sand made up of siltstone and claystone. Overall low gas and one peak through the interval. The Cassin sand was medium gray with lower to upper fine and upper very fine grained sand common but not abundant. Overall it was unconsolidated, well sorted, sub rounded to rounded with high to moderate sphericity and some clay infill with the samples become more consolidated through the interval. The sandstones where firm to friable, grain supported, slightly calcareous, lower fine to upper very fine grained and sub angular to angular with moderate sorting. The fluorescence was moderate yellowish white on 20% of the sample with no immediate observable cut to extremely slow cut and a moderate white residual fluorescence observed. No hydrocarbon odor detected. Cassin #1 10 The siltstones were medium gray to dark medium gray with poor to occasional moderate induration, crumbly to brittle to slightly pulverulent tenacity and irregular to sometimes planar fracture. The cuttings habit was typically platy to tabular, dull to earthy luster and a silty to gritty texture. The claystones were dark medium gray to medium gray with blackish hues and had poor to no induration with a dull to earthy luster. The tenacity was pulverulent to crumbly to malleable with blocky to irregular to earthy fracture and silty to clayey texture. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5242 212 38248 4645 1816 195 286 28 0 3.2.5 Blackburn Sand and Shale 5495’ to 5667’ MD / 5489.455’ to 5661.266’ TVD / (-5387’ to -5558’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 91 9 57 68 1 22 The Blackburn sand was made up of tuffaceous sandstone and sand with the lower section to the Sanford sand being made up of a sandy siltstone. The sandstone and sand was medium gray to light medium gray, unconsolidated to poorly consolidated with upper very fine to fine grains. Overall it was sub angular to sub rounded, had moderate sphericity with well to moderate sorting and grain supported. There was a minor amount of carbonaceous banding and detritus in the clasts with visible de-gassing in the carbonaceous banding and sandstone clasts. There was a moderate amount of clay infill and volcanic ash in the interval. Overall the interval had 10% Cassin #1 11 weak yellow fluorescence with no cut or odor. From 5530’ to 5550’ there was 95% weak straw yellow fluorescence on the samples with no cut or odor. The sandy siltstone was medium gray to dark medium gray with poor to occasionally moderate induration and crumbly to pulverulent to malleable tenacity. The fracture was irregular to earthy to blocky and an earthy to slightly sparkly luster. Moderate amount of clay infill and occasional sand stringers pale straw yellow on <5% of the samples; no visible cut or odor. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5509 68 11804 1939 1234 193 332 12 8 5522 58 10199 1646 1055 164 285 15 10 5535 56 9736 1544 997 154 269 18 12 5549 53 9263 1441 938 143 254 22 14 3.2.6 Sanford Sand and Shale 5667’ to 6052’ MD / 5661.266’ to 6045.845’ TVD / (-5558’ to -5944’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 126 5 54 114 10 22 The Sanford sand is made up of sandstone and a minor amount of silt and clay with the interval below and until the Brown sand is predominantly sandy siltstone and claystone. The Sanford sand is light gray, salt and pepper with very fine lower to lower fine grain sized sandstone in an argillaceous calcareous matrix cement. There was also visible degassing in the sample with faint yellow calcite mineral fluorescence and dim to slightly brighter green-yellow cut fluorescence. Weakly indurated and friable, subangular to subrounded, fair sphericity, young to more mature textural maturity; moderate sphericity with unconsolidated sands and siltstone entrained. The sandy siltstone is gray to light gray with a salt and pepper appearance. It is weak, friable and is grain/matrix supported with low visual porosity. Overall well sorted, subrounded to round grains with a calcareous argillaceous matrix cement and fair sphericity. It’s also well sorted, very fine low to fine low grain size, trace black carbon material with slight calcite mineral fluorescence and no immediate cut or streaming. Cut fluorescence is dim to weak yellow; no petroleum odor. The claystones are medium gray to dark gray in color, soft to malleable to firmer crumbly. Trace shales and black carbon material. The claystone is partially calcareous, irregular fracture with a smooth to gritty Cassin #1 12 texture, dull to shiny waxy luster and a thick structure. No sample fluorescence, petroleum odor or cut fluorescence. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5699 93 15329 2117 1224 169 293 0 0 5710 101 14702 2010 1094 139 236 0 0 5725 114 16600 2127 1157 162 285 12 15 3.2.7 Brown Sand to TD 6052’ to 6520’ MD / 6045.845’ to 6513.45’ TVD / (-5944’ to -6411’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 237 6 87 270 10 58 The Brown sand was an unexpected hydrocarbon zone encountered at 6052’MD/-5944 TVDSS. It is primarily made up of sandstone and trace amounts of siltstone. The remaining interval of the lower Torok is made up of sandstone and siltstone down to TD. The Brown sand is primarily a salt and pepper sandstone that is light gray to medium gray in color. It’s matrix supported grading towards a strong grain supported sandstone with good visual porosity. Overall it has subangular to subrounded grains, well sorted with good high sphericity and well matured textural maturity. It’s typically more friable then indurated, weakly cemented and calcareous in part in an argillaceous matrix cement. Golden yellow sample fluorescence at 60% of sample surface with a slow to moderate yellow green cut fluorescence. The siltstone is medium gray with blackish hues to dark medium gray. Often poor to moderate induration, brittle to crumbly, platy to tabular cuttings habit with an earthy to micro sparkly luster and a silty to gritty texture. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6081 247 34179 4769 2344 268 436 43 18 6108 270 26669 4012 2140 268 439 31 0 6125 209 21064 2995 1545 188 326 18 0 6160 136 14264 1924 967 120 213 41 0 6351 86 12095 1849 1047 141 249 31 25 Cassin #1 13 3.3 Connection Gases Depth (MD) Gas (units above background) Depth (MD) Gas (units above background) 4492 3 4770 5 4307 2 4863 4 4122 7 4955 8 4030 9 5418 4 3659 3 5881 17 3474 9 6252 18 3381 6 6345 15 4585 2 6437 16 Connection Gases 4678 5 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Equivalent Depth (feet) Trip to (feet) Gas (units) Downtime (hours) 6520’ 2384 73 5 Cassin #1 14 3.5 Sampling Program / Sample Dispatch Set Type/Purpose Frequency Interval Dispatched To A Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Jon Kaplan Alaska Archives 1300 West 56 th Avenue, Unit 14 Anchorage, AK 99518 B Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Jon Kaplan Alaska Archives 1300 West 56 th Avenue, Unit 14 Anchorage, AK 99518 C Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Wayne Svejnoha, Chief Branch of Energy and Minerals BLM-Alaska State Office 222 W. 7 th Avenue #13 Anchorage, AK 99513 D Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD AOGCC Attn: Howard Okland 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 E Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Grogans Mill Records Center Attn: Kenny Bland 9190 Grogans Mill Road The Woodlands, TX 77380 F Wet, unwashed bagged for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Halliburton Energy Services 6900 Arctic Boulevard Anchorage, AK 99518 Attn: Robert Haverfield G Wet, unwashed bagged for geologic analysis. 30 ft 10 ft 0’ to 5220’ MD 5220’’ to 6520’ MD Halliburton Energy Services 6900 Arctic Boulevard Anchorage, AK 99518 Attn: Robert Haverfield H IsoTubes 500 ft 30 ft 10 ft 0’ to 2388’ MD 2388’ to 5220’ MD 5220’ to 6520’ MD Isotech Laboratories, Inc. CPAI samples, contact: Albert Holba 1308 Parkland Court Champaign, IL 61821 Sampling For USGS I Can Samples 30 ft 0’ to 2388’ MD Tom Lorenson U.S. Geological Survey 345 Middlefield Road, MS-999 Menlo Park, CA 94025 J IsoTubes 50 ft 0 to 2388’ MD Bob Dias Denver Federal Center Building 53, Ent. S-1, MS 977 Denver, CO 80225 Ca s s i n # 1 15 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A 4. 1 P o r e p r e s s u r e e v a l u a t i o n In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) TV D (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators Ba s e P e r m a f r o s t C l a y s t o n e 8 0 % S a n d 2 0 % 1 0 . 0 1 0 . 1 Ev e n M W , B G K5 M a r k e r C l a y s t o n e 7 0 % S a n d 3 0 % 1 6 1 8 1 6 1 7 . 5 6 5 1 0 . 0 1 0 . 1 E v e n M W , B G Na n u s h u k / K 3 C l a y s t o n e 8 0 % Si l t s t o n e / S a n d 20 % 25 8 6 2 5 8 5 . 3 0 5 9 . 8 9 . 8 E v e n M W , B G To r o k S i l t s t o n e 5 0 % C l a y s t o n e 3 0 % 3 8 8 1 3 8 7 5 . 9 3 7 9 . 8 9 . 8 E v e n M W , B G Ca s s i n S a n d Tu f f s a n d s t o n e 40 % Sa n d 3 0 % 5 1 6 0 5 1 5 4 . 3 1 8 9 . 8 9 . 8 S l i g h t i n c C G , B G , T G Bl a c k b u r n S a n d Sa n d s t o n e 70 % Si l t s t o n e 1 0 % 5 4 9 5 5 4 8 9 . 4 5 5 9 . 8 9 . 8 S l i g h t i n c C G , BG, TG Sa n f o r d S a n d Sa n d s t o n e 40 % Sa n d 2 0 % 5 6 6 7 5 6 6 1 . 2 6 6 9 . 8 9 . 8 G o o d i n c C B , B G , T G Br o w n S a n d Sa n d s t o n e 90 % Si l t s t o n e 1 0 % 6 0 5 2 6 0 4 5 . 8 4 5 9 . 8 9 . 8 F a i r i n c C B , B G , TG TD 6 5 2 0 6 5 1 3 . 4 5 0 9 . 8 9 . 8 NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i lt s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c e o u s S i l t s t o n e Ca s s i n # 1 16 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s r e l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u lating de n s i t y ( E C D ) , i n c l u d i n g i n c r e a s e s i n b a c k g r o u n d g a s ( B G ) , ap p e a r a n c e a n d t r e n d s o f c o n n e c t i o n g a s ( C G ) , a n d ma g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( W G ) . R e g i o na l p o r e p r e s s u r e t r e n d s f r o m s o n i c d a t a , p r o v i d e d b y Co n o c o P h i l l i p s , a n d s u r f a c e m a n i f e s t a t i o n s o f h o l e c o n d i t i on s w e r e a l s o c o n s i d e r e d . As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u la p r o v i d e d b y C a n r i g D r i l l i n g T e c h n o l o g y L T D , a n d t hen modified us i n g t h e i n d i c a t o r s d e s c r i b e d a b o v e , D X C a n d r e s i s t i v i t y (R E S ) d a t a . T h e f o r m u l a u s e s D X , E C D , a n d B G a s m e a s u r ed by t o t a l d i t c h g a s : PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , and TLGSU mu s t b e d i f f e r e n t i a t e d f r o m s h o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t o n r e l i a b l e D X data. Ho w e v e r , t h e f o r m u l a p r o v e d u s e f u l i n h e l p i n g f o r m u l at e a P P G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d ata, with da t a p o i n t s i n s h a l e i n t e r v a l s . Cassin #1 17 5 DRILLING DATA 5.1 Survey Data : (Survey Data References NAD83) Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 27.6 0 0 27.6 0 0 0 0 131.61 0.14 50.8 131.61 0.08 0.1 0.01 0.13 222.66 0.39 53.97 222.66 0.33 0.44 0.07 0.27 315.97 0.39 42.69 315.97 0.75 0.91 0.11 0.08 402.28 0.42 39.61 402.27 1.21 1.31 0.07 0.04 492.59 0.38 51.42 492.58 1.65 1.75 0.07 0.1 591.42 1.02 133.4 591.41 1.25 2.65 0.99 1.05 683.67 0.92 128.75 683.64 0.23 3.82 2.55 0.14 777.78 0.85 135.26 777.74 -0.74 4.9 3.99 0.13 867.76 0.92 132.97 867.71 -1.71 5.9 5.38 0.09 961.6 0.9 127.42 961.54 -2.67 7.04 6.87 0.1 1054.3 0.83 129.9 1054.23 -3.54 8.13 8.26 0.09 1146.75 0.95 127.91 1146.67 -4.44 9.25 9.69 0.13 1239.71 0.83 128.81 1239.62 -5.34 10.38 11.12 0.13 1330.46 0.81 128.83 1330.36 -6.15 11.39 12.41 0.02 1419.02 0.96 134.38 1418.91 -7.06 12.41 13.78 0.19 1518.05 0.93 134.34 1517.92 -8.21 13.58 15.41 0.03 1613.64 0.89 131.69 1613.5 -9.24 14.69 16.93 0.06 1701.66 0.72 132.32 1701.51 -10.07 15.61 18.16 0.19 1795.1 0.67 123.48 1794.95 -10.77 16.5 19.28 0.13 1887.4 0.88 127.68 1887.24 -11.5 17.51 20.51 0.24 1981.16 0.76 126.97 1980.99 -12.31 18.58 21.84 0.13 2073.01 0.61 115.19 2072.83 -12.89 19.51 22.91 0.22 2165.26 0.61 127.72 2165.08 -13.39 20.34 23.86 0.14 2256.71 0.66 114.91 2256.52 -13.91 21.2 24.83 0.16 2310.78 0.65 110.63 2310.59 -14.15 21.77 25.41 0.09 2379.81 0.6 134.3 2379.61 -14.54 22.4 26.13 0.38 2475.46 0.63 122.49 2475.26 -15.18 23.2 27.14 0.14 2567.16 2.48 127.72 2566.92 -16.66 25.19 29.6 2.02 2659.31 3.9 131.04 2658.92 -19.94 29.13 34.7 1.55 2752 6.01 139.98 2751.26 -25.72 34.63 42.68 2.42 2846.37 6.25 141.68 2845.09 -33.54 40.99 52.71 0.32 2939.2 6.19 140.99 2937.38 -41.39 47.28 62.7 0.1 3030.9 6.01 140.87 3028.56 -48.96 53.42 72.39 0.2 3119.65 5.9 141.29 3116.83 -56.12 59.2 81.55 0.13 3213.25 6 142.15 3209.93 -63.74 65.21 91.18 0.14 3303.48 6.04 141.14 3299.66 -71.16 71.09 100.58 0.13 3396.76 5.89 142 3392.43 -78.75 77.11 110.21 0.19 3492.8 6.02 142.35 3487.95 -86.62 83.22 120.09 0.14 3586.43 5.99 142.36 3581.07 -94.38 89.2 129.81 0.03 Cassin #1 18 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 3679.88 4.76 137.34 3674.11 -101.09 94.81 138.52 1.41 3770.29 3.3 134.77 3764.29 -105.68 99.2 144.87 1.63 3863.02 3.11 133.17 3856.88 -109.28 102.93 150.05 0.23 3957.55 1.45 131.85 3951.33 -111.83 105.69 153.81 1.76 4050.76 1.21 142.08 4044.51 -113.4 107.17 155.96 0.36 4141.21 0.51 199.42 4134.95 -114.53 107.63 157.08 1.14 4235.14 1.27 283.28 4228.88 -114.69 106.47 156.38 1.4 4327.35 1.35 284.01 4321.06 -114.19 104.43 154.58 0.09 4416.53 1.38 282.07 4410.22 -113.71 102.36 152.77 0.06 4512.48 1.33 284.92 4506.14 -113.18 100.15 150.84 0.09 4604.27 1.23 290.53 4597.91 -112.56 98.2 149.02 0.17 4695.12 1.03 293.24 4688.74 -111.9 96.54 147.37 0.23 4788.69 1.11 287.23 4782.29 -111.3 94.9 145.79 0.15 4877.84 1.05 326.74 4871.43 -110.36 93.62 144.23 0.82 4974.1 1.04 321.87 4967.67 -108.93 92.6 142.5 0.09 5069.52 0.36 23.51 5063.08 -107.98 92.19 141.53 0.97 5162.03 0.3 41.23 5155.59 -107.53 92.46 141.4 0.13 5254.17 0.27 79.93 5247.73 -107.31 92.83 141.51 0.21 5344.7 0.53 55.06 5338.26 -107.03 93.39 141.71 0.34 5435.96 0.27 70.07 5429.52 -106.72 93.94 141.87 0.3 5529.84 0.25 60.88 5523.4 -106.54 94.32 142.02 0.05 5621.66 0.26 70.42 5615.22 -106.37 94.69 142.17 0.05 5715.24 0.43 73.1 5708.79 -106.2 95.23 142.43 0.18 5807.52 0.35 86.51 5801.07 -106.08 95.84 142.78 0.13 5900.16 0.51 70.41 5893.71 -105.93 96.51 143.14 0.21 5994.96 0.49 69.54 5988.51 -105.64 97.29 143.49 0.02 6088.91 0.49 66.29 6082.45 -105.34 98.03 143.81 0.03 6181.08 0.49 82.1 6174.62 -105.13 98.79 144.19 0.15 6267.08 0.8 82.15 6260.61 -105 99.74 144.77 0.36 6366.68 1.51 84.82 6360.19 -104.78 101.74 146.03 0.71 6451.25 1.74 85.6 6444.73 -104.59 104.13 147.58 0.27 6520 1.74 85.6 6513.45 -104.42 106.21 148.94 0 Ca s s i n # 1 19 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M W e a r B H A 1 1 2 . 2 5 B a k e r V M - 3 / 5 2 1 8 9 4 5 3x 1 8 , 1x 1 4 / 0. 8 9 5 8 10 8 ’ 2 3 8 8 ’ 2 8 8 0 . 6 9 . 4 6 7 1 - 1 - E R - A - E - I - N O - T D 1 2 8 . 5 H D B S FX 5 5 D / 11 7 3 2 8 7 0 3X 1 5 , 2X 1 6 / 0. 9 1 0 4 24 1 8 ’ 4 1 0 2 ’ 5 2 7 8 0 - 1 - C T - S - X - 1 - W T - T D 3 Ca s s i n # 1 20 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O ; M u d T y p e : S p u d M u d Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 3/ 2 / 2 0 1 3 0 1 0 . 0 - 1 6 8 3 8 4 2 1 7 / 3 3 / 3 3 - - / - 9 / 9 1 - 9.5 1100 80 3/ 3 / 2 0 1 3 8 1 7 1 0 . 0 - 2 2 5 3 5 4 5 3 8 / 7 5 / 7 6 - - / - 1 1 1 / 8 8 - 9 . 6 1 0 0 0 8 0 3/ 4 / 2 0 1 3 2 3 8 4 1 0 . 0 - 2 1 8 4 0 4 8 2 7 / 5 8 / 6 9 4 . 6 2 / - 1 2 . 5 / 8 8 - 8 . 9 1 0 0 0 8 0 3/ 5 / 2 0 1 3 2 4 0 0 1 0 . 0 1 9 8 4 2 4 3 2 8 / 6 5 / 7 7 4 . 7 2 / - 1 0 . 5 / 9 0 - 9 . 1 1 0 0 0 8 0 3/ 6 / 2 0 1 3 2 4 0 0 1 0 . 0 - 6 4 3 5 1 9 5 / 6 / 1 2 6 . 4 2 / - 1 0 / 9 0 - 8 . 9 9 0 0 8 0 3/ 7 / 2 0 1 3 2 4 0 0 1 0 . 0 - 7 3 3 1 1 6 4 / 5 / 1 1 6 . 2 2 / - 1 0 / 9 0 - 8 . 9 9 0 0 8 0 3/ 8 / 2 0 1 3 2 4 0 0 9 . 9 - 6 1 2 6 9 4 / 5 / 1 1 6 . 2 2 / - 1 0 / 9 0 - 8 . 9 9 0 0 8 0 3/ 9 / 2 0 1 3 2 4 0 6 9 . 8 - 4 2 8 1 0 1 0 / 1 3 / 1 3 1 7 1 / - 8 / 9 2 - 1 0 . 0 1 1 0 0 8 0 MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o nt e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y W L = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N C = N o t R e p o r t e d Co n t r a c t o r : M I S W A C O ; M u d T y p e : 9 . 8 K l a - S h i e l d Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 3/ 1 0 / 2 0 1 3 2 6 8 9 9 . 8 - 5 6 1 2 1 7 5 / 8 / 1 6 4 . 9 1 / - 7 2 / 9 1 - 1 0 . 3 3 6 0 0 0 8 0 3/ 1 1 / 2 0 1 3 4 4 6 5 9 . 8 1 1 . 2 7 6 1 1 8 3 3 1 0 / 2 1 / 3 2 4 1 / - 1 0 5 / 8 5 - 9 . 9 3 4 0 0 0 8 0 3/ 1 2 / 2 0 1 3 5 2 3 0 9 . 8 1 1 . 4 2 6 8 1 7 3 6 1 1 / 2 0 / 3 6 4 . 4 1 / - 10 5 / 8 5 T r 9 . 8 3 3 0 0 0 8 0 3/ 1 3 / 2 0 1 3 6 5 2 0 9 . 8 1 0 . 7 1 5 9 1 7 3 8 1 3 / 2 2 / 3 0 4 . 8 1 / - 10 5 / 8 5 - 9 . 5 3 2 0 0 0 8 0 3/ 1 4 / 2 0 1 3 6 5 2 0 9 . 8 9 . 9 2 6 8 1 6 3 9 1 3 / 2 2 / 3 0 4 . 8 1 / - 1 0 5 / 8 5 - 9 . 6 3 2 0 0 0 8 0 3/ 1 5 / 2 0 1 3 6 5 2 0 9 . 8 9 . 9 6 8 1 6 3 9 1 3 / 2 2 / 3 0 4 . 8 1 / - 1 0 5 / 8 5 - 9 . 6 3 2 0 0 0 8 0 MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o nt e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y W L = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N C = N o t R e p o r t e d 21 6 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 2575 MD 2605 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 138 154 154 146 WOB 2.8 4.7 4.7 4.1 RPM 62.4 71.7 75.0 67.5 Mud Weight 9.8 9.8 9.8 9.8 Chloride 3,600 3,600 3,600 3,600 Total Gas 26 69 14 69 C1 (ppm) 5,388 160,024 3,414 16,024 C2 (ppm) 4 15 2 15 C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor moderate Fluorescence Cut Fluorescence Residual Cut Stain Amount 10% Type inst/strm Amount Amount 5% Distribution on clasts Intensity mod/good Color Color pale brown Intensity moderate Color white Residual Fluorescence Cut Color pale yel wht Intesity Color dark brown Color Oil Show Rating Free Oil in Mud Comments Report by: moderate Instantaneous bright white cut with a short lived bright white fast streaming cut; very weak and pale blue residual ring. moderate to pale yellowish white fluorescence on the clasts of siltstone; very weak pale blue fluorescence on the remaining sample. yes, 5-10% pin heads 2 blue-wht North Slope Bourogh Alaska USA 501032066300 Cassin #1 Bear Tooth Unit Doyon 141 3/10/2013 19:15 Medim gray to light medium gray; unconsolidated; upper to lower fine to upper very fine; moderate to well sorted; sub angular to sub rounded; moderate to high sphericity; dominated by translucent quartz; the sandy siltstone clasts show poor to no induration and grade towards a claystone; crumbly and falls apart when prodded; dull to earthy luster; earthy to irregular fracture; silty to gritty texture; pin head free oil in sample; moderate odor in samples and strong to moderate in the pits; pale to medium brown staining on the quartz grains low pale blue Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5220 MD 5260 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 136 148 60 267 WOB 10.9 9.0 6.1 12.0 RPM 73.0 80.0 83.0 81.0 Mud Weight 9.8 9.8 9.8 9.8 Chloride 33,000 33,000 33,000 33,000 Total Gas 41 106 39 212 C1 (ppm) 7,938 19,102 6,441 38,248 C2 (ppm) 776 2,306 878 4,645 C3 (ppm) 270 899 366 1,819 C4 (ppm) 57 237 106 482 C5 (ppm) 3 14 5 28 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount 20% Type Amount Amount Distribution on clasts Intensity Color Color Intensity moderate Color Residual Fluorescence Cut Color yel-wht Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: medium gray; lower to upper fine with upper very fine common but not abundant; unconsolidated; well sorted; sub rounded to rounded; high to moderate sphericity; some clay infill and the samples become more consolidated through the interval; the consolidated clasts where firm to friable; grain supported; slightly calcareous; lower fine to upper very fine grained; sub angular to angular; moderate sorting North Slope Bourogh Alaska USA 501032066300 Cassin #1 Bear Tooth Unit Doyon 141 3/12/2013 20:02 moderate Joshua dubowski moderate yellowish white fluorescence on 20% of the sample; no immediate cut to extremely slow cut; moderate white residual fluorescence observed; no odor. no 0.4 white Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5500 MD 5560 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 52 53 60 90 WOB 2.7 3.0 6.1 4.0 RPM 83.0 81.0 83.0 81.0 Mud Weight 9.8 9.8 9.8 9.8 Chloride 33,000 33,000 33,000 33,000 Total Gas 12 38 39 68 C1 (ppm) 2,101 6,620 6,441 11,804 C2 (ppm) 355 1,057 878 1,939 C3 (ppm) 223 681 366 1,234 C4 (ppm) 95 290 106 526 C5 (ppm) 1 19 5 35 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount 95% Type Amount Amount Distribution grain, clasts Intensity Color Color Intensity dull Color Residual Fluorescence Cut Color yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: Medium gray to light medium gray; unconsolidated to poorly consolidated; upper very fine to fine; sub angular to sub rounded; moderate sphericity; well to moderate sorting; grain supported; carbonaceous banding and detritus in the clasts; visible de-gassing in the carbonaceous banding and sandstone clasts; moderate amount of clay and siltstone North Slope Bourogh Alaska USA 501032066300 Cassin #1 Bear Tooth Unit Doyon 141 3/13/2013 2:37 Joshua Dubowski 95% weak straw yellow fluorescence from 5530' to 5550'; 10% weak yellow fluorescence on the remaining samples; no cut or odor from any. 0.5 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 4 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 6050 MD 6120 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 70 97 82 90 WOB 13.0 8.0 6.0 4.0 RPM 84.0 80.0 81.0 81.0 Mud Weight 9.8 9.8 9.8 9.8 Chloride 33,000 33,000 33,000 33,000 Total Gas 19 106 98 270 C1 (ppm) 2,703 13,921 9,946 34,179 C2 (ppm) 366 1,962 1,387 4,769 C3 (ppm) 177 977 707 2,344 C4 (ppm) 47 298 237 708 C5 (ppm) 18 26 7 115 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount 60% Type slow Amount Amount Distribution scattered Intensity moderate Color Color Intensity moderate Color grn-yel Residual Fluorescence Cut Color gold-yel Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: salt and pepper sandstone; light gray to medium gray color; matrix supported grading towards a strong grain supported sandstone with good visual porosity; subangular to subrounded grains; well sorted with good high sphericity; well matured textural maturity; more friable then indurated, weakly cemented; calcareous in part in a argillaceous matrix cement North Slope Bourogh Alaska USA 501032066300 Cassin #1 Bear Tooth Unit Doyon 141 3/13/2013 14:42 Joshua Dubowski golden yellow sample fluorescence at 60% of sample surface with a slow to moderate yellow green cut fluorescence. 1.3 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 5 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5689 MD 5733 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 56 55 52 117 WOB 4.6 3.7 2.5 6.0 RPM 83.9 83.2 84.5 81.0 Mud Weight 9.8 9.8 9.8 9.8 Chloride 33,000 33,000 33,000 33,000 Total Gas 18 114 29 114 C1 (ppm) 2,851 16,600 3,725 16,600 C2 (ppm) 407 2,127 582 2,127 C3 (ppm) 264 1,224 392 1,224 C4 (ppm) 116 462 158 462 C5 (ppm) - 27 7 27 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount 30% Type Amount Amount Distribution scattered Intensity pale Color Color Intensity faint Color grn-yel Residual Fluorescence Cut Color yel Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: Harry E. Bleys faint yellow calcite mineral fluorescence dim to slightly brighter green yellow cut fluorescence. 1 North Slope Bourogh Alaska USA 501032066300 Cassin #1 Bear Tooth Unit Doyon 141 3/13/2013 17:34 Light gray salt and pepper very fine lower to lower fine grain sized sandstone in argillaceous calcareous matrix cement; visible degassing with faint yellow calcite mineral fluorescence dim to slightly brighter green yellow cut fluorescence; weakly indurated and friable; subangular to subrounded fair sphericity; young to more mature textural maturity; moderate sphericity; unconsolidated sands and siltstone entrained; sandstone reduces and siltstone increases along with claystone in this lower interval; max gas in this interval was 114 units. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 22 7 DAILY REPORTS ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, L. Martin S. Heim Date: 03/02/2013 Time: 00:01 Current Depth (MD): 108 Current Depth (TVD): 108 Current Operations: P/U BHA 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 10.0 FV: 168 PV: 38 YP: 42 FL: - Gels: 17/33/33 Sol: 9 pH: 9.5 Cl -: 1100 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Mudlogging Unit rigged up and operational; gas sampling system calibrated and tested. P/U 5” DP and racked back. Picking up BHA at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $6610.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, L. Martin S. Heim Date: 03/03/2013 Time: 00:01 Current Depth (MD): 858 Current Depth (TVD): 858 Current Operations: Drilling 24 hr Footage (MD): 750 Drilling Parameters ROP: Current: 81 Max: 214 Torque: Current: 1624 Max: 3165 WOB: Current 7.9 Max: 21 RPM: Current: 78 Max: 83 PP: Current: 1120 Max: 1175 Lag: Strokes: 1054 Time: 9.5 Surf-Surf: Strokes: 1142 Time: 10.5 ECD: Current: Max: Mud Properties MW: 10.0 FV: 225 PV: 35 YP: 45 FL: - Gels: 38/75/76 Sol: 11 pH: 9.6 Cl -: 1000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 4 Max: 7 Depth (MD/TVD): 833 Avg BG : 0 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 90% Claystone 10% Sand Last 24 hrs: 90% Claystone 10% Sand Operational Summary: P/U BHA. Flood lines and conductor. Observe fluid coming out of weep hole on diverter line. Troubleshoot and fix problem with knife valve. Flood conductor and lines, test to 3500 psi (good). Drill to 408’ and POOH. P/U Directional BHA and RIH and drill to 708’. P/U off bottom to change out shaker screens then drill to 858’ at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, L. Martin S. Heim Date: 03/04/2013 Time: 00:01 Current Depth (MD): 2384’ Current Depth (TVD): 2384’ Current Operations: Drilling 24 hr Footage (MD): 1526’ Drilling Parameters ROP: Current: 96 Max: 246 Torque: Current: 2170 Max: 16937 WOB: Current 11.9 Max: 21 RPM: Current: 81 Max: 84 PP: Current: 1328 Max: 1793 Lag: Strokes: 2889 Time: 21 Surf-Surf: Strokes: 3246 Time: 23 ECD: Current: Max: Mud Properties MW: 10.0 FV: 218 PV: 40 YP: 48 FL: 4.6 Gels: 27/58/69 Sol: 12.5 pH: 8.9 Cl -: 1000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2 Max: 22 Depth (MD/TVD): 2337’ Avg BG : 3 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1000’ MD 7 6271 1500’ MD 1.5 280 2000’ MD 1.1 204 Lithologies: Current: 80% Claystone 10% Siltstone 10% Sand Last 24 hrs: 90% Claystone 10% Sand Operational Summary: Drilled ahead from 858’ to 2384’. Waiting on TD confirmation from geologist at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, L. Martin S. Heim Date: 03/05/2013 Time: 00:01 Current Depth (MD): 2388’ Current Depth (TVD): 2388’ Current Operations: Prep cement 24 hr Footage (MD): 4’ Drilling Parameters ROP: Current: - Max: 80 Torque: Current: - Max: 2424 WOB: Current - Max: 11.8 RPM: Current: - Max: 80 PP: Current: - Max: 1899 Lag: Strokes: 2894 Time: 21 Surf-Surf: Strokes: 3251 Time: 23 ECD: Current: Max: Mud Properties MW: 10.0 FV: 220 PV: 46 YP: 45 FL: 4.4 Gels: 31/65/74 Sol: 10 pH: 9.0 Cl -: 1000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 7 Depth (MD/TVD): 2386’ Avg BG : 4 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 80% Claystone 10% Siltstone 10% Sand Last 24 hrs: 80% Claystone 10% Siltstone 10% Sand Operational Summary: Drilled to TD at 2388’. CBU, pump sweep, CBU 2x’s. POOH to 2334’ and monitor (static). Continue POOH to 671’ then RIH to 2388’. Flow line packing off with clay, worked pipe until hole circulated clean. POOH to 2334’ and monitor (static). POOH and L/D BHA. R/U and run 9 5/8” casing. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, L. Martin S. Heim Date: 03/06/2013 Time: 00:01 Current Depth (MD): 2388’ Current Depth (TVD): 2388’ Current Operations: R/U BOP test 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: Max: Mud Properties MW: 10.0 FV: 64 PV: 35 YP: 19 FL: 6.4 Gels: 5/6/12 Sol: 10 pH: 8.9 Cl -: 900 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: R/U cementing equipment and cement casing. R/D cement equipment and N/D diverter system. Notice bubbles coming from backside. Descision made to pick up a stand of DP and and monitor well (observed 40 ppm LEL). Monitor well while waiting on descision. P/U 3 joints of 1” DP and attempt to run in. Would not go, clean top of hanger and attempt again, no go. N/D diverter and attempt to run 1” pipe into annulas but too large. Use 3/4" pipe for cement top job and cement. Rig up for BOP test. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/07/2013 Time: 00:01 Current Depth (MD): 2388’ Current Depth (TVD): 2388’ Current Operations: Waiting on weather 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: Max: Mud Properties MW: 10.0 FV: 73 PV: 31 YP: 16 FL: 6.2 Gels: 4/5/11 Sol: 10 pH: 8.9 Cl -: 900 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Finish nippling up BOP stack and test (good). R/D testing equipment and R/U floor for drilling. P/U 60 joints of DP and 8” jars. Begin M/U BHA until phase 3 was called. Currently waiting on weather. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/08/2013 Time: 00:01 Current Depth (MD): 2388’ Current Depth (TVD): 2388’ Current Operations: Drilling Cement 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf-Surf: Strokes: - Time: - ECD: Current: Max: Mud Properties MW: 9.9 FV: 61 PV: 26 YP: 9 FL: 6.2 Gels: 4/5/11 Sol: 10 pH: 8.9 Cl -: 900 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Weather cleared and P/U BHA. Single into hole w/45 joints to 2082’ Perform casing test. Begin drilling out cement. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/09/2013 Time: 00:01 Current Depth (MD): 2408’ Current Depth (TVD): 2408’ Current Operations: Cementing 24 hr Footage (MD): 20’ Drilling Parameters ROP: Current: - Max: 78 Torque: Current: - Max: 1593 WOB: Current - Max: 7 RPM: Current: - Max: 76 PP: Current: - Max: 1728 Lag: Strokes: 1179 Time: 8.5 Surf-Surf: Strokes: 1539 Time: 11 ECD: Current: Max: Mud Properties MW: 9.8 FV: 42 PV: 8 YP: 10 FL: 17 Gels: 10/13/13 Sol: 8 pH: 10.0 Cl -: 1100 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 7 Depth (MD/TVD): 2397’ Avg BG : 5.6 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Drilled out shoe track to 2408’ and CBU. Perform LOT, test failed. Test surface equipment, test good. Circulate and condition mud while waiting on orders. POOH and wait on 3.5” EUE pipe. Load and P/U 3.5” tubing and RIH. Displace to 9.8. Pump cement and begin hesitation squeeze. Calibrations: THA, Chromatograph, peak simple Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/10/2013 Time: 00:01 Current Depth (MD): 2959’ Current Depth (TVD): 2959’ Current Operations: Drilling 24 hr Footage (MD): 551’ Drilling Parameters ROP: Current: 153 Max: 326 Torque: Current: 2193 Max: 3614 WOB: Current 8.2 Max: 20.4 RPM: Current: 70 Max: 94 PP: Current: 2001 Max: 2051 Lag: Strokes: 1457 Time: 10.5 Surf-Surf: Strokes: 1937 Time: 14 ECD: Current: Max: Mud Properties MW: 9.8 FV: 56 PV: 12 YP: 17 FL: 4.9 Gels: 5/8/16 Sol: 7 pH: 10.3 Cl -: 36000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 12 Max: 69 Depth (MD/TVD): 2589’ Avg BG : 15 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 2820 8 1914 2850 17 3973 2880 11 2620 2910 7 1658 2940 15 3473 Lithologies: Current: 80% Siltstone 20% Sand Last 24 hrs: 60% siltstone 30% sand 10% claystone Operational Summary: Finished hesitation squeeze and POOH. L/D 15 joints of 3.5” EUE round tubing. P/U cleanout BHA and RIH. Tag cement at 2367’ and CBU. Drill to 2418’ and perform LOT to 14.3 EMW. POOH and pick up directional BHA, RIH and drill to 2959’ at report time Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/11/2013 Time: 00:01 Current Depth (MD): 4478’ Current Depth (TVD): 4472’ Current Operations: Drilling 24 hr Footage (MD): 1519’ Drilling Parameters ROP: Current: 91 Max: 245 Torque: Current: 1765 Max: 3917 WOB: Current 8.8 Max: 21 RPM: Current: 65 Max: 92 PP: Current: 1986 Max: 2317 Lag: Strokes: 2120 Time: 14 Surf-Surf: Strokes: 2844 Time: 19 ECD: Current: Max: Mud Properties MW: 9.8 FV: 61 PV: 18 YP: 33 FL: 4 Gels: 10/21/32 Sol: 10 pH: 9.9 Cl -: 34000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 12 Max: 83 Depth (MD/TVD): 3830’ Avg BG : 12 Gas Events Depth (MD/TVD) Gas (units above background) Depth (MD/TVD) Gas (units above background) 4492 3 3659 3 4307 2 3474 9 4122 7 3381 6 Connection Gases 4030 9 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 4350 9.5 2466 121 53 3 20 4380 13 2662 127 53 21 4410 12 2441 114 40 2.2 4400 10.4 2136 108 37 4470 8 1572 86 30 Lithologies: Current: 50% Claystone 40% Siltstone 10% Sand Last 24 hrs: 50% Claystone 40% Siltstone 10% Sand Operational Summary: Drilled from 2959’ to 4478’ Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: L. Hill, D. Coats S. Heim Date: 03/12/2013 Time: 00:01 Current Depth (MD): 5428’ Current Depth (TVD): 5420’ Current Operations: Drilling 24 hr Footage (MD): 950’ Drilling Parameters ROP: Current: 94 Max: 298 Torque: Current: 2446 Max: 5442 WOB: Current 10.3 Max: 21 RPM: Current: 73 Max: 84 PP: Current: 2316 Max: 2622 Lag: Strokes: 2552 Time: 17 Surf-Surf: Strokes: 3443 Time: 23 ECD: Current: Max: Mud Properties MW: 9.8 FV: 68 PV: 17 YP: 36 FL: 4.4 Gels: 11/20/36 Sol: 10 pH: 9.8 Cl -: 33000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 11 Max: 212 Depth (MD/TVD): 5242 Avg BG : 18 Gas Events Depth (MD/TVD) Gas (units above background) Depth (MD/TVD) Gas (units above background) 4585 2 4955 8 4678 5 5418 4 4770 5 Connection Gases 4863 4 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5400 13 2053 342 178 22 42 5410 15 2340 390 207 27 50 5420 13 2075 348 190 26 47 5430 14 2215 372 209 29 52 5440 12 1845 311 178 26 45 Lithologies: Current: Siltstone 40% Claystone 30% Sandstone 20% Sand 10% Last 24 hrs: Siltstone 40% Claystone 30% Sandstone 20% Sand 10% Operational Summary: Drilled from 4478’ to 5044’ and made a short trip to the shoe. Run back to bottom and continue drilling ahead to 5428’. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/13/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513” Current Operations: Short trip to shoe 24 hr Footage (MD): 1092’ Drilling Parameters ROP: Current: 69 Max: 236 Torque: Current: 2888 Max: 6972 WOB: Current 9.4 Max: 21 RPM: Current: 81 Max: 85 PP: Current: 2407 Max: 2783 Lag: Strokes: 3048 Time: 20 Surf-Surf: Strokes: 4121 Time: 27.5 ECD: Current: Max: Mud Properties MW: 9.8 FV: 59 PV: 17 YP: 38 FL: 4.8 Gels: 13/22/30 Sol: 10 pH: 9.5 Cl -: 32000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 12 Max: 268 Depth (MD/TVD): 6108 Avg BG : 36 Gas Events Depth (MD/TVD) Gas (units above background) Depth (MD/TVD) Gas (units above background) 5881 17 6252 18 6345 15 Connection Gases 6437 16 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6420 30 3967 651 415 59 109 5 8 6450 20 2756 467 312 46 85 2 6 6480 23 2993 524 365 55 102 0 6 6510 12 1837 349 257 38 72 3 1 6520 18 2421 479 359 54 100 8 Lithologies: Current: 60% siltstone 20% sandstone 10% sand 10% clay Last 24 hrs: 45% siltstone 35% sandstone 10% sand 10% clay Operational Summary: Drilled from 5428’ to TD at 6520’. CBU 3X and begin short trip to the shoe. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/14/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513” Current Operations: Testing BOP’s 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 68 PV: 16 YP: 39 FL: 4.8 Gels: 13/22/30 Sol: 10 pH: 9.6 Cl -: 32000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) 5 73 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: POOH to 2361’ and monitor (static). RIH to 6435’, wash and ream to 6520’ and CBU 3x. POOH to 6437’ and monitor (static). POOH to 6220’. Mad pass 6220’- 6087’, 5864’-5717’, 5689’-5537’, 5394’-5257’. POOH to 2352’ and monitor (static). POOH to 600’ and monitor (static). L/D BHA, pull wear bushing, set test plug and R/U to test BOP’s. Testing BOP’s at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/15/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513” Current Operations: Wireline 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 68 PV: 16 YP: 39 FL: 4.8 Gels: 13/22/30 Sol: 10 pH: 9.6 Cl -: 32000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish testing BOP’s then R/D testing equipment. R/U wireline equipment and run wireline. Calibrations: None Failures: None Daily Cost: $2210.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/16/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513” Current Operations: POOH 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 80 PV: 18 YP: 34 FL: 4.7 Gels: 11/18/23 Sol: 10 pH: 10.0 Cl -: 31000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) 54 36 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish RDT wireline and L/D tools. P/U cleanout BHA and RIH to 6520’ and CBU 3x. Monitor well (static). POOH to 2322’ and monitor hole (static). CBU, B/D top drive and continue to POOH. Calibrations: None Failures: None Daily Cost: $2210.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/17/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513’ Current Operations: Wireline 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 83 PV: 15 YP: 32 FL: 4.7 Gels: 9/17/22 Sol: 10 pH: 10.0 Cl -: 31000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: POOH and L/D BHA. R/U wireline tools and run wireline. Calibrations: None Failures: None Daily Cost: $2210.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: G. Whitlock, D. Coats R. Reinhart Date: 03/18/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513’ Current Operations: Cleanout Run 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 107 PV: 16 YP: 34 FL: 4.4 Gels: 9/16/21 Sol: 11 pH: 10.2 Cl -: 29000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) 30 17 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish running Wireline and R/D wireline tools. P/U cleanout BHA and RIH. Calibrations: None Failures: None Daily Cost: $2210.00 ConocoPhillips Alaska Inc. Cassin #1 Daily Report Report for: Guy Whitlock Lee Martin Date: 03/19/2013 Time: 00:01 Current Depth (MD): 6520’ Current Depth (TVD): 6513’ Current Operations: Running 7” casing 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties MW: 9.8 FV: 88 PV: 16 YP: 31 FL: 4.4 Gels: 9/16/21 Sol: 11 pH: 10.1 Cl -: 29000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue to RIH and CBU 3x. POOH on elevators and pull wear bushing. Change out rams to 7” and test BOP’s. R/U casing equipment and run 7” casing. Calibrations: None Failures: None Daily Cost: $2210.00
