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Home My WebLink About213-160 • • Pip 2/3 —/c Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, September 20, 2016 8:43 AM To: Loepp,Victoria T(DOA) Subject: RE:Alpine's production well CD3-130(PTD#213-160)was reported with SCP of the IA. Follow Up Flag: Follow up Flag Status: Flagged Victoria- Because CD3 is a remote location, it is set up with a set of electronic gauges that provide a live feed of the well head pressures. The drill site operator is required to review and approve the pressures on a daily basis. Also the DSO will be physically on location on every Sunday and Thursday weather permitting. Both operations and the problem wells personnel receive a daily report of the well head pressures because the well is"flagged"for being above our maximum anticipated pressure. With these systems in place the well will be monitored closely throughout the 2 week data collection period. Any substantial changes to the well head pressures or status will be relayed to the AOGCC along with a plan of action. Please let me know if you have any further questions. Thanks. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 FEB 1 62017 Cell phone: (907)943-0450 TEAM 4IVELLScps From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,September 20, 2016 8:12 AM To: NSK Problem Well Supv<n1617@conocophillips.com> Subject: [EXTERNAL]RE:Alpine's production well CD3-130(PID#213-160)was reported with SCP of the IA. Dusty, What is the frequency of the monitoring of the IA pressure? Thanx, Victoria From: NSK Problem Well Supv[mailto:n1617@conocophillips.com] Sent: Monday, September 19, 2016 4:55 PM To: Loepp, Victoria T(DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine's production well CD3-130(PTD# 213-160)was reported with SCP of the IA. Victoria- 1 • • Alpine's production well CD3-130(PTD#213-160)was reported with SCP of the IA. The well was shut in on the 14th of September for a reservoir pressure survey which is needed to provide information about a future well that will be drilled in the area in close proximity to CD3-130. To obtain this data a set of down hole gauges was set on the 15th of Sept with intentions of leaving them in place for^'2 weeks. The IA pressure has increased since the well was shut in. Operations attempted to bleed the IA however the IA pressure built back up. Because the data being collected from the down hole gauges is a time sensitive matter due to planning for future"drill by" it is CPAI's intentions to leave the gauges in place and let the IA stabilize over the DNE of 2000 psi. At this point in time the IA is being reported at 2117 psi. The IA has 7 5/8"29.7 lb L-80 pipe which has a pressure rating of 6890 psi. If the IA pressure starts to approach 45 percent of the burst rating,immediate action will be taken to manage the IA pressure. If the IA stabilizes below the 45 percent the IA will be left as is until the 2 week data collection period has been completed. At that point in time diagnostics will start to identify the pressure source of the high IA pressure and the necessary repairs will be done to mitigate the communication. Please let me know if you have any questions or disagree with the plan. Attached is a wellbore schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 illIZELLS TEAM Conocahilips2 . pro z/.3-/6,O Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,July 15,2016 10:25 AM To: Loepp,Victoria T(DOA) Cc: Send R.T ler, NSK Problem Well Supv Subject: CD3-130(PTD#213-160) SCP of the IX) Attachments: CD3-130.pdf;CD3-130 90 Day TIO plot.JPG Follow Up Flag: Follow up Flag Status: Flagged Victoria- Alpine's production well CD3-130(PTD#213-160)was reported with SCP of the IA. They well is used as a swing well during the recent high ambient temperature conditions and was shut in on the 13th of July. Yesterday the pad operator found the IA at 2250 psi and attempted to bleed. The IA rebuilt the pressure and appeared to be tracking tubing pressure. The IA has 7 5/8"29.7 lb L-80 pipe which has a pressure rating of 6890 psi. It is suspected that the well has a faulty gas lift valve and slick line will start diagnostics as soon as reasonably possible. Please let me know if you have any questions or disagree with the plan forward. Attached is a wellbore schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 SCANNED FEB 0 62017 Cell phone: (907)943-0450 AWELLS TEAM cono0;7Pw' nos1 l --- \ •NS PROD CD3-130 ConocoP lillipsil Well Attributes Max Angle&MD TD Alaska,Inc.. i Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) cix I pc 501032067700 FIORD KUPARUK PROD 15,757.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD3-130,4/23/2015 2:30:17 PM SSSV:TRDP _ Last WO: 36.60 Vertical schematic(actual) , AnnotationSDepth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 4/15/2015 HANGER;31.1 CasingStrings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L CONDUCTOR 20 19.124 36.6 115.6 115.6 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 36.6 3,353.8 2,480.5 45.50 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 34.2 14,309.5 6,511.8 29.70 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW 6.8 13,133.0 13,150.0 6,164.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Id i LINER 6 5.340 12,148.2 15,090.0 6,716.3 20.10 EX-80 XPC XO Reducing;111.4 .I/ Liner Details u Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;36.6-115.61 12,148.2 5,854.2 71.94 TAPER GUIDE TAPER GUIDE EX-80 5.340 j -_ j 12,149.0 5,854.4 71.93 HANGER/ HANGER&SEALS.085 VITON,EX-80- 5.340 I SEALS UNEXPANDED c. SSSV;2,259.8 Tubing Strings i I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-41/2x3 31/2 2.992 31.1 12,184.9 5,865.6 9.30 L-80 EUE i - 1/2 @111.42 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.00 HANGER FMC HANGER-ELASTOMER 3.958 II 111.4 111.4 0.12 XO Reducing XO-4 1/2"IBT(B)x 31/2"EUE 8 RD(P) 2.992 SURFACE;36.6-3,353.8 2,259.8 1,995.3 49.22 SSSV CAMCO TRMAXX-53 W/2.812"X PROFILE 2.812 -- 12,084.0 5,834.4 72.26 LOCATOR BAKER LOCATOR 2.992 12,086.0 5,835.0 72.25 PBR BAKER PBR 3.000 GAS LIFT;4,668.3 12,109.5 5,842.2 72.11 PACKER BAKER FHL RETRIEVABLE PACKER 2.910 L. 12,133.0 5,849.5 71.98 NIPPLE XLINE LANDING XN NIPPLE,NO GO 2.750 12,182.3 5,864.8 71.92 MULE SHOE BAKER AUTO ENTRY SHOE 2.990 } Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.) I J Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Corn Run Date ID(in) - 13,133.0 6,159.1 71.87 WHIPSTOCK TOW 13,133'&BOW 13,150' 1/29/2015 Perforations&Slots GAS LIFT;8,464.0 ,( Shot Dens Top(ND) Btm(ND) (shots/f - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 14,984.0 15,012.0 6,693.3 6,699.6 4/12/2015 (PERF 6 spf,60 deg phasing _ Mandrel Inserts GAS LIFT;11,651.0 (ti St ,- ati on Top(TVD) Valve Latch Port Size TRO Run _ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 4,668.3 2,998.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,938.0 3/12/2015 - 2 8,464.0 4,503.9 CAMCO KBMG 1 GAS LIFT GIV 0.188 1,872.0 3/10/2015 3 11,651.0 5,698.7 CAMCO KBMG 1 GAS LIFT OV BTM 0.250 2,500.0 3/10/2015 LOCATOR;12,084.0 Notes: General&Safety End Date Annotation PBR;12,086.0 CINOTE: PACKER;12,109.51.1 I I �I XO-Threads;12,180.5 •F-Of i MULE SHOE;12,182.3 .( • \ ., • _. =... 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J0 V Oma' Z N O co I— N 0 ce a 8 O coa Om J W = Ce a 0 W 0Z U 0 O o Z Q r_ N df o o O- c 0 • Na a) • r E U8M 0 w O J Q o a CI H 0 0 C LL N_ c c0 • N ea re N M W //� J N A J co O r V Q O 0 z -CO U co Z d • CV 0 • G m t0 - -a ch 3 N d d CI r- V w in A U U £ E d • • dk3 - 00(71.11 WELL LOG TRANSMITTAL (7 .z [5- o28 To: Alaska Oil and Gas Conservation Comm. October 7, 2015 Attn.: Meredith Guhl 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 REDEWED OCT 092015 RE: Perforation Record: 2N-312 and CD3-130 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-312 and CD3-130 Perforation records for 2N-312 4 color logs 2 t oM Perforation records for CD3-130 2 color logs 2 SLt( 3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Ig (1 Signed: DELVED 2 1 3 1 6 0 • ' 296,.) 26265 chiumberger AOGCC Transmittal if: 29SEP15-SP02 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery `l iZ9i2015 K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Meredith Guhl Well No: CD3-130 Date Dispatched: 29-Sep-15 Job#: 14AKA0043 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD x x Scope Resistivity 2"ND x x Scope Resistivity 5"MD Scope Resistivity 5"ND x x LAS Digital Data N/A Contents on CD x Directional Data N/A Contents on CD Nad27 x As-Built Survey N/A Contents on CD Nad83 x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter@slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 ✓� '�/ Received By: t6 2.X3 —\ Lea RECEIVED ConocoPhillips APR 2 7 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 23, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7111 Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space.. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, 7an ,:y. C„........_ MJ oveld ConocoPhillips Well Integrity Projects Supervisor aI, ConoconlIllps Alaska helico Surface Casing by 5-AgAcion•Anni9Q.is Cement, Corrosion inbiUtor°, Seal5an;:Top-off Report of Sundry Operations(10404) Alpine Field Date 4123/2015 CD3 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD3-121 50103206150000 2100220 32" NA 32" NA 29.7 3/12/2015 CD3-122 50103206090000 2091530 74" NA 74" NA 49.3\ii) 3/12/2015 tD3-130 50103206770000 2131600 38" NA 38" NA 20.4 3/12/2015 CD3-198 50103206370000 2110240 28" NA 15" NA 2.5 3/24/2015 CD3-316 50103205590300 2140180 9" NA 26" NA 14 4/20/2015 CD3-320 50103206670000 2130060 6" NA 6" NA 1.7 3/24/2015 RECEIVED • STATE OF ALASKA • APR 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AEGlatib la.Well Status: Oil ❑. Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development O , Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. • or Aband.: February 28,2015• 213-160/314-686/315-104 3.Address: 6.Date Spudded: 30 M.fs 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 January?.44;2014 WO 50-103-20677-00 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4037'FNL, 1243'FEL,Sec.5,T12N, R5E, UM February 8,2015' CRU CD3-130 ' Top of Productive Horizon: 8. KB(ft above MSL): 49'RKB 15.Field/Pool(s): 2512'FSL,2144'FEL,Sec.33,T13N, R5, UM GL(ft above MSL): 12.6'AMSL Colville River Field . 9.Plug Back Depth(MD+TVD): Total Depth: 286'FSL, 1050'FEL,Sec.28,T13N, R5E,UM 15081'MD/6714'TVD' Fiord Oil Pool - 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-387799 y- 6003744 Zone-4 .15757'MD/6822'TVD ADL 364472,364471,372104,372105 TPI: x-394898 y- 6010189 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-396027 y- 6013227 Zone-4 SSSV @ 2260'MD/1995'TVD Tobin#931986,931976 18.Directional Survey: Yes ❑ . 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) 1262'MD/1241'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 GR/Res,CBL/CCL/GR • 13133'MD/6159'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20"x34" 78.6# A-53 37' 115' 37' 115' 42" 5.5 sx Ready Mix 10.75" 45.5# L-80 36' 3354' 36' 2480' 13.5" 1373 sx ALC,310 sx Class G 7.625" 29.7# L-80 34' 13150'(BOW) 34' 6164' 9.875" 441 sx Class G 6" 20.1# EX80 12148' 15090' 5854' 6716' 7.875" Expandable liner 24.Open to production or injection? Yes ❑ 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) 4.5 x 3.5 12185' 12109'MD/5842'TVD solid liner perfs from 14984'-15012'MD 6692'-6698'TVD 6 spf perfs behind liner from 13193'-13198'MD 6178'-6179'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. perfs behind liner from 13105'-13110'MD 6151'-6152'TVD Was hydraulic fracturing used during completion? Yes❑ No❑✓ "+w DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 15090' 47 bbls 16.2 ppg cement Z �5 13193'-13198' 15.3 bbls 15.8 ppg cement 27. - PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) April 14,2015 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/15/2015 12.0 Test Period--> 237 1794 460 100% 5401 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 303 psi 1102 24-Hour Rate-> 431 3633 907 not available 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+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. NONE Form 10-407 Revised 10/2012 / �7 CONTINUED ONGR�`$E�tSE RBDM APR 2 Sit original only G ATL Gt 13I/� T PA 6 {IF/r 29. GEOLOGIC MARKERS(List all formations and marncountered): 30. • FORMATION TESTS NAME I MD TVD Well tested? Yes Ell 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 1262' 1241' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk C 14987' 6694' Nechelik 15507' 6566' N/A Formation at total depth: Kuparuk C 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32. I hereby certify that the foregoing is true and corr he best of m knowledge. 2Z_Pcx its Contact: Danny Kane @ 265-6048 Email: Danny.Kane .conocophillips.com Printed Name G. L.�Alvord Title: Alaska Drilling Manager Signature .C Q� Phone 265-6120 Date 4(2- -la l5 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 WNS PROD CD3-130 ConocoPhillips 4 Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cc,.ROPlvnpc 501032067700 FIORD KUPARUK PROD 15,757.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD3-130,4/23/20152'.30'.17 PM SSSV:TRDP Last WO: 3 6.6 0 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 4/15/2015 HANGER;31.1 .. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ------------------------------------' --- CONDUCTOR 20 19.124 36.6 115.6 115.6 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread SURFACE 103/4 9.950 36.6 3,353.8 2,480.5 45.50 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ..,. .., INTERMEDIATE 75/8 6.875 34.2 14,309.5 6,511.8 29.70 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW 6.8 13,133.0 13,150.0 6,164.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 6 5.340 12,148.2 15,090.0 6,716.3 20.10 EX-80 XPC XO Reducing;111.4 ' Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB)_Top Incl(3 Item Des Corn (in) CONDUCTOR;36.6-115.6 12,148.2 5,854.2 71.94 TAPER GUIDE TAPER GUIDE EX-80 5.340 12,149.0 5,854.4 71.93 HANGER/ HANGER&SEALS.085 VITON,EX-80- 5.340 SEALS UNEXPANDED sssv;2,259.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-41/2x3 31/2 2.992 31.1 12,184.9 5,865.6 9.30 L-80 EUE 1/2 @111.42 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.00 HANGER FMC HANGER-ELASTOMER 3.958 111.4 111.4 0.12 XO Reducing XO-41/2"IBT(B)x31/2"EUE 8 RD(P) 2.992 SURFACE;36.6-3,353.8 2,259.8 1,995.3 49.22 SSSV CAMCO TRMAXX-53 W/2.812"X PROFILE 2.812 12,084.0 5,834.4 72.26 LOCATOR BAKER LOCATOR 2.992 12,086.0 5,835.0 72.25 PBR BAKER PBR 3.000 GAS LIFT;4,668.3 12,109.5 5,842.2 72.11 PACKER BAKER FHL RETRIEVABLE PACKER 2.910 12,133.0 5,849.5 71.98 NIPPLE XLINE LANDING XN NIPPLE,NO GO 2.750 12,182.3 5,864.8 71.92 MULE SHOE BAKER AUTO ENTRY SHOE 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) -- 13,133.0 6,159.1 71.87 WHIPSTOCK TOW 13,133'&BOW 13,150' 1/29/2015 lig Perforations&Slots GAS LIFT;8,464.0 Shot Dens Top(TVD) Bim(TVD) (shots/f Top(ftKB) BOB(ftKB) (ftKB( (ftKB) Zone Date t) Type Com 14,984.0 15,012.0 6,693.3 6,699.6 4/12/2015 IPERF 6 spf,60 deg phasing Mandrel Inserts GAS LIFT;11,851.0 St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn -f 4,668.3 2,998.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,938.0 3/12/2015 2 8,464.0 4,503.9 CAMCO KBMG 1 GAS LIFT GIV 0.188 1,872.0 3/10/2015 3 11,651.0 5,698.7 CAMCO KBMG 1 GAS LIFT OV BTM 0.250 2,500.0 3/10/2015 LOCATOR;12,064.0- Notes:General&Safety PBR;12.0000 = End Date Annotation imi NOTE. PACKER;12,109.5 I • I ,I ; I 00-Threads;12,180.5 I `/ MULE SHOE;12,182.3- I v. II! 000 U h IP370 � - 'It' WINDOW; {Vs �f i`, ' I INTERMEDIATE;34.2-14,309.5 IPERF;14,984.0-15,012.0 LINER;12,148.2-15,090.0 ' CD3-130 PRE-RIG WELL WORK DATE SUMMARY • 10/12/2014 TAGGED TOP OF CEMENT @ 13920' SLM w/2.73" CENT, SAMPLE BAILER. IN PROGRESS 10/13/2014 RAN CEMENT BOND LOG f/ 13935'- 13000' RKB &7409'-4709' RKB. COMPLETE 1/11/2015 STAGED EQUIPMENT FOR CD3-103 CEMENT SQUEEZE. TROUBLESHOT TOOLSTRING COMMUNICATION PROBLEMS BETWEEN WELLTEC TRACTOR AND GAMM/CCL TOOLS. COMMUNICATION PROBLEMS SOLVED AND WILL CONTINUE WORK TOMORROW. ***IN PROGRESS*** 1/12/2015 SET SPIRAL PLUG WITH MID ELEMENT AT 13272'. SET PLUG WITH CCL STOP DEPTH OF 13246.3' WITH A 25.7' CCL TO PLUG OFFSET. 1/13/2015 PERFORATED INTERVALS 13193-13198'AND 13105-13110'. PERFORATED WITH 2.5" HSC GUNS, 6 SPF, 11 gm. HMX CHARGES AND 60 DEG PHASING. CORRELATED TO GAMMA RAY ON SLB MWD LOG DATED 22-FEB-14. 1/14/2015 INJECTIVITY TEST DOWN TBG FOR CTU INITIAL T/I/O= 273/273/323 FINAL T/I/0=1358/1358/452 JOB COMPLETE 1/16/2015 PERFORMED WEEKLY BOPE TEST. DRIFTED TO 13,192' CTMD APPROXIMATELY 88' OFF TOP OF BRIDGE PLUG. DECISION MADE TO RUN MEMORY LOG TO CORRELATE RETAINER SETTING DEPTH. ELECTRICAL AND MECHANICAL COUNTERS WERE OFF DEPTH AFTER RETUNING TO SURFACE. JOB IN PROGRESS. 1/17/2015 PERFORMED CORRELATION LOGGING RUN FOR RETAINER SETTING DEPTH CONTROL. FLAGGED EOP AT 13,142.42'MD DEPTH ENCODERS ON COIL UNIT OFF 40 FEET. JOB IN PROGRESS. 1/17/2015 RIH WITH INFLATABLE CEMENT RETAINER, STOP AT FLAG CORRECT TO 13152.63'THAT CENTER OF ELEMENT. DROP .5"ALUMINUM BALL, PUMPED 2 COIL VOLUMES, BALL NEVER MADE IT TO SEAT. DROP .5" PHONOLIC BALL. PUMPED COIL VOLUME AND A HALF. NO GO. POOH TO CHECK TOOLS. 1/18/2015 ATTEMPTED TO SET INFLATABLE CEMENT RETAINER AT13,175' MD. RETAINER APPEARS TO HAVE SOFT SET IN CASING. LEFT RETAINER IN WELL (8.57' OAL). RECOVERED REMAINDER OF BHA. DRIFTED TUBING TO 2500' CTMD ESTABLISHED INJECTION RATE OF .5BPM AT 2500 PSI. WELL FREEZE PROTECTED JOB COMPLETE. • ConacaPhillips Time Log & Summary Wellview Web Reporting Report Well Name: CD3-130 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/21/2015 1:00:00 AM Rig Release: 3/3/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/18/2015 24hrSummary Secure well and RD. Move Ball Mill from CD2-40 to CD3-130. Move Pits and Motors. Skid rig floor back. Replace tire on rig sub. Move Pipe shed. 14:00 17:30 3.50 INTRM1 MOVE MOB T Prep Rig for move. Start rig generators and take Rig off of highline power. Review Move checklist. Electrician disconnected Rig from pit complexes. Note: Rig off or high line power at 15:30 hrs, 1/18/15 17:30 00:00 6.50 INTRM1 MOVE MOB T Skid rig floor back and secure rig. Replace rig tire on the sub. Move Ball Mill to CD3-130 location. Move Pits/Motors and Pipe shed to CD3 via ice road. 31/19/2015 Finish moving Pits/Motors and Pipe shed to CD3-130. Move rig Sub, camp and shop. Spot rig next to the well. Spot modules. Swap out cellar wind walls. Spot camp on location. Rig up. 00:00 06:45 6.75 INTRM1 MOVE MOB T Continue moving Motors/Pits and pipe shed onto CD3-130 location. Change tire on rig sub. Position and fuel rig for move. 06:45 19:00 12.25 INTRM1 MOVE MOB T PJSM. Move rig from CD2-40 to CD3-130. Spot rig next to well and spot modules. Move camp and shop to CD3-130. 19:00 22:00 3.00 INTRM1 MOVE MOB T Continue to move camp and shop to CD3-130 spot on pad. 22:00 00:00 2.00 INTRMI MOVE MOB T Rig up camp. Replace wind walls on 'the rig cellar. 01/20/2015 C/O cellar wind walls. Move sub on pad. Spot sub over well. Spot pits&motors. Rig up. 00:00 08:00 8.00 INTRMI MOVE MOB T Prep well for sub. C/O cellar wind walls. Set sewer plant containment. 08:00 15:00 7.00 INTRM1 MOVE MOB T Set herculite&matts for pits/motors complex. Prep to move sub on pad. Cont.with wind walls 15:00 18:00 3.00 INTRM1 MOVE MOB T Move sub on pad. Sub spotted @ 18:00 hrs. 18:00 21:00 3.00 INTRM1 MOVE MOB T ,Lower support feet. Secure rear wind walls. Skid floor into drilling position 21:00 22:00 1.00 INTRM1 MOVE MOB T Spot pits&motors to sub. 22:00 00:00 2.00 INTRM1 MOVE MOB T Connect service lines. Position high linbe.Work on pre-spud check list. Spot ball mill Page 1 of 28 Time Logs ill 4 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/21/2015 24hrSummary Cont. rigging up.Accept rig. Pre spud meeting. R/U tiger tank. R/U to displace out diesel. Displace out+/- 300 bbls diesel w/9.6 ppg brine. Flow check. Install BPV&test(good). N/D tree&N/U B.O.P.'s 00:00 00:30 0.50 ! INTRM1 MOVE MOB T Cont.to spot ball mill&work on rig acceptance check list. 00:30 01:00 0.50 INTRM1 MOVE SFTY T Pre-spud meeting. 01:00 02:15 1.25 INTRM1 MOVE RURD T Work on high line. Rig accepted @ 01:00 hrs. Rig on high line @ 02:15 _hrs. Reposition MPD equip in cellar. 02:15 06:30 4.25 INTRM1 WELCTL RURD T Spot tiger tank. R/U to displace. Work on frozen choke hose. Replace heater&apply steam to lines. 06:30 07:30 1.00 INTRM1 WELCTL MPSP T R/U lubricator&test to 3500 psi. Pull BPV. I/A 0 psi&0/A 250 psi. 07:30 08:30 1.00 INTRM1 WELCTL RURD T Cont.to rig up to displace. Load pit #6 w/9.6 ppg brine. 08:30 09:45 1.25 INTRM1 WELCTL KLWL T PJSM. Pump 104 bbls of 9.6 ppg brine w/3 bpm @ 140-270 psi.Take _returns to tiger tank. 09:45 10:45 1.00 INTRM1 WELCTL KLWL T Shut in well&let fluid migrate w/U tube across top of well 10:45 11:30 0.75 INTRM1 WELCTL KLWL T Pump 100 bbls of 9.6 ppg brine w/3 bpm @ 310-320 psi.Take returns to tiger tank. 11:30 13:00 1.50 INTRM1 WELCTL KLWL T Shut in well&let fluid migrate w/U tube across top of well 13:00 13:30 0.50 INTRM1 WELCTL KLWL T Pump 100 bbls of 9.6 ppg brine w/3 bpm @ 250-260 psi.Take returns to tiger tank. 13:30 15:30 2.00 INTRM1 WELCTL KLWL T Shut in well&let fluid migrate w/U tube across top of well. Pre-spud meeting with daylight crew @ 14:00 hrs 15:30 16:00 0.50 INTRM1 WELCTL KLWL T Pump 100 bbls of 9.6 ppg brine w/3 bpm @ 130-290 psi.Take returns _to tiger tank. 16:00 18:00 2.00 INTRM1 WELCTL KLWL T Shut in well&let fluid migrate w/U tube across top of well 18:00 18:45 0.75 INTRM1 WELCTL KLWL T Pump 100 bbls of 9.6 ppg brine w/3 bpm @ 320-350 psi.Take returns to tiger tank. Pumped total of 500 bbls w/100%returns. 18:45 19:45 1.00 INTRM1 WELCTLOWFF T Observe well for 30 min on low psi gauge. No increase in psi. 10 psi on I/A&500 psi on 0/A. Observe well for 30 min open to atmosphere. Slight ooze 19:45 21:00 1.25 INTRM1 WHDBO MPSP T Install BPV and test to 1000 psi& chart for 10 min(good) 21:00 00:00 3.00 INTRM1 WHDBO NUND T PJSM. B/D lines. N/D tree&install blanking plug. N/U BOPE stack. N/D dutch riser adaptor. SIMOPS-C/0 saver sub on top drive. 01/22/2015 Cont. to N/U BOPE and MPD equip. Test MPD equip. Test BOPE. C/0 man/auto!BOP. 00:00 05:00 5.00 INTRM1 WHDBO NUND T Cont.to N/U BOPE. N/U MPD spool &riser. Page 2 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 10:45 5.75 INTRM1 WHDBO MPDA T R/U MPD euipment in cellar(lines& valves) 10:45 14:00 3.25 INTRM1 WHDBO MPDA T Fill lines&PSI test on MPD equipment. Body test, flow line, butterfly valves&flow meter 100 psi for 5 min (good)Choke valves, chok manifold, &orbit valve 250/1200 psi for 5 min (good) 14:00 15:30 1.50 INTRM1 WHDBO RURD T R/U to test B.O.P.'s. M/U 3 1/2"test jt. Fill lines w/H20 15:30 17:00 1.50 INTRM1 WHDBO WAIT T Wait on AOGCC to witness BOPE test 17:00 23:00 6.00 INTRM1 WHDBO BOPE T Test BOPE w/3 1/2&4"test jts. (Annular&HCR choke/kill 250/2500 psi&chart for 5 min-passed) (Choke valves#1 - 14, HCR choke/kill, man choke/kill, needle valve,dart valve, FOSV, upper/lower 3 1/2"x 6"VBR's, blind rams to 250/3500 psi for 5 min-passed) (Man/auto IBOP fail&digital gauges on choke fail/pass) Draw down test on man/super choke to 1100 psi. Accumulator test, Int 3100 psi/1500 psi after function, 27 sec to first 200 psi& 170 sec to full system psi. 4 bottles @ 1975 psi. Gas alarms tested. Test witnessed by AOGCC Louis Grimaldi 23:00 00:00 1.00 INTRM1 WHDBO BOPE T PJSM. C/O manual&auto IBOP on top drive. 01/23/2015 Cont.to C/O man&auto IBOP&test. Button up top drive. Pull blanking plug&BPV. M/U landing jt A&pull hanger. Circ B/U. F/C 00:00 11:00 11.00 INTRM1 WHDBO BOPE T Cont to change out auto&man IBOP. Body test auto&man IBOP. Auot failed. Changed out auto IBOP with new one from Doyon 141. Adjusted timing on valve and body test auto IBOP(good test) 11:00 12:00 1.00 INTRM1 WHDBO BOPE T Test&chart auto&man IBOP 250/3500 psi for 5 min (good) 12:00 20:15 8.25 INTRM1 WHDBO BOPE T Button back up top drive. R/U fedder rings&sfatey wire. 20:15 21:00 0.75 INTRM1 WHDBO MPSP T Bleed off psi from IA. Pull BPV. M/U test jt&pull blanking plug. (<1bbl of diesel back) 21:00 22:45 1.75 2,298 2,264 INTRMI RPCOM PULL T M/U landing jt A&pull tubing hanger to rig floor. (95k to pull hanger free) 22:45 23:30 0.75 2,264 2,264 INTRM1 RPCOM CIRC T M/U XO to 3 1/2"tubing&circ B/U w/250 gpm @ 220 psi 23:30 00:00 0.50 2,264 2,264 INTRMI RPCOM OWFF T Observe well for flow. (Slight ooze then static) 01/24/2015 POOH&L/D 3 1/2"tubing. M/U scraper BHA#1 &RIH while picking up 4" DP to HES stage collar. Ream thru stage collar. Circ B/U. Cont. in hole while picking up 4" DP to 9,670' 00:00 00:15 0.25 2,264 2,264 INTRM1 RPCOM OWFF T Cont.to F/C&B/D top drive Page 3 of 28 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 03:30 3.25 2,264 0 INTRM1 RPCOM PULL T POOH while laying down 3 1/2"kill string f/2,264'to surface 03:30 04:15 0.75 0 0 INTRM1 PLUG RURD T Install mouse hole&set 7.0625" wear ring. 04:15 07:15 3.00 0 147 INTRMI PLUG BHAH T P/U BHA tools&M/U Baker scraper BHA to 147' 07:15 17:30 10.25 147 6,865 INTRM1 PLUG PULD T RIH f/147'to 6,685'while P/U 4" DP. Fill pipe every 2,000' 17:30 18:00 0.50 6,865 6,865 INTRM1 PLUG SFTY T Safety stand down 18:00 18:45 0.75 6,865 6,931 INTRM1 PLUG COCF T Obtain T&D parameters-PU 140 k, SO 100 k, ROT 120 k, 60 rpm @ 5.5 k trq.W&R f/6,865'to 6,931'w/5 bpm @ 540 psi. No indication of stage collar. (stage collar 6,911'to 6,914') 18:45 19:15 0.50 6,931 6,931 INTRM1 PLUG CIRC T Circ B/U w/8 bpm @ 1240 psi 19:15 19:30 0.25 6,931 6,931 INTRM1 PLUG OWFF T F/C&B/D top drive 19:30 00:00 4.50 6,931 9,670 INTRM1 PLUG PULD T RIH f/6,931'to 9,670'while P/U 4" DP. Fill pipe every 2,000' 31/25/2015 RIH w/clean out BHA to 13,003'. Circ B/U.Wash in hole to 13,240'. Spot pill. POOH. L/D clean out BHA#1. 00:00 04:45 4.75 9,670 13,003 INTRM1 PLUG PULD T Pick up drill pipe 4" Drill pipe from 9,670'to 13,003'. Fill pipe every 2,000'. Up wt 215k DN wt 108k Calculated Disp 77.4bbls Actual Disp 75.5bbls 04:45 05:45 1.00 13,003 13,003 INTRM1 PLUG CIRC T Circulate and condition fluid to 9.6ppg in and out. 300gpm @ 1,480psi. Reciprocate pipe while circulating. 05:45 07:45 2.00 13,003 13,240 INTRM1 PLUG WASH T Wash down from 13,003'to 13,240' 250gpm 1,076psi Did not encounter any obstructions while washing in the hole. 07:45 08:30 0.75 13,240 13,198 INTRM1 PLUG CIRC T Spot 25bbls polymer pill in hole f/13,240'to 13,198'w/5 bpm @ 780 psi. 08:30 08:45 0.25 13,198 13,097 INTRM1 PLUG PMPO T Pump OOH f/13,198'to 13,097'w/6 bpm @ 780 psi 08:45 10:00 1.25 13,097 13,003 INTRM1 PLUG CIRC T Circ B/U w/300 gpm @ 1300 psi. Rack back 1 stand f/13,097'to 13,003' 10:00 10:30 0.50 13,003 13,003 INTRM1 PLUG OWFF T F/C(static) 10:30 21:30 11.00 13,003 604 INTRM1 PLUG TRIP T POOH on elevators on TT f/13003'to 604'. 21:30 21:45 0.25 604 604 INTRM1 PLUG OWFF T F/C(static) 21:45 23:30 1.75 604 0 INTRM1 PLUG BHAH T Rack back HWDP. L/D clean out BHA#1 as per Baker rep. 23:30 00:00 0.50 0 0 INTRM1 PLUG BHAH T L/D BHA tools. Clear&clean floor. C/O elevators 01/26/2015 M/U K-1 cement reatainer. RIH w/retainer to 13,155'. Squeeze cement. Circ clean. POOH f/13,155'to 12,122'. Cut&slip drill line. Service rig. Cont.to POOH f/12,122'to 11,741' Page 4 of 28 411 Time Logs S Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 INTRM1 PLUG BHAH T M/U K-1 cementreatiner&XO as per baker rep 00:30 10:45 10.25 0 12,694 INTRM1 PLUG TRIP T RIH with retainer to 12,694'with pipe out of the derrick breaking circulation every 3,000'. No anomolies going through stage collar at 6,911'. 10:45 11:30 0.75 12,694 13,155 INTRM1 PLUG PULD T Continue to trip in the hole with the retainer picking pipe up from the shed f/12,694'to 13,155' 11:30 11:45 0.25 13,155 13,155 INTRMI PLUG MPSP T Set cement retainer as per Baker rep @ 13,155'. Ensure set w/35k set wt &35k pull test, 11:45 12:30 0.75 13,155 13,155 INTRM1 PLUG RURD T R/U to test. PJSM on suicide squeeze. 12:30 13:00 0.50 13,155 13,155 INTRMI PLUG PRTS T Test cement retainer to 1000 psi& chart(good) 13:00 13:45 0.75 13,155 13,155 INTRM1 PLUG CIRC T Perform circulation test. Pump w/.5bpm @ 2440 psi. Not able to establish circulation. Pumped away 15 bbls. 13:45 14:00 0.25 13,155 13,155 INTRM1 PLUG MPSP T P/U to 150k, apply 10 wraps to the right&release from retainer. 14:00 14:45 0.75 13,155 13,155 INTRM1 PLUG RURD T P/U&break out single jt. B/D top drive. Remove bell guide&R/U head pin. R/U to cement. 14:45 16:00 1.25 13,155 13,155 INTRM1 PLUG CIRC T Circ one DP volume of 136 bbls w/3 bpm @ 260 psi. (270 psi through choke) 16:00 18:00 2.00 13,155 13,155 INTRMI PLUG SQEZ T Perform cement squeeze. Dowell pump 1.5 bbls&pressure test to 4000 psi. Dowell pump 5.8 bbls 11.5 ppg mud push, 15.3 bbls 15.8 ppg cement, 5 bbls mud push,& 1.5 bbls H20. Rig pump 107.8 bbls of 9.6 ppg brine w/3 bpm @ 290-320 psi& while holding back pressure with choke. Sting into retainer&squeeze cement w/.5 bpm. ICP 2230 psi& FCP 2090 psi. Pumped total of 129.2 bbls of brine. CIP @ 17:55 hrs 18:00 18:15 0.25 13,155 13,075 INTRM1 PLUG RURD T Bleed off psi. Unsting from retainer. R/D cement lines&hoses. 18:15 18:30 0.25 13,075 13,075 INTRM1 PLUG TRIP T POOH f/13,155'to 13,075' 18:30 20:00 1.50 13,075 13,075 INTRM1 PLUG CIRC T Circ 2 B/U w/330 gpm @ 1220- 1360 psi. 20:00 20:45 0.75 13,075 13,075 INTRM1 PLUG OWFF T F/C(static)SIMOPS B/D top drive& kill line, Install bell guide&prep to POOH 20:45 22:00 1.25 13,075 12,122 INTRM1 PLUG TRIP T POOH on elevators on TT f/13,075'to 12,122' 22:00 23:00 1.00 12,122 12,122 INTRMI PLUG SLPC T Slip&cut 60'drill line 23:00 23:30 0.50 12,122 12,122 INTRM1 PLUG SVRG T Service rig&top drive 23:30 00:00 0.50 12,122 11,741 INTRMI PLUG TRIP T POOH on elevators on TT f/12,122'to 11,741' Page 5 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 31/27/2015 24 hr Summary Cont.to POOH f/11,741'. L/D running tool. M/U Baker clean out BHA#3. RIH to 12,898'.W&R to 13,155'. Circ clean. Spot 200 bbl lube pill. 00:00 07:30 7.50 11,741 0 INTRM1 PLUG TRIP T POOH on elevators on TT f/11/741'to Surface. &L/D running tool. (F/C @ HWDP-static) 07:30 08:15 0.75 0 138 INTRM1 PLUG BHAH T M/U Baker clean out BHA#3 as per Baker rep to 138' 08:15 16:30 8.25 138 10,419 INTRM1 PLUG TRIP T RIH w/clean out BHA w/stands from derrick f/138'to 10,419'. Fill pipe every 20-stds. 16:30 20:00 3.50 10,419 12,898 INTRM1 PLUG PULD T Cont.to RIH while P/U remaining 4" DP from pipe shed f/10,419'to 12,898' 20:00 22:15 2.25 12,898 13,155 INTRM1 PLUG REAM T W&R in hole f/12,898'to 13,155'. (Tag cement stringer @ 13,060')Tag top of retainer @ 13,155'without rotation with 15 k WOB PU wt 250k, SO wt 108k, ROT wt 150k,50 rpm w/10.5- 13.5 k ft/lbs trq 22:15 00:00 1.75 13,155 13,155 INTRM1 PLUG CIRC T Pump 27 bbls high vis sweep&circ B/U w/390 gpm @ 1940 psi. Pump& spot 200 bbls lube pill w/390 gpm @ 1780 psi. 01/28/2015 POOH f/13,155'&L/D clean out BHA. M/U MPD element stand. Hand pinched finger. Safety stand down. Cont.to M/U MPD element to running tool. M/U whipstock/milling BHA. 00:00 00:30 0.50 13,155 13,155 INTRM1 PLUG OWFF T F/C(static). SIMOPS B/D top drive, install air slips. Prep to POOH 00:30 09:00 8.50 13,155 45 INTRMI PLUG TRIP T POOH one elevators on trip tank f/13,155'to 45'. F/C @ HWDP. Racked back HWDP. Hole fill calc 78.9 bbls/act 76 bbls 09:00 10:00 1.00 45 0 INTRM1 PLUG BHAH T L/D Bakewr clean out BHA. Clear rig floor of BHA toolsw. 10:00 10:30 0.50 0 0 INTRM1 WHPST MPDA T M/U 2 singles DP to MPD running tool. Bring up to floor MPD stabbing stand. MPD hand pinched finger in stabbing stand 10:30 18:45 8.25 0 0 INTRM1 WHPST SFTY T Safety stand down due to MPD hand pinched finger. SIMOPS all rig personnel hazard hunt. 18:45 20:45 2.00 0 0 INTRM1 WHPST MPDA T PJSM. M/U MPD element to running tool. Satnd back in derrick. 20:45 00:00 3.25 0 113 INTRM1 WHPST BHAH T M/U whipstock milling BHA as per Baker rep&SLB rep to 113' 01/29/2015 Safety stand down with night crew. RIH w/whipstock/mill assy to 1,600'. Shallow test(good). Cont.to RIH& tag cement retainer @ 13,155. Set whip stock. Displace to 9.8 ppg LSND. Mill window from TOW @ 13,133'• to 13,138' 00:00 00:30 0.50 113 113 INTRM1 WHPST SFTY T Safety stand down with night crew. Monitor well on trip tank. 00:30 02:15 1.75 113 1,603 INTRMI WHPST TRIP T RIH with whipstock/milling assembly f/113'to 1,603' Page 6 of 28 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 02:45 0.50 1,603 1,603 INTRMI WHPST DHEQ T Break circulation with 250 gpm @ 950 psi&shallow hole test MWD (good) 02:45 13:45 11.00 1,603 12,967 INTRM1 WHPST TRIP T RIH with whipstock/milling assembly f/1,603'to 12,967'. Fill pipe every 20 stands 13:45 17:00 3.25 12,967 13,133 INTRM1 WHPST WPST T Orient whipstock to 64 degree right. Wash do f/12,967'to 13,155'.w/250 gpm @ 1440-1530 psi. Tag cement retainer @ 13,155. PU wt 200 k& SO wt 130 k. Set anchor w/13 k& shear off whipstock w/30 k (Planned TOW 13,133'&BOW 13,150') 17:00 19:15 2.25 13,133 13,133 INTRM1 WHPST DISP T PJSM-Pump 33 bbl spacer& displace to 9.8 ppg LSND w/295 gpm @ 2120 psi. Take SPR's 19:15 19:45 0.50 13,133 13,133 INTRM1 WHPST OWFF T F/C(static)Obtain T&D parameters &prep to mill window PU wt 200 k&SO wt 130 k w/pumps off. ROT wt 150, 80 rpm @ 9.5 k ft/lbs trq w/250 gpm @ 1700 psi. 19:45 00:00 4.25 13,133 13,138 INTRM1 WHPST MILL T Millwindowf/13,133'to 13,138' w/250 gpm @ 1700 psi&w/80-100 rpm @ 12-15 k trq. (TOW 13,133'&BOW 13,150') 01/30/2015 • Cont.to mill window as per Baker rep(TOW 13,133'&BOW 13,150')Drill new formation to 13,175'. Pump sweep&circ clean. FIT to 12.5 ppg. Install MPD element. POOH&L/D milling BHA. Clear&clean floor. 00:00 03:00 3.00 13,138 13,150 INTRM1 WHPST MILL T Cont.to mill window(/13,138'to 13,150'w/250 gpm @ 1700 psi& w/80-100 rpm @ 12- 15 k trq. (TOW 13,133'&BOW 13,150') 03:00 04:30 1.50 13,150 13,175 INTRM1 WHPST DDRL T Drill 25'new hole with milling assembly f/13,150'to 13,175'MD 6,171'TVD ADT 1.5 hrs 270 gpm 2060 psi&w/100 rpm 13.5 -14.8kft/Ibstrq. 04:30 05:30 1.00 13,175 13,103 INTRM1 WHPST REAM T Ream thru window w/270 gpm @ 1990 psi&w/100 rpm @ 13 k trq. Work thru window once without rotation. 2-3 k drag across slide. POOH to above top of window to 13,103' 05:30 06:45 1.25 13,103 13,103 INTRM1 WHPST RGRP T Trouble shoot mud pump#2. Replace stem on 4" Demco isolation valve.Test to 3500 psi(good) 06:45 08:30 1.75 13,103 13,103 INTRM1 WHPST CIRC T Pump 38 bbl high vis super sweep& circ clean w/300 gpm @ 2400 psi& w/25 rpm @ 6.8 k tq. 08:30 09:00 0.50 13,103 13,103 INTRMI WHPST OWFF T F/C(static) B/D top drive. 09:00 10:00 1.00 13,103 13,103 INTRM1 WHPST FIT T Peform FIT to 12.5 ppg 10:00 10:30 0.50 13,103 13,103 INTRMI WHPST OWFF T F/C(static)SIMOPS-PJSM on installing MPD element. Page 7 of 28 Time Logs S S Date From To Dur S. Depth E. Depth Phase `Code Subcode T Comment 10:30 11:00 0.50 13,103 13,103 INTRM1 WHPST CIRC T Pump 38 bbls 14 ppg dry job 11:00 11:30 0.50 13,103 13,103 INTRM1 WHPST MPDA T Install MPD element 11:30 20:00 8.50 13,103 642 INTRM1 WHPST TRIP T Strip OOH w/MPD @ 3.5 bpm f/13,103'to 642'.40 psi in slips& 400 psi while pulling. 20:00 20:15 0.25 642 642 INTRM1 WHPST OWFF T F/C(static) 20:15 21:30 1.25 642 642 INTRM1 WHPST MPDA T PJSM. Remove RCD element. B/D @ Balance linmes&cmnt lines. 21:30 00:00 2.50 642 0 INTRM1 WHPST BHAH T Rack back HWDP. L/D milling BHA as per SLB&Baker reps. (starter mill 1/8"under gauge&upper mill full gauge)Clear&clean floor of BHA tools. 31/31/2015 Flush stack. R/U&test BOPE. M/U 6.80"milling BHA. RIH to 10,087'. Slip&cut drill. Service rig. RIH f/10,087'to10,844 00:00 00:30 0.50 0 0 INTRM1 WHPST BHAH T Cont. to clear&clean floor of BHA tools. 00:30 02:30 2.00 0 0 INTRM1 WHPST WWWH T FMC pull wear ring. M/U stack washer w/magnet&flush stack. L/D stack washer&drain stack. B/D top drive 02:30 03:30 1.00 0 0 INTRM1 WHDBO RURD T R/U to test BOPE. Set 4"test jt. Fill stack&lines w/H20. C/O valve on test pump. 03:30 09:30 6.00 0 0 INTRM1 WHDBO BOPE T Test BOPE w/4"&6"test jts. (Annular&HCR choke/kill 250/2500 psi&chart for 5 min-passed) (Choke valves#1 -14, HCR choke/kill, man choke/kill, needle valve,dart valve, FOSV, upper/lower 3 1/2"x 6"VBR's, blind rams to 250/3500 psi for 5 min-passed) Draw down test on man/super choke to 1100 psi.Accumulator test, Int 3075 psi/1450 psi after function, 35 sec to first 200 psi&203 sec to full system psi. 4 bottles @ 1988 psi. Gas alarms tested. Test waived by AOGCC Johnny Hill 09:30 10:30 1.00 0 0 INTRM1 WHDBO RURD T R/D testing equipment. Set 7 1/16" wear ring. 10:30 11:30 1.00 0 89 INTRM1 WHPST BHAH T M/U 6.80"milling BHA as per Baker rep to 89' 11:30 21:15 9.75 89 10,087 INTRM1 WHPST TRIP T RIH w/6.80"milling BHA f/89'to 10,087'. Fill pipe every 20 stands. 21:15 22:30 1.25 10,087 10,087 INTRM1 WHPST SLPC T PJSM. Slip&cut 68'of drill line. 22:30 23:00 0.50 10,087 10,087 INTRM1 WHPST SVRG T Service rig&top drive. 23:00 00:00 1.00 10,087 10,844 INTRM1 WHPST TRIP T RIH w/6.80"milling BHA f/10,087'to 10,844'. Fill pipe every 20 stands. 02/01/2015 Cont.to RIH to 13,133'. Enlarge window to 13,175'. Circ hole clean. Install MPD element. Strip OOH w/MPD. L/D milling BHA. Dummy run w/DPC(Change out drilling bails w/16'bails) 00:00 02:30 2.50 10,844 13,101 INTRM1 WHPST TRIP T RIH w/6.80"milling BHA f/10,844'to 13,101'. Fill pipe every 20 stands. Page 8 of 28 Time Logs • • Date From To Dur` S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 13,101 13,133 INTRM1 WHPST WASH T Wash down f/13,101'to 13,133'&tag top of window w/2k. 300 gpm @ 1800 psi, PU wt 200 k, SO wt 120 k, ROT wt 145 k, 80 rpm 10.5 k trq 03:00 05:30 2.50 13,133 13,175 INTRM1 WHPST REAM T Enlarge windo f/6.75"to 6.80"w/300 gpm @ 1800 psi&w/80 rpm @ 12.5 - 14 k trq. 05:30 08:00 2.50 13,175 13,101 INTRMI WHPST CIRC T Pump 37 bbls super sweep&circ hole clean w/350 gpm @ 2260 psi. Once sweep out of bit in open hole pulled out to above window&finished circ clean inside casing w/20 rpm @ 10 k trq. 08:00 08:30 0.50 13,101 13,101 INTRMI WHPST OWFF T F/C(static)SIMOPS-PJSM on installing MPD element. 08:30 08:45 0.25 13,101 13,101 INTRM1 WHPST CIRC T Pump 35 bbls of 13.8 ppg dry job. 08:45 09:30 0.75 13,101 13,101 INTRM1 WHPST MPDA T Install MPD element. 09:30 10:00 0.50 13,101 13,101 INTRM1 WHPST SFTY T Safety stand down with D crew 10:00 18:15 8.25 13,101 1,014 INTRM1 WHPST TRIP T Stripp OOH @ 3.5 bpm with MPD f/13,101'to 1,014'.40 psi on slips& 400 psi while pulling. 18:15 18:30 0.25 1,014 1,014 INTRM1 WHPST OWFF T F/C(static)SIMOPS-PJSM on removing MPD element. 18:30 19:15 0.75 1,014 1,014 INTRM1 WHPST MPDA T M/U to MPD running tool&remove RCD element. B/D @ Balance lines &cmnt lines. 19:15 19:45 0.50 1,014 182 INTRM1 WHPST TRIP T POOH on elevators on TT f/1,014'to 182'. (Racked back HWDP) 19:45 23:15 3.50 182 0 INTRM1 WHPST BHAH T L/D 6.80"milling BHA as per Baker rep. (L/D spiral collars). Clear& clean floor 23:15 00:00 0.75 0 INTRM1 WHPST RURD T Dummy run w/DPC(Drill Pipe Circ) Change out drilling bails w/16'long bails 02/02/2015 Cont.to R/U DPC lines&equipment. Dummy run&function test w/DPC. Install drilling bails.Test standpipe, kelly hose&cement lines to 5000 psi. M/U 6 3/4"kick off BHA. RIH to 7,800' 00:00 13:15 13.25 0 0 INTRM1 WHPST RURD T Cont.to R/U DPC lines&equipment. R/U DPC tool to long bails. Perform dummy run with DPC tool&fuction test. (good). Install safety cables on DPC lines in derrick. Swap out bails to drilling bails&install 4"elevators 13:15 15:15 2.00 0 0 INTRM1 WHPST SEQP T R/U&test surface lines(standpipe, kelly hose, &cement lines)to 5000 psi&chart for 10 min. (good)R/D testing equip. 15:15 17:45 2.50 0 477 INTRM1 WHPST BHAH T M/U RSS kick off BHA#6 as per SLB to 477'(Power drive X6, ImPulse,VPWD, FS, UBHO,Jars, HWDP) 17:45 18:15 0.50 477 1,890 INTRM1 WHPST TRIP T RIH w/BHA#6 to 1,890' 18:15 18:45 0.50 1,890 1,890 INTRM1 WHPST DHEQ T Fill pipe&shallow hole test MWD w/220 gpm @ 1030 psi --- Page 9of28_ Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 00:00 5.25 1,890 7,800 INTRM1 WHPST TRIP T RIH w/BHA#6 f/1,890'to 7,800'. Fill pipe every 20 stds 02/03/2015 RIH to TOW. Install MPD element&finger print MPD. R/U E-line. Drill kick off f/13,175' to TD of 13,353'md. RU E-Line. RIH with Gyro tool.Attempt to thaw wire line packoff. 00:00 04:30 4.50 7,800 13,067 INTRM1 WHPST TRIP T RIH w/BHA#6 f/7,800'to 13,067'. Fill pipe every 20 stds. Calc/Actual= 78.77/75.0 bbl. Flo-chk-static PU= 195K, S0= 115K lb. 04:30 05:15 0.75 13,067 13,067 INTRM1 WHPST MPDA T PJSM. Install MPD element. Set 30K down then pull test to 25K lb- good. POOH and LD running tool. 05:15 06:45 1.50 13,067 13,067 INTRM1 WHPST MPDA T Perform MPD finger print with 100-250 bbl/min, 860-22,00 psi, 50 rpm, 11K TQ. PU=210K, S0= 110 K, ROT= 145K while pumping and holding back pressure. 06:45 07:00 0.25 13,067 13,067 INTRM1 WHPST CIRC T SPRs- 13,175'md, 0650 hrs MP#1: 20-720,30-930 MP#2: 20-720,30-930 Held table top Kick While Drilling drill 07:00 07:15 0.25 13,067 13,162 INTRM1 WHPST TRIP T RIH from 13,067'to 13,162'. Stab hung up at 13,147'and with 8K stack out. PU 5'and worked STAB down. 07:15 07:30 0.25 13,162 13,175 INTRM1 WHPST REAM T RIH from 13,162'to 13,175'with pumps and rotary at 250 gpm, 2,390 psi, 60 rpm, 9.5K TQ. 07:30 12:00 4.50 13,175 13,325 INTRM1 DRILL DDRL T Kick off and drill from 13,175'to 13,325',ADT=3.29,TVD=6,224'. 12:00 12:30 0.50 13,175 13,325 INTRM1 DRILL DDRL T Drill ahead from 13,325'to 13,353', cumulative ADT=3.77,TVD=6,224'. 12:30 14:15 1.75 13,175 13,325 INTRM1 DRILL CIRC T CBU at 230 gpm, 2,060 psi, 80 rpm, 14K TQ SPRs- 13,353'md, 1400 hrs MP#1: 15-640,25-840 MP#2: 15-640,25-840 14:15 15:15 1.00 13,175 13,325 INTRM1 DRILL OWFF T Flow-chk with a slight ooze, decreasing to static. Perform stick test checking break over hook load at 10 min-ok/15-ok/20 min- okay. 15:15 16:15 1.00 13,175 13,325 INTRM1 DRILL ELOG T RU wire line adapter, pack-off,XOs and TIW valve. 16:15 22:00 5.75 13,175 13,325 INTRM1 DRILL ELOG T Unable to MU crossover to pack-off. RD WL adapter and E-line. Trouble shoot. MU WL adapter, pack-off and Gyro tool. PJSM for WL. Re-check WL head. Page 10 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 13,175 13,325 INTRM1 DRILL ELOG T Continue to work pipe every 20 min. Run Gyro to above TIW and check for obstructions. Position Gyro, close TIW and attempt to pressure test to 1,000 psi. Hose to pack-off had a pin hole leak. Replace hose. Pressure test TIW-packoff to 1,000 psi-good. Attempt to run Gyro but no-go past 500'. PU to 1,700 lb on wire line. RU steam hose and attempt to thaw pack-off. Maintained circulation with 1.1 bbl/min, 530-540 psi and full returns. 02/04/2015 RIH/Pump-in-hole with gyro. Gyro hole to confirm dog legs. POOH with Gyro, RD E-Line. Strip-OOH with DP. Handle BHA. 00:00 03:15 3.25 13,175 13,325 INTRM1 DRILL ELOG T Continue to work pipe every 20 min. Continue to thaw pack-off and goose-neck on TD with steam hose and blanket wrap. Made an attempt to PU on WL tool and PU weight had increased 600 lb over previous attempt(more freezing). Maintained circulation with 1.1 bbl/min, 530-540 psi and full returns.Warmed mud in pits to 70 deg for circulation. Gain/ Loss=0 bbl. 03:15 04:00 0.75 13,325 13,352 INTRM1 DRILL FLOG T PJSM. Slack-off from 13,338'to 13,352'. Break connection and blow down TD using the mud-bucket. Attach top hat wireline support. PU and pull on wireline and had movement, verifying tool was free down hole, inside DP. 04:00 06:30 2.50 13,352 13,352 INTRM1 DRILL FLOG T PJSM. Break WL pack-off connection at TD and inspect.WL pack-off and WL entry guide were frozen.Thaw pack-off free of ice with steam line. Could not thaw goose neck beyond the apex. Continue to work pipe every 20 min. 06:30 07:00 0.50 13,352 13,352 INTRM1 DRILL FLOG T PJSM. MU WL pack-off to entry guide on TD. Continue to work pipe every 20 min. Gain/Loss=0 bbl. 07:00 08:00 1.00 13,352 13,352 INTRM1 DRILL FLOG T PJSM. Pull Gyro tool from 500'. Work string every 20 min. Gain/ Loss=0 bbl. 08:00 08:45 0.75 13,352 13,352 INTRM1 DRILL FLOG T PJSM. LD Gyro tool, RD WL Entry Guide and pack-off from TD. RD TIW valve and 4"lubricator joint. (Entry guide was packed full with ice). Install bull plug in goose neck on TD. 08:45 09:15 0.50 13,352 13,352 INTRM1 DRILL SEQP T Blow down TD to ensure there was no residual ice from steaming. Blow down cement line and MPD equip. Pressure test Kelly hose and bull plug to 3,500 psi-good. Page 11 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:00 1.75 13,175 13,325 INTRM1 DRILL CIRC T C&C with 200 gpm, 1,850 psi, 80 rpm, 13.5-14.0 TQ 11:00 11:45 0.75 13,325 13,067 INTRM1 DRILL PMPO T Pump-OOH from 13, 353'to 13,067' with 3.5 bpm, 1,040 psi. 13,215'-overpull= 15K lb 13,195'-overpull= 18K lb 13,190'-overpull=20K lb 13,187'-overpull= 15K lb(rotate 1/4 turn and pull) 11:45 12:00 0.25 13,067 13,067 INTRM1 DRILL OWFF T Flow-chk-static. Blow down TD. 12:00 12:30 0.50 13,067 13,067 INTRM1 DRILL CIRC T Pump 35 bbl, 13.3 lb/bbl slug. Blow down TD and line up to MPD. 12:30 21:45 9.25 13,067 477 INTRM1 DRILL TRIP T Strip OOH from 13,067'to 477'hold 400 psi back pressure with MPD and 40 psi back pressure at connections. 21:45 22:15 0.50 13,067 477 INTRM1 DRILL OWFF T Flow chk for 30 min-static. Clean rig floor, PU MPD running tool. 22:15 00:00 1.75 13,067 477 INTRMI DRILL MPDA T Pull RCD element and LD. MU new RCD element on running tool and stand back. 32/05/2015 Test BOPE. RD test equip. PU/MU RSS BHA#7 and RIH. 00:00 00:45 0.75 477 477 INTRM1 DRILL MPDA T Blow down MPD lines and mud lines. PJSM for handling BHA. 00:45 01:00 0.25 477 113 INTRM1 DRILL BHAH T POOH from 477'to 113'laying down BHA(rack back Jars and HWDP). Calc/Actual fill=81.7/94.0 bbl 01:00 02:30 1.50 113 0 INTRM1 DRILL BHAH T LD MWD/LWD tools&PD X-6 02:30 04:30 2.00 0 0 INTRM1 WHDBO RURD T Drain stack. Clear and clean rig floor. Pull 7.0625"ID WB. Set 4"test jt and test plug. Fill stack, chk manifold and lines with water. 04:30 12:30 8.00 0 0 INTRM1 WHDBO BOPE T BOPE Test: Test w/4"test joint, Annular to 250/2,500 psi for 5 min, Test UPRs and LPR 3.5 x 6"VBRs to 250/3,500 psi. Tested choke valves#1 -14, auto&man IBOP, HCR choke&kill,4"Demco,4" FOSV, dart&needle valves, HCR choke&kill to 250/3500 psi for 5 min. (all good). Koomey test; IP= 3,000 psi,After close= 1,400 psi, 200 psi recovery 33 sec, full recovery 192 sec, N2-4 bottle average= 1,900 psi.Tested gas alarms. Witness of test waived by AOGCC John Crisp. Note: changed out two valves on test pump. (repaired 2 manifold valves& 1 test pump valve) 12:30 17:15 4.75 0 0 INTRM1 WHDBO BOPE T Test w/6"test joint,Annular to 250/2,500 psi for 5 min, Test UPRs and LPR 3.5 x 6"VBRs to 250/ 3,500 psi. . (all good). 17:15 18:00 0.75 0 0 INTRMI WHDBO RURD T R/D testing equipment. Pull test plug &set wear ring. B/D lines Page 12 of 28 Time Logs II S Date From To Dur S. Depth E.`Depth Phase Code Subcode T Comment 18:00 18:45 0.75 0 0 INTRM1 DRILL BHAH T P/U BHA tools to rig floor 18:45 00:00 5.25 0 180 INTRM1 DRILL BHAH T M/U BHA#7 as per SLB to 180'(PD X-6, ImPilse,VPWD,ADN,XBat, Stabs, Riptide, NMDC, HWDP, & Jars) Load Nukes in LWD 02/06/2015 RIH with RSS BHA#7. Shallow test MWD-ok. Continue to RIH to above window at 13,042'md. Cut and Slip DL. Install MPD element. Pass thru window ok,wash to btm. Open under-reamer and drill ahead. 00:00 01:00 1.00 0 183 INTRM1 DRILL BHAH T Change out from 3-1/2"to 4"DP. Set Reamer below rotary table and pump at 155 gpm and 500 psi and verified reamer was not open. Blow down TD. 01:00 02:00 1.00 183 1,485 INTRM1 DRILL TRIP T RIH with 4"HWDP from 183'to 548' and DP to 1,485'. 02:00 02:30 0.50 183 1,485 INTRM1 DRILL DHEQ T Shallow pulse test MWD with 260 gpm, 1,560 psi-good. 02:30 12:30 10.00 1,485 13,042 INTRM1 DRILL TRIP T Continue RIH to 13,042'filling pipe every 20 stds. Fill pipe. PJSM for cut and slip. Calc/Actual=77.5 bbl /75.5 bbl. 12:30 13:45 1.25 13,042 13,042 INTRM1 DRILL SLPC T Cut and slip 60'of drill line.Adjust brake 13:45 14:15 0.50 13,042 13,042 INTRM1 DRILL SVRG T Service TD and drawworks. 14:15 14:45 0.50 13,042 13,042 INTRM1 DRILL SEQP T Calibrate block height for MWD 14:45 15:45 1.00 13,042 13,042 INTRM1 DRILL MPDA T PJSM. Install MPD element. Set down with 30K lb and lock in place. Pull test to 30K-good. Pump with 115 gpm, 890 psi and pressure test MPD to 50 psi-good. J-out from MPD element and stand back running tool. PU=200K, S0= 125K. 15:45 16:00 0.25 13,042 13,092 INTRM1 DRILL DHEQ T Calibrate XBAT caliper tool rotating at 30 rpm and 12.5K TQ. 16:00 16:45 0.75 13,092 13,333 INTRM1 DRILL TRIP T RIH from 13,092'to 13,333'with 8-12K drag as STABs passed thru the window. 16:45 17:15 0.50 13,333 13,333 INTRM1 DRILL REAM T Pump with 265 gpm,2,650 psi with MWD turbine rpm at 3,840 rpm with 100%flow and 12.5K baseline torque.Tag btm at 13,353'md. 17:15 18:30 1.25 13,333 13,333 INTRM1 DRILL CIRC T Drop 1.25"reamer activation ball and pump down with 2.7-5.0 bbl/min, 1,180-1,800 psi,20 rpm, 12K TQ(bit at 13,333'and UR blades at 13,194'). Ball on seat with 200 bbl pumped. Stage pump pressure up to 1,800/ 1,900 psi and had MWD turbine rpm drop from 3,840 to 3,540 rpm, pump pressure decreased by 100 psi and rotary TQ briefly spiked to 14K ft-lb. Page 13 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:00 1.50 13,333 13,353 INTRM1 DRILL REAM T Ream 3-5'sections from 13,333'to 13,348'with 265 bbl/min, 2,450 psi, 23 rpm 12.5K TQ and attempt to tag up on reamed ledges to confirm reamer is open. No weight/torque changes seen due to probable hole wash out. All other indications that reamer is open. Confer with town and send down links to MWD tool. 20:00 00:00 4.00 13,353 13,615 INTRM1 DRILL DDRL T Drill 6-3/4"x 7-7/8"hole from 13,353 to 13,615'. ADT=2.63 hrs, TVD= 6,305'. PU=208K, SO= 112K, ROT= 149K, TQ on/off= 18.8/13K ft-lb with 2% Lo-Torque lube SPRs- 13,373'md,2300 hrs MP#1: 20-870, 30- 1,130 02/07/2015 Drill ahead 6-3/4"x 7-7/8"hole to 15,115'md. (daily footage= 1,500') 00:00 12:00 12.00 13,615 14,262 INTRM1 DRILL DDRL T (Drill 6-3/4"x 7-7/8"hole from 13,615' to 14,282'. ADT= 11.07 hrs, TVD= 6,476'. PU=215K, SO= 118K, ROT= 149K, TQ on/off= 16.5/15.5K ft-lb with 2.5%Lo-Torque lube ECD:11.93 ppg SPRs-14,282'md, 1130 hrs MP#1: 20- 1,090, 30- 1,310 MP#2: 20- 1,080, 30- 1,300 12:00 00:00 12.00 14,262 15,115 INTRM1 DRILL DDRL T Drill 6-3/4"x 7-7/8"hole from 14,262' to 15,115'. ADT=9.05 hrs,TVD= 6,722'. PU=235K, SO= 106K, ROT= 151K, TQ on/off= 18.0/12.5K ft-lb with 2.0% Lo-Torque/0.5%MI-776 lube ECD: 12.02 ppg SPRs-15,046'md, 2315 hrs MP#1: 20- 1,240, 30- 1,450 MP#2: 20- 1,230, 30- 1,450 32/08/2015 Drill ahead 6-3/4"x 7-7/8"hole to 15,757'md. (daily footage=642'). Pump sweep, CBU 2X, pump 2nd sweep, CBU 3X. PJSM, displace well to 11.5 ppg LSND. Flo-chk,Attempt to strip-OOH, Taking wt. 00:00 11:45 11.75 15,115 15,757 INTRM1 DRILL DDRL T Drill 6-3/4"x 7-7/8"hole from 15,115' to 15,757'..ADT=8.96 hrs,TVD= 6,821'. PU=228K, SO= 102K, ROT= 150K, TQ on/off= 15.5/13.5K ft-lb with 2.0%Lo-Torque/0.5%MI-776 lube ECD: 11.71 ppg SPRs- 15,713'md, 1010 hrs MP#1: 20- 1,010, 30- 1,210 MP#2: 20- 1,000, 30- 1,240 11:45 12:00 0.25 15,757 15,757 INTRM1 CASING SRVY T Take MWD check shot on btm with 285 gpm, 3,130 psi. Page 14 of 28 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 19:00 7.00 15,757 15,757 INTRM1 CASING CIRC T PJSM. Circ clean w/285-300 gpm ©3130-3450 psi. Pump 30 bbl, 11.8 ppg weight sweep followed by CBU 2X. Pump second weighted sweep followed by CBU 3X. Had sand returns followed by predominantly splintered shale with decreased and finer sized shale cuttings after the second sweep. 19:00 23:30 4.50 15,757 15,757 INTRM1 CASING DISP T Displace f/9.8 ppg LSND to 11.5 ppg LSND. Initial circ rate of 6 bpm @ 3150 psi&final circ rate of 1 bpm @ 410 psi as per pump schedule. Total stokes pumped 7218 stks 23:30 23:45 0.25 15,757 15,757 INTRM1 CASING OWFF T F/C(static)BD top drive. 23:45 00:00 0.25 15,757 15,757 INTRM1 CASING TRIP T Attempt to Strip OOH on MPD w/2.5 bpm @ 170 psi. Started pulling tight with 350 k PU wt(Decision made to pump out of hole) 02/09/2015 Strip-OOH taking caliper readings and holding backpressure with MPD. Pass thru window, flo-chk. Strip-OOH to 3,288'. 00:00 01:00 1.00 15,757 15,617 INTRM1 CASING BKRM T BROOH from 6-3/4"pilot hole from 15,757'to 15,617'with 40 rpm, 12-18K TQ, 1 bpm,410 psi, overpulling with 5-10K. SPRs-15,757'md, 00:15 hrs MP#1: 10-410 01:00 08:15 7.25 15,617 13,130 INTRM1 CASING DLOG T POOH from 15,617'to 13,130'at 600' -300'/hr making XBAT caliper survey, holding 250 psi back pressure and 40 psi at the connections. When stabilizers passed thru the window had 10-15K overpull. PU=220K, SO=115K lb. 08:15 08:30 0.25 13,130 13,042 INTRMI CASING DHEQ T Make calibration check of XBAT tool, inside csg,from 13,130'to 13,042'at 30 rpm, 11.5K TQ. PU=210K, SO= 115K, ROT= 148K w/o pumps. 08:30 11:15 2.75 13,130 13,042 INTRM1 CASING OWFF T Monitor well while retrieving DP drift from ice plug in DP racked back in derrick. 11:15 12:30 1.25 13,130 13,042 INTRMI CASING CIRC T Circ at 2.5 bbl/min, 130 psi while drifting and knocking frost/ice out of unused DP in derrick 12:30 00:00 11.50 13,042 3,288 INTRM1 CASING TRIP T Strip-OOH from 13,042'to 3,288', holding MPD back pressure and 40 psi at the connections as per the tripping schedule. PU= 100K, SO=95K lb. 02/10/2015 Continue to strip-OOH, retrieve MPD element,flo-chk, POOH and handle BHA. PU csg tools and monitoring equip. PU/MU expandable casing and equip. PU/MU expandable liner and RIH to 2,244'. Page 15 of 28 Time Logs • S Date From To Dur - S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 3,255 639 INTRM1 CASING TRIP T POOH from 3,288'to 639', holding MPD back pressure and 40 psi at the connections as per the tripping schedule. 02:15 03:15 1.00 639 639 INTRMI CASING MPDA T Flo-chk for 15 min-static. Pull MPD element and LD. Flo-chk static. 03:15 04:30 1.25 639 180 INTRM1 CASING TRIP T POOH from 639'to 180'. 04:30 06:00 1.50 639 97 INTRM1 CASING BHAH T PJSM. Rack back BHA to 97'and retrieve sources from MWD. 06:00 07:15 1.25 97 97 INTRM1 CASING BHAH T Inspect and LD reamer and BHA tools. LD XBAT tool to shed for downloading. 07:15 08:15 1.00 97 97 INTRM1 CASING BHAH T LD BHA tools and MPD element. Plug in and download MWD data. 08:15 09:00 0.75 97 0 INTRM1 CASING BHAH T LD remaining BHA tools. Calc/ Actual=95.3/125 bbl(pulling wet with heavy mud) 09:00 12:00 3.00 0 0 INTRM1 CASING RURD T Clear and clean rig floor. Install new MPD element on running tool. PU liner running tools to rig floor. 12:00 13:00 1.00 0 0 INTRM1 CASING RURD T PU csg tools and bring to rig floor. RU power tongs. 13:00 14:30 1.50 0 0 INTRM1 CASING RURD T PJSM. MU XO to floor safety valve, expandable liner shoe, launcher, debris barriers. 14:30 00:00 9.50 0 2,224 INTRMI CASING PUTB T PJSM. Test casing tong torque limit on pup jt.. Run 6", 20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner casing with 6.135"Wearsox cents(2/jt) on joints 1-67. MUT=7,000 ft-lb. Monitor and record MUT w/TQ-turn equip. Run 60 of 79 jts to 2,224"md. Fill pipe every 10 jts. Calc/Actual= 16/17 bbl for 60 jts. 02/11/2015 Continue running expandable liner, PU/MU liner hanger and set in slips/dog collar. RD csg equip, clear floor, RU work platform,false table/bowl and change to DP elevators. RIH with inner-string screw into liner safety sub,continue to run liner on DP to 10,423'md. SO= 105K lb 00:00 02:30 1 2.50 2,224 2,941 INTRM1 CASING PUTB T Continue to run 6",20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner casing without 6.135"Wearsox cents on joints 68-79. MUT=7,000 ft-lb. Monitor and record MUT w/TQ-turn equip. Run joints 61 -79 jts from 2,224'-2,941'md. Fill pipe every 10 jts. PU=90K, S0=85K lb for the liner. 02:30 03:30 1.00 2,941 2,941 INTRM1 CASING RURD T RD Power tongs,6"elevators and casing equip. RU work platform,false rotary table and bowl. Set liner in slips and dog collar. RU 4"DP elevators Page 16 of 28 Time Logs 4111 IP Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 08:30 5.00 2,941 2,941 INTRM1 CASING PUTB T PU/MU ACME thread screw in assembly and XOs on 4"DP, inner-string. Run inner-string inside 6"expandable csg and tag up Safety sub/cone assembly with 5K lb at 2,933'. Inner-string: PU=95K, SO= 90K lb at 2,933'. PU and rotate Inner-string at 3 rpm, 1.4K TQ (free-rotating)and ROT=90K lb. Shut down rotary and RD false table/bowl/slips and work platform. 08:30 08:45 0.25 2,941 2,941 INTRM1 CASING OTHR T Screw into Safety sub/cone with ACME thread assembly with 2 rpm, 1.2K TQ until stalling out TD with torque limiter set at 3.4K ft-lb. Fully made up after 8 wraps. Release trapped TQ. Liner+ Inner-string: PU= 138K, SO=123K lb. 08:45 09:30 0.75 2,941 2,941 INTRM1 CASING CIRC T Circ with 1 bbl/min, 300 psi. Blow down TD. 09:30 12:00 2.50 2,941 4,557 INTRM1 CASING RUNL T Continue to run 6", 20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner on DP from 2,933'to 4,557'md. Fill pipe every 20 stds with 9.8 ppg, LSND mud. SO= 100K lb at 4,557'. 12:00 00:00 12.00 4,557 10,423 INTRM1 CASING RUNL T Continue to run 6",20 Ib/ft, L-80, XPC-ORNU-GIIC, R3 liner on DP from 4,557'to 10,423'md. Fill pipe every 20 stds with 9.8 ppg, LSND mud. SO= 105K lb at 10,423'. Note: Fire Drill-CRT: 53 sec 02/12/2015 Continue running expandable liner filling with 9.8 ppg LSND. Install MPD element 10 stds above the window at 12,180'. Change out to long, 16'bails and rig up DPC. Continue to RIH,fill pipe prior to exiting the window. Continue to RIH in open hole to 14,434'. Fill and work pipe with with 35-50K overpull. 00:00 05:45 5.75 10,423 12,180 INTRM1 CASING RUNL T Continue to run 6",20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner on 4" DP from 10,423"to 12,180'md. Fill pipe every 20 stds with 9.8 ppg, LSND mud. SO= 115K lb 05:45 06:15 0.50 12,180 12,180 INTRMI CASING CIRC T Fill pipe with 9.8ppg LSND mud and break circulation for 9bbls at.5bpm 800psi. (Simops PJSM on installing MPD element) 06:15 07:00 0.75 12,180 12,180 INTRM1 CASING MPDA T Install MPD element. Set 30k down in bowl,function locking mechanism 24seconds to pressure up. Pull test to 30k.J out of element with 1 /4 turn.Apply 350psi back pressure and strip out and rack back element handling stand. 07:00 10:45 3.75 12,180 12,180 INTRMI CASING RURD T PJSM-R/D 4"DP elevators and 10' bails. R/U 16'bails, DPC,service lines&4"DP elevators, Function test DPC(Good)-Dry run DPC through derrick. Install safety cables. Page 17 off 28 Time Logs Date From To Dur S.-Depth E.Depth Phase Code Subcode T Comment 10:45 11:00 0.25 12,180 12,180 INTRM1 CASING SFTY T PJSM on tripping in hole with Liner on drill pipe with long bails and DPC tool. 11:00 12:00 1.00 12,180 12,370 INTRM1 CASING RUNL T Continue to run 6",20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner on 4"DP from 12,180'to 12,370'md. SO= 110K lb Function DPC motor on stands to check motor function and alignment 12:00 13:30 1.50 12,370 12,370 INTRM1 CASING EQRP T Decide to change DPC tool out for spare. Packing around wash pipe area appears to be too tight and laboring motor. Installed spare DPC tool aligned and function tested good with higher spin rate and break out effectiveness. Installed high pressure clamps on 1"high pressure lines on DPC head. 13:30 17:30 4.00 12,370 13,133 INTRM1 CASING RUNL T Continue to run 6",20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner on 4"DP from 12,370'to 13,133'md. PU= 242K S0= 112K lb(at the window). 17:30 18:00 0.50 13,133 13,133 INTRMI CASING CIRC T Fill pipe and break circulation with 9bbls at 1/2 bpm, 975psi 18:00 23:00 5.00 13,133 14,410 INTRMI CASING RUNL T Continue to run 6", 20 lb/ft, L-80, XPC-ORNU-GIIC, R3 liner on 4"DP from 13,133'to 14,410'and with DPC. Excess drag thru the shales 5-15K (avg approx 8K). Work thru tight spot at 14,410'(25K). 23:00 00:00 1.00 14,410 14,434 INTRM1 CASING RUNL P Pump down DP at 1.1 bpm, 1,240 psi at 14,434'md. PU to 300K(60K overpull)and breakover to 253K lb. Slackoff pumping 1.1 bpm, 1,240 psi to 14,510'and pump pressure increased to 1,450 psi.Work pipe up and weight broke over at 285K back to 252K lb. Confer with town and circulate hole at 1 bpm. 32/13/2015 Continue to work pipe and circulate from 14,373'to 14,606'md. 00:00 02:15 2.25 14,434 14,420 INTRM1 CASING RUNL T Continue to work pipe from 14,510'to 14,420'attempting to find a free spot to establish circulation. Up wt 275K max overpull of 320k. Hold 530psi back pressure while picking up. Page 18 of 28 Time Logs • Date From To Dur " S. Depth E. Depth Phase Code Subcode T Comment 02:15 05:00 2.75 14,420 14,420 INTRM1 CASING CIRC T Circulate and condition well starting at.7bpm working pump rate to 2.7bpm I,070psi to 1,380psi. Several pack off attempts no more than 100psi over circulating pressure. Displacing 11.5ppg LSND in the well with 9.8ppg LSND #1 MP lined up on the backside for back pressure pump with 11.5ppg LSND #2 MP lined up down the drill pipe with 9.8ppg LSND Move pipe down 1'while circulating for pipe management. 05:00 09:30 4.50 14,420 14,373 INTRM1 CASING CIRC T Hole packed off-Shut down pump bleed off pressure. MPD Holding back pressure.Work pipe free to 14,373'. Continue to displace well starting at .5bpm working up to 5bpm increasing pump rate by.25bpm every OH volume pumped(3lbbls). 540-950psi Cont.displace out 11.5ppg LSND on backside with 9.8ppg LSND. 09:30 10:15 0.75 14,373 14,347 INTRM1 CASING WASH T PJSM. Wash down from 14,373'to 14,393'with 5 bbl/min, 1,340 psi. Hole packed off,shut down pump and bleed off. PU to 14,347'pulling to 320K Ib, slack back off. 10:15 10:30 0.25 14,347 14,347 INTRM1 CASING CIRC T C&C staging pump from 0.5-2 bpm, 540-950 psi. 10:30 12:00 1.50 14,347 14,434 INTRMI CASING RUNL T Hold 300 psi back pressure with MPD and RIH with 6"liner on 4"DP from 14,347'to 14,434'md. 12:00 00:00 12.00 14,434 14,617 INTRM1 CASING RUNL P Hold 300 psi back pressure with MPD and RIH with 6"liner on 4" DP from 14,434'to 14,617'md. 02/14/2015 Continue to work pipe and circulate from 14,617'to 14,758'md. 00:00 12:00 12.00 14,617 14,705 INTRMI CASING RUNL P Hold 2-300 psi back pressure with MPD and RIH with 6"liner on 4" DP from 14,617'to 14,705'md. 12:00 00:00 12.00 14,761 14,758 INTRM1 CASING RUNL P Hold 2-300 psi back pressure with MPD and RIH with 6"liner on 4"DP from 14,761'to 14,758'md. 02/15/2015 Continue to work pipe with limited progress. Establish circulation and work through pack off events. 00:00 07:15 7.25 14,758 14,765 INTRM1 CASING RUNL P PJSM. Continue to work pipe from 14,758'to 14,765'holding 250-300 psi backpressure with MPD. 07:15 14:30 7.25 14,765 14,765 INTRM1 CASING CIRC T PJSM. Attempt to establish circulation with 0.5 bbp with hole trying to pack off. Blow down TD and continue to work pipe. Page 19 of 28 Time Logs 10 Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 14,765 14,737 INTRM1 CASING RUNL P PJSM.Work pipe to 14,737' and establish circulation. Stage pump up from 0.5-2.2 bpm, 810-1,180 psi. 18:00 00:00 6.00 14,737 14,737 INTRM1 CASING CIRC T PJSM. Continue to circulate at 14,737' with hole packing off several times before bringing rate to 3.5 bpm. Stage pump up from 0.5-3.5 bpm, 810-1,600 psi adding MI-776 lube to system (2%). 02/16/2015 Continue to work pipe from 14,764'to 14,812'. Establish circulation at 0.4-4.0 bpm and work through pack off events. 00:00 09:00 9.00 14,737 14,764 INTRM1 CASING CIRC T PJSM.Work pipe back from 14,737' to 14,764'.. Stage pump from 0.2 bpm to 1.1 bpm with hole packing off. 09:00 12:00 3.00 14,764 14,773 INTRM1 CASING RUNL P Work pipe past obstruction from 14,764'to 14,773'. 12:00 00:00 12.00 14,773 14,812 INTRM1 CASING RUNL P PJSM.Work pipe from 14,773'to 14,812'holding 50-200 psi back pressure with MPD. Circ at 0.8 to 2.5 bpm and 840-907 psi. PU=310K, S0=81K at 14,809' 02/17/2015 Cont. to work pipe&attempt to circ f/14,812'to 14,840'. (Packing off) 00:00 14:30 14.50 14,812 14,840 INTRMI CASING RUNL P Work pipe from 14,812'to 14,840' holding 50-200 psi back pressure with MPD. Circ at 0.5 to 3 bpm and 780-950 psi. PU Wt=310K, SO Wt= 105 K at 14,840' Pumped 90 bbls bead sweep w/no success 14:30 00:00 9.50 14,840 14,840 INTRMI CASING CIRC T Working pipe&attempt to get circulation w/1 spm to 5 spm @ 390 -640 psi. Hole packing off. @ Balance holding 50 psi on down stroke&200 psi on up stroke. (Racked back stand#157 in derrick &working stand#156 f/14,819 to 14,825') 02/18/2015 Cont. to work pipe&attempt to circ f/14,840'to 14,885'. 00:00 03:30 3.50 14,840 14,846 INTRM1 CASING RUNL P Work pipe from 14,840'to 14,846'. Holding 50-200 psi back pressure with MPD. 03:30 04:30 1.00 14,846 14,846 INTRM1 CASING CIRC T Attempt to circulate with hole packing off 04:30 14:45 10.25 14,846 14,851 INTRM1 CASING RUNL P Work pipe from 14,846'to 14,851'. Holding 50-200 psi back pressure with MPD. PU wt 295 K&SO wt 110 K 14:45 15:00 0.25 14,851 14,851 INTRMI CASING CIRC T Break circulation w/0.5 bpm @ 820 psi 15:00 16:45 1.75 14,851 14,869 INTRMI CASING RUNL P Work pipe from 14,851'to 14,869'. Holding 50-200 psi back pressure with MPD. 16:45 17:00 0.25 14,869 14,869 INTRM1 CASING CIRC T Break circulation w/1 bpm @ 880 psi Page 20 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:15 3.25 14,869 14,877 INTRM1 CASING RUNL P Work pipe from 14,869'to 14,877'. Holding 50-200 psi back pressure with MPD. PU wt 295 K&SO wt 110 K 20:15 20:30 0.25 14,877 14,877 INTRM1 CASING CIRC T Break circulation w/0.5 bpm @ 810 psi 20:30 00:00 3.50 14,877 14,885 INTRM1 CASING RUNL P Work pipe from 14,877'to 14,885'. Holding 50-200 psi back pressure with MPD. PU wt 315 K&SO wt 75 K 32/19/2015 Cont. to work pipe f/14,885'to 15,046 00:00 18:00 18.00 14,885 15,009 INTRMI CASING RUNL P Work pipe from 14,885'to 15,009'. Holding 50-100/200 psi back pressure with MPD. PU wt 315 K&SO wt 105 K 18:00 18:30 0.50 15,009 15,009 INTRM1 CASING CIRC T Break circ.w/.5 bpm @ 1180 psi. Hole packed off. 18:30 21:30 3.00 15,009 15,038 INTRMI CASING RUNL P Work pipe from 15,009'to 15,038'. Holding 50- 100/200 psi back pressure with MPD. 21:30 21:45 0.25 15,038 15,038 INTRM1 CASING CIRC T Attempt to circ. Hole packed off 21:45 22:45 1.00 15,038 15,043 INTRM1 CASING RUNL P Work pipe from 15,038'to 15,043'. Holding 50- 100/200 psi back pressure with MPD. PU wt 315 K&SO wt 105 K 22:45 23:00 0.25 15,043 15,043 INTRM1 CASING CIRC T Break circ.w/.5 bpm @ 1120 psi. 23:00 00:00 1.00 15,043 15,046 INTRM1 CASING RUNL P Work pipe from 15,043'to 15,046'. Holding 50- 100/200 psi back pressure with MPD. PU wt 310 K&SO wt 105 K 02/20/2015 Cont.to work pipe f/15,046 to 15,090'. Circ&cond mud for cement job. Packed off @ 3.5 bpm.Work liner& attempt to circ. 00:00 01:30 1.50 15,046 15,048 INTRM1 CASING RUNL P Work pipe from 15,046'to 15,048'. Holding 50- 100/200 psi back pressure with MPD. PU wt 310 K& SO wt 105 K 01:30 02:00 0.50 15,048 15,048 INTRM1 CASING CIRC T Break circ w/.5 bpm ICP= 1170& FCP 1000 psi. Hole packed off after 10.5 bbls pumped 02:00 05:00 3.00 15,062 15,062 INTRM1 CASING RUNL P Work pipe from 15,048'to 15,062'. Holding 50- 100/200 psi back pressure with MPD. PU wt 320 K& SO wt 100 K 05:00 06:45 1.75 15,062 15,062 INTRM1 CASING CIRC T Break circ&stage rate up to 1 bpm. ICP 840 psi&FCP 810 psi with full returns for 60 bbls.Attempt to increase flow rate to 1.3 bpm&hole packed off 06:45 15:30 8.75 15,062 15,090 INTRM1 CASING RUNL P Work pipe from 15,062'to 15,090'. Holding 50- 100/200 psi back pressure with MPD. PU wt 320 K& SO wt 100 K. Conference call with town&decision made to proceed with cementing&expanding liner. Page 21 of 28 Time Logs • • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 23:30 8.00 15,090 15,090 INTRM1 CEMEN"CIRC P Circ&condition mud for cement job. Initial .5 bpm @ 820 psi&Final 3.2 bpm @ 1100 psi. Increase rate from 3.2 bpm to 3.5 bpm @ 1250 psi& hole packed off. 23:30 00:00 0.50 15,090 15,090 INTRM1 CEMEN'CIRC T Working liner&attempting to circulate w/PU 360 k max. No circulation. Packed off. Line up on MPD&hold 200 psi back pressure while working pipe up. 02/21/2015 Work liner free w/375 k max PU wt.Attempt to circ. Hole cont to pack off. Establish injection rate. Bull head 47 bbls cement. Attempt to expand liner w/no success.Appeared liner ruptured down hole. Emergency left hand release from launcher. Establish circulation&start weighting up active system to 10.1 ppg. 00:00 02:15 2.25 15,090 15,090 INTRM1 CEMEN-CIRC T Working liner&attempting to circulate w/PU 375 k max&SO 60 k max. MPD hold 200 psi back pressure while working pipe up. Work pipe free. 02:15 09:30 7.25 15,090 15,090 INTRM1 CEMEN-CIRCT Break circulation w/.2 bpm @ 450 psi. Stage rate up to 1 bpm @ 720 psi. Hole packed off work pipe and attempt to circulate. Establish circulation again and packed off at 1.2bpm staged up at.3bpm. 09:30 12:30 3.00 15,090 15,090 INTRM1 CEMEN RURD P Lay down 2 joints of drill pipe. Pick up Baker cementing head and 14.63' pup joint and space out to 15,090' Rig up lines and valves on the rig floor for cement job. PSI test lines to 3500 psi(ggod) 12:30 14:00 1.50 15,090 15,090 INTRM1 CEMEN-CIRC T Establish injectivity test at 2bpm 2,730psi pump 6.5bbls away. Confer with town and decide to bull head cement. 14:00 18:00 4.00 15,090 15,090 INTRM1 CEMEN CMNT P PJSM . Pump 6.lbbls of warm water and pressure test lines to 4,000psi. Batch up and pump 20bbls of CW100,20bbls of 11.5ppg Mud Push II,47bbls of 16.2ppg Cement. Water on cement at 15:00hrs. Drop plug, push out with 5bbls of water verify dropped with tattle tail. Break bottom connection on cement head and install foam wiper ball. Displace and bump plug with 140bblslnjecting at 2bbls/min pump last 20bbls at 4bbls/min. Final pump pressure 3,000psi bump plug and hold 3,500psi. CIP at 18:00hrs 18:00 19:00 1.00 15,090 15,090 INTRM1 CEMEN-RURD P Break out cement head&R/D cement lines. 19:00 19:30 0.50 15,090 15,090 INTRM1 CEMEN SFTY P PJSM on expanding liner Page 22 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 23:00 3.50 15,090 15,090 INTRM1 CEMEN-OTHR T Pressure test lines to 7000 psi (good).Attempt to start expansion on liner as per Enventure reps. P/U on string to 325 k&psi up to 6200 psi,work pipe w/no movement. Bleed off to 3500 psi. P/U on string to 340 k&psi up to 6600 psi,work pipe w/no movement. Bleed off to 2000 psi. P/U on string to 375 k&psi up to 6800 psi,work pipe w/no movement. P/U on string to 380 k& psi up to 6600 psi,work pipe w/no movement. SO to 300 k&bleed off all psi. Set slips, LD 14,63 pup jt& P/U 1 jt DP. Line up on top drive& psi up to 300 psi.Work pipe down& attempt to clear any debris from launcher assembly. Increase to 500 psi&repeat same. PSI would not bleed off and appears launcher is packed off.Consult with town on plan forward. Decision made to attempt to expand @ max parameters. P/U on string to 385 k&psi up to 6800 psi. PSI bleed off to 5000 psi. P/U on string to 400 k&not able to maintain psi. Injecting fluid w/1.2 bpm @ 4500 psi. Observed leak on DPC tool. Bleed off psi&inspect tool(good). Attempt to PSI up&inject fluid w/1.3 bpm @ 3400 psi. Consult town& appears liner is ruptured around launcher. 23:00 23:30 0.50 15,090 15,043 COMPZ WELLPF OTHR T Emergency release from liner/launcher. Set torque stall @ 10 k max.Apply left hand torque&work pipe w/150 k down-225 k up& release from liner w/12.5 total wraps. P/U on string with 225 k hookload f/15/090'to 15,043' 23:30 00:00 0.50 15,043 15,043 COMPZ WELLPF CIRC T Break circulation&stage flow rate up to 2 bpm @ 1220 psi.Weight up active system to 10.1 ppg. SIMOPS -R/D cement hard lines 02/22/2015 Cont.to circ&wt up to 10.1 ppg while rigging down cementing&DPC equipment. C/O bails. Pump OOH f/15,043'to 12,140'. Circ clean&R/D DPC service loops. POOH on elevators f/12,140'to 11,662'. Set storm packer. R/U&test BOPE 00:00 04:30 4.50 15,043 15,043 COMPZ WELLPF CIRC T Cont to circulate&weight up to 10.1 ppg w/5 bpm @ 1970 psi. 560 bbls total. SIMOPS-R/D DPC tool& lines off of long bails. R/D long bails &R/U short bails. L/D cementing hardlines&DPC tools. 04:30 10:30 6.00 15,043 12,140 COMPZ WELLPF PMPO P Pump OOH w/3 bpm f/15,043'to 12,140'. Calc Fill= 17.82 bbls/Act Fill=29.5 bbls Page 23 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 12,140 12,140 COMPZ WELLPFSVRG P Service Rig 11:00 13:30 2.50 12,140 12,140 COMPZ WELLPF CIRC P Circ&cond.on top of liner w/460 gpm @ 2530 psi. SIMOPS-R/D DPC service lines from derrick. 13:30 14:30 1.00 12,140 11,662 COMPZ WELLPF TRIP P POOH on elevators f112,140'to 11,662' 14:30 15:30 1.00 11,662 11,662 COMPZ WELLPFMPDA P Remove RCD element. B/D MPD lines&equipment. 15:30 15:45 0.25 11,662 11,662 COMPZ WELLPFOWFF P F/C(static) 15:45 17:45 2.00 11,662 11,662 COMPZ WELLPF MPSP P M/U storm packer. PU wt 185 k& SO wt 115 k. Set storm back @ 120'.Test storm packer t/1000 psi for 10 min. 17:45 19:30 1.75 11,662 11,662 COMPZ WHDBO RURD P B/D lines&drain stack. Pull W/R& set test plug. R/U to test BOPE. Fill lines w/H20 19:30 00:00 4.50 11,662 11,662 COMPZ WHDBO BOPE P Test BOPE w/4"&4.5""test jts. (Annular&HCR choke/kill 250/2500 psi&chart for 5 min-passed) (Choke valves#1 -14, HCR choke/kill, man choke/kill, needle valve,dart valve, FOSV, upper/lower 3 1/2"x 6"VBR's to 250/3500 psi for 5 min-passed)Gas alarms tested. Test waived by AOGCC Bob Noble 02/23/2015 Cont to test BOPE. Retrieve storm packer. POOH f/11,662&L/D liner running tools.Test BOPE w/3 1/2" test jt. Brk down baker cement head. M/U mule shoe&RIH w/4" DP from derruick to 2,548'. 00:00 01:00 1.00 11,662 11,662 COMPZ WHDBO BOPE P Cont to test BOPE(Blind rams to 250/3500 psi for 5 min-passed) Draw down test on man/super choke to 1100 psi.Accumulator test, Int 3000 psi/1450 psi after function,28 sec to first 200 psi&200 sec to full system psi.4 bottles @ 1900 psi. Gas alarms tested.Test waived by AOGCC Bob Noble 01:00 02:15 1.25 11,662 11,662 COMPZ WHDBO RURD P R/D testing equipment. Set 7.875' wear ring. 02:15 04:00 1.75 11,662 11,662 COMPZ WELLPF MPSP P M/U Baker retrieval tool&RIH to engage storm packer. Engage packer&POOH&L/D same. 04:00 05:00 1.00 11,662 11,662 COMPZ WELLPF CIRC P Circ B/U w/420 gpm @ 2150 psi 05:00 05:30 0.50 11,662 11,662 COMPZ WELLPFOWFF P F/C(static) 05:30 06:00 0.50 11,662 11,662 COMPZ WELLPF CIRC P Pump 35 bbls 12.1 ppg dry job. B/D top drive. Install air slips 06:00 15:30 9.50 11,662 778 COMPZ WELLPF TRIP P POOH on elevators on TT f/11,662'to 778' 15:30 17:30 2.00 778 0 COMPZ WELLPF PULD P Cont. POOH while L/D 4"DP to pipe shed f/778'to Enventure jewlery. L/D jewlery. 17:30 18:15 0.75 0 0 COMPZ WELLPF BHAH P Clean&clear floor of enventure tools &equipment. Page 24 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 19:15 1.00 0 0 COMPZ WELLPF BOPE P Drain stack. Pull W/R&set test plug. R/U to test BOPE. Fill lines with H2O 19:15 20:15 1.00 0 0 COMPZ WELLPF BOPE P Test BOPE w/3 1/2"test jt. (Annular to 250/2500 psi for 5 min& upper/lower VBR's to 250/3500 psi for 5 min)Good Test 20:15 21:00 0.75 0 0 COMPZ WELLPF BOPE P R/D testing equipment. Set 8.75" thin wall W/R 21:00 21:45 0.75 0 0 COMPZ WELLPF PULD P P/U Baker cement head from pipe shed&break out pup jts. 21:45 00:00 2.25 0 2,548 COMPZ WELLPF TRIP P M/U mule shoe&RIH w/4" DP from derrick to 2,548' 02/24/2015 RIH w/4"DP to 6,140'. Slip&cut drill line. POOH&L/D 4" DP from derrick. RIH remaing 90 stds 4"DP& HWDP in derrcik to 9,100'. Pump dry job. Service rig. POOH whil;e L/D DP to 8,300' 00:00 03:30 3.50 2,548 6,140 COMPZ WELLPF TRIP P Cont.to RIH w/4"DP from derrick f12,548'to 6,140' Calc. Disp 35.1 /Act Disp 36 bbls 03:30 05:15 1.75 6,140 6,140 COMPZ WELLPF SLPC P Slip&cut 60'drill line 05:15 05:45 0.50 6,140 6,140 COMPZ WELLPF SVRG P Service top drive&draw works 05:45 06:30 0.75 6,140 6,140 COMPZ WELLPF CIRC P Pump 20 bbls 10.6 ppg dry job. B/D top drive 06:30 15:30 9.00 6,140 0 COMPZ WELLPF PULD P POOH while L/D 4"DP(/6,140'to surface 15:30 20:45 5.25 0 9,100 COMPZ WELLPF TRIP P RIH w/4"DP&HWDP from derrick to 9,100' 20:45 22:00 1.25 9,100 9,100 COMPZ WELLPF CIRC P Circ B/U w/415 gpm @ 1890 psi. Pump 21 bbl 10.7 ppg dry job. B/D top drive 22:00 22:30 0.50 9,100 9,100 COMPZ WELLPF SVRG P Service top drive&draw works 22:30 00:00 1.50 9,100 8,300 COMPZ WELLPF PULD P POOH while LID HWDP&4"DP f/9,100' to 8,300' PUwt= 152k/SOwt= 108k 02/25/2015 Cont.to POOH while L/D 4"DP(/8,300'to surface. Brk dwn @ Balance element stand. CIO wear rings. R/U to run 3 1/2"comp. RIH w/3 1/2"completion to 3,298' 00:00 12:00 12.00 8,300 0 COMPZ WELLPF PULD P POOH while L/D HWDP&4"DP f/8,300'to surface 12:00 12:45 0.75 0 0 COMPZ WELLPF MPDA P Break down @ Balance MPD element running tool. 12:45 13:30 0.75 0 0 COMPZ RPCOM RURD P Change out thin wall wear ring to 9" ID wear ring. 13:30 16:45 3.25 0 0 COMPZ RPCOM RURD P Clean&clear floor. R/U to run 3 1/2" completion. R/U paoer tongs&CIO elevators&slips. 16:45 17:15 0.50 0 0 COMPZ RPCOM SFTY P PJSM on running 3 1/2"completion. 17:15 00:00 6.75 0 3,298 COMPZ RPCOM PUTB P RIH w/3 1/2"completion as per tally to 3,298'SO wt 76 k 02/26/2015 Cont.to RIH 3 1/2"completion&space out on depth. Displace to 9.8 ppg brine. FIC 00:00 09:30 9.50 3,298 9,908 COMPZ RPCOM PUTB P RIH w/3 1/2"completion as per tally f/3,298'to 9,908' 09:30 11:00 1.50 9,908 9,908 COMPZ RPCOM SSSV P M/U Camco control line to SSSV Page 25 of 28 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:00 15:30 4.50 9,908 12,069 COMPZ RPCOM PUTB P Cont.to RIH w/3 1/2"completion f/9,908'to 12,069' 15:30 16:30 1.00 12,069 12,069 COMPZ RPCOM RURD P R/D double stack tongs. R/U casing tongs&C/O elevators to 4 1/2". 16:30 17:15 0.75 12,069 12,185 COMPZ RPCOM HOSO P P/U 3 jts of 4 1/2"IBT&2'pup jt& space out on depth @ 12,185'. (Land out on centralizer&no-go on TOL, P/U to packer set depth of 12,109& shoe depth of 12,184.87')PU wt 133k&SO wt 85k 17:15 17:45 0.50 12,185 12,185 COMPZ RPCOM RURD P Remove bell guide&R/U head pin to cement hose. 17:45 23:45 6.00 12,185 12,185 COMPZ RPCOM DISP P Displace 10.1 ppg LSND mud to 9.8 ppg NaCl/KCL brine w/3 bpm @ 620 psi ICP&340 psi FCP 23:45 00:00 0.25 12,185 12,185 ',COMPZ RPCOM OWFF P F/C(static) 32/27/2015 Spot corrosion inhibited brine around packer. Drop ball/rod&set packer. Shear PBR. M/U hanger&terminate lines&test packer. Spot corrosion inhibited brine. Land hanger&psi test. Set TWC&test. Prep cellar for N/D. N/D BOPE 00:00 00:30 0.50 12,185 12,185 COMPZ RPCOM OWFF P F/C(static)SIMOPS-PJSM for spotting corrosion inhibited brine 00:30 01:30 1.00 12,185 12,185 COMPZ RPCOM CRIH P Pump 7 bbls corrosion inhibited brine &spot across packer&PBR w/3 bpm @ 350 psi. Displace w/1078 stks, left 2 bbls in tubing string. 01:30 02:30 1.00 12,185 12,106 COMPZ RPCOM PACK P Drop ball 1.30"ball&rod. Pressure up to 2500 psi&set packer.While holding 2000 psi PU with 150 k& shear off of PBR. Bleed off psi. (Top of PBR @ 12,086, Packer @ 12,109, Btm of PBR Seal ASSY, 12,106'&Auto Entry Shoe @ 12,185') 02:30 03:30 1.00 12,106 12,066 COMPZ RPCOM HOSO P POOH&L/D 2.06'pup jt& 1 jt 4 1/2" IBT tubing.f/12,185'to 12,144' 03:30 05:15 1.75 12,066 12,066 COMPZ RPCOM THGR P M/U landing jt B&retrieve wear ring. R/U head pin&cement line to landing jt A. M/U hanger to landing jt A&terminate control lines. Pressure test Camco SSSV lines to 5000 psi (good) 05:15 06:15 1.00 12,066 12,083 COMPZ RPCOM PRTS P Wash down w/1 bpm @ 50 psi& locate top of BPR w/seals. PSI increase f/50 to 200 psi. P/U out of seals. Line up on kill line. Close Annular&PSI test packer to 1500 psi&chart for 10 min(good) 06:15 07:00 0.75 12,083 12,083 COMPZ RPCOM CRIH P Pump 21 bbls corrosion inhibited brine&spot from to ofPBR to 1st GLM @ 11,651'w/5 bpm @ 750 psi. Displace w/1069 stks, left 2 bbls in tubing string. 07:00 07:30 0.50 12,083 12,083 COMPZ RPCOM RURD P B/D all lines Page 26 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:30 2.00 12,083 12,106 COMPZ RPCOM THGR P Land hanger w/2'space out from fully located. Run in lock down screws. PSI test to 250/5000 psi. 5000 psi (test failed). Metal to metal seals on hanger leaking&2 failed JIC fittings. Adjust hanger&re-test(failed) 09:30 11:45 2.25 12,106 12,083 COMPZ RPCOM THGR T Pull hanger to rig floor. Swap out hanger for Elastomer Hanger. Re-terminate lines. Pressure test Camco SSSV lines to 5000 psi (good)SIMOPS-L/D Camco equipment via beaver slide. 11:45 16:00 4.25 12,083 12,106 COMPZ RPCOM THGR T Land hanger w/2'space out from fully located. Run in lock down screws. PSI test to 250/5000 psi. 5000 psi (test failed)Leaking JIC fitting. C/O fitting&attempt to re-test.Test hoses in high tension.Add hose extension&retest. Leaking in hose on high test. C/O hoses&R/U to test w/FMC test pump. (SIMOPS- L/D mouse hole, R/U squeeze manifold&hard lines)Attempt to test w/FMC test pump&test pump failed. C/O test pumps&re-test 250/5000 psi for 10 min. (good test) 16:00 19:00 3.00 12,106 12,106 COMPZ RPCOM PRTS P Pressure test lines to 4000 psi. Pressure test tubing to 3500 psi for 30 min(good). Bleed down to 2000 psi&Pressure test annulus to 3500 psi(good). Bleed off psi on annulus &tubing. Pressure up on annulus to 2730 psi&shear SOV. Establish circ w/2.2 bpm @ 720 psi 19:00 20:45 1.75 0 0 COMPZ WHDBO MPSP P R/D hoses&landing jt A. Install TWC&P/U landing jt B. Pressure test TWC in direction of flow to 3000 psi for 10 min. 20:45 21:45 1.00 0 0 COMPZ WHDBO OTHR P Remove old tree from cellar&bring in new tree. L/D tools&equipment from rig floor 21:45 00:00 2.25 0 0 COMPZ WHDBO MPDA P PJSM. N/D MPD equipment from BOPE stack. L/D hoses X2/28/2015 Cont.to N/D BOPE. N/U tree. Test tree adapter void&tree. Pull TWC&freeze protect well. R/D lines.Work of Safe Kick flow box in cellar.Wait on Phase 3 weather. 00:00 02:45 2.75 0 0 COMPZ WHDBO NUND P Cont.to N/D MPD valves&hoses& N/D BOPE 02:45 04:30 1.75 0 0 COMPZ WHDBO NUND P N/U tree. FMC&Camco terminate SSSV control line. SIMOPS-clean &clear rfloor&cellar. 04:30 05:00 0.50 0 0 COMPZ WHDBO PRTS P Test tree adapter void to 5000 psi (good). Camco open SSSV w/5000 psi on control line 05:00 06:45 1.75 0 0 COMPZ WHDBO PRTS P R/U&test tree to 250/5000 psi& chart for 10 min(good) R/D testing equipment. Page 27 of 28 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:45 07:15 0.50 0 0 COMPZ WHDBO MPSP P Pull TWC 07:15 08:00 0.75 0 0 COMPZ WHDBO FRZP P R/U squeeze manifold&hard lines to well head for freeze protect. 08:00 10:45 2.75 0 0 COMPZ WHDBO FRZP P Pressure test lines to 2500 psi. Dowell pump 3.3 bbls dwn IA& pressure up to 2600 psi. Shut down. No returns.Appears that SSSV is still closed. Observe 0 psi on control line gauge. Pressure up control line to to 5700 psi&open SSSV. Dowell pump 97 bbls diesel w/2.5 bpm @ 560 ICP& 1340 psi FCP. Full returns 10:45 11:15 0.50 0 0 COMPZ WHDBO FRZP P Monitor well&let U-Tube for 30 min. (SIMOPS-PJSM on B/D&R/D circulating equip) 11:15 12:00 0.75 0 0 COMPZ WHDBO FRZP P Flush lines&B/D&R/D circulating equip. 12:00 13:30 1.50 0 0 COMPZ WHDBO MPSP P FMC set PBV to 2500 psi for 10 min in direction of flow. 13:30 15:00 1.50 0 0 DEMOB MOVE RURD P B/D lines&R/D hard lines, hoses& squeeze manifold. L/D tools from rig floor.Well secure 15:00 17:30 2.50 0 0 DEMOB MOVE MPDA P P/U Safe Kick flow box in cellar&rig up. 17:30 00:00 6.50 0 0 DEMOB MOVE WAIT T Phase 3 weather called @ 17:30 hrs. _ Shut down&wait on weather. 03/01/2015 Wait on Phase 3 Weather Until 17:00 hrs.Work on Safe Kick flow box. Finish cleaning pits. Remove @ Blance MPD equipment from cellar. 00:00 15:00 15.00 0 0 DEMOB MOVE WAIT T Wait on phase 3 weather 15:00 00:00 9.00 0 0 DEMOB MOVE MPDA P PJSM.Work on Safe Kick flow box in cellar. (SIMOPS-Drain mud pumps&pull caps. clean pits. Remove flow box&send over to shop for modifications. Remove @ _ Balance MPD equipment from cellar) 03/02/2015 Cont.to work on Safe Kick flow box. SIMOPS-C/O saver sub on top drive.Work on mud pumps.Work on PM's. Service rig&draw works. 00:00 15:00 15.00 0 0 DEMOB MOVE MPDA P !Work on Safe Kick flow box. (SIMOPS-Change out saver sub on top drive to NC-50.Work on mud pump#1 &#2, change out swabs& liners. Service brakes&change out brake pads on draw works. Stage pipe rams in cellar(post MPI inspection). Disconnect service lines from ball mill to pits. Change out gear oil filter on top drive. Prep for rig move) 15:00 00:00 9.00 0 0 DEMOB MOVE WAIT T Wait on pad prep for CD4. (SIMOPS -Service rig,top drive&draw works. Clean pipe rack&drip pan. L/D& P/U subs from rig floor.Work on PM's&work orders. Prep for rig move) Page 28 of 28 C*30 POST-RIG WELL WORK • 3/8/2015 PUMPED 290 BBLS OF CRUDE DOWN IA TOOK RETURNS UP TBG TO FLOWLINE OFWELL 127. U- TUBE TBG AND IA FOR FREEZE PROTECT. JOB COMPLETE. 3/9/2015 PULLED BALL& ROD @ 12130' RKB. PULLED 1" SOV @ 11655' RKB. ATTEMPT TO SET OV @ 11655' WAS UNSUCCSESSFULL, UNABLE TO LEAVE VALVE IN POCKET. IN PROGRESS 3/10/2015 SET BTM LATCH OV(1/4" PORT) @ 11655' RKB. PULLED DGLV @ 8454' RKB, REPLACED w/GLV (3/16" PORT, TRO= 1872). IN PROGRESS 3/12/2015 PULLED DV @ 4668' RKB. REPLACE w/ 1" GLV(3/16" PORT/TRO = 1938). IN PROGRESS. 3/13/2015 PULLED 2.81" RHC PLUG BODY© 12133' RKB. RAN 2.61" DMY GUN ASSY (OAL = 16.08'). STOPPED FALLING w/o ASSIST @ 14716' SLM (VERY SLOW f/ 13200' SLM/- 10-20 fpm). IN PROGRESS. 3/14/2015 DELAYED START DUE TO COLD TEMPS. RAN 5' X 2.5" DD BAILER TO 14796' RKB (14772' SLM/24' CF FROM XN-NIP). RECOVERED SAMPLE. 3/22/2015 CLEAN OUT WITH 2.0" DJN USING SLICK SEAWATER WITH DIESEL GEL SWEEPS. MAX DEPTH REACHED WAS 15050' CTMD, DID NOT TAG END OF LINER. SAW HEAVY DRILLING MUD IN GEL SWEEPS. CIRCULATED WELLBORE OVER TO SLICK DIESEL WITH LUBE 776 TO HELP GET ELINE TO DESIRED PERFORATING DEPTH AT 78 DEGREE DEVIATION 3/23/2015 UNABLE TO DRIFT PAST 14484' RKB W/ 11'X 2.59" DMY PERF GUN. BAILED HARD (DRY) DRILLING MUD @ 14584" RKB. **RECOVERED -5 QT'S**. COMPLETE. 4/1/2015 MOBILIZE TO ALPINE. RIG UP TO CD3 130. JOB IN PROGRESS. 4/2/2015 UNABLE TO TRACTOR PAST 14696' DESPITE MULTIPLE ATTEMPTS. WHILE COMING UPHOLE, BECAME STUCK ON TUBING SHOE AND RELEASED FROM ROPE SOCKET. TOOL STRING IS DESCRIBED BELOW. TOOL STRING LENGTH = 56', WEIGHT= 370 LBS, TOOL HAS 1 3/8" FISHING NECK LOOKING UP. A TOOL STRING DIAGRAM WAS LEFT WITH THE JOB FOLDER. 4/4/2015 RECOVERED -56' OF E-LINE TS IN 2 SEGMENTS @ 14,576' SLM, JOB COMPLETE. 4/10/2015 WAITED ON TRACTOR REPLACEMENT 7 HOURS NPT. STARTED RIH TO PERFORM FCO. CREW CHANGE. 4/11/2015 CLEAN OUT HEAVY MUD/DRILLING FLUID, TAKING 100' BITES FOR THE FIRST 1000', PICK UP WT'S ALL LOOKED GOOD. MADE IT TO BOTTOM WITH NO ERRATIC WEIGHT SWINGS, DID BOTTOMS UP FROM TD TO SURFACE, DID A FINAL GEL SWEEP, CHASE OUT OF HOLE. GETTING CLEAN WATER IN RETURNS AT SURFACE. MADE UP LOGGING TOOLS, STARTED THE LOGGING PASS. CHANGE OUT WITH MARK ADAMS. ****JOB IN PROGRESS**** 4/11/2015 PERFORMED CBL/CCL/GR SURVEY FROM 15,080'TO 12,185'. CORRELATED MEMORY LOG AND PERFORATED FROM 14,984' - 15,012' MD WITH 28' OF 2" 6 SPF 60* PHASING, PJ OMEGA HMX 11 GM SLB GUNS. WELL SWAPPEDTO DIESEL AND FREEZE PROTECTED. GUNS CONFIRMED FIRED. JOB COMPLETE. 4/13/2015 ROLLED CREW BACK TO DAYS. RIGGED DOWN UNIT AND MOBILIZED TO KUPARUK 2T-39. 4/13/2015 MEASURED BHP © 14500' RKB. PSI = 3636 @ 164 F. COMPLETE. • S NADConversion Western North Slope CD3 Fiord Pad CD3-130 Definitive Survey Report _ &- • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 usft Northing: 6,003,743.55 usft Latitude: 70°25'8.970 N +El-W 0.00 usft Easting: 387,799.14 usft Longitude: 150°54'50.530 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 12.50 usft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BG G M 2014 1/20/2015 18.54 80.87 57,556 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,083.86 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) . (°) 7 0.00 0.00 0.00 333.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 116.69 195.98 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 246.78 523.39 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:00: 581.10 3,288.08 CD3-130PB2 MWD I(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:00: 3,383.02 13,083.86 CD3-130PB2 MWD II(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:00 13,133.00 13,133.00 CD3-130 Srvy#1-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 3:40:' 13,159.59 13,221.64 CD3-130 Srvy#2-INC+TREND(CD3-13 INC+TREND Inclinometer+known azi trend 2/24/2015 2:47:' 13,290.02 15,722.29 CD3-130 Srvy#3-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 2:50:' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100') (C) Survey Tool Name 36.60 0.00 0.00 36.60 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.69 0.13 154.32 116.69 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.04 0.20 113.61 174.04 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.23 GYD-GC-SS(1) 195.98 0.43 347.45 195.98 146.88 -0.12 0.18 6,003,743.43 387,799.31 2.60 -0.18 GYD-GC-SS(1) 246.78 1.48 253.68 246.77 197.67 -0.11 -0.49 6,003,743.44 387,798.64 3.09 0.12 GYD-GC-SS(2) 264.39 1.99 249.47 264.38 215.28 -0.29 -1.00 6,003,743.28 387,798.14 2.98 0.20 GYD-GC-SS(2) 294.67 1.78 251.65 294.64 245.54 -0.62 -1.94 6,003,742.96 387,797.19 0.73 0.33 GYD-GC-SS(2) 340.31 1.68 252.62 340.26 291.16 -1.04 -3.25 6,003,742.56 387,795.87 0.23 0.55 GYD-GC-SS(2) 388.34 1.95 271.93 388.26 339.16 -1.22 -4.74 6,003,742.39 387,794.38 1.38 1.06 GYD-GC-SS(2) 2/24/2015 5:26.'10PM Page 2 COMPASS 5000.1 Build 65 • i Definitive Survey Report .,,_--- ,,�. .w _ _ Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) I1 Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) y Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 430.86 2.33 297.40 430.76 381.66 -0.80 -6.23 6,003,742.84 387,792.90 2.38 2.11 GYD-GC-SS(2) 523.39 4.55 323.70 523.12 474.02 3.02 -10.07 6,003,746.72 387,789.11 2.88 7.27 GYD-GC-SS(2) 581.10 6.81 328.21 580.54 531.44 7.78 -13.23 6,003,751.52 387,786.03 3.99 12.93 MWD+IFR-AK-CAZ-SC(3) 673.14 8.88 328.76 671.72 622.62 18.49 -19.79 6,003,762.33 387,779.63 2.25 25.46 MWD+IFR-AK-CAZ-SC(3) 766.63 11.82 329.96 763.67 714.57 32.95 -28.33 6,003,776.92 387,771.31 3.15 42.22 MW1D+IFR-AK-CAZ-SC(3) 863.43 15.51 333.17 857.72 808.62 53.09 -39.14 6,003,797.21 387,760.81 3.89 65.07 MWD+IFR-AK-CAZ-SC(3) 957.77 21.32 339.17 947.20 898.10 80.40 -50.94 6,003,824.70 387,749.42 6.47 94.76 MWD+IFR-AK-CAZ-SC(3) 1,007.05 22.34 340.91 992.94 943.84 97.62 -57.19 6,003,842.01 387,743.43 2.45 112.95 MWD+IFR-AK-CAZ-SC(3) 1,050.31 20.83 341.51 1,033.17 984.07 112.69 -62.32 6,003,857.15 387,738.53 3.53 128.70 MWD+IFR-AK-CAZ-SC(3) 1,143.43 20.47 342.59 1,120.31 1,071.21 143.93 -72.44 6,003,888.54 387,728.88 0.56 161.13 MW3+IFR-AK-CAZ-SC(3) 1,237.27 22.95 344.74 1,207.48 1,158.38 177.24 -82.16 6,003,921.99 387,719.65 2.77 195.23 MWD+IFR-AK-CAZ-SC(3) 1,330.96 28.20 345.89 1,291.97 1,242.87 216.36 -92.38 6,003,961.25 387,710.03 5.63 234.72 MVVD+IFR-AK-CAZ-SC(3) 1,377.30 31.42 347.29 1,332.17 1,283.07 238.77 -97.70 6,003,983.74 387,705.04 7.11 257.10 MWD+IFR-AK-CAZ-SC(3) 1,420.99 30.24 347.61 1,369.69 1,320.59 260.62 -102.57 6,004,005.66 387,700.51 2.73 278.78 MWD+IFR-AK-CAZ-SC(3) 1,515.26 34.39 351.00 1,449.34 1,400.24 310.13 -111.83 6,004,055.30 387,691.99 4.80 327.10 MWD+IFR-AK-CAZ-SC(3) 1,611.91 37.55 354.83 1,527.57 1,478.47 366.44 -118.76 6,004,111.70 387,685.91 4.01 380.42 MWD+IFR-AK-CAZ-SC(3) 1,706.66 37.56 356.81 1,602.68 1,553.58 424.03 -122.97 6,004,169.35 387,682.57 1.27 433.64 MWD+IFR-AK-CAZ-SC(3) 1,800.81 41.32 6.06 1,675.44 1,626.34 483.67 -121.28 6,004,228.94 387,685.15 7.40 486.01 MWD+IFR-AK-CAZ-SC(3) 1,848.26 43.60 10.34 1,710.46 1,661.36 515.35 -116.69 6,004,260.55 387,690.22 7.75 512.16 M1MD+IFR-AK-CAZSC(3) 1,895.17 43.23 11.92 1,744.53 1,695.43 546.98 -110.47 6,004,292.08 387,696.91 2.45 537.52 MWD+IFR-AK-CAZ-SC(3) 1,989.25 45.20 16.54 1,811.98 1,762.88 610.53 -94.31 6,004,355.37 387,714.03 4.01 586.80 MWD+IFR-AK-CAZSC(3) 2,084.45 47.26 22.32 1,877.86 1,828.76 675.28 -71.40 6,004,419.77 387,737.90 4.89 634.10 MWD+IFR-AK-CAZ-SC(3) 2,178.57 47.75 27.18 1,941.46 1,892.36 738.26 -42.35 6,004,482.30 387,767.89 3.84 677.03 MWD+IFR-AK-CAZ-SC(3) 2,273.37 49.47 32.23 2,004.16 1,955.06 799.98 -7.10 6,004,543.47 387,804.07 4.39 716.01 MWD+IFR-AK-CAZ-SC(3) 2,367.80 53.11 36.13 2,063.22 2,014.12 860.87 34.33 6,004,603.73 387,846.40 5.02 751.45 MWD+IFR-AK-CAZ-SC(3) 2,415.75 54.92 37.46 2,091.39 2,042.29 891.93 57.57 6,004,634.44 387,870.10 4.39 768.58 MWD+IFR-AK-CAZ-SC(3) 2,462.21 56.48 38.46 2,117.57 2,068.47 922.19 81.18 6,004,664.34 387,894.16 3.80 784.82 MWD+IFR-AK-CAZ-SC(3) 2,556.13 59.99 40.46 2,167.01 2,117.91 983.81 131.94 6,004,725.18 387,945.84 4.15 816.68 MWD+IFR-AK-CAZ-SC(3) 2,650.76 63.05 42.23 2,212.13 2,163.03 1,046.23 186.89 6,004,786.76 388,001.72 3.63 847.35 MWD+IFR-AK-CAZ-SC(3) 2,746.60 66.54 44.40 2,252.95 2,203.85 1,109.30 246.38 6,004,848.92 388,062.14 4.18 876.54 MWD+IFR-AK-CAZ-SC(3) 2,840.06 69.42 45.36 2,287.98 2,238.88 1,170.68 307.52 6,004,909.37 388,124.19 3.23 903.47 MW3+IFR-AK-CAZ-SC(3) 2,936.50 69.04 49.56 2,322.20 2,273.10 1,231.63 373.93 6,004,969.31 388,191.51 4.09 927.63 MWD+IFR-AK-CAZSC(3) 3,028.93 67.59 51.65 2,356.35 2,307.25 1,286.14 440.30 6,005,022.82 388,258.68 2.62 946.07 MWD+IFR-AK-CAZSC(3) 3,124.41 67.67 51.38 2,392.69 2,343.59 1,341.09 509.41 6,005,076.71 388,328.60 0.27 963.65 MWD+IFR-AK-CAZ-SC(3) 3,217.44 67.26 50.87 2,428.34 2,379.24 1,395.02 576.31 6,005,129.62 388,396.30 0.67 981.33 MWD+IFR-AK-CAZ-SC(3) 3,288.08 67.57 51.09 2,455.47 2,406.37 1,436.08 626.98 6,005,169.92 388,447.58 0.52 994.91 MWD+IFR-AK-CAZ-SC(3) 3,353.60 67.73 50.04 2,480.39 2,431 29 1,474.57 673.78 6,005,207.70 388,494.95 1.50 1 007.96 MWD+IFR-AK-CAZ-SC(4) 10-314"x 13-112" 3,383.02 67.80 49.57 2,491.52 2,442.42 1,492.15 694.58 6,005,224.96 388,516.01 1.50 1,014.18 MVVD+IFR-AK-CAZ-SC(4) 3,452.44 69.13 50.92 2,517.01 2,467.91 1,533.44 744.23 6,005,265.49 388,566.26 2.63 1,028.43 MWD+IFR-AK-CA2-SC(4) 2/24/2015 5:26:10PM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) i Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section 1 (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3.545.71 66.99 46.85 2,551.87 2,502.77 1,590 29 809.40 6,005,321.36 388,632 28 4.65 1.049.50 MWD+IFR-AK-CAZ-SC(4) 3,640.02 67.18 45.90 2,588.59 2,539.49 1,650.22 872.28 6,005,380.33 388,696.04 0.95 1,074.35 MWD+IFR-AK-CAZ-SC(4) 3,735.05 67.68 48.12 2,625.06 2,575.96 1,710.05 936.46 6,005,439.18 388,761.12 2.22 1,098.52 MWD+IFR-AK-CAZ-SC(4) 3,828.48 67.02 50.16 2,661.05 2,611.95 1,766.46 1,001.67 6,005,494.60 388,827.16 2.14 1,119.18 MWD+IFR-AK-CAZ-SC(4) 3,924.06 66.83 48.92 2,698.51 2,649.41 1,823.52 1,068.57 6,005,550.64 388,894.90 1.21 1,139.64 MWD+IFR-AK-CAZ-SC(4) 4,019.21 66.30 50.36 2,736.35 2,687.25 1,880.05 1,135.09 6,005,606.17 388,962.26 1.50 1,159.82 MWD+IFR-AK-CAZ-SC(4) • 4,114.29 66.18 53.52 2,774.67 2,725.57 1,933.69 1,203.60 6,005,658.77 389,031.56 3.04 1,176.51 MWD+IFR-AK-CAZ-SC(4) 4,206.92 66.19 52.98 2,812.07 2,762.97 1,984.39 1,271.50 6,005,708.44 389,100.20 0.53 1,190.86 MWD+IFR-AK-CAZ-SC(4) 4,301.87 66.10 53.17 2,850.47 2,801.37 2,036.56 1,340.92 6,005,759.55 389,170.40 0.21 1,205.83 MWD+IFR-AK-CAZ-SC(4) 4,395.68 66.18 50.77 2,888.42 2,839.32 2,089.41 1,408.49 6,005,811.38 389,238.75 2.34 1,222.24 MW1J+IFR-AK-CAZ-SC(4) 4,488.92 66.07 48.83 2,926.17 2,877.07 2,144.44 1,473.61 6,005,865.42 389,304.68 1.91 1,241.71 MWD+IFR-AK-CAZ-SC(4) 4,583.28 66.13 48.40 2,964.39 2,915.29 2,201.48 1,538.33 6,005,921.47 389,370.25 0.42 1,263.14 MWD+IFR-AK-CAZ-SC(4) 4,678.37 66.18 51.48 3,002.84 2,953.74 2,257.44 1,604.89 6,005,976.42 389,437.63 2.96 1,282.79 MWD+IFR-AK-CAZ-SC(4) 4,772.52 66.25 51.89 3,040.82 2,991.72 2,310.86 1,672.49 6,006,028.81 389,506.02 0.41 1,299.70 MWD+IFR-AK-CAZ-SC(4) 4,866.24 66.13 54.96 3,078.66 3,029.56 2,361.94 1,741.33 6,006,078.85 389,575.62 3.00 1,313.96 MWD+IFR-AK-CAZ-SC(4) 4,960.77 66.16 55.68 3,116.89 3,067.79 2,411.13 1,812.43 6,006,126.96 389,647.44 0.70 1,325.51 MWD+IFR-AK-CAZ-SC(4) 5,060.57 66.12 55.17 3,157.26 3,108.16 2,462.93 1,887.58 6,006,177.62 389,723.36 0.47 1,337.54 MWD+IFR-AK-CAZ-SC(4) 5,156.54 65.96 54.51 3,196.23 3,147.13 2,513.43 1,959.28 6,006,227.03 389,795.80 0.65 1,349.99 MWD+IFR-AK-CAZ-SC(4) 5,251.34 66.22 51.63 3,234.66 3,185.56 2,565.50 2,028.54 6,006,278.05 389,865.83 2.79 1,364.93 MWD+IFR-AK-CAZ-SC(4) 5,344.92 66.31 50.36 3,272.33 3,223.23 2,619.41 2,095.11 6,006,330.95 389,933.20 1.25 1,382.75 MVVD+IFR-AK-CAZ-SC(4) 5,438.08 66.89 51.30 3,309.33 3,260.23 2,673.41 2,161.39 6,006,383.94 390,000.28 1.12 1,400.77 MWD+IFR-AK-CAZ-SC(4) 5,533.42 66.33 51.53 3,347.18 3,298.08 2,727.99 2,229.79 6,006,437.48 390,069.49 0.63 1,418.35 MWD+IFR-AK-CAZ-SC(4) 5,628.02 66.63 50.05 3,384.93 3,335.83 2,782.82 2,297.00 6,006,491.29 390,137.51 1.47 1,436.69 MWD+IFR-AK-CAZ-SC(4) 5,723.32 66.56 49.04 3,422.79 3,373.69 2,839.57 2,363.55 6,006,547.03 390,204.89 0.98 1,457.04 MWD+IFR-AK-CAZ-SC(4) 5,816.92 66.67 49.21 3,459.94 3,410.84 2,895.79 2,428.51 6,006,602.26 390,270.69 0.20 1,477.65 MWD+IFR-AK-CAZ-SC(4) 5,911.07 66.55 48.87 3,497.31 3,448.21 2,952.43 2,493.77 6,006,657.92 390,336.78 0.36 1,498.49 MW2+IFR-AK-CAZ-SC(4) 6,005.64 66.99 50.07 3,534.62 3,485.52 3,008.90 2,559.82 6,006,713.38 390,403.67 1.26 1,518.82 MWD+IFR-AK-CAZ-SC(4) 6,100.09 66.81 52.58 3,571.68 3,522.58 3,063.19 2,627.63 6,006,766.64 390,472.29 2.45 1,536.40 MWD+IFR-AK-CAZ-SC(4) 6,194.63 66.94 51.85 3,608.81 3,559.71 3,116.46 2,696.35 6,006,818.87 390,541.79 0.72 1,552.67 MWD+IFR-AK-CAZ-SC(4) 6,288.49 66.62 50.65 3,645.81 3,596.71 3,170.45 2,763.62 6,006,871.83 390,609.85 1.22 1,570.23 MWD+IFR-AK-CAZ-SC(4) 6,383.05 66.98 51.07 3,683.06 3,633.96 3,225.31 2,831.03 6,006,925.67 390,678.08 0.56 1,588.51 MWD+IFR-AK-CAZ-SC(4) 6,477.60 66.79 54.00 3,720.19 3,671.09 3,278.20 2,900.04 6,006,977.51 390,747.87 2.86 1,604.31 MWD+IFR-AK-CAZ-SC(4) 6,571.92 66.86 57.16 3,757.32 3,708.22 3,327.20 2,971.55 6,007,025.43 390,820.11 3.08 1,615.50 MWD+IFR-AK-CAZ-SC(4) 6,666.03 66.68 57.62 3,794.44 3,745.34 3,373.81 3,044.40 6,007,070.93 390,893.64 0.49 1,623.96 MWD+IFR-AK-CAZ-SC(4) 6,761.05 66.99 55.86 3,831.82 3,782.72 3,421.72 3,117.45 6,007,117.73 390,967.39 1.73 1,633.48 MWD+IFR-AK-CAZ-SC(4) 6,853.66 66.59 53.64 3,868.32 3,819.22 3,470.84 3,186.95 6,007,165.80 391,037.62 2.25 1,645.69 MWD+IFR-AK-CAZ-SC(4) 6,949.56 66.70 50.93 3,906.34 3,857.24 3,524.69 3,256.59 6,007,218.59 391,108.05 2.60 1,662.06 MWD+IFR-AK-CAZ-SC(4) 7,044.53 66.60 50.73 3,943.98 3,894.88 3,579.76 3,324.19 6,007,272.64 391,176.46 0.22 1,680.44 MWD+IFR-AK-CAZ-SC(4) 7,136.15 66.91 50.51 3,980.14 3,931.04 3,633.17 3,389.25 6,007,325.06 391,242.32 0.40 1,698.49 MWD+IFR-AK-CAZ-SC(4) 7,232.23 66.69 50.61 4,017.99 3,968.89 3,689.27 3,457.46 6,007,380.12 391,311.35 0.25 1,717.51 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 5:26:10PM Page 4 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60©49.10usft(Doyon 19) ,, Well: CD3-130 North Reference: True l' Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 l i Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,327.46 66.72 49.59 4,055.65 4,006.55 3,745.38 3,524.56 6,007,435.21 391,379.28 0.98 1,737.04 MWD+IFR-AK-CAZ-SC(4) 7,421.47 66.97 48.71 4,092.62 4,043.52 3,801.91 3,589.94 6,007,490.75 391,445.50 0.90 1,757.73 MWD+IFR-AK-CAZ-SC(4) 7,514.67 66.72 48.92 4,129.27 4,080.17 3,858.34 3,654.43 6,007,546.20 391,510.83 0.34 1,778.73 MW1J+IFR-AK-CAZ-SC(4) 7,610.76 66.68 48.12 4,167.28 4,118.18 3,916.80 3,720.55 6,007,603.65 391,577.81 0.77 1,800.80 MWD+IFR-AK-CAZ-SC(4) 7,704.41 66.85 48.44 4,204.22 4,155.12 3,974.06 3,784.78 6,007,659.94 391,642.89 0.36 1,822.66 MWD+IFR-AK-CAZ-SC(4) 7,799.43 66.72 50.92 4,241.68 4,192.58 4,030.56 3,851.35 6,007,715.43 391,710.30 2.40 1,842.78 MWD+IFR-AK-CAZ-SC(4) 7,893.36 66.88 51.97 4,278.69 4,229.59 4,084.37 3,918.87 6,007,768.21 391,778.61 1.04 1,860.07 MW3+IFR-AK-CAZ-SC(4) 7,987.98 66.72 53.23 4,315.96 4,266.86 4,137.19 3,987.95 6,007,819.98 391,848.48 1.24 1,875.77 MWD+IFR-AK-CAZ-SC(4) 8,082.51 66.65 52.74 4,353.38 4,304.28 4,189.46 4,057.27 6,007,871.19 391,918.56 0.48 1,890.87 MWD+IFR-AK-CAZ-SC(4) 8,176.45 66.91 52.48 4,390.41 4,341.31 4,241.88 4,125.86 6,007,922.58 391,987.93 0.38 1,906.44 MWD+IFR-AK-CAZ-SC(4) 8,271.14 66.54 52.12 4,427.83 4,378.73 4,295.07 4,194.68 6,007,974.72 392,057.54 0.52 1,922.59 MWD+IFR-AK-CAZ-SC(4) 8,364.82 66.97 52.06 4,464.80 4,415.70 4,347.96 4,262.59 6,008,026.58 392,126.23 0.46 1,938.88 MWD+IFR-AK-CA2-SC(4) 8,459.60 66.66 52.27 4,502.12 4,453.02 4,401.40 4,331.40 6,008,078.98 392,195.83 0.39 1,955.26 MWD+IFR-AK-CAZ-SC(4) 8,553.46 66.76 52.13 4,539.23 4,490.13 4,454.24 4,399.53 6,008,130.78 392,264.73 0.17 1,971.41 MWD+IFR-AK-CAZ-SC(4) 8,648.01 66.88 50.93 4,576.45 4,527.35 4,508.31 4,467.57 6,008,183.82 392,333.58 1.17 1,988.70 MWD+IFR-AK-CAZ-SC(4) 8,742.00 66.82 49.83 4,613.40 4,564.30 4,563.42 4,534.14 6,008,237.92 392,400.96 1.08 2,007.58 MWD+IFR-AK-CAZ-SC(4) 8,836.78 66.82 48.91 4,650.71 4,601.61 4,620.15 4,600.27 6,008,293.65 392,467.93 0.89 2,028.11 MWD+IFR-AK-CAZ-SC(4) 8,930.83 66.78 50.56 4,687.76 4,638.66 4,676.02 4,666.23 6,008,348.51 392,534.71 1.61 2,047.95 MWD+IFR-AK-CAZ-SC(4) 9,026.03 66.75 51.24 4,725.31 4,676.21 4,731.19 4,734.11 6,008,402.65 392,603.42 0.66 2,066.28 MWD+IFR-AK-CAZ-SC(4) 9,119.62 66.81 52.29 4,762.21 4,713.11 4,784.42 4,801.67 6,008,454.86 392,671.76 1.03 2,083.04 MW1J+IFR-AK-CAZ-SC(4) 9,213.86 66.71 51.72 4,799.40 4,750.30 4,837.73 4,869.91 6,008,507.13 392,740.79 0.57 2,099.55 MWD+IFR-AK-CAZ-SC(4) 9,308.72 66.79 51.57 4,836.85 4,787.75 4,891.81 4,938.26 6,008,560.17 392,809.93 0.17 2,116.71 MWD+IFR-AK-CAZ-SC(4) 9,402.76 66.77 52.33 4,873.92 4,824.82 4,945.08 5,006.31 6,008,612.40 392,878.78 0.74 2,133.28 MWD+IFR-AK-CAZ-SC(4) 9,497.24 66.79 51.76 4,911.17 4,862.07 4,998.48 5,074.77 6,008,664.77 392,948.03 0.55 2,149.78 MWD+IFR-AK-CAZ-SC(4) 9,591.73 66.72 51.92 4,948.46 4,899.36 5,052.12 5,143.04 6,008,717.37 393,017.08 0.17 2,166.58 MVVD+IFR-AK-CAZ-SC(4) 9,686.07 66.74 51.86 4,985.74 4,936.64 5,105.61 5,211.23 6,008,769.82 393,086.07 0.06 2,183.28 MW2+IFR-AK-CAZ-SC(4) 9,779.86 66.69 51.71 5,022.81 4,973.71 5,158.90 5,278.92 6,008,822.09 393,154.54 0.16 2,200.04 MWD+IFR-AK-CAZ-SC(4) 9,874.93 66.61 50.83 5,060.49 5,011.39 5,213.51 5,347.01 6,008,875.66 393,223.44 0.85 2,217.78 MWD+IFR-AK-CAZ-SC(4) 9,969.44 66.32 49.56 5,098.23 5,049.13 5,268.98 5,413.57 6,008,930.12 393,290.82 1.27 2,236.99 MWD+IFR-AK-CAZ-SC(4) 10,064.14 67.78 49.07 5,135.16 5,086.06 5,325.83 5,479.70 6,008,985.96 393,357.79 1.61 2,257.62 MWD+IFR-AK-CAZ-SC(4) 10,157.69 67.27 48.49 5,170.92 5,121.82 5,382.79 5,544.72 6,009,041.94 393,423.65 0.79 2,278.85 MWD+IFR-AK-CAZ-SC(4) 10,252.35 67.12 48.97 5,207.61 5,158.51 5,440.35 5,610.30 6,009,098.50 393,490.09 0.49 2,300.36 MWD+IFR-AK-CAZ-SC(4) 10,347.01 67.37 50.97 5,244.23 5,195.13 5,496.49 5,677.14 6,009,153.62 393,557.76 1.97 2,320.04 MWD+IFR-AK-CAZ-SC(4) 10,441.01 67.49 52.78 5,280.31 5,231.21 5,550.07 5,745.42 6,009,206.17 393,626.83 1.78 2,336.79 MWD+IFR-AK-CAZ-SC(4) 10,535.65 68.00 54.67 5,316.15 5,267.05 5,601.89 5,816.03 6,009,256.92 393,698.21 1.93 2,350.90 MWD+IFR-AK-CAZ-SC(4) 10,629.41 68.55 55.28 5,350.86 5,301.76 5,651.88 5,887.36 6,009,305.82 393,770.27 0.84 2,363.06 MWD+IFR-AK-CAZ-SC(4) 10,724.08 68.57 54.10 5,385.46 5,336.36 5,702.81 5,959.27 6,009,355.67 393,842.93 1.16 2,375.79 MWD+IFR-AK-CAZ-SC(4) 10,818.35 68.88 53.26 5,419.67 5,370.57 5,754.84 6,030.04 6,009,406.62 393,914.47 0.89 2,390.02 MWD+IFR-AK-CAZ-SC(4) 10,912.76 69.47 51.94 5,453.24 5,404.14 5,808.44 6,100.14 6,009,459.15 393,985.36 1.45 2,405.95 MWD+IFR-AK-CAZ-SC(4) 11,007.72 70.06 51.78 5,486.08 5,436.98 5,863.47 6,170.22 6,009,513.12 394,056.25 0.64 2,423.17 M1MD+IFR-AK-CAZ-SC(4) 2/24/2015 5:26:10PM Page 5 COMPASS 5000.1 Build 65 • • Definitive Survey Report t, Company: NADConversion Local Co-ordinate Reference: Well CD3-130 r Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey � N * `i l 1 1 I " ` x'oOPpImIiNKVi ±. _ ii nIt $ . = , Map Map Vertical *' MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,101.51 69.97 51.87 5,518.13 5,469.03 5,917.94 6,239.51 6,009,566.54 394,126.35 0.13 2,440.25 MWD+IFR-AK-CAZ-SC(4) 11,195.93 70.88 50.27 5,549.77 5,500.67 5,973.84 6,308.71 6,009,621.39 394,196.37 1.86 2,458.64 MWD+IFR-AK-CAZ-SC(4) 11,290.91 70.55 50.16 5,581.14 5,532.04 6,031.21 6,377.60 6,009,677.71 394,266.11 0.36 2,478.48 MWD+IFR-AK-CAZ-SC(4) 11,384.85 70.84 50.04 5,612.20 5,563.10 6,088.08 6,445.61 6,009,733.55 394,334.97 0.33 2,498.27 MWD+IFR-AK-CAZSC(4) 11,479.40 70.95 49.71 5,643.14 5,594.04 6,145.66 6,513.93 6,009,790.09 394,404.14 0.35 2,518.56 MWD+IFR-AK-CAZ-SC(4) 11,573.08 71.03 49.91 5,673.66 5,624.56 6,202.82 6,581.59 6,009,846.22 394,472.64 0.22 2,538.77 MWD+IFR-AK-CAZ-SC(4) 11,668.90 71.69 50.04 5,704.28 5,655.18 6,261.21 6,651.12 6,009,903.55 394,543.03 0.70 2,559.23 MWD+IFR-AK-CAZ-SC(4) 11,762.19 71.41 49.94 5,733.81 5,684.71 6,318.10 6,718.90 6,009,959.42 394,611.65 0.32 2,579.16 MWD+IFR-AK-CAZ-SC(4) 11,857.33 71.27 50.73 5,764.25 5,715.15 6,375.64 6,788.28 6,010,015.90 394,681.89 0.80 2,598.92 MWD+IFR-AK-CAZ-SC(4) 11,950.69 71.88 50.21 5,793.75 5,744.65 6,432.01 6,856.60 6,010,071.24 394,751.04 0.84 2,618.13 MW3+IFR-AK-CAZ-SC(4) 12,045.71 72.48 50.38 5,822.83 5,773.73 6,489.80 6,926.19 6,010,127.97 394,821.49 0.65 2,638.03 MWD+IFR-AK-CAZ-SC(4) 12,139.45 71.94 50.70 5,851.47 5,802.37 6,546.53 6,995.11 6,010,183.65 394,891.24 0.66 2,657.29 MWD+IFR-AK-CAZ-SC(4) 12,233.98 71.89 48.55 5,880.82 5,831.72 6,604.74 7,063.56 6,010,240.81 394,960.56 2.16 2,678.07 MWD+IFR-AK-CAZ-SC(4) 12,328.94 71.63 47.37 5,910.54 5,861.44 6,665.13 7,130.54 6,010,300.19 395,028.43 1.21 2,701.48 MWD+IFR-AK-CAZ-SC(4) 12,422.93 71.86 47.27 5,939.99 5,890.89 6,725.64 7,196.16 6,010,359.70 395,094.95 0.26 2,725.60 MWD+IFR-AK-CAZ-SC(4) 12,516.70 71.78 46.93 5,969.24 5,920.14 6,786.28 7,261.42 6,010,419.35 395,161.11 0.35 2,750.01 MWD+IFR-AK-CAZ-SC(4) 12,611.40 71.02 46.15 5,999.45 5,950.35 6,848.02 7,326.57 6,010,480.09 395,227.17 1.12 2,775.44 MWD+IFR-AK-CAZ-SC(4) 12,705.69 71.65 46.96 6,029.63 5,980.53 6,909.44 7,391.43 6,010,540.53 395,292.94 1.05 2,800.72 MVV3+IFR-AK-CAZSC(4) 12,800.91 72.07 45.30 6,059.27 6,010.17 6,972.15 7,456.66 6,010,602.25 395,359.10 1.71 2,826.98 MWD+IFR-AK-CAZ-SC(4) 12,894.79 72.30 42.33 6,088.00 6,038.90 7,036.64 7,518.53 6,010,665.79 395,421.92 3.02 2,856.35 MVVD+IFR-AK-CAZ-SC(4) 12,988.83 73.05 38.28 6,116.02 6,066.92 7,105.09 7,576.58 6,010,733.36 395,480.99 4.19 2,890.99 MVVD+IFR-AK-CAZ-SC(4) 13,083.81 72.57 34.38 6,144.10 6,095.00 7,178.17 7,630.32 6,010,805.61 395,535.83 3.96 2,931.70 MVVD+IFR-AK-CAZ-SC(4) 13,133.00 71.87 32.49 6,159.12 6,110.02 7,217.25 7,656.13 6,010,844.30 395,562.22 3.93 2,954.81 MWD+IFR-AK-CAZ-SC(5) 13,159.59 71.47 34.70 6,167.48 6,118.38 7,238.28 7,670.10 6,010,865.11 395,576.49 8.03 2,967.20 INC+TREND(6) 13,221.64 72.96 34.78 6,186.43 6,137.33 7,286.83 7,703.77 6,010,913.15 395,610.89 2.40 2,995.18 INC+TREND(6) 13,290.02 72.81 33.35 6,206.56 6,157.46 7,340.96 7,740.37 6,010,966.72 395,648.30 2.01 3,026.79 MVVD+IFR-AK-CAZ-SC(7) 13,298.03 72.78 34.84 6,208.93 6,159.83 7,347.30 7,744.66 6,010,972.99 395,652.68 17.77 3,030.49 MWD+IFR-AK-CAZ-SC(7) 13,386.37 72.65 33.82 6,235.18 6,186.08 7,416.96 7,792.23 6,011,041.92 395,701.29 1.11 3,070.96 MWD+IFR-AK-CAZ-SC(7) 13,484.45 71.76 32.22 6,265.15 6,216.05 7,495.25 7,843.12 6,011,119.44 395,753.34 1.80 3,117.62 MVVD+IFR-AK-CAZ-SC(7) 13,579.78 71.27 29.78 6,295.38 6,246.28 7,572.74 7,889.68 6,011,196.21 395,801.06 2.48 3,165.52 MWD+IFR-AK-CAZ-SC(7) 13,674.32 71.64 26.95 6,325.45 6,276.35 7,651.60 7,932.26 6,011,274.42 395,844.82 2.86 3,216.46 MVVD+IFR-AK-CAZ-SC(7) 13,768.99 71.46 25.25 6,355.42 6,306.32 7,732.25 7,971.76 6,011,354.45 395,885.53 1.71 3,270.38 MWD+IFR-AK-CAZ-SC(7) 13,865.52 72.77 23.12 6,385.07 6,335.97 7,816.04 8,009.39 6,011,437.67 395,924.40 2.50 3,327.96 MVVD+IFR-AK-CAZ-SC(7) 13,959.37 72.46 22.49 6,413.11 6,364.01 7,898.60 8,044.11 6,011,519.69 395,960.35 0.72 3,385.76 MWD+IFR-AK-CAZ-SC(7) 14,055.60 74.39 20.46 6,440.56 6,391.46 7,984.43 8,077.86 6,011,604.99 395,995.39 2.85 3,446.91 MWD+IFR-AK-CAZ-SC(7) 14,151.45 73.56 16.19 6,467.03 6,417.93 8,071.85 8,106.82 6,011,691.96 396,025.66 4.37 3,511.65 MWD+IFR-AK-CAZSC(7) 14,246.43 73.49 12.51 6,493.98 6,444.88 8,160.08 8,129.39 6,011,779.83 396,049.55 3.72 3,580.01 MWD+IFR-AK-CAZSC(7) 14,341.85 73.82 9.50 6,520.83 6,471.73 8,249.94 8,146.87 6,011,869.41 396,068.38 3.05 3,652.15 MVVD+IFR-AK-CAZ-SC(7) 14,438.31 74.20 6.66 6,547.41 6,498.31 8,341.74 8,159.90 6,011,961.00 396,082.78 2.86 3,728.03 MVVD+IFR-AK-CAZ-SC(7) 14,532.95 74.54 5.60 6,572.91 6,523.81 8,432.36 8,169.63 6,012,051.45 396,093.87 1.14 3,804.35 MVVD+IFR-AK-CAZ-SC(7) 2/24/2015 5:26:10PM Page 6 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +Ei-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 14,628.23 74.21 641 6,598.57 6,549.47 8,523.61 8,179.23 6,012,142 54 396,104.84 0.89 3,881.30 MWD+IFR-AK-CAZ-SC(7) 14,723.68 73.93 8.03 6,624.77 6,575.67 8,614.67 8,190.76 6,012,233.40 396,117.74 1.66 3,957.20 MWD+IFR-AK-CAZ-SC(7) 14,818.61 73.83 7.91 6,651.13 6,602.03 8,704.98 8,203.41 6,012,323.51 396,131.74 0.16 4,031.93 MWD+IFR-AK-CAZ-SC(7) 14,914.03 75.43 4.83 6,676.43 6,627.33 8,796.41 8,213.60 6,012,414.77 396,143.31 3.54 4,108.76 MWD+IFR-AK-CAZ-SC(7) 15,009.95 77.17 1.20 6,699.15 6,650.05 8,889.45 8,218.49 6,012,507.71 396,149.60 4.10 4,189.44 MWD+IFR-AK-CAZ-SC(7) 15,105.09 78.29 358.92 6,719.37 6,670.27 8,982.41 8,218.59 6,012,600.65 396,151.09 2.62 4,272.22 MWD+IFR-AK-CAZ-SC(7) 15,200.20 78.76 356.24 6,738.30 6,689.20 9,075.52 8,214.65 6,012,693.81 396,148.55 2.81 4,356.98 MWD+IFR-AK-CAZ-SC(7) 15,295.87 78.91 353.88 6,756.82 6,707.72 9,169.03 8,206.57 6,012,787.42 396,141.88 2.43 4,443.96 MWD+IFR-AK-CAZ-SC(7) 15,390.86 80.45 349.98 6,773.85 6,724.75 9,261.53 8,193.44 6,012,880.10 396,130.14 4.35 4,532.34 MWD+IFR-AK-CAZ-SC(7) 15,486.39 81.01 345.81 6,789.24 6,740.14 9,353.70 8,173.67 6,012,972.54 396,111.76 4.35 4,623.43 MWD+IFR-AK-CAZ-SC(7) 15,581.01 82.91 342.05 6,802.48 6,753.38 9,443.70 8,147.74 6,013,062.92 396,087.19 4.42 4,715.40 MWD+IFR-AK-CAZ-SC(7) 15,677.16 83.82 338.93 6,813.59 6,764.49 9,533.71 8,115.84 6,013,153.39 396,056.65 3.36 4,810.08 MWD+IFR-AK-CAZ-SC(7) 15,722.29 84.25 337.06 6,818.28 6,769.18 9,575.32 8,099.03 6,013,195.25 396,040.46 4.23 4,854.80 MWD+IFR-AK-CAZ-SC(7) 15,757.00 84.25 337.06 6,821.76 6,772.66 9,607.13 8,085.57 6,013,227.25 396,027.48 0.00 4,889.24 PROJECTED to TD 2/24/2015 5:26:10PM Page 7 COMPASS 5000.1 Build 65 • I 0'jlilloi Cement Detail Report CD3-130 ConouP'hillips 01I.sskn String: Conductor Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 4/6/2011 00:00 4/8/2011 00:00 CD3-130PB2 Com ment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 36.6 115.6 Yes Yes No Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Mixed AFC cement 3500#-filled from top Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 9/17/2015 • • 0,i Cement Detail Report a CD3-130 ConocoPhillips String: Cement Plug#1 Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug#1 1/31/2014 16:45 1/31/2014 18:30 CD3-130PB1 Comment Performed job using 100%excess in calcs for 400'plug Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Cement Plug#1 Plug back surface 839.0 1,055.0 Yes 0.0 No No Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5, 5 50.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 839.0 Work String Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement AS1 839.0 1,055.0 859 G 142.2 Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 0.93 3.54 15.70 95.3 3.87 500.0 Additives Additive Type Concentration Cone Unit label Retarder D110 Page 1/1 Report Printed: 9/17/2015 • • Cement Detail Report CD3-130 Conor h4IIps Alaska String: Cement Plug#2 Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug#2 2/1/2014 13:15 2/1/2014 14:30 CD3-130PB1 Comment Performed job using 100%excess in calcs for 565'plug Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Cement Plug#2 Plug back surface 696.0 839.0 Yes 0.0 No No Q Pump Init(bbilm...Q Pump Final(bbll...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 50.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 696.0 Work String Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement AS1 696.0 839.0 1,281 G 200.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 0.93 3.54 15.70 95.3 3.87 500.0 Additives Additive Type Concentration Conc Unit label Retarder D110 Page 1/1 Report Printed: 9/17/2015 • • 8 Cement Detail Report CD3-130 ConocoPhillips String: Cement Plug#3 Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug#3 2/2/2014 09:00 2/2/2014 10:30 CD3-130PB1 Comment Performed job using 250%excess in calcs for 324'plug Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug#3 Plug back surface 484.0 696.0 Yes 0.0 No No Q Pump!nit(bbl/m...Q Pump Final(bbl!...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 50.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 484.0 Work String Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 • Cement Detail Report 0•,; a CD3-130 ConocoPhillips String: Cement Plug#4 Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug#4 2/3/2014 02:45 2/3/2014 06:00 CD3-130PB1 Comment Performed job using 235%excess in calcs for 212'of plug Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Cement Plug#4 Plug back surface 176.0 484.0 Yes 30.0 No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 140.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 176.0 Drill Bit 196.0 13 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gailsa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 9/17/2015 • i 0 Cement Detail Report a CD3-130 Cor tHagps M ka String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/8/2014 01:00 2/8/2014 03:30 CD3-130PB2 Comment Tested lines to 2500 psi-Mixed&pumped 50 bbls Mud Push @ 10.3 ppg-Dropped btm plug-Mixed&pumped 472 bbls(1373 sks)(1.93 yield)ALC @ 11.02 ppg followed by 64 bbls(310 sxs)(1.16 yield)Class G tail @ 15.8 ppg-Dropped top plug w/20 bbls water from Dowell-Switched to rig pumps&displaced w/ 294 bbls 9.9 ppg mud-Bumped plug-pressured up to 1100 psi-Bled off pressure-Floats holding-CIP @ 0321 hrs.-Full returns during job w/65 bbls cmt returns to surface Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 36.6 3,366.0 Yes 65.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 3 7 600.0 1,100.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,366.0 9 7/8 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.6 2,855.0 1,373 G 472.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.93 11.02 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,855.0 3,366.0 310 G 64.0 Yield(ft'/sack) Mix 1420 Ratio(gal/sa... Pree Water(%) Density(1b/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 s i y Cement Detail Report ta CD3-130 ConocoPhitlips String: Corrosion Mitigation Job: DRILLING ORIGINAL, 1/20/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Corrosion Mitigation 2/8/2014 12:30 2/8/2014 12:45 CD3-130PB2 Comment Pressure test tool to 1500 psi-Wash down f/top of fluted hanger to 20'@ 1 bbl/min,PU and insert into next set flutes,wash down 20'at 1 bbl/min,increase rate to 4 bpm, pumped 26 bbls water to clean out surface cement f/20"x 10 3/4"annulus-Mixed&pumped 6 bbls 15.8 ppg Qannik blend with cement to 4" outlet below casing hanger @ 1 bbl/min-pulled up w/jetting tool to 4"outlet below hanger-pumping an additional 4 bbls 15.8 ppg Qannik blend-Flush lines with fresh water into cellar-Blow down lines-Vac out cmt returns&clean up water w/Super Sucker-5 bbls cmt in place in 20"x 10 3/4"annulus-Pulled TQF tool back to rig floor and RD,wrapped hanger with plastic to prevent water entry-installed 4"plug in outlet Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Corrosion Mitigation Cmt 38.6 56.6 Yes No No Q Pump!nit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl!... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 50.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 • ! 0 z Cement Detail Report CD3-130 ConocoPhillips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/26/2014 18:00 2/26/2014 20:38 CD3-130PB2 Comment Pressure test casing to 3500 psi-Pump 2nd stage cement job(Dowell Pump=40.2 bbl CW 100-40.1 bbl 11.5 ppg mud push-91.1 bbls(441 sxs 1.16 yield)D 600 G cement-10 bbls H2O flush&Rig Disp=305 bbls 10.5 ppg LSND-bump plug w/3050 stks)-Full returns-Increase pressure to 1570 psi&hold for 5 min -Check stage collar closed(good)-CIP @ 20:38 hrs Cement Stages Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 5,213.0 6,913.0 Yes Yes No Cement Stage 2 Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 1 5 280.0 1,570.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,909.0 Comment Stage 2 Cement Job Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement D 600 G(Gas Block 5,209.0 6,909.0 441 G 91.1 Stage 2 Latex) Yield(ft'/sack) Mix 1120 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.23 15.80 75.5 0.00 1,693.0 Additives Additive Type Concentration Conc Unit label Antifoam 0047 Additive Type Concentration Conc Unit label Dispersant D065 0.5 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Accelerator D186 Additive Type Concentration Conc Unit label Gas Block D600G Page 111 Report Printed: 9/17/2015 • • ill Cement Detail Report CD3-130 ConocoPhillips String: Cement Squeeze Job: DRILLING ORIGINAL, 1/18/2015 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 1/26/2015 16:00 1/26/2015 18:00 CD3-130PB2 Comment Dowell pump 1.5 bbls&pressure test to 4000 psi.Dowell pump 5.8 bbls 11.5 ppg mud push, 15.3 bbls 15.8 ppg cement,5 bbls mud push,&1.5 bbls H20.Rig pump 107.8 bbls of 9.6 ppg brine w/3 bpm @ 290-320 psi&while holding back pressure with choke.Sting into retainer&squeeze cement w/.5 bpm. ICP 2230 psi&FCP 2090 psi.Pumped total of 129.2 bbls of brine.CIP @ 17:55 hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Cement Squeeze Squeeze Pens 13,193.0 13,198.0 No No No Q Pump!nit(bblim...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 2,090.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) -Drill Out Diameter(in) Comment Dowell pump 1.5 bbls&pressure test to 4000 psi.Dowell pump 5.8 bbls 11.5 ppg mud push, 15.3 bbls 15.8 ppg cement,5 bbls mud push,&1.5 bbls H20.Rig pump 107.8 bbls of 9.6 ppg brine w/3 bpm @ 290-320 psi&while holding back pressure with choke.Sting into retainer&squeeze cement w/.5 bpm.ICP 2230 psi&FCP 2090 psi.Pumped total of 129.2 bbls of brine.CIP @ 17:55 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 • • Cement Detail Report CD3-130 ConocoPhillips String: Intemediate Liner Shoe Squeeze Job: DRILLING ORIGINAL, 1/18/2015 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intemediate Liner Shoe Squeeze 2/21/2015 15:45 2/21/2015 18:00 CD3-130 Comment PJSM.Pump 6.1 bbls of warm water and pressure test lines to 4,000psi.Batch up and pump 20bbls of CW100,20bbls of 11.5ppg Mud Push II,47bbls of 16.2ppg Cement.Water on cement at 15:00hrs.Drop plug,push out with 5bbls of water verify dropped with tattle tail.Break bottom connection on cement head and install foam wiper ball. Displace and bump plug with 140bblslnjecting at 2bbls/min pump last 20bbls at 4bbls/min. Final pump pressure 3,000psi bump plug and hold 3,500psi.CIP at 18:00hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Intemediate Liner Shoe Squeeze Shoe 15,090.0 No No Yes Squeeze Q Pump snit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 2 2 2,970.0 3,500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM. Pump 6.1 bbls of warm water and pressure test lines to 4,000psi. Batch up and pump 20bbls of CW100,20bbls of 11.5ppg Mud Push II,47bbls of 16.2ppg Cement.Water on cement at 15:00hrs.Drop plug,push out with 5bbls of water verify dropped with tattle tail. Break bottom connection on cement head and install foam wiper ball. Displace and bump plug with 140bblslnjecting at 2bbls/min pump last 20bbls at 4bbls/min.Final pump pressure 3,000psi bump plug and hold 3,500psi.CIP at 18:00hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/17/2015 • • Cement Detail Report CD3-130 Conoco hillips String: Intemediate Liner Shoe Squeeze Job: DRILLING ORIGINAL, 1/18/2015 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intemediate Liner Shoe Squeeze 2/21/2015 15:45 2/21/2015 18:00 CD3-130 Comment PJSM . Pump 6.1 bbls of warm water and pressure test lines to 4,000psi.Batch up and pump 20bbls of CW100,20bbls of 11.5ppg Mud Push II,47bbls of 16.2ppg Cement.Water on cement at 15:00hrs.Drop plug,push out with 5bbls of water verify dropped with tattle tail.Break bottom connection on cement head and install foam wiper ball. Displace and bump plug with 140bblslnjecting at 2bbls/min pump last 20bbls at 4bbls/min.Final pump pressure 3,000psi bump plug and hold 3,500psi.CIP at 18:00hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intemediate Liner Shoe Squeeze Shoe 15,090.0 No No Yes Squeeze Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 2 2 2,970.0 3,500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM.Pump 6.1bbls of warm water and pressure test lines to 4,000psi.Batch up and pump 20bbls of CW100,20bbls of 11.5ppg Mud Push II,47bbls of 16.2ppg Cement.Water on cement at 15:00hrs.Drop plug,push out with 5bbls of water verify dropped with tattle tail.Break bottom connection on cement head and install foam wiper ball.Displace and bump plug with 140bblslnjecting at 2bbls/min pump last 20bbls at 4bbls/min.Final pump pressure 3,000psi bump plug and hold 3,500psi.CIP at 18:00hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 9/16/2015 i or i Cement Detail Report CD3-130 ConocoPhillips String: Cement Squeeze Job: DRILLING ORIGINAL, 1/18/2015 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 1/26/2015 16:00 1/26/2015 18:00 CD3-130PB2 Comment Dowell pump 1.5 bbls&pressure test to 4000 psi.Dowell pump 5.8 bbls 11.5 ppg mud push, 15.3 bbls 15.8 ppg cement,5 bbls mud push,&1.5 bbls H20.Rig pump 107.8 bbls of 9.6 ppg brine w/3 bpm @ 290-320 psi&while holding back pressure with choke.Sting into retainer&squeeze cement w/.5 bpm. ICP 2230 psi&FCP 2090 psi.Pumped total of 129.2 bbls of brine.CIP @ 17:55 hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Squeeze Squeeze Perfs 13,193.0 13,198.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 2,090.0 No No Tagged Depth(WE) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Dowell pump 1.5 bbls&pressure test to 4000 psi. Dowell pump 5.8 bbls 11.5 ppg mud push, 15.3 bbls 15.8 ppg cement,5 bbls mud push,&1.5 bbls H20. Rig pump 107.8 bbls of 9.6 ppg brine w/3 bpm @ 290-320 psi&while holding back pressure with choke.Sting into retainer&squeeze cement w/.5 bpm.ICP 2230 psi&FCP 2090 psi.Pumped total of 129.2 bbls of brine.CIP @ 17:55 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1l1 Report Printed: 9/16/2015 • • prn 2/ 3 -!t,a Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday,April 07, 2015 9:58 PM To: Kane, Danny Subject: Re: CD3-130(PTD 213-160) 10-407 Submission Follow Up Flag: Follow up Flag Status: Flagged Submitting the 10-407 at the end of the CD3 ice road season is acceptable- Victoria Sent from my iPhone On Apr 7, 2015, at 3:35 PM, Kane, Danny<Danny.Kane@conocophillips.com>wrote: Victoria, Here is the latest update for CD3-130. After the weather finally cleared last week,we attempted to a tractor a CBL to the bottom of the un-expanded expandable liner but were unable to get to bottom—it appears that excess fill is still in our way. While pulling the assembly out E-line severed at the rope socket and the E-line BHA was left in hole. That was successfully fished over the weekend. Currently we are preparing a Coiled-Tubing fill clean-out of the liner(solids within the LSND dropped out when completion brine mixed with it inside the liner) so that we can complete the CBL/perforations planned for this well. Since the ice road to CD3 is limited in time, I'd like to request an extension on submitting the 10-407 to the end of the CD3 ice road season (end-April to mid-May). By that date we will definitively know the well's status(coiled tubing will have regained access to the bottom of the liner or not)and can submit the 10-407 without having to worry about a significant change shortly thereafter. Regards, - Danny From: Kane, Danny Sent: Wednesday, March 25, 2015 3:15 PM To: Loepp, Victoria T(DOA) Subject: RE: CD3-130(PTD 213-160) 10-407 Submission Victoria, Here is the latest update on CD3-130. We ran into some issues with excessive fill the bottom of the liner, so we performed a fill clean-out with coiled tubing over the weekend. The current schedule shows that they will run the perforation guns via tractor either tomorrow or Friday. Regards, - Danny 1 • . Danny Kane Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 dannv.kane@conocophillips.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, March 20, 2015 8:48 AM To: Kane, Danny Subject: [EXTERNAL]RE: CD3-130(PTD 213-160) 10-407 Submission Danny, Approval is granted to submit the 10-407 after the post-rig perforations are shot. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loem@alaska.gov From: Kane, Danny [mailto:Danny.KaneCaconocophillips.com] Sent: Thursday, March 19, 2015 4:01 PM To: Loepp, Victoria T(DOA) Subject: CD3-130 - Completion Report Submittal Victoria, In our last CD3-130 Sundry(#315-104)to Change Approved Program & Perforate,we configured the well as a Kuparuk C producer and requested to perforate the Kuparuk C. While performing a drift run prior to running the E-line/tractor conveyed perforation guns, we encountered thick mud within the liner and are going to perform a coiled-tubing clean-out prior to running the perforation guns. Currently we are estimating that the perforations will be shot before the end of the month. My question concerns submitting the 10-407 Well Completion Report. If we wait for the perforations to be shot,we risk turning the 10-407 in late(>30days after the rig has moved off the well). However, since the post-rig perforations were part of the sundry, should we wait for this work to be performed prior to turning in the 10-407? Some guidance would be appreciated. 2 • 21 31 60 FIIICEIVED ConocoPhillips MAR 19 2015 AOGCC 2 5 5 3 2 TRANSMITTAL 25 533 r,N IDE i a L DATA 1"°r Ft;;.��-�.�.�.I�,.TI __ DATA LOGGED iVtC 3/2o/2015 M.K.BENDER FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD3-130, CD3-130PB1 DATE: 03/18/2015 Transmitted: Colville River Unit, Alaska CD3-130, CD3-130PB1 1 CD and hardcopy report Halliburton-Surface data logging and End of Well report- mud logging data for CD3-130/CD3-130PB1; 03/03/2014; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 each -color log prints: CD3-130 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD CD3-130PB 1 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.Lemke(aJCOP.com CC: CD3-130 transmittal folder, production well files, eSearch Receipfi)"14424"L'17) Ofate: 1113 . GIS-Technical Data Management I ConocoPhillips 'Anchorage, Alaska I Ph: 907265.6947 EatG/f > a ® -a2 II. u, � @na C) z •o, o= , o 868 -,, / n % % m n o c n o /\ƒ\0 W Ui 7 } a o G \ \ rr § .. .. z- n � m p . « 7. o kqk ƒ \ - \ c \ .- r-I&gJRP ) 44 ƒ e = e %so>, _ a 8 / \ c 0 2 / CD \7§/(r2 CUD ƒ E. 7 \ 7 J C r' c,�§E � wf � _ 0 = r ' B a- 2 _ \/ ~ ~ §el 4) § §� 0_ / % 0 / J / / § g \ § E m / \ $ & c a % p t ° K / 0 \ / 0 / \ ■ Cu M $ —• 0 O J r $ » $ Ei o > NJe 0 � LE1 \ / \ 2 c o . mme D C G $ / \ 3 a ƒ m\ 3 ° -. U C . %- =/ $ / ƒ g E $ e\ J ) \ \ a -o g & � g () $U- b � \I0 v, f ± \ E \ \ \ _ % § o / § 3 0 = } / • 5g \ 7 0 3 , 0 \ r 0 3 _ ? c 0 0 / » AA oma / 7 n [ \ E / , § ® CO 03 CO X CCC ' f \ � •= 0 0- CO G § \ ¢ c_ / °$ 3 � $� ADD _ / br/ bm 3 / ° t0 / / CD � k & i-, 7 § ƒ & G CD zzzm _. z z z 2 s 0000 $ e ƒ 2 2 X / E G F / ( r+ & / 1.A 13 C �_ ( ( § CD CD � � C / / 13 CL co 0 § ( § 2 \ 0 \ § § §/ E S e 000C $ o \ \ /\ 18 0 0 ■ \ / / k \ \ 553 a) ° / / /% / - n n @ 2. = n a) \ f o _ E / \ / ) / \ 0 RECEIVED • 2 1 3 1 60 MAR 0 6 2015 ehiumberger Akonr Transmittal#: 06MAR15-SP01 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 3ict /2015 M. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD3-130 Date Dispatched: 6-Mar-15 Job#: 14AKA0043 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD x x Scope Resistivity 2"TVD x x Scope Resistivity 5"MD x x Scope Resistivity 5"ND x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey: PDF �, x r Cr( 11Y0 rc yovIce\uyitA\\ \\ fsV 01frips 1-1•-• Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 vvl 1/9 Received By: • • 213160 25484 RECEIVED MAR 0 6 2015 /- FINAL FINAL A®GCC NADConversion Western North Slope CD3 Fiord Pad CD3-130 Definitive Survey Report NAD 27 24 February, 2015 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 usft Northing: 6,003,743.55 usft Latitude: 70°25'8.970 N +El-W 0.00 usft Easting: 387,799.14 usft Longitude: 150°54'50.530 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 12.50 usft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°) (nT) BGGM2014 1/20/2015 18.54 80.87 57,556 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,083.86 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 333.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 116.69 195.98 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 246.78 523.39 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:00: 581.10 3,288.08 CD3-130PB2 MWD I(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:00: 3,383.02 13,083.86 CD3-130PB2 MWD II(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:00 13,133.00 13,133.00 CD3-130 Srvy#1-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 3:40:, 13,159.59 13,221.64 CD3-130 Srvy#2-INC+TREND(CD3-13 INC+TREND Inclinometer+known azi trend 2/24/2015 2:47: 13,290.02 15,722.29 CD3-130 Srvy#3-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 2:50: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 36.60 0.00 0.00 36.60 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.69 0.13 154.32 116.69 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.04 0.20 113.61 174.04 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.23 GYD-GC-SS(1) 195.98 0.43 347.45 195.98 146.88 -0.12 0.18 6,003,743.43 387,799.31 2.60 -0.18 GYD-GC-SS(1) 246.78 1.48 253.68 246.77 197.67 -0.11 -0.49 6,003,743.44 387,798.64 3.09 0.12 GYD-GC-SS(2) 264.39 1.99 249.47 264.38 215.28 -0.29 -1.00 6,003,743.28 387,798.14 2.98 0.20 GYD-GC-SS(2) 294.67 1.78 251.65 294.64 245.54 -0.62 -1.94 6,003,742.96 387,797.19 0.73 0.33 GYD-GC-SS(2) 340.31 1.68 252.62 340.26 291.16 -1.04 -3.25 6,003,742.56 387,795.87 0.23 0.55 GYD-GC-SS(2) 388.34 1.95 271.93 388.26 339.16 -1.22 -4.74 6,003,742.39 387,794.38 1.38 1.06 GYD-GC-SS(2) 2/24/2015 5:26:10PM Page 2 COMPASS 5000.1 Build 65 0 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 430.86 2.33 297.40 430.76 381.66 -0.80 -6.23 6,003,742.84 387,792.90 2.38 2.11 GYD-GC-SS(2) 523.39 4.55 323.70 523.12 474.02 3.02 -10.07 6,003,746.72 387,789.11 2.88 7.27 GYD-GC-SS(2) 581.10 6.81 328.21 580.54 531.44 7.78 -13.23 6,003,751.52 387,786.03 3.99 12.93 MWD+IFR-AK-CAZ-SC(3) 673.14 8.88 328.76 671.72 622.62 18.49 -19.79 6,003,762.33 387,779.63 2.25 25.46 MWD+IFR-AK-CAZ-SC(3) 766.63 11.82 329.96 763.67 714.57 32.95 -28.33 6,003,776.92 387,771.31 3.15 42.22 MWD+IFR-AK-CAZ-SC(3) 863.43 15.51 333.17 857.72 808.62 53.09 -39.14 6,003,797.21 387,760.81 3.89 65.07 MWD+IFR-AK-CAZ-SC(3) 957.77 21.32 339.17 947.20 898.10 80.40 -50.94 6,003,824.70 387,749.42 6.47 94.76 MWD+IFR-AK-CAZ-SC(3) 1,007.05 22.34 340.91 992.94 943.84 97.62 -57.19 6,003,842.01 387,743.43 2.45 112.95 MWD+IFR-AK-CAZ-SC(3) 1,050.31 20.83 341.51 1,033.17 984.07 112.69 -62.32 6,003,857.15 387,738.53 3.53 128.70 MWD+IFR-AK-CAZ-SC(3) 1,143.43 20.47 342.59 1,120.31 1,071.21 143.93 -72.44 6,003,888.54 387,728.88 0.56 161.13 MWD+IFR-AK-CAZ-SC(3) 1,237.27 22.95 344.74 1,207.48 1,158.38 177.24 -82.16 6,003,921.99 387,719.65 2.77 195.23 MWD+IFR-AK-CAZ-SC(3) 1,330.96 28.20 345.89 1,291.97 1,242.87 216.36 -92.38 6,003,961.25 387,710.03 5.63 234.72 MW1D+IFR-AK-CAZ-SC(3) 1,377.30 31.42 347.29 1,332.17 1,283.07 238.77 -97.70 6,003,983.74 387,705.04 7.11 257.10 MWD+IFR-AK-CAZ-SC(3) 1,420.99 30.24 347.61 1,369.69 1,320.59 260.62 -102.57 6,004,005.66 387,700.51 2.73 278.78 MWD+IFR-AK-CAZ-SC(3) 1,515.26 34.39 351.00 1,449.34 1,400.24 310.13 -111.83 6,004,055.30 387,691.99 4.80 327.10 MWD+IFR-AK-CAZ-SC(3) 1,611.91 37.55 354.83 1,527.57 1,478.47 366.44 -118.76 6,004,111.70 387,685.91 4.01 380.42 MWD+IFR-AK-CAZ-SC(3) 1,706.66 37.56 356.81 1,602.68 1,553.58 424.03 -122.97 6,004,169.35 387,682.57 1.27 433.64 MWD+IFR-AK-CAZ-SC(3) 1,800.81 41.32 6.06 1,675.44 1,626.34 483.67 -121.28 6,004,228.94 387,685.15 7.40 486.01 MWD+IFR-AK-CAZ-SC(3) 1,848.26 43.60 10.34 1,710.46 1,661.36 515.35 -116.69 6,004,260.55 387,690.22 7.75 512.16 MWD+IFR-AK-CAZ-SC(3) 1,895.17 43.23 11.92 1,744.53 1,695.43 546.98 -110.47 6,004,292.08 387,696.91 2.45 537.52 MWD+IFR-AK-CAZ-SC(3) 1,989.25 45.20 16.54 1,811.98 1,762.88 610.53 -94.31 6,004,355.37 387,714.03 4.01 586.80 MWD+IFR-AK-CAZ-SC(3) 2,084.45 47.26 22.32 1,877.86 1,828.76 675.28 -71.40 6,004,419.77 387,737.90 4.89 634.10 MWD+IFR-AK-CAZ-SC(3) 2,178.57 47.75 27.18 1,941.46 1,892.36 738.26 -42.35 6,004,482.30 387,767.89 3.84 677.03 MWD+IFR-AK-CAZ-SC(3) 2,273.37 49.47 32.23 2,004.16 1,955.06 799.98 -7.10 6,004,543.47 387,804.07 4.39 716.01 MWD+IFR-AK-CAZ-SC(3) 2,367.80 53.11 36.13 2,063.22 2,014.12 860.87 34.33 6,004,603.73 387,846.40 5.02 751.45 MWD+IFR-AK-CAZ-SC(3) 2,415.75 54.92 37.46 2,091.39 2,042.29 891.93 57.57 6,004,634.44 387,870.10 4.39 768.58 MWD+IFR-AK-CAZ-SC(3) 2,462.21 56.48 38.46 2,117.57 2,068.47 922.19 81.18 6,004,664.34 387,894.16 3.80 784.82 MWD+IFR-AK-CAZ-SC(3) 2,556.13 59.99 40.46 2,167.01 2,117.91 983.81 131.94 6,004,725.18 387,945.84 4.15 816.68 MWD+IFR-AK-CAZ-SC(3) 2,650.76 63.05 42.23 2,212.13 2,163.03 1,046.23 186.89 6,004,786.76 388,001.72 3.63 847.35 MWD+IFR-AK-CAZ-SC(3) 2,746.60 66.54 44.40 2,252.95 2,203.85 1,109.30 246.38 6,004,848.92 388,062.14 4.18 876.54 MWD+IFR-AK-CAZ-SC(3) 2,840.06 69.42 45.36 2,287.98 2,238.88 1,170.68 307.52 6,004,909.37 388,124.19 3.23 903.47 MWD+IFR-AK-CAZ-SC(3) 2,936.50 69.04 49.56 2,322.20 2,273.10 1,231.63 373.93 6,004,969.31 388,191.51 4.09 927.63 MWD+IFR-AK-CAZ-SC(3) 3,028.93 67.59 51.65 2,356.35 2,307.25 1,286.14 440.30 6,005,022.82 388,258.68 2.62 946.07 MWD+IFR-AK-CAZ-SC(3) 3,124.41 67.67 51.38 2,392.69 2,343.59 1,341.09 509.41 6,005,076.71 388,328.60 0.27 963.65 MWD+IFR-AK-CAZ-SC(3) 3,217.44 67.26 50.87 2,428.34 2,379.24 1,395.02 576.31 6,005,129.62 388,396.30 0.67 981.33 MWD+IFR-AK-CAZ-SC(3) 3,288.08 67.57 51.09 2,455.47 2,406.37 1,436.08 626.98 6,005,169.92 388,447.58 0.52 994.91 MWD+IFR-AK-CAZ-SC(3) 3,353.60 67.73 50.04 2,480.39 2,431.29 1,474.57 673.78 6,005,207.70 388,494.95 1.50 1,007.96 MWD+IFR-AK-CAZ-SC(4) 10-3/4"x 13-1/2" 3,383.02 67.80 49.57 2,491.52 2,442.42 1,492.15 694.58 6,005,224.96 388,516.01 1.50 1,014.18 MWD+IFR-AK-CAZ-SC(4) 3,452.44 69.13 50.92 2,517.01 2,467.91 1,533.44 744.23 6,005,265.49 388,566.26 2.63 1,028.43 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 5:26:10PM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (`) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 3,545.71 66.99 46.85 2,551.87 2,502.77 1,590.29 809.40 6,005,321.36 388,632.28 4.65 1,049.50 MWD+IFR-AK-CAZ-SC(4) 3,640.02 67.18 45.90 2,588.59 2,539.49 1,650.22 872.28 6,005,380.33 388,696.04 0.95 1,074.35 MWD+IFR-AK-CAZ-SC(4) 3,735.05 67.68 48.12 2,625.06 2,575.96 1,710.05 936.46 6,005,439.18 388,761.12 2.22 1,098.52 MWD+IFR-AK-CAZ-SC(4) 3,828.48 67.02 50.16 2,661.05 2,611.95 1,766.46 1,001.67 6,005,494.60 388,827.16 2.14 1,119.18 MWD+IFR-AK-CAZ-SC(4) 3,924.06 66.83 48.92 2,698.51 2,649.41 1,823.52 1,068.57 6,005,550.64 388,894.90 1.21 1,139.64 MWD+IFR-AK-CAZ-SC(4) 4,019.21 66.30 50.36 2,736.35 2,687.25 1,880.05 1,135.09 6,005,606.17 388,962.26 1.50 1,159.82 MWD+IFR-AK-CAZ-SC(4) 4,114.29 66.18 53.52 2,774.67 2,725.57 1,933.69 1,203.60 6,005,658.77 389,031.56 3.04 1,176.51 MWD+IFR-AK-CAZ-SC(4) 4,206.92 66.19 52.98 2,812.07 2,762.97 1,984.39 1,271.50 6,005,708.44 389,100.20 0.53 1,190.86 MWD+IFR-AK-CAZ-SC(4) 4,301.87 66.10 53.17 2,850.47 2,801.37 2,036.56 1,340.92 6,005,759.55 389,170.40 0.21 1,205.83 MWD+IFR-AK-CAZ-SC(4) 4,395.68 66.18 50.77 2,888.42 2,839.32 2,089.41 1,408.49 6,005,811.38 389,238.75 2.34 1,222.24 MWD+IFR-AK-CAZ-SC(4) 4,488.92 66.07 48.83 2,926.17 2,877.07 2,144.44 1,473.61 6,005,865.42 389,304.68 1.91 1,241.71 MWD+IFR-AK-CAZ-SC(4) 4,583.28 66.13 48.40 2,964.39 2,915.29 2,201.48 1,538.33 6,005,921.47 389,370.25 0.42 1,263.14 MWD+IFR-AK-CAZ-SC(4) 4,678.37 66.18 51.48 3,002.84 2,953.74 2,257.44 1,604.89 6,005,976.42 389,437.63 2.96 1,282.79 MWD+IFR-AK-CAZ-SC(4) 4,772.52 66.25 51.89 3,040.82 2,991.72 2,310.86 1,672.49 6,006,028.81 389,506.02 0.41 1,299.70 MWD+IFR-AK-CAZ-SC(4) 4,866.24 66.13 54.96 3,078.66 3,029.56 2,361.94 1,741.33 6,006,078.85 389,575.62 3.00 1,313.96 MWD+IFR-AK-CAZ-SC(4) 4,960.77 66.16 55.68 3,116.89 3,067.79 2,411.13 1,812.43 6,006,126.96 389,647.44 0.70 1,325.51 MWD+IFR-AK-CAZ-SC(4) 5,060.57 66.12 55.17 3,157.26 3,108.16 2,462.93 1,887.58 6,006,177.62 389,723.36 0.47 1,337.54 MWD+IFR-AK-CAZ-SC(4) 5,156.54 65.96 54.51 3,196.23 3,147.13 2,513.43 1,959.28 6,006,227.03 389,795.80 0.65 1,349.99 MWD+IFR-AK-CAZ-SC(4) 5,251.34 66.22 51.63 3,234.66 3,185.56 2,565.50 2,028.54 6,006,278.05 389,865.83 2.79 1,364.93 MWD+IFR-AK-CAZ-SC(4) 5,344.92 66.31 50.36 3,272.33 3,223.23 2,619.41 2,095.11 6,006,330.95 389,933.20 1.25 1,382.75 MWD+IFR-AK-CAZ-SC(4) 5,438.08 66.89 51.30 3,309.33 3,260.23 2,673.41 2,161.39 6,006,383.94 390,000.28 1.12 1,400.77 MWD+IFR-AK-CAZ-SC(4) 5,533.42 66.33 51.53 3,347.18 3,298.08 2,727.99 2,229.79 6,006,437.48 390,069.49 0.63 1,418.35 MWD+IFR-AK-CAZ-SC(4) 5,628.02 66.63 50.05 3,384.93 3,335.83 2,782.82 2,297.00 6,006,491.29 390,137.51 1.47 1,436.69 MWD+IFR-AK-CAZ-SC(4) 5,723.32 66.56 49.04 3,422.79 3,373.69 2,839.57 2,363.55 6,006,547.03 390,204.89 0.98 1,457.04 MWD+IFR-AK-CAZ-SC(4) 5,816.92 66.67 49.21 3,459.94 3,410.84 2,895.79 2,428.51 6,006,602.26 390,270.69 0.20 1,477.65 MWD+IFR-AK-CAZ-SC(4) 5,911.07 66.55 48.87 3,497.31 3,448.21 2,952.43 2,493.77 6,006,657.92 390,336.78 0.36 1,498.49 MWD+IFR-AK-CAZ-SC(4) 6,005.64 66.99 50.07 3,534.62 3,485.52 3,008.90 2,559.82 6,006,713.38 390,403.67 1.26 1,518.82 MWD+IFR-AK-CAZ-SC(4) 6,100.09 66.81 52.58 3,571.68 3,522.58 3,063.19 2,627.63 6,006,766.64 390,472.29 2.45 1,536.40 MWD+IFR-AK-CAZ-SC(4) 6,194.63 66.94 51.85 3,608.81 3,559.71 3,116.46 2,696.35 6,006,818.87 390,541.79 0.72 1,552.67 MWD+IFR-AK-CAZ-SC(4) 6,288.49 66.62 50.65 3,645.81 3,596.71 3,170.45 2,763.62 6,006,871.83 390,609.85 1.22 1,570.23 MWD+IFR-AK-CAZ-SC(4) 6,383.05 66.98 51.07 3,683.06 3,633.96 3,225.31 2,831.03 6,006,925.67 390,678.08 0.56 1,588.51 MWD+IFR-AK-CAZ-SC(4) 6,477.60 66.79 54.00 3,720.19 3,671.09 3,278.20 2,900.04 6,006,977.51 390,747.87 2.86 1,604.31 MWD+IFR-AK-CAZ-SC(4) 6,571.92 66.86 57.16 3,757.32 3,708.22 3,327.20 2,971.55 6,007,025.43 390,820.11 3.08 1,615.50 MWD+IFR-AK-CAZ-SC(4) 6,666.03 66.68 57.62 3,794.44 3,745.34 3,373.81 3,044.40 6,007,070.93 390,893.64 0.49 1,623.96 MWD+IFR-AK-CAZ-SC(4) 6,761.05 66.99 55.86 3,831.82 3,782.72 3,421.72 3,117.45 6,007,117.73 390,967.39 1.73 1,633.48 MWD+IFR-AK-CAZ-SC(4) 6,853.66 66.59 53.64 3,868.32 3,819.22 3,470.84 3,186.95 6,007,165.80 391,037.62 2.25 1,645.69 MWD+IFR-AK-CAZ-SC(4) 6,949.56 66.70 50.93 3,906.34 3,857.24 3,524.69 3,256.59 6,007,218.59 391,108.05 2.60 1,662.06 MWD+IFR-AK-CAZ-SC(4) 7,044.53 66.60 50.73 3,943.98 3,894.88 3,579.76 3,324.19 6,007,272.64 391,176.46 0.22 1,680.44 MWD+IFR-AK-CAZ-SC(4) 7,136.15 66.91 50.51 3,980.14 3,931.04 3,633.17 3,389.25 6,007,325.06 391,242.32 0.40 1,698.49 MWD+IFR-AK-CAZ-SC(4) 7,232.23 66.69 50.61 4,017.99 3,968.89 3,689.27 3,457.46 6,007,380.12 391,311.35 0.25 1,717.51 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 5:26:10PM Page 4 COMPASS 5000.1 Build 65 • S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130: 12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,327.46 66.72 49.59 4,055.65 4,006.55 3,745.38 3,524.56 6,007,435.21 391,379.28 0.98 1,737.04 MWD+IFR-AK-CAZ-SC(4) 7,421.47 66.97 48.71 4,092.62 4,043.52 3,801.91 3,589.94 6,007,490.75 391,445.50 0.90 1,757.73 MWD+IFR-AK-CAZ-SC(4) 7,514.67 66.72 48.92 4,129.27 4,080.17 3,858.34 3,654.43 6,007,546.20 391,510.83 0.34 1,778.73 MWD+IFR-AK-CAZ-SC(4) 7,610.76 66.68 48.12 4,167.28 4,118.18 3,916.80 3,720.55 6,007,603.65 391,577.81 0.77 1,800.80 MWD+IFR-AK-CAZ-SC(4) 7,704.41 66.85 48.44 4,204.22 4,155.12 3,974.06 3,784.78 6,007,659.94 391,642.89 0.36 1,822.66 MWD+IFR-AK-CAZ-SC(4) 7,799.43 66.72 50.92 4,241.68 4,192.58 4,030.56 3,851.35 6,007,715.43 391,710.30 2.40 1,842.78 MWD+IFR-AK-CAZ-SC(4) 7,893.36 66.88 51.97 4,278.69 4,229.59 4,084.37 3,918.87 6,007,768.21 391,778.61 1.04 1,860.07 MWD+IFR-AK-CAZ-SC(4) 7,987.98 66.72 53.23 4,315.96 4,266.86 4,137.19 3,987.95 6,007,819.98 391,848.48 1.24 1,875.77 MWD+IFR-AK-CAZ-SC(4) 8,082.51 66.65 52.74 4,353.38 4,304.28 4,189.46 4,057.27 6,007,871.19 391,918.56 0.48 1,890.87 MWD+IFR-AK-CAZ-SC(4) 8,176.45 66.91 52.48 4,390.41 4,341.31 4,241.88 4,125.86 6,007,922.58 391,987.93 0.38 1,906.44 MWD+IFR-AK-CAZ-SC(4) 8,271.14 66.54 52.12 4,427.83 4,378.73 4,295.07 4,194.68 6,007,974.72 392,057.54 0.52 1,922.59 MWD+IFR-AK-CAZ-SC(4) 8,364.82 66.97 52.06 4,464.80 4,415.70 4,347.96 4,262.59 6,008,026.58 392,126.23 0.46 1,938.88 MWD+IFR-AK-CAZ-SC(4) 8,459.60 66.66 52.27 4,502.12 4,453.02 4,401.40 4,331.40 6,008,078.98 392,195.83 0.39 1,955.26 MWD+IFR-AK-CAZ-SC(4) 8,553.46 66.76 52.13 4,539.23 4,490.13 4,454.24 4,399.53 6,008,130.78 392,264.73 0.17 1,971.41 MWD+IFR-AK-CAZ-SC(4) 8,648.01 66.88 50.93 4,576.45 4,527.35 4,508.31 4,467.57 6,008,183.82 392,333.58 1.17 1,988.70 MWD+IFR-AK-CAZ-SC(4) 8,742.00 66.82 49.83 4,613.40 4,564.30 4,563.42 4,534.14 6,008,237.92 392,400.96 1.08 2,007.58 MWD+IFR-AK-CAZ-SC(4) 8,836.78 66.82 48.91 4,650.71 4,601.61 4,620.15 4,600.27 6,008,293.65 392,467.93 0.89 2,028.11 MWD+IFR-AK-CAZ-SC(4) 8,930.83 66.78 50.56 4,687.76 4,638.66 4,676.02 4,666.23 6,008,348.51 392,534.71 1.61 2,047.95 MWD+IFR-AK-CAZ-SC(4) 9,026.03 66.75 51.24 4,725.31 4,676.21 4,731.19 4,734.11 6,008,402.65 392,603.42 0.66 2,066.28 MWD+IFR-AK-CAZ-SC(4) 9,119.62 66.81 52.29 4,762.21 4,713.11 4,784.42 4,801.67 6,008,454.86 392,671.76 1.03 2,083.04 MWD+IFR-AK-CAZ-SC(4) 9,213.86 66.71 51.72 4,799.40 4,750.30 4,837.73 4,869.91 6,008,507.13 392,740.79 0.57 2,099.55 MWD+IFR-AK-CAZ-SC(4) 9,308.72 66.79 51.57 4,836.85 4,787.75 4,891.81 4,938.26 6,008,560.17 392,809.93 0.17 2,116.71 MWD+IFR-AK-CAZ-SC(4) 9,402.76 66.77 52.33 4,873.92 4,824.82 4,945.08 5,006.31 6,008,612.40 392,878.78 0.74 2,133.28 MWD+IFR-AK-CAZ-SC(4) 9,497.24 66.79 51.76 4,911.17 4,862.07 4,998.48 5,074.77 6,008,664.77 392,948.03 0.55 2,149.78 MWD+IFR-AK-CAZ-SC(4) 9,591.73 66.72 51.92 4,948.46 4,899.36 5,052.12 5,143.04 6,008,717.37 393,017.08 0.17 2,166.58 MWD+IFR-AK-CAZ-SC(4) 9,686.07 66.74 51.86 4,985.74 4,936.64 5,105.61 5,211.23 6,008,769.82 393,086.07 0.06 2,183.28 MWD+IFR-AK-CAZ-SC(4) 9,779.86 66.69 51.71 5,022.81 4,973.71 5,158.90 5,278.92 6,008,822.09 393,154.54 0.16 2,200.04 MW1D+IFR-AK-CAZ-SC(4) 9,874.93 66.61 50.83 5,060.49 5,011.39 5,213.51 5,347.01 6,008,875.66 393,223.44 0.85 2,217.78 MWD+IFR-AK-CAZ-SC(4) 9,969.44 66.32 49.56 5,098.23 5,049.13 5,268.98 5,413.57 6,008,930.12 393,290.82 1.27 2,236.99 MWD+IFR-AK-CAZ-SC(4) 10,064.14 67.78 49.07 5,135.16 5,086.06 5,325.83 5,479.70 6,008,985.96 393,357.79 1.61 2,257.62 MWD+IFR-AK-CAZ-SC(4) 10,157.69 67.27 48.49 5,170.92 5,121.82 5,382.79 5,544.72 6,009,041.94 393,423.65 0.79 2,278.85 MWD+IFR-AK-CAZ-SC(4) 10,252.35 67.12 48.97 5,207.61 5,158.51 5,440.35 5,610.30 6,009,098.50 393,490.09 0.49 2,300.36 MWD+IFR-AK-CAZ-SC(4) 10,347.01 67.37 50.97 5,244.23 5,195.13 5,496.49 5,677.14 6,009,153.62 393,557.76 1.97 2,320.04 MW1J+IFR-AK-CAZ-SC(4) 10,441.01 67.49 52.78 5,280.31 5,231.21 5,550.07 5,745.42 6,009,206.17 393,626.83 1.78 2,336.79 MWD+IFR-AK-CAZ-SC(4) 10,535.65 68.00 54.67 5,316.15 5,267.05 5,601.89 5,816.03 6,009,256.92 393,698.21 1.93 2,350.90 MWD+IFR-AK-CAZ-SC(4) 10,629.41 68.55 55.28 5,350.86 5,301.76 5,651.88 5,887.36 6,009,305.82 393,770.27 0.84 2,363.06 MWD+IFR-AK-CAZ-SC(4) 10,724.08 68.57 54.10 5,385.46 5,336.36 5,702.81 5,959.27 6,009,355.67 393,842.93 1.16 2,375.79 MWD+IFR-AK-CAZ-SC(4) 10,818.35 68.88 53.26 5,419.67 5,370.57 5,754.84 6,030.04 6,009,406.62 393,914.47 0.89 2,390.02 MWD+IFR-AK-CAZ-SC(4) 10,912.76 69.47 51.94 5,453.24 5,404.14 5,808.44 6,100.14 6,009,459.15 393,985.36 1.45 2,405.95 MWD+IFR-AK-CAZ-SC(4) 11,007.72 70.06 51.78 5,486.08 5,436.98 5,863.47 6,170.22 6,009,513.12 394,056.25 0.64 2,423.17 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 5:26:10PM Page 5 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,101.51 69.97 51.87 5,518.13 5,469.03 5,917.94 6,239.51 6,009,566.54 394,126.35 0.13 2,440.25 MVVD+IFR-AK-CAZ-SC(4) 11,195.93 70.88 50.27 5,549.77 5,500.67 5,973.84 6,308.71 6,009,621.39 394,196.37 1.86 2,458.64 MWD+IFR-AK-CAZ-SC(4) 11,290.91 70.55 50.16 5,581.14 5,532.04 6,031.21 6,377.60 6,009,677.71 394,266.11 0.36 2,478.48 MWD+IFR-AK-CAZ-SC(4) 11,384.85 70.84 50.04 5,612.20 5,563.10 6,088.08 6,445.61 6,009,733.55 394,334.97 0.33 2,498.27 MWD+IFR-AK-CAZ-SC(4) 11,479.40 70.95 49.71 5,643.14 5,594.04 6,145.66 6,513.93 6,009,790.09 394,404.14 0.35 2,518.56 MWD+IFR-AK-CAZ-SC(4) 11,573.08 71.03 49.91 5,673.66 5,624.56 6,202.82 6,581.59 6,009,846.22 394,472.64 0.22 2,538.77 MWD+IFR-AK-CAZ-SC(4) 11,668.90 71.69 50.04 5,704.28 5,655.18 6,261.21 6,651.12 6,009,903.55 394,543.03 0.70 2,559.23 MWD+IFR-AK-CAZ-SC(4) 11,762.19 71.41 49.94 5,733.81 5,684.71 6,318.10 6,718.90 6,009,959.42 394,611.65 0.32 2,579.16 MWD+IFR-AK-CAZ-SC(4) 11,857.33 71.27 50.73 5,764.25 5,715.15 6,375.64 6,788.28 6,010,015.90 394,681.89 0.80 2,598.92 MWD+IFR-AK-CAZ-SC(4) 11,950.69 71.88 50.21 5,793.75 5,744.65 6,432.01 6,856.60 6,010,071.24 394,751.04 0.84 2,618.13 MWD+IFR-AK-CAZ-SC(4) 12,045.71 72.48 50.38 5,822.83 5,773.73 6,489.80 6,926.19 6,010,127.97 394,821.49 0.65 2,638.03 MWD+IFR-AK-CAZ-SC(4) 12,139.45 71.94 50.70 5,851.47 5,802.37 6,546.53 6,995.11 6,010,183.65 394,891.24 0.66 2,657.29 MWD+IFR-AK-CAZ-SC(4) 12,233.98 71.89 48.55 5,880.82 5,831.72 6,604.74 7,063.56 6,010,240.81 394,960.56 2.16 2,678.07 MWD+IFR-AK-CAZ-SC(4) 12,328.94 71.63 47.37 5,910.54 5,861.44 6,665.13 7,130.54 6,010,300.19 395,028.43 1.21 2,701.48 MW1J+IFR-AK-CAZ-SC(4) 12,422.93 71.86 47.27 5,939.99 5,890.89 6,725.64 7,196.16 6,010,359.70 395,094.95 0.26 2,725.60 MWD+IFR-AK-CAZ-SC(4) 12,516.70 71.78 46.93 5,969.24 5,920.14 6,786.28 7,261.42 6,010,419.35 395,161.11 0.35 2,750.01 MWD+IFR-AK-CAZ-SC(4) 12,611.40 71.02 46.15 5,999.45 5,950.35 6,848.02 7,326.57 6,010,480.09 395,227.17 1.12 2,775.44 MWD+IFR-AK-CAZ-SC(4) 12,705.69 71.65 46.96 6,029.63 5,980.53 6,909.44 7,391.43 6,010,540.53 395,292.94 1.05 2,800.72 MWD+IFR-AK-CAZ-SC(4) 12,800.91 72.07 45.30 6,059.27 6,010.17 6,972.15 7,456.66 6,010,602.25 395,359.10 1.71 2,826.98 MWD+IFR-AK-CAZ-SC(4) 12,894.79 72.30 42.33 6,088.00 6,038.90 7,036.64 7,518.53 6,010,665.79 395,421.92 3.02 2,856.35 MWD+IFR-AK-CAZ-SC(4) 12,988.83 73.05 38.28 6,116.02 6,066.92 7,105.09 7,576.58 6,010,733.36 395,480.99 4.19 2,890.99 MWD+IFR-AK-CAZ-SC(4) 13,083.81 72.57 34.38 6,144.10 6,095.00 7,178.17 7,630.32 6,010,805.61 395,535.83 3.96 2,931.70 MWD+IFR-AK-CAZ-SC(4) 13,133.00 71.87 32.49 6,159.12 6,110.02 7,217.25 7,656.13 6,010,844.30 395,562.22 3.93 2,954.81 MWD+IFR-AK-CAZ-SC(5) 13,159.59 71.47 34.70 6,167.48 6,118.38 7,238.28 7,670.10 6,010,865.11 395,576.49 8.03 2,967.20 INC+TREND(6) 13,221.64 72.96 34.78 6,186.43 6,137.33 7,286.83 7,703.77 6,010,913.15 395,610.89 2.40 2,995.18 INC+TREND(6) 13,290.02 72.81 33.35 6,206.56 6,157.46 7,340.96 7,740.37 6,010,966.72 395,648.30 2.01 3,026.79 MWD+IFR-AK-CAZ-SC(7) 13,298.03 72.78 34.84 6,208.93 6,159.83 7,347.30 7,744.66 6,010,972.99 395,652.68 17.77 3,030.49 MWD+IFR-AK-CAZ-SC(7) 13,386.37 72.65 33.82 6,235.18 6,186.08 7,416.96 7,792.23 6,011,041.92 395,701.29 1.11 3,070.96 MWD+IFR-AK-CAZ-SC(7) 13,484.45 71.76 32.22 6,265.15 6,216.05 7,495.25 7,843.12 6,011,119.44 395,753.34 1.80 3,117.62 MWD+IFR-AK-CAZ-SC(7) 13,579.78 71.27 29.78 6,295.38 6,246.28 7,572.74 7,889.68 6,011,196.21 395,801.06 2.48 3,165.52 MWD+IFR-AK-CAZ-SC(7) 13,674.32 71.64 26.95 6,325.45 6,276.35 7,651.60 7,932.26 6,011,274.42 395,844.82 2.86 3,216.46 MWD+IFR-AK-CAZ-SC(7) 13,768.99 71.46 25.25 6,355.42 6,306.32 7,732.25 7,971.76 6,011,354.45 395,885.53 1.71 3,270.38 MWD+IFR-AK-CAZ-SC(7) 13,865.52 72.77 23.12 6,385.07 6,335.97 7,816.04 8,009.39 6,011,437.67 395,924.40 2.50 3,327.96 MWD+IFR-AK-CAZ-SC(7) 13,959.37 72.46 22.49 6,413.11 6,364.01 7,898.60 8,044.11 6,011,519.69 395,960.35 0.72 3,385.76 MWD+IFR-AK-CAZ-SC(7) 14,055.60 74.39 20.46 6,440.56 6,391.46 7,984.43 8,077.86 6,011,604.99 395,995.39 2.85 3,446.91 MWD+IFR-AK-CAZ-SC(7) 14,151.45 73.56 16.19 6,467.03 6,417.93 8,071.85 8,106.82 6,011,691.96 396,025.66 4.37 3,511.65 MWD+IFR-AK-CAZ-SC(7) 14,246.43 73.49 12.51 6,493.98 6,444.88 8,160.08 8,129.39 6,011,779.83 396,049.55 3.72 3,580.01 MWD+IFR-AK-CAZ-SC(7) 14,341.85 73.82 9.50 6,520.83 6,471.73 8,249.94 8,146.87 6,011,869.41 396,068.38 3.05 3,652.15 MWD+IFR-AK-CAZ-SC(7) 14,438.31 74.20 6.66 6,547.41 6,498.31 8,341.74 8,159.90 6,011,961.00 396,082.78 2.86 3,728.03 MWD+IFR-AK-CAZ-SC(7) 14,532.95 74.54 5.60 6,572.91 6,523.81 8,432.36 8,169.63 6,012,051.45 396,093.87 1.14 3,804.35 MWD+IFR-AK-CAZ-SC(7) 2/24/2015 5:26:10PM Page 6 COMPASS 5000.1 Build 65 • i i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 14,628.23 74.21 6.41 6,598.57 6,549.47 8,523.61 8,179.23 6,012,142.54 396,104.84 0.89 3,881.30 MWD+IFR-AK-CAZ-SC(7) 14,723.68 73.93 8.03 6,624.77 6,575.67 8,614.67 8,190.76 6,012,233.40 396,117.74 1.66 3,957.20 MWD+IFR-AK-CAZ-SC(7) 14,818.61 73.83 7.91 6,651.13 6,602.03 8,704.98 8,203.41 6,012,323.51 396,131.74 0.16 4,031.93 MWD+IFR-AK-CAZ-SC(7) 14,914.03 75.43 4.83 6,676.43 6,627.33 8,796.41 8,213.60 6,012,414.77 396,143.31 3.54 4,108.76 MWD+IFR-AK-CAZ-SC(7) 15,009.95 77.17 1.20 6,699.15 6,650.05 8,889.45 8,218.49 6,012,507.71 396,149.60 4.10 4,189.44 MWD+IFR-AK-CAZ-SC(7) 15,105.09 78.29 358.92 6,719.37 6,670.27 8,982.41 8,218.59 6,012,600.65 396,151.09 2.62 4,272.22 MWD+IFR-AK-CAZ-SC(7) 15,200.20 78.76 356.24 6,738.30 6,689.20 9,075.52 8,214.65 6,012,693.81 396,148.55 2.81 4,356.98 MWD+IFR-AK-CAZ-SC(7) 15,295.87 78.91 353.88 6,756.82 6,707.72 9,169.03 8,206.57 6,012,787.42 396,141.88 2.43 4,443.96 MWD+IFR-AK-CAZ-SC(7) 15,390.86 80.45 349.98 6,773.85 6,724.75 9,261.53 8,193.44 6,012,880.10 396,130.14 4.35 4,532.34 MWD+IFR-AK-CAZ-SC(7) 15,486.39 81.01 345.81 6,789.24 6,740.14 9,353.70 8,173.67 6,012,972.54 396,111.76 4.35 4,623.43 MWD+IFR-AK-CAZ-SC(7) 15,581.01 82.91 342.05 6,802.48 6,753.38 9,443.70 8,147.74 6,013,062.92 396,087.19 4.42 4,715.40 MWD+IFR-AK-CAZ-SC(7) 15,677.16 83.82 338.93 6,813.59 6,764.49 9,533.71 8,115.84 6,013,153.39 396,056.65 3.36 4,810.08 MWD+IFR-AK-CAZ-SC(7) 15,722.29 84.25 337.06 6,818.28 6,769.18 9,575.32 8,099.03 6,013,195.25 396,040.46 4.23 4,854.80 MWD+IFR-AK-CAZ-SC(7) 15,757.00 84.25 337.06 6,821.76 6,772.66 9,607.13 8,085.57 6,013,227.25 396,027.48 0.00 4,889.24 PROJECTED to TD 2/24/2015 5:26:10PM Page 7 COMPASS 5000.1 Build 65 • • 213160 25484 RECEIVED MAR 0 6 2015 FINAL AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-130 Definitive Survey Report NAD 83 24 February, 2015 , • • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States 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 4 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 usft Northing: 6,003,490.74 usfl Latitude: 70°25'7.804 N +EI-W 0.00 usft Easting: 1,527,831.05 usfl Longitude: 150°55'1.908 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 12.50 usft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 1/20/2015 18.54 80.87 57,556 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,083.86 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.60 0.00 0.00 333.00 Survey Program Date 2/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 116.69 195.98 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:C 246.78 523.39 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:C 581.10 3,288.08 CD3-130PB2 MWD I(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:C 3,383.02 13,083.86 CD3-130PB2 MWD II(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:C 13,133.00 13,133.00 CD3-130 Srvy#1 -MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 3:41 13,159.59 13,221.64 CD3-130 Srvy#2-INC+TREND(CD3-13 INC+TREND Inclinometer+known azi trend 2/24/2015 2:4 13,290.02 15,722.29 CD3-130 Srvy#3-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2015 2:51 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100.) (ft) Survey Tool Name 36.60 0.00 0.00 36.60 -12.50 0.00 0.00 6,003,490.74 1,527,831.05 0.00 0.00 UNDEFINED 116.69 0.13 154.32 116.69 67.59 -0.08 0.04 6,003,490.66 1,527,831.09 0.16 -0.09 GYD-GC-SS(1) 174.04 0.20 113.61 174.04 124.94 -0.18 0.16 6,003,490.56 1,527,831.21 0.23 -0.23 GYD-GC-SS(1) 195.98 0.43 347.45 195.98 146.88 -0.12 0.18 6,003,490.62 1,527,831.22 2.60 -0.18 GYD-GC-SS(1) 246.78 1.48 253.68 246.77 197.67 -0.11 -0.49 6,003,490.63 1,527,830.55 3.09 0.12 GYD-GC-SS(2) 264.39 1.99 249.47 264.38 215.28 -0.29 -1.00 6,003,490.47 1,527,830.05 2.98 0.20 GYD-GC-SS(2) 294.67 1.78 251.65 294.64 245.54 -0.62 -1.94 6,003,490.15 1,527,829.10 0.73 0.33 GYD-GC-SS(2) 340.31 1.68 252.62 340.26 291.16 -1.04 -3.25 6,003,489.75 1,527,827.79 0.23 0.55 GYD-GC-SS(2) 388.34 1.95 271.93 388.26 339.16 -1.22 -4.74 6,003,489.59 1,527,826.29 1.38 1.06 GYD-GC-SS(2) 430.86 2.33 297.40 430.76 381.66 -0.80 -6.23 6,003,490.03 1,527,824.81 2.38 2.11 GYD-GC-SS(2) 523.39 4.55 323.70 523.12 474.02 3.02 -10.07 6,003,493.91 1,527,821.03 2.88 7.27 GYD-GC-SS(2) 581.10 6.81 328.21 580.54 531.44 7.78 -13.23 6,003,498.71 1,527,817.94 3.99 12.93 MWD+IFR-AK-CAZ-SC(3) 2/24/2015 3:47:57PM Page 2 COMPASS 5000.1 Build 65 • S . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 673.14 8.88 328.76 671.72 622.62 18.49 -19.79 6,003,509.52 1,527,811.54 2.25 25.46 MWD+IFR-AK-CAZ-SC(3) 766.63 11.82 329.96 763.67 714.57 32.95 -28.33 6,003,524.11 1,527,803.23 3.15 42.22 MWD+IFR-AK-CAZ-SC(3) 863.43 15.51 333.17 857.72 808.62 53.09 -39.14 6,003,544.41 1,527,792.72 3.89 65.07 MWD+IFR-AK-CAZ-SC(3) 957.77 21.32 339.17 947.20 898.10 80.40 -50.94 6,003,571.89 1,527,781.33 6.47 94.76 MWD+IFR-AK-CAZ-SC(3) 1,007.05 22.34 340.91 992.94 943.84 97.62 -57.19 6,003,589.21 1,527,775.35 2.45 112.95 MWD+IFR-AK-CAZ-SC(3) 1,050.31 20.83 341.51 1,033.17 984.07 112.69 -62.32 6,003,604.35 1,527,770.45 3.53 128.70 MWD+IFR-AK-CAZ-SC(3) 1,143.43 20.47 342.59 1,120.31 1,071.21 143.93 -72.44 6,003,635.73 1,527,760.80 0.56 161.13 MWD+IFR-AK-CAZ-SC(3) 1,237.27 22.95 344.74 1,207.48 1,158.38 177.24 -82.16 6,003,669.19 1,527,751.57 2.77 195.23 MWD+IFR-AK-CAZSC(3) 1,330.96 28.20 345.89 1,291.97 1,242.87 216.36 -92.38 6,003,708.45 1,527,741.96 5.63 234.72 MWD+IFR-AK-CAZ-SC(3) 1,377.30 31.42 347.29 1,332.17 1,283.07 238.77 -97.70 6,003,730.93 1,527,736.97 7.11 257.10 MWD+IFR-AK-CAZ-SC(3) 1,420.99 30.24 347.61 1,369.69 1,320.59 260.62 -102.57 6,003,752.86 1,527,732.43 2.73 278.78 MWD+IFR-AK-CAZ-SC(3) 1,515.26 34.39 351.00 1,449.34 1,400.24 310.13 -111.83 6,003,802.49 1,527,723.92 4.80 327.10 MWD+IFR-AK-CAZ-SC(3) 1,611.91 37.55 354.83 1,527.57 1,478.47 366.44 -118.76 6,003,858.90 1,527,717.84 4.01 380.42 MWD+IFR-AK-CAZ-SC(3) 1,706.66 37.56 356.81 1,602.68 1,553.58 424.03 -122.97 6,003,916.54 1,527,714.50 1.27 433.64 MWD+IFR-AK-CAZ-SC(3) 1,800.81 41.32 6.06 1,675.44 1,626.34 483.67 -121.28 6,003,976.14 1,527,717.09 7.40 486.01 MWD+IFR-AK-CAZ-SC(3) 1,848.26 43.60 10.34 1,710.46 1,661.36 515.35 -116.69 6,004,007.75 1,527,722.15 7.75 512.16 MWD+IFR-AK-CAZSC(3) 1,895.17 43.23 11.92 1,744.53 1,695.43 546.98 -110.47 6,004,039.28 1,527,728.85 2.45 537.52 MWD+IFR-AK-CAZ-SC(3) 1,989.25 45.20 16.54 1,811.98 1,762.88 610.53 -94.31 6,004,102.57 1,527,745.97 4.01 586.80 MWD+IFR-AK-CAZ-SC(3) 2,084.45 47.26 22.32 1,877.86 1,828.76 675.28 -71.40 6,004,166.96 1,527,769.85 4.89 634.10 MWD+IFR-AK-CAZ-SC(3) 2,178.57 47.75 27.18 1,941.46 1,892.36 738.26 -42.35 6,004,229.50 1,527,799.84 3.84 677.03 MWD+IFR-AK-CAZ-SC(3) 2,273.37 49.47 32.23 2,004.16 1,955.06 799.98 -7.10 6,004,290.67 1,527,836.02 4.39 716.01 MWD+IFR-AK-CAZ-SC(3) 2,367.80 53.11 36.13 2,063.22 2,014.12 860.87 34.33 6,004,350.92 1,527,878.36 5.02 751.45 MWD+IFR-AK-CAZ-SC(3) 2,415.75 54.92 37.46 2,091.39 2,042.29 891.93 57.57 6,004,381.63 1,527,902.06 4.39 768.58 MWD+IFR-AK-CAZ-SC(3) 2,462.21 56.48 38.46 2,117.57 2,068.47 922.19 81.18 6,004,411.52 1,527,926.12 3.80 784.82 MWD+IFR-AK-CAZ-SC(3) 2,556.13 59.99 40.46 2,167.01 2,117.91 983.81 131.94 6,004,472.37 1,527,977.80 4.15 816.68 MWD+IFR-AK-CAZ-SC(3) 2,650.76 63.05 42.23 2,212.13 2,163.03 1,046.23 186.89 6,004,533.95 1,528,033.68 3.63 847.35 MWD+IFR-AK-CAZ-SC(3) 2,746.60 66.54 44.40 2,252.95 2,203.85 1,109.30 246.38 6,004,596.10 1,528,094.11 4.18 876.54 MWD+IFR-AK-CAZ-SC(3) 2,840.06 69.42 45.36 2,287.98 2,238.88 1,170.68 307.52 6,004,656.55 1,528,156.16 3.23 903.47 MWD+IFR-AK-CAZ-SC(3) 2,936.50 69.04 49.56 2,322.20 2,273.10 1,231.63 373.93 6,004,716.48 1,528,223.48 4.09 927.63 MWD+IFR-AK-CAZ-SC(3) 3,028.93 67.59 51.65 2,356.35 2,307.25 1,286.14 440.30 6,004,769.98 1,528,290.65 2.62 946.07 MWD+IFR-AK-CAZ-SC(3) 3,124.41 67.67 51.38 2,392.69 2,343.59 1,341.09 509.41 6,004,823.88 1,528,360.58 0.27 963.65 MWD+IFR-AK-CAZ-SC(3) 3,217.44 67.26 50.87 2,428.34 2,379.24 1,395.02 576.31 6,004,876.79 1,528,428.28 0.67 981.33 MWD+IFR-AK-CAZ-SC(3) 3,288.08 67.57 51.09 2,455.47 2,406.37 1,436.08 626.98 6,004,917.08 1,528,479.56 0.52 994.91 MWD+IFR-AK-CAZ-SC(3) 3,353.60 67.73 50.04 2,480.39 2,431.29 1,474.57 673.78 6,004,954.86 1,528,526.93 1.50 1,007.96 MWD+IFR-AK-CAZ-SC(4) 10-3/4"x 13-1/2" 3,383.02 67.80 49.57 2,491.52 2,442.42 1,492.15 694.58 6,004,972.11 1,528,548.00 1.50 1,014.18 MWD+IFR-AK-CAZ-SC(4) 3,452.44 69.13 50.92 2,517.01 2,467.91 1,533.44 744.23 6,005,012.65 1,528,598.25 2.63 1,028.43 MWD+IFR-AK-CAZ-SC(4) 3,545.71 66.99 46.85 2,551.87 2,502.77 1,590.29 809.40 6,005,068.51 1,528,664.27 4.65 1,049.50 MWD+IFR-AK-CAZ-SC(4) 3,640.02 67.18 45.90 2,588.59 2,539.49 1,650.22 872.28 6,005,127.48 1,528,728.04 0.95 1,074.35 MWD+IFR-AK-CAZ-SC(4) 3,735.05 67.68 48.12 2,625.06 2,575.96 1,710.05 936.46 6,005,186.33 1,528,793.12 2.22 1,098.52 MWD+IFR-AK-CAZ-SC(4) 3,828.48 67.02 50.16 2,661.05 2,611.95 1,766.46 1,001.67 6,005,241.74 1,528,859.16 2.14 1,119.18 MWD+IFR-AK-CAZ-SC(4) 3,924.06 66.83 48.92 2,698.51 2,649.41 1,823.52 1,068.57 6,005,297.78 1,528,926.91 1.21 1,139.64 MWD+IFR-AK-CAZ-SC(4) 4,019.21 66.30 50.36 2,736.35 2,687.25 1,880.05 1,135.09 6,005,353.30 1,528,994.27 1.50 1,159.82 MWD+IFR-AK-CAZ-SC(4) 4,114.29 66.18 53.52 2,774.67 2,725.57 1,933.69 1,203.60 6,005,405.89 1,529,063.57 3.04 1,176.51 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 3:47:57PM Page 3 COMPASS 5000.1 Build 65 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,206.92 66.19 52.98 2,812.07 2,762.97 1,984.39 1,271.50 6,005,455.56 1,529,132.22 0.53 1,190.86 MWD+IFR-AK-CAZ-SC(4) 4,301.87 66.10 53.17 2,850.47 2,801.37 2,036.56 1,340.92 6,005,506.68 1,529,202.41 0.21 1,205.83 MWD+IFR-AK-CAZ-SC(4) 4,395.68 66.18 50.77 2,888.42 2,839.32 2,089.41 1,408.49 6,005,558.50 1,529,270.77 2.34 1,222.24 MWD+IFR-AK-CAZ-SC(4) 4,488.92 66.07 48.83 2,926.17 2,877.07 2,144.44 1,473.61 6,005,612.53 1,529,336.70 1.91 1,241.71 MWD+IFR-AK-CAZ-SC(4) 4,583.28 66.13 48.40 2,964.39 2,915.29 2,201.48 1,538.33 6,005,668.58 1,529,402.28 0.42 1,263.14 MWD+IFR-AK-CAZ-SC(4) 4,678.37 66.18 51.48 3,002.84 2,953.74 2,257.44 1,604.89 6,005,723.53 1,529,469.66 2.96 1,282.79 MWD+IFR-AK-CAZ-SC(4) 4,772.52 66.25 51.89 3,040.82 2,991.72 2,310.86 1,672.49 6,005,775.91 1,529,538.05 0.41 1,299.70 MWD+I FR-AK-CAZ-SC(4) 4,866.24 66.13 54.96 3,078.66 3,029.56 2,361.94 1,741.33 6,005,825.95 1,529,607.66 3.00 1,313.96 MWD+I FR-AK-CAZ-SC(4) 4,960.77 66.16 55.68 3,116.89 3,067.79 2,411.13 1,812.43 6,005,874.06 1,529,679.48 0.70 1,325.51 MWD+IFR-AK-CAZ-SC(4) 5,060.57 66.12 55.17 3,157.26 3,108.16 2,462.93 1,887.58 6,005,924.71 1,529,755.39 0.47 1,337.54 MWD+IFR-AK-CAZ-SC(4) 5,156.54 65.96 54.51 3,196.23 3,147.13 2,513.43 1,959.28 6,005,974.12 1,529,827.84 0.65 1,349.99 MWD+IFR-AK-CAZ-SC(4) 5,251.34 66.22 51.63 3,234.66 3,185.56 2,565.50 2,028.54 6,006,025.13 1,529,897.88 2.79 1,364.93 MW D+I FR-AK-CAZ-SC(4) 5,344.92 66.31 50.36 3,272.33 3,223.23 2,619.41 2,095.11 6,006,078.03 1,529,965.24 1.25 1,382.75 MWD+I FR-AK-CAZ-SC(4) 5,438.08 66.89 51.30 3,309.33 3,260.23 2,673.41 2,161.39 6,006,131.02 1,530,032.33 1.12 1,400.77 MWD+I FR-AK-CAZ-SC(4) 5,533.42 66.33 51.53 3,347.18 3,298.08 2,727.99 2,229.79 6,006,184.56 1,530,101.54 0.63 1,418.35 MWD+I FR-AK-CAZ-SC(4) 5,628.02 66.63 50.05 3,384.93 3,335.83 2,782.82 2,297.00 6,006,238.36 1,530,169.56 1.47 1,436.69 MWD+I FR-AK-CAZ-S C(4) 5,723.32 66.56 49.04 3,422.79 3,373.69 2,839.57 2,363.55 6,006,294.10 1,530,236.95 0.98 1,457.04 MWD+I FR-AK-CAZ-S C(4) 5,816.92 66.67 49.21 3,459.94 3,410.84 2,895.79 2,428.51 6,006,349.33 1,530,302.75 0.20 1,477.65 MWD+IFR-AK-CAZ-SC(4) 5,911.07 66.55 48.87 3,497.31 3,448.21 2,952.43 2,493.77 6,006,404.98 1,530,368.84 0.36 1,498.49 MWD+IFR-AK-CAZ-SC(4) 6,005.64 66.99 50.07 3,534.62 3,485.52 3,008.90 2,559.82 6,006,460.44 1,530,435.73 1.26 1,518.82 MWD+I FR-AK-CAZ-SC(4) 6,100.09 66.81 52.58 3,571.68 3,522.58 3,063.19 2,627.63 6,006,513.69 1,530,504.36 2.45 1,536.40 MW D+IFR-AK-CAZ-SC(4) 6,194.63 66.94 51.85 3,608.81 3,559.71 3,116.46 2,696.35 6,006,565.92 1,530,573.86 0.72 1,552.67 MWD+IFR-AK-CAZ-SC(4) 6,288.49 66.62 50.65 3,645.81 3,596.71 3,170.45 2,763.62 6,006,618.88 1,530,641.93 1.22 1,570.23 MWD+I FR-AK-CAZ-SC(4) 6,383.05 66.98 51.07 3,683.06 3,633.96 3,225.31 2,831.03 6,006,672.71 1,530,710.15 0.56 1,588.51 MWD+I FR-AK-CAZ-SC(4) 6,477.60 66.79 54.00 3,720.19 3,671.09 3,278.20 2,900.04 6,006,724.55 1,530,779.95 2.86 1,604.31 MWD+I FR-AK-CAZ-SC(4) 6,571.92 66.86 57.16 3,757.32 3,708.22 3,327.20 2,971.55 6,006,772.47 1,530,852.19 3.08 1,615.50 MWD+I FR-AK-CAZ-SC(4) 6,666.03 66.68 57.62 3,794.44 3,745.34 3,373.81 3,044.40 6,006,817.96 1,530,925.72 0.49 1,623.96 MWD+I FR-AK-CAZ-SC(4) 6,761.05 66.99 55.86 3,831.82 3,782.72 3,421.72 3,117.45 6,006,864.76 1,530,999.48 1.73 1,633.48 MW D+I FR-AK-CAZ-SC(4) 6,853.66 66.59 53.64 3,868.32 3,819.22 3,470.84 3,186.95 6,006,912.82 1,531,069.71 2.25 1,645.69 MWD+IFR-AK-CAZ-SC(4) 6,949.56 66.70 50.93 3,906.34 3,857.24 3,524.69 3,256.59 6,006,965.61 1,531,140.14 2.60 1,662.06 MWD+IFR-AK-CAZ-SC(4) 7,044.53 66.60 50.73 3,943.98 3,894.88 3,579.76 3,324.19 6,007,019.66 1,531,208.56 0.22 1,680.44 MWD+IFR-AK-CAZ-SC(4) 7,136.15 66.91 50.51 3,980.14 3,931.04 3,633.17 3,389.25 6,007,072.07 1,531,274.42 0.40 1,698.49 MWD+IFR-AK-CAZ-SC(4) 7,232.23 66.69 50.61 4,017.99 3,968.89 3,689.27 3,457.46 6,007,127.14 1,531,343.45 0.25 1,717.51 MWD+IFR-AK-CAZ-SC(4) 7,327.46 66.72 49.59 4,055.65 4,006.55 3,745.38 3,524.56 6,007,182.22 1,531,411.39 0.98 1,737.04 MWD+IFR-AK-CAZ-SC(4) 7,421.47 66.97 48.71 4,092.62 4,043.52 3,801.91 3,589.94 6,007,237.76 1,531,477.61 0.90 1,757.73 MWD+IFR-AK-CAZ-SC(4) 7,514.67 66.72 48.92 4,129.27 4,080.17 3,858.34 3,654.43 6,007,293.20 1,531,542.94 0.34 1,778.73 MWD+IFR-AK-CAZ-SC(4) 7,610.76 66.68 48.12 4,167.28 4,118.18 3,916.80 3,720.55 6,007,350.65 1,531,609.92 0.77 1,800.80 MWD+IFR-AK-CAZ-SC(4) 7,704.41 66.85 48.44 4,204.22 4,155.12 3,974.06 3,784.78 6,007,406.93 1,531,675.01 0.36 1,822.66 MWD+I FR-AK-CAZ-SC(4) 7,799.43 66.72 50.92 4,241.68 4,192.58 4,030.56 3,851.35 6,007,462.42 1,531,742.42 2.40 1,842.78 MWD+IFR-AK-CAZ-SC(4) 7,893.36 66.88 51.97 4,278.69 4,229.59 4,084.37 3,918.87 6,007,515.20 1,531,810.73 1.04 1,860.07 MWD+I FR-AK-CAZ-SC(4) 7,987.98 66.72 53.23 4,315.96 4,266.86 4,137.19 3,987.95 6,007,566.97 1,531,880.60 1.24 1,875.77 MWD+I FR-AK-CAZ-SC(4) 8,082.51 66.65 52.74 4,353.38 4,304.28 4,189.46 4,057.27 6,007,618.17 1,531,950.69 0.48 1,890.87 MWD+IFR-AK-CAZ-SC(4) 8,176.45 66.91 52.48 4,390.41 4,341.31 4,241.88 4,125.86 6,007,669.55 1,532,020.06 0.38 1,906.44 MWD+I FR-AK-CAZ-SC(4) 8,271.14 66.54 52.12 4,427.83 4,378.73 4,295.07 4,194.68 6,007,721.70 1,532,089.67 0.52 1,922.59 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 3:47:57PM Page 4 COMPASS 5000.1 Build 65 • • • . ConocoPhilhhps Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,364.82 66.97 52.06 4,464.80 4,415.70 4,347.96 4,262.59 6,007,773.55 1,532,158.37 0.46 1,938.88 MWD+IFR-AK-CAZ-SC(4) 8,459.60 66.66 52.27 4,502.12 4,453.02 4,401.40 4,331.40 6,007,825.94 1,532,227.97 0.39 1,955.26 MWD+IFR-AK-CAZ-SC(4) 8,553.46 66.76 52.13 4,539.23 4,490.13 4,454.24 4,399.53 6,007,877.74 1,532,296.87 0.17 1,971.41 MWD+IFR-AK-CAZ-SC(4) 8,648.01 66.88 50.93 4,576.45 4,527.35 4,508.31 4,467.57 6,007,930.78 1,532,365.72 1.17 1,988.70 MWD+IFR-AK-CAZ-SC(4) 8,742.00 66.82 49.83 4,613.40 4,564.30 4,563.42 4,534.14 6,007,984.87 1,532,433.11 1.08 2,007.58 MWD+IFR-AK-CAZ-SC(4) 8,836.78 66.82 48.91 4,650.71 4,601.61 4,620.15 4,600.27 6,008,040.60 1,532,500.08 0.89 2,028.11 MWD+IFR-AK-CAZ-SC(4) 8,930.83 66.78 50.56 4,687.76 4,638.66 4,676.02 4,666.23 6,008,095.46 1,532,566.86 1.61 2,047.95 MWD+IFR-AK-CAZ-SC(4) 9,026.03 66.75 51.24 4,725.31 4,676.21 4,731.19 4,734.11 6,008,149.60 1,532,635.57 0.66 2,066.28 MWD+IFR-AK-CAZ-SC(4) 9,119.62 66.81 52.29 4,762.21 4,713.11 4,784.42 4,801.67 6,008,201.80 1,532,703.92 1.03 2,083.04 MWD+IFR-AK-CAZ-SC(4) 9,213.86 66.71 51.72 4,799.40 4,750.30 4,837.73 4,869.91 6,008,254.06 1,532,772.95 0.57 2,099.55 MWD+IFR-AK-CAZSC(4) 9,308.72 66.79 51.57 4,836.85 4,787.75 4,891.81 4,938.26 6,008,307.10 1,532,842.10 0.17 2,116.71 MWD+IFR-AK-CAZ-SC(4) 9,402.76 66.77 52.33 4,873.92 4,824.82 4,945.08 5,006.31 6,008,359.33 1,532,910.94 0.74 2,133.28 MWD+IFR-AK-CAZSC(4) 9,497.24 66.79 51.76 4,911.17 4,862.07 4,998.48 5,074.77 6,008,411.69 1,532,980.19 0.55 2,149.78 MWD+IFR-AK-CAZ-SC(4) 9,591.73 66.72 51.92 4,948.46 4,899.36 5,052.12 5,143.04 6,008,464.29 1,533,049.25 0.17 2,166.58 MWD+IFR-AK-CAZ-SC(4) 9,686.07 66.74 51.86 4,985.74 4,936.64 5,105.61 5,211.23 6,008,516.74 1,533,118.24 0.06 2,183.28 MWD+IFR-AK-CAZ-SC(4) 9,779.86 66.69 51.71 5,022.81 4,973.71 5,158.90 5,278.92 6,008,569.01 1,533,186.72 0.16 2,200.04 MWD+IFR-AK-CAZSC(4) 9,874.93 66.61 50.83 5,060.49 5,011.39 5,213.51 5,347.01 6,008,622.58 1,533,255.62 0.85 2,217.78 MWD+IFR-AK-CAZ-SC(4) 9,969.44 66.32 49.56 5,098.23 5,049.13 5,268.98 5,413.57 6,008,677.03 1,533,323.00 1.27 2,236.99 MWD+IFR-AK-CAZ-SC(4) 10,064.14 67.78 49.07 5,135.16 5,086.06 5,325.83 5,479.70 6,008,732.87 1,533,389.97 1.61 2,257.62 MWD+IFR-AK-CAZ-SC(4) 10,157.69 67.27 48.49 5,170.92 5,121.82 5,382.79 5,544.72 6,008,788.84 1,533,455.84 0.79 2,278.85 MWD+IFR-AK-CAZ-SC(4) 10,252.35 67.12 48.97 5,207.61 5,158.51 5,440.35 5,610.30 6,008,845.40 1,533,522.28 0.49 2,300.36 MWD+IFR-AK-CAZ-SC(4) 10,347.01 67.37 50.97 5,244.23 5,195.13 5,496.49 5,677.14 6,008,900.52 1,533,589.95 1.97 2,320.04 MWD+IFR-AK-CAZ-SC(4) 10,441.01 67.49 52.78 5,280.31 5,231.21 5,550.07 5,745.42 6,008,953.06 1,533,659.03 1.78 2,336.79 MWD+IFR-AK-CAZ-SC(4) 10,535.65 68.00 54.67 5,316.15 5,267.05 5,601.89 5,816.03 6,009,003.80 1,533,730.40 1.93 2,350.90 MWD+IFR-AK-CAZ-SC(4) 10,629.41 68.55 55.28 5,350.86 5,301.76 5,651.88 5,887.36 6,009,052.71 1,533,802.47 0.84 2,363.06 MWD+IFR-AK-CAZ-SC(4) 10,724.08 68.57 54.10 5,385.46 5,336.36 5,702.81 5,959.27 6,009,102.54 1,533,875.13 1.16 2,375.79 MWD+IFR-AK-CAZ-SC(4) 10,818.35 68.88 53.26 5,419.67 5,370.57 5,754.84 6,030.04 6,009,153.50 1,533,946.68 0.89 2,390.02 MWD+IFR-AK-CAZ-SC(4) 10,912.76 69.47 51.94 5,453.24 5,404.14 5,808.44 6,100.14 6,009,206.03 1,534,017.57 1.45 2,405.95 MWD+IFR-AK-CAZ-SC(4) 11,007.72 70.06 51.78 5,486.08 5,436.98 5,863.47 6,170.22 6,009,259.98 1,534,088.46 0.64 2,423.17 MWD+IFR-AK-CAZ-SC(4) 11,101.51 69.97 51.87 5,518.13 5,469.03 5,917.94 6,239.51 6,009,313.41 1,534,158.56 0.13 2,440.25 MWD+IFR-AK-CAZ-SC(4) 11,195.93 70.88 50.27 5,549.77 5,500.67 5,973.84 6,308.71 6,009,368.25 1,534,228.59 1.86 2,458.64 MWD+IFR-AK-CAZ-SC(4) 11,290.91 70.55 50.16 5,581.14 5,532.04 6,031.21 6,377.60 6,009,424.57 1,534,298.33 0.36 2,478.48 MWD+IFR-AK-CAZ-SC(4) 11,384.85 70.84 50.04 5,612.20 5,563.10 6,088.08 6,445.61 6,009,480.40 1,534,367.19 0.33 2,498.27 MWD+IFR-AK-CAZ-SC(4) 11,479.40 70.95 49.71 5,643.14 5,594.04 6,145.66 6,513.93 6,009,536.94 1,534,436.36 0.35 2,518.56 MWD+I FR-AK-CAZ-SC(4) 11,573.08 71.03 49.91 5,673.66 5,624.56 6,202.82 6,581.59 6,009,593.06 1,534,504.87 0.22 2,538.77 MWD+IFR-AK-CAZ-SC(4) 11,668.90 71.69 50.04 5,704.28 5,655.18 6,261.21 6,651.12 6,009,650.39 1,534,575.26 0.70 2,559.23 MWD+IFR-AK-CAZ-SC(4) 11,762.19 71.41 49.94 5,733.81 5,684.71 6,318.10 6,718.90 6,009,706.26 1,534,643.89 0.32 2,579.16 MWD+IFR-AK-CAZ-SC(4) 11,857.33 71.27 50.73 5,764.25 5,715.15 6,375.64 6,788.28 6,009,762.73 1,534,714.13 0.80 2,598.92 MWD+IFR-AK-CAZ-SC(4) 11,950.69 71.88 50.21 5,793.75 5,744.65 6,432.01 6,856.60 6,009,818.07 1,534,783.28 0.84 2,618.13 MWD+IFR-AK-CAZ-SC(4) 12,045.71 72.48 50.38 5,822.83 5,773.73 6,489.80 6,926.19 6,009,874.80 1,534,853.74 0.65 2,638.03 MWD+IFR-AK-CAZ-SC(4) 12,139.45 71.94 50.70 5,851.47 5,802.37 6,546.53 6,995.11 6,009,930.47 1,534,923.49 0.66 2,657.29 MWD+IFR-AK-CAZ-SC(4) 12,233.98 71.89 48.55 5,880.82 5,831.72 6,604.74 7,063,56 6,009,987.63 1,534,992.81 2.16 2,678.07 MWD+IFR-AK-CAZ-SC(4) 12,328.94 71.63 47.37 5,910.54 5,861.44 6,665.13 7,130.54 6,010,047.00 1,535,060.68 1.21 2,701.48 MWD+IFR-AK-CAZ-SC(4) 12,422.93 71.86 47.27 5,939.99 5,890.89 6,725.64 7,196.16 6,010,106.51 1,535,127.20 0.26 2,725.60 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 3:47:57PM Page 5 COMPASS 5000.1 Build 65 . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.60 @ 49.10usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,516.70 71.78 46.93 5,969.24 5,920.14 6,786.28 7,261.42 6,010,166.16 1,535,193.37 0.35 2,750.01 MWD+IFR-AK-CAZ-SC(4) 12,611.40 71.02 46.15 5,999.45 5,950.35 6,848.02 7,326.57 6,010,226.90 1,535,259.43 1.12 2,775.44 MWD+IFR-AK-CAZ-SC(4) 12,705.69 71.65 46.96 6,029.63 5,980.53 6,909.44 7,391.43 6,010,287.34 1,535,325.20 1.05 2,800.72 MWD+IFR-AK-CAZ-SC(4) 12,800.91 72.07 45.30 6,059.27 6,010.17 6,972.15 7,456.66 6,010,349.05 1,535,391.36 1.71 2,826.98 MWD+IFR-AK-CAZ-SC(4) 12,894.79 72.30 42.33 6,088.00 6,038.90 7,036.64 7,518.53 6,010,412.59 1,535,454.20 3.02 2,856.35 MW D+I FR-AK-CAZ-SC(4) 12,988.83 73.05 38.28 6,116.02 6,066.92 7,105.09 7,576.58 6,010,480.15 1,535,513.27 4.19 2,890.99 MWD+I FR-AK-CAZ-SC(4) 13,083.81 72.57 34.38 6,144.10 6,095.00 7,178.17 7,630.32 6,010,552.41 1,535,568.11 3.96 2,931.70 MWD+IFR-AK-CAZ-SC(4) 13,133.00 71.87 32.49 6,159.12 6,110.02 7,217.25 7,656.13 6,010,591.09 1,535,594.50 3.93 2,954.81 MWD+I FR-AK-CAZ-SC(5) 13,159.59 71.47 34.70 6,167.48 6,118.38 7,238.28 7,670.10 6,010,611.90 1,535,608.78 8.03 2,967.20 INC+TREND(6) 13,221.64 72.96 34.78 6,186.43 6,137.33 7,286.83 7,703.77 6,010,659.94 1,535,643.17 2.40 2,995.18 INC+TREND(6) 13,290.02 72.81 33.35 6,206.56 6,157.46 7,340.96 7,740.37 6,010,713.51 1,535,680.59 2.01 3,026.79 MWD+IFR-AK-CAZ-SC(7) 13,298.03 72.78 34.84 6,208.93 6,159.83 7,347.30 7,744.66 6,010,719.78 1,535,684.97 17.77 3,030.49 MWD+IFR-AK-CAZ-SC(7) 13,386.37 72.65 33.82 6,235.18 6,186.08 7,416.96 7,792.23 6,010,788.70 1,535,733.58 1.11 3,070.96 MWD+IFR-AK-CAZSC(7) 13,484.45 71.76 32.22 6,265.15 6,216.05 7,495.25 7,843.12 6,010,866.22 1,535,785.64 1.80 3,117.62 MWD+I FR-AK-CAZ-SC(7) 13,579.78 71.27 29.78 6,295.38 6,246.28 7,572.74 7,889.68 6,010,942.99 1,535,833.36 2.48 3,165.52 MWD+I FR-AK-CAZ-SC(7) 13,674.32 71.64 26.95 6,325.45 6,276.35 7,651.60 7,932.26 6,011,021.19 1,535,877.12 2.86 3,216.46 MWD+I FR-AK-CAZ-SC(7) 13,768.99 71.46 25.25 6,355.42 6,306.32 7,732.25 7,971.76 6,011,101.22 1,535,917.83 1.71 3,270.38 MWD+IFR-AK-CAZ-SC(7) 13,865.52 72.77 23.12 6,385.07 6,335.97 7,816.04 8,009.39 6,011,184.44 1,535,956.72 2.50 3,327.96 MWD+I FR-AK-CAZ-SC(7) 13,959.37 72.46 22.49 6,413.11 6,364.01 7,898.60 8,044.11 6,011,266.46 1,535,992.67 0.72 3,385.76 MWD+I FR-AK-CAZ-SC(7) 14,055.60 74.39 20.46 6,440.56 6,391.46 7,984.43 8,077.86 6,011,351.75 1,536,027.71 2.85 3,446.91 MW D+I FR-AK-CAZ-SC(7) 14,151.45 73.56 16.19 6,467.03 6,417.93 8,071.85 8,106.82 6,011,438.73 1,536,057.99 4.37 3,511.65 MWD+IFR-AK-CAZ-SC(7) 14,246.43 73.49 12.51 6,493.98 6,444.88 8,160.08 8,129.39 6,011,526.59 1,536,081.88 3.72 3,580.01 MWD+IFR-AK-CAZ-SC(7) 14,341.85 73.82 9.50 6,520.83 6,471.73 8,249.94 8,146.87 6,011,616.18 1,536,100.71 3.05 3,652.15 MWD+IFR-AK-CAZ-SC(7) 14,438.31 74.20 6.66 6,547.41 6,498.31 8,341.74 8,159.90 6,011,707.76 1,536,115.12 2.86 3,728.03 MWD+IFR-AK-CAZ-SC(7) 14,532.95 74.54 5.60 6,572.91 6,523.81 8,432.36 8,169.63 6,011,798.21 1,536,126.22 1.14 3,804.35 MWD+IFR-AK-CAZ-SC(7) 14,628.23 74.21 6.41 6,598.57 6,549.47 8,523.61 8,179.23 6,011,889.30 1,536,137.19 0.89 3,881.30 MWD+IFR-AK-CAZ-SC(7) 14,723.68 73.93 8.03 6,624.77 6,575.67 8,614.67 8,190.76 6,011,980.16 1,536,150.10 1.66 3,957.20 MWD+IFR-AK-CAZ-SC(7) 14,818.61 73.83 7.91 6,651.13 6,602.03 8,704.98 8,203.41 6,012,070.27 1,536,164.10 0.16 4,031.93 MWD+IFR-AK-CAZ-SC(7) 14,914.03 75.43 4.83 6,676.43 6,627.33 8,796.41 8,213.60 6,012,161.53 1,536,175.67 3.54 4,108.76 MWD+IFR-AK-CAZ-SC(7) 15,009.95 77.17 1.20 6,699.15 6,650.05 8,889.45 8,218.49 6,012,254.47 1,536,181.97 4.10 4,189.44 MWD+I FR-AK-CAZ-SC(7) 15,105.09 78.29 358.92 6,719.37 6,670.27 8,982.41 8,218.59 6,012,347.41 1,536,183.46 2.62 4,272.22 MWD+IFR-AK-CAZ-SC(7) 15,200.20 78.76 356.24 6,738.30 6,689.20 9,075.52 8,214.65 6,012,440.57 1,536,180.93 2.81 4,356.98 MWD+I FR-AK-CAZ-SC(7) 15,295.87 78.91 353.88 6,756.82 6,707.72 9,169.03 8,206.57 6,012,534.18 1,536,174.26 2.43 4,443.96 MWD+IFR-AK-CAZ-SC(7) 15,390.86 80.45 349.98 6,773.85 6,724.75 9,261.53 8,193.44 6,012,626.86 1,536,162.53 4.35 4,532.34 MWD+IFR-AK-CAZ-SC(7) 15,486.39 81.01 345.81 6,789.24 6,740.14 9,353.70 8,173.67 6,012,719.30 1,536,144.16 4.35 4,623.43 MWD+I FR-AK-CAZ-SC(7) 15,581.01 82.91 342.05 6,802.48 6,753.38 9,443.70 8,147.74 6,012,809.68 1,536,119.58 4.42 4,715.40 MWD+IFR-AK-CAZSC(7) 15,677.16 83.82 338.93 6,813.59 6,764.49 9,533.71 8,115.84 6,012,900.16 1,536,089.05 3.36 4,810.08 MWD+IFR-AK-CAZ-SC(7) 15,722.29 84.25 337.06 6,818.28 6,769.18 9,575.32 8,099.03 6,012,942.02 1,536,072.87 4.23 4,854.80 MWD+I FR-AK-CAZ-SC(7) 15,757.00 84.25 337.06 6,821.76 6,772.66 9,607.13 8,085.57 6,012,974.02 1,536,059.89 0.00 4,889.24 PROJECTED to TD 2124/2015 3:47:57PM Page 6 COMPASS 5000.1 Build 65 ti OF T�� I//7. THE STATE Alaska Oil and Gas jh1- ofA L A St KA Conservation Commission tritt = _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS r" Fax: 907.276.7542 www,aogcc.alaska.gov Robert Stinson / Supervisor Drilling Engineer t 3 - (0 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord River Oil Pool, CRU CD3-130 Sundry Number: 315-104 Dear Mr. Stinson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,A1e-t4 Cathy P. oerster J Chair, Commissioner DATED this d of March, 2015 Encl. • • RECEIVED STATE OF ALASKA FEB 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program E k Suspend ❑ Plug Perforations ❑ Perforate Q • Pull Tubing❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 213-160 3.Address: Stratigraphic ❑ Service Q 6.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 50-103-20677-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.#569/ CRU CD3-130 Will planned perforations require a spacing exception? Yes ❑ No Q / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 364472, 364471, 372104, 372105 . Colville River Field/Fiord Oil Pool 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): 15,757' 6,821' • 15,082' ' 6,714' • 15090' 15,082' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 114' 114' Surface 3,317' 10-3/4" 3,354" 2,480' 5210 2470 Intermediate 14,275' 7-5/8" 14,309' 6,549' 6890 4790 Production 2,941' 6" 15,090' 6,716' 7920 6220 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 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 24-Feb-15 15.Well Status after proposed work: Commencing Operations: Oil Q - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 24-Feb-15 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Victoria Loepp GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Danny Kane Email Danny.Kane( conocophillips.com Printed Name TitleoobefTglScol Ji nov.• Fna v Signature Phone Dat ,263-yr 9 y-/S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 5- Plug Integrity ❑ BOP Test in Mechanical Integrity Test ❑ Location Clearance ❑ Other: i f fo /➢n r'5 P / z 3 cl 5 J 1 k?v1 ✓'/r,1 ! p I-e- fr t 7 te-ir 7-4-$ t- TO Z .---CC, f'S i Spacing Exception Required? Yes ❑ No17 Subsequent Form Required: /C — 4 c 7_ tP APPROVED BY Approved by: COMMISSIONER THE- COMMISSION Date:3 2 l3 R4 A glass-e d � 3�pZ�fSSubmit Form and Form 10-403( evised 10/2012) A r r n `_t��f r 12 months from the date of approval. RBDMS,� hments in Duplicate Vr-L z/z7/ice M9AR - 52015 ConocoPhillips Alaska,Inc. • • Post Office Box 100360 RECEIVED ConocoPhillips Anchorage,Alaska 99510-0360 Telephone 907-276-1215 FEB 2 4 2015 February 24th2014 HA ®GCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Sundry to Perforate&Change Approved Program for CRU CD3-130 Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Sundry Permit to Perforate&Change Approved Program for CD3-130 from an onshore Fiord Nechelik injector to an onshore Fiord Kuparuk producer. CD3-130 was planned as a horizontal injector in the Fiord Nechelik reservoir under PTD(#213-160). The 13-1/2"surface hole (CD3-130 PB 1)was drilled to 3194' MD before encountering instability&accidentally sidetracking the wellbore. After setting a cement plug to surface,the surface hole was sidetracked and redrilled to 3366' MD before running&cementing the 10-3/4" surface casing at 3353' MD. A 9-7/8"x 11"intermediate hole was drilled to 15483' MD but the 7-5/8"intermediate casing was unsuccessfully run and landed high at 14309' MD(1174' MD off-bottom)after encountering tight hole and packing off from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown(#314- 117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar and setting a cement retainer at 14167' MD,the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C&Nechelik. A 3-1/2"kill string was set at 2299'MD and Doyon 19 moved off of CD3-130 to CD3-316B. Doyon 19 returned to CD3-130 this winter ice road season to redrill the horizontal injector(Sundry#314-686). After attempting a suicide squeeze to cement the whipstock location,a whipstock was set,and a window milled in the 7-5/8" INTRMI casing(13133' MD TOW). A 6-3/4"x 7-7/8"hole was drilled to TD of 15757' MD within the Nechelik and an Enventure SET 6"Expandable Liner was picked up and run in hole. The liner run encountered tight hole but the rig was able to work the liner past the Minimum Setting Depth and ultimately 103' MD past the Kuparuk C before the decision was made to set the liner high and expand in place. Unfortunately,the rig failed to initiate liner expansion(currently investigating)and the unexpanded liner was left in the hole after safetying off the liner with the inner string. With approximately 6' of Kuparuk C gross pay(3' net)behind the liner,the decision was made to salvage the INTRM2 hole section by perforating the expandable liner and producing from the Kuparuk C via a 3-1/2"tubing completion with a production packer immediat ey above the expandable liner top within the 7-5/8"INTRM 1 casing. Please find attached the information required by 20 ACC 25.280 for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR SUNDRY APPROVAL as per 20 ACC 25.280 2. A description summary of proposal 3. Current&proposed completion diagrams If you have any questions or require further information,please contact Danny Kane at 265-6048 (danny.kaneAconocophillips.com)or Rob Stinson at 263-4449. Sincerely, cc: 41/041 CD3-130 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson • ATO 1728 Chip Alvord ATO 1570 Danny Kane Erik Nelson ATO 1786 Drilling Engineer Lanston Chin Kuukpik Corp i • CRU CD3-130 Sundry Application for Perforating&Change f Approved Program ConocoPhillips Attachment 1—Description of Events& Plan Forward History CD3-130 was planned as a horizontal injector in the Fiord Nechelik reservoir under PTD (#213-160). The 13-1/2" surface hole (CD3-130 PB1)was drilled to 3194' MD before encountering instability& accidentally sidetracking the wellbore. After setting a cement plug to surface,the surface hole was sidetracked and redrilled to 3366' MD before running&cementing the 10-3/4"surface casing at 3353' MD. A 9-7/8"x 11" intermediate hole was drilled to 15483' MD but the 7-5/8" intermediate casing was unsuccessfully run and landed high at 14309' MD (1174' MD off-bottom) after encountering tight hole and packing off from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown (#314-117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar and setting a cement retainer at 14167' MD,the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C& Nechelik. A 3-1/2" kill string was set at 2299' MD and Doyon 19 moved off of CD3-130 to CD3-316B. Doyon 19 returned to CD3-130 this winter ice road season to redrill the horizontal injector(Sundry#314- 686). After attempting a suicide squeeze to cement the whipstock location, a whipstock was set, and a window milled in the 7-5/8" INTRM1 casing (13133' MD TOW). A 6-3/4"x 7-7/8" hole was drilled to TD of 15757' MD within the Nechelik and an Enventure SET 6" Expandable Liner was picked up and run in hole. The liner run encountered tight hole but the rig was able to work the liner past the Minimum Setting Depth and ultimately 103' MD past the Kuparuk C before the decision was made to set the liner high and expand in place. Unfortunately,the rig failed to initiate liner expansion (currently investigating) and the unexpanded liner was left in the hole after safetying off the the inner string from the liner launcher. Proposed Plan Forward &Operations Summary ConocoPhillips Alaska's plan-forward is to complete CD3-130 as a Fiord Kuparuk C Producer by perforating the unexpanded liner at the Kuparuk C and installing a 3-1/2" production tubing string from surface to a production packer set within the 7-5/8" immediately above the liner top. Changes in the Drilling Program: • Upper Completion Change (Dropped Lower Completion) o 3-1/2" 9.3#L-80 EUE-8rd Tubing String • Camco TRMAXX-5E SSSV • 3x Camco GLM o 7-5/8" x 3-1/2" Baker FHL Packer • 2.813" XN Nipple • Baker Auto-Entry Shoe • Perforate 6" 20.1#EX-80 SET at Kuparuk C Page 1 of 3 • • CRU CD3-130 Sundry Application for Perforating&Change Approved Program ConocoPhillips Attachment 1—Description of Events& Plan Forward Overview of Pre-Rig& Rig Operations Rig Work(Doyon 19) 1. L/D 4" Drill Pipe 2. M/U &TIH w/3-1/2" Production Tubing String 3. Drop Ball & Rod 4. Set Baker FHL Packer, Release Sealbore from PBR 5. Space Out&Spot KW Brine 6. Pressure Test Annulus to 1000psi 7. OWFF 30min 8. Pressure Test Tubing to 3500psi 9. Bleed Tubing to 2000psi, Pressure Test IA to 3500psi 10. Bleed Tubing to Shear SOV in Lower GLM, Bleed Tubing& IA 11. Install 2-Way Check& Pressure Test Upper Hanger Seals (250/5000psi) 12. Pressure Test 2-Way Check in Direction of Flow By Pressuring Up on IA to 3000psi 13. Bleed Off Annulus 14. OWFF 30min 15. N/D BOPE, N/U Tree 16. Pressure Up Tubing Hanger x Adapter to 5000psi to Test Lower& Upper Hanger Seals 17. Pressure Test 2-Way Check Valve 250/5000psi 18. R/U FMC Lubricator& Pull 2-Way Check Valve 19. Freeze Protect Tubing x IA 20. Secure Well & Prepare Rig to Move-Off CD3-130 Post-Rig Work 1. R/U E-Line w/Tractor Services 2. Pull Ball & Rod 3. Pull SOV&GLM Dummies 4. Install Gas Lift System 5. Pull RHC Plug Body 6. Perforate Kuparuk C from —14984'—15012' MD 7. R/D E-Line w/Tractor Services 8. R/U & Flow Back w/Expro if Needed 9. Complete Facilities Work& Bring on Production Page 2 of 3 • • CRU CD3-130 Sundry Application for Perforating&Change Approved Program ConocoPhillips Attachment 1—Description of Events& Plan Forward Summary for Verbal Approval of Kuparuk C Completion: As we discussed, our final setting depth of the expandable liner was 15,090'MD. This was a minimum set depth that was selected in the event that getting the liner to the planned set point of 15618'MD was problematic, which it proved to be. This set depth allowed two things: 1. It covered the Kuparuk Interval(a 6'gross,3'net pay section)at 14987'MD. 2. It cleared liner centralizers out of the 7 5/8"casing to allow expansion, and was deep enough to allow drilling to the originally planned Nechelik target. Over the weekend,per the plan, we pumped cement prior to expansion. As we discussed, we were not able to circulate the job around the liner. We were able to squeeze the 47 barrel job away at 2 bpm, with some indication of initial lift,but most likely squeezing away right at the shoe depth above the Nechelik and below the Kuparuk intervals. The pumping pressures indicated that the job did not pump into either sand interval. When we attempted to expand the liner, we could not initiate expansion after several attempts,and the expansion tool failed at a pressure of 6800 psi. We were then able to successfully release off of the liner using the emergency back-off contingency,circulate freely and pull out the 4"inner string without issue. We were planning on abandoning the lower section for a future slot recovery and sidetrack. As discussed, we were challenged by the asset to complete the well above the liner top and perforate the Kuparuk. After discussing options, we presented to you our completion plan with the following points of isolation,knowing that our cement jobs were squeezed away at points in the well without circulation: We have cement verified with a log in the 7 5/8"by 11"hole from 6911'MD to 5209'MD above the Qannik. We have isolation below the Qannik verified by our inability to establish a circulation between perforations at 13,105'-13,110'MD and 13,193'-13,198'MD. Cement was squeezed into the lowest set of perforations prior to sidetracking. _ On the sidetrack,our managed pressure drilling operations never indicated communication with the Qannik above us. The isolation provided by the pack-off around the 75/8"casing will isolate this annulus from any pressure at the unsealed and unexpanded liner top. A packer will be set at the base of the production tubing to isolate the un sealed liner top from the surface. The Liner ID is 5.34"ID and will accept a 3 'z"entry guide to the tubing. Our intent is to produce the well as a Kuparuk producer. We will follow with proper Sundry application,but request a verbal approval to move forward with the completion. Page 3 of 3 Colville River Field — R3-130 Kuparuk C Proder (Fiord Oil Pool) • Proposed Completion Updated: 24-Feb-2015 Upper Completion MD ND 20"Conductor to 80' \ / 1)Tubing Hanger 21' 21' 2)4-W 12.6#/ft IBT-Mod Tubing(2 jts), 80' 80' Freeze protect to+/-1500'TVD 3) XO 4-W 12.6#IBT-M x 3-'/z"9.3#EUE-8rd-M L-80 4)Camco TRMAXX-5E nipple w/2.812"ID X Profile (47.2°) 2266' 2000' with control line to surface. Cannon Cross-coupling clamps on every joint 5) 3-''/"X 1"Camco KBMG GLM w/Dv (67.2°) 4671' 3000' 10-3/4"45.5#L-80 BTC-M 6) 3-W X 1"Camco KBMG GLM w/Dv (70) 8454' 4500' A Ir Surface Casing 7)3-W X 1"Camco KBMG GLM w/DCK2 (72.6°) 11655' 5700' @ 3353'MD/2481 TVD cemented to surface Pinned for 2500 psi casing to tbg shear 8)3'/2"Baker FHL Packer with PBR 12120' 5845' . 9)2.813"XN Profile with 2.75"Lock profile(72.7°) 12130' 5848' 10)Baker Auto-Entry shoe 12150' 5851' - Estimated TOC-5209'MD Kuparuk C(2015 Logs) iMPuiser'I RT Uncorrected Attenuelwn Resnlmty len 34*d 0 C O Top HES Stage Collar X502 r9ai2A0i2( trkc)OAWHa{ii23 < r,ku w`,,,R u' • 6911'MD/3892'ND Unnom3oed Powe shin Roust.y to%nen Bunt Norm Catrecn 1 Bottom(0 nik ,-„RT 9peane 021/Hz tPRIOUNCi iMPOz4ll RM ADNil RM .0 o'm"20002 °nmm 290.025 S0mx3 025 Cenr4y Caliper.Ate*ape iCCAV;ADN(1I RT Tol Stock 4 m 9 1..0 iFw w '•Paase WI ftes,c -,,t e.3,s61 Thermal Nnueat Po osAT(Reno UMW n Top Qannik ., A 40IR+ '"at 3:PIZ iP343•:3344:3i*P3313-e,0*2 Selected i.RMlw+(Te0'H/Ad1iI R+A 7485'MD/4119'TVD c. 442 .__ 0,0000 393 0 f ie '- 'moo j A30 I+Alc :_ � 1: 11"Underreamer -� seNe9, j -- — Malfunctioned Trip Out i rtvd R�►1 r DRHe 310 ( lig J Uncertain Closing Depth _ 1 - i� cilCAV 9HKR91< �-• R i •I •I 1 I ' ' I ... 6"Unexpanded Liner Top: \ '', 12, ' , 'ND (Tapered 148MD/5Entry851Guide) Upper Perfs ;13,105-13110'MD A , \ ' ' Ciro✓/n.fj„.. Baker G2 XL --- HRZ Slumped Top TOW 13133'MD - - 13679'MD/6325'TVD HRZ Top Length 17' 13970'MD/6415'TVD DLS 8.4°/100 ft �-�-. HRZ Base Cement Retainer 14510'MD/6565'TVD 13160'-13168'MD Z n, (Attempted Suicide Kuparuk C 14987 MD/6692'TVD Squeeze btw Perfs, Of/ �� No Communication) /, r, Lower Perfs s‘ iritiMEE W.1!?:'::::::„....„ '''-,, .... Nechelik 15507'MD/6791'TVD 13193 13198'MD // -----;;;;;Iiiiiii iiiIiiinilill-ililli-l:'''' ''' ''''''''' . T 7-7/8"INTRM2 TD TopIBP Fish 13260'MD 1 1 'MD/6805'TVD 568 60 `�is Wireline Bridge Plug 5 MI i 18.'T )'i`:i Middle of Mandrel 13272'MD` 1 6-3/4"INTRM2 Pilot Hole TD ::::::: ::::::::: ::::: ::::: :::::::::::::::: :::::::::::: ::::::::::::::::.: ::/ 15757 MD/6820'TVD 2014 Cement Retainer Set , 14167'MD/6506'TVD ""f 6"Unexpanded Liner Shoe 2014 7-5/8"29.7#L-80 BTC-M Casing 15090'MD/6715'ND Pre-expansion: 6.0"OD/5.34"ID/20.1#EX-80 14,309.29'MD/6,549'TVD Connection ID:5.278",Drift 5.215" • • RECEIVED STATE OF ALASKA 7B 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A®GrC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redril! ❑ Perforate New Pool ❑ Repair Well E Change Approved Program Q Suspend ❑ Plug Perforations ❑ Perforate Q Pull Tubing❑ Time Extension ❑ Operations Shutdown I Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ her: ❑ 2.Operator Name: 4.Current Well Class: 5:Permitto Drill Number: ConocoPhillips Alaska,Inc. ,i Exploratory ❑ Development ❑ 13-160 v / 3.Address: n 6.API Number: Stratigraphic Service 7. ; P.O.Box 100360,Anchorage,AK 99510-0360 50-103-20677-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.#569 , CRU CD3-130 , Will planned perforations require a spacing exception? Yes ❑I No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 364472, 364471, 372104, 372105- / Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY lir Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth j; : Plugs(measured): Junk(measured): 15,757' 6,821' 15,082' 6,714' 4,/ 15090' 15,082' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 114' 114' Surface 3,317' 10-3/4" 3,354" ! 2,480' 5210 2470 Intermediate 14,275' 7-5/8" 14,309' ( 6,549' 6890 4790 Production 2,941' 6" 15,090' 6,716' 7920 6220 i Liner q\ Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Sizgwfi`/ \ Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal 13.Well Class after proposed work: Detailed Operations Program L, BOP Sketch I ^� Exploratory ❑ Stratigraphic H Development H Service ❑ , 14.Estimated Date for V 24-Feb-15 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 24-Feb-15 WINJ ❑, GINJ E WAG ❑ Abandoned E Commission Representative: Victoria Loepp GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Danny Kane Email Danny.Kaneconoco hillips.com Printed Namer r Title !f1I .Ft citir e l .) r. X1't ,. , , . , .n ilns ee~ Signature Phone Data " ..26', r-"Y 7 2 ._ -_,/f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ P Test ❑ Mechanical Integrity Test E Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: @rR1 Submit Form and Form 10-403(Revised 10/2012) fP a1ic1 j vAl r.:12 months from the date of approval. Attachments in Duplicate • S ConocoPhillips Alaska,Inc. RECEIVED Post ECE1VPost Office Box 10 99 0 Anchorage,Alaska 99510-0360 ConocoPhillips FEB 2 4 2015 Telephone 907-276-1215 February 24t,2014 AOGCC Alaska Oil and Gas Conservation Commission v 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Sundry to Perforate&Change Approved Program for CRU CD3-130 Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Sundry Permit to Perforate&Change Approved Program for CD3-130 from an onshore Fiord Nechelik injector to an onshore Fiord Kuparuk producer. CD3-130 was planned as a horizontal injector in the Fiord Nechelik reservoir under PTD(#213-160). The 13-1/2"surface hole (CD3-130 PB 1)was drilled to 3194'MD before encountering instability&accidentally sidetracking the wellbore. After setting a cement plug to surface,the surface hole was sidetracked and redrilled to 3366' MD before running&cementing the 10-3/4" surface casing at 3353'MD. A 9-7/8"x 11"intermediate hole was drilled to 15483'MD but the 7-5/8"intermediate casing was unsuccessfully run and landed high at 14309'MD(1174'MD off-bottom)after encountering tight hole and packing off from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown(#314- 117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar and setting a cement retainer at 14167' MD,the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C&Nechelik. A 3-1/2"kill string was set at 2299' MD and Doyon 19 moved off of CD3-130 to CD3-316B. Doyon 19 returned to CD3-130 this winter ice road season to redrill the horizontal injector(Sundry#314-686). After attempting a suicide squeeze to cement the whipstock location,a whipstock was set,and a window milled in the 7-5/8" INTRM1 casing(13133' MD TOW). A 6-3/4"x 7-7/8"hole was drilled to TD of 15757'MD within the Nechelik and an Enventure SET 6"Expandable Liner was picked up and run in hole. The liner run encountered tight hole but the rig was able to work the liner past the Minimum Setting Depth and ultimately 103'MD past the Kuparuk C before the decision was made to set the liner high and expand in place. Unfortunately,the rig failed to initiate liner expansion(currently investigating)and the unexpanded liner was left in the hole after safetying off the liner with the inner string. With approximately 6'of Kuparuk C gross pay(3'net)behind the liner,the decision was made to salvage the INTRM2 hole section by perforating the expandable liner and producing from the Kuparuk C via a 3-1/2"tubing completion with a production packer immediatley above the expandable liner top within the 7-5/8"INTRM1 casing. Please find attached the information required by 20 ACC 25.280 for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR SUNDRY APPROVAL as per 20 ACC 25.280 2. A description summary of proposal 3. Current&proposed completion diagrams If you have any questions or require further information,please contact Danny Kane at 265-6048 (dannv.kane(a�conocophillips.com)or Rob Stinson at 263-4449. Sincerely, cc: CD3-130 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1728 Chip Alvord ATO 1570 Danny Kane Erik Nelson ATO 1786 Drilling Engineer Lanston Chin Kuukpik Corp • • CRU CD3-130 Sundry Application for Perforating&Change Approved Program ConocoPhillips Attachment 1 —Description of Events& Plan Forward History CD3-130 was planned as a horizontal injector in the Fiord Nechelik reservoir under PTD (#213-160). The 13-1/2"surface hole (CD3-130 PB1)was drilled to 3194' MD before encountering instability& accidentally sidetracking the wellbore. After setting a cement plug to surface,the surface hole was sidetracked and redrilled to 3366' MD before running&cementing the 10-3/4"surface casing at 3353' MD. A 9-7/8"x 11" intermediate hole was drilled to 15483' MD but the 7-5/8" intermediate casing was unsuccessfully run and landed high at 14309' MD (1174' MD off-bottom) after encountering tight hole and packing off from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown (#314-117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar and setting a cement retainer at 14167' MD,the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C& Nechelik. A 3-1/2" kill string was set at 2299' MD and Doyon 19 moved off of CD3-130 to CD3-316B. Doyon 19 returned to CD3-130 this winter ice road season to redrill the horizontal injector(Sundry#314- 686). After attempting a suicide squeeze to cement the whipstock location, a whipstock was set, and a window milled in the 7-5/8" INTRM1 casing (13133' MD TOW). A 6-3/4" x 7-7/8" hole was drilled to TD of 15757' MD within the Nechelik and an Enventure SET 6" Expandable Liner was picked up and run in hole. The liner run encountered tight hole but the rig was able to work the liner past the Minimum Setting Depth and ultimately 103' MD past the Kuparuk C before the decision was made to set the liner high and expand in place. Unfortunately,the rig failed to initiate liner expansion (currently investigating) and the unexpanded liner was left in the hole after safetying off the the inner string from the liner launcher. Proposed Plan Forward &Operations Summary ConocoPhillips Alaska's plan-forward is to complete CD3-130 as a Fiord Kuparuk C Producer by perforating the unexpanded liner at the Kuparuk C and installing a 3-1/2" production tubing string from surface to a production packer set within the 7-5/8" immediately above the liner top. Changes in the Drilling Program: • Upper Completion Change (Dropped Lower Completion) o 3-1/2" 9.3#L-80 EUE-8rd Tubing String ■ Camco TRMAXX-5E SSSV ■ 3x Camco GLM o 7-5/8" x 3-1/2" Baker FHL Packer ■ 2.813"XN Nipple ■ Baker Auto-Entry Shoe • Perforate 6" 20.1# EX-80 SET at Kuparuk C Page 1 of 3 • • CRU CD3-130 Sundry Application for Perforating&Change Approved Program ConocoPhillips Attachment 1—Description of Events& Plan Forward Overview of Pre-Rig& Rig Operations Rig Work(Doyon 19) 1. L/D 4" Drill Pipe 2. M/U &TIH w/3-1/2" Production Tubing String 3. Drop Ball & Rod 4. Set Baker FHL Packer, Release Sealbore from PBR 5. Space Out&Spot KW Brine 6. Pressure Test Annulus to 1000psi 7. OWFF 30min 8. Pressure Test Tubing to 3500psi 9. Bleed Tubing to 2000psi, Pressure Test IA to 3500psi 10. Bleed Tubing to Shear SOV in Lower GLM, Bleed Tubing& IA 11. Install 2-Way Check& Pressure Test Upper Hanger Seals (250/5000psi) 12. Pressure Test 2-Way Check in Direction of Flow By Pressuring Up on IA to 3000psi 13. Bleed Off Annulus 14. OWFF 30min 15. N/D BOPE, N/U Tree 16. Pressure Up Tubing Hanger x Adapter to 5000psi to Test Lower& Upper Hanger Seals 17. Pressure Test 2-Way Check Valve 250/5000psi 18. R/U FMC Lubricator& Pull 2-Way Check Valve 19. Freeze Protect Tubing x IA 20. Secure Well & Prepare Rig to Move-Off CD3-130 Post-Rig Work 1. R/U E-Line w/Tractor Services 2. Pull Ball & Rod 3. Pull SOV&GLM Dummies 4. Install Gas Lift System 5. Pull RHC Plug Body 6. Perforate Kuparuk C from "14984'—15012' MD 7. R/D E-Line w/Tractor Services 8. R/U & Flow Back w/Expro if Needed 9. Complete Facilities Work& Bring on Production Page 2 of 3 • • CRU CD3-130 Sundry Application for Perforating&Change Approved Program ConocoPhillips Attachment 1—Description of Events& Plan Forward Summary for Verbal Approval of Kuparuk C Completion: As we discussed, our final setting depth of the expandable liner was 15,090'MD. This was a minimum set depth that was selected in the event that getting the liner to the planned set point of 15618'MD was problematic, which it proved to be. This set depth allowed two things: 1. It covered the Kuparuk Interval(a 6'gross,3'net pay section)at 14987'MD. 2. It cleared liner centralizers out of the 7 5/8"casing to allow expansion, and was deep enough to allow drilling to the originally planned Nechelik target. Over the weekend,per the plan, we pumped cement prior to expansion. As we discussed, we were not able to circulate the job around the liner. We were able to squeeze the 47 barrel job away at 2 bpm, with some indication of initial lift,but most likely squeezing away right at the shoe depth above the Nechelik and below the Kuparuk intervals. The pumping pressures indicated that the job did not pump into either sand interval. When we attempted to expand the liner, we could not initiate expansion after several attempts, and the expansion tool failed at a pressure of 6800 psi. We were then able to successfully release off of the liner using the emergency back-off contingency,circulate freely and pull out the 4"inner string without issue. We were planning on abandoning the lower section for a future slot recovery and sidetrack. As discussed, we were challenged by the asset to complete the well above the liner top and perforate the Kuparuk. After discussing options, we presented to you our completion plan with the following points of isolation,knowing that our cement jobs were squeezed away at points in the well without circulation: We have cement verified with a log in the 7 5/8"by 11"hole from 6911'MD to 5209'MD above the Qannik. We have isolation below the Qannik verified by our inability to establish a circulation between perforations at 13,105'-13,110'MD and 13,193'-13,198'MD. Cement was squeezed into the lowest set of perforations prior to sidetracking. On the sidetrack, our managed pressure drilling operations never indicated communication with the Qannik above us. The isolation provided by the pack-off around the 7 5/8"casing will isolate this annulus from any pressure at the unsealed and unexpanded liner top. A packer will be set at the base of the production tubing to isolate the un sealed liner top from the surface. The Liner ID is 5.34"ID and will accept a 3 'z"entry guide to the tubing. Our intent is to produce the well as a Kuparuk producer. We will follow with proper Sundry application,but request a verbal approval to move forward with the completion. Page 3 of 3 e Colville River Field — c3-130 Kuparuk C Produ!er (Fiord Oil p Pool) Proposed Completion Updated: 24-Feb-2015 A , 20"Conductor to 80' Upper Completion MD TVD 1)Tubing Hanger 21' 21' 2)4-%"12.6#/ft IBT-Mod Tubing(2 jts), 80' 80' .40 Freeze protect to+/-1500'TVD 3) XO 4-W 12.6#IBT-M x 3-'W 9.3#EUE-8rd-M L-80 4)Camco TRMAXX-5E nipple w/2.812"ID X Profile (47.2°) 2266' 2000' with control line to surface. Cannon Cross-coupling clamps on every joint 5) 3-'/2'X 1"Camco KBMG GLM w/Dv (67.2°) 4671' 3000' 10-3/4"45.5#L-80 BTC-M 6) 3-W X 1"Camco KBMG GLM w/Dv (70) 8454' 4500' 4 Surface Casing @ 3353'MD/2481 TVD 7)3-W X 1"Camco KBMG GLM w/DCK2 (72.6°) 11655' 5700' cemented to surface Pinned for 2500 psi casing to tbg shear 8)3-'/2"Baker FHL Packer with PBR 12120' 5845' 9)2.813"XN Profile with 2.75"Lock profile(72.7°) 12130' 5848' 10)Baker Auto-Entry shoe 12150' 5851' Estimated TOC-5209'MD Kuparuk C(2015 Logs) C O IfdPu+se(+1 RT Uncorrected b ttenualan Res�xmt9 kv 3a,rd' Top HES Stage Collar ° s a300000 2 ��R��e„R m � tl _ 1(1 6911'MD/3892'TVD Speed iR?sA;Udm ted PAnad Sh t Rename,for 16 e+ch Buk Density Caroraat..&man IORHBI RT Syec2g042MHz PP#6H-Ut lNP+tMtI ROA ADPC)RN .. •.,. 0.2 Orem 200.025 4an3 025 ,. ,� a ed Phase'S`SM Ruasrco34 fir 34 tack Thermal Neutron Pocady!Rain mance Top Qannik :,,, at 2 MHz 009.04_2NCt tAP43413 RM Selected Udsiemz(TNPH)ADM11RA1 7485'MD/4119'TVD 402 . 0.0 0:3413 0 5 ides .4_ e .21%,UNC b4.e /tv4T.34,H UNG f �� `�.•: ',� 11"Underreamer 3 o ' ' Malfunctioned Trip Out RN :OR16 Uncertain Closing Depth z3)cAv s RSK' i K i c i ) A 6"Unexpanded Liner Top: 12,148'MD/5,851'TVD \\,,,, \ \ (Tapered Entry Guide) Upper Perfs 13105-13110'MD Baker G2 XL HRZ Slumped Top TOW 13133'MD 13679'MD/6325'TVD Length 17' HRZ Top g 13970'MD/6415'TVD DLS 8.4°/100 ft Cement Retainer', HRZ Base 14510'MD/6565'TVD 13160'-13168'MD — _ (Attempted Suicide ',, Kuparuk C 14987 MD/6692'TVD Squeeze btw Perfs, No Communication) /� Lower Perfs I 13193-13198'MD �� Necr euk!scot MD/s7sr TVD Top IBP Fish 13260'MD 7-7/8"INTRM2 TD CD3 130 PB2 15618'MD/6805'TVD Wireline Bridge Plug 4 5483 MD:f&818.T1lD / 1 Middle of Mandrel 13272'MD 1 6-3/4"INTRM2 Pilot Hole TD _ "'% 1575T MD/6820'TVD 2014 Cement Retainer Set j 14167'MD/6506'TVD ""ii 6"Unexpanded Liner Shoe 2014 7-5/8"29.7#L-80 BTC-M Casing 15090'MD/6715'TVD Pre-expansion: 6.0"OD/5.34"ID/20.1#EX-80 14,309.29'MD/6,549'TVD Connection ID:5.278",Drift 5.215" • CP-G✓ CO3-j30 Z(31660 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, February 18, 2015 10:52 AM 2e� To: 'Hobbs, Greg S'; Stinson, Rob D; Kane, Danny Cc: Herbert, Frederick 0; Loepp, Victoria T (DOA); 'AOGCC.Inspectors@alaska.gov' Subject: RE: CD3-130 Operations Update CRU CD3-130 (PTD 2131600) Thank you for coming in to discuss the challenging circumstances in getting the expandable liner to depth in CD3- 130. As discussed, I am granting an indefinite extension to the BOPE test (due today) on Doyon 19 to enable you to get the liner run to its planned setting depth, cemented and expanded. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Wednesday, February 18, 2015 8:28 AM To: Regg, James B (DOA); Loepp, Victoria T (DOA) Cc: Kane, Danny; Stinson, Rob D; Herbert, Frederick 0 Subject: CD3-130 Operations Update Good Morning Jim and Victoria- Through the night, the rig was able to work the liner through 14,835', and then experienced packing off. After circulating out the pack-offs, we have been able to work our way to 14,845'. The pipe is still free to the depths we have worked to, and we have entered into the Kuparuk D,just passing through what has historically been a troublesome formation transition. Danny, Rob, Fred and Myself will see you at 10 o'clock with more information on the run and our thoughts on what could be ahead of us. Thank-you! Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W: (907)263-4749 C:(907)231-0515 1 Q • • N4 th a) O111 K inmco 1•1') N 4 OCU 04. •mil ‘ I It) L.L. , . Immo 1 mom N. 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'1111 ,41, ,; li . f . . i r ,FgfP C1 � ' nom ' J•i i ,•4 { . f{p o- "'!!! �!1 h: iia' * # 'q k ''4:4.1...i'44-4:' * l 4 I°- , , -:',f, + , '.4.1/4---_-74,.., .., .--'---,4,-.-, -,—, , --- — --------- -- -- -- - °,,,iiiii,,‘ .,..1 le 6, 1,-W ,.,..«, IIIIIIMIlli a � -�wbgYC e A fi4 iIIIc:: !;!! "V 1.... • a i ., . . . I ..v • rte w •i-�-i `r ,21, ,1. f 1 • Pro 2.13-11,0 Loepp, Victoria T (DOA) From: Hobbs,Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, February 16, 2015 11:22 AM To: Loepp,Victoria T(DOA) Cc: Kane, Danny Subject: CD3-130 Weekend Update- Follow Up Flag: Follow up Flag Status: Flagged Victoria- I know you are out today, but I wanted to give you an update of the CD3-130 well project. We are still slowly washing and working our liner to bottom. We are currently at 14750'with a planned setting depth of 15618'. We are making slow progress and,while not hugely optimistic,are in hopes of getting it to TD. Greg Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W:(907)263-4749 C:(907)231-0515 1 Loepp. Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Monday, February 16,2015 10:20 AM To: Loepp,Victoria T(DOA) Subject: FW:ConocoPhillips Well:CD3-130 Production Hole FIT Follow Up Flag: Follow up Flag Status: Flagged Victoria, I received your voicemail from Friday pertaining to CD3-130 FIT. I know you are likely OOTO for the holiday today but as an update, due to recent operational issues and the high potential we will not get the liner to an acceptable TD,the previous request is no longer an issue. Currently we are' 1000ft MD high of the planned TD. Danny Kane will be in touch when we get a definitive answer on the plan forward for more information. -Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earharti conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 From: Earhart, Will C Sent: Wednesday, February 11, 2015 5:32 PM To: victoria.ferguson(aalaska.gov Cc: Stinson, Rob D; Kane, Danny; Hobbs, Greg S Subject: ConocoPhillips Well: CD3-130 Production Hole FIT PTD:214-018 API:50-103-20559-03-00 Victoria, We are looking for some guidance on where we need to conduct the FIT when drilling out with the production drilling BHA on CD3-130.As you may recall,we are deploying an expandable liner for the lower intermediate casing. Given the reamer location in the previous BHA and the anticipated axial contraction that the liner will undergo during the expansion process,we will likely be left with—139ft of rathole below the Intermediate 2 casing shoe.As the regulations require an FIT/LOT between 20-50ft of the new formation drilled,that would put us>150ft away from the previous shoe at the time of the FIT. I would like to conduct the FIT after drilling 30ft beyond the previous casing shoe.This would be a safer point to conduct the FIT and would better facilitate any remedial cementing operations if needed rather than have>150ft of rathole exposed.Technically this is still within the previous rathole section however it is highly likely that the bit will not track the rathole precisely and will have some formation exposed by that point. 1 • • We encountered a similar issue when utilizing the steerable-drilling-liner technology last year on CD4-96 and used the same approach for the FIT. I'm filling in covering the operations for Danny Kane for a few days as he is away from the office becoming a dad. Please let me know if you have any questions or concerns.Sorry if he has already covered this with you before. We are anticipating beingready to drill out and conduct the FIT Tuesday, February17th if allgoes to plan. Thanks, Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earharaconocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 2 • pT7J 2/ 3 - 14' o Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Friday, February 13,2015 2:39 PM To: Loepp,Victoria T(DOA) Cc: Kane, Danny;Stinson, Rob D Subject: FW:CD3-130 Preparation for Slot Recovery Victoria- Up to 11:30 p.m. last night,operations on the CD3-130 well were progressing per plan. At that point,the run of the expandable liner met resistance that required establishing circulation to wash the liner in the hole. To this point,we have washed to 14,510' MD with a planned set depth of 15,618' MD. There is 1108'of open hole below us. In the event we decide to abandon the liner run,our plan is: Emergency off of the 6"OD liner leaving its top at 11,800' MD. Trip out of the hole. Run in hole and set a cement retainer at the top of the liner. Attempt to establish injection below the retainer. If injection is successful: Pump 153 bbl of cement into the liner to cover the open hole and liner volumes below the retainer. Place 9 bbl of cement above the retainer for 200'of cement above the retainer and a top of cement at 11,600'. If injection is not successful: Place 50 bbl of cement above the retainer for approximately 1100'of a cement plug above the retainer and a TOC of 10,670'. In either case,we would trip out of the hole to surface,finish waiting on cement if necessary,and test the casing to 3500 psi. After a successful pressure test,we would set a plug at approximately 4,000'for suspension of the slot or immediate slot recovery operations after the failure of the current liner operations. Should we not be able to emergency release from the liner,we would cut drillpipe,set a retainer above the cut point and proceed with the above steps. We will follow approval of these operations with the required sundries and supporting documents should we need to proceed with them. Thank-you! Greg 1 • S Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Thursday, February 19, 2015 10:53 AM To: Regg,James B (DOA); Loepp,Victoria T(DOA) Cc: Stinson, Rob D; Kane, Danny; Herbert, Frederick 0; Doyon 19 Company Man Subject: CD3-130 Update Attachments: CD3-130 BOPs.pdf Follow Up Flag: Follow up Flag Status: Flagged Jim and Victoria- As of this morning,we have made 100 more feet with the liner assembly(far better than earlier days)and are currently at 14,963'with the liner shoe. The wellbore is still behaving,and we feel that the current mechanism of hold-up is the wear sox centralizers hanging up in the hole above us. We are almost to the Kuparuk C(14,897'),then will enter the Kingak Shale. Attached,also please find the schematic from the rig of the current BOP configuration. Do not hesitate to contact me if you have any further questions. Thank-you! Greg Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W:(907)263-4749 C:(907)231-0515 8 • • Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Friday, February 20, 2015 8:22 AM To: Regg,James B (DOA); Loepp,Victoria T(DOA) Cc: Stinson, Rob D; Herbert, Frederick 0; Kane, Danny; Doyon 19 Company Man Subject: CD3-130 updateA Follow Up Flag: Follow up Flag Status: Flagged Jim and Victoria, As of this morning,we have worked the liner to 15062'. We are working toward our planned set depth of 15618' md. The hole conditions are continuing to be favorable. Do not hesitate to contact me if you need any information or have any questions. Thank-you! Greg Sent from my iPhone • • Loepp. Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Saturday, February 21, 2015 11:23 PM To: Regg,James B (DOA); Loepp,Victoria T(DOA) Cc: Doyon 19 Company Man;Stinson, Rob D; Hobbs, Greg S Subject: CD3-130 - Expandable Liner Update Attachments: FW:CD3-130 Preparation for Slot Recovery Follow Up Flag: Follow up Flag Status: Flagged Jim &Victoria, Over the past 24hours with the liner at 15090' MD we were able to stage circulation to 3.25bpm before we packed the liner off trying to stage to 3.5bpm. After freeing the liner and trying to unsuccessfully regain circulation>1bpm,we established injection and decided to bullhead our primary cement job as there was the reason to believe we could still lift cement above the liner. We successfully pumped our cement job but were unable to initiate expansion after rupturing the liner launcher(tentative assessment). I will provide schematics tomorrow with more information, but the liner(pre-expansion) is stuck as follows: • 12,148' MD—6" (Pre-Expansion OD) Liner Top • 13,133' MD—TOW in 7-5/8" 29.7#L-80 BTC-M • 13,150' MD—BOW • 14,987' MD—Top Kuparuk C • 15,090' MD—Liner Launcher Shoe • 15,507' MD—Top Nechelik • 15,757' MD—INTRM2 TD We are currently attempting to safety-off our inner string from the liner launcher. Our immediate plan forward is to spotting trip-margin mud wei ht and circulate& safety-off the liner,attempt to wash out to above the liner top sp gweight, condition our drilling mud. After confirming that the well is dead,we intend to trip out to the point that we can safely test our BOPE and after a successful test,finish laying-down the inner string. We are still confirming our plan forward after this point, but we will most likely abandon this hole section in a similar fashion as outlined in an earlier email to Victoria (attached,from when we thought we wouldn't be able to work the liner down to a point we could expand). I will be in touch over the next couple days to ensure that we satisfy AOGCC requirements for the plan forward we decide to proceed ahead with. Regards, - Danny Danny Kane Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 6 O Loepp, Victoria T (DOA) From: Hobbs,Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, February 23, 2015 3:33 PM To: Loepp,Victoria T(DOA) Cc: Kane, Danny; Stinson, Rob D Subject: CD3-130 Kuparuk Completion Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank-you for the time and the discussion of the CD3-130 well project this afternoon. As we discussed,our final setting depth of the expandable liner was 15,090' MD. This was a minimum set depth that was selected in the event that getting the liner to the planned set point of 15618' MD was problematic,which it proved to be. This set depth allowed two things: 1. It covered the Kuparuk Interval (a 6'gross, 3' net pay section)at 14987' MD. 2. It cleared liner centralizers out of the 7 5/8"casing to allow expansion,and was deep enough to allow drilling to the originally planned Nechelik target. notablecirculate prior to expansion. As we discussed, to Over the weekend, per the plan,we pumped cement p o pans we were the job around the liner. We were able to squeeze the 47 barrel job away at 2 bpm,with some indication of initial lift, but most likely squeezing away right at the shoe depth above the Nechelik and below the Kuparuk intervals. The pumping pressures indicated that the job did not pump into either sand interval. When we attempted to expand the liner,we could not initiate expansion after several attempts,and the expansion tool failed at a pressure of 6800 psi. We were then able to successfully release off of the liner using the emergency back-off contingency,circulate freely and pull out the 4" inner string without issue. We were planning on abandoning the lower section for a future slot recovery and sidetrack. As discussed,we were challenged by the asset to complete the well above the liner top and perforate the Kuparuk. After discussing options,we presented to you our completion plan with the following points of isolation, knowing that our cement jobs were squeezed away at points in the well without circulation: We have cement verified with a log in the 7 5/8" by 11" hole from 6911' MD to 5209' MD above the Qannik. We have isolation below the Qannik verified by our inability to establish a circulation between perforations at 13,105'- 13,110' MD and 13,193'-13,198' MD. Cement was squeezed into the lowest set of perforations prior to sidetracking. 4 On the sidetrack,our managed pressure drilling operations never indicated communication with the Qannik above us. The isolation provided by the pack-off around the 7 5/8"casing will isolate this annulus from any pressure at the unsealed and unexpanded liner top. A packer will be set at the base of the production tubing to isolate the un sealed liner top from the surface. The Liner ID is 5.34" ID and will accept a 3 1/2" entry guide to the tubing. Our intent is to produce the well as a Kuparuk producer. We will follow with proper Sundry application, but request a verbal approval to move forward with the completion. Thank-you! Greg Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W:(907)263-4749 C:(907)231-0515 5 Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Tuesday, February 24,2015 7:23 AM To: Loepp,Victoria T(DOA) Cc: Kane, Danny;Stinson, Rob D Subject: RE:CD3-130 Kuparuk Completion Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank-you. We will follow with required applications for the change in well service and completion today- Greg From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent: Tuesday, February 24, 2015 6:58 AM To: Hobbs, Greg S Subject: [EXTERNAL]RE: CD3-130 Kuparuk Completion Greg, Verbal approval is granted to proceed as discussed in our meeting and outlined below. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp ..alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Monday, February 23, 2015 3:33 PM To: Loepp, Victoria T(DOA) Cc: Kane, Danny; Stinson, Rob D Subject: CD3-130 Kuparuk Completion Victoria, 1 i S Thank-you for the time and the discussion of the CD3-130 well project this afternoon. As we discussed,our final setting depth of the expandable liner was 15,090' MD. This was a minimum set depth that was selected in the event that getting the liner to the planned set point of 15618' MD was problematic,which it proved to be. This set depth allowed two things: 1. It covered the Kuparuk Interval (a 6'gross,3' net pay section)at 14987' MD. 2. It cleared liner centralizers out of the 7 5/8"casing to allow expansion,and was deep enough to allow drilling to the originally planned Nechelik target. Over the weekend, per the plan,we pumped cement prior to expansion. As we discussed,we were not able to circulate the job around the liner. We were able to squeeze the 47 barrel job away at 2 bpm,with some indication of initial lift, but most likely squeezing away right at the shoe depth above the Nechelik and below the Kuparuk intervals. The pumping pressures indicated that the job did not pump into either sand interval. When we attempted to expand the liner,we could not initiate expansion after several attempts,and the expansion tool failed at a pressure of 6800 psi. We were then able to successfully release off of the liner using the emergency back-off contingency,circulate freely and pull out the 4" inner string without issue. We were planning on abandoning the lower section for a future slot recovery and sidetrack. As discussed,we were challenged by the asset to complete the well above the liner top and perforate the Kuparuk. After discussing options,we presented to you our completion plan with the following points of isolation, knowing that our cement jobs were squeezed away at points in the well without circulation: We have cement verified with a log in the 7 5/8" by 11" hole from 6911' MD to 5209' MD above the Qannik. We have isolation below the Qannik verified by our inability to establish a circulation between perforations at 13,105'- 13,110' MD and 13,193'- 13,198' MD. Cement was squeezed into the lowest set of perforations prior to sidetracking. On the sidetrack,our managed pressure drilling operations never indicated communication with the Qannik above us. The isolation provided by the pack-off around the 7 5/8"casing will isolate this annulus from any pressure at the unsealed and unexpanded liner top. A packer will be set at the base of the production tubing to isolate the un sealed liner top from the surface. The Liner ID is 5.34" ID and will accept a 3%"entry guide to the tubing. Our intent is to produce the well as a Kuparuk producer. We will follow with proper Sundry application, but request a verbal approval to move forward with the completion. Thank-you! 2 • CD3-130 49.1 2, Rig Floor Elevation Measurements From Rig Floor >I 18.10' Annular I I I I Top Pipe 3-1/2" x 6" K > 20.29' I I I I Blinds K > 22.63' I I C I I Bottom Pipe 3-1/2" x 6" 1< > 26.45' I I Tbg Flange Elevation )E • • • • _ - RKB to Upper LDS 31 .07' RKB to LLDS >I 34.15' RKB to top of Landing Ring 36.60' 12.5' k Conductor Elevation > anding Ring I Surface Csg Flange Above Plan Pad Level I Conductor Planned Pad Elevation Comments: Conductors are cut at planned pad level • /STD Z/3 —/h v Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Friday, February 13, 2015 3:59 PM To: Loepp, Victoria T(DOA) Cc: Kane, Danny Subject: RE:CD3-130 Preparation for Slot Recovery Follow Up Flag: Follow up Flag Status: Flagged Victoria- At this time we are still working the pipe down. We will proceed with the plan outlined below if needed through the weekend. We will keep you informed of the operation. Thank-you! Greg Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W:(907)263-4749 C:(907)231-0515 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, February 13, 2015 2:45 PM To: Hobbs, Greg S Subject: [EXTERNAL]RE: CD3-130 Preparation for Slot Recovery Greg, Thank you for the update and plan forward options- Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeI i aaalaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeno@alaska.gov 1 i • From: Hobbs, Greg S [mailto:Greg.S.Hobhs@conocophillios.com] Sent: Friday, February 13, 2015 2:39 PM To: Loepp, Victoria T(DOA) Cc: Kane, Danny; Stinson, Rob D Subject: FW: CD3-130 Preparation for Slot Recovery Victoria- Up to 11:30 p.m. last night, operations on the CD3-130 well were progressing per plan. At that point,the run of the expandable liner met resistance that required establishing circulation to wash the liner in the hole. To this point,we have washed to 14, MD with a planned set depth of 15,618' MD. There is 1108'of open hole below us. In the event we decide to abandon the liner run, our plan is: Emergency off of the 6" OD liner leaving its top at 11,800' MD. Trip out of the hole. Run in hole and set a cement retainer at the top of the liner. Attempt to establish injection below the retainer. If injection is successful: Pump 153 bbl of cement into the liner to cover the open hole and liner volumes below the retainer. Place 9 bbl of cement above the retainer for 200'of cement above the retainer and a top of cement at 11,600'. If injection is not successful: Place 50 bbl of cement above the retainer for approximately 1100'of a cement plug above the retainer and a TOC of 10,670'. In either case,we would trip out of the hole to surface, finish waiting on cement if necessary,and test the casing to 3500 psi. After a successful pressure test,we would set a plug at approximately 4,000'for suspension of the slot or immediate slot recovery operations after the failure of the current liner operations. Should we not be able to emergency release from the liner,we would cut drillpipe, set a retainer above the cut point and proceed with the above steps. We will follow approval of these operations with the required sundries and supporting documents should we need to proceed with them. Thank-you! Greg Greg Hobbs Staff Drilling Engineer WNS Rotary Drilling W:(907)263-4749 C:(907)231-0515 2 • AVE L540-I WELL LOG TRANSMITTAL FEB 13 2015 DATA LOGGED 2 15 AOGCC tN.K.K.BENDER R To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: CD3-130 Run Date: 1/13/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-130 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20677-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 12AL4I$OJ /5._ • FICE1VED 2.54og WELL LOG TRANSMITTAL FEB 13 2015 DATA«'LOGGED 2 v2o15 A K.BEND R To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: CD3-130 Run Date: 1/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-130 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20677-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: UFTk + \ � � 7, s. THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `T*' Main: 907.279,1433 ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-130 Sundry Number: 314-686 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r fo.)).e_4_,,ctze Cathy Foerster Chair DATED this 7 day of January, 2015 Encl. RECEIVED • STATE OF ALASKA • DEC 3 4 014 ALASKA OIL AND GAS CONSERVATION COMMISSION cf5 ) /Z 0.30.3-1--A APPLICATION►' FOR SUNDRY APPROVALS AnCC _� i i 1/15 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program 0' Suspend ❑ Plug Perforations ❑ Perforate 0 . Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ - Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 213-160 3.Address: Stratigraphic ❑ Service E , 6.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 50-103-20677-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C. O. #569 ' CRU CD3-130 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ i/ 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 364472, 364471, 372104, 372105 Colville River Field/Fiord Oil Pool - 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): 15483 6818 -14044' 6468' 5bbls on top of Cement Retainer N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 114' 114' Surface 3317' 10-3/4" 3354' 2480' 5210 2470 Intermediate 14275' 7-5/8" 14309' 6549' 6890 4790 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3-1/2" L-80 2299' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Cement Retainer 14153'MD/6502'TVD 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development [ Service ❑ 14. Estimated Date for 1/12/2015 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 Danny Kane Email Danny.Kane(c�conocophillips.com Printed Name G.L.Alvord Title Drilling Manager SignaturePhone 907-265-6120 Date 12/30/2014 ,r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -S V-1- CO 1 LQ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: /P 7,--5 7 fio g 5o 6 /2 S i (M)25)0 1$ x 3 9 9 , 5: "thr leer iprrvllr2lcr/e-5f t' 2.-do p5j Liv:c-rC•3L iceva- i' e-�, (',,v,,, ., v✓1i`r01c- lf:sv/f5 /a /1-06ezC .;to/c v✓r Ivie-55ed /14 1-1.—)At re vii-z'p/ q ft-E., 5/-ab17/3cd /`,-,let /-7'0,-, Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: /0_ 407 / APPROVED BY Approved by: //' 7• ?-C i -- \\ - COMMISSIONER THE COMMISSION Date: / 7 - / ?I-e. J ,).5 AO V J�(.1" Submit Form and Form 10-403(Revised 10/2012) p o li a o i v d or 12 months from the date of approval. chments in Duplicate VTC- (/ /)c R fi I L RUE MS JAN - 9 201,�J ConocoPhillips Alaska,Inc. • • Post Office Box 100360 Anchorage,Alaska 99510-0360 RECEIVEr ConocoPhillips Telephone 907-276-1215 DEC 3 0 2014 December,30th,2014 /'+ Alaska Oil and Gas Conservation Commission AOGCC 333 West 7"Avenue, Suite 100 Anchorage,Alaska 99501 Re: Sundry to Perforate,Alter Casing,&Change Approved Program for CRU CD3-130 Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Sundry to Perforate,Alter Casing,&Change Approved Program for CD3-130, an onshore injector well from the CD3 drilling pad that will be re-entered&drilled using the Doyon 19 drilling rig during the 2015 ice road season. CD3-130 was planned to be a horizontal injector in the Fiord Nechelik reservoir under PTD(#213-160). The original 13-1/2" surface hole(CD3-130 PB1)was drilled to 3194' MD before encountering instability&the wellbore was accidentally sidetracked. After setting an open-hole kick-off plug to surface,the surface hole was sidetracked and redrilled to 3366' MD; the 10-3/4"surface casing was run, landed,and successfully cemented at 3353' MD. The 9-7/8"x 11"intermediate hole was then drilled to 15483'MD and the 7-5/8"intermediate casing was unsuccessfully run and landed high at 14309' MD(1174' MD off-bottom)after encountering tight hole and fully-packing off above the casing shoe from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown(#314-117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar,performing an injectivity test,and setting a cement retainer at 14167' MD,the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C&Nechelik hydrocarbon-bearing zones. After confirming well integrity via pressure testing, a 3-1/2"kill string was set at 2299' MD and Doyon 19 moved off of CD3-130 to CD3-316B. With the intermediate casing landed above the target reservoir,ConocoPhillips Alaska is requesting a Sundry to Perforate,Alter Casign,&Change an Approved Program to re-enter the well&complete CD3-130 as a horizontal iniector—as originally, planned. ConocoPhillips Alaska plans to first set a whipstock&mill✓window in the 7-5/8"intermediate casing, sidetrack and drill a 6-3/4"x 7-7/8"hole to the Fiord Nechelik reservoir(land 250'to the northeast originally-planned CD3-130 PB2 heel location),and run,cement,&expand an Enventure SET expandable liner. After confirming ceyient&liner integrity,a 6-1/8" production lateral would then be drilled to TD at 22622' MD(originally-planned toe location). A Lower Completion consisting of 4-1/2"liner and pre-perforated pups would be run followed by a 3-1/2"upper completion tied back to surface. After an E-line cement-bond log run in July 2014 confirmed there is no cement at the planned whipstock location, ConocoPhillips Alaska is planning to perform a sui icide squeeze with the rig prior to setting the whipstock. As part of this Sundry application,ConocoPhillips Alaska is requesting approval to first use E-line pre-rig to set a plug beneath the planned perforations to use as a base during suicide squeeze operations and then shoot two sets of perforations straddling the planned whipstock location to circulate across while performing the suicide squeeze. Please fmd attached the information required by 20 ACC 25.280 for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR SUNDRY APPROVAL as per 20 ACC 25.280 2. A description summary of proposal 3. Current&proposed completion diagrams 4. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) If you have any questions or require further information,please contact Danny Kane at 265-6048 (danny.kane(a conocophillips.com)or Chip Alvord at 265-6120. Sincerely, cc: \ CD3-130 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1728 Chip Alvord ATO 1570 Danny Kane Erik Nelson ATO 1786 Drilling Engineer Lanston Chin Kuukpik Corp CRU CD3-130 Sundry Applicata for • Perforating,Alter Casing, &Change Approved Program ConocoPhillips Attachment 1 —Description of Events & Plan Forward History CD3-130 was planned to be a horizontal injector in the Fiord Nechelik reservoir under PTD (#213-160). The original 13-1/2" surface hole (CD3-130 PB1) was drilled to 3194' MD before encountering instability &the wellbore was accidentally sidetracked. After setting an open-hole kick-off plug to surface, the surface hole was sidetracked and re-drilled to 3366' MD; the 10-3/4" surface casing was run, landed, and successfully cemented at 3353' MD. The 9-7/8" x 11" intermediate hole was then drilled to 15483' MD and the 7-5/8" intermediate casing was unsuccessfully run and landed high at 14309' MD (1174' MD off-bottom) after encountering tight hole and fully-packing off above the casing shoe from suspected instability. Unable to free the stuck casing and after applying for a Sundry for Operations Shutdown (#314-117), the second stage cement job was pumped to provide zonal isolation of the shallower Qannik hydrocarbon-bearing zone. After drilling out the stage collar, performing an injectivity test, and setting a cement retainer at 14167' MD, the primary cement job was bullheaded to provide zonal isolation of the Kuparuk C& Nechelik hydrocarbon-bearing zones. After confirming well integrity via pressure tests, a 3-1/2" kill string was set at 2299' MD. The original hole beneath the whipstock will be renamed CD3- 130 PB2. Proposed Plan Forward &Operations Summary ConocoPhillips Alaska's plan-forward is to perform a suicide squeeze pre-rigs set a whipstock in the 7- 5/8" 29.7# L-80 BTC-M intermediate casing, drill a 6-3/4" x 7-7/8" hole to the Fiord Nechelik reservoir, and run, cement, &expand an Enventure SET expandable liner. A 6-1/8" lateral would then be drilled to planned TD and the lower completion consisting of 4-1/2" liner with pre-perforated pups would be run followed by the upper completion consisting of 3-1/2" liner tied back to surface. Changes in the Drilling Program: • Added INTRM2 Section o 6.800" Window in 7-5/8" 29.7# L-80 BTC-M Casing 13136-13154' MD o 6-3/4" x 7-7/8" Hole o 6.808" 21.45# EX-80 XPC-ORNU-GIIC (Post-Expansion) Enventure SET Liner o INTRM2 Liner Cement—Designed to fill entire open-hole annulus post-expansion with a 50' cap above the liner lap. • 41.25bbls 15.8#GASBLOK—Final volume to be adjusted based upon drilling & LMWD caliper data. • Pre-Expansion Cement Placement: • 41.25bbls/ (7-7/8" OH x 6" OD Pre-Expansion Liner= 1632' MD • Estimated TOC 14103' MD, Base Cement at Liner Shoe 15735' MD • Post-Expansion Cement Placement: • OH Annular Volume (7-7/8" x 6.808" OD Post-Expansion Liner) o (15735'—13136') x 0.01522bb1/ft = 39.56bbls • Liner Lap Volume (6.875" x 6.808" OD Post-Expansion Liner) o (13136'—12946') x 0.0008906bb1/ft= 0.169bbls • Cap Volume (6.875" x 4" 14#S-135 XT-39 DP) o (12946'— 12846') x .03037bb1/ft= 1.52bbls Page 1 of 3 CRU CD3-130 Sundry Applica•for Perforating,Alter Casing, &Change Approved Program ConocoPhillips Attachment 1 -Description of Events& Plan Forward Major Changes in the Drilling Program (cont.): • PROD Section o 6-3/4" Open Hole Reduced to 6-1/8" o Heel Shifted 250' NW of CD3-130 PB2 Location • Provide Sufficient Anti-Collision Separation from Original Wellbore • Same Toe Location as Originally Planned o Pore Pressure Profile w/Continued Fiord Nechelik Production Over 1 Year • Heel Pressure Increases from 8.0 to 8.5ppg EMW • Toe Pressure Decreases from 8.0 to 7.5ppg EMW Overview of Pre-Rig& Rig Operations Pre-Rig Work 1. R/U E-Line. 2. Set Plug in 7-5/8" 29.7# L-80 BTC-M casing at-13300' MD. o Objective: This plug will be set as a bottom for suicide squeeze operations. 3. Shoot two sets of perforations for Suicide Squeeze. o Bottom Set Perforations-13170' to 13175' MD o Top Set Perforations"'13105' to 13110' MD o Perforations will be spaced out to allow for spacing-out of cement retainer&whipstock assembly between. 4. R/D E-Line. Rig Work(Doyon 19) 1. MIRU over CD3-130. 2. Displace diesel freeze protect with 9.6ppg brine. 3. Decomplete 3-1/2" kill string (Set 2262' MD). 4. Perform clean-out run with 6-3/4" tri-cone, 6.800" string mills, &string magnets to -13250' MD. o Objective: Drift 7-5/8" casing down to window& liner lap location for setting the expandable liner and ensure casing is clean prior to setting cement retainer. 5. Set K-1 Cement Retainer at"'13160' MD. 6. Establish circulation between perforation sets. Perform suicide squeeze by pumping"'10bbls 15.8#Class G cement into annulus between perforation sets-planned for 150%excess. 7. Perform clean-out run with 6-3/4"tricone &tag-up/confirm on cement retainer. o Objective: Clean-casing of residual cement down to cement retainer. 8. R/U MPD Equipment i 9. Space out, orient, & set Baker G2 XL Whipstock&Anchor on cement retainer. �;\1 1� c�` 10. Mill 6.750" window in 7-5/8" 29.7# L-80 BTC-M casing o Planned TOW: 13136' MD, Planned BOW: 13154' MD 11. Drill 20' new formation to"'13174' MD. 12. Perform FIT to 12.5ppg EMW. 13. P/U tandem 6.800" string mills& enlarge window to 6.800". o Objective: Ensure window is large enough for liner post-expansion. 14. P/U Kick-Off Assembly& drill 6-3/4" hole to 13300' MD 15. Objective: Dedicated assembly to reduce unintentional tortuosity& provide sufficient pilot hole for final drilling/reaming assembly. Page 2 of 3 CRU CD3-130 Sundry Applica•for • Perforating,Alter Casing, &Change Approved Program ConocoPhillips Attachment 1 —Description of Events& Plan Forward Rig Work(Doyon 19 cont.) 16. P/U Final Drilling& Reaming assembly& drill 6-3/4" x 7-7/8" hole to reamer TD of 15720' MD. o 10.0ppg LSND WBM w/MPD Holding 11.5-12.0ppg EMW o TD determined by reamer depth to ensure expandable liner remains in Fiord Nechelik reservoir for all expandable liner expansion scenarios. o NOTE: Planned TD offset 250'to the NW of the originally-planned CD3-130 heel location. 17. Trip Out with Final Drilling & Reaming Assembly to gauge hole condition. Perform drift run across whipstock prior to tripping to surface. 18. P/U & M/U "2950' 6" 20.1# EX-80 XPC-ORNU-GIIC (Enventure SET) expandable liner. 19. M/U False Rotary Table & RIH w/4" 14#S-135 XT-39 DP inner workstring, connect to expandable liner launcher. 20. RIH w/Expandable Liner to 15720' MD, Perform Liner Top Pressure Test 21. Circulate &Condition, Pump "'41.25bbls 15.8#GASBLOK cement (Adjust Volume amount to displace entire post-expansion open-hole annulus) o Ensure cement is sufficiently retarded to allow for expansion activities. 22. Expand 6" 20.1# EX-80 XPC-ORNU-GIIC liner to post-expansion diameter 6.808" (21.45#) 23. Perform Liner Clean-Out w/6-1/8" tri-cone to launcher(shoe). o Objective: Prepare liner for E-line evaluation. Launcher (shoe) will not be drilled out. 24. R/U E-Line 25. Tractor [-Line to perform cement bond log of liner. - Zow, gni cR 6- 26. R/DE-Line I-r5t.r« /}ObGG 27. P/U Lateral Drilling Assembly,Trip In to Above Launcher (Shoe) 28. Perform Liner Pressure Test 29. Drill-Out Launcher(Shoe), Clean-Out Shoe Track to 15820' MD, & Drill 20' New Formation to "'15840' MD 30. Perform FIT to 12.5ppg EMW. 31. Drill 6-1/8" Lateral to Planned TD 22622' MD o NOTE: Originally-planned CD3-130 toe location. 32. Run 4-1/2" 12.6# Liner& Pre-PerforatedPup LowerCompletion, Pressure Test 33. Run 3-1/2" 9.34# Upper Completion, Pressure Test Page 3 of 3 • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday, January 06, 2015 9:28 AM To: Loepp, Victoria T (DOA) Subject: RE:CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Victoria, Questions answered below: • MPSP (Slightly Higher, FPP at the Heel Location has prognosed to have come up from 8.5 to 8.0ppg EMW). o Drilling Beneath 7-5/8"Window Cut at 13136' MD • 3388 psi ASP = [(FG*.052)-.1]*TVD (shoe), 3388psi = [(12.5*.052)-.1]*6160 • 2399 psi ASP= [(PP*.052*TVD (next casing point)]-(0.1*TVD(shoe)), 2399psi = [(8.5*.052*6822]-(0.1*6160) o Drilling Beneath 6.808"INTRM2 Liner Shoe at 15736' MD • 3752 psi ASP= [(FG*.052)-.1]*TVD (shoe),3752psi = [(12.5*.052)-.1]*6822 • 2333 psi ASP= [(PP*.052*TVD (next casing point)]-(0.1*TVD(shoe)), 2333psi= [(8.5*.052*6822]-(0.1*6822) • BOP Test Pressure: 3500psi (Same As Approved PTD) • Injection Packer Depth: 15600' MD o The waiver granted last year was so that we could have improved wireline access to the packer. With the new well design & expandable liner,we will have to tractor no matter where we place the injection packer, so we have moved it back within 200' MD of the first pre-perforated pup. Regards, - Danny Danny Kane Senior Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Loepp, Victoria T(DOA) [rnailto:victoria.loepp@alaska.gov] Sent: Tuesday, January 06, 2015 8:49 AM To: Kane, Danny Subject: [EXTERNAL]CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Danny, 1. What is the MPSP?Same as original drilling permit? BOP test to? 2. What is the packer depth? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska 1 • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday,January 06, 2015 9:41 AM To: Loepp, Victoria T(DOA) Subject: RE: CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Victoria, I have provided a short and long answer to your question: The short: We are currently planning to perform the suicide squeeze pre-rig but in the event that the Alpine Resupply Road does not open on time,we will perform the squeeze with the rig after it has MIRU. The long: The suicide squeeze was originally planned to be performed with the rig; however,given the early Alpine Resupply Road prognosed opening date,we would actually prefer to perform the suicide squeeze pre-rig using a coiled-tubing unit and pumping unit. Here is a little background: • When planning for this well, we preferred to pump the suicide squeeze pre-rig, but we don't have a mobile pumping unit(for cement) out at Alpine to accompany the coiled-tubing unit—we would have to wait for the Alpine resupply road to open to Kuparuk. • Normally the Alpine Resupply road doesn't open until 01-Feb, so the we switched gears and planned to perform the suicide squeeze with the rig after wireline had set a bottom plug(to act as a base for the suicide squeeze cement) and shoot two sets of perforations. This plan had the least weather impact as we weren't sure when the Resupply Road would open. • Ice road building has been ahead of schedule with favorable weather and we have learned this week that the Alpine Resupply Road is prognosed to be open to travel 16-Jan-2015 —which gives us a good window to perform the work pre-rig as we can get a cement pumping unit over from Kuparuk. Regards, - Danny Danny Kane Senior Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1 907 227-6037 danny.kaneaconocophillips_com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, January 06, 2015 9:12 AM To: Kane, Danny Subject: [EXTIERNAL]RE: CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Is suicide squeeze pre-rig or after MIRU? From: Loepp, Victoria T(DOA) Sent: Tuesday, January 06, 2015 8:49 AM 1 Colville River Field • i CD3-130 Nechelik Injection Well Updated S.Brunswick (2/27/2013) 20"Conductor to 80' AIDIIIII 3-'/z"tubing kill string- 1500' MD liiiiii Freeze protect to+/-1500'TVD 10-3/4"45.5#L-80 BTC-M iiiii OIL Surface Casing @ 3353'MD/2480 TVD cemented to surface Estimated TOC-5209' MD 1HES 7-5/8"Stage Collar � @6909' MD Qannik Interval 7485'MD/4113'TVD 9.8 ppg kill weight brine in 7-5/8"Casing Opened hole to 11"starting© 13311' MD Packed off believed near shoe Shoe currently @ 14307' MD HRZ Top 13735'MD/6360'TVD Cement Retainer set '•' HRZ Base 14370' MD/6564'TVD 14153'MD .: its :`i;iiiiiM,in Kuparuk C l 14.832'MD/ 6690' '''''---;4101111111111111111111111111111111 TVD --- .;iiiiiiiiWniiMi: u,._.*_*-, 7-5/8"29.7#L-80 BTC-M Casing proposed setting @ 15,463' MD Nechelik 15.412 MD/6,806'TVD TD—15483 ft MD Colville River Field — Eandable Liner with Whipock (wp16) CD3-130 Nechelik Injection Well Updated: 29-Dec-2014 by Danny Kane Upper Completion MD ND 4 :, 20"Conductor to 80' / 1)\ ubing Hanger 21' 21' 2) 4-'/2'12.6#/ft IBT-Mod Tubing(2 jts), 80' 80' i::::: =-_ Freeze protect to+/-1500'TVD 3) XO 4-%"12.6#IBT-M x 3-''/z'9.3#EUE-8rd-M L-80 4) Camco TRMAXX-5E Nipple w/2.812"ID X Profile(47.2°) 2266' 2000' w/Control Line to Surface Cannon Cross-Coupling Clamps Every Joint III < 5) 3-'/z"X 1"Camco KBMG GLM w/DV (67.2°) 5662' 3400' EIS' 10-3/4"45.5#L-80 BTC-M 6) 3-'/z"X 1"Camco KBMG GLM w/DV (70.0°) 11343' 5600' Surface Casing 7) 3-'/z"X 1"Camco KBMG GLM w/DCK2 (72.6°) 14755' 6637' @ 3353'MD/2481 TVD cemented to surface Pinned for 2500 psi Casing to Tubing Shear 8) HES 2.813"X Profile (72.7°) 14819' 6654' 9) BOT 80-40 GBH locator 15600' 6806' Estimated TOC-5209'MD Lower Completion 10)Baker 5.5"X 7-5/8"HRD ZXP w/Hold Downs(82.7°) 15600' 6806' • Baker 5.5"RS Nipple (;/ -.Q 0 Top HES Stage Collar Baker 5.5"x 7-5/8"Flex Lock Liner Hanger 15626' 6811' - f 6911'MD/3892'TVD XO 5.5"Hydril 563 Box x 5"Hydril 521 Box Baker 80-40 Seal Bore Extension Hydril 521 box down Top Qannik Hydril 521 Pin X Pin pup joint 7485'MD/4119'TVD 11) 4-'W 12.6#L-80 IBT-M Tubing w/ Pre-Perf Pups 15645' 6808' Spaced Out-440 ft.Torque Rings Installed 12) 4-'W'12.6#L-80 IBT-M Orange Peel Shoe 22612' 6764' 11"Underreamer Malfunctioned Trip Out Uncertain Closing Depth Expandable Liner Top(Post Expansion)+/-12946'MD '!!!.t Upper Perfs 13105-13110'MD 1ii;, ' - HRZ Raft Top 13646'MD/6315 TVD Expandable Liner Shoe(Post-Expansion) ,S> ® HRZ Top Baker G2 XL 14007'MD/6422'ND 15736'MD/6822'ND TOW 13136'Mt::. .- HRZ Base Pre-Expansion: 6.0"OD/5.34"ID/20.1#EX-80 Length 17.5' 14503'MD/6566'TVD Post-Expansion: 6.8"OD/6.185"ID/6.125"Drift DLS 8.4°/100 ft t 2x Wearsox/jt 6.64"OD,Spaced 11'from Each End(-36'Joint Length) Baker K-1 Centralized 13616'-15736'MD Cement Retainer Kuparuk C 14971'MD/6690'TVD Top13160'MD , '` �� `. •',,, Nechelik 15618'MD/6,809'TVD Lower Perfs 13170-13175'MD ' 4-1/2"12.6#L-80 IBT-M Liner 22612'MD/6764'ND O 6 Wireline Set PlugJ : c13tpB2 :. , �� -13300'MD8$'tNll�a$1 'Tt s • L ::1 Gi r'rl G1 rid Ci rid Ci til 2014 Cement Retainer Set 14167'MD/6506'TVD a 2014 7-5/8"29.7#L-80 BTC-M Casing 6-%"x 7-'/8"INTRM2 TD 6-1/8"Production TD 14,309.29'MD/6,549'TVD 15836'MD/6831'TVD 22622'MD/6764'TVD DDP CD3-13 ?wp1 6 7 . 360 Plan Summary SURVEY PROGRAM I � /200 C9pth From Depth To Survey/Plan Tool 16C 116.71 196.00 CD3-130PB1 Gyro I (CD3-130PB1) GYD-GC-SS ' 246.80 523.41 CD3-130PB2 Gyro (CD3-130PB2) GYD-GC-SS 581.12 3288.10 CD3-130PB2 MWD I (CD3-130PB2) MWD+IFR-AK-CAZ-SC 12C 3383.04 13136.00 CD3-130PB2 MWD II (CD3-130PB2) MWD+IFR-AK-CAZ-SC 13136.00 14636.00 CD3-130wp16 (Plan: CD3-130) MWD80( 13136.00 15735.00 CD3-130wp16 (Plan: CD3 130) MWD+IFR-AK CAZ SC ,t0 1,, 15735.00 17235.00 CD3-130wp16 (Plan: CD3-130) MWD 15735.00 22622.59 CD3-130wp16 (Plan: CD3-130) MWD+IFR-AK-CAZ-SC i/ 401 aim- i 0 CASING DETAILS ` aI � . .. ... ...............TVD MD Name Size6160.07 13136.00 7-5/8" x 9-7/8" by 11" 7-5/8 -E 6822.18 15735.00 6-4/5"x 6-3/4"by 7-1/2" 6-13/16 ....L-- _ 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 tiff 0 0 0 0 0 OD 88888 Top Kupanik C LCU Base Nuiqsut _ 0 0° C-30 C K-3 Basal ShaleAboveHRZ Top Nechelik 0 10 3/4"x 13 12 5 11 K-2 K-2 Basal Base HRZ _5 3,',p�' iv o �� o0 0 7-518"x 9-7/8"by 111 K 3 , Albian 96 v ' Top Kuparuk D - o 40 000 0 0 K 1 M n0 0 00 00 0 'I 16-4/Y x 6-3/4"by 7-1/2"1 0 or , - o 0 0 0 NI o f cT o o 14-1/2"x 6-1/8"1 o Albian 97 ---- ShaleAboveHRZBase - Illimi X. 1 , mo 00,o 4) Top HRZ 0 0 _Mi�� . . m �10-3/4"x13-1/2' I I/ I I I 1 I I I o°o - o• 0 t 0 10000 15000 ` 20000 0 3000 6000 9000 12000 4.5t.:0 0 1'8080°"2100( I7-5/8"x 9-7/8"by 111 Measured Depth I6-415"x 6-3/4"by 7-1/2" Horizontal Departure 0 0 M126 330 30 CD3130PE2 , . , 60 ILII aoo eo -- an - n 1� ,46 1 ip5 nuc 3 - 14400 M. Z. W 30 SII �N ruq��: 1.:o - 1.0 270101'"11 .4.,::2',,', 90 - 1.12o - 16780 N I 240 120 , - 17100 7100 _ 17720 0 e - i I I 1 I I I I I I I 210 150 70 Imo 13500 15000 16500 18000 19500 21000 22500 180 z1 - 20550 21280 SECTION DETAILS ,,,.° _,°° Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation -2509.1 1 13136.00 71.83 32.37 6160.07 7219.64 7657.65 0.00 0.00 2956.25 KOP:8.4°/100'DLS,75°TF,for 17.5' C-30 213153.50 72.21 33.86 6165.47 7233.59 7666.74 8.40 75.00 2964.54 Hold for 50' 313203.50 72.21 33.86 6180.75 7273.12 7693.27 0.00 0.00 2987.72 Start 3.5°/100'DLS,90°TF,for 100' -2897.1 413303.50 72.25 37.54 6211.28 7350.44 7748.83 3.50 90.00 3031.39 Adjust TF to-90°,for 343.05' 513646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 Start 21100'DLS,-88.8°TF,for 250.78' 613897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 Hold for 269.52' 714166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 Start 2°/100'DLS,-83.21°TF,for 653.24' C-20 814820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CD3-130 0.BtmLtdSteer Start 3.49°/100'DLS,-76.09°TF,for 798.76' 915618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-130 1.Heel 120814 JB Hold for 20' 1015638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 Start 3.5°/100'DLS,-63.79°TF,for 489.72' -39 1 11 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 Hold for 6494.02' _49 Basal 12 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.0011660.69 CD3-130 2.Toe 120514 JB TD:22622.59'MD,6764.12'TVD 42 K-2 Basal P r`r it pa CK -5757.1 Albian 97 -5979.1 Albian 96 -63..; -64-. 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V o (O h LY LY LY LY C w O) .- C- 6 C) O) N 0 0 LL LL LL LL ai 0 0 0 0 0 0 0 y 0 0 0 0 0 0 0 E ui vi ui ui o o ui CD• Q F- v 0 CO C) 0) d d 7 O O) c0 a0 V' N p2 V ^) N 0) 0 O7 CD M C O d ( ) ' (CD (0 CO 2.1.. CO O COM V a- N N N V' V' N 10 N N .- .- a- a- N- T., d h O O0) V' N 0 CO -p0 La r u) O n N i 6 O O c7 O O c 4) O.g <- co 0 (OD co co) O0) S a- N d 7 a- a0 N N W W W T d V E co co N- V' 0 CO 7- CO N u) 0 V' CO. 0) 0 E d E ' OUMN E N _ OV' N d• ' 0 0 CO CO V' : 1 N N .- .- a- .- N !C a /� d 0. d 'O 0 La n N 0 I CO O O CO t0 3 a : r co ro ri m o 3 3 3 3 co 0 M O n C▪ 0 — y Q.y V' O O (s- O) O) 0 0 0 0 O d G W 0 0 0 0 c0 O N 06 co" co- co DI CO DI M ) 3 A N N M M c7 07 co M 2 ❑U U U U V3 0 CI r O m U O U ? E 00 0 0 0 0 0) L d 0 'C 0 v 0 0 0 0 N COr M 0 U0u ) N LO 0 7 +a N O e. MN (N ' M 1M C(•I N 0I- U) V O 1- c- a- a- NO M N R T V 0 Cl c a a U • 0 d d A E O N d• 0 0 0 0 L 7 !L (0 N O D- CO a- 0 0 0 0 0 C) Q • N a a co \ O O M 0) c0 u) u) 1O co CO c C J O) O M O O N N N co co co Na N. O . l A ) N- \ Li CO- t of = /� t0 v 'R m rn CD M M r) o 7. 0- to y (N°- U• r) ❑ ci U U 0 m Q � d a N f, d ❑ CJ ❑ ❑ N ❑ w O N LL y 7 E U U U m m 030 O O N J tl d 0 _ .�- Q 0 100 Z ,O 0 00 N- N- O O) O) O) M O ON C LL V (00, CO r r r r M O a M M M M M M (`� (') 000000 ❑ ❑ d : Z co6 N C 'Q 000000 0 0 E E a £ , O ^ o U .O a 0 j A N L. O 0 O) W W W M M ✓ (� A R d E M d) co) (0) (') co co d) A 6 ❑ UUCCN O C.) U U U 0 U U C d < h K en in • 3 8 ' � o Q o 5- Q r3 G U) 0 M • 0) m c 0 Ca a. cr) Q p w I u ta) 1 = N C 3 U 3 a) a a) a 3 0 m U M c O E a) U a) (4, o v• w c Q 2 0 U0 _ aa) - .2 L j O N c O C 4 C O N N a 3 4� N N N a) O }1 O U 22 c 'E. 3 Q ta U L 3 a ^ a 'no a) O U fUp ai O C U �G) N (0 N LL N O N N U a) 0E N N Cl) U OU N O 3 ON .a C N •• U p N N a) OU C.) N N 0 m ++ CO m C m m E 0 Q N N N a — co a.) w 0 = 0 u) 0 U Q • ConocoPhillips C D3-130wp 16 Schlumberger Alaska 0 U 300 0 (0 Q N 150 / - CD0 0 - m 0) U I)III/'IIII 0 I I I I I I I I i 1 1 I I 1 1 1 1 13500 15000 16500 18000 19500 21000 22500 Measured Depth Equivelant Magnetic Distance Displayed interval could be less than entire range: 13136.00 To 22622.59 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 13136.00 To 22622.59 Results Limited By: Centre Distance: 2458.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 116.71 196.00 CD3-130PB1 Gyro I (CD3-130PB1) GYD-GC-SS 246.80 523.41 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS 581.12 3288.10 CD3-130PB2 MWD I (CD3-130PB2) MWD+IFR-AK-CAZ-SC 3383.04 13136.00 CD3-130PB2 MWD II (CD3-130PB2) MWD+IFR-AK-CAZ-SC 13136.00 14636.00 CD3-130wp16 (Plan:CD3-130) MWD 13136.00 15735.00 CD3-130wp16 (Plan:CD3-130) MWD+IFR-AK-CAZ-SC 15735.00 17235.00 CD3-130wp16 (Plan:CD3-130) MWD 15735.00 22622.59 CD3-130wp16 (Plan:CD3-130) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 6160.07 13136.00 7-5/8"x 9-7/8" by 11" 7-5/8 6822.18 15735.00 6-4/5"x 6-3/4"by 7-1/2" 6-13/16 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 LEGEND -0- CD3-106,CD3-106,CD3-106 VO -A- CD3-119,CD3-119PB1,CD3-119PB1 VO -A- CD3-199,CD3-199,CD3-199 VO - CD3-106,CD3-106L1,CD3-106L1 VO -e- CD3-121,CD3-121,CD3-121 VO CD3-301,CD3301,CD3-301 V4 CD3-107,CD3-107,CD3-107 V7 -e- CD3-122,CD3-122,CD3-122 VO -g- CD3-301,CD3301A,CD3-301A VO CD3-107,CD3-107L1,CD3-107L1 VO -- CD3-123,CD3-123,CD3-123 VO -A- CD3-301,CD3301APB1,CD3-301APB1 VO X CD3-108,CD3-108,CD3-108 V14 -A- CD3-124,CD3-124,CD3-124 VO -X- CD3-301,CD3301 PB1,CD3-301 PB1 V1 - CD3-109,CD3-109,CD3-109 V5 -e- CD3-125,CD3-125,CD3-125 VO -e- CD3-302,CD3-302,CD3-302 V3 CD3-110,CD3-110,CD3-110 V12 CD3-125,CD3-125PB1,CD3-125PB1 VO CD3-302,CD3302A,CD3-302A VO 0 CD3-111,CD3-111,CD3-111 V7 -B- CD3-125,CD3-125PB1(surface),CD3-125PB1(surface)VO $- CD3-302,CD3302PB3,CD3-302PB3 V2 - CD3-111,CD3-111L1,CD3-111L1 V1 $- CD3-127,CD3-127,CD3-127 VO CD3-320,CD3320,CD3-320 VO -X- CD3-112,CD3-112,CD3-112 V3 CD3-127,CD3-127PB1,CD3-127PB1 VO -X- CD3-320,Plan:C03320A,CD3320Awp01 VO - CD3-114,CD3-114,CD3-114 V14 -e- CD3-128,CD3-128,CD3-128 VO Plan:CD3-126,Plan:CD3-126,CD3-126wp10 VO CD3-115,CD3-115,CD3-115 VO $ CD3-128,CD3-128(Intermediate),CD3-128(Intermediate)VO -0- Plan:CD3-129,Plan:CD3-129,CD3-129wp03 VO )( CD3 117,CD3-117,CD3-117 VO $- CD3-130,CD3-130PB1,CD3-130PB1 VO -9- Plan:CD3-131,Plan:CD3-131,CD3-131wp01 VO --X- CD3-118 CD3-118,CD3-118 VO CD3-130,CD3-130PB2,CD3-130PB2 VO -8-- CD3-130wp16 -X- CD3-119,CD3-119,CD3-119 VO --G- CD3-198,CD3-198,CD3-198 VO • • ConocoPhillips CD3-1 30wp16 Schlumberger Alaska 0 U 60 • c 0 cc a a) ami 30 0 - m - m _ I � I I I I I I I r- I I I I -1 13200 13275 13350 13425 13500 13575 13650 Measured Depth Equivelant Magnetic Distance Displayed interval could be less than entire range: 13136.00 To 22622.59 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 13136.00 To 22622.59 Results Limited By: Centre Distance: 2458.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 116.71 196.00 CD3-130PB1 Gyro I (CD3-130PB1) GYD-GC-SS 246.80 523.41 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS 581.12 3288.10 CD3-130PB2 MWD I (CD3-130PB2) MWD+IFR-AK-CAZ-SC 3383.04 13136.00 CD3-130PB2 MWD II (CD3-130PB2) MWD+IFR-AK-CAZ-SC 13136.00 14636.00 CD3-130wp16 (Plan: CD3-130) MWD 13136.00 15735.00 CD3-130wp16 (Plan: CD3-130) MWD+IFR-AK-CAZ-SC 15735.00 17235.00 CD3-130wp16 (Plan:CD3-130) MWD 15735.00 22622.59 CD3-130wp16 (Plan: CD3-130) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 6160.07 13136.00 7-5/8"x 9-7/8" by 11" 7-5/8 6822.18 15735.00 6-4/5"x 6-3/4"by 7-1/2" 6-13/16 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 LEGEND -0-- CD3-106,CD3-106,CD3-106 VO $- CD3-119,CD3-119PB1,CO3-119PB1 VO -4- CD3-199,CD3-199,CD3-199 VO -X- CD3-106,CD3-106L1,CD3-106L1 VO -A- CD3-121,CD3-121,CD3-121 VO $ CD3-301,CD3-301,CD3-301 V4 -9- CD3-107,CD3-107,CD3-107 V7 -0-- CD3-122,CD3-122,CD3-122 VO -e- CD3301,CD3301A,CD3301A VO - - CD3-107,CD3-107L1,CD3-107L1 VO - CD3-123,CD3-123,CD3-123 VO -4-- CD3301,CD3-301APB1,CD3-301APB1 VO -h- CD3-108,CD3-108,CD3-108 V14 -0- CD3-124,CD3-124,CD3-124 VO -A- CD3-301,CD3301PB1,CD3-301PB1 V1 - CD3-109,CD3-109,CD3-109 V5 -0- CD3-125,CD3-125,CD3-125 VO -0-- CD3-302,CD3-302,CD3-302 V3 - CD3-110,CD3-110,CD3-110 V12 -8- CD3-125,CD3-125PB1,CD3-125PB1 VO -a- CD3302,CD3302A,CD3302A VO -X- CD3-111,CD3-111,CD3-111 V7 $" CD3-125,CD3-125PB1(surface),CD3-125PB1(surface)VO -e- CD3302,CD3-302PB3,CD3-302PB3 V2 - CD3-111,CD3-111L1,CD3-111L1 V1 -9- CD3-127,CD3-127,CD3-127 VO CD3320,CD3-320,CD3-320 VO - CD3-112,CD3-112,CD3-112 V3 -9- CD3-127,CD3-127PB1,CD3-127PB1 VO --A- CD3320,Plan:CD3320A,CD3320Awp01 VO --X- CD3-114,CD3-114,CD3-114 V14 -0- CD3-128,CD3-128,CD3-128 VO -X- Plan:CD3-126,Plan:CD3-126,CD3-126wp10 VO -e-- CD3-115,CD3-115,CD3-115 VO -e- CD3-128,CD3-128(Intermediate),CD3-128(Intermediate)VO -X- Plan:CD3-129,Plan:CD3-129,CD3-129wp03 VO - CD3-117,CD3-117,CD3-117 VO -8- CD3-130,CD3-130PB1,CD3-130PB1 VO Plan:CD3-131,Plan:CD3-131,CD3-131wp01 VO CD3-118,CD3-118,CD3-118 VO -e- CD3-130,CD3-130PB2,CD3-130PB2 VO CD3-130wp16 CD3-119,CD3-119,CD3-119 VO -X- CD3-198,CD3-198,CD3-198 VO MD Inc Azi TVD 4-N/-S .E/-W Dleg TFace VS t Target U I313b 131363 32.37 6160.07 7219.64 7657.65 0.00 0.00 29 CD3-130wp16 13153. 1 33.86 6165.47 7233.59 7666.74 8.40 75.00 2 13136 13320 s� 13203.5 .21 33.86 6180.75 7273.12 7693.27 0.00 0.00 29 13136.00 To 22622.59 13303.50 72.25 37.54 6211.28 7350.44 7748.03 3.50 90.00 3031.39 13320 13500 13646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 13897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 14166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 13500 13680 14820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CD3-1300.8tmltdSteer 9:42,December 30 2014 15618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-1301.Heel 120814JB 13680 13860 15638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 13860 14040 SURVEY PROGRAM 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.00 11660.69 CD3-130 2.Toe 120514 JB Mpih From Depth To Survey/Plan Tool 116.71 196.00 CD3-130P131 Gyro l(003-130161513GC-SS 14040 14220 .60 523.61 CD3.130P132 Gyro(C033130PaipGC-SS 561 561.12 3288.10 C13330PB2 MWD 1(CD3-130BiM3"IFRiK•CAZ-SC 3383 04 13136 00 131361:100 463600 CD3-13. 816(Plant.CD3-13n09IWWD"I� 002 14220 14400 13136.00 15735.00 CD3-130wp16(Ran:CO3-1390W0"IFR-AK.CA2-SC 15735.00 17235.00 CD3-130mp16(Plan:CO3-130(.1WD 14400 14740 15735.00 22622.59 CD3-130,16(Ran:CD -A 3-13001WD"IFRK.CAZ-SC CASING DETAILS 14740 15080 TVD MD Name Size 15080 ----"" 15410 6160.07 13136.06/8"x 9-7/8"by 11" 7-5/8 6822.18 1573fi66"x 6-3/4"by 7-1/2" 6-13/16 15410 --_--- 15750 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 15750 16090 16090 16420 0/360 16420 16760 16760 17100 17100 17790 -30/330 210 �' - 30 17790 18480 18480 19170 r19170 19860 -0111.11111116.1 -180444441%".,_- 165 - 19860 20550 150 20550 21240 olimitimi% �� 21240 21930 -60/300 60 21930 22623 II till 10 -� \ , ., , '' 90 -0 14- N. 60 _.....a.,,v.z....„.:tviti.....,_ _ ._......, 4,.. .,„....,-- ...,..,„.74,,,._ i _ 4 90/270 .2r ..\$.yl►1 q fll.#6.4§40 111111',16.t.4044..et• 90 ///))1 \iN\ \\ _ 1.111s./1414)) 90 CD3-130P82�-_ - � 10 -120/240 101111 �� ► 120 � - 150 � �� 165 180195 -150/210 210 150 -180/180 aro $ C1 Oro 3- D 102 $ � 3- Pu 4D3-120.671064 -4197 C03106. 4 $ $ 426 CO3.1122624A8 4 n 26,0o3-126aSWVo �- 4n77,,CD3107 v 4 2.CW-118,003114014 -& CD3 123,003 123,CO3 123 VO $ 22 IV-31228122 Cm-126 I6aenne2(80(00 1 VI 139 CO3 131,CO3 131rr70100 -6- W 4- 0 115,003116 vo $ C $ C� $ C0 $ CO31306918 Kan 4(- Oro D314a 004706074wc $ 0133 125,CO3-123.001125 30 4 c CO $ CO3 -F m -E c 116,003116 v4 4 00 $ Co lot CC3-193&CD3 me v4�� $ CO 3 V2 -& $ 25.003-126"61 pupm4000126701(-rlecel V0 C -6- 49' C03111,004111,CO3 111 1/7 ' CD3 116.003113791,003116781 Vo 9 003127,003127.00112700 4 003391.0030601.000060100 -X- 003320,7l03.0033244,0013200"901 00 • Northing (4000 usft/in) • IIIIIIiitiIlitiImiIiiiiIiiiiImiIiiiiIiiiiIiiiiIjiiiIiiiiIiiiiIiii , IiL - o c - a N 3 `o O Q - N U M CO Q - U — N - - cL - O c- — o R - co, a. - — a - - 0 " - - I i - 0 _ LCO L - a Cr) a a_ co N 01T 0 T COQ — — , cMccj„ Q 0 Q rnU Q .., U - U :..i.,,,,, , U , r Et 0 O M , Q I I fr. \ :. 1, N CO � ,ii O � ` UN C Q1M OM 'C r _co .� ' cn U CT) - so_ U —O coC:;......00000ooe,, cr / `W 1 U — Q N- U ... M Q N Q U CO el, — QQ C., ok% _.43,7 T 1��11�� U - c+> Q 0 1,�� M cci- Iii= T11Vr M M CD Q r ►', Q N U, I Q Z cu U — - 0° o ' -y� U R C. etQ)f_, N _ _ — 07, - 3o Q CO •"+ M - a I -411114 (ui/usn 000 ) 6uiuyoN 41 ci AC Flipbook ' M Inc Azi TVD +N/-S +E/-W Dleg TFace V Target U ISISb 13153.3 33.86 6165.47 7233.59 7666.74 8.40 5.00 2 CD3-130w 16 13153. 1 33.86 6165.47 7233.59 7666.74 8.40 75.00 2 13136 13320 P 13203.50 21 33.86 6180.75 7273.12 7693.27 0.00 0.00 29 13136.00 To 14000.00 13646.55 7225 37.54 6211.28 7350.44 7948.04 3.50 90.00 3031.393 13320 13500 13646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 13897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 14166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 13500 13680 14820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CO3-130 0.BtmLtdSteer 9:44,December 30 2014 15618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-130 1.Heel 120814 JB 13680 13860 15638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 13$60 14040 SURVEY PROGRAM 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.00 11660.69 CD3-130 2.Toe 120514 JB 3ep111 From Depth To Survey/Pan Tool ,fi.11 196.00 CD3-130P151 Gyro 11CD3430551DGC-SS 14040 14220 205.00 523.41 CO3-130Pe2 Gyro 1CD3-130Pe27IGC-SS 501.12 3200.10 CD3-130P132 MWD 1(CO3-1301•11),IFl1.AK.CAZ-SC 3303.04 1313E00 CO3-130M52 MWD II(CD3.138/619rIFR.AKGAZ-SC 14220 14400 13136.00 14635.00 C0.3-130wp16(Plan:CD3-130MWD 13130.00 15735.00 CD3-130wp151Ma:CD3-130I11WD9IFR-AK- SC-SC 1573E00 1723500 CD3-130,16 . 15735.00 2262259 CO3-1300ap151Man:CD3-130MWDolFR-AK-CALSC 14400 14740 CASING DETAILS 14740 15080 TVD MD Name Size 15080 15410 6160.07 13136.06/8"x 9-7/8"by 11" 7-5/8 6822.18 1573548"x 6-3/4"by 7-1/2" 6-13/16 15410 " 15750 6764.12 22622.59 4-112'x 6-1/8" 4-1/2 15750 16090 16090 16420 0/360 ID 16420 16760 16760 17100 17100 - 17790 -30/330 ;01111111lF210 30 17790 '- 18480 7 195 18480 19170 180 19170 19860 165 19860 20550 20550 21240 Ir 150 � �a� ))., ` 21240 21930 - 60 21930 22623 60/300 ��/ 10��60tor,...,.... blit seta � is90/270 -lows ....,i�yr��>,e9 iiii ytt,„....**1:, ,ss 31 S''''''.',..- - N4iiimiio...,/ ,...._ \, 90120/240 � %alio,. __ / 1204:..NHIN44.4*%%1111 150 180 - %.41.41141111195 ..-150/210 210 150 -180/180 a 003.100,000.104003.10 VO -E' C 1 9 C0 121,CO3-121.CO3-121 20 003-127. 100 -9- C } w0. Raw 009-124046-129mlp Va + C0 0 -- CO3-112.003-112. V 0 c 9' 0 - 003-;0B COS-120 VS -fr C Pu". 003.1290'06'VO -t- CD 9 C09 -6- C $ C -12e 93erme212el.Cm-1230nam0ea0el 20 9( C 1VI $ Parc 046161,C46-131rcp01 VO -6' CD 004 046.115603115 00 -8- 00122,046124,003-12420 C -0- C 03402003402V3 P6 $ CO3-13o.1p25. -4E m -X- c 112,046-11),00}11)VO 4 00 CO3.125.CD3-125 00 $ C 00 9 CO3-302.C46-30x1.0033020 VO 1.0' CO W N ' 9 C -a' CO 402 -6' m -- 0133-119.CO3410,CO3-119 V0 -e C 207uao0 P35P91aduo V0 ->' cos -et- CO3-330.CO3-320.(303-320 20 $ 003111.003111.600.111 V) $ 000110.046119441.003119951 VO $ 003127.003127.003-127 20 -0' CO3-311.046201.00440104 -- CO3s0,Plan:0033204Cm3209,01V0 ' M Inc Azi TVD +N/-S +E/-W Dleg TFace Target U 13'Lib I q 13136. 3 32.37 6160.07 7219.64 7657.65 0.00 0.00 2 CD3-130wp16 /31531 33.86 6165.47 7233.59 7666.74 8.40 75.00 2 13136 13320 13203.5 .21 33.86 6180.75 7273.12 7693.27 0.00 0.00 29 14000.00 To 15000.00 13303.50 72.25 37.54 6211.28 7350.44 7748.83 3.50 90.00 3031.39 13320 13500 13646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 13897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 14166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 13500 13680 14820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CD3-130 0.BtmLtdSteer 9:45,December 30 2014 15618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-130 1.Heel 120814 JB 13680 13860 15638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 13860 14040 SURVEY PROGRAM 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.00 11660.69 CO3-130 2.Toe 120514 JB Iep111From 16..71 0¢196.00 th To 003190PB1 Gyro I(CD3.1307001 SS 14040 14220 66.80 52341 CO3-100Pe2 Gyro(CD3JIGC-SS 581.12 3380.10 003-130732 MWD I(CD3-734-130Vf IFOAKGA2-SC 330304 13136.00 003-130PS2MVO II(CO3-1961914o1F7AKGA2.SC 14220 14400 13136.00 16636.00 C133-130wp16(Ran:CD3.13019WD 13136.00 1573500 CD3.130wp16(Ran:CO3-13019WD.IFR-0K-CA2SC 1573500 17235.00 CD3.13002016(0547:CO3-1310WD 1573500 22622.59 CM-130,16(Fl4n:CO3.13019WD.1MAK-CAZ0C 14400 14740 CASING DETAILS 14740 15080 ND MD Name Size 15080 15410 6160.07 13136.08/8"x 9-7/8"by 11" 7-5/8 6822.18 15733108"x 63/4"by 7-1/2" 6-13/16 15410 15750 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 15750 --- 16090 III 16090 16420 ----------""-. 16420 --"-"- 16760 0/360 ----- -- 16760 17100 17100 - 17790 30/330 2107 30 17790 18480 18480 19170 180 ._ - ---- . , . .. . 19170 19860 165 19860 20550 150 20550 21240 21240 21930 ---Ho-.. V 60 21930 22623 -60/300 � � '.i 7_ ii: CD3-130PB2� i 11 (I ��1�1��4. V ��NVI\lct ' : /. . 1 \‘ 3 i "-'.. 11\iiiiiillhillii10111 ii Aft -90/270 mwe wru,I,Wlp r /// ` 90 7.ny i ' ' '.'4P -4--*71‘%%% ,,,, , 4 ��, 60 75 90 - %%11130.0.,s%miii0 -120/240 r 120 ` 150 165 %� 180 195 -150/210 ` _. 210 150 225 -180/180 -e $ .DD2-11101.DM-111013, + 100 $ + 124,710 VI a 0 -x a D -� - .126.70301 -f- -9- -& $ t 20 6.am 401 0 CO3-1211 300500204)00 -- 1 VI $ 0 w.C0310i.CO3-121.001 V0 -& .- -A- a -0- $ coo-10 s.R -X- cp ;a:�1004W 4E 063.11 � D � D 00 � � CO3-302A 00 -9- m 9e D --E-- �- $ 202 -& aE D 1/B.00}11400 $ Co 0741row5060 02105741,3000.100 C6 -o- 033-320.cwszo.on0124 00 -eDDo-,11.C133-111.00211,07 -& 003-114.00011-51.005-„976100 $ 002-,21.00121.003.127 ro + Cp220,.002161.00266,V. 032220.7)40 0033206.CO3-3204,01 0000 ' M Inc Azi TVD -1.N1-6 +E/-W Dleg TFace Target U 1.51.5b 13136. 3 32.37 6160.07 7219.64 7657.65 0.00 0.00 2 CD3-130wp16 131531 33.86 6165.47 7233.59 7666.74 8.40 75.00 2 13136 13320 13203.50 2.21 33.86 6180.75 7273.12 7693.27 0.00 0.00 298 . 15000.00 To 16000.00 13303.50 72.25 37.54 6211.28 7350.44 7748.83 3.50 90.00 3031.39 13320 13500 13646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 13897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 14166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 13500 13680 14820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CD3-1300.BtmLtdSteer 9:46,December 30 2014 15618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-130 1.Heel 120814 JB 13680 13860 15638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 13860 14040 SURVEY PROGRAM 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.00 11660.69 CD3-130 2.Toe 120514 JB MD.116.71 De196.00 CD3-130To 6lan Tool 681 Gyro I(CD3.1301551QGC-SS 14040 - 14220 268.80 523.61 C133-130P132 Gyro ICD3/130PB1pGC-SS 581.12 328800 CD3-130682 MWD 1(CD3-13pW2p.IFR-AK-CA2-SC 3383.01 1313600 C133-1306152 WO II(C133-130M20.1FR-A11-CA2-SC 14220 14400 1913600 16636.00 CD3-130wp1 ((Man:CD3-130{5WD 13136.00 1573500 0133-130,165(Ran:CD3-130MIWO.IFR-AK-CAZ-SC 15735.00 17235.00 003-130wp16(Ran:CD3-130MWD 14400 14740 15735.00 22612.59 CD3-130wp16(Maw CD3.130MWD.IF10-AK-CA2-SC CASING DETAILS 14740 15080 TVD MD Name Size 15080 15410 6160.07 13136.096/8"x 9-7/8"by 11" 7-5/8 6822.18 1573545"x 6-3/4"by 7-1/2" 6-13/16 15410 15750 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 15750 16090 ID16090 - 16420 16420 16760 0/360 16760 17100 17100 17790 -30/330 210 30 17790 18480 • .. 18480 19170 180 19170 19860 16519860 20550 150 20550 21240 21240 21930 60/300 �< 120 \\I 21930 22623 e , mi ------ \\/\35-90/270 - - 90 ikiik ler "illy --- W-1-4-441kv 1..,,.,\ \ , 4 __ ftifiii. ill,1 )4i � 1or .0.0 10 PD3-1306131 -120/240 �;' \`�` IIIII. 120 _ 150 ,�� - 165 180 Q -150/210` 210 .0"..e..°. 150 -180/180 $ ro $ � VI -e- CO3-121, + V3 $ C i- 6,. N. Coo e °.°�,055,V5 a -;26033-;22:03312220 -e (memo 2p0OVS -F' -& $ -lOe 005-1205 u0 4422:.crow-128 ry"ana06161 VO 4E 1 V, $ 27 C03131.0034312W vu -e- + -kr 03 -e- 033-,3A a n 130P51.CO3 1307131 00 < $ 103135..15 -3 00.`0031001 V1:VO �7 w -e 2 VD -0. CO3-302.003 3024.1D3-3020 00 + -e- CO3-121003-103 m'a Ise 07 6 $ VI -Pr 0.500770 VV12 l6.006170 W $ :1 506233 5 3125601 022.0.,00 -� -o- a 103•111.003•111,053-111 W -fr 0D>„3.05 11565,.0D3.71.P57 49 $ 103127.CP,27.103127 W + 103 003301.003301 04 � 103-320.PI-003320,.10320.250100 M Inc Azi TVD *N/-S +E/-W Dleg TFace Target U 131.3b 13136. 3 32.37 6160.07 7219.64 7657.65 0.00 0.00 2 CD3-130wp16 131531 33.86 6165.47 7233.59 7666.74 8.40 75.00 2 13136 13320 13203.50 .21 33.86 6180.75 7273.12 7693.27 0.00 0.00 298 . 16000.00 To 22622.59 13303.50 72.25 37.54 6211.28 7350.44 7748.83 3.50 90.00 3031.39 13320 13500 13646.55 72.65 24.95 6315.12 7629.43 7918.04 3.50 -90.00 3203.15 13897.33 72.82 19.70 6389.61 7850.87 8008.97 2.00 -88.80 3359.18 14166.85 72.82 19.70 6469.21 8093.29 8095.77 0.00 0.00 3535.77 13500 13680 14820.09 74.80 6.25 6652.12 8703.03 8235.89 2.00 -83.21 4015.45 CD3-130 0.BtmLtdSteer 9:48,December 30 2014 15618.85 82.93 339.00 6809.12 9471.42 8133.76 3.49 -76.09 4746.45 CD3-130 1.Heel 120814 JB 13680 13860 15638.85 82.93 339.00 6811.58 9489.95 8126.65 0.00 0.00 4766.19 16128.56 90.66 323.67 6839.11 9917.23 7892.74 3.50 -63.79 5253.09 13860 14040 SURVEY PROGRAM 22622.59 90.66 323.67 6764.12 15148.29 4045.31 0.00 0.00 11660.69 CD3-130 2.Toe 120514 JB lapth From Depth To Survey/Plan Tool _____ 116.71 196.00 CD3-13077611 Gyro I(CO3-13013915 -SS 14040 _ 14220 206.60 523.41 C133-130P132 Gyro(C133cOO.73PSEpGC-SS 561.12 3266.10 CO3-13077132 MWD I!CD3-130BY151.IFFAx-CAI-SC 3383.04 13136.00 CD3-130PB2MW1311(CD3-1)9ie15.IFRAx.CA2-SC 14220 14400 13136.00 10636.00 CO3-130wp16(Ran:CD3-13011WD 13136.00 15735.00 CD3-13044p1 (Ran:CD3-130�1WD.IFR AI(.CA2..SC 15735.00 17235.00 CD3-130wp15(Plow CD3-13WD 14400 14740 15735.00 22622.59 CD3-130wp16(Plan:CD3.13920MWD.IERAx-AP -SC CASING DETAILS 14740 15080 TVD MD Name Size15080 15410 6160.07 13136.Q96/8"x 9-7/8"by 11" 7-5/8Different 6822.18 1573548"x 6-3/4"by 7-1/2" 6-13/16 15410 15750 6764.12 22622.59 4-1/2"x 6-1/8" 4-1/2 4' y Axes 5C 1 K?S 15750 16090 16090- 16420 0/360 16420 16760 • 16760 _ "" 17100 17100 - 17790 30/330/ 450 420 30 17790 18480 V __-, 390 18480 19170 360 ` ` 19170 19860 j330 " 19860 20550 300 20550 21240 21240 21930 270 - 60/300 / :,-.. 240 Oil 211 __.--- - , 60 21930 22623 . 011111111*51 /1///((///(„,„,,,,„,,,, 9 _12s ), . , ,7/ , • -90/270 90 .,, iilipios .„111 _,„- 12s - . k ,, _. .%111111111111111110 -120/240 120 270 `_ 300 330 360 390 .--... -150/210 ` 420 150 450 -180/180 -e. $ Dai 1 + 003-127, 100 $ + R-. 00.1242770 V0 031100 2,03 V a -e - 503-1.4p03 VO -6 -& $ 25 TOBm1a�1003-122IW.,a..00 -x 1 V1 $ % a"003,131,DD3;3,2,00,VO -i/f. -� m -� o -o- DD a $ CO3-130.1716 R 4E CD3,100,0:13-103.X105 4 0 X117.C133117w D 240 -o- Co3-3084.CO3-30211 VO CDa»a,003712 00 + Dai $ V2 -tr -x $ 61 aW+m4CP 1267761420.221 V0 -� D -� 003-320.0133-320.003-320 VO -a CD3-I11,Da 111.DD,-111 V, -- CD3-119,CM-119M,'003-1106140 $ 003.127.CD3-127,003-,2740 -.I. 001171.003301.00330142 ->F 00,320.Raw 0033200.0002040701 00 • 0 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-130 Plan: CD3-130 Plan: CD3-130wp16 Error Ellipse Survey Report 30 December, 2014 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130PB1:12.5+36.62 @ 49.12usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130PB1:12.5+36.62 @ 49.12usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: Plan:CD3-130 Survey Calculation Method: Minimum Curvature , Design: CD3-130wp16 Output errors are at 1.00 sigma ) t(p(}/ ° 58 to Database: OAKEDMP2 L get actual errors Project Western North Slope,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD3 Fiord Pad Site Position: Northing: usft Latitude: 70°25'9.315 N From: Map Easting: usft Longitude: 150°54'41.768 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.86 ° Well CD3-130 .. :. Well Position +N/-S 0.00 usft Northing: usft Latitude: 70°25'7.804 N +El-W 0.00 usft Easting: usft Longitude: 150°55'1.908 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 12.50 usft Wellbore Plan:CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 2/1/2015 18.52 80.87 57,555 Design CD3-130wp16 Audit Notes: Version: Phase: PLAN Tie On Depth: 13,136.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.62 0.00 0.00 333.00 Survey Tool Program Date 12/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 116.71 196.00 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 246.80 523.41 CD3-130PB2 Gyro(CD3-130PB2) GYD-GC-SS Gyrodata gyro single shots 581.12 3,288.10 CD3-130PB2 MWD I(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,383.04 13,136.00 CD3-130PB2 MWD II(CD3-130PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,136.00 14,636.00 CD3-130wp16(Plan:CD3-130) MWD MWD-Standard 13,136.00 15,735.00 CD3-130wp16(Plan:CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15,735.00 17,235.00 CD3-130wp16(Plan:CD3-130) MWD MWD-Standard 15,735.00 22,622.59 CD3-130wp16(Plan:CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude semi-major semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (01 (°) loon) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 13,136.00 71.83 32.37 6,160.07 17.79 -1.22 43.77 2.74 15.88 4.33 10.60 45.53 8.01 48.65 MWD+IFR-AK-CAZ-SC(1,4) 13,153.50 72.21 33.86 6,165.47 17.69 -1.27 44.18 2.51 15.88 4.34 10.62 45.65 8.01 48.68 MWD(1,5) 13,203.50 72.21 33.86 6,180.75 17.69 -127 44.61 2.58 15.89 4.36 10.71 46.06 8.03 48.52 MWD(1,5) 13,303.50 72.25 37.54 6,211.28 17.52 -1.23 46.12 2.12 15.89 4.40 10.87 46.91 8.09 48.24 MWD(1,5) 12/30/2014 9:50:53AM Page 2 COMPASS 5000.1 Build 65 SSchlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-13OPB1:12.5+36.62 @ 49.12usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130PB1:12.5+36.62 @ 49.12usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: Plan:CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130wp16 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (soft) (°) l°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 13,646.55 72.65 24.95 6,315.12 18.31 -1.53 46.30 4.63 15.98 4.55 11.43 49.85 8.34 47.04 MWD(1,5) 13,897.33 72.82 19.70 6,389.61 18.80 -1.70 46.89 5.57 16.09 4.65 11.78 52.03 8.71 45.77 MWD(1,5) 14,007.41 72.82 19.70 6,422.12 18.91 -1.70 48.89 5.59 16.21 4.74 12.04 53.79 9.03 44.73 MWD(1,5) 14,166.85 72.82 19.70 6,469.21 18.96 -1.70 49.57 5.60 16.25 4.76 12.13 54.39 9.15 44.39 MWD(1,5) 14,503.24 73.73 12.74 6,566.12 19.84 -2.21 50.21 6.95 16.63 4.94 12.58 58.35 10.14 41.89 MWD(1,5) 14,670.11 74.27 9.31 6,612.12 21.50 -2.26 40.58 6.72 18.45 4.98 12.60 50.40 9.26 45.82 MWD+IFR-AK-CAZ-SC(2,5) 14,820.09 74.80 6.25 6,652.12 21.73 -2.41 39.71 7.12 18.65 5.02 12.74 50.71 9.43 45.52 MWD+IFR-AK-CAZ-SC(2,5) 14,971.41 76.13 0.96 6,690.12 21.92 -2.90 36.77 8.11 18.95 5.09 12.93 51.14 9.74 45.03 MWD+IFR-AK-CAZ-SC(2,5) 14,992.41 76.33 0.23 6,695.12 21.92 -2.90 36.77 8.11 18.95 5.09 12.93 51.14 9.74 45.03 MVVD+IFR-AK-CAZ-SC(2,5) 15,125.34 77.60 355.65 6,725.12 21.91 -3.44 33.14 9.11 19.29 5.15 13.12 51.54 10.15 44.46 M1ND+IFR-AK-CAZ-SC(2,5) 15,618.85 82.93 339.00 6,809.12 21.41 -4.46 24.87 10.83 20.00 5.23 13.43 52.15 11.32 43.21 MWD+IFR-AK-CAZ-SC(2,5) 15,638.85 82.93 339.00 6,811.58 21.44 -4.46 24.94 10.83 20.04 5.23 13.44 52.17 11.37 43.16 MWD+IFR-AK-CAZ-SC(2,5) 15,735.00 84.42 335.96 6,822.18 20.97 -4.82 22.19 11.12 2011 5.25 13.35 52.69 11.58 42.31 MWD(2,6) 16,128.56 90.66 323.67 6,839.11 20.21 -5.31 18.66 10.47 20.26 5.26 12.25 53.66 13.07 38.84 MWD(2,6) 22,622.59 90.66 323.67 6,764.12 23.63 -5.30 47.36 12.10 23.67 5.20 16.03 62.63 31.81 13.09 MWD+IFR-AK-CAZ-SC(3,6) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 13,136.00 6,160.07 7-5/8"x 9-7/8"by 11" 7-5/8 11 15,735.00 6,822.18 6-4/5"x 6-3/4"by 7-1/2" 6-13/16 7-1/2 22,622.59 6,764.12 4-1/2"x 6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 3,430.48 2,509.12 C-30 4,417.17 2,897.12 C-20 7,004.52 3,928.12 K-3 7,397.19 4,083.12 K-3 Basal 7,486.39 4,118.12 K-2 7,747.30 4,221.12 K-2 Basal 11,835.07 5,757.12 Albian 97 12,548.04 5,979.12 Albian 96 13,646.55 6,315.12 ShaleAboveHRZ 14,007.41 6,422.12 ShaleAboveHRZBase 14,007.41 6,422.12 Top HRZ 14,503.24 6,566.12 Base HRZ 14,670.11 6,612.12 K-1 14,820.09 6,652.12 Top Kuparuk D 14,971.41 6,690.12 Top Kuparuk C 14,992.41 6,695.12 LCU 15,125.34 6,725.12 Base Nuiqsut 15,618.85 6,809.12 Top Nechelik 12/30/2014 9:50:53AM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130PB1:12.5+36.62 @ 49.12usft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130P61:12.5+36.62 @ 49.12usft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: Plan:CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130wp16 Output errors are at 1.00 sigma Database: OAKE D M P2 ' Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 13,136.00 6,160.07 7,219.64 7,657.65 KOP:8.47100'DLS,75°TF,for 17.5' 13,153.50 6,165.47 7,233.59 7,666.74 Hold for 50' 13,203.50 6,180.75 7,273.12 7,693.27 Start 3.57100'OLS,90°TF,for 100' 13,303.50 6,211.28 7,350.44 7,748.83 Adjust TF to-90°,for 343.05' 13,646.55 6,315.12 7,629.43 7,918.04 Start 27100'DLS,-88.8°TF,for 250.78' 13,897.33 6,389.61 7,850.87 8,008.97 Hold for 269.52' 14,166.85 6,469.21 8,093.29 8,095.77 Start 27100'DLS,-83.21°TF,for 653.24' 14,820.09 6,652.12 8,703.03 8,235.89 Start 3.497100'DLS,-76.09°TF,for 798.76' 15,618.85 6,809.12 9,471.42 8,133.76 Hold for 20' 15,638.85 6,811.58 9,489.95 8,126.65 Start 3.57100'DLS,-63.79°TF,for 489.72' 16,128.56 6,839.11 9,917.23 7,892.74 Hold for 6494.02' 22,622.59 6,764.12 15,148.29 4,045.31 TD:22622.59'MD,6764.12'TVD Checked By: Approved By: Date: 12/30/2014 9:50:53AM Page 4 COMPASS 5000.1 Build 65 Pool Report Noma • • O O O Lf) 1— CD O O x.08p8p$8 O Z -0 0 N N ..-- 8 b 'mmaa a ¢x¢¢ P-3 u i 0 000 C" lk r; O Q N N N N N Q cu`•'iolot V O 0)w my ,„ 08 J m67m67 -0R4 11111141, 551.1-8 1$ H _ Q C (97S rgin� �0' OT '•1, V .W Z00000 e •s• cn* gfh littiii, ° 0 1 1: e� Og'3o ': \"$4.' 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Quit I Help 1 CD3-130wp16 Kick-off Point tv CPAI Coordinate Converter c=i I a X From: To: Datum: (NAD83 V I Region: lalaska2.J. Datum: NAD27 ...I Region: (alaska .1 C Latitude/Longitude (Decimal Degrees V C Latitude/Longitude (Decimal Degrees C UTM Zone. r---- E South C UTM Zone: (True E South f State Plane Zone: r4---_-1 Units: tri; r. State Plane Zone: IT rue 77 j, Units: [us-It VI .1, C . ,Ii' Legal Description(NAD 27 only) ..i L Starting Coordinates: Legal Description X: 11535596.05FE, Range: 1005 ITE Township: (013 Y: (601059346 Meridian: lu .. Section:133 _ [FNL j (2101.5970 FE11 j 11484.9101 I. Transform Quit I Help • • CD3-130wp16 Intermediate Casing II tj CPAI Coordinate Converter ' i ( From: _ i To: Datum: ra—INAD83 .1 Region: lalaska .I Datum: INAD27 .1 Region: lalaska • Latitude/Longitude 'Decimal Degrees .i C Latitude/Longitude 'Decimal Degrees UTM Zone: [ E South C` UTM Zone: IT rue E South State Plane Zone: Ft . Units: us-ft • (. State Plane Zone: {True Units: us ft • r. mat Descupticn 1NAD27`°r`;' t: Legal Description(NAD27 only) Starting Coordinates , Legal Description ........ ... .. _____ �. _, X: 11536063.94 Township: 1013 N . Range: 1005 11-7.. Y: 16012945.04 Meridian: 1u ,' Section:128 _� FNL •. 15023.4939 FEL • 11044.4229 Transform Quit Help CD3-130wp16 TD 4 CPAI Coordinate Converter 1,``=` 1 tom'1,00 From: To: Datum: 1NAD83 .I Region: lalaska . Datum: ;NAD27 . Region: Ialaska v r Latitude/Longitude (Decimal Degrees 2_, r''' Latitude/Longitude 'Decimal Degrees . C UTM Zone: [ (— South C` UTM Zone: True E South A- State Plane Zone. 4 Units: us.tt +� State Plane Zone: True . Units: us ft • 1 rs ri Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11532104.00 Township: 013 F-E Range: 1005 E • Y: $6018575.00 Meridian: Eu Section-121 FFT.11:—C1 14729.7398 FEL • 15070.0816 1 Transform Quit I Help I . * • Tollerable Collision Risk Worksheet As - built 4 DATE BY CK APP DESCRIPTION REV DATE BY COAPP DESCRIPTION • 10 2/2/11 CZ DB C.A. UPDATED PER K110003ACS 11 4/11/11 CZ GD I C.A. UPDATED PER K110003ACS [NAD 83 ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-198 6,003,630.37 1.528,434.35 70° 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 12.5 CD3-199 6,003.625.99 1,528,415.38 70' 25' 09.221" 150' 54' 44.833" 1387' 661' 7.3 12.8 CD3-301A 6,003,621.33 1.528,395.58 70° 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 CD3-302A 6,003,616.72 1.528,376.38 70' 25' 09.124" 150° 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6,003,612.52 1.528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3-304 6,003,607.82 1,528,337.04 70° 25' 09.031" 150° 54' 47.122" 1368' 739' 7.3 13.4 CD3-305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150° 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6,003.599.43 1,528,298.37 70° 25' 08.942" 150° 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528,278.93 70° 25' 08.890" 150° 54' 48.820" 1354' 797' 7.3 13.2 CD3-108 6,003,589.85 1.528,259.61 70' 25' 08.842" 150° 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1,528,239.85 70° 25' 08.794" 150° 54' 49.962" 1344' 836' 7.3 13.1 CD3-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150° 54' 50.533" 1339' 855' 7.3 13.0 CD3-111 6,003.576.13 1,528,201.08 70' 25' 08.699" 150° 54' 51.095" 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54' 51.676" 1330' 894' 7.3 13.1 CD3-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150° 54' 52.255" 1325' 914' 7.3 13.1 CD3-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150° 54' 52.815" 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150° 54' 53.388" 1315' 953' 7.3 13.2 CD3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150° 54' 53.950" 1311' 972' 7.3 13.2 CD3-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150° 54' 54.516" 1306' 991' 7.3 13.1 CD3-118 6,003,544.88 1,528,064.44 70' 25' 08.372" 150° 54' 55.086" 1301' 011' 7.3 12.8 CD3-X19 6,003.540.17 1,528,044.86 70' 25' 08.322" 150' 54' 55.660" 1296' 030' 7.3 12.8 CD3-X20 6,003.535.95 1,528,025.39 70' 25' 08.278" 150° 54' 56.229" 1291' 050' 7.3 12.6 CD3-121 6,003,531.41 1,528,006.04 70° 25' 08.230" 150' 54' 56.794" 1286' 069' 7.3 12.5 CD3-122 6,003,527.00 1,527,986.67 70' 25' 08.184" 150° 54' 57.360" 1282' 088' 7.3 12.6 CD3-123 6,003,522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 1277' 108' 7.3 12.6 CD3-124 6.003,518.17 1,527,947.59 70' 25' 08.091" 150° 54' 58.502" 72' 127' 7.3 12.5 CD3-125 6,003,513.62 1,527,927.89 70' 25' 08.044" 150' 54' 59.078" 67' 147' 7.3 12.6 CD3-X26 6,003,508.97 1,527,908.70 70' 25' 07.995" 150' 54' 59.639" 1263' 166' 7.3 12.6 CD3-127 6,003,504.45 1,527,889.34 70' 25' 07.948" 150' 55' 00.204" 1258' 185' 7.3 12.6 CD3-128 6.003,500.08 1,527,870.01 70' 25' 07.902" 150' 55' 00.769" 1253' 204' 7.3 12.6 CD3-X29 6,003.495,32 1.527,850.64 70' 25' 07.852" 150' 55' 01.335" 1248' 224' 7.3 12.6 CD3-X30 6,003,490.74 1,527,831.05 70' 25' 07.804" 150° 55' 01.908" 1243' 243' 7.3 12.5 CD3-X31 6,003,486.58 1.527.811.73 70' 25' 07.760" 150' 55' 02.472" 1239' 263' 7.3 12.3 CD3-X32 6,003,482.02 1,527,792.33 70' 25' 07.713" 150' 55' 03.039" 1234' 282 7.3 12.1 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) �.� ALPINE MODULE:CD30 UNIT: CD ConocePhillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 CE-CD30-111 2 OF 3 11 `REV DATE BY CK APP •DESCRIPTION REV DATE BY APP DESCRIPTION • 8 5/12/10 CZ GD C.A. UPDATED PER K100002ACS 9 4/11/11 CZ GD C.A. UPDATED PER K110003ACS N 0�•RJ% cj\il (59 I�'LL SI E D- � wCv7l �� ts i , ,f,IEL- ;,h4r,,r,"iv: CD3 S•ce 1 i°. `'. ii', I c' 1 'ICY LOCATION OF !1g1 "�' - THIS SURVEY 1'OA 1 1161Zi AO_ i f'-`' ALPINE SATELLITE DEVELOPMENT i i,^ VICINITY MAP NOT TO SCALE SNOUuDER OF PPD DES\GN CD-3 CD3R PAD EWTON D31 ,m� .40% m O \ R MnNK Av m"'�-`,SN000$es:•it - poop 57D AjR omro•-n-3 ,1„nou�: . • GENE t N N i K%M M U U U. • _ -_,,....§.0. '...'I CD3D �, �+',1, T'N o U 8$$ I$ 40000 �� CD3x R_\\\I\ S.i •u o S.0 2.d ��01�.111. •••• PRHCD-R- /',PAR COR ao 10 1,4, CD3 G VUE Il OIL N,ODu E Cc'O SKID vjFRENpuSE PLANT N ASPC MERY N RS ASN EQu PRTE 00 1300'00" ,J w Li 10 LCMF LEGEND: 0 Li Li 0 PROPOSED CONDUCTOR , w �0 N _N • EXISTING CONDUCTOR �➢ , , v Z. r0 0 N N Z 0➢� Z Z m 0 O 0 0 KUUKPIK 0 0 0 . w W LCMFW .... .......„07m.• 571 omce I ) Alpine Survey Office 1111r7. ALPINE MODULE:CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A 11/3/05 CE—CD30-111 1 OF 3 9 'REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION • s 6 4/17/10 CZ DB C.A. UPDA D PER K100003ACS 7 4/11/11 CZ D C.A. UPDATED PER K110003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, MARCH 2005 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD3-108, CD3-109, CD3-110, CD3-111 , 3/16/05, FB 2005-08 PGS 52-53; CD3-301, CD3-302, 3/19/05, FB 2005-09 PGS. 24-25; CD3-304, 4/16/05, FB 2005-12 PGS 35-37. CD3-303 2/10/06, FB 2006-03 PG 11. CD3-112, 2/23/06, FB 2006-05 PGS 29-31 . CD3-107, 3/26/06, FB 2006-09, PGS.9,25-27. CD3-305, CD3-106, CD3-113, CD3-114, CD3-115, CD3-116, CD3-117, 5/2/06, FB 2006-11 PGS 57-61; CD3-X18, 4/7/07, FB 2007-07 PG. 67; CD3-X98, CDX-99, CD3-X19, CD3-X20, CD3-X21, CD3-X22, CD3-X23, CD3-X24, 4/13/09, FB 2009-05 PGS. 70-72; CD3-X25, CD3-X26, CD3-X27, 4/16/10, FB 2010-03 PGS. 62-63; CD3-X28, 4/6/11, FB 2011-05 PG. 18; CD3-X29, CD3-X30, 4/8/11, FB 2011 -05 PG. 24; CD3-X31, CD3-X32, 4/10/11, FB 2011-05 PG. 29. SURVEYOR'S CERTIFICATE outos maii4 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED '7�� E"OF..q�gS ♦♦ AS-BUILT PRACTICETO REP ESE TSRAEYING IN THE SURVEY MADE TBYEOF MEE ORALASKA,ER MY DIRECT 4• `�.�'• ••••.9 ♦♦ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST �� ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE * 49th � � CORRECT. • / DATE: REGISTRATION NO, LS-5077 • I / ■ ♦ -2„ Donald G. Bruce o -ai ♦♦��%F• No. LS-5077 SI, • •••' �J • KUUKPIK ; ICF .0 _ _ 139 E.51.IAw. AMwa9t Alnlo 98503 (90])219 1830 Npine Office (B6])6]0.4]38 Alpine Survey Office 1110V ALPINE MODULE:CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-3 3-17-05 CE-CD30-111 3 OF 3 7 • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday,January 06, 2015 9:41 AM To: Loepp, Victoria T (DOA) Subject: RE:CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Victoria, I have provided a short and long answer to your question: The short: We are currently planning to perform the suicide squeeze pre-rig but in the event that the Alpine Resupply Road does not open on time,we will perform the squeeze with the rig after it has MIRU. The long: The suicide squeeze was originally planned to be performed with the rig; however, given the early Alpine Resupply Road prognosed opening date, we would actually prefer to perform the suicide squeeze pre-rig using a coiled-tubing unit and pumping unit. Here is a little background: • When planning for this well, we preferred to pump the suicide squeeze pre-rig, but we don't have a mobile pumping unit (for cement)out at Alpine to accompany the coiled-tubing unit—we would have to wait for the Alpine resupply road to open to Kuparuk. • Normally the Alpine Resupply road doesn't open until 01-Feb, so the we switched gears and planned to perform the suicide squeeze with the rig after wireline had set a bottom plug(to act as a base for the suicide squeeze cement) and shoot two sets of perforations. This plan had the least weather impact as we weren't sure when the Resupply Road would open. • Ice road building has been ahead of schedule with favorable weather and we have learned this week that the Alpine Resupply Road is prognosed to be open to travel 16-Jan-2015 —which gives us a good window to perform the work pre-rig as we can get a cement pumping unit over from Kuparuk. Regards, - Danny Danny Kane Senior Drilling Engineer ineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska,goA Sent: Tuesday, January 06, 2015 9:12 AM To: Kane, Danny Subject: [EXTERNAL]RE: CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Is suicide squeeze pre-rig or after MIRU? From: Loepp, Victoria T(DOA) Sent: Tuesday, January 06, 2015 8:49 AM i • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday, January 06, 2015 9:28 AM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Victoria, Questions answered below: • MPSP (Slightly Higher, FPP at the Heel Location has prognosed to have come up from 8.5 to 8.0ppg EMW). o Drilling Beneath 7-5/8"Window Cut at 13136' MD • 3388 psi ASP= [(FG*.052)-.1]*TVD (shoe), 3388psi = [(12.5*.052)-.1]*6160 • 2399 psi ASP = [(PP*.052*TVD (next casing point)]-(0.1*TVD(shoe)), 2399psi = [(8.5*.052*6822]-(0.1*6160) o Drilling Beneath 6.808" INTRM2 Liner Shoe at 15736' MD • 3752 psi ASP= [(FG*.052)-.1]*TVD (shoe), 3752psi = [(12.5*.052)-.1]*6822 • 2333 psi ASP= [(PP*.052*TVD (next casing point)]-(0.1*TVD(shoe)), 2333psi = [(8.5*.052*6822]-(0.1*6822) • BOP Test Pressure: 3500psi (Same As Approved PTD) • Injection Packer Depth: 15600' MD o The waiver granted last year was so that we could have improved wireline access to the packer. With the new well design&expandable liner,we will have to tractor no matter where we place the injection packer, so we have moved it back within 200' MD of the first pre-perforated pup. Regards, - Danny Danny Kane Senior Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepo( alaska.gov] Sent: Tuesday, January 06, 2015 8:49 AM To: Kane, Danny Subject: [EXTERNAL]CRU CD3-130(PTD 213-160, Sundry 314-686) Change of Approved Program Danny, 1. What is the MPSP?Same as original drilling permit? BOP test to? 2. What is the packer depth? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska 1 • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday, December 30,2014 3:09 PM To: Loepp,Victoria T(DOA) Subject: CRU CD3-130-Incoming Sundry Attachments: SUBMITTED -CRU CD3-130 Sundry Peri Alter Change Program.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I wanted to give you a heads up on an incoming Sundry to Perforate,Alter Casing,&Change Approved Program for CRU CD3-130. This well will be the only well drilled at CD3 this winter season and while contingent upon ice road construction,ConocoPhillips Alaska would like to move to CD3 as soon as the ice roads open; I know JG Samuell has been working with you in regards to a couple potential work-overs,these will be used as a schedule filler if Doyon 19 finishes up CD4-289 too early to move to CD3. I have included the pre-rig work as part of this sundry(E-line preparation for a suicide squeeze with the rig)and would appreciate a quick turnover if possible so that we can complete the necessary pre-rig work. Please feel free to call me if you would like to discuss the Sundry. I have attached a PDF copy(no signatures)of the Submitted Sundry; John Bell will be running the sundry over later today on behalf of Sharon. Regards, - Danny Danny Kane Senior Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 dannv.kane@conocophillips.com 1 p7-12 2/3 — )( O Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, December 09, 2014 9:47 AM To: 'Kane, Danny' Subject: RE: CD3-130 - Sundry to Re-Enter Well in Operations Shutdown (PTD 213-160) Danny, If the BHL or the proposed location of an objective formation is not changed by more than 500 feet laterally or vertically, then a new PTD is not required(20 AAC 25.015(b)(1)).A 10-403 Sundry,Change of Approved Program would be needed. The current status of the well is Operations Shutdown, not suspended. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it tc you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov From: Kane, Danny [mailto:Danny.Kane(aconocophillips.com] Sent: Tuesday, December 09, 2014 8:55 AM To: Loepp, Victoria T(DOA) Subject: CD3-130 - Sundry to Re-Enter Suspended Well Importance: High Victoria, CD3-130 PB2 was suspended in Q1 2014 after the intermediate casing was landed high and the attached Sundry Approval was received. ConocoPhillips plans to finish CD3-130 this ice road season by the following means: • Set Whipstock in the 7-5/8' Intermediate Casing at 13303' MD • Mill window&drill 6-3/4"x 8" hole (underreamed)to land in the Nechelik reservoir,—250' MD to the right of the CD3-130 PB2 heel location. • RIH, Cement, & Expand Expandable Liner from the Nechelik up into the Intermediate Casing • Drill 6-1/8" production hole from new heel location ("'250' MD to the right of the abandoned heel)to the originally-planned toe location. • Run originally-planned completion. • • Per the Sundry,we need to submit a new PTD or a 10-403 to finish this well. Given that we are essentially planning a sidetrack with close heel location &original toe location, I am assuming that we'll need a 10-403; however,can you provide clarification on what Type of Request this would be? Change Approved Program? Regards, - Danny Danny Kane Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 2 STATE OF ALASKA ALAAPOIL AND GAS CONSERVATION COMMON 3 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate rOther Suspend Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown f Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Pzrmit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 213-160 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20677-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364472,364471,372104,372105 ' CD3-130 and CD3-130PB1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): GR/Res/Neutron/Density . Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 15483 feet Plugs(measured) 176', 14153' • true vertical 6818 feet Junk(measured) none Effective Depth measured - 14153 feet Packer(measured) none true vertical 6503 feet (true vertical) none Casing Length Size MD TVD Burst Collapse Conductor 79' 20" 114' 114 Surface 3317' 10.75" 3354' 2480 Intermediate 14275' 7.625" 14309' 6549 RECEIVED APR 072014 Perforation depth: Measured depth: none True Vertical Depth: none AOGCC Tubing(size,grade,MD,and TVD) 3.5"kill string, L-80 EUE, @ 2299.75' MD RBDMS 4..MAY 14 2014 Packers&SSSV(type,MD,and TVD) no packer no SSSV 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 XXX Exploratory r Development r Service ro. Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations_XXX GSTOR r WIND r WAG r GINJ r SUSP SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-117 Contact Scott Brunswick a 263-4249 Email Scott.A.Brunswick(cr�conocophillips.corn Printed Name Scot Brunswick Title Drilling Engineer Signature `' lig* Phone:263-4249 Date S-- / /47 vF 6 //4/1 4" 16�6,� Form 10-404 Revised 10/2012 Submit Original Only WNS SVC • CD3-130 ConocoPhillips y $ Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status not(") MD(ftKB) Act Btm(ftKB) tpc 501032067700 FIORD NECHELIK SVC 80.19 15,346.78 15,483.0 –. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) –Rig Release Date HORIZONTAL-CO3-130.4!3/2014331;11 PM Last WO: 36.62 3/5/2014 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag: Rev Reason:NEW WELL,SUSPENDED postojl 4/3/2014 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread E CONDUCTOR 34" 20 19.124 36.6 115.6 115.6 94.00 H-40 Welded — HANGER;31.0 , Insulated Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1..Grade Top Thread : SURFACE 103/4 9.950 36.4 3,353.6 2,480.4 45.50 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 34.0 14,309.3 6,549.5 29.70 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection KILL STRING 31/2 2.992 31.0 2,299.8 2.021.2 9.30 L80 EUE Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(')_ Item Des Com (in) 31.0 31.0 0.00 HANGER TUBING HANGER FMC-ELASTOMER 3.958 XO REDUCING;34.634.8 34.8 0.00 XO 4-1/2"IBT BOX x 3-1/2"EUE PIN XO 2.992 REDUCING 2,298.5 2,020.3 50.44 MULE SHOE MULE SHOE 31/2" 3.125 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl •:/•.: Top(ftKB) (ftKB) I') Des Com Run Date ID lin) 14,167.0 6,507.2 71.69 Cement Cement Retainer set at 14167' 3/3/2014 ..:.a Retainer :i:Notes:General&Safety .:r JJ ✓ .m•1,• End Date Annotation '-•;:,t rr 4/3/2014 NOTE: INTERMEDIATE CASING STUCK @14,309 ,:':l + f l'-';.4/3/2014 NOTE:WELL SUSPENDED W/KILL STRING 1,: CONDUCTOR 34'Insulated:>`u+y 366..6-11R-tt5.6 rr 1; MULE SHOE;2,296.4 Ire 'r SURFACE;36.4-3353.6— I • Cement Retainer;14,167.0 I - INTERMEDIATE;34.0.14,309.3 I t a Conoc Phillips Time Log & Summary We!Mew Web Reporting Report Well Name: CD3-130 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/23/2014 12:00:00 AM Rig Release: 3/5/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 31/20/2014 24 hr Summary Rig down. Move pipe shed. Disconnect and secure mud complex. Move Ball mill and pump complex away from rig. Cantilever rig back and secure for move. Pickup legs and move rig away from well. 00:00 12:00 12.00 MIRU MOVE MOB P RD and secure rig for move from CD4-290 to CD3-130. Move pipe shed away from rig, attach tow hitch and Sow and commence move to CD3 staging area. Disconnect mud complex. Move ball mill and pump complex away from well. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM on rig move 12:30 00:00 11.50 MIRU MOVE MOB P Blow down rig. Cantilever floor back, pick up rig legs. Disconnect from high-line power. Back rig away from well and stage at edge of pad. Load mats to send to CD3 31/21/2014 Move pits, pipe shed&motor complex to CD3,sub base in route from CD4 to CD3 00:00 00:00 24.00 MIRU 'MOVE MOB P Move pits, pipe shed&motor complex to CD3, sub base in route from CD4 to CD3(elec hooked up cables between pits&motors, welder repaired steam return line wash outs, boilers on&steam running on pit side) 01/22/2014 Move sub to CD3&spot over well&skid floor, move in pits, motors complex&pipe shed, move ball mill, rig camp and shop to CD3&spot in place, hook up service lines and install knife valve on diverter. 00:00 00:00 124.00 MIRU MOVE MOB P Move rig f/CD4 to CD3-Finish moving sub to CD3-Moved ball mill- Spotted sub over well level rig&shim up-Skid rig floor into drilling position -Spot in place pit&motor complexes to sub-Moved camp& shop to CD3-Spot in place pipe shed&ball mill-hook up service lines&install knife valve on diverter- (Safety stand down with both crews, re-capped rig move, discussed HSE alerts from around the field, &talked about staying focused and working safe as we progress forward) 31/23/2014 Cont. RU after move, !load BHA tools in shed&bring on spud mud, install diveter line, prep shed for drill pipe, safety stand down, load shed w/5"DP&HWDP Page 1 of 46 • Time Logs II s Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 SURFA( DRILL RURD P Shim-up&level pipe shed-Spot air headter-Button up pipe shed-Cont. RU knife valve&surface riser. Accepted rig @ 0000 hrs, 1/23/2014 06:00 12:00 6.00 SURFA( DRILL RURD P Laod Schlumberger BHA tools in pipe shed-Cont. RU surface riser- Take on spud mud-Spot site control office-lay out high line cable 12:00 19:30 7.50 SURFA( DRILL RURD P Install diverter line&prep shed to load drill pipe 19:30 20:30 1.00 SURFA( DRILL SFTY P Safety stand down on recent incidents from around the field with all personnel on rig 20:30 00:00 3.50 SURFA( DRILL RURD P Install non skid mats on rig floor- P/U to floor BHA components-load pipe shed with 90 jts 5"NC50 drill pipe& 17 jts 5"HWDP 01/24/2014 Bring BHA componentes to rig floor-Function test diverter-PU&std back 5" NC-50 DP-PU 5" HWDP& std back-Slip&cut drill line-PU 7"NM DC's&std back-Cal blocks w/SLB-M/U clean out BHA&clean out conductor&48'new hole t/163' MD(spud well @ 18:45 hrs)-POOH&UD BHA#1 &M/U directional BHA#2 00:00 01:30 1.50 SURFA( DRILL PULD P Cont.to bring BHA components to rig floor 01:30 02:00 0.50 SURFA( DRILL OTHR P PJSM-On PU Dp&function test diverter 02:00 02:30 0.50 SURFA( DRILL OTHR P Remove roller from skate to pick up DP(needed for safe work area between iron rough neck&skate) 02:30 04:00 1.50 SURFA( DRILL OTHR P PU 3 jts. 5"DP-RIH&tagged ice plug @ 54'-Function test diverter- Hydril closed in 25 sec. &knife valve open 04:00 10:30 6.50 SURFA( DRILL PULD P Cont. PU 5"DP&std back in derrick (90 jts total-30 stds)-PU 15 jts 5" HWDP&std back 10:30 13:30 3.00 SURFA( DRILL SLPC P PSJM-Slip&cut drill line 60'- service top drive 13:30 15:30 2.00 SURFA( DRILL PULD P P/U&std back in derrick 1 HWDP& NMFC-Cal block height with SLB 15:30 16:15 0.75 SURFA( DRILL PULD P M/U clean out BHA as per SLB(Bit, bit sub, bottle neck XO) 16:15 16:45 0.50 SURFA( DRILL SFTY P Pre Spud Meeting 16:45 18:15 1.50 SURFA( DRILL OTHR P Hook up mud line under rig floor- Install valves on wellhead-Fill conductor with drill out mud from pit #6&check for leaks(32 bbls to fill)- Pressure test surface lines to 3500 psi (test good) 18:15 18:45 0.50 0 115 SURFA( DRILL DRLG P RIH with clean out BHA#1 on HWDP and tag ice plug at 54'-clean out conductor to 115'-Swap over to spud mud Page 2 of 46 •Time Logs 1111 s Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:15 0.50 115 163 SURFA( DRILL DRLG P Drill ahead new formation f/115'- t/163' MD-163'TVD with 450 gpm @ 320 psi-60 rpm @ 1.5 k trq- ADT 0.65 hrs 19:15 20:45 1.50 163 0 SURFA( DRILL TRIP P POOH& L/D clean out BHA#1 - Rack back HWDP in derrick 20:45 00:00 3.25 0 124 SURFA( DRILL PULD P M/U directional BHA#2(Mud motor, gyro, LWD, MWD) 01/25/2014 Cont. MU BHA#2-Shallow test tools on NMFC&pressured up&cannot circ-POOH checking for blockage -Bit plugged with gravel&scale-Shallow tested motor&motor weak-L/D motor&M/U new motor&BHA #3-Drill ahead f/168'-t/1051'MD 1043'TVD 00:00 00:45 0.75 124 163 SURFA( DRILL PULD P Cont. MU BHA#2 f/124'to 163'(1 NMDC) 00:45 04:30 3.75 163 0 SURFA( DRILL CIRC T Attempt to circ-string pressured up to 1600 psi-Std back NMDC's- Blow down TD-Break down BHA checking for obstructions, pumping& checking for flow, Break bit(jets plugged)Circ thru motor w/o bit @ 400 gpm @ 380 psi(motor weak) Blow down TD-Check pump screens on suctions(small amt. of gravel) &check for gravel under shakers(clean) Stood back BHA f/Btm stab above motor to top stab above UBHO in derrick 04:30 05:00 0.50 0 0 SURFA( DRILL CIRC T Flush motor(weak) LD motor 05:00 06:15 1.25 0 0 SURFA( DRILL CIRC T Latch up BHA f/derrick-flush w/ 500 gpm @ 70 psi-Blow down TD- std BHA back in derrick 06:15 08:45 2.50 0 163 SURFA( DRILL CIRC T PU back up motor-flush w/420 gpm ©30 psi(Good)MU bit-MU BHA f/ derrick-Obtain offset correction for gyro&MWD-RIH to 163' 08:45 12:00 3.25 163 401 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/163' to 401' MD 400'TVD ADT-1.42 hrs=ART-.97 hrs AST- .45 hrs- Footage 238' WOB 25/30 k, RPM-60, GPM 525 @ 970 psi 12:00 00:00 12.00 401 1,051 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/401' to 1051' MD 1043'TVD ADT-8.16 hrs=ART-2.31 hrs AST-5.85 hrs- Footage 650' WOB 25/30 k, RPM-60, GPM 500 © 1030 psi, PU-110, SO-115, ROT-115, DTQ-2.5 k, OBT-1 k 31/26/2014 Drilled 13 1/2"hole f/1051'to 2431 MD 2106'TVD Page 3 of 46 • Tame Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 1,051 1,632 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1051' to 1632' MD 1565'TVD ADT-4.92 hrs. =AST 3.48 hrs.ART 1.48 hrs. -Footage 581' WOB 20/25 K RPM 60 GPM 650 @ 1720 psi 12:00 00:00 12.00 1,632 2,431 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1632' to 2431' MD 2106'TVD ADT-5.69 hrs=ART-2.07 hrs AST-3.62 hrs- Footage 799' WOB 25/30 k, RPM-60, GPM 750 @ 2480 psi, PU-133, SO-120, ROT-125, DTQ-5 k, OBT-3.5 k (Wt up to 9.8ppg @ 2276') (Work through tight spot on back ream f/2295'to 2280') 01/27/2014 Drilled 13 1/2"hole f/2431'to TD of 3194'MD 2491'ND-Circ hole clean for 3 B/U-Flow check-Wiper trip back ream out of hole(/3030'to 1709' 00:00 12:00 12.00 2,431 2,934 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2431' to 2934'MD 2388'TVD ADT-7.48 hrs=ART-4.64 hrs AST 2.84 hrs-Footage 503' WOB 30/35 K RPM 60 GPM 750 @ 2790 psi 12:00 17:00 5.00 2,934 3,194 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2934' to 3194' MD 2491'TVD ADT-3.35 hrs=ART-2.54 hrs AST-0.81 hrs- Footage 260' WOB 30/35 k, RPM-60/70, GPM 750 ©2610 psi, PU-137, SO-115, ROT-125, DTQ-6.5 k, OBT-4 k (hole attempting to pack off after slides) 17:00 18:45 1.75 3,194 3,030 SURFA( DRILL CIRC P Circulate hole clean for 3 B/U with 750 GPM @ 2470 psi&70 RPM @ 4.5 k trq while racking back 1 stand every 30 min(flow check static) 18:45 00:00 5.25 3,030 1,709 SURFA( DRILL TRIP P BROOH f/3030'to 1709'with 700 GPM @ 2040 psi&60 RPM @ 4-5 k/trq(hole un-loading periodically, gravel&clay balls) Spot check survey @ 1748' 01/28/2014 Back ream out of hole f/1709'-to 700'-RIH f/700'to 3194'washing last stand to bottom-Circ hole clean while weighting up to 10.0 ppg-Shut down&repair sand chute on ball mill-Cont.to circ hole clean&weight up to 10.0 ppg-Flow Check-Pull out of hole f/3194'to 344' Page 4 of 46 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 1,709 700 SURFA( DRILL TRIP P BROOH f/1709'to 1250'with 700 GPM @ 1870 psi&60 RPM @ 3.5 k/trq-BROOH(/1250'to 700'with 500 GPM @ 860 psi&60 RPM @ 1.5 k/trq(slowed down last 2 stands and allowed hole to clean up) (hole un-loading periodically, gravel, sand,wood&clay balls) Spot check survey @ 1561' 05:00 08:00 3.00 700 3,194 SURFA( DRILL TRIP P B/D top drive-RIH f/700'to 3194' (worked through tight spot at 830', orientated high side&washed through with 450 GPM,worked back through without pumps&tight spot gone)-Washed last stand to bottom with 600 GPM @ 1790 psi&60 RPM @4.5ktrq 08:00 08:30 0.50 3,194 3,194 SURFA( DRILL CIRC P Circulate hole clean with 700 GPM @ 2280 psi&60 RPM @ 4.5 k trq& weight up system from 9.8 ppg to 10.0 ppg 08:30 11:30 3.00 3,194 3,194 SURFA( DRILL EQRP T Work pipe without pumping and without rotation while repairing/replacing sand chute on ball mill 11:30 13:30 2.00 3,194 3,194 SURFA( DRILL CIRC P Circulate hole clean with 600 GPM @ 1950 psi&60 RPM @ 5 k trq& weight up system from 9.8 ppg to 10.0 ppg 13:30 14:45 1.25 3,194 2,559 SURFA( DRILL TRIP P B/D top drive-Flow check(static)- POOH on elevators on TT f/3194'to 2559' 14:45 00:00 9.25 2,559 344 SURFA( DRILL TRIP P Pull out of hole f/2559'to 344'- Attempted to pull on elevators with tight hole&25-40 k max over pull- Overall back reamed out of hole with 500-650 GPM @ 1100-1800 psi& 60 RPM @ 3.5 -5 k/trq-(reduced flow rate to 500 GPM while pulling through permafrost)-Attempted to pull on elevators f/2465'-t/2349', 2181'-t11898',&f/1709'-t/1520'with tight spots)-Steady flow of cuttings on shakers while back reaming with no signs of hole un-loading until 550' -once hole un-loaded @ 550'saw large amounts of gravel&sand)- Spot checked JORPS surveys @ 2509', 1846', & 1793' 01/29/2014 BROOH f/344'to 300'-L/D directional BHA-Clear&clean rig floor-Dummy run 10 3/4"casing hanger-R/U Tesco-RIH 10 3/4"casing to 1180'-Attempt to work through tight spot-No success-POOH while L/D 10 3/4"casing f/1180'to 162'with pumps @ 3 bpm @ 100 psi 00:00 00:30 0.50 344 300 SURFA( DRILL TRIP P BROOH f/344'to 300'w/500 GPM @ 780 psi&60 RPM @ 1 k trq Page 5 of 46 S Time Logs Date From To Dur S. Depth-E. Death Phase Code Subcode T Comment 00:30 03:45 3.25 300 0 SURFA( DRILL PULD P Rack back 1 stand HWDP&NMFC- L/D BHA#3 as per SLB(Stabs, LWD/MWD, Gyro, &motor) 03:45 04:15 0.50 0 0 SURFA( CASING OTHR P Perform dummy run with 10 3/4" casing hanger(good) 04:15 06:15 2.00 0 0 SURFA( CASING RURD P PJSM&R/U Tesco casing running equipment 06:15 10:00 3.75 0 1,180 SURFA( CASING RNCS P RIH 10 3/4"45.5#L-80 BTC-M casing from surface to 1180'(30 jts total) (tight hole @ 710', 840', 1050, & 1160') Float Shoe(Ray Oil tools silver bullet) 2 jts casing-Float collar(Weatherford Model 402) 1 jt- All connections made up w/ BakerLoc-Fill pipe&check floats- Installed 1 bow spring centralizer per jts for first 500'&1 per 2 jts f/500'- TD 10:00 11:15 1.25 1,180 1,180 SURFA( CASING RNCS T Attempt tp work through tigh hole @ 1180'w/5-6 bpm, 150-170 psi, PU wt 110, SO wt 95 11:15 11:45 0.50 1,180 1,180 SURFA( CASING RNCS T Wait on ball mill(over-loaded with sand) 11:45 15:00 3.25 1,180 1,180 SURFA( CASING RNCS T Attempt tp work through tight hole @ 1180'w/2-8bpm, 80-230 psi, PU wt 110, SO wt 95 No success! 15:00 00:00 9.00 1,180 162 SURFA( CASING TRIP T PJSM, POOH while L/D 10 3/4" casing f/1180'to 162'w/pumps @ 3 bpm @ 100 psi 31/30/2014 Cont LD 10 3/4"casing&R/D Tesco-M/U clean out BHA-RIH to 1033'with hole trouble-Slide drill f/1033' to 1055'&attempt to get back in old hole-Pump psi increase f/1300 psi to 2600 psi&lost MWD signal- POH with pumps at 3 bpm @ 850 psi with hole trouble-L/D clean out assembly. 00:00 01:45 1.75 162 0 SURFA( CASING TRIP T L/D 10-3/4"casing from 162'to surface pumping 3 bpm 01:45 04:30 2.75 0 0 SURFA( CASING RURD T Blow down TD, R/D casing equip, M/U bails,elevators and bell guide, clear floor 04:30 04:45 0.25 0 0 SURFA( CASING SFTY T PJSM on M/U SLB BHA 04:45 07:45 3.00 0 200 SURFA( CASING PULD T M/U SLB clean out assy/Drlg assy to 200' 07:45 08:30 0.75 200 200 SURFA( CASING OTHR T Prep suction pit#6 with clean mud (excess gravel discovered in suction pit#5) 08:30 09:00 0.50 200 750 SURFA( CASING TRIP T RIH from 200'to 750', 100K up, 98K dwn 09:00 09:30 0.50 750 750 SURFA( CASING CIRC T Flush surface lines, pressure up to seat new#2 MP valves/seats, check pressures#1 MP erratic 09:30 10:15 0.75 750 750 SURFA( CASING CIRC T Shallow test MWD w/430 gpm, 900 psi, orient mtr HS Page6of46 • ITime Logs Date From To Dur S. Depth E. Depth Phase.r Code Subcode < T Comment 10:15 10:30 0.25 750 831 SURFA( CASING TRIP T RIH from 750'to 831',took weight 10:30 12:00 1.50 831 842 SURFA( CASING REAM T Work past ledge at 831'with 2 bpm, 20 rpm rolled off, RIH took wt at 840', could not roll off or work past. Increase flow rate to 445 gpm, 1270 psi, orient HS and drill through. String bouncing and through at 842'. 12:00 14:15 2.25 842 1,002 SURFA( CASING REAM T Wiped ledge at 840'to pass ok w/o pump oriented HS, cont RIH,took wt at 874', had to drill/Slide HS thru, wiped till pass ok w/o pump HS, RIH to 1002',took wt, PU and slide/work past w/2 bpm to std down at 1033', PU to wipe/ream area and could not get back thru. 14:15 16:15 2.00 1,002 1,055 SURFA( CASING REAM T Slide HS attempting to get thru/pass ledge,400 gpm, 1040 psi,appears drilling, holding bit wt to 1023', continue slide HS trying reaquire old hole. Slid to 1055'appearing to be drilling new hole, survey with GWD at 1008' MD, shows we lost 2.38° inclination from original hole. 16:15 18:00 1.75 1,055 1,055 SURFA( CASING CIRC T Consult town, decision made to drill 40'more and survey while town talks of options.Attempt to drill, observe excess pump pressure and no MWD signal. May have plugged pulsar. Attempt to clear source of inc presssure w/o success. Meanwhile decision made to POOH and cement back surface hole due to deteriating hole conditions. 18:00 21:15 3.25 1,055 196 SURFA( CASING TRIP T POOH with pumps f/1055'to 196' with 2-3 bpm @ 450-850 psi. - (attempted to pull on elevators f/750' to 658'with hole swabbing)-(various tight spots&hole attempting to pack off f/655'to 620') 21:15 00:00 2.75 196 29 SURFA( CASING PULD T PJSM-Lay down clean out assembly(rack back in derrick NMFC-UD stabs, LWD/MWD, Gyro &motor) 01/31/2014 L/D clean out BHA-Clear&clean floor-Clean pits&shakers-M/U 3 1/2"stinger on 4" DP& RIH to 1058'- Circ&cond for cement-Pump 1st stage cement plug(CIP @ 18:10 hrs)-POOH f/1058'to 473'-Circ 2 B/U 400 GPM @ 200 psi-POOH w/4"DP&3 1/2"stinger assembly-RIH 4" DP from cement job&circ to clear string-W.O.C. 00:00 00:45 0.75 29 0 SURFA( CASING PULD T Continue L/D clean-out BHA#4 00:45 07:15 6.50 0 0 SURFA( PLUG OTHR T Clean pits, prep to P/U 4" DP cement string, Dowell continue hauling cement 07:15 09:15 2.00 0 0 SURFA( PLUG OTHR T PJSM, change out TD saver sub to 4"XT-39 and die blocks 09:15 09:45 0.50 0 0 SURFA( PLUG SFTY T PJSM on picking up cemnt string Page 7 of 46 Titne Logs 411 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 14:45 5.00 0 1,058 SURFA( PLUG TRIP T MU 1 bent Jt 3.5"tubing (hole finder) w/bull nose mule shoe and XO, RIH on 4"XT39 DP to568',took wt at 551', orient and got thru, cont to RIH f/568'to 1058'(worked thru various hard spots f/568'to 738'-rotating pipe&pumping w/2 bpm @ 210 psi) 14:45 16:15 1.50 1,058 1,058 SURFA( PLUG CIRC T Circ&condition mud/hole for 1st stage cement plug w/6.8 bpm @ 300 psi 16:15 16:45 0.50 1,056 1,056 SURFA( PLUG PULD T PJSM, L/D single joint 4"DP& P/U 15'pup joint, RIH back to 1056'& R/U head pin&cement hose 16:45 18:30 1.75 1,056 1,056 SURFA( PLUG CMNT T PJSM for cement job while pumping w/5 bpm @ 300 psi,test cement lines t/3000 psi, pump 1st stage cement job(40.2 bbls 11.5 ppg mud push, 142.2 bbls(859 sks)(.93 yield) 15.8 ppg AS1 cement, 1.2 bbls 11.5 ppg mud push, &chase w/5.4 bbls 10.0 ppg spud mud from rig)flush lines, check for u-tube(balanced) CIP @ 18:10 hrs. Full returns. 18:30 19:00 0.50 1,056 473 SURFA( PLUG TRIP T R/D head pin&cement hose, L/D 15' pup joint& POOH on elevators on TT f/1056'to 473'(6 stands DP total) 19:00 19:30 0.50 473 473 SURFA( PLUG CIRC T Pump 35 bbl Biozan/Nut Plug sweep &circ 2 B/U w/400 GPM @ 200 psi (no contaminated mud or cement seen at surface) 19:30 20:45 1.25 473 0 SURFA( PLUG TRIP T B/D top drive&POOH on elevators on TT f/473'to surface, UD 2 joints 4"DP, C/O elevaotrs to 3 1/2"& L/D 3 1/2"stinger&mule shoe 20:45 22:30 1.75 0 0 SURFA( PLUG TRIP T C/O elevators to 4", RIH 3 stands at a time the remaining 6 stands of drill pie used for cement job, each 3 stands were circulated w/350 GPM @ 80 psi&flushed prior to racking back in derrick. 22:30 00:00 1.50 0 0 SURFA( PLUG WOC T Clear&clean floor,W.O.C.,work on P.M.'s&work orders 02/01/2014 W.O.C. 1st stage-RIH w/cement stinger&tag good cement @ 839'-Pump 2nd stage cement&POH to 114'-Pump Biozan/Nut Plug sweep&circ clean-RIH 2 stds 1 at a time and flush DP-M/U mule shoe, 3 1/2"stinger stinger& 1 std DP-Flush stack, Install TIW-W.O.C. 00:00 01:00 1.00 0 0 SURFA( PLUG WOC T Wait on cement, monitor well on trip tank no G/L. Perform work orders 01:00 01:15 0.25 0 0 SURFA( PLUG TRIP T RIH one stand to 90', M/U FOSV 01:15 05:00 3.75 0 0 SURFA( PLUG WOC T Wait on cement, monitor well on trip tank, no G/L, perform work orders on MP's, RF tuggers, DC clamps, elevators,shakers and degasser. Service Dwks Page 8of46 410 • Time Logs , Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 07:15 2.25 0 750 SURFA( PLUG TRIP T PJSM, M/U bull nose, bentjt and RIH t/314', (Calc disp 1.86 bbls, actual disp 2 bbls)M/U T/D and wash in hole w/1.5 bpm @ 10 psi to 750'.(Took wt at 662',678', 695' worked thru by orienting bentjt.) 07:15 08:00 0.75 750 750 SURFA( PLUG CIRC T Circ and confirm not washing thru soft cement, CBU x2 w/6 bpm @ 90 psi with no indication of cement. 08:00 08:30 0.50 750 839 SURFA( PLUG TRIP T Cont. RIH f/750'to 839'w/1.5 bpm @ 10 psi,tag w/5 K,work string 1/4 turn at a time w/SO to 12 k max and confirm good cement 08:30 09:00 0.50 839 786 SURFA( PLUG CIRC T Circ B/U w/7 bpm @ 130 psi(pH increase on B/U)POH f/839 to 786' & B/D T/D 09:00 10:00 1.00 786 835 SURFA( PLUG PULD T PJSM, M/U space out pup&single joint, RIH to 835', R/U head pin& cement line 10:00 13:15 3.25 835 835 SURFA( PLUG CIRC T Circ&cond for cement job w/2 bpm @ 70 psi 13:15 14:30 1.25 835 835 SURFA( PLUG CMNT T PJSM for cement job,test cement lines to 2500 psi, pump 2nd stage cement job(33 bbls 11.5 ppg mud push, 200.1 bbls(1281 sks)(.93 yield) 15.7 ppg AS1 cement, 2.5 bbls 11.5 ppg mud push)flush lines, check for u-tube(suction on DP)CIP @ 14:30 hrs. Full returns. 14:30 15:15 0.75 835 114 SURFA( PLUG TRIP T R/D head pin&cement line, POOH f/835'to 114' 15:15 15:30 0.25 114 114 SURFA( PLUG CIRC T Pump Biozan/Nut Plug sweep and circ clean w/10 bpm @ 100 psi w/20 RPM @ 0 k trq (no contaminated mud or cement to surface) 15:30 16:15 0.75 114 0 SURFA( PLUG PULD T B/D T/D, rack back 1 stand 4"DP, breal off mule shoe&L/D 3 1/2' stinger 16:15 20:30 4.25 0 0 SURFA( PLUG WOC T W.O.C., install ring for riser,work on work orders, inspect DP for cement, RIH 2 stands of DP 1 at a time and flush w/9 bpm 20:30 22:00 1.50 0 125 SURFA( PLUG WOC T PJSM, M/U mule shoe on 3 1/5" stinger&M/U 1 stand 4"DP, flush annular and riser, RIH 1 stand to 125', B/D T/D, install TIW 22:00 00:00 2.00 125 125 SURFA( PLUG WOC T W.O.C., scrub&clean rig,work on work orders&P.M.'s X2/02/2014 W.O.C.2nd stage cement plug(work on work orders)-RIH w/3 1/2"stinger&4"DP washing @ 1.5 bpm and tag top of cement @ 697'-Circ&cond for cement job-Pump 3rd stage cement plug-POOH&circ conductor clean-W.O.C.-RIH w/3 1/2"stinger&4" DP to 135'-Trouble shoot mud pump#2-Cont RIH w/ pumps @ 1.5 bpm and tag top of cement @ 484'-Circ&cond for cement job. Page 9 of 46 • Tipte Logs II Date From To Dur ' S. Depth E. Depth-Phase 'Code Subcode T Comment 00:00 05:00 5.00 125 125 SURFA( PLUG WOC T W.O.C., monitor well on trip tank no G/L, Drk insp shackles, RF equip inventory,work orders on travel blocks, clean dwks, pit room, beam clamp inventory/insp, lift chain inventory/insp,fall-harness inv/insp, PJSM on RIH 05:00 07:15 2.25 125 697 SURFA( PLUG TRIP T R/D FOSV, RIH f/125'to 220', M/U T/D and wash down w/1.5 bpm, 20 psi to 697', could not work past Work past spots at 377', 570', 617', 681') 07:15 07:30 0.25 697 692 SURFA( PLUG TRIP T Rack back stand to 692' 07:30 08:30 1.00 692 692 SURFA( PLUG CIRC T Circ and condition mud, 6 bpm, 100 psi. Lots of mud push observed at shakers and pH increase to peak of 11 at 190 bbls pumped, continue pump and condition thick mud 08:30 09:00 0.50 692 692 SURFA( PLUG RURD T PJSM, R/U headpin, cement hose 09:00 10:30 1.50 692 692 SURFA( PLUG CMNT T PJSM, Dowell pump 40 bbls Mud Push at 11.5 ppg, 201 bbls 15.7 ppg AS1 cement(1214 sks)(.93 yield), 1 bbl Mud Push at 11.5 ppg, rig pump and balance with 3.3 bbls 10.0 ppg mud. (Used 250%excess) Pumped job at 5 bpm, no losses to hole. CIP at 1015 Hrs. Open head pin, observe plug balanced. Mud returns became thicker and thicker with pH increase to 12 by end of job.Appears contaminated interface. 10:30 11:00 0.50 692 112 SURFA( PLUG TRIP T POOH f/692'to 112'at 1600'/hr 11:00 12:00 1.00 112 26 SURFA( PLUG CIRC T Wash/flush conductor and bag f/112' to 26'with mud at 8 bpm, 20 psi, 10 rpm, .3k tq 12:00 12:30 0.50 26 0 SURFA( PLUG RURD T PJSM, C/O elevators&UD 3 1/2" stinger joint&mule shoe 12:30 14:00 1.50 0 0 SURFA( PLUG WOC T RIH 7 stds(1 std at a time)&flush with 9 bpm 14:00 14:30 0.50 0 114 SURFA( PLUG WOC T M/U mule shoe&3 1/2"stinger joint on 1 std of 4"DP&RIH t/114' 14:30 18:00 3.50 114 114 SURFA( PLUG WOC T W.O.C., clean cellar&rig floor, clean 10 3/4"centralizers& L/D, inspect come-a-longs on rig& re-install 18:00 18:30 0.50 114 114 SURFA( PLUG TRIP T Attempt to wash down to tag cement f/114'to 135', mud pump#2 not stroking properly, POOH t/114', B/D T/D 18:30 20:00 1.50 114 114 SURFA( PLUG RGRP T Trouble shoot mud pump#2(check valves&seats, clean suction screens, clean suction chamber, clean discharge chamber, &back flush suction w/H2O) Page 10 of 46 Tine Logs 1111 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 114 484 SURFA(PLUG TRIP T M/U T/D and wash down w/1.5 bpm, 20 psi f/114'to 484', could not work past 484'(top of cement)(Work past spots at 181', 354',408', &427') 21:30 00:00 2.50 484 484 SURFA( PLUG CIRC T Circ&cond mud for cement job w/9 bpm @ 100 psi while reciprocate pipe(thick contaminated mud back to surface) 02/03/2014 Circ&cond mud for cement job-Pump 4th stage cement plug(CIP @ 230 hrs)-POOH&circ conductor clean-Flush stds of DP-L/D cement string-C/O TD saver sub-M/U BHA-Function test diverter system- M/U BHA-Pre Spud Mtg-Spud in&tag cement @ 176'-Shut down&work on shakers-Resume drilling ahead f/176'to 231'MD 231'TVD-(Drilling became much smoother at 196')Mud system locked up-Attempt to circ out thick contaminated mud-POOH into conductor f/231'to 105' 00:00 00:45 0.75 484 483 SURFA( PLUG PULD T PJSM for cement job, L/D single joint 4"DP&P/U 10'4"pup joint, & RIH t/483' 00:45 01:30 0.75 483 483 SURFA( PLUG CIRC T Circ&cond mud for cement job(wait on ball ill to empty fluids and take on H2O) 01:30 02:45 1.25 483 483 SURFA( PLUG CMNT T Turn over to Dowell,test cement lines to 2500 psi, pump 40.4 bbls Mud Push at 11.5 ppg, 202.2 bbls 15.7 ppg AS1 cement&3.2 bbls Mud Push at 11.5 ppg, pumped job at 5 bpm, no losses to hole& reciprocate pipe, CIP at 230 hrs. (with 60 bbls cement pumped/100 bbls total had thick contaminated mud back to surface,with150 bbls cement pumped/190 bbls total had mud push back at surface mixed with gravel, sand&wood, continued to have mud push at surface for remainder of cement job)flush cement lines&R/D head pin& cement hose 02:45 03:15 0.50 483 112 SURFA( PLUG TRIP T POOH @ 1600'-1800'per hr f/483' to 112' 03:15 04:15 1.00 112 98 SURFA( PLUG CIRC T M/U T/D&circulate clean conductor, diverter, &riser f/112'to 8'w/8 bpm @ 30 psi&10 RPM @ 3 k trq (10bbls into circulating had green cement at surface, &continued to circulate until conductor was clean) RIH to 98' 04:15 05:15 1.00 98 98 SURFA( PLUG CIRC T @ 98'M/U stands 2,3,4,5 one at a time to stump&flush w/9 bpm @ 40 psi 05:15 06:00 0.75 98 0 SURFA( PLUG PULD T POOH f/98'to rig floor,flow check (static), B/D T/D, M/U tubing tongs& break out 3 1/2"stinger&mule shoe, R/D tubing tongs 06:00 07:15 1.25 0 0 SURFA( PLUG OTHR T PJSM, clean&clear floor, L/D tubing equipment&4"pup joints, monitor well on TT Page 11 of 46 I • •Tine Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T, Comment 07:15 09:00 1.75 0 0 SURFA( PLUG PULD T L/D 4"DP via mouse hole(9 stds) SIMEOPS-build drill out mud& clean pits 09:00 12:45 3.75 0 0 SURFA( PLUG RGRP T PJSM, C/O grabber&saver sub on T/D to 5"NC50, SIMEOPS-clean pits,work on mud pump#1 suction screen, discharge screen, &suction chamber, C/O draw works blower motor 12:45 15:30 2.75 0 95 SURFA( DRILL PULD T PJSM, M/U BHA#5 as per SLB to 95'(bit, motor, stabilize, Gyro Pulse, LWD/MWD) 15:30 16:30 1.00 95 95 SURFA( DRILL SEQP T PJSM, Break diverter line&function test annular&knife valve(annular 23 sec full closure @ 1100 psi) 16:30 18:00 1.50 95 105 SURFA( DRILL PULD T Cont. M/U BHA#5 as per SLB f/95' to 105'(NM stabilizer&bottle neck XO) 18:00 18:45 0.75 105 105 SURFA( DRILL SFTY T Pre-Spud Safety Meeting w/all rig personnel&service companies 18:45 19:00 0.25 105 105 SURFA( DRILL OTHR T Fill riser&flush mud lines&check for leaks 19:00 19:30 0.50 105 176 SURFA( DRILL TRIP T RIH f/105'&tag top of cement @ 176', bring on pumps&stage pumps up to 450 GPM @ 590 psi(only 2 shakers working&not able to handle flow)POOH back into conductor 19:30 21:00 1.50 176 176 SURFA( DRILL RGRP T Work on shakers, replacing decking on shaker#1 21:00 21:30 0.50 176 201 SURFA( DRILL DDRL T Drill ahead f/176'to 201'w/450 GPM @ 890 psi w/60 RPM @ 1 k trq w/1 -2 k WOB ADT 0.15(f/190'to 200' appeared to be off plug and drilling new formation, swapped over to spud mud with no issues) 21:30 22:30 1.00 201 201 SURFA( DRILL OTHR T P/U 1 std HWDP&shallow test MWD&Gyro Data 22:30 22:45 0.25 201 231 SURFA( DRILL DDRL T Drill ahead f/201'to 231'w/450 GPM @ 890 psi w/60 RPM @ 1 k trq w/1 -2 k WOB ADT 0.12-Total drill time 0.27(started seeing thick contaminated mud back at surface& mud system locked up) 22:45 23:00 0.25 231 231 SURFA( DRILL CIRC T Attempt to circulate out thick mud with 168 GPM @ 350 psi w/20 RPM (no success)decision made to POOH to inside conductor 23:00 00:00 1.00 231 105 SURFA( DRILL TRIP T POOH f/231'to 105', Racked back NMFC 105 SURFA( 32/04/2014 Circ and condition mud at 105', precautionary ream in hole to 231', reducing rate as needed to handle and condition thick mud out, drill/slide from 231'to 241',circ out thick contaminated mud, drill/slide to 251', circ out thick contaminated mud, cont drilling(Much harder from 247'holding 6-8K wob), cont drilling with no more contaminated mud. Continue slide/rotary drilling to 1,186'md. ( Page 12 of 46 • Time Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 105 105 SURFA( DRILL CIRC T Circulate and condition contaminated mud at 250 gpm, 350 psi. SIMOPS= Work on#2 MP valves 04:00 06:00 2.00 105 231 SURFA( DRILL CIRC T Precautionary ream in hole from 105' to 231'at 300 gpm,460 psi, 20 rpm, 0.5k tq circulating out thick contaminated mud. 06:00 12:00 6.00 231 474 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/231' to 474' MD 473'TVD ADT-3.32 hrs=ART-0.29 hrs AST-3.03 hrs- Footage 243' WOB 20 k, RPM-30, GPM 450 @ 1020 psi, PU-82, SO-82, ROT-82, DTQ-1 k, OBT-1 k 12:00 00:00 12.00 474 1,186 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/474' to 1,186' MD , 1,161'TVD ADT-8.26 hrs=ART-1.52 hrs AST-6.74 hrs- Footage 712' WOB 30 k, RPM-60, GPM 500 @ 1280 psi, PU-110, SO-110, ROT-110, DTQ-4 k, OBT-2 k 02/05/2014 Continue to rotate/slide drill to 1,503'md.Wash and ream to smooth out hole, continue to rotate/slide drill to 2,730' and 00:00 03:45 3.75 1,186 1,503 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/1,186' to 1,503' MD , 1,438'TVD ADT-2.63 hrs=ART-0.53 hrs AST-2.10 hrs- Footage 317' WOB 30 k, RPM-60, GPM 500 @ 1280 psi, PU-110, SO-110, ROT-110, DTQ-4 k, OBT-2 k 03:45 05:45 2.00 1,503 1,503 SURFA( DRILL REAM T PU to 1,369'md.Wash and ream to bottom working thru dogleg with 575 gpm, 60 rpm, 3-5K TQ-okay. 05:45 12:00 6.25 1,503 1,879 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/1,503' to 1,869' MD , 1,732'TVD ADT-1.78 hrs=ART-0.94 hrs AST- 0.84 hrs- Footage 376' WOB 30 k, RPM-60, GPM 600 @ 1,670 psi, PU-120, SO-107, ROT-115, DTQ-4.5 k, OBT-3 k 12:00 00:00 12.00 1,879 2,730 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/1,879' to 2,730'MD,2,247'TVD ADT-6.41 hrs=ART-2.99 hrs AST- 3.42 hrs- Footage 851' WOB 25 k, RPM-60, GPM 650 @ 2,240 psi, PU-125, SO-108, ROT-120, DTQ-7 k, OBT-6 k 32/06/2014 Drill to TD of surface hole section at 3,366'tvd/2,485'tvd. Flow chk-static. CBU 3x, increasing mud wt to 10.0 ppg. BROOH to base of permafrost at 780 gpm and 60 rpm. Slow pumps to 500 gpm and 40 rpm and BROOH to HWDP. CBU 4x, flow-chk-static. POOH and stand back HWDP, LD BHA. Page 13 of 46 Time Logs , Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 12.00 2,730 3,295 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/2,730' to 3,295' MD , 2,457'TVD ADT-7.81 hrs=ART-6.29 hrs AST- 1.52 hrs- Footage 565' WOB 25/30 k, RPM-60, GPM 780 @ 3,040 psi, PU-128, SO-108, ROT-118, DTQ-6.5 k, OBT-4.5 k 12:00 12:30 0.50 3,295 3,366 SURFA( DRILL DDRL T Drilled 13 1/2"hole w/motor f/3,295' to 3,366' MD , 2,485'TVD ADT-0.75 hrs=ART-0.75 hrs AST- 0.0 hrs- Footage 71' WOB 25/30 k, RPM-60, GPM 780 @ 3,010 psi, PU-128, SO-108, ROT-118, DTQ-6.5 k, OBT-4.5 k 12:30 12:45 0.25 3,366 3,366 SURFA( CASING OWFF T Flow check-static 12:45 14:15 1.50 3,366 3,106 SURFA( CASING CIRC T CBU 3x at 780 gpm, 2,900 psi, 60 rpm, TQ=5.5K. Stand back 1 stand/30 min to 3,106'md. 14:15 19:15 5.00 3,106 1,315 SURFA( CASING REAM T Flow-chk-static. BROOH from 3,106'to 1,315'and @ 780 gpm, 2,550 psi, 60 rpm and Tq=3.5K 19:15 21:15 2.00 1,315 756 SURFA( CASING REAM T BROOH thru permafrost from 1,315' to HWDP at 756'with 500 gpm, 1,240 psi,40 rpm,TQ=2.5K. Slow pulling speed to 200'/hr from 940'to 756'and CBU 4x. Heavy clay in the returns but very little gravel. Orient to high side for pulling. 21:15 21:45 0.50 756 756 SURFA( CASING OWFF T Blow down TD, flow-chk-static 21:45 23:45 2.00 756 105 SURFA( CASING TRIP T POOH on Trip tank from 756 to 105'. Tite spot at 686-684'and(OP= 18K Ib). Work thru 3x and pull clean. Well static. Total losses on trip= 235 bbl (most went over the shakers with the heavy clay returns) 23:45 00:00 0.25 105 105 SURFA( CASING SFTY T PJSM on LD BHA. 02/07/2014 LD BHA, Clear floor, RU Tesco, Run 10-3/4"casing to 3,354' md. RU csg equip, C&C mud for cementing. PJSM for cement job. 00:00' 02:15 2.25 105 i 0 SURFA( CASING PULD T LD BHA 02:15 03:15 1.00 0 0 SURFA( CASING OTHR T Clear and clean floor 03:15 05:15 2.00 0 0 SURFA( CASING RURD T PJSM, RD bails, elevators, RU Tesco CDS and slips 05:15 06:00 0.75 0 0 SURFA( CASING RURD T Rearrange pipeshed with new shoe track with hydraforms installed, clean threads and install torque rings Page 14'of 46 • •Time Logs • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 06:00 09:30 3.50 0 829 SURFA( CASING RNCS T PJSM, RIH w/Silver bullet FS, 2 Jts, Weatherfrd FC, 10-3/4"45.5#L80, R2, BTCM casing with TQ rings installed. MU to 15K ft-lb of torque. Ran 1 Hydroform cent on jts#1-14, ran 1 Hydroforn cent on every other jt #15-68 and 1 bowspring on every other#70-80. Used Run&Seal thread dope on every pin connection.Work through spots at 587', 619'OK, stopped at 829' 09:30 10:00 0.50 829 850 SURFA( CASING CIRC T Work spot at 829', attempt work through orienting silver bullet, no success, establish circulation at 1.6 bpm, 30 psi, attempt wash through no success, apply rotation at 2 rpm, 4K tq, rotated through slowly ok to 850' 10:00 10:45 0.75 850 1,180 SURFA( CASING RNCS T Run 10-3/4"casing f/850' to 1180' 10:45 11:00 0.25 1,180 1,420 SURFA( CASING RNCS P Run 10-3/4"casing f/1180' to 1420' Held Kick while tripping drill 11:00 12:00 1.00 1,420 1,420 SURFA( CASING CIRC P Circulate, stage pump rate up to 5 bpm, 140 psi. Total 2 BU calculated. A lot of clay, gravel and sand. 12:00 13:30 1.50 1,420 2,027 SURFA( CASING RNCS P Continue RIH w/10-3/4"45.5#L80, BTCM casing from 1,420'to 2,027' md.Work through spots at 1,515', 1,590', 1,600', 1,717'and 1,857'. 13:30 14:30 1.00 2,027 2,027 SURFA( CASING RNCS P PJSM on changing casing jts. POOH and LD 2x bad casing joints (bad collars on joint#50). Change out joints#50 and 51. 14:30 18:30 4.00 1,420 3,354 SURFA( CASING RNCS P Continue RIH w/10-3/4"45.5#L80, BTCM casing from 1,984'to 3,360' md. MU casing hangar and land. 18:30 20:15 1.75 3,354 3,354 SURFA( CASING CIRC P CBU with 1.5-7 bpm,240-600 psi. PJSM on LD casing equip. 20:15 22:00 1.75 3,354 3,354 SURFA( CASING RURD P RD TESCO casing equip, clean floor and tools, blow down TD, PU long bails, install slips, install XO and cement head, install long bails, ru cement lines. SPRs: MP#1 2 bpm=230 psi, 7 bpm=330 psi MP#2 2 bpm=220 psi, 7 bpm=320 psi 22:00 00:00 2.00 3,354 3,354 SURFA( CASING CIRC P C&C mud for surface cement job at 7 bpm,600-450 psi. PU at start 165K, SO=118K, after circ PU= 150K, S0= 110K. Reciprocate pipe throughout. ?age c 15 of 46 • • Tune Logs , Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 02/08/2014 24 hr Summary Perform surface cement job, bump plug, check floats ok, RD Cmt equip, ND diverter,flow lines, riser, annular and conductor adapter, perform corrosion mitigation cement job on upper 20'of 20"x 10.75"annulus, NU wellhead, BOPE 00:00 03:30 3.50 3,354 3,354 SURFA( CEMEN'CMNT P Rig pumped 100 bbls mud with nut plug marker added followed by 35 bbls Biozan/Nut plug spacer. Dowell pressure test lines to 2500 psi, pump 53.2 bbls 10.3 ppg Mud Push II at 5.8 bpm, 300 psi, drop bottom plug, mix and pump 472 bbls, 11.02 ppg ALC(1373 sks)(1.93 yield)at 6.8 bpm, 700 to 300 psi, nut plug observed at surface, switch to and pump 64 bbls 15.8 ppg tail cement (310 sks)(1.16 yield)at 4.5 bpm, 100 psi. Stop reciprocating remainder of job. Drop top plug, kick out with 20 bbls water. Rig displace with mud at 6.7 bpm, 330 to 800 psi. Bump on schedule with 500 psi over FCP. CIP at 0321 hrs. Bleed off and check floats holding. Full returns throughout job,65 bbls cement returned to surface. 03:30 04:00 0.50 0 0 SURFA( CEMEN"OWFF P Monitor well, dropped slightly SIMEOPS; PJSM and RD Cmt equip 04:00 04:45 0.75 0 0 SURFA( CEMEN-RURD P RD Csg equip, elevators,XO, clean and LD equip beaver slide 04:45 06:30 1.75 0 0 SURFA( CEMEN'RURD P PJSM, FMC back out landing jt and LD, RD casing bails and LD 06:30 11:00 4.50 0 0 SURFA( CEMEN-NUND P PJSM,drain riser, ND diverter, flowline, riser, annular preventer and conductor adapter. 11:00 12:00 1.00 0 0 SURFA( CEMEN RURD P PJSM, RU thunder Quad flush tool and cement line 12:00 12:15 0.25 0 0 SURFA( CEMEN"SFTY P PJSM on cement job Page 76 off 46 • •Time Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 14:30 2.25 0 0 SURFA( CEMEN'CMNT P Pressure test tool to 1500 psi- Wash down f/top of fluted hanger to 20'@ 1 bbl/min,20 psi, PU and insert into next set flutes,wash down 20'at 1 bbl/min, increase rate to 4 bpm,270 psi pumped 26 bbls water to clean out surface cement f/20"x 10 3/4"annulus-Mixed&pumped 6 bbls 15.8 ppg Qannik blend with cement to 4"outlet below casing hanger @ 1.2 bbl/min, 100 psi- pulled up w/jetting tool to 4"outlet 2' below hanger-while pumping an additional 4 bbls 15.8 ppg Qannik blend-Flush lines with fresh water into cellar-Blow down lines-Vac out cmt returns&clean up water w/ Super Sucker-5 bbls cmt in place in 20"x 10 3/4"annulus-Pulled TQF tool back to rig floor and RD, wrapped hanger with plastic to prevent water entry-installed 4"plug in outlet 14:30 14:45 0.25 0 0 SURFA( CEMEN'SFTY P PJSM for NU wellhead and BOPs 14:45 16:00 1.25 0 0 SURFA( CEMEN-NUND P NU wellhead,test to 1,000 psi for 10 min-ok. 16:00 20:15 4.25 0 0 SURFA( CEMEN'NUND P NU BOPs, hook up accumulator lines. Change out saver sub to DS50 pin, hook up choke line. 20:15 20:30 0.25 0 0 SURFA( CEMEN SFTY P PJSM for PU 5"DP 20:30 00:00 3.50 0 0 SURFA( CEMEN"PULD P PU 41 Jts of 5"DS50 DP and break-in connection: MU connections to 34,400 ft-lb, unscrew, inspect, re-dope with Run and lube DP dope, MU again to 34,400 ft-lb, unscrew, inspect, re-dope and MU to 43,000 ft-lb. Stand back in derrick. 02/09/2014 Finish PU 5" DP. RU and test BOPE. RD. PU remaining 43 stands of 5"DP. Note:Test witnessed by Mr. Bob Noble of the AOGCC 00:00 01:30 1.50 0 0 SURFA( CEMEN'PULD P Continue PU 5"DS50 DP and break-in connection: MU connections to 34,400 ft-lb, unscrew, inspect, re-dope with Run and lube DP dope, MU again to 34,400 ft-lb, unscrew, inspect, re-dope and MU to 43,000 ft-lb. (51 Jts total needing breaking in). Stand back in derrick. 01:30 02:00 0.50 0 0 SURFA( CEMEN'PULD P PJSM, Shuttle 6 stds of HWDP from Off driller side to driller's side of derrick to make room for DS50 DP. 02:00 03:00 1.00 0 0 SURFA( CEMEN-PULD P PJSM, Rack back 17 stds of DS50. 03:00 10:00 7.00 0 0 SURFA( CEMEN"PULD P Continue to PU and rack back 5" DS50 DP (67 stds total). Page 17 of 46 • 1110 Tiine Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 0 0 SURFA( CEMEN'RURD P PJSM. Pull 10"ID Wear bushing and set 5"test plug and tool joint. Fill stack, choke manifold and Kill line with water. 12:00 12:15 0.25 0 0 SURFA( CEMEN-SFTY P PJSM for BOP testing 12:15 19:30 7.25 0 0 SURFA( CEMEN-BOPE P Test Annular preventer to 250/2,500 psi for 5 min ea. Test choke manifold valves#1 -16, FOSV, 5"dart valve, 4" Demco, all to 250 PSI/3,500 psi for 5 mins each. Test Upper 3'/z"x 6"variable pipe rams, HCR choke and kill valves to 250 PSI/3,500 psi for 5 mins each. Test Lower 3'/2"x 6" variable pipe rams with 5"test joint to 250 PSI/3,500 psi for 5 mins each. Gas alarms tested. Perform accumulator test. System pressure before=2,950 psi, after= 1,450 psi., 34 secs recovery 200 psi, 172 secs to 3,000 psi. Flush poor boy degasser.Test super choke and manual choke to 1100 psi(checking auto choke bean performance)with 1-2 bbl/min and 1,100 psi. Blow down lines. Function Blind rams from remote panel. All tests were charted. Bob Noble of AOGCC witnessed test. 19:30 20:00 0.50 0 0 SURFA( CEMEN-BOPE P Pull test plug and set 10"WB. 20:00 20:45 0.75 0 0 SURFA( CEMEN-PULD P Service Iron Rfnk, remove roller frpm pipe skate. 20:45 21:15 0.50 0 0 SURFA( CEMEN SFTY P PJSM on PU 5"DP via the Mouse hole. 21:15 00:00 2.75 0 0 SURFA( CEMEN'PULD P Continue to PU and rack back 36 jts of 5"DS50 DP 02/10/2014 PU BHA#6. Surface test the Riptide HO. Upload and shallow test MWD. RIH and pressure test csg to 3,500 psi-ok. Slip and cut DL,service TD and rig. 00:00 04:15 4.25 0 0 SURFA( CEMEN'PULD P Continue to PU and rack back 31 jts of 5"DS50 DP 04:15 04:30 0.25 0 0 SURFA( CEMEN'PULD P PJSM for PU BHA 04:30 05:15 0.75 0 0 SURFA( CEMEN PULD P PJSM. PU BHA tools&equip via the Beaver slide 05:15 05:30 0.25 0 0 SURFA( CEMEN'PULD P PJSM-MU BHA 05:30 07:15 1.75 0 80 SURFA( CEMEN-PULD P MU BHA per directional driller and MWD to 80' 07:15 08:30 1.25 80 80 SURFA( CEMEN-PULD P Plug in and upload to MWD at 80' 08:30 08:45 0.25 80 80 SURFA( CEMEN PULD P PJSM and load radioactive sources 08:45 09:00 0.25 80 95 SURFA( CEMEN-TRIPP RIH taking weight-PU=SO=75K. At 95'could not go down. Page 18 of 46 •Tune Logs 4111 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1.00 95 110 SURFA( CEMEN-TRIP P MU TD and wash down 95-186'with 3 bpm, 0 psi, taking weight at 108', 110', 112', 120', 153'. Work string over interval 2x-ok. Blow down TD. 10:00 11:15 1.25 110 135 SURFA( CEMEN-OTHR P Continue MU BHA from 110-135'. At 135'test RipTide reamer. Drop activation RFID tag and pump with 400 gpm, 370 psi(visually verify tool opening). Drop deactivation RFID tag, wait 10 min, pump w/400 gpm,270 psi(visually watch tool close and remain closed). C/O from3x blank jets to 3x 8/32 jets. 11:15 12:00 0.75 135 170 SURFA( CEMEN'PULD P Continue to MU BHA per Dir driller to 170' 12:00 13:30 1.50 170 790 SURFA( CEMEN PULD P Continue to MU BHA per Dir driller to 790' 13:30 13:45 0.25 170 790 SURFA( CEMEN-SFTY P PJSM on single in hole 13:45 18:45 5.00 790 3,045 SURFA( CEMEN-TRIP P RIH to 2,575'md, PU/MU Ghost reamer#1, continue RIH to 3,045'. PU= 143K, S0= 100K, ROT= 115K, TQ=7K 18:45 20:00 1.25 3,045 3,139 SURFA( CEMEN WASH P Wash down from 3,045'to 3,139'with 450 gpm, 1,040 psi, 20 rpm, 7 K ft-lb. Circ and cond mud for Casing test. 20:00 21:15 1.25 3,139 3,139 SURFA( CEMEN-PRTS P PJSM. RU to test csg. Pressure test 10-3/4"casing to 3,500 psi for 30 min-good. Blow down lines and RD. 21:15 21:30 0.25 3,139 3,139 SURFA( CEMEN"SFTY P PJSM on slip and cut 21:30 23:15 1.75 3,139 3,139 SURFA( CEMEN"SVRG P Slip and cut 45'of drill line. 23:15 00:00 0.75 3,139 3,139 SURFA( CEMEN-SVRG P Inspect TD and service rig. 02/11/2014 Ream in hole and tag up on TOC at 3,265'. Drill out cement shoe track.Drill out FS and 20'of new formation to 3,386'. C&C mud, pull back inside csg shoe, Perform LOT to 16.5 ppg EMW. Drill ahead 9-7/8"and displace to 9.8 ppg LSND mud. Drill ahead 9-7/8"hole to 4,460'md. 00:00 00:30 0.50 3,139 3,139 SURFA( CEMEN OTHR P Calibrate MWD block height and Hook load sensor. Calibrate WOB and Totco Blk height. PU= 155K, SO= 105K, ROT=120 K. 00:30 01:00 0.50 3,139 3,242 SURFA( CEMEN-COCF P Wash and ream to 3,242'and with 500 gpm, 1,230 psi, 50 rpm, TQ-8K. Tag up on firm cement with WOB- 2 K. SPRs at 3,139' MP#1 30- 110 psi, 40- 180 psi MP#2 30-110 psi, 40- 170 psi 01:00 06:00 5.00 3,242 3,266 SURFA( CEMEN'DRLG P Drill out cement and shoe track to 3,353', rat hole to 3,266'with 500 gpm, 1,140 psi,60 rpm, 7-11K ft-lb of TQ. (FC at 3,266', FS at 3,353'md). Page 19 of 46 • •Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 3,266 3,386 SURFA( CEMEN-DRLG P Drill new formation to 3,386'with 500 gpm, 1,120 psi, 60 rpm, 7.5-9.5 ft-lb of TQ. 06:30 07:00 0.50 3,266 3,386 SURFA( CEMEN-CIRC P Circ and Cond mud at 3,386'and for LOT with 500 gpm, 1,120 psi, 60 rpm, 7.5-9.5 ft-lb TQ. SIMOPS PJSM for LOT. Chk fluid level- static. 07:00 08:00 1.00 3,266 3,353 SURFA( CEMEN-LOT P Pull back inside of casing shoe. RU test equip, and chart recorder. Check mud props. Perform LOT to 16.5 EMW with 9.8 ppg mud and 1,050 surface press. Shut in well and monitor for 10 min-ok. 08:00 08:15 0.25 3,353 3,386 INTRM1 DRILL TRIP P Wash back down to TD. 08:15 08:45 0.50 3,423 3,423 INTRM1 DRILL CIRC P SPRs at 3,386' MP#1 30- 110 psi, 40- 180 psi MP#2 30-110 psi, 40- 170 psi Clean under shakers in mud pits, change out both of the mud pump suction screens. 08:45 09:15 0.50 3,386 3,423 INTRM1 DRILL DDRL P Drilled 9-7/8"hole w/RSS assembly f/3,386'to 3,423'MD 2506'TVD ADT-0.51 hrs- Footage 37' SIMOPS-Displace well to 9.8 ppg LSND mud from 9.8 ppg Spud mud while drill ahead with 500 gpm, Initial Circulating pressure ICP) 1,150 psi, Final Circ pressure=820 psi at 60 rpm, 10 K TQ. Pump 33 bbl at 3 Ib/bbl, 9.8 ppg FLOZAN Hi-Vis spacer. Chase with 340 bbl 9.8 LSND. 09:15 12:00 2.75 3,423 3,611 INTRM1 DRILL DDRL P Drilled 9-7/8"hole w/RSS f/3423'to 3611'MD 2575'TVD ADT-2.22 hrs Footage 188' ECD- 10.75 ppg WOB 5/10 k RPM 120 GPM 650 @ 1360 psi String wt. PU 150 SO 108 ROT 126 Torque on/off btm.- 10/75. k ft/lbs Page 20 of 46 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 3,611 4,660 INTRM1 DRILL DDRL P Drilled 9-7/8" hole w/RSS f/3,611' to 4,660' MD 2,914'TVD ADT-7.25 hrs Footage 1,049' ECD- 11.2 ppg WOB 6/15 k RPM 120 GPM 700 @ 1,920 psi String wt. PU 144 SO 124 ROT 128 Torque on/off btm.-9.5/5.5 k ft-lbs Note: Sweeps giving 100-150% increase in cutting returns. Pumped 40 bbl weighted sweeps every 3rd stand. Increased Drill Torque lube to 1.5% due to erratic surface torque. No stick-slip or high vibration seen in downhole sensors. 02/12/2014 Drilled 9 7/8'hole w/RSS f/4460'to 6,262'md. 00:00 12:00 12.00 4,660 5,505 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/RSS f/4460'to 5505' MD 3334'TVD ADT-6.31 hrs Footage-1045' ECD- 11.20 ppg WOB 10/15 k RPM 120 GPM 700 @2190 psi String wt. PU 153 SO 130 ROT 140 Torque on/off btm.-9/6.5 k ft/lbs Pumped 40 bbl 11.8 ppg weighted sweeps @ 4604' 4862' 5052'& 5332' -each sweep brought back 100%increase in cuttings Kick While DrIg Drill-CRT: 52 sec SPRs at 5,220'md, 0810 hrs MP#1 30= 180, 40=230 psi MP#2 30= 180, 40=230 psi 12:00 17:15 5.25 5,505 6,024 INTRM1 DRILL DDRL P Drilled 9 7/8'hole w/RSS f/5,505'to 6,024' MD 3,539'TVD Footage-519' ECD- 11.30 ppg WOB 10/15 k RPM 120 GPM 700 @ 2,380 psi String wt. PU 157 SO 132 ROT 144 Torque on/off btm.-10.5/7 k ft/lbs Pumped 40 bbl 11.8 ppg weighted sweeps @ 5,717' and 6,000' -each sweep brought back 100%, and 50% increase in cuttings. 17:15 18:15 1.00 6,024 6,024 INTRM1 DRILL RGRP T Top Drive Gear oil warning lights/alarms on. Trouble shoot, add hydraulic fluid, grease swivel packing,service rig Page 21 of 46 T;me Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 19:15 1.00 6,024 6,091 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/RSS f/6,024'to 6,091'MD 19:15 21:30 2.25 6,091 6,091 INTRM1 DRILL RGRP T Top Drive gear oil light/alarms on. Change filter,trouble shoot problem, check pressure of system 21:30 00:00 2.50 6,091 6,262 INTRM1 DRILL DDRL P Drilled 9 7/8' hole w/RSS f/6,091'to 6,262' MD 3,633'TVD ADT=5.12 hrs Footage- 171' ECD- 11.17 ppg WOB 10/15 k RPM 120 GPM 700 @ 2,345 psi String wt. PU 156 SO 135 ROT 140 Torque on/off btm.- 10/7 k ft/lbs Pumped 40 bbl 11.8 ppg weighted sweep @ 6,270' -brought back a 25% increase in cuttings. Plan to sweep every 5 stds. SPRs at 6,262' md, 2330 hrs MP#1 30= 160, 40=220 psi MP#2 30= 160, 40=220 psi 02/13/2014 Drilled 9 7/8" hole w/RSS f/6262'to 8,242 md. Trouble shoot TD hydraulic fluids, flush lines. Continue drilling 9-7/8" hole to 8,432'md,4,487'tvd. -Footage: 2,170' 00:00 12:00 12.00 6,262 7,328 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6262'to 7328' MD 4053'TVD ADT-6.54 hrs. ECD- 11.2 ppg Footage-1066' WOB 10/15 k RPM 120 GPM 700 @ 2310 psi String wt. -PU 167 SO 144 ROT 155 Torque on/ioff btm.- 11/7 k ft/lbs Pumped 40 bbls HDNP© 11.8 pp sweeps @ 6270' , 6740', &7229' - Observed 25%increase in cutting f/ sweeps SPR©7299'-11:00 hrs #1 SPM 30 @ 250 psi SPM 40© 320 psi #2 SPM 30 @ 250 psi SPM 40© 320 psi Page 22 of 46 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 21:00 9.00 7,328 8,242 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7,328'to 8,242' MD 4,412'TVD ECD-11.2 ppg Footage-914' WOB 22 k RPM 120 GPM 700 @ 2,560 psi String wt. -PU 177 SO 149 ROT 163 Torque on/ioff btm.- 13/7.5 k ft/lbs Pumped 40 bbls HDNP @ 11.8 pp sweep @ 7,674' -Observed 0% increase-discontinued sweeps 21:00 22:00 1.00 7,328 8,242 INTRM1 DRILL RGRP T Truoble shoot TD,flush hydraulic line. Check gear oil pressure, check gear box.Visually inspect hydraulic fluid flow. Looked ok. 22:00 00:00 2.00 8,242 8,432 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/8,242'to 8,432'MD 4,487'TVD ECD- 11.15 ppg Footage- 190' WOB 15/25 k RPM 120 GPM 700 @ 2,590 psi String wt. -PU 180K SO 150K ROT 160K Torque on/ioff btm.- 13.5/7.5 k ft/lbs SPR @ 8,242'-21:00 hrs MP#1 SPM 30 @ 260 psi SPM 40 @ 320 psi MP#2 SPM 30©260 psi SPM 40 @ 320 psi 02/14/2014 Drilled 9 7/8"hole w/RSS f/8432'to 10,885' 00:00 12:00 12.00 8,432 9,751 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/8432'to 9751' MD 5007'TVD ADT-6.31 hrs. ECD-11.20 ppg Footage- 1319' WOB 20/25 k RPM 130 GPM 700 @ 2360 psi String wt. PU 193 SO 157 ROT 172 Torque on/off btm.-15/8.5 k ft/lbs SPR's @ 9279' -0730 hrs. #1 30 spm @ 310 psi 40 spm @ 360 psi #2 30 spm @ 310 psi 40 spm @ 360 psi 12:00 13:00 1.00 9,751 9,751 INTRM1 DRILL SVRG P Perform surface equipment pressure loss test with 2,500 psi. Compare pressures at 420 gpm and 1,120 psi for both MP#1 and MP#2. Results were the same. Page 23 of 46 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 00:00 11.00 9,751 10,885 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/9,751'to 10,885' MD 5,425'TVD ADT-5.48 hrs. ECD- 11.24 ppg Footage- 1,134' WOB 15/25 k RPM 130 GPM 700 @ 2380 psi String wt. PU 255 SO 150 ROT 180 Torque on/off btm.-20/15 k ft/lbs SPR's @ 10,789' -2300 hrs. #1 30 spm @ 320 psi 40 spm @ 380 psi #2 30 spm @ 320 psi 40 spm @ 390 psi 02/15/2014 Drilled 9 7/8"hole f/10,884'to 12,304'-Wiper trip f/12304'to 11,356'-RIH to 12,304'Circ btms up, flow chk-ok. Changed oil&hydraulic pump in TD,tested-good. Drill ahead to 12,454'md. 00:00 12:00 12.00 10,885 12,111 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/10,884' to 12,111'MD 5839'TVD ADT-6.03 hrs. ECD- 11.10 ppg Footage- 1227' WOB 25/30 k RPM 130 GPM 700 @ 2500 psi String wt. PU 265 SO 152 ROT 191 Torque on/off btm.-22/19 k ft/lbs SPR's @ 11,922' #1 30 spm @ 390 40 spm @ 440 psi #2 30 spm @ 390 40 spm @ 440 psi 12:00 13:30 1.50 12,111 12,299 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/RSS f/12,111' to 12,299' ECD- 11.05 ppg Footage-188' WOB 25/30 k RPM 130 GPM 700 @ 2500 psi 13:30 16:30 3.00 12,299 11,356 INTRM1 DRILL REAM P PJSM. BROOH from 12,299'to 11,356'md,with 759 gpm, 2,670 psi, 140 rpm,TQ=20K ft-lb. Blow down TD. 16:30 17:15 0.75 11,356 12,299 INTRMI DRILL TRIP P RIH 11,356'to 12,005'md,wash to btm at 12,299'md wirh 600 gpm and 1,900 psi. 17:15 18:45 1.50 12,299 12,005 INTRM1 DRILL CIRC P Circ btms up with 600 gpm, 1,900 psi.TQ=20k. Blow down TD. 18:45 19:00 0.25 12,299 12,005 INTRM1 DRILL OWFF P Flow-chk-static. PU=235K, SO= 155K 19:00 19:30 0.50 12,005 12,005 INTRM1 DRILL RGRP T Service rig, PJSM for working on TD. 19:30 22:00 2.50 12,005 12,299 INTRM1 DRILL RGRP T Repair Top Drive-change out gear oil, Hydraulic Pump Unit, hydraulic oil. Replace, secured and pressure tested-okay Page 24 of 46 • Time Logs , Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 22:00 00:00 2.00 12,299 12,454 INTRM1 DRILL DDRL P Break circulation,work stand up and down at 80 rpm and 600 gpm, run to btm, no warning lights went on. MU next stand. Drilled 9 7/8"hole w/RSS f/12,299' to 12,454'MD 5,946'TVD ADT-1.61 hrs. ECD- 11.19 ppg Footage- 155' WOB 30 k RPM 130 GPM 700 @ 2,490 psi String wt. PU 265 SO 155 ROT 192 Torque on/off btm.-25/22 k ft/lbs SPR's @ 12,395' # 1 30 spm @ 390 40 spm @ 440 psi #2 30 spm @ 390 40 spm @ 440 psi 02/16/2014 Drilled 9 7/8"hole f/12454'to 13,311'-Open Rip Trde reamer-Continue drilling 9 7/8"x 11"hole f/13,311'to 14,377' 00:00 01:30 1.50 12,454 12,620 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/12,454'to 12,620'MD WOB 25/30 k RPM 130 GPM 700 @ 2460 psi String wt. PU 270 SO 155 ROT 195 Torque on/off btm.-23.5/21 k ft/lbs 01:30 02:00 0.50 12,620 12,620 INTRM1 DRILL CIRC T Circ @ 750 psi @ 2660 psi@ 180 rpm @ 19.5-24 k torque(trouble shoot MWD) 02:00 09:00 7.00 12,620 13,311 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/12,620'to 13,311' MD WOB 20/22 k RPM 150 GPM 700 @ 2410 psi String wt. PU 250 SO 165 ROT 200 Torque on/off btm.-26.5/15 k ft/lbs (Glydril dilution @ 12,970'while drilling ahead) Page 25 of 46 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:15 1.25 13,311 13,311 INTRM1 DRILL CIRC P Dropped 7 RFID"open"tags w/bit @ 13,311'&Rip Tide UR blades @ 13,190'-pumped W 700 gpm @ 2690 psi w/60 rpm @ 14.5 k torque- Slow pump @ 1700 stks to 175 gpm @ 490 psi w/no rotation for 600 stks as RFID tags passed through UR w/ 50 RPM &stage pump up to 700 gpm-torque increased to 17 k- Pump pressure dropped f/2690 to 2390 psi-UR appears to have opened-TD stalled @ 28 k torque on ream down-lowered pump rate to 375 gpm @ 950 psi-trapped torque was released as UR blades retracted 10:15 12:00 1.75 13,311 13,433 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole w/RSS& Rip Tide UR f/13,311'to 13,433' MD -6254'TVD ADT-5.08 hrs(total for tour) ECD- 10.99 ppg Footage-979' WOB 20/27 k RPM 150 GPM 700 @ 2430 psi String wt. PU 250 SO 165 ROT 200 Torque on/off btm 26.5/15 k ft/lbs **Note UR blades are 122'back f/bit SPR @ 13,337' #1 30 spm 410 psi 40 spm 460 psi #2 30 spm 410 psi 40 spm 460 psi 12:00 19:15 7.25 13,311 14,008 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole w/RSS& Rip Tide UR f/13,311'to 14,008' MD ECD- 11.25 ppg,WOB 25/30 k RPM 150 GPM 750 @ 2,930 psi Torque on/off btm 26/16.5 k ft/lbs **Note UR blades are 122' back f/bit 19:15 20:30 1.25 14,008 14,185 INTRM1 DRILL DDRL T Hole packed off. Lost full returns, PU, reduce flowrate to 500 gpm, 2,270 psi, 80 rpm with TQ=20K. Regain returns.work pipe, monitor returns, stage pumps up to 650 gpm with full returns and no losses. Circulate 4,000 stks monitoring well. Flow-chk well-static. Drill next stand down to 14,185',flow check- static. Note: 21 bbls lost 20:30 21:15 0.75 14,008 14,185 INTRM1 DRILL CIRC T CBU with 650 gpm, 2,500 psi, 150 rpm,TQ=21K. Gas peaked at 5,900 units from packoff then decreased to normal background level. Page 26 of 46 Time Logs • • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 14,185 14,377 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole w/RSS& Rip Tide UR f/14,185'to 14,377' MD, 6,254'TVD, ECD-11.24 ppg,WOB 18/30 k RPM 150 GPM 750 @ 3,100 psi Torque on/off btm 27/17 k ft/lbs **Note UR blades are 122'back f/bit UR total hrs= 14, UR total footage= 1,066' SPR @ 14,282' # 1 30 spm 370 psi 40 spm 430 psi #2 30 spm 370 psi 40 spm 430 psi 02/17/2014 Drilled 9 7/8"x 11"hole f/14,377'to 14,754'. C&C mud, flow-chk. Trouble shoot and fix electrical problem with Top Drive. Drill from 14,754'to 14,844'.Well packing off. Circulate and work pipe at 450-650 gpm. Drill ahead 14,844- 15,130' 00:00 05:30 5.50 14,377 14,754 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole f/14,377'to 14,754' MD 6665'TVD ADT-3.75 hrs ECD-11.37 ppg Footage-377' WOB 25/30 K RPM 160 GPM 750 @ 3420 psi String wt. PU 272 SO 150 ROT 210 Torque on/off btm.-26/19.5 k 05:30 06:00 0.50 14,754 14,754 INTRM1 DRILL RGRP T Top quit on back ream-Circ- service rig-Trouble shoot TD 06:00 11:30 5.50 14,754 14,754 INTRM1 DRILL RGRP T Circ-700 to 500 gpm 2980 to 1640 psi-work pipe while repairing TD electrical problem 11:30 12:00 0.50 14,754 14,754 INTRM1 DRILL CIRC P Make connection-obtain SPR- Down link to MWD SPR @ 14,754 #1 30 spm @ 350 psi 40 spm @ 400 psi #2 30 spm @ 350 psi 40 spm @ 420 psi 12:00 12:30 0.50 14,754 14,844 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole f/14,754'to 14,844' MD hole packing off. 12:30 14:30 2.00 14,844 14,844 INTRM1 DRILL CIRC T Circ and cond with 450 gpm, 1,450 psi, 120 rpm while working std- ECD: 10.79 Circ and cond with 500 gpm, 1,600 psi, 120 rpm while working std- ECD: 10.81 Hole packed off Page 27 of 46 111110 Time Logs • , Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:30 17:30 3.00 14,844 14,844 INTRM1 DRILL CIRC T Circ and Gond with 450 gpm, 1,400 psi, 120 rpm while working std- ECD: 10.79 Circ and cond with 500 gpm, 1,600 psi, 120 rpm while working std- ECD: 10.81 Circ and cond with 550 gpm, 1,900 psi, 120 rpm while working std- ECD: 10.84 Circ and cond with 600 gpm, 2,200 psi, 120 rpm while working std- ECD: 10.91 - 10.85 Circ and cond with 650 gpm, 2,500 psi, 120 rpm while working std- ECD: 10.89 TQ=20-25K 17:30 23:00 5.50 14,844 15,130 INTRM1 DRILL DDRL P Drilled 9 7/8"x 11"hole f/14,844'to 15,130'MD 6,757 TVD ADT-4.96 hrs ECD-11.26 ppg Footage-286' WOB 25/30 K RPM 155 GPM 750 @ 3,330 psi String wt. PU 302 SO 155 ROT 168 Torque on/off btm.-28/22 k SPRs - 15,036'at 18:00 hrs MP#1 30- 23:00 00:00 1.00 14,844 15,130 INTRM1 DRILL DDRL T Packed off, stall out. Worked pipe. Pulled free at 375K. PU=302K, SO= 150K.Work pipe with 2 bbl/min, 340-569 psi, 80 rpm,TQ= 22-29K 02/18/2014 Attempt to regain circulation from pack off @ 15130'-Work pipe f/15130'to 14942'&establish circulation- Gas spiked to 10K units-Wt up f/10.0 ppg to 10.5 ppg-Wash down to 15132'-Drop tag&close under reamer-Drill ahead f/15132'to 15226'-Packed off-Work pipe&attempt to establish circ f/15226'to 15036' with tight hole&hole attempting to pack off-BROOH(/15036'to 14847'&establish full returns while staging pumps up to full drill rate. 00:00 03:30 3.50 15,130 15,036 INTRM1 DRILL CIRC T Work pipe f/15,036'to 14,942' attempting to establishion circulation -@ 126 to 450 gpm @ 450 to 2670 psi(packing off&stalling TD)60 to 160 rpm' 17 to 32 k torque-Pumped away 45 bbls-Established circulation @ 450 gpm @ 1650 psi stable PSI-Gas spkied to 10 K units 03:30 05:15 1.75 15,036 15,036 INTRM1 DRILL CIRC T Slow pump rate to 399 gpm lower ECD to 11.16 ppg f/11.22 ppg-bring pumps back to 600 gpm @ 2440 psi -Q 120 rpm w/21.5 to 28 k torque- circ btms up-Blow down TD Page 28 of 46 • Time Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:45 0.50 15,036 15,036 INTRM1 DRILL OWFF T Flow ck-slight ooze for 5 mins.then static for 25 mins 05:45 08:15 2.50 15,036 15,036 INTRM1 DRILL CIRC T Obtain SPR w/10.5 ppg-Circ& stage pump back to 600 gpm @ 2470 psi-work pipe w/No rotation checking electricial connections on TD)Observed btms up gas @ 2630 units Max. no gas break out observed @ flow line or no LEL readings on hand held meter 08:15 09:00 0.75 15,036 15,132 INTRM1 DRILL WASH T Wash down f/15036'to 15132'W 600 gpm @ 2440 psi w/120 rpm's @ 23.5 k torque 09:00 12:30 3.50 15,036 15,036 INTRM1 DRILL CIRC T Flow ck-well flowing&gas breaking out-Pump©450 gpm @ 1650 psi w/120 rpm 23 to 30 k torque-wt. up f/10.0 to 10.5 ppg -Stage pump to 600 gpm©2440 psi w/120 rpm @ 21.5 to 28 k torque 12:30 14:45 2.25 15,132 15,132 INTRM1 DRILL CIRC P Drop tag to close under reamer-Circ w/600 w/120 rpm @ 21K trq-@ 1900 stks reduce flow to 175 gpm @ 550 psi&let set for 10 min-Work string w/305 k pu wt& 155 k so wt- Attempt to close under reamer 14:45 16:00 1.25 15,132 15,266 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/15132"to 15266' MD 6773'TVD ADT-0.84 hrs ECD-11.24 ppg Footage- 134' WOB 25/30 K RPM 120 GPM 600 @ 2480 psi String wt. PU 302 SO 150 ROT 210 Torque on/off btm.-27/21 k 16:00 22:00 6.00 15,266 15,036 INTRM1 DRILL CIRC T Packed off while back reaming stand prior to connection-Attempt to regain circulation f/15226'to 15036' with tight hole and hole continuing to pack off-Lossed power to sub base -Trouble shoot electrical and regain power&re-establish circulation- Attempt to establish full circulation with 84-320 gpm @ 560-940 psi& 60-120 rpm @ 20-27 k trq-Not able to establish full drilling parameters 22:00 23:00 1.00 15,036 14,847 INTRM1 DRILL TRIP T BROOH(/15036'to 14847'w/450 gpm @ 1450 psi&80 rpm @ 21 k trq 23:00 00:00 1.00 14,847 14,847 INTRM1 DRILL CIRC T Stage up pumps to 600 gpm @ 2320 psi w/160 rpm @ 25 k trq&circulate &condition hole X2/19/2014 Wash&ream hole f/14,847'to 15,226'-Drilled 9 7/8"hole f/15,226'to 15,483'TD of section-Circ&Cond hole-Circ&displace WBSP-Pump out hole&spot in place WBSP f/15483'to 14230'-Started pulling tight &attempt to work thru with no success-Drop down 2 stds to 14474&circ 30 min's w/full drilling parameters -Attempt to POOH with 3 BPM&no rotation (pulling tight)-BROOH f/14380'-14250'(started pulling tight& hole packing off)-Cont to work thru trouble spot&BROOH to 13903' Page 29 of 46 Time Logs 1 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 14,847 15,226 INTRM1 DRILL WASH T Wash&ream down f/14,847'to 15,226'@ 625 gpm @ 2470 psi w/ 150 rpm's w/21 to 25.5 k torque- Torqued up&packed-off @ 15,139'- Bring pump rate down to 450 gpm @ 1450 psi-Stage pump back up f/ 450 to 700 gpm @ 1450 to 2970 psi- Full returns 06:00 11:15 5.25 15,226 15,483 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/15,226' to 15,483'MD 6818'TVD ADT 4.23 hrs ECD- 11.38 ppg Footage-257' WOB 15/22 k RPM 150 GPM 700 @ 2950 psi String wt. PU 290 SO 155 ROT 205 Torque on/off btm.-28/26 k ft/lbs TD called by CPAI Geo. -15,483'MD Rig pick for top of Nechelik- 15,415' 11:15 14:15 3.00 15,483 15,483 INTRM1 CASING CIRC P Circulate&condition hole w/700 GPM @ 2970 PSI &w/150 RPM @ 26-28.5 K Trq 14:15 14:45 0.50 15,483 15,483 INTRM1 CASING OWFF P Obtain torque&drag parameters - Flow check(static) 14:45 15:45 1.00 15,483 15,483 INTRM1 CASING CIRC P Circulate&spot wellbore strengthening pill w/350-600 GPM @ 1100-2350 PSi& 120 RPM @ 20 K Trq 15:45 18:00 2.25 15,483 14,230 INTRM1 CASING TRIP P Pump out of hole f/15483'to 14230' while spotting wellbore strengthening pill w/3 BPM @ 280 PSI-PU Wt 290 SO 150-Started pulling tight @ 14232'w/25-30 K max over pull 18:00 19:30 1.50 14,230 14,230 INTRM1 CASING TRIP T Attemp to work thru tight spot w/170 -600 GPM @ 740-2500 PSI &50- 130 RPM @ 19-27 K Trq-(hole packing off with excessive torque and stalling top drive) 19:30 20:30 1.00 14,230 14,474 INTRM1 CASING CIRC T RIH 2 stands to 14474'&circ 30 minutes w/700 GPM @ 2970 PSI& 150 RPM @ 22 K Trq(no issues with packing off while circulating) Max gas 9750 units 20:30 22:00 1.50 14,474 14,250 INTRM1 CASING TRIP T Attempt to pull out of hole with 3 BPM&no rotation with no success (30-40K max overpull)-BROOH with various parameters of 230-700 GPM @ 1050-2920 PSI &50- 130 RPM @ 19-27 K Trq to 14250'(hole packed off, pulling tight&not able to work past 14250') Page 30 of 46 I Time Logs S Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:00 00:00 2.00 14,250 13,903 INTRM1 CASING TRIP P Re-adjusted drilling parameters& re-established circulation& continued to BROOH w/reduced parameters of 200-350 GPM @ 720 -1050 PSI &60 RPM @ 18-20 K Trqw/2-5KWOB 02/20/2014 Cont. BROOH f/13,903'to above HRZ @ 13,526'-Circulate B/U-Drop RFID tags to close reamer-Observe well for flow&let reamer relax-Attempt to POOH on TT(swabbing)-BROOH(under reamer blades still open)to 12,489'-Trouble shoot top drive&reprogram VFD to only run 1 motor-Cont. BROOH to 10,885' 00:00 01:30 1.50 13,903 13,526 INTRM1 CASING TRIP P Cont. BROOH f/13,903'to 13,526'w/ 355 gpm @ 1090 psi w/70 rpm's w/ 17 to 22 k torque(tight @ 13818;)- PU wt. 252 SO wt 162 Rot wt 190 w/pump 01:30 02:45 1.25 13,526 13,526 INTRM1 CASING CIRC P @ 13,526'-Circ-stage rotary up f/ 70 to 125 rpm w/17 to 24.5 k torque &pump f/355 to 700 gpm w/1090 to 2910 psi-(pressure dropped @ 700 gpm f/2850 to 2630&torque increased f/19.5 to 22 k ft/lbs- Indicating UR has opened-MWD turbin RPM reduced also) 02:45 03:30 0.75 13,526 13,526 INTRM1 CASING CIRC P Dropped 10 RFID closing tags for UR -Pumped tags down 700 gpm @ 2940 psi w/50 rpm w/15.5 k torque- after 1700 strokes slowed pump to 200 gpm @ 510 psi for last 650 stks -Blow down TD 03:30 04:00 0.50 13,526 13,526 INTRM1 CASING OWFF P Monitor well for 30 mins-well static 04:00 04:45 0.75 13,526 13,337 INTRM1 CASING TRIP P Attempt to POOH on elevators(no good-swabbing) BROOH f/13,526' to 13,337'@ 600 gpm @ 2220 psi& 120 rpm's w/20 to 28.5 k torque 04:45 05:15 0.50 13,337 13,243 INTRMI CASING TRIP P POOH f/13,337' @ 1 to 2 bbls/min @ 140 to 510 psi(packed-off&over pulled 50 k @ 13,276'-UR blades @ 9 7/8"hole w/bit @ 13,311'-stage pump up to 600 gpm @ 2220 psi-no rotation&POOH to 13,243' 05:15 09:30 4.25 13,243 12,489 INTRM1 CASING TRIP P BROOH f/13,243'to 12,489'w/600 to 700 gpm @ 2220 to 2840 psi w/ 120 rpm's w/18.5 to 29 k torque tight spots @ 12,592'-, 12,586'- 12,561'-12,549'-12,536'- 12,525'- 12,496) 09:30 16:30 7.00 12,489 12,489 INTRMI CASING RGRP T Top Drive shut down electrical problem-Circ&work pipe @ 167 gpm @ 420 psi-PU wt 235 SO wt. 154- Whlie trouble shooting TD- Re-program VFD to only run 1 traction motor Page 1I of 46 • Time Logs 40 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 00:00 7.50 12,489 10,885 INTRM1 CASING TRIP P BROOH f/12,489'to 10,885'w/350- 450 gpm @ 1040- 1450 psi&w/100 rpm @ 20 k trq-Pulling good with a few tight spots @ 11,685'& 11,615'_ Originally attempted to BROOH w/full drilling parametrs of 600-700 gpm, but hole trying to pack off with higher flow rates 02/21/2014 BROOH f/10,885'to 9280'-Pump OOH f/9280'to 7254'-Circ. B/U f/9280'to 7204'-Pump OOH f/7204'to 6112'(pull tight)-RIH to 6166'- BROOH f/6166'to 5789'-Pump OOH f/5789'to 5204'(pull tight)-Circ. B/U f/5204'to 5129'-BROOH f/5129'to 3517'-Pump OOH f/3517'to 3490' (attempt to pull reamer into shoe- pulling tight&packing off-not able to work past 3490')-RIH f/3490'to 3611'&attempt to clean hole up(hole packing off)-Pump OOH f/3611'to inside casing at 3329'(took 30 k max over pull to get BHA inside casing) _ 00:00 04:45 4.75 10,885 9,280 INTRM1 CASING TRIP P BROOH f/10,885'to 9280'@ 450 gpm @370 psi w/100 rpm's w/12.5 to 19ktorque-PUwrt210 SO wt 132 04:45 09:00 4.25 9,280 7,299 INTRM1 CASING TRIP P POOH f/9280'to 7254 w/450 gpm @ 1350 to 1270 psi(No rotation- had VFD fault)tight spots©9038', 8560', 7905', 7307', 7254'(RIH to 7299' 09:00 10:00 1.00 7,299 7,204 INTRM1 CASING TRIP P BROOH f/7299'to 7204'@ 700 gpm @ 2270 psi w/100 rpm's w/8.5 to 12 k torque(tight spot @ 7289')circ btms up-Observed some clay pattes @ shakers 10:00 11:45 1.75 7,204 6,166 INTRMI CASING TRIP P POOH on elevators w/pump @ 450 gpm @ 1090 to 1190 psi(tight spots @ 6686', 6640',6592',6582', 6126', 6112')RIH to 6166' 11:45 13:30 1.75 6,166 5,789 INTRM1 CASING TRIP P BROOH f/6166'to 5789"@ 700 gpm w/2510 psi w/100 rpm's w/7.5 k torque(Observed higher pump pressure MWD also Observed increase RPM in turbin- Rip Tide UR appears to have closed 13:30 14:45 1.25 5,789 5,204 INTRMI CASING TRIP P Pump OOH f/5789'to 5204'w/450 gpm @1110 psi(tight @ 5257'& 5204') 14:45 15:30 0.75 5,204 5,129 INTRM1 CASING CIRC P Circulate B/U f/5204'to 5129'w/700 gpm @ 2380 psi&w/100 rpm @ 5.5 k trq 15:30 22:00 6.50 5,129 3,517 INTRM1 CASING TRIP P BROOH f/5129'to 3517'w/450- 700gpm @970-2290 psi&w/100 rpm @ 6-9 k trq(tight @ 4588', 4304'-4255'&4237') 22:00 23:00 1.00 3,517 3,490 INTRM1 CASING TRIP P Pump OOH f/3517'to 3490'w/125- 450 gpm ©270- 1200 psi(hole tight &packing off, 20 k max over pull- not able to work past 2490') 23:00 23:30 0.50 3,490 3,611 INTRM1 CASING CIRC T Wash&ream back down f/3490'to 3611'w/200 gpm&50 rpm-stage pumps up to 600 gpm @ 1940 psi w/100 rpm @ 5.5 k trq and attempt to clean hole up(hole continued to try and pack off with erratic trq) Page 32 of 46 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 3,611 3,329 INTRM1 CASING TRIP P Pump OOH f/3611'to 3329'w/1 -7 bpm @ 150-580 psi(hole continued to attempt to pack off and pull tight, had to pull 30 k max overpull to get BHA inside of shoe)- BHA appeared to be completely packed off with clay 02/22/2014 Pump sweep&circulate casing clean-Monitor well for flow-Attempt to POOH on elevators(hole swabbing) -Pump OOH f/3329'to 236'-B/D T/D-L/D BHA as per SLB-R/U to test B.O.P.'s-Test. B.O.P.'s-Monitor well for flow-Cont.w/B.O.P.test 00:00 01:30 1.50 3,329 3,329 INTRM1 CASING CIRC P Pumped 37 bbls 10.5 ppg Nut Plug/ Screen Kleen sweep @ 3329'- @ 600 to 750 gpm @ 1650 to 2390 psi w/60 rpm's w/4 k torque to clean up BHA&casing 01:30 02:00 0.50 3,329 3,329 INTRM1 CASING OWFF P Monitor well for 30 mins.-Static 02:00 06:00 4.00 3,329 790 INTRM1 CASING TRIP P POOH w/pump f/3329'to 790'@ 210 gpm @270 psi(attempted to Pull on elevators-swabbing) 06:00 07:00 1.00 790 236 INTRM1 CASING TRIP P Flow ck-Static-Attemtp to POOH on elevators-Swabbing-POOH w/ pump f/790'to 236'@ 210 gpm @ 210 psi-Blow down T/D 07:00 08:15 1.25 236 116 INTRM1 CASING PULD P PJSM-Pull&L/D saver float sub- NM flex DC's-NM stab-Monel-Rip Tide under reamer to 116' 08:15 08:45 0.50 116 116 INTRMI CASING OTHR P PJSM on removing RA sources- Pulled up&removed RA sources f/ MWD(All hands were clear from floor) 08:45 09:30 0.75 116 116 INTRMI CASING OTHR P Weathorford CIO reamer jets w/blank jets&pump w/450 gpm&visually confirm reamer blades in closed position&would not open 09:30 10:30 1.00 116 0 INTRM1 CASING PULD P Cont.to L/D BHA as per SLB Total Calc.Trip Fill= 133.41 bbls Total Act.Trip Fill=278.5 bbls 10:30 12:45 2.25 0 0 INTRM1 CASING OTHR P Clean&clear BHA tools f/rig floor (SIMEOPS-C/O upper rams f/3-1/2" X 6"to 7-5/8"-clean both mud pump suction&discharge screens) Page 33 of 46 Tithe Logs I Date From To Dur S. Depth E. Depth'Phase Code Subcode T Comment 12:45 18:00 5.25 0 0 INTRM1 CASING BOPE P M/U DP single&flush stack-B/D T/D-M/U running tool-Drain stack- Pull wear ring (22 K to pull)-Set test plug w/7-5/8"test joint-R/U head pin&test equip-(7-5/8"test joint would not space out properly in test plug to test upper rams&annular without being modified)-C/O rams f/7-5/8"to 3-1/2"X 6"VBR's-Set test plug w/5"test joint&rig up to test B.O.P.'s-(Observe staedy stream of 10.5ppg mud f/annulus while filling lines)-Test upper rams t/3500 psi&chart for 5 min-R/D test equip&pull test plug-L/D test joint&B/D choke 18:00 20:00 2.00 0 0 INTRM1 CASING OWFF T Fill hole w/10.5 ppg mud&monitor well for flow(mud flaculated&aired up, added defoamer, &initial drop with slight increase after 30 min-7" fluctuation=0.25bbls)-Line up to TT and monitor well over top of hole(no gain&no loss after 30 min)- Decesion made to proceed with B.O.P.test 20:00 00:00 4.00 0 0 INTRM1 CASING BOPE P P/U 5"test joint&M/U to LWR test plug-R/U to test B.O.P.'s&fill lines -Test B.O.P.'s(Annular t/250& 2500 psi f/5 min-Valves#1 -16, upper rams, auto IBOP, main IBOP, needle valve, 5"dart valve, 5"FOSV, HCR choke/kill, &4"demco t/250 &3500 psi f/5 min)-Witnessed waived by Chuck Scheve AOGCC- (monitored well on TT during test& gained 1.25 bbls in 2.5 hrs-mud aired up and flaculated) 02/23/2014 Tested B.O.P.'s-Set 10-3/4"W/R-R/D 5"handling equip-R/U Tesco anti rotation bracket-Dummy run w/7-5/8"hanger-R/U Tesco casing running tool-Run 7-5/8"casing to 6329'(Circ&cond @ shoe& circulating B/U every 1000' in open hole to circ out gas) 00:00 02:00 2.00 0 0 INTRM1 CASING BOPE P Cont. BOP test-Tested lower pipe rams w/5"test jt to 250&3500 psi . -Performed Accumulator recovery test-back to 200 psi in 35 sec. back to full charge in 166 secs. -N2 bottles @ 2000 psi-Tested blind rams to 250&3500 psi-Performed choke draw down test to 1100 psi- Blow down choke&kill lines 02:00 03:00 1.00 0 0 INTRM1 CASING OTHR P PJSM-Changed top pipe rams f/3 12/"x 6"VBR to 7 5/8"solid body 03:00 04:30 1.50 0 0 INTRM1 CASING BOPE P PJS-Set 7 5/8"testjt.w/upper test plug-Fill stack w/water-Test annular&top pipe rams to 250& 3500 psi-Drain stack(total 3 bbls gain since beginning of BOP test Page 34 of 46 Time Logs I I , Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:30 05:00 0.50 0 0 INTRM1 CASING OTHR P PJSM-RD 5"elevators, bails&bell guide-PU long bails, casing slips, cmt head&stage collar, float collar &baffle collar-RU Tesco anti rotation backet(monitor well on TT no gain/no loss 05:00 05:15 0.25 0 0 INTRM1 CASING OTHR P PU FMC casing hanger&landing jt &make dummy run (OK)LD landing jt&hanger 05:15 05:45 0.50 0 0 INTRM1 CASING RURD P PJSM-RU Tesco CDS tool&7 5/8" single jt. elevator&slips 05:45 07:15 1.50 0 0 INTRM1 CASING RURD P PJSM-RD 5"elevators, bails&bell guide-PU long bails, casing slips, cmt head&stage collar,float collar &baffle collar-RU Tesco anti rotation backet(monitor well on TT 07:15 07:30 0.25 0 0 INTRM1 CASING SFTY P PJSm on running 7 5/8'casing 07:30 11:30 4.00 0 2,202 INTRM1 CASING RNCS P Ran 7 5/8"29.7#L-80 BTC-M casing as follows: Float shoe( Ray Oil Tools-silver bullet)2 jts csg- float collar( Halliburton Super Seal II w/baffle adaptor on top of FC)) 1 jt. casing, Baffle collar(Halliburton) 1 jt. csg.(All connections made up w/ BakerLoc-Stab into jt#4&fill pipe &check floats)48 jts casing to 2202'(52 jts total in hole (got back 2 bbls excess displacement- Observed slight flow) 11:30 12:00 0.50 2,202 2,202 INTRM1 CASING CIRC P Circ btms up @ 2202' @ 4 bbls/min @ 160 to 120 psi-PU wt. 105 SO wt 105--@ btms up observed No gas and 10.5 ppg mud wt out 12:00 13:45 1.75 2,202 3,342 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing f/2202'to 3342'(79 jts total in hole) Installed Hydroform cent. on jts. 1 thru 33 13:45 15:15 1.50 3,342 3,342 INTRM1 CASING CIRC P Circ&cond. mud-Stage pump up to 5 bbls/min @ 210 psi-Observed 10 K units of gas to surface w/860 stk pumped-Observed small bubble break out @ flow line&7 to 11 % LEL w/hand held monitor in mud buckett line 15:15 16:45 1.50 3,342 4,225 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing(/3342'to 4225'(100 jts total in hole) 16:45 17:45 1.00 4,225 4,225 INTRMI CASING CIRC P Circ&cond. mud-Stage pump up to 6 bbls/min @ 270 psi-Max gas 6400 units 17:45 19:15 1.50 4,225 5,349 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing f/4225'to 5349'(127 jts total in hole) 19:15 20:30 1.25 5,349 5,349 INTRMI CASING CIRC P Circ&cond. mud-Stage pump up to 6 bbls/min @ 310 psi-Max gas 8700 units Page 35 of 46 Time Logs Date iii From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 5,349 6,329 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing f/5349'to 6329'(150 jts total in hole) 22:00 00:00 2.00 6,329 6,329 INTRM1 CASING CIRC P Circ&cond. mud-Stage pump up to 6 bbls/min @ 320 psi-Max gas 9000 units 02/24/2014 Cont. run 7-5/8"intermediate casing f/6329' to 13525'(Circulated every 1000'to circulate out gas) 00:00 01:15 1.25 6,329 7,353 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing f/6329'to 7353'(174 jts total in hole) 01:15 03:15 2.00 7,353 7,353 INTRM1 CASING CIRC P Circ&stage pump up to 6 bbls/min @ 330 psi Max gas 5675 units PUwt. 197k/SO wt. 129k 03:15 04:45 1.50 7,353 8,369 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC- M casing(/7353'to 8369'(198 jts total in hole-hydroforms on jts 175- 198) Stage coller baker locked between jts 175& 176 04:45 06:15 1.50 8,369 8,369 INTRM1 CASING CIRC P Circ&stage pump up to 6 bbls/min @ 320 psi Max gas 540 units PU wt.210 k/SOwt. 140 k 06:15 07:45 1.50 8,369 9,299 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC-M casing f/8369'to 9299'(220 jts in the hole-hydroforms on jts 199 -203) 07:45 10:00 2.25 9,299 9,299 INTRM1 CASING CIRC P Circ&stage pump up to 6 bbls/min @ 360 psi Max gas 2400 units PU wt.225 k(brk over 300 k)/SO wt. 140 k 10:00 15:00 5.00 9,299 12,255 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC-M casing f/9299'to 12,255' (290 jts in the hole-straight blade centralizers on jts 287-289) 15:00 18:45 3.75 12,255 12,255 INTRM1 CASING CIRC P Circ&stage pump up to 6 bbls/min @ 420 psi Max gas 8400 units PU wt. 295 k(brk over 375 k)/SO wt. 151 k 18:45 21:15 2.50 12,255 13,525 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC-M casing 1/12,255'to 13,525' (320 jts in the hole-straight blade centralizers on every other jt 291 - 320) 21:15 00:00 2.75 13,525 13,525 INTRM1 CASING CIRC P Circ&stage pump up to 6 bbls/min @ 450 psi Max gas peaked out @ 10000 units w/18%LEL observed @ flow line PU wt. 330 k(brk over 400 k)/SO wt. 150 k Page 36 of 46 Time Logs 411° 4110 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 32/25/2014 24 hr summary Cont.to circ out gas @ 13525'-RIH f/13525'to 14212' -Lost all down wt-Attempt to work casing down (no success)-Attempt to POOH (no success)-Attempt to break circ(packed off)-Cont.to work casing down f/14200'to 14307'(329 jts in hole)-Casing stopped-Work stuck casing-Stage scaffolding 00:00 01:30 1.50 13,525 13,525 INTRM1 CASING CIRC P Cond.to circ w/6 bbls/min @ 450 psi Max gas peaked out @ 10000 units w/18% LEL observed @ flow line PU wt. 330 k/SO wt. 150 k 01:30 03:30 2.00 13,525 14,212 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTC-M casing(/13,525'to 14,212' (337 jts in the hole-straight blade centralizers on every other jt 321 - 337)-Worked thru a bridge @ 14000'w/50 k max wob&once thru had all down wt back until casing stopped @ 14,212' 03:30 05:00 1.50 14,212 14,186 INTRM1 CASING RNCS T Decesion made to POOH to above 14000'on jt 331 @ 13998'and establish circulation-L/D jt#337& attempt to POOH-Started pulling tight with 450 k max over pull @ 14186'-Work string&attempt to establish circulation @ 1 bpm with no success-Hole packed off w/max 850 psi-Apply 15 k max trq& attempt to work casing-Decesion made to try&go back in hole and work casing down. 05:00 08:45 3.75 14,186 14,307 INTRM1 CASING RNCS T Attempt to work casing back in hole -Worked in hole f/14186'to 14307' (jts 336-339)-Worked casing down w/15 k trq (appeared to be transfering wait to bit)&periodically trying to establish circulation- Was not able to work past 14307'(worked total of 95'in hole before all forward progress was stopped) 08:45 00:00 15.25 14,307 14,307 INTRM1 CASING RNCS T Cont. to work stuck casing © 14307' w/450 k max over pull&50 k max slack off wt-Attempt to work torque into pipe w/15 k max trq with no success-Not able to estabilsh circulation-Monitor well on TT(2bbl total loss)-Stage scaffolding on rig floor Plan forward to R/D Tesco, M/U cement head&attepmt to establish circulation&cement 02/26/2014 R/D Tesco-R/U scaffolding-M/U cement head&cement line-R/D scaffolding-Wait on cement blend to come from Deadhorse-Work stuck casing-Open stage collar -Circ&cond. mud for 2nd stage cement job -Pump 2nd stage cement&pump blug-Close annular on csg&monitor annulus&casing-W.O.C.while cleaning rig floor&wind walls-Work on P.M.'s&work orders 00:00 01:00 1.00 14,307 14,307 INTRM1 CASING RURD T PJSM, RD Tesco, LD via beaver slide (0-G/L) 01:00 02:00 1.00 14,307 14,307 INTRM1 CEMEN.RURD T PJSM, RU 16'bails and elevators Page 37 of 46 Time Logs 110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:30 1.50 14,307 14,307 INTRMI CEMEN-RURD T Scaffold crew erect scaffolding, 14' casing stick up(SIMOPS-PJSM on RU cement head) 03:30 04:30 1.00 14,307 14,307 INTRM1 CEMEN'RURD T R/U X-over to stump-M/U cement head&R/U cement lines-R/D scaffolding 04:30 12:30 8.00 14,307 14,307 INTRM1 CEMEN"WOC T W.O.C. D 600 G blend to come from Deadhorse-Every 30 min.work stuck casing w/350 k P/U wt&50 k S/O wt-work on P.M.'s&work orders-Monitor well on TT G/L= -2.5 bbls) 12:30 13:15 0.75 14,307 14,307 INTRM1 CEMEN"CIRC T Pressure test lines to 3800 psi- Stage pumps up to 6 bpm @ 2760 psi-pumped 39 bbls(minimal returns-slight ooze)Suspect from casing expansion. 13:15 14:30 1.25 14,307 14,307 INTRM1 CEMEN"OWFF T Shut in&monitor pressure& observe slight flow-Bleed off pressure&monitor returns to pits (2.25 bbl gain in 15 min) Diminished greatly last 5 min. 14:30 18:00 3.50 14,307 14,307 INTRM1 CEMEN'CIRC T Bring pumps up to 8 bpm&open stage collar w/3700 psi-pumped 16 bbls-circ&cond mud for cement job w/6-7 bpm @360-450 psi-Wt up mud system f/10.5 to 10.8 ppg 18:00 21:00 3.00 14,307 14,307 INTRMI CEMEN-CMNT T PJSM for 2nd stage cement job- Pressure test casing to 3500 psi- Pump 2nd stage cement job(Dowell Pump=40.2 bbl CW 100-40.1 bbl 11.5 ppg mud push-91.1 bbls(441 sks, 1.16 yield) D 600 G cement- 10 bbls H2O flush&Rig Disp=305 bbls 10.5 ppg LSND-bump plug w/3050 stks)-Increase pressure to 1570 psi &hold for 5 min-Check stage collar closed(good)-CIP @ 20:38 hrs- Full returns throughout job. 21:00 00:00 3.00 14,307 14,307 INTRM1 CEMEN'WOC T B/D cement line-R/U gauge on casing and annulus to monitor pressure-W.O.C. -clean wind walls &rig floor-Work on P.M.'s&work orders @24:00 hrs Ann = 12 psi/Csg=35 psi 02/27/2014 W.O.C. -Bleed off Csg&Annulus&monitor well (static)-Brk stack @ lower flange&P/U stack-Set emergency slips&cut csg-L/D jt 339&9.14'cut off of jt 338-Move stack out of way&set pack off-N/U B.O.P. &test pack off to 3800 psi(good)-C/O saver sub on T/D to 4"XT-39-N/U B.O.P. 00:00 10:00 10.00 0 0 INTRM1 CEMEN-WOC T W.O.C. -Clean wind walls on rig floor-Work on mud pumps-Load pipe shed w/4"DP 10:00 12:15 2.25 0 0 INTRM1 CEMEN-OWFF T PJSM-Bleead off 10 psi f/casing& 4 psi f/annulus-Open bag-Obserev well for flow(static)-SIMEOPS prep to break stack @ lower flange Po. Time Logs •' • Date From To Dur S. Depth'E Depth Phase Code Subcode T Comment 12:15 14:00 1.75 0 0 INTRM1 CEMEN'NUND T PJSM-B/D kill&hole fill line-Drain stack-Remove flow line&hole fill line-Break stack @ lower flange 14:00 16:45 2.75 0 0 INTRMI CEMEN"OTHR T P/U stack&set emergency slips- Cut hole in csg&let drain-L/D cement head 16:45 18:45 2.00 0 0 INTRM1 CEMEN'CPBO T FMC cut casing&dress cut 18:45 19:30 0.75 0 0 INTRM1 CEMEN'PULD T PJSM-Break out&L/D jt#339& 9.14'cut off of jt#338 19:30 21:00 1.50 0 0 INTRM1 CEMEN-WWSP T PJSM-Remove riser from B.O.P.- Move stack out of way-set pack off 21:00 22:00 1.00 0 0 INTRM1 CEMEN'NUND T PJSM-N/U B.O.P. @ lower flange 22:00 23:00 1.00 0 0 INTRM1 CEMEN WWSP T R/U&test pack off and lower flange to 3800 psi for 10 min (good test)- SIMEOPS C/O saver sub t/4" XT-39 23:00 00:00 1.00 0 0 INTRMI CEMEN NUND T N/U riser to stack&N/U flow line& fill up line-SIMEOPS C/O saver sub t/4" XT-39 X2/28/2014 Cont.to C/O saver sub t/4"XT-39(SIMEOPS perform injectivity test on OA)-R/U bails&5"handling equip.- L/D 5"HWDP, all 5"NC-50& 10 stds 5"DS-50 DP-R/U wire line, RIH w/magnet&retrieve fish(6"wrench)- Cont. to L/D 5"DS-50 DP (leaving 49 stds in derrick)-C/O top rams to 3-1/2"X 6"&test B.O.P.'s w/3-1/2"& 4"test'ts 00:00 01:30 1.50 0 0 INTRM1 CEMEN RURD T Cont.to C/O saver sub to 4"XT-39- SIMEOPS perform injectivity test, water flush&freeze protect OA (300bbls H2O&64 bbls diesel) 01:30 02:30 1.00 0 0 INTRM1 CEMEN RURD T PJSM-R/U bails&5"handling equipment-Install mouse hole 02:30 10:15 7.75 0 0 INTRM1 CEMEN'PULD T L/D 5"HWDP&jars-L/D al 5" NC-50 DP& L/D 10 stds 5"DS-50 DP via maouse hole 10:15 12:15 2.00 0 0 INTRM1 CEMEN-FISH T PJSM-R/U wireline sheaves& magnet for fishing-RIH w/wireline& fishing magnet t/3000'-POOH w/wirleine&recovered fish(6" crescent wrench)- R/D wireline equipment 12:15 18:00 5.75 0 0 INTRM1 CEMEN PULD T Cont. L/D 5"DS-50 DP(108 stds total)-Move 10 stds 5"DS-50 DP f/ODS to DS(leaves 50 stds total Of 5"DS-50 DP in derrick for next well) 18:00 20:00 2.00 0 0 INTRM1 CEMEN'NUND T PJSM-Drain stack-C/O upper rams to 3-1/2"X 6"VBR's- SIMEOPS L/D scaffolding f/rig floor via beaver slide 20:00 00:00 4.00 0 0 INTRMI CEMEN-BOPE T PJSM-Pull W/R-Set upper test plug&R/U to test B.O.P.'s-Test annular t/250&2500 psi for 5 min w/3-1/2"&4"test jts-Test upper& lower rams w/4"test jt,4"FSOV, dart valve, HCR chkoe/kill lines t/250 &3500 psi&chart for 5 min-Test upper rams w/3-1/2"test jt t/250& 3500 psi&chart for 5 min Page 39 of 46 Time Logs al Date From To Dur S. Deoth E. Depth Phase Code Subcode T 'Comment 33/01/2014 24 hr Summary Cont.to test upper rams-M/U clean out BHA w/csg scrapper and single in hole w/HWDP-Slip&cut drill line-Cont.to single in hole w/4"DP to top of stage collar @ 6909'-Test csg to 1000 psi-Drill out stage collar-W&R to 7221'-Circ csg clean-Cont.to RIH while picking up 4"DP to 7505'(W&R thru tight spots @ 7345'&7471') 00:00 00:30 0.50 0 0 INTRM1 CEMEN'BOPE T Cont.to test lower rams w/3-1/2" test jt against HCR's(250/3500 psi& chart for 5 min) 00:30 01:00 0.50 0 0 INTRM1 CEMEN-OTHR T FMC set 7.0625" ID W/R 01:00 03:30 2.50 0 380 INTRM1 CEMEN PULD T PJSM-C/O handling equip to 4"- R/U roller on skate-M/U CIO casing scraper BHA as per SLB t/380' 03:30 04:45 1.25 380 380 INTRM1 CEMEN-RURD T PJSM-Re-rig&re-position counter balance shackles on T/D&blocks 04:45 06:15 1.50 380 380 INTRM1 CEMEN SLPC T Slip&cut 90'drill line&service T/D 06:15 11:15 5.00 380 4,476 INTRM1 CEMEN-TRIPT Cont.to RIH w/C/O BHA while picking up singles of 4"DP from pipe shed f/380'-to 4476' 11:15 12:00 0.75 4,476 4,476 INTRM1 CEMEN'PULD T PJSM-P/U&rack back in derrick via mouse hole 5 stds of 4" DP for drilling out stage collar 12:00 15:45 3.75 4,476 6,747 INTRM1 CEMEN-TRIPT Cont. to RIH w/C/O BHA while picking up singles of 4"DP from pipe shed f/4476'-to 6747'(fill pipe every 20 stds) 15:45 16:30 0.75 6,747 6,747 INTRM1 CEMEN'RURD T B/D T/D-PJSM-Remove bell guide -R/U head pin&cement hose 16:30 16:45 0.25 6,747 6,747 INTRM1 CEMEN-PRTS T Test csg to 1000 psi&chart for 10 min(good) 16:45 17:30 0.75 6,747 6,747 INTRM1 CEMEN'RURD T B/D Kill line&cement hose-R/D head pin-install bell guide 17:30 18:30 1.00 6,747 6,913 INTRM1 CEMEN'WASH T Wash&ream f/6747'to 6913'w/6 bpm @ 970 psi w/50 rpm @ 5.5 k trq 18:30 20:00 1.50 6,913 6,916 INTRM1 CEMEN'DRLG T Drill plug&stage collar f/6913'to 6914'w/1 -5 bpm @ 220-780 psi w/50-60 k trq @ 5.5-7 k trq- Worked thru several times with& without roatation to confirm stage collar clear-(stage collar©6914') 20:00 21:45 1.75 6,916 7,221 INTRM1 CEMEN WASH T Wash&ream f/6916'to 7221'w/6 bpm @ 1030 psi w/60 rpm @ 7 k trq 21:45 22:45 1.00 7,221 7,221 INTRM1 CEMEN-CIRCT Circ B/U w/6 bpm @ 1030 psi w/60 rpm @7ktrq 22:45 00:00 1.25 7,221 7,505 INTRM1 CEMEN"TRIP T Cont.to RIH w/C/O BHA while picking up singles of 4"DP from pipe shed(/7221'-to 7505'(75 stds in the hole) Washed&Reamed thru tight spot @ 7345'&7471'w/6 bpm @ 1050 psi& w/60 rpm @ 8.5 k trq (P/U wt 175k, S/0wt95-90k, ROT wt 115 k) Page 40 of 46 Time Logs I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/02/2014 24 hr summary Cont. to RIH while picking up 4"DP to 9581'-Circ B/U-Cont.to RIH while picking up 4"DP to 14176'&tag baffle collar-P/U to 14166'&pump sweep&circ clean w/300 gpm-Perform injectivity test-POOH on elevators on TT f/14166'to 3143' 00:00 00:30 0.50 7,505 7,694 INTRM1 CEMEN'WASH T Wash&ream f/7505'to 7694'w/250 gpm @ 1060 psi w/60 rpm @ 7.5 k trq-B/D top drive 00:30 04:15 3.75 7,694 9,581 INTRM1 CEMEN"TRIP T Cont.to RIH w/C/O BHA while picking up singles of 4"DP from pipe shed f/7694'to 9581'(fill pipe every 20 stds)-C/O jts#524&525 @ 8732'(bad box/pins) 04:15 05:15 1.00 9,581 9,581 INTRMI CEMEN CIRC T Circ B/U w/350 gpm @ 2220 psi w/60 rpm @ 9 k trq-(significant amounts of cement&plug rubber while cicrulating) 05:15 11:15 6.00 9,581 14,166 INTRMI CEMEN-TRIPT Cont.to RIH w/C/O BHA while picking up singles of 4"DP from pipe shed f/9581'to 14176' (fill pipe every 20 stds)-Tag top of baffle collar @ 14176'w/5 k wob-P/U to 14166'-7' of pipe stretch P/U wt 205 k, S/O wt 110 k, ROT wt 160 k 11:15 13:30 2.25 14,166 14,166 INTRMI CEMEN CIRC T Stage pumps up to 300 gpm&pump weighted sweep-Circ clean w/300 gpm @ 2170 psi w/30 rpm @ 13.5- 17.5 k trq 13:30 15:15 1.75 14,166 14,166 INTRM1 CEMEN PRTS T PJSM-SPR's-Line up f/injectivity test-Test with T/D&upper rams- Injectivity test-Brought up pump to 2 bpm, pressure increased to 2890 psi, paused pumping 5 min, pressure dropped to 2400 psi, resume pumping at 2 bpm, pressure increased to 3650 psi max before breaking over, continued pumping 20 bbls away at stabilized pressure of 3050 psi(±100 psi), reduced pump rate to 1 bpm and pumped 10 bbls away at 2650 psi(±100 psi), stopped pumping and monitored pressure bleed off then stabilize at 1850 psi for 10 min, bleed off pressure, B/D top drive&monitor well for flow(static) 15:15 17:00 1.75 14,166 13,171 INTRMI CEMEN-TRIP T POOH on elevators on TT f/14166'to 13171' 17:00 17:30 0.50 13,171 13,171 INTRM1 CEMEN-CIRC T Flow check(static)-Pump dry job- B/D top drive 17:30 00:00 6.50 13,171 3,143 INTRM1 CEMEN-TRIPT POOH on elevators on TT f/13171'to 3143' (no drag thru stage collar @ 6914') 03/03/2014 Cont. POOH &LID C/O BHA-M/U cement retainer&RIH to 14167"&set retainer-Test casing to 3500 psi for 30 min-R/U head pin&hose and perform injectivity test-Bull head cement out retainer/shoe-POOH to above cement @ 13945'-Reverse circ clean for 2 B/U-Monitor well-Displace to 9.8 ppg brine Page 41 of 46 Time Logs 1111 , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 3,143 380 INTRM1 CEMEN"TRIP T POOH on elevators on TTf/3143'to 380' Cal. Hole Fill=89.9 bbls/Act. Hole Fill=88 bbls 01:15 01:30 0.25 380 380 INTRMI CEMEN OWFF T Observe well for flow-(SIMEOPS- PJSM on L/D BHA) 01:30 02:30 1.00 380 0 INTRM1 CEMEN"PULD T Rack back in derrick 2 stds HWDP &2 stds DC w/jars-L/D clean out BHA(csg scraper, boot basket&bit) 02:30 03:30 1.00 0 0 INTRMI CEMEN OTHR T Clear&clean floor-L/D BHA via beaver slide-Change out elevators to 4" 03:30 13:15 9.75 0 14,176 INTRM1 CEMEN'TRIP T M/U cement retainer&RIH w/4"DP to 14176'&tag top of baffle collar (every 50 stds add 1 full turn to left to keep cement retainer in neutral position) P/U wt 275 k, S/O wt 104 k Clac Disp=86.4 bbls/Act. Disp= 91.5 bbls 13:15 14:00 0.75 14,176 14,167 INTRM1 CEMEN"PACK T P/U f/14176 to 14167'&set retainer- Measure stretch @ 7.25'-Rotate 35 turns to right to set cement reatiner- P/U wt 335 k/S/O wt 80 k&confirm set @ 14167' 14:00 15:30 1.50 14,167 14,167 INTRM1 CEMEN PRTS T Line up to test casing w/upper rams- Test casing to 3500 psi&chart for 30 min-B/D kill line 15:30 16:00 0.50 14,167 14,167 INTRM1 CEMEN'PRTS T Perform injectivity test-Pump 2 bpm ICP=2830 psi&FCP=2770 psi- Pump 3 bpm ICP=3230 psi&FCP =3220 psi 16:00 16:30 0.50 14,167 14,167 INTRM1 CEMEN'OTHR T Shut down pumps&pressure bled to 1680 psi-Check floats(good)- Pressure up to 1000 psi, P/U to 275 k&rotate string to right 9 wraps& release from cement retainer 16:30 17:00 0.50 14,167 14,153 INTRM1 CEMEN-TRIP T POOH f/14167'to 14122'&rack back 1 stand in derrick-Remove bell)guide on T/D-P/U 1 single joint f/pipe shed&RIH t/14153' 17:00 17:30 0.50 14,153 14,153 INTRMI CEMEN RURD T M/U head pin&swing valve to 14' pup jt&M/U to drill string-RIH& confirm space out into cement retainer-P/U to 14153'&hold PJSM for bull heading cement 17:30 18:00 0.50 14,153 14,153 INTRM1 CEMEN CIRC T Close annular&fill choke lines- Establish circ rates&circ pressure through choke w/1 bpm @ 550 psi Page 42 of 46 Time Logs 10 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 14,153 14,163 INTRM1 CEMEN-CMNT T Dowell pressure test line to 5000 psi &fill lines w/1.9 bbls H2O-Pump 10 bbls 11.5 ppg mud push& 125 bbls 15.8 ppg G 600 cement-Shut down pumps&SIO to 80 k&sting into cement retainer-Cont.to pump 22 bbls 15.8 ppg G 600 Gasblok cement(147 bbls total cement/708 sxs 1.17 ft3/sx yield)-Dowell displace cement w/5 bbls H2O&135 bbls 10.5 ppg mud-leaving 5 bbls cement in DP to leave on top of retainer-ICP @ 4.5 bpm =3200- 3800 psi&FCP @ 2.5 bpm=2400- 2600 psi-CIP @ 19:57 hrs Bull headed&displaced cement while maintaining back pressure as per cementing/pump schedule 20:00 20:30 0.50 14,163 13,945 INTRM1 CEMEN'TRIP T P/U&un-sting from retainer (pressure dropped f/1850 psi to 0 psi) -Brk out pup&set in mouse hole- R/D cement hose-L/D single jt& POOH 2 stands to 13945', left 5 bbls cement on retainer. ETOC 14,058' 20:30 21:45 1.25 13,945 13,945 INTRM1 CEMEN-CIRC T Circ down drill pipe w/8 bpm @ 2530 psi for 22.5 bbls to confirm circulation can be established- Reverse circulate clean for 349 bbls w/6.5 bpm @ 2140 psi , no cement seen 21:45 22:30 0.75 13,945 13,945 INTRM1 CEMEN"OWFF T Monitor well for flow 30 min(static)- SIMEOPS(B/D kill line&cement line-R/D head pin&hose-PJSM for displacing to 9.8 ppg brine) 22:30 00:00 1.50 13,945 13,945 INTRM1 CEMEN-CIRCT Pump 35 bbls high vis spacerw/6 bpm @ 1400 psi, pump 74.5 bbls 9.8 ppg un-inhibited 6% KCL/NaCl Brine w/7 bpm @ 1660 psi, &pump 9.8 ppg corrosion inhibited 6%KCL/NaCl Brine w/6 bpm @ 1320 psi-100% returns with 1 to 1 ratio for bbls pumped to bbls returned 03/04/2014 Cont. to displace to 9.8ppg brine-Monitor well-POOH w/cement retainer running tool-L/D running tool- Test casing to 3500 psi for 10 min-L/D 4"DP Page 43 of 46 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 13,945 13,931 INTRM1 CEMEN-CIRC T Continue to pump 530 bbls 9.9 ppg inhibited brine, 25 bbl of 10 ppg uninhibited brine with 970 psi FCP. (Pumped a total of 36 bbl 8.3 ppg Vis-H20 spacer, 74 bbl of 9.8 inhib brine, 530 bbl of 9.8 ppg, inhib brine, 25 bbl of 10 ppg brine at 6 bpm, 1,320 ICP to 970 FCP.A total of 665 total bbls pumped and returned). Obtain SPRs, B/D TD. SPRs-0030 hrs at 13,931'tmd MP#2 20 spm- 110 psi, 30 spm- 270 psi 00:45 01:45 1.00 13,931 13,931 INTRM1 CEMEN'CIRC T Flow-chk. Had a slight ooze as the 10 ppg brine sank. Observe until it went static. (SIMOPS-clean under the shale shakers). 01:45 07:45 6.00 13,931 99 INTRMI CEMEN"TRIP T POOH from 13,931'tmd to 99'on trip tank. Flow-chk at 99'-well static. Stand DP back in derrick. 07:45 08:00 0.25 99 0 INTRM1 CEMEN'RURD T POOH from 99'and LD BOT cmt stinger and running tool. Calc fill= Actual fill=82.5 bbls 08:00 09:00 1.00 0 0 INTRM1 CEMEN-OTHR T PJSM. Clear and clean rig floor. LD tools and equipment vis the Beaver slide/Otter slide. RU Bell guide on TD(Monitor well on TT with no gain/loss. 09:00 09:30 0.50 0 0 INTRM1 DRILL SVRG T Service Top Drive 09:30 10:00 0.50 0 0 INTRM1 DRILL PRTS T PJSM. R/U and test 7-5/8"csg to 1,000 for 10 min on chart recorder- B/D lines. 10:00 12:00 2.00 0 0 INTRM1 DRILL RURD T PJSM. LD 9 stds of 4" DP via the Mouse hole. Monitor well on TT- gain/loss=0. 12:00 13:15 1.25 0 0 INTRM1 DRILL RURD T PJSM. LD 11 stds of 4"DP via the Mouse hole. Monitor well on TT- gain/loss=0. 13:15 13:45 0.50 0 0 INTRMI DRILL SVRG T Service draworks and Iron Roughneck 13:45 00:00 10.25 0 0 INTRM1 DRILL RURD T Cont. LD 83 stds of 4" DP via the Mouse hole. Monitor well on TT- gain/loss=0. 33/05/2014 Move 4" HWDP&DC's to Driller's Side of derrick. Pull wear ring, run 3-1/2"kill string, land on elastomer hanger. Set TWC and test in direction of flow to 1000 psi for 10 min. ND BOPE/NU tree and test to 5000 psi. Pull TWC. RU and pump 70 bbls diesel freeze protect in annulus.Allow diesel to U-Tube. Set BPV and test in direction of flow 1000 psi for 10 min. RD, prep for and move to CD3-316B 00:00 02:00 2.00 0 0 INTRMI DRILL RURD T Cont. LD 16 stds of 4" DP via the Mouse hole. Monitor well on TT- gain/loss=0. 02:00 02:30 0.50 0 0 INTRM1 DRILL RURD T Shuttle 4 stds of HWDP and DCs from ODS to DS and rack back for rig move. 02:30 03:00 0.50 0 0 INTRM1 DRILL RURD T Pull wear bushing Page 44 of 46 I Time Logs • • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:45 0.75 0 0 INTRM1 DRILL RURD T PJSM. RU power tongs and 3-1/2" equipment 03:45 08:15 4.50 0 0 INTRM1 DRILL RCST T Run 3-1/2"mule shoe, 72 Jt 3-1/2" 9.3 lb/ft L-80 EUE tbg,4-1/2"IBT x 3-1/2"EUE BxP XO, FMC tbg hngr 08:15 09:00 0.75 0 0 INTRM1 DRILL RCST T Change out 3-1/2"elevators to 4-1/2". MU tbg hngr, Landing Jt A, 3-1/2"EUE x 4-1/2"IBT XO. PU=S0=75K 09:00 09:45 0.75 0 0 INTRM1 DRILL RCST T Land Hngr with Mule shoe depth at 2,299'md. Run-in Upper LDS (SIMOPS-RD tbg tongs, RU test equip for testing TWC. 09:45 10:15 0.50 0 0 INTRMI DRILL RCST T RU and test Hngr seals-no good. Trouble shoot. 10:15 11:15 1.00 0 0 INTRM1 DRILL RCST T Back out Upper LDS and pull Hngr to rig floor. Hangr not fully located, sifting 8"high of located position. Set down with 10K lb-no good. 11:15 12:00 0.75 0 0 INTRM1 DRILL RCST T RU tbg power tongs to swap out Hangers.Attempt to land tbg on hanger with Landing Jt B while waiting for new hanger. 12:00 12:30 0.50 0 0 INTRM1 DRILL RCST T Run Hngr on Landing Jt A and land fully located. 12:30 13:30 1.00 0 0 INTRM1 DRILL PRTS T Pressure test Hanger seals to 250 psi for 5 min-ok, pressure up to 5,000 psi and hold for 10 min.-good 13:30 13:45 0.25 0 0 INTRMI DRILL RURD T Lay down Landing Jt A and set TWC 13:45 14:00 0.25 0 0 INTRM1 DRILL SFTY T PJSM and RU to test TWC 14:00 14:15 0.25 0 0 INTRM1 DRILL PRTS T Test TWC to 1,000 psi in direction of flow and hold for 10 min-good. 14:15 14:30 0.25 0 0 INTRM1 DRILL RURD T Blow down Mud line and Hole fill. 14:30 14:45 0.25 0 0 INTRM1 DRILL SFTY T PJSM for ND BOPE/NU Tree 14:45 16:15 1.50 0 0 INTRM1 DRILL NUND T ND BOPE,work on TD cable on roof 16:15 17:45 1.50 0 0 INTRM1 DRILL NUND T NU tree, continue work on TD cable 17:45 18:00 0.25 0 0 INTRM1 DRILL RURD T RU to test tree 18:00 19:15 1.25 0 0 INTRMI DRILL PRTS T Test tree to 250 psi low for 10 min, 5,000 psi high for 10 min-good 19:15 20:30 1.25 0 0 INTRM1 DRILL RURD T Pull TWC, RU hardline and hoses to Freeze protect well 20:30 21:00 0.50 0 0 INTRM1 DRILL SFTY T PJSM for Frz protect. Dowell pressure test lines to 2,000 psi with water. 21:00 22:00 1.00 0 0 INTRM1 DRILL FRZP T Dowell pump 70 bbls of diesel Frz Prot. Blow down lines to Dowell unit. 22:00 22:45 0.75 0 0 INTRM1 DRILL FRZP T U-tube diesel for Frz Prot. 22:45 23:15 0.50 0 0 INTRM1 DRILL RURD T Blow down hardline and hoses. RD pumping equipment. 23:15 23:30 0.25 0 0 INTRM1 DRILL RURD T Set BPV 23:30 23:45 0.25 0 0 INTRM1 DRILL PRTS T RU to test BPV Page 45 of 46 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 0 0 INTRM1 DRILL PRTS T Test BPV to 1,000 psi for 10 min- ok. RD for move to CD3-116B. Note: Released Rig at 2400 hrs 03/05/2014 Page 46of46 • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-130 i1Definitive Survey Report INAD27 20 March, 2014 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Project Western North Slope 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 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,743.55 ft Latitude: 70°25'8.970 N +E/-W 0.00 ft Easting: 387,799.14 ft Longitude: 150°54'50.530 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50 ft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 2/3/2014 14.81 79.84 57,361 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 36.62 0.00 0.00 325.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.71 196.00 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 246.80 523.41 CD3-130 Gyro(CD3-130) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:00 581.12 3,288.10 CD3-130 MWD I(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:00 3,383.04 15,416.73 CD3-130 MWD II(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.24 GYD-GC-SS(1) 196.00 0.43 347.45 196.00 146.88 -0.12 0.18 6,003,743.43 387,799.31 2.60 -0.20 GY0-GC-SS(1) 246.80 1.48 253.68 246.79 197.67 -0.11 -0.49 6,003,743.44 387,798.64 3.09 0.19 GYD-GC-SS(2) 264.41 1.99 249.47 264.40 215.28 -0.29 -1.00 6,003,743.28 387,798.14 2.98 0.34 GYD-GC-SS(2) 294.69 1.78 251.65 294.66 245.54 -0.62 -1.94 6,003,742.96 387,797.19 0.73 0.60 GYD-GC-SS(2) 340.33 1.68 252.62 340.28 291.16 -1.04 -3.25 6,003,742.55 387,795.87 0.23 1.01 GYD-GC-SS(2) 388.36 1.95 271.93 388.28 339.16 -1.22 -4.74 6,003,742.39 387,794.38 1.38 1.71 GYD-GC-SS(2) 430.88 2.33 297.40 430.78 381.66 -0.80 -6.23 6,003,742.84 387,792.90 2.38 2.92 GYD-GC-SS(2) 523.41 4.55 323.70 523.14 474.02 3.02 -10.07 6,003,746.72 387,789.11 2.88 8.25 GYD-GC-SS(2) 3/20/2014 4:23:35PM Page 2 COMPASS 2003.16 Build 69 i • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 581.12 6.81 328.21 580.56 531.44 7.78 -13.23 6,003,751.52 387,786.03 3.99 13.96 MWD+IFR-AK-CAZ-SC(3) 673.16 8.88 328.76 671.74 622.62 18.49 -19.79 6,003,762.33 387,779.63 2.25 26.50 MWD+IFR-AK-CAZ-SC(3) 766.65 11.82 329.96 763.69 714.57 32.95 -28.33 6,003,776.92 387,771.31 3.15 43.24 MWD+IFR-AK-CAZ-SC(3) 863.45 15.51 333.17 857.74 808.62 53.09 -39.14 6,003,797.21 387,760.81 3.89 65.94 MWD+IFR-AK-CAZ-SC(3) 957.79 21.32 339.17 947.22 898.10 80.40 -50.94 6,003,824.70 387,749.42 6.47 95.08 MWD+IFR-AK-CAZ-SC(3) 1,007.07 22.34 340.91 992.96 943.84 97.62 -57.19 6,003,842.01 387,743.43 2.45 112.77 MWD+IFR-AK-CAZ-SC(3) 1,050.33 20.83 341.51 1,033.19 984.07 112.69 -62.32 6,003,857.15 387,738.53 3.53 128.05 MWD+IFR-AK-CAZ-SC(3) 1,143.45 20.47 342.59 1,120.33 1,071.21 143.93 -72.44 6,003,888.54 387,728.88 0.56 159.45 MWD+IFR-AK-CAZ-SC(3) 1,237.29 22.95 344.74 1,207.50 1,158.38 177.24 -82.16 6,003,921.99 387,719.65 2.77 192.32 MWD+IFR-AK-CAZ-SC(3) 1,330.98 28.20 345.89 1,291.99 1,242.87 216.36 -92.38 6,003,961.25 387,710.03 5.63 230.22 MWD+IFR-AK-CAZ-SC(3) 1,377.32 31.42 347.29 1,332.19 1,283.07 238.77 -97.70 6,003,983.74 387,705.04 7.11 251.63 MWD+IFR-AK-CAZ-SC(3) 1,421.01 30.24 347.61 1,369.71 1,320.59 260.62 -102.57 6,004,005.66 387,700.51 2.73 272.32 MWD+IFR-AK-CAZ-SC(3) 1,515.28 34.39 351.00 1,449.36 1,400.24 310.13 -111.83 6,004,055.30 387,691.99 4.80 318.19 MWD+IFR-AK-CAZ-SC(3) 1,611.93 37.55 354.83 1,527.59 1,478.47 366.44 -118.76 6,004,111.70 387,685.91 4.01 368.29 MWD+IFR-AK-CAZ-SC(3) 1,706.68 37.56 356.81 1,602.70 1,553.58 424.03 -122.97 6,004,169.34 387,682.57 1.27 417.88 MWD+IFR-AK-CAZ-SC(3) 1,800.83 41.32 6.06 1,675.46 1,626.34 483.67 -121.28 6,004,228.94 387,685.15 7.40 465.76 MWD+IFR-AK-CAZ-SC(3) 1,848.28 43.60 10.34 1,710.48 1,661.36 515.35 -116.69 6,004,260.55 387,690.22 7.75 489.08 MWD+IFR-AK-CAZ-SC(3) 1,895.19 43.23 11.92 1,744.55 1,695.43 546.98 -110.47 6,004,292.08 387,696.91 2.45 511.42 MWD+IFR-AK-CAZ-SC(3) 1,989.27 45.20 16.54 1,812.00 1,762.88 610.53 -94.31 6,004,355.37 387,714.03 4.01 554.21 MWD+IFR-AK-CAZ-SC(3) 2,084.47 47.26 22.32 1,877.88 1,828.76 675.28 -71.40 6,004,419.77 387,737.90 4.89 594.11 MWD+IFR-AK-CAZ-SC(3) 2,178.59 47.75 27.18 1,941.48 1,892.36 738.26 -42.35 6,004,482.30 387,767.89 3.84 629.04 MWD+IFR-AK-CAZ-SC(3) 2,273.39 49.47 32.23 2,004.18 1,955.06 799.98 -7.10 6,004,543.47 387,804.07 4.39 659.37 MWD+IFR-AK-CAZ-SC(3) 2,367.82 53.11 36.13 2,063.24 2,014.12 860.87 34.33 6,004,603.73 387,846.40 5.02 685.49 MWD+IFR-AK-CAZ-SC(3) 2,415.77 54.92 37.46 2,091.41 2,042.29 891.93 57.57 6,004,634.44 387,870.10 4.39 697.61 MWD+IFR-AK-CAZ-SC(3) 2,462.23 56.48 38.46 2,117.59 2,068.47 922.19 81.18 6,004,664.34 387,894.16 3.80 708.85 MWD+IFR-AK-CAZ-SC(3) 2,556.15 59.99 40.46 2,167.03 2,117.91 983.81 131.94 6,004,725.18 387,945.84 4.15 730.21 MWD+IFR-AK-CAZ-SC(3) 2,650.78 63.05 42.23 2,212.15 2,163.03 1,046.23 186.89 6,004,786.76 388,001.72 3.63 749.83 MWD+IFR-AK-CAZ-SC(3) 2,746.62 66.54 44.40 2,252.97 2,203.85 1,109.30 246.38 6,004,848.92 388,062.14 4.18 767.36 MWD+IFR-AK-CAZ-SC(3) 2,840.08 69.42 45.36 2,288.00 2,238.88 1,170.68 307.52 6,004,909.37 388,124.19 3.23 782.58 MWD+IFR-AK-CAZ-SC(3) 2,936.52 69.04 49.56 2,322.22 2,273.10 1,231.63 373.93 6,004,969.31 388,191.51 4.09 794.41 MWD+IFR-AK-CAZ-SC(3) 3,028.95 67.59 51.65 2,356.37 2,307.25 1,286.14 440.30 6,005,022.81 388,258.68 2.62 801.00 MWD+IFR-AK-CAZ-SC(3) 3,124.43 67.67 51.38 2,392.71 2,343.59 1,341.09 509.41 6,005,076.71 388,328.60 0.27 806.37 MWD+IFR-AK-CAZ-SC(3) 3,217.46 67.26 50.87 2,428.36 2,379.24 1,395.02 576.31 6,005,129.62 388,396.30 0.67 812.17 MWD+IFR-AK-CAZ-SC(3) 3,288.10 67.57 51.09 2,455.49 2,406.37 1,436.08 626.98 6,005,169.92 388,447.58 0.52 816.75 MWD+IFR-AK-CAZ-SC(3) 3,353.62 67.73 50.04 2,480.41 2,431.29 1,474.57 673.78 6,005,207.70 388,494.95 1.50 821.43 MW0+IFR-AK-CAZ-SC(4) 10-3/4"x 13-1/2" 3,383.04 67.80 49.57 2,491.54 2,442.42 1,492.15 694.58 6,005,224.96 388,516.01 1.50 823.90 MWD+IFR-AK-CAZ-SC(4) 3,452.46 69.13 50.92 2,517.03 2,467.91 1,533.44 744.23 6,005,265.49 388,566.26 2.63 829.25 MWD+IFR-AK-CAZ-SC(4) 3,545.73 66.99 46.85 2,551.89 2,502.77 1,590.29 809.40 6,005,321.36 388,632.28 4.65 838.44 MWD+IFR-AK-CAZ-SC(4) 3,640.04 67.18 45.90 2,588.61 2,539.49 1,650.22 872.28 6,005,380.33 388,696.04 0.95 851.46 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 3 COMPASS 2003.16 Build 69 • • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100) (ft) Survey Tool Name 3,735.07 67.68 48.12 2,625.08 2,575.96 1,710.05 936.46 6,005,439.18 388,761.12 2.22 863.66 MWD+IFR-AK-CAZ-SC(4) 3,828.50 67.02 50.16 2,661.07 2,611.95 1,766.46 1,001.67 6,005,494.60 388,827.16 2.14 872.46 MWD+IFR-AK-CAZ-SC(4) 3,924.08 66.83 48.92 2,698.53 2,649.41 1,823.52 1,068.57 6,005,550.64 388,894.90 1.21 880.83 MWD+IFR-AK-CAZ-SC(4) 4,019.23 66.30 50.36 2,736.37 2,687.25 1,880.05 1,135.09 6,005,606.17 388,962.26 1.50 888.99 MWD+IFR-AK-CAZ-SC(4) 4,114.31 66.18 53.52 2,774.69 2,725.57 1,933.69 1,203.60 6,005,658.77 389,031.56 3.04 893.63 MWD+IFR-AK-CAZ-SC(4) 4,206.94 66.19 52.98 2,812.09 2,762.97 1,984.39 1,271.50 6,005,708.44 389,100.20 0.53 896.22 MWD+IFR-AK-CAZ-SC(4) 4,301.89 66.10 53.17 2,850.49 2,801.37 2,036.56 1,340.92 6,005,759.55 389,170.40 0.21 899.14 MWD+IFR-AK-CAZ-SC(4) 4,395.70 66.18 50.77 2,888.44 2,839.32 2,089.41 1,408.49 6,005,811.38 389,238.75 2.34 903.67 MWD+IFR-AK-CAZ-SC(4) 4,488.94 66.07 48.83 2,926.19 2,877.07 2,144.44 1,473.61 6,005,865.42 389,304.68 1.91 911.40 MWD+IFR-AK-CAZ-SC(4) 4,583.30 66.13 48.40 2,964.41 2,915.29 2,201.48 1,538.33 6,005,921.47 389,370.25 0.42 920.99 MWD+IFR-AK-CAZ-SC(4) 4,678.39 66.18 51.48 3,002.86 2,953.74 2,257.44 1,604.89 6,005,976.42 389,437.63 2.96 928.66 MWD+IFR-AK-CAZ-SC(4) 4,772.54 66.25 51.89 3,040.84 2,991.72 2,310.86 1,672.49 6,006,028.81 389,506.02 0.41 933.64 MWD+IFR-AK-CAZ-SC(4) 4,866.26 66.13 54.96 3,078.68 3,029.56 2,361.94 1,741.33 6,006,078.85 389,575.62 3.00 936.00 MWD+IFR-AK-CAZ-SC(4) 4,960.79 66.16 55.68 3,116.91 3,067.79 2,411.13 1,812.43 6,006,126.96 389,647.44 0.70 935.52 MWD+IFR-AK-CAZ-SC(4) 5,060.59 66.12 55.17 3,157.28 3,108.16 2,462.93 1,887.58 6,006,177.62 389,723.36 0.47 934.84 MWD+IFR-AK-CAZ-SC(4) 5,156.56 65.96 54.51 3,196.25 3,147.13 2,513.43 1,959.28 6,006,227.03 389,795.80 0.65 935.09 MWD+IFR-AK-CAZ-SC(4) 5,251.36 66.22 51.63 3,234.68 3,185.56 2,565.50 2,028.54 6,006,278.05 389,865.83 2.79 938.01 MWD+1FR-AK-CAZ-SC(4) 5,344.94 66.31 50.36 3,272.35 3,223.23 2,619.41 2,095.11 6,006,330.95 389,933.20 1.25 943.99 MWD+IFR-AK-CAZ-SC(4) 5,438.10 66.89 51.30 3,309.35 3,260.23 2,673.41 2,161.39 6,006,383.94 390,000.28 1.12 950.21 MWD+IFR-AK-CAZ-SC(4) 5,533.44 66.33 51.53 3,347.20 3,298.08 2,727.99 2,229.79 6,006,437.48 390,069.49 0.63 955.68 MWD+IFR-AK-CAZ-SC(4) 5,628.04 66.63 50.05 3,384.95 3,335.83 2,782.82 2,297.00 6,006,491.29 390,137.51 1.47 962.05 MWD+IFR-AK-CAZ-SC(4) 5,723.34 66.56 49.04 3,422.81 3,373.69 2,839.57 2,363.55 6,006,547.03 390,204.89 0.98 970.36 MWD+IFR-AK-CAZ-SC(4) 5,816.94 66.67 49.21 3,459.96 3,410.84 2,895.79 2,428.51 6,006,602.26 390,270.69 0.20 979.15 MWD+1FR-AK-CAZ-SC(4) 5,911.09 66.55 48.87 3,497.33 3,448.21 2,952.43 2,493.77 6,006,657.92 390,336.78 0.36 988.13 MWD+IFR-AK-CAZ-SC(4) 6,005.66 66.99 50.07 3,534.64 3,485.52 3,008.90 2,559.82 6,006,713.38 390,403.67 1.26 996.50 MWD+IFR-AK-CAZ-SC(4) 6,100.11 66.81 52.58 3,571.70 3,522.58 3,063.19 2,627.63 6,006,766.64 390,472.29 2.45 1,002.07 MWD+IFR-AK-CAZ-SC(4) 6,194.65 66.94 51.85 3,608.83 3,559.71 3,116.46 2,696.35 6,006,818.86 390,541.79 0.72 1,006.29 MWD+IFR-AK-CAZ-SC(4) 6,288.51 66.62 50.65 3,645.83 3,596.71 3,170.45 2,763.62 6,006,871.83 390,609.85 1.22 1,011.93 MWD+IFR-AK-CAZ-SC(4) 6,383.07 66.98 51.07 3,683.08 3,633.96 3,225.31 2,831.03 6,006,925.67 390,678.08 0.56 1,018.21 MWD+IFR-AK-CAZ-SC(4) 6,477.62 66.79 54.00 3,720.21 3,671.09 3,278.20 2,900.04 6,006,977.51 390,747.87 2.86 1,021.95 MWD+IFR-AK-CAZ-SC(4) 6,571.94 66.86 57.16 3,757.34 3,708.22 3,327.20 2,971.55 6,007,025.43 390,820.11 3.08 1,021.07 MWD+IFR-AK-CAZ-SC(4) 6,666.05 66.68 57.62 3,794.46 3,745.34 3,373.81 3,044.40 6,007,070.93 390,893.64 0.49 1,017.46 MWD+IFR-AK-CAZ-SC(4) 6,761.07 66.99 55.86 3,831.84 3,782.72 3,421.72 3,117.45 6,007,117.73 390,967.39 1.73 1,014.81 MWD+IFR-AK-CAZ-SC(4) 6,853.68 66.59 53.64 3,868.34 3,819.22 3,470.84 3,186.95 6,007,165.80 391,037.62 2.25 1,015.18 MWD+IFR-AK-CAZ-SC(4) 6,949.58 66.70 50.93 3,906.36 3,857.24 3,524.69 3,256.59. 6,007,218.59 391,108.05 2.60 1,019.35 MWD+IFR-AK-CAZ-SC(4) 7,044.55 66.60 50.73 3,944.00 3,894.88 3,579.76 3,324.19 6,007,272.64 391,176.46 0.22 1,025.69 MWD+1FR-AK-CAZ-SC(4) 7,136.17 66.91 50.51 3,980.16 3,931.04 3,633.17 3,389.25 6,007,325.06 391,242.32 0.40 1,032.12 MWD+1FR-AK-CAZ-SC(4) 7,232.25 66.69 50.61 4,018.01 3,968.89 3,689.27 3,457.46 6,007,380.12 391,311.35 0.25 1,038.96 MWD+1FR-AK-CAZ-SC(4) 7,327.48 66.72 49.59 4,055.67 4,006.55 3,745.38 3,524.56 6,007,435.21 391,379.28 0.98 1,046.43 MWD+IFR-AK-CAZ-SC(4) 7,421.49 66.97 48.71 4,092.64 4,043.52 3,801.91 3,589.94 6,007,490.75 391,445.50 0.90 1,055.24 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PMPage 4 COMPASS 2003.16 Build 69 4111 III Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,514.69 66.72 48.92 4,129.29 4,080.17 3,858.34 3,654.43 6,007,546.20 391,510.83 0.34 1064.47 MWD+IFR-AK-CAZ-SC(4) 7,610.78 66.68 48.12 4,167.30 4,118.18 3,916.80 3,720.55 6,007,603.65 391,577.81 0.77 1,074.43 MWD+IFR-AK-CAZ-SC(4) 7,704.43 66.85 48.44 4,204.24 4,155.12 3,974.06 3,784.78 6,007,659.94 391,642.89 0.36 1,084.50 MWD+IFR-AK-CAZ-SC(4) 7,799.45 66.72 50.92 4,241.70 4,192.58 4,030.56 3,851.35 6,007,715.43 391,710.30 2.40 1,092.60 MWD+IFR-AK-CAZ-SC(4) 7,893.38 66.88 51.97 4,278.71 4,229.59 4,084.37 3,918.87 6,007,768.21 391,778.61 1.04 1,097.95 MWD+IFR-AK-CAZ-SC(4) 7,988.00 66.72 53.23 4,315.98 4,266.86 4,137.19 3,987.95 6,007,819.98 391,848.48 1.24 1,101.60 MWD+IFR-AK-CAZ-SC(4) 8,082.53 66.65 52.74 4,353.40 4,304.28 4,189.46 4,057.27 6,007,871.19 391,918.56 0.48 1,104.65 MWD+IFR-AK-CAZ-SC(4) 8,176.47 66.91 52.48 4,390.43 4,341.31 4,241.88 4,125.86 6,007,922.58 391,987.93 0.38 1,108.25 MWD+IFR-AK-CAZ-SC(4) 8,271.16 66.54 52.12 4,427.85 4,378.73 4,295.07 4,194.68 6,007,974.72 392,057.54 0.52 1,112.34 MWD+IFR-AK-CAZ-SC(4) 8,364.84 66.97 52.06 4,464.82 4,415.70 4,347.96 4,262.59 6,008,026.58 392,126.23 0.46 1,116.71 MWD+IFR-AK-CAZ-SC(4) 8,459.62 66.66 52.27 4,502.14 4,453.02 4,401.40 4,331.40 6,008,078.98 392,195.83 0.39 1,121.02 MWD+IFR-AK-CAZ-SC(4) 8,553.48 66.76 52.13 4,539.25 4,490.13 4,454.24 4,399.53 6,008,130.78 392,264.73 0.17 1,125.24 MWD+IFR-AK-CAZ-SC(4) 8,648.03 66.88 50.93 4,576.47 4,527.35 4,508.31 4,467.57 6,008,183.82 392,333.58 1.17 1,130.50 MWD+IFR-AK-CAZ-SC(4) 8,742.02 66.82 49.83 4,613.42 4,564.30 4,563.42 4,534.14 6,008,237.92 392,400.96 1.08 1,137.46 MWD+IFR-AK-CAZ-SC(4) 8,836.80 66.82 48.91 4,650.73 4,601.61 4,620.15 4,600.27 6,008,293.65 392,467.93 0.89 1,146.00 MWD+IFR-AK-CAZ-SC(4) 8,930.85 66.78 50.56 4,687.78 4,638.66 4,676.02 4,666.23 6,008,348.51 392,534.71 1.61 1,153.94 MWD+IFR-AK-CAZ-SC(4) 9,026.05 66.75 51.24 4,725.33 4,676.21 4,731.19 4,734.11 6,008,402.65 392,603.42 0.66 1,160.19 MWD+IFR-AK-CAZ-SC(4) 9,119.64 66.81 52.29 4,762.23 4,713.11 4,784.42 4,801.67 6,008,454.86 392,671.76 1.03 1,165.04 MWD+IFR-AK-CAZ-SC(4) 9,213.88 66.71 51.72 4,799.42 4,750.30 4,837.73 4,869.91 6,008,507.13 392,740.79 0.57 1,169.57 MWD+IFR-AK-CAZ-SC(4) 9,308.74 66.79 51.57 4,836.87 4,787.75 4,891.81 4,938.26 6,008,560.17 392,809.93 0.17 1,174.67 MWD+IFR-AK-CAZ-SC(4) 9,402.78 66.77 52.33 4,873.94 4,824.82 4,945.08 5,006.31 6,008,612.40 392,878.78 0.74 1,179.27 MWD+IFR-AK-CAZ-SC(4) 9,497.26 66.79 51.76 4,911.19 4,862.07 4,998.48 5,074.77 6,008,664.77 392,948.03 0.55 1,183.74 MWD+IFR-AK-CAZ-SC(4) 9,591.75 66.72 51.92 4,948.48 4,899.36 5,052.12 5,143.04 6,008,717.37 393,017.08 0.17 1,188.53 MWD+IFR-AK-CAZ-SC(4) 9,686.09 66.74 51.86 4,985.76 4,936.64 5,105.61 5,211.23 6,008,769.82 393,086.07 0.06 1,193.23 MWD+IFR-AK-CAZ-SC(4) 9,779.88 66.69 51.71 5,022.83 4,973.71 5,158.90 5,278.92 6,008,822.09 393,154.54 0.16 1,198.06 MWD+IFR-AK-CAZ-SC(4) 9,874.95 66.61 50.83 5,060.51 5,011.39 5,213.51 5,347.01 6,008,875.66 393,223.44 0.85 1,203.74 MWD+IFR-AK-CAZ-SC(4) 9,969.46 66.32 49.56 5,098.25 5,049.13 5,268.98 5,413.57 6,008,930.12 393,290.82 1.27 1,211.00 MWD+IFR-AK-CAZ-SC(4) 10,064.16 67.78 49.07 5,135.18 5,086.06 5,325.83 5,479.70 6,008,985.96 393,357.79 1.61 1,219.64 MWD+IFR-AK-CAZ-SC(4) 10,157.71 67.27 48.49 5,170.94 5,121.82 5,382.79 5,544.72 6,009,041.94 393,423.65 0.79 1,229.00 MWD+IFR-AK-CAZ-SC(4) 10,252.37 67.12 48.97 5,207.63 5,158.51 5,440.35 5,610.30 6,009,098.50 393,490.09 0.49 1,238.53 MWD+IFR-AK-CAZ-SC(4) 10,347.03 67.37 50.97 5,244.25 5,195.13 5,496.49 5,677.14 6,009,153.62 393,557.76 1.97 1,246.19 MWD+IFR-AK-CAZ-SC(4) 10,441.03 67.49 52.78 5,280.33 5,231.21 5,550.07 5,745.42 6,009,206.17 393,626.83 1.78 1,250.92 MWD+IFR-AK-CAZ-SC(4) 10,535.67 68.00 54.67 5,316.17 5,267.05 5,601.89 5,816.03 6,009,256.92 393,698.21 1.93 1,252.86 MWD+IFR-AK-CAZ-SC(4) 10,629.43 68.55 , 55.28 5,350.88 5,301.76 5,651.88 5,887.36 6,009,305.82 393,770.27 0.84 1,252.90 MWD+IFR-AK-CAZ-SC(4) 10,724.10 68.57 54.10 5,385.48 5,336.36 5,702.81 5,959.27 6,009,355.67 393,842.93 1.16 1,253.38 MWD+IFR-AK-CAZ-SC(4) 10,818.37 68.88 53.26 5,419.69 5,370.57 5,754.84 6,030.04 6,009,406.62 393,914.47 0.89 1,255.40 MWD+IFR-AK-CAZ-SC(4) 10,912.78 69.47 51.94 5,453.26 5,404.14 5,808.44 6,100.14 6,009,459.15 393,985.36 1.45 1,259.10 MWD+IFR-AK-CAZ-SC(4) 11,007.74 70.06 51.78 5,486.10 5,436.98 5,863.47 6,170.22 6,009,513.12 394,056.25 0.64 1,263.98 MWD+IFR-AK-CAZ-SC(4) 11,101.53 69.97 51.87 5,518.15 5,469.03 5,917.94 6,239.51 6,009,566.54 394,126.35 0.13 1,268.86 MWD+IFR-AK-CAZ-SC(4) 11,195.95 70.88 50.27 5,549.79 5,500.67 5,973.84 6,308.71 6,009,621.39 394,196.37 1.86 1,274.96 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 5 COMPASS 2003.16 Build 69 ! • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 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 11,290.93. 70.55 50.16 5,581.16 5,532.04 6,031.21 6,377.60 6,009,677.71 394,266.11 0.36 1,282.44 MWD+IFR-AK-CAZ-SC(4) 11,384.87 70.84 50.04 5,612.22 5,563.10 6,088.08 6,445.61 6,009,733.55 394,334.97 0.33 1,290.01 MWD+IFR-AK-CAZ-SC(4) 11,479.42 70.95 49.71 5,643.16 5,594.04 6,145.66 6,513.93 6,009,790.09 394,404.14 0.35 1,297.99 MWD+IFR-AK-CAZ-SC(4) 11,573.10 71.03 49.91 5,673.68 5,624.56 6,202.82 6,581.59 6,009,846.22 394,472.64 0.22 1,306.01 MWD+IFR-AK-CAZ-SC(4) 11,668.92 71.69 50.04 5,704.30 5,655.18 6,261.21 6,651.12 6,009,903.55 394,543.03 0.70 1,313.96 MWD+IFR-AK-CAZ-SC(4) 11,762.21 71.41 49.94 5,733.83 5,684.71 6,318.10 6,718.90 6,009,959.42 394,611.65 0.32 1,321.69 MWD+IFR-AK-CAZ-SC(4) 11,857.35 71.27 50.73 5,764.27 5,715.15 6,375.64 6,788.28 6,010,015.90 394,681.89 0.80 1,329.02 MWD+IFR-AK-CAZ-SC(4) 11,950.71 71.88 50.21 5,793.77 5,744.65 6,432.01 6,856.60 6,010,071.24 394,751.04 0.84 1,336.01 MWD+IFR-AK-CAZ-SC(4) 12,045.73 72.48 50.38 5,822.85 5,773.73 6,489.80 6,926.19 6,010,127.97 394,821.49 0.65 1,343.43 MWD+IFR-AK-CAZ-SC(4) 12,139.47 71.94 50.70 5,851.49 5,802.37 6,546.53 6,995.11 6,010,183.65 394,891.24 0.66 1,350.37 MWD+IFR-AK-CAZ-SC(4) 12,234.00 71.89 48.55 5,880.84 5,831.72 6,604.74 7,063.56 6,010,240.81 394,960.56 2.16 1,358.79 MWD+IFR-AK-CAZ-SC(4) 12,328.96 71.63 47.37 5,910.56 5,861.44 6,665.13 7,130.54 6,010,300.19 395,028.43 1.21 1,369.84 MWD+IFR-AK-CAZ-SC(4) 12,422.95 71.86 47.27 5,940.01 5,890.89 6,725.64 7,196.16 6,010,359.70 395,094.95 0.26 1,381.77 MWD+IFR-AK-CAZ-SC(4) 12,516.72 71.78 46.93 5,969.26 5,920.14 6,786.28 7,261.42 6,010,419.35 395,161.11 0.35 1,394.02 MWD+IFR-AK-CAZ-SC(4) 12,611.42 71.02 46.15 5,999.47 5,950.35 6,848.02 7,326.57 6,010,480.09 395,227.17 1.12 1,407.22 MWD+IFR-AK-CAZ-SC(4) 12,705.71 71.65 46.96 6,029.65 5,980.53 6,909.44 7,391.43 6,010,540.53 395,292.94 1.05 1,420.34 MWD+IFR-AK-CAZ-SC(4) 12,800.93 72.07 45.30 6,059.29 6,010.17 6,972.15 7,456.66 6,010,602.25 395,359.10 1.71 1,434.29 MWD+IFR-AK-CAZ-SC(4) 12,894.81 72.30 42.33 6,088.02 6,038.90 7,036.64 7,518.53 6,010,665.79 395,421.92 3.02 1,451.63 MWD+IFR-AK-CAZ-SC(4) 12,988.85 73.05 38.28 6,116.04 6,066.92 7,105.09 7,576.58 6,010,733.36 395,480.99 4.19 1,474.40 MWD+IFR-AK-CAZ-SC(4) 13,083.83 72.57 34.38 6,144.12 6,095.00 7,178.17 7,630.32 6,010,805.61 395,535.83 3.96 1,503.44 MWD+IFR-AK-CAZ-SC(4) 13,178.07 71.24 30.74 6,173.39 6,124.27 7,253.65 7,678.53 6,010,880.35 395,585.16 3.93 1,537.61 MWD+IFR-AK-CAZ-SC(4) 13,271.12 70.65 27.65 6,203.78 6,154.66 7,330.41 7,721.43 6,010,956.46 395,629.20 3.20 1,575.89 MWD+IFR-AK-CAZ-SC(4) 13,366.63 70.34 25.46 6,235.67 6,186.55 7,410.93 7,761.68 6,011,036.36 395,670.65 2.19 1,618.77 MWD+IFR-AK-CAZ-SC(4) 13,459.98 70.21 23.40 6,267.18 6,218.06 7,490.93 7,798.02 6,011,115.80 395,708.19 2.08 1,663.46 MWD+IFR-AK-CAZ-SC(4) 13,554.94 69.58 21.16 6,299.83 6,250.71 7,573.44 7,831.83 6,011,197.78 395,743.23 2.31 1,711.65 MWD+IFR-AK-CAZ-SC(4) 13,649.51 69.11 17.88 6,333.19 6,284.07 7,656.83 7,861.39 6,011,280.71 395,774.04 3.28 1,763.00 MWD+IFR-AK-CAZ-SC(4) 13,742.82 69.67 14.32 6,366.05 6,316.93 7,740.73 7,885.60 6,011,364.23 395,799.51 3.62 1,817.84 MWD+IFR-AK-CAZ-SC(4) 13,837.83 69.45 11.47 6,399.23 6,350.11 7,827.50 7,905.47 6,011,450.68 395,820.68 2.82 1,877.52 MWD+IFR-AK-CAZ-SC(4) 13,932.61 70.22 9.44 6,431.91 6,382.79 7,914.99 7,921.61 6,011,537.91 395,838.13 2.17 1,939.93 MWD+IFR-AK-CAZ-SC(4) 14,026.68 71.71 8.68 6,462.59 6,413.47 8,002.80 7,935.61 6,011,625.49 395,853.45 1.76 2,003.83 MWD+IFR-AK-CAZ-SC(4) 14,120.90 71.24 8.03 6,492.53 6,443.41 8,091.19 7,948.59 6,011,713.67 395,867.75 0.82 2,068.79 MWD+IFR-AK-CAZ-SC(4) 14,216.13 72.18 9.10 6,522.41 6,473.29 8,180.60 7,962.06 6,011,802.86 395,882.56 1.45 2,134.30 MWD+IFR-AK-CAZ-SC(4) 14,309.29 74.03 9.40 6,549.48 6,500.36 8,268.57 7,976.39 6,011,890.60 395,898.21 2.01 2,198.15 MWD+IFR-AK-CAZ-SC(4) 7-5/8"X 9-7/8" 14,309.77 74.04 9.40 6,549.62 6,500.50 8,269.03 7,976.46 6,011,891.06 395,898.29 2.01 2,198.48 MWD+IFR-AK-CAZ-SC(4) 14,404.81 74.57 8.03 6,575.33 6,526.21 8,359.47 7,990.32 6,011,981.27 395,913.51 1.50 2,264.61 MWD+IFR-AK-CAZ-SC(4) 14,497.87 74.54 4.02 6,600.12 6,551.00 8,448.65 7,999.74 6,012,070.29 395,924.26 4.15 2,332.27 MWD+IFR-AK-CAZ-SC(4) 14,593.40 74.71 1.42 6,625.45 6,576.33 8,540.65 8,004.11 6,012,162.21 395,930.01 2.63 2,405.12 MWD+IFR-AK-CAZ-SC(4) 14,686.02 74.34 0.08 6,650.17 6,601.05 8,629.90 8,005.28 6,012,251.42 395,932.52 1.45 2,477.56 MWD+IFR-AK-CAZ-SC(4) 14,781.94 73.97 358.63 6,676.36 6,627.24 8,722.17 8,004.24 6,012,343.69 395,932.87 1.50 2,553.74 MWD+IFR-AK-CAZ-SC(4) 14,876.10 74.34 356.42 6,702.07 6,652.95 8,812.66 8,000.33 6,012,434.22 395,930.32 2.29 2,630.11 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 6 COMPASS 2003.16 Build 69 s s Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,970.72 77.01 355.58 6,725.48 6,676.36 8,904.10 7,993.93 6,012,525.74 395,925.30 2.95 2,708.69 MWD+IFR-AK-CAZ-SC(4) 15,064.14 79.73 354.81 6,744.31 6,695.19 8,995.27 7,986.26 6,012,617.01 395,919.00 3.02 2,787.77 MWD+IFR-AK-CAZ-SC(4) 15,158.59 79.56 352.00 6,761.29 6,712.17 9,087.56 7,975.59 6,012,709.44 395,909.72 2.93 2,869.48 MWD+IFR-AK-CAZ-SC(4) 15,252.77 79.73 350.02 6,778.22 6,729.10 9,179.06 7,961.11 6,012,801.14 395,896.62 2.08 2,952.74 MWD+IFR-AK-CAZ-SC(4) 15,346.80 80.19 347.89 6,794.61 6,745.49 9,269.93 7,943.38 6,012,892.26 395,880.25 2.28 3,037.35 MWD+IFR-AK-CAZ-SC(4) 15,416.73 80.08 346.82 6,806.60 6,757.48 9,337.16 7,928.29 6,012,959.70 395,866.19 1.52 3,101.07 MWD+IFR-AK-CAZ-SC(4) 15,483.00 80.08 346.82 6,818.01 6,768.89 9,400.72 7,913.41 6,013,023.47 395,852.26 0.00 3,161.67 PROJECTED to TD 3/20/2014 4:23:35PM Page 7 COMPASS 2003.16 Build 69 • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-130PB1 Definitive Survey Report N A D 2 7 20 March, 2014 • • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Project Western North Slope 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 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,743.55 ft Latitude: 70°25'8.970 N +El-W 0.00 ft Easting: 387,799.14 ft Longitude: 150°54'50.530 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft Wellbore CD3-130PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 1/11/2014 14.84 79.83 57,361 Design CD3-130PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 36.62 0.00 0.00 325.00 • Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.71 1,519.32 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 1,612.45 1,612.45 CD3-130PB1 MWD I(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2014 12:00:C 1,706.53 1,751.55 CD3-130PB1 Gyro II(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 3/20/2014 12:00 1,801.15 3,095.78 CD3-130PB1 MWD II(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/20/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.24 GYD-GC-SS(1) 265.12 2.21 334.14 265.10 215.98 1.34 -0.46 6,003,744.89 387,798.70 2.60 1.36 GYD-GC-SS(1) 358.32 3.07 336.64 358.20 309.08 5.24 -2.23 6,003,748.82 387,796.98 0.93 5.58 GYD-GC-SS(1) 450.68 3.42 340.45 450.41 401.29 10.11 -4.14 6,003,753.72 387,795.15 0.44 10.66 GYD-GC-SS(1) 542.74 4.16 337.25 542.27 493.15 15.78 -6.35 6,003,759.42 387,793.03 0.84 16.56 GYD-GC-SS(1) 635.62 5.94 338.90 634.78 585.66 23.37 -9.38 6,003,767.05 387,790.11 1.92 24.52 GYD-GC-SS(1) 727.71 7.28 342.70 726.26 677.14 33.39 -12.83 6,003,777.12 387,786.81 1.53 34.71 GYD-GC-SS(1) 820.83 8.92 346.36 818.45 769.33 46.04 -16.29 6,003,789.82 387,783.55 1.85 47.05 GYD-GC-SS(1) 913.55 12.62 349.44 909.52 860.40 62.98 -19.84 6,003,806.82 387,780.25 4.04 62.97 GYD-GC-SS(1) 3/20/2014 4:22:15PM Page 2 COMPASS 2003.16 Build 69 0 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/10(Y) (ft) Survey Tool Name 1,008.38 17.61 353.18 1,001.04 951.92 87.43 -23.45 6,003,831.31 387,777.01 5.36 85.06 GYD-GC-SS(1) 1,056.20 17.64 354.61 1,046.62 997.50 101.82 -24.98 6,003,845.73 387,775.69 0.91 97.74 GYD-GC-SS(1) 1,100.44 17.67 354.60 1,088.78 1,039.66 115.18 -26.25 6,003,859.10 387,774.63 0.07 109.41 GYD-GC-SS(1) 1,194.41 20.95 353.06 1,177.45 1,128.33 146.07 -29.62 6,003,890.03 387,771.72 3.53 136.64 GYD-GC-SS(1) 1,289.24 23.10 353.09 1,265.35 1,216.23 181.37 -33.91 6,003,925.39 387,767.96 2.27 168.01 GYD-GC-SS(1) 1,383.67 28.68 351.79 1,350.27 1,301.15 222.22 -39.38 6,003,966.31 387,763.11 5.94 204.61 GYD-GC-SS(1) 1,424.33 30.07 349.91 1,385.70 1,336.58 241.90 -42.55 6,003,986.04 387,760.23 4.10 222.56 GYD-GC-SS(1) 1,519.32 32.81 353.39 1,466.75 1,417.63 290.91 -49.69 6,004,035.15 387,753.83 3.46 266.80 GYD-GC-SS(1) 1,612.45 35.66 359.70 1,543.76 1,494.64 343.15 -52.74 6,004,087.42 387,751.57 4.88 311.34 MWD+IFR-AK-CAZ-SC(2) 1,706.53 38.04 6.38 1,619.07 1,569.95 399.41 -49.66 6,004,143.62 387,755.49 4.95 355.66 GYD-GC-SS(3) 1,751.55 40.07 8.60 1,654.03 1,604.91 427.52 -45.95 6,004,171.68 387,759.63 5.48 376.56 GYD-GC-SS(3) 1,801.15 40.30 9.88 1,691.92 1,642.80 459.11 -40.81 6,004,203.18 387,765.24 1.73 399.49 MWD+IFR-AK-CAZ-SC(4) 1,895.81 41.80 16.42 1,763.34 1,714.22 519.56 -26.63 6,004,263.41 387,780.32 4.80 440.88 MWD+IFR-AK-CAZ-SC(4) 1,990.70 42.87 21.04 1,833.50 1,784.38 580.04 -6.10 6,004,323.56 387,801.76 3.47 478.64 MWD+IFR-AK-CAZ-SC(4) 2,085.47 42.77 27.25 1,903.04 1,853.92 638.76 20.22 6,004,381.88 387,828.96 4.45 511.64 MWD+1FR-AK-CAZ-SC(4) 2,179.35 44.44 31.19 1,971.03 1,921.91 695.23 51.85 6,004,437.86 387,861.42 3.40 539.76 MWD+IFR-AK-CAZ-SC(4) 2,273.59 48.52 32.77 2,035.92 1,986.80 753.16 88.06 6,004,495.23 387,898.50 4.50 566.45 MWD+IFR-AK-CAZ-SC(4) 2,368.48 53.76 33.86 2,095.43 2,046.31 814.87 128.65 6,004,556.32 387,940.00 5.59 593.71 MWD+IFR-AK-CAZ-SC(4) 2,413.97 58.09 34.95 2,120.91 2,071.79 845.94 149.94 6,004,587.07 387,961.76 9.72 606.96 MWD+IFR-AK-CAZ-SC(4) 2,463.13 59.08 35.36 2,146.54 2,097.42 880.24 174.09 6,004,621.00 387,986.43 2.14 621.20 MWD+IFR-AK-CAZ-SC(4) 2,510.46 59.31 35.83 2,170.77 2,121.65 913.30 197.76 6,004,653.69 388,010.58 0.98 634.70 MWD+IFR-AK-CAZ-SC(4) 2,556.61 59.46 37.55 2,194.28 2,145.16 945.15 221.49 6,004,685.18 388,034.78 3.22 647.18 MWD+IFR-AK-CAZ-SC(4) 2,651.75 60.95 40.65 2,241.56 2,192.44 1,009.20 273.56 6,004,748.43 388,087.81 3.23 669.78 MWD+IFR-AK-CAZ-SC(4) 2,745.27 61.76 44.49 2,286.41 2,237.29 1,069.62 329.07 6,004,808.00 388,144.22 3.71 687.43 MWD+IFR-AK-CAZ-SC(4) 2,838.90 63.22 48.39 2,329.67 2,280.55 1,126.81 389.24 6,004,864.28 388,205.24 4.01 699.77 MWD+IFR-AK-CAZ-SC(4) 2,937.08 65.17 50.31 2,372.41 2,323.29 1,184.38 456.31 6,004,920.83 388,273.15 2.65 708.46 MWD+IFR-AK-CAZ-SC(4) 3,028.20 66.99 50.87 2,409.35 2,360.23 1,237.25 520.66 6,004,972.73 388,338.29 2.07 714.86 MWD+IFR-AK-CAZ-SC(4) 3,095.78 66.83 51.26 2,435.85 2,386.73 1,276.32 569.02 6,005,011.06 388,387.22 0.58 719.12 MWD+IFR-AK-CAZ-SC(4) 3,194.01 66.83 51.26 2,474.50 2,425.38 1,332.83 639.46 6,005,066.50 388,458.50 0.00 725.02 PROJECTED to TD 3/20/2014 4:22:15PM Page 3 COMPASS 2003.16 Build 69 3 Schlumberger Transmittal#: 6801 Drilling&Measurements DATA.�LOqGcGED MWD/LWD Log Product Delivery ' , -62014 .M K BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: CD3-130 Date Dispatched: 26-Mar-14 Job#: 13AKA0115 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Vision Service 2"MD 1 Contents on CD Vision Service 2 TVD 1 Contents on CD Vision Service 5'MD 1 Contents on CD Vision Service 5"TVD 1 Contents on CD LAS Digital Data Contents on CD SURVEYS 2 Contents on CD _FINAL SURVEY NAD 27 1 each FINAL SURVEY NAD 83 1 each EOW CD 1 CD LIAR 2 7 2014 AOGCC Please sign and email a copy to: Please sign and email/fax a copy to: afellt_a7,slb.com spacillo@slb.com Stephanie Pacillo Arina Fell Fax:907-561-8317 907-265-6519 ATO 1525 N ,/y1 Received By: r ' / 6#-/-14164"z' i • ego 240'13 RECEIVED MAR 2 7 2014 AOGCC ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-130 Definitive Survey Report ESAD 27 20 March, 2014 • I Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Project Western North Slope 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 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,743.55 ft Latitude: 70°25'8.970 N +EI-W 0.00 ft Easting: 387,799.14 ft Longitude: 150°54'50.530 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 2/3/2014 14.81 79.84 57,361 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.62 0.00 0.00 325.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.71 196.00 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 246.80 523.41 CD3-130 Gyro(CD3-130) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:00 581.12 3,288.10 CD3-130 MWD I(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:00 3,383.04 15,416.73 CD3-130 MWD II(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.24 GYD-GC-SS(1) 196.00 0.43 347.45 196.00 146.88 -0.12 0.18 6,003,743.43 387,799.31 2.60 -0.20 GYD-GC-SS(1) 246.80 1.48 253.68 246.79 197.67 -0.11 -0.49 6,003,743.44 387,798.64 3.09 0.19 GYD-GC-SS(2) 264.41 1.99 249.47 264.40 215.28 -0.29 -1.00 6,003,743.28 387,798.14 2.98 0.34 GYD-GC-SS(2) 294.69 1.78 251.65 294.66 245.54 -0.62 -1.94 6,003,742.96 387,797.19 0.73 0.60 GYD-GC-SS(2) 340.33 1.68 252.62 340.28 291.16 -1.04 -3.25 6,003,742.55 387,795.87 0.23 1.01 GYD-GC-SS(2) 388.36 1.95 271.93 388.28 339.16 -1.22 -4.74 6,003,742.39 387,794.38 1.38 1.71 GYD-GC-SS(2) 430.88 2.33 297.40 430.78 381.66 -0.80 -6.23 6,003,742.84 387,792.90 2.38 2.92 GYD-GC-SS(2) 523.41 4,55 323.70 523.14 474.02 3.02 -10.07 6,003,746.72 387,789.11 2.88 8.25 GYD-GC-SS(2) 3/20/2014 4:23:35PM Page 2 COMPASS 2003.16 Build 69 III • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS i-N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 581.12 6.81 328.21 580.56 531.44 7.78 -13.23 6,003,751.52 387,786.03 3.99 13.96 MWD+IFR-AK-CAZ-SC(3) 673.16 8.88 328.76 671.74 622.62 18.49 -19.79 6,003,762.33 387,779.63 2.25 26.50 MWD+IFR-AK-CAZ-SC(3) 766.65 11.82 329.96 763.69 714.57 32.95 -28.33 6,003,776.92 387,771.31 3.15 43.24 MWD+IFR-AK-CAZ-SC(3) 863.45 15.51 333.17 857.74 808.62 53.09 -39.14 6,003,797.21 387,760.81 3.89 65.94 MWD+IFR-AK-CAZ-SC(3) 957.79 21.32 339.17 947.22 898.10 80.40 -50.94 6,003,824.70 387,749.42 6.47 95.08 MWD+IFR-AK-CAZ-SC(3) 1,007.07 22.34 340.91 992.96 943.84 97.62 -57.19 6,003,842.01 387,743.43 2.45 112.77 MWD+IFR-AK-CAZ-SC(3) 1,050.33 20.83 341.51 1,033.19 984.07 112.69 -62.32 6,003,857.15 387,738.53 3.53 128.05 MWD+IFR-AK-CAZ-SC(3) 1,143.45 20.47 342.59 1,120.33 1,071.21 143.93 -72.44 6,003,888.54 387,728.88 0.56 159.45 MWD+IFR-AK-CAZ-SC(3) 1,237.29 22.95 344.74 1,207.50 1,158.38 177.24 -82.16 6,003,921.99 387,719.65 2.77 192.32 MWD+IFR-AK-CAZ-SC(3) 1,330.98 28.20 345.89 1,291.99 1,242.87 216.36 -92.38 6,003,961.25 387,710.03 5.63 230.22 MWD+IFR-AK-CAZ-SC(3) 1,377.32 31.42 347.29 1,332.19 1,283.07 238.77 -97.70 6,003,983.74 387,705.04 7.11 251.63 MWD+IFR-AK-CAZ-SC(3) 1,421.01 30.24 347.61 1,369.71 1,320.59 260.62 -102.57 6,004,005.66 387,700.51 2.73 272.32 MWD+IFR-AK-CAZ-SC(3) 1,515.28 34.39 351.00 1,449.36 1,400.24 310.13 -111.83 6,004,055.30 387,691.99 4.80 318.19 MWD+IFR-AK-CAZ-SC(3) 1,611.93 37.55 354.83 1,527.59 1,478.47 366.44 -118.76 6,004,111.70 387,685.91 4.01 368.29 MWD+IFR-AK-CAZ-SC(3) 1,706.68 37.56 356.81 1,602.70 1,553.58 424.03 -122.97 6,004,169.34 387,682.57 1.27 417.88 MWD+IFR-AK-CAZ-SC(3) 1,800.83 41.32 6.06 1,675.46 1,626.34 483.67 -121.28 6,004,228.94 387,685.15 7.40 465.76 MWD+IFR-AK-CAZ-SC(3) 1,848.28 43.60 10.34 1,710.48 1,661.36 515.35 -116.69 6,004,260.55 387,690.22 7.75 489.08 MWD+IFR-AK-CAZ-SC(3) 1,895.19 43.23 11.92 1,744.55 1,695.43 546.98 -110.47 6,004,292.08 387,696.91 2.45 511.42 MWD+IFR-AK-CAZ-SC(3) 1,989.27 45.20 16.54 1,812.00 1,762.88 610.53 -94.31 6,004,355.37 387,714.03 4.01 554.21 MWD+IFR-AK-CAZ-SC(3) 2,084.47 47.26 22.32 1,877.88 1,828.76 675.28 -71.40 6,004,419.77 387,737.90 4.89 594.11 MWD+IFR-AK-CAZ-SC(3) 2,178.59 47.75 27.18 1,941.48 1,892.36 738.26 -42.35 6,004,482.30 387,767.89 3.84 629.04 MWD+IFR-AK-CAZ-SC(3) 2,273.39 49.47 32.23 2,004.18 1,955.06 799.98 -7.10 6,004,543.47 387,804.07 4.39 659.37 MWD+IFR-AK-CAZ-SC(3) 2,367.82 53.11 36.13 2,063.24 2,014.12 860.87 34.33 6,004,603.73 387,846.40 5.02 685.49 MWD+IFR-AK-CAZ-SC(3) 2,415.77 54.92 37.46 2,091.41 2,042.29 891.93 57.57 6,004,634.44 387,870.10 4.39 697.61 MWD+IFR-AK-CAZ-SC(3) 2,462.23 56.48 38.46 2,117.59 2,068.47 922.19 81.18 6,004,664.34 387,894.16 3.80 708.85 MWD+IFR-AK-CAZ-SC(3) 2,556.15 59.99 40.46 2,167.03 2,117.91 983.81 131.94 6,004,725.18 387,945.84 4.15 730.21 MWD+IFR-AK-CAZ-SC(3) 2,650.78 63.05 42.23 2,212.15 2,163.03 1,046.23 186.89 6,004,786.76 388,001.72 3.63 749.83 MWD+IFR-AK-CAZ-SC(3) 2,746.62 66.54 44.40 2,252.97 2,203.85 1,109.30 246.38 6,004,848.92 388,062.14 4.18 767.36 MWD+IFR-AK-CAZ-SC(3) 2,840.08 69.42 45.36 2,288.00 2,238.88 1,170.68 307.52 6,004,909.37 388,124.19 3.23 782.58 MWD+IFR-AK-CAZ-SC(3) 2,936.52 69.04 49.56 2,322.22 2,273.10 1,231.63 373.93 6,004,969.31 388,191.51 4.09 794.41 MWD+IFR-AK-CAZ-SC(3) 3,028.95 67.59 51.65 2,356.37 2,307.25 1,286.14 440.30 6,005,022.81 388,258.68 2.62 801.00 MWD+IFR-AK-CAZ-SC(3) 3,124.43 67.67 51.38 2,392.71 2,343.59 1,341.09 509.41 6,005,076.71 388,328.60 0.27 806.37 MWD+IFR-AK-CAZ-SC(3) 3,217.46 67.26 50.87 2,428.36 2,379.24 1,395.02 576.31 6,005,129.62 388,396.30 0.67 812.17 MWD+IFR-AK-CAZ-SC(3) 3,288.10 67.57 51.09 2,455.49 2,406.37 1,436.08 626.98 6,005,169.92 388,447.58 0.52 816.75 MWD+IFR-AK-CAZ-SC(3) 3,353.62 67.73 50.04 2,480.41 2,431.29 1,474.57 673.78 6,005,207.70 388,494.95 1.50 821.43 MWD+IFR-AK-CAZ-SC(4) 10314"x 13-112 3,383.04 67.80 49.57 2,491.54 2,442.42 1,492.15 694.58 6,005,224.96 388,516.01 1.50 823.90 MWD+IFR-AK-CAZ-SC(4) 3,452.46 69.13 50.92 2,517.03 2,467.91 1,533.44 744.23 6,005,265.49 388,566.26 2.63 829.25 MWD+IFR-AK-CAZ-SC(4) 3,545.73 66.99 46.85 2,551.89 2,502.77 1,590.29 809.40 6,005,321.36 388,632.28 4.65 838.44 MWD+IFR-AK-CAZ-SC(4) 3,640.04 67.18 45.90 2,588.61 2,539.49 1,650.22 872.28 6,005,380.33 388,696.04 0.95 851.46 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 3 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,735.07 67.68 48.12 2,625.08 2,575.96 1,710.05 936.46 6,005,439.18 388,761 12 2.22 863.66 MWD+IFR-AK-CAZ-SC(4) 3,828.50 67.02 50.16 2,661.07 2,611.95 1,766.46 1,001.67 6,005,494.60 388,827.16 2.14 872.46 MWD+IFR-AK-CAZ-SC(4) 3,924.08 66.83 48.92 2,698.53 2,649.41 1,823.52 1,068.57 6,005,550.64 388,894.90 1.21 880.83 MWD+IFR-AK-CAZ-SC(4) 4,019.23 86.30 50.36 2,736.37 2,687.25 1,880.05 1,135.09 6,005,606.17 388,962.26 1.50 888.99 MWD+IFR-AK-CAZ-SC(4) 4,114.31 66.18 53.52 2,774.69 2,725.57 1,933.69 1,203.60 6,005,658.77 389,031.56 3.04 893.63 MWD+IFR-AK-CAZ-SC(4) 4,206.94 66.19 52.98 2,812.09 2,762.97 1,984.39 1,271.50 6,005,708.44 389,100.20 0.53 896.22 MWD+IFR-AK-CAZ-SC(4) 4,301.89 66.10 53.17 2,850.49 2,801.37 2,036.56 1,340.92 6,005,759.55 389,170.40 0.21 899.14 MWD+IFR-AK-CAZ-SC(4) 4,395.70 66.18 50.77 2,888.44 2,839.32 2,089.41 1,408.49 6,005,811.38 389,238.75 2.34 903.67 MWD+IFR-AK-CAZ-SC(4) 4,488.94 66.07 48.83 2,926.19 2,877.07 2,144.44 1,473.61 6,005,865.42 389,304.68 1.91 911.40 MWD+IFR-AK-CAZ-SC(4) 4,583.30 66.13 48.40 2,964.41 2,915.29 2,201.48 1,538.33 6,005,921.47 389,370.25 0.42 920.99 MWD+IFR-AK-CAZ-SC(4) 4,678.39 66.18 51.48 3,002.86 2,953.74 2,257.44 1,604.89 6,005,976.42 389,437.63 2.96 928.66 MWD+IFR-AK-CAZ-SC(4) 4,772.54 66.25 51.89 3,040.84 2,991.72 2,310.86 1,672.49 6,006,028.81 389,506.02 0.41 933.64 MWD+IFR-AK-CAZ-SC(4) 4,866.26 66.13 54.96 3,078.68 3,029.56 2,361.94 1,741.33 6,006,078.85 389,575.62 3.00 936.00 MWD+IFR-AK-CAZ-SC(4) 4,960.79 66.16 55.68 3,116.91 3,067.79 2,411.13 1,812.43 6,006,126.96 389,647.44 0.70 935.52 MWD+IFR-AK-CAZ-SC(4) 5,060.59 66.12 55.17 3,157.28 3,108.16 2,462.93 1,887.58 6,006,177.62 389,723.36 0.47 934.84 MWD+IFR-AK-CAZ-SC(4) 5,156.56 65.96 54.51 3,196.25 3,147.13 2,513.43 1,959.28 6,006,227.03 389,795.80 0.65 935.09 MWD+IFR-AK-CAZ-SC(4) 5,251.36 66.22 51.63 3,234.68 3,185.56 2,565.50 2,028.54 6,006,278.05 389,865.83 2.79 938.01 MWD+IFR-AK-CAZ-SC(4) 5,344.94 66.31 50.36 3,272.35 3,223.23 2,619.41 2,095.11 6,006,330.95 389,933.20 1.25 943.99 MWD+IFR-AK-CAZ-SC(4) 5,438.10 66.89 51.30 3,309.35 3,260.23 2,673.41 2,161.39 6,006,383.94 390,000.28 1.12 950.21 MWD+IFR-AK-CAZ-SC(4) 5,533.44 66.33 51.53 3,347.20 3,298.08 2,727.99 2,229.79 6,006,437.48 390,069.49 0.63 955.68 MWD+IFR-AK-CAZ-SC(4) 5,628.04 66.63 50.05 3,384.95 3,335.83 2,782.82 2,297.00 6,006,491.29 390,137.51 1.47 962.05 MWD+1FR-AK-CAZ-SC(4) 5,723.34 66.56 49.04 3,422.81 3,373.69 2,839.57 2,363.55 6,006,547.03 390,204.89 0.98 970.36 MWD+IFR-AK-CAZ-SC(4) 5,816.94 66.67 49.21 3,459.96 3,410.84 2,895.79 2,428.51 6,006,602.26 390,270.69 0.20 979.15 MWD+1FR-AK-CAZ-SC(4) 5,911.09 66.55 48.87 3,497.33 3,448.21 2,952.43 2,493.77 6,006,657.92 390,336.78 0.36 988.13 MWD+IFR-AK-CAZ-SC(4) 6,005.66 66.99 50.07 3,534.64 3,485.52 3,008.90 2,559.82 6,006,713.38 390,403.67 1.26 996.50 MWD+IFR-AK-CAZ-SC(4) 6,100.11 66.81 52.58 3,571.70 3,522.58 3,063.19 2,627.63 6,006,766.64 390,472.29 2.45 1,002.07 MWD+IFR-AK-CAZ-SC(4) 6,194.65 66.94 51.85 3,608.83 3,559.71 3,116.46 2,696.35 6,006,818.86 390,541.79 0.72 1,006.29 MWD+IFR-AK-CAZ-SC(4) 6,288.51 66.62 50.65 3,645.83 3,596.71 3,170.45 2,763.62 6,006,871.83 390,609.85 1.22 1,011.93 MWD+1FR-AK-CAZ-SC(4) 6,383.07 66.98 51.07 3,683.08 3,633.96 3,225.31 2,831.03 6,006,925.67 390,678.08 0.56 1,018.21 MWD+IFR-AK-CAZ-SC(4) 6,477.62 66.79 54.00 3,720.21 3,671.09 3,278.20 2,900.04 6,006,977.51 390,747.87 2.86 1,021.95 MWD+IFR-AK-CAZ-SC(4) 6,571.94 66.86 57.16 3,757.34 3,708.22 3,327.20 2,971.55 6,007,025.43 390,820.11 3.08 1,021.07 MWD+1FR-AK-CAZ-SC(4) 6,666.05 66.68 57.62 3,794.46 3,745.34 3,373.81 3,044.40 6,007,070.93 390,893.64 0.49 1,017.46 MWD+IFR-AK-CAZ-SC(4) 6,761.07 66.99 55.86 3,831.84 3,782.72 3,421.72 3,117.45 6,007,117.73 390,967.39 1.73 1,014.81 MWD+1FR-AK-CAZ-SC(4) 6,853.68 66.59 53.64 3,868.34 3,819.22 3,470.84 3,186.95 6,007,165.80 391,037.62 2.25 1,015.18 MWD+IFR-AK-CAZ-SC(4) 6,949.58 66.70 50.93 3,906.36 3,857.24 3,524.69 3,256.59 6,007,218.59 391,108.05 2.60 1,019.35 MWD+IFR-AK-CAZ-SC(4) 7,044.55 66.60 50.73 3,944.00 3,894.88 3,579.76 3,324.19 6,007,272.64 391,176.46 0.22 1,025.69 MWD+IFR-AK-CAZ-SC(4) 7,136.17 66.91 50.51 3,980.16 3,931.04 3,633.17 3,389.25 6,007,325.06 391,242.32 0.40 1,032.12 MWD+IFR-AK-CAZ-SC(4) 7,232.25 66.69 50.61 4,018.01 3,968.89 3,689.27 3,457.46 6,007,380.12 391,311.35 0.25 1,038.96 MWD+IFR-AK-CAZ-SC(4) 7,327.48 66.72 49.59 4,055.67 4,006.55 3,745.38 3,524.56 6,007,435.21 391,379.28 0.98 1,046.43 MWD+IFR-AK-CAZ-SC(4) 7,421.49 66.97 48.71 4,092.64 4,043.52 3,801.91 3,589.94 6,007,490.75 391,445.50 0.90 1,055.24 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 4 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,514.69 66.72 48.92 4,129.29 4,080.17 3,858.34 3,654.43 6,007,546.20 391,510.83 0.34 1,064.47 MWD+IFR-AK-CAZ-SC(4) 7,610.78 66.68 48.12 4,167.30 4,118.18 3,916.80 3,720.55 6,007,603.65 391,577.81 0.77 1,074.43 MWD+IFR-AK-CAZ-SC(4) 7,704.43 66.85 48.44 4,204.24 4,155.12 3,974.06 3,784.78 6,007,659.94 391,642.89 0.36 1,084.50 MWD+IFR-AK-CAZ-SC(4) 7,799.45 66.72 50.92 4,241.70 4,192.58 4,030.56 3,851.35 6,007,715.43 391,710.30 2.40 1,092.60 MWD+IFR-AK-CAZ-SC(4) 7,893.38 66.88 51.97 4,278.71 4,229.59 4,084.37 3,918.87 6,007,768.21 391,778.61 1.04 1,097.95 MWD+IFR-AK-CAZ-SC(4) 7,988.00 66.72 53.23 4,315.98 4,266.86 4,137.19 3,987.95 6,007,819.98 391,848.48 1.24 1,101.60 MWD+IFR-AK-CAZ-SC(4) 8,082.53 66.65 52.74 4,353.40 4,304.28 4,189.46 4,057.27 6,007,871.19 391,918.56 0.48 1,104.65 MWD+IFR-AK-CAZ-SC(4) 8,176.47 66.91 52.48 4,390.43 4,341.31 4,241.88 4,125.86 6,007,922.58 391,987.93 0.38 1,108.25 MWD+IFR-AK-CAZ-SC(4) 8,271.16 66.54 52.12 4,427.85 4,378.73 4,295.07 4,194.68 6,007,974.72 392,057.54 0.52 1,112.34 MWD+IFR-AK-CAZ-SC(4) 8,364.84 66.97 52.06 4,464.82 4,415.70 4,347.96 4,262.59 6,008,026.58 392,126.23 0.46 1,116.71 MWD+IFR-AK-CAZ-SC(4) 8,459.62 66.66 52.27 4,502.14 4,453.02 4,401.40 4,331.40 6,008,078.98 392,195.83 0.39 1,121.02 MWD+IFR-AK-CAZ-SC(4) 8,553.48 66.76 52.13 4,539.25 4,490.13 4,454.24 4,399.53 6,008,130.78 392,264.73 0.17 1,125.24 MWD+IFR-AK-CAZ-SC(4) 8,648.03 66.88 50.93 4,576.47 4,527.35 4,508.31 4,467.57 6,008,183.82 392,333.58 1.17 1,130.50 MWD+IFR-AK-CAZ-SC(4) 8,742.02 66.82 49.83 4,613.42 4,564.30 4,563.42 4,534.14 6,008,237.92 392,400.96 1.08 1,137.46 MWD+IFR-AK-CAZ-SC(4) 8,836.80 66.82 48.91 4,650.73 4,601.61 4,620.15 4,600.27 6,008,293.65 392,467.93 0.89 1,146.00 MWD+IFR-AK-CAZ-SC(4) 8,930.85 66.78 50.56 4,687.78 4,638.66 4,676.02 4,666.23 6,008,348.51 392,534.71 1.61 1,153.94 MWD+IFR-AK-CAZ-SC(4) 9,026.05 66.75 51.24 4,725.33 4,676.21 4,731.19 4,734.11 6,008,402.65 392,603.42 0.66 1,160.19 MWD+IFR-AK-CAZ-SC(4) 9,119.64 66.81 52.29 4,762.23 4,713.11 4,784.42 4,801.67 6,008,454.86 392,671.76 1.03 1,165.04 MWD+IFR-AK-CAZ-SC(4) 9,213.88 66.71 51.72 4,799.42 4,750.30 4,837.73 4,869.91 6,008,507.13 392,740.79 0.57 1,169.57 MWD+IFR-AK-CAZ-SC(4) 9,308.74 66.79 51.57 4,836.87 4,787.75 4,891.81 4,938.26 6,008,560.17 392,809.93 0.17 1,174.67 MWD+IFR-AK-CAZ-SC(4) 9,402.78 66.77 52.33 4,873.94 4,824.82 4,945.08 5,006.31 6,008,612.40 392,878.78 0.74 1,179.27 MWD+IFR-AK-CAZ-SC(4) 9,497.26 66.79 51.76 4,911.19 4,862.07 4,998.48 5,074.77 6,008,664.77 392,948.03 0.55 1,183.74 MWD+IFR-AK-CAZ-SC(4) 9,591.75 66.72 51.92 4,948.48 4,899.36 5,052.12 5,143.04 6,008,717.37 393,017.08 0.17 1,188.53 MWD+IFR-AK-CAZ-SC(4) 9,686.09 66.74 51.86 4,985.76 4,936.64 5,105.61 5,211.23 6,008,769.82 393,086.07 0.06 1,193.23 MWD+IFR-AK-CAZ-SC(4) 9,779.88 66.69 51.71 5,022.83 4,973.71 5,158.90 5,278.92 6,008,822.09 393,154.54 0.16 1,198.06 MWD+IFR-AK-CAZ-SC(4) 9,874.95 66.61 50.83 5,060.51 5,011.39 5,213.51 5,347.01 6,008,875.66 393,223.44 0.85 1,203.74 MWD+IFR-AK-CAZ-SC(4) 9,969.46 66.32 49.56 5,098.25 5,049.13 5,268.98 5,413.57 6,008,930.12 393,290.82 1.27 1,211.00 MWD+IFR-AK-CAZ-SC(4) 10,064.16 67.78 49.07 5,135.18 5,086.06 5,325.83 5,479.70 6,008,985.96 393,357.79 1.61 1,219.64 MWD+IFR-AK-CAZ-SC(4) 10,157.71 67.27 48.49 5,170.94 5,121.82 5,382.79 5,544.72 6,009,041.94 393,423.65 0.79 1,229.00 MWD+IFR-AK-CAZ-SC(4) 10,252.37 67.12 48.97 5,207.63 5,158.51 5,440.35 5,610.30 6,009,098.50 393,490.09 0.49 1,238.53 MWD+IFR-AK-CAZ-SC(4) 10,347.03 67.37 50.97 5,244.25 5,195.13 5,496.49 5,677.14 6,009,153.62 393,557.76 1.97 1,246.19 MWD+IFR-AK-CAZ-SC(4) 10,441.03 67.49 52.78 5,280.33 5,231.21 5,550.07 5,745.42 6,009,206.17 393,626.83 1.78 1,250.92 MWD+IFR-AK-CAZ-SC(4) 10,535.67 68.00 54.67 5,316.17 5,267.05 5,601.89 5,816.03 6,009,256.92 393,698.21 1.93 1,252.86 MWD+IFR-AK-CAZ-SC(4) 10,629.43 68.55 55.28 5,350.88 5,301.76 5,651.88 5,887.36 6,009,305.82 393,770.27 0.84 1,252.90 MWD+IFR-AK-CAZ-SC(4) 10,724.10 68.57 54.10 5,385.48 5,336.36 5,702.81 5,959.27 6,009,355.67 393,842.93 1.16 1,253.38 MWD+IFR-AK-CAZ-SC(4) 10,818.37 68.88 53.26 5,419.69 5,370.57 5,754.84 6,030.04 6,009,406.62 393,914.47 0.89 1,255.40 MWD+IFR-AK-CAZ-SC(4) 10,912.78 69.47 51.94 5,453.26 5,404.14 5,808.44 6,100.14 6,009,459.15 393,985.36 1.45 1,259.10 MWD+IFR-AK-CAZ-SC(4) 11,007.74 70.06 51.78 5,486.10 5,436.98 5,863.47 6,170.22 6,009,513.12 394,056.25 0.64 1,263.98 MWD+IFR-AK-CAZ-SC(4) 11,101.53 69.97 51.87 5,518.15 5,469.03 5,917.94 6,239.51 6,009,566.54 394,126.35 0.13 1,268.86 MWD+IFR-AK-CAZ-SC(4) 11,195.95 70.88 50.27 5,549.79 5,500.67 5,973.84 6,308.71 6,009,621.39 394,196.37 1.86 1,274.96 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 5 COMPASS 2003.16 Build 69 ID • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,290.93 70.55 50.16 5,581.16 5,532.04 6,031.21 6,377.60 6,009,677.71 394,266.11 0.36 1,282.44 MWD+IFR-AK-CAZ-SC(4) 11,384.87 70.84 50.04 5,612.22 5,563.10 6,088.08 6,445.61 6,009,733.55 394,334.97 0.33 1,290.01 MWD+IFR-AK-CAZ-SC(4) 11,479.42 70.95 49.71 5,643.16 5,594.04 6,145.66 6,513.93 6,009,790.09 394,404.14 0.35 1,297.99 MWD+IFR-AK-CAZ-SC(4) 11,573.10 71.03 49.91 5,673.68 5,624.56 6,202.82 6,581.59 6,009,846.22 394,472.64 0.22 1,306.01 MWD+IFR-AK-CAZ-SC(4) 11,668.92 71.69 50.04 5,704.30 5,655.18 6,261.21 6,651.12 6,009,903.55 394,543.03 0.70 1,313.96 MWD+IFR-AK-CAZ-SC(4) 11,762.21 71.41 49.94 5,733.83 5,684.71 6,318.10 6,718.90 6,009,959.42 394,611.65 0.32 1,321.69 MWD+IFR-AK-CAZ-SC(4) 11,857.35 71.27 50.73 5,764.27 5,715.15 6,375.64 6,788.28 6,010,015.90 394,681.89 0.80 1,329.02 MWD+IFR-AK-CAZ-SC(4) 11,950.71 71.88 50.21 5,793.77 5,744.65 6,432.01 6,856.60 6,010,071.24 394,751.04 0.84 1,336.01 MWD+IFR-AK-CAZ-SC(4) 12,045.73 72.48 50.38 5,822.85 5,773.73 6,489.80 6,926.19 6,010,127.97 394,821.49 0.65 1,343.43 MWD+IFR-AK-CAZ-SC(4) 12,139.47 71.94 50.70 5,851.49 5,802.37 6,546.53 6,995.11 6,010,183.65 394,891.24 0.66 1,350.37 MWD+IFR-AK-CAZ-SC(4) 12,234.00 71.89 48.55 5,880.84 5,831.72 6,604.74 7,063.56 6,010,240.81 394,960.56 2.16 1,358.79 MWD+IFR-AK-CAZ-SC(4) 12,328.96 71.63 47.37 5,910.56 5,861.44 6,665.13 7,130.54 6,010,300.19 395,028.43 1.21 1,369.84 MWD+IFR-AK-CAZ-SC(4) 12,422.95 71.86 47.27 5,940.01 5,890.89 6,725.64 7,196.16 6,010,359.70 395,094.95 0.26 1,381.77 MWD+IFR-AK-CAZ-SC(4) 12,516.72 71.78 46.93 5,969.26 5,920.14 6,786.28 7,261.42 6,010,419.35 395,161.11 0.35 1,394.02 MWD+IFR-AK-CAZ-SC(4) 12,611.42 71.02 46.15 5,999.47 5,950.35 6,848.02 7,326.57 6,010,480.09 395,227.17 1.12 1,407.22 MWD+IFR-AK-CAZ-SC(4) 12,705.71 71.65 46.96 6,029.65 5,980.53 6,909.44 7,391.43 6,010,540.53 395,292.94 1.05 1,420.34 MWD+IFR-AK-CAZ-SC(4) 12,800.93 72.07 45.30 6,059.29 6,010.17 6,972.15 7,456.66 6,010,602.25 395,359.10 1.71 1,434.29 MWD+IFR-AK-CAZ-SC(4) 12,894.81 72.30 42.33 6,088.02 6,038.90 7,036.64 7,518.53 6,010,665.79 395,421.92 3.02 1,451.63 MWD+IFR-AK-CAZ-SC(4) 12,988.85 73.05 38.28 6,116.04 6,066.92 7,105.09 7,576.58 6,010,733.36 395,480.99 4.19 1,474.40 MWD+IFR-AK-CAZ-SC(4) 13,083.83 72.57 34.38 6,144.12 6,095.00 7,178.17 7,630.32 6,010,805.61 395,535.83 3.96 1,503.44 MWD+IFR-AK-CAZ-SC(4) 13,178.07 71.24 30.74 6,173.39 6,124.27 7,253.65 7,678.53 6,010,880.35 395,585.16 3.93 1,537.61 MWD+IFR-AK-CAZ-SC(4) 13,271.12 70.65 27.65 6,203.78 6,154.66 7,330.41 7,721.43 6,010,956.46 395,629.20 3.20 1,575.89 MWD+IFR-AK-CAZ-SC(4) 13,366.63 70.34 25.46 6,235.67 6,186.55 7,410.93 7,761.68 6,011,036.36 395,670.65 2.19 1,618.77 MWD+IFR-AK-CAZ-SC(4) 13,459.98 70.21 23.40 6,267.18 6,218.06 7,490.93 7,798.02 6,011,115.80 395,708.19 2.08 1,663.46 MWD+IFR-AK-CAZ-SC(4) 13,554.94 69.58 21.16 6,299.83 6,250.71 7,573.44 7,831.83 6,011,197.78 395,743.23 2.31 1,711.65 MWD+IFR-AK-CAZ-SC(4) 13,649.51 69.11 17.88 6,333.19 6,284.07 7,656.83 7,861.39 6,011,280.71 395,774.04 3.28 1,763.00 MWD+IFR-AK-CAZ-SC(4) 13,742.82 69.67 14.32 6,366.05 6,316.93 7,740.73 7,885.60 6,011,364.23 395,799.51 3.62 1,817.84 MWD+IFR-AK-CAZ-SC(4) 13,837.83 69.45 11.47 6,399.23 6,350.11 7,827.50 7,905.47 6,011,450.68 395,820.68 2.82 1,877.52 MWD+IFR-AK-CAZ-SC(4) 13,932.61 70.22 9.44 6,431.91 6,382.79 7,914.99 7,921.61 6,011,537.91 395,838.13 2.17 1,939.93 MWD+IFR-AK-CAZ-SC(4) 14,026.68 71.71 8.68 6,462.59 6,413.47 8,002.80 7,935.61 6,011,625.49 395,853.45 1.76 2,003.83 MWD+IFR-AK-CAZ-SC(4) 14,120.90 71.24 8.03 6,492.53 6,443.41 8,091.19 7,948.59 6,011,713.67 395,867.75 0.82 2,068.79 MWD+IFR-AK-CAZ-SC(4) 14,216.13 72.18 9.10 6,522.41 6,473.29 8,180.60 7,962.06 6,011,802.86 395,882.56 1.45 2,134.30 MWD+IFR-AK-CAZ-SC(4) 14,309.29 74.03 9.40 6,549.48 6,500.36 8,268.57 7,976.39 6,011,890.60 395,898.21 2.01 2,198.15 MWD+IFR-AK-CAZ-SC(4) 7-518"X 9-7/8" 14,309.77 74.04 9.40 6,549.62 6,500.50 8,269.03 7,976.46 6,011,891.06 395,898.29 2.01 2,198.48 MWD+IFR-AK-CAZ-SC(4) 14,404.81 74.57 8.03 6,575.33 6,526.21 8,359.47 7,990.32 6,011,981.27 395,913.51 1.50 2,264.61 MWD+IFR-AK-CAZ-SC(4) 14,497.87 74.54 4.02 6,600.12 6,551.00 8,448.65 7,999.74 6,012,070.29 395,924.26 4.15 2,332.27 MWD+IFR-AK-CAZ-SC(4) 14,593.40 74.71 1.42 6,625.45 6,576.33 8,540.65 8,004.11 6,012,162.21 395,930.01 2.63 2,405.12 MWD+IFR-AK-CAZ-SC(4) 14,686.02 74.34 0.08 6,650.17 6,601.05 8,629.90 8,005.28 6,012,251.42 395,932.52 1.45 2,477.56 MWD+IFR-AK-CAZ-SC(4) 14,781.94 73.97 358.63 6,676.36 6,627.24 8,722.17 8,004.24 6,012,343.69 395,932.87 1.50 2,553.74 MWD+IFR-AK-CAZ-SC(4) 14,876.10 74.34 356.42 6,702.07 6,652.95 8,812.66 8,000.33 6,012,434.22 395,930.32 2.29 2,630.11 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 4:23:35PM Page 6 COMPASS 2003.16 Build 69 i • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 14,970.72 77.01 355.58 6,725.48 6,676.36 8,904.10 7,993.93 6,012,525.74 395,925.30 2.95 2,708.69 MWD+IFR-AK-CAZ-SC(4) 15,064.14 79.73 354.81 6,744.31 6,695.19 8,995.27 7,986.26 6,012,617.01 395,919.00 3.02 2,787.77 MWD+IFR-AK-CAZ-SC(4) 15,158.59 79.56 352.00 6,761.29 6,712.17 9,087.56 7,975.59 6,012,709.44 395,909.72 2.93 2,869.48 MWD+IFR-AK-CAZ-SC(4) 15,252.77 79.73 350.02 6,778.22 6,729.10 9,179.06 7,961.11 6,012,801.14 395,896.62 2.08 2,952.74 MWD+IFR-AK-CAZ-SC(4) 15,346.80 80.19 347.89 6,794.61 6,745.49 9,269.93 7,943.38 6,012,892.26 395,880.25 2.28 3,037.35 MWD+IFR-AK-CAZ-SC(4) 15,416.73 80.08 346.82 6,806.60 6,757.48 9,337.16 7,928.29 6,012,959.70 395,866.19 1.52 3,101.07 MWD+IFR-AK-CAZ-SC(4) 15,483.00 80.08 346.82 6,818.01 6,768.89 9,400.72 7,913.41 6,013,023.47 395,852.26 0.00 3,161.67 PROJECTED to TD 3/20/2014 4:23:35PM Page 7 COMPASS 2003.16 Build 69 • • 2 fl-13 RECEIVED MAR 2 7 2014 AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-130 Definitive Survey Report 20 March, 2014 i • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Project Western North Slope,North Slope Alaska,United States 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 4 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,490.74 ft Latitude: 70°25'7.804 N +E/-W 0.00 ft Easting: 1,527,831.05 ft Longitude: 150°55'1.908 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50 ft Wellbore CD3-130 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 2/3/2014 19.02 80.86 57,594 Design CD3-130 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 36.62 0.00 0.00 325.00 Survey Program Date 3/20/2014 From To (ft) (ft) Survey(Wellbore) Tool Name . Description Survey Date 116.71 196.00 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 246.80 523.41 CD3-130 Gyro(CD3-130) GYD-GC-SS Gyrodata gyro single shots 2/11/2014 12:00 581.12 3,288.10 CD3-130 MWD I(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/11/2014 12:00 3,383.04 15,416.73 CD3-130 MWD II(CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,490.74 1,527,831.05 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,490.66 1,527,831.09 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,490.56 1,527,831.21 0.23 -0.24 GYD-GC-SS(1) 196.00 0.43 347.45 196.00 146.88 -0.12 0.18 6,003,490.62 1,527,831.22 2.60 -0.20 GYD-GC-SS(1) 246.80 1.48 253.68 246.79 197.67 -0.11 -0.49 6,003,490.63 1,527,830.55 3.09 0.19 GYD-GC-SS(2) 264.41 1.99 249.47 264.40 215.28 -0.29 -1.00 6,003,490.47 1,527,830.05 2.98 0.34 GYD-GC-SS(2) 294.69 1.78 251.65 294.66 245.54 -0.62 -1.94 6,003,490.15 1,527,829.10 0.73 0.60 GYD-GC-SS(2) 340.33 1.68 252.62 340.28 291.16 -1.04 -3.25 6,003,489.75 1,527,827.79 0.23 1.01 GYD-GC-SS(2) 388.36 1.95 271.93 388.28 339.16 -1.22 -4.74 6,003,489.59 1,527,826.29 1.38 1.71 GYD-GC-SS(2) 430.88 2.33 297.40 430.78 381.66 -0.80 -6.23 6,003,490.03 1,527,824.81 2.38 2.92 GYD-GC-SS(2) 523.41 4.55 323.70 523.14 474.02 3.02 -10.07 6,003,493.91 1,527,821.03 2.88 8.25 GYD-GC-SS(2) 3/20/2014 3:53:23PM Page 2 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 581.12 6.81 328.21 580.56 531.44 7.78 -13.23 6,003,498.71 1,527,817.94 3.99 13.96 MWD+IFR-AK-CAZ-SC(3) 673.16 8.88 328.76 671.74 622.62 18.49 -19.79 6,003,509.52 1,527,811.54 2.25 26.50 MWD+IFR-AK-CAZ-SC(3) 766.65 11.82 329.96 763.69 714.57 32.95 -28.33 6,003,524.11 1,527,803.23 3.15 43.24 MWD+IFR-AK-CAZ-SC(3) 863.45 15.51 333.17 857.74 808.62 53.09 -39.14 6,003,544.41 1,527,792.72 3.89 65.94 MWD+IFR-AK-CAZ-SC(3) 957.79 21.32 339.17 947.22 898.10 80.40 -50.94 6,003,571.89 1,527,781.33 6.47 95.08 MWD+IFR-AK-CAZ-SC(3) 1,007.07 22.34 340.91 992.96 943.84 97.62 -57.19 6,003,589.21 1,527,775.35 2.45 112.77 MWD+IFR-AK-CAZ-SC(3) 1,050.33 20.83 341.51 1,033.19 984.07 112.69 -62.32 6,003,604.35 1,527,770.45 3.53 128.05 MWD+IFR-AK-CAZ-SC(3) 1,143.45 20.47 342.59 1,120.33 1,071.21 143.93 -72.44 6,003,635.73 1,527,760.80 0.56 159.45 MWD+IFR-AK-CAZ-SC(3) 1,237.29 22.95 344.74 1,207.50 1,158.38 177.24 -82.16 6,003,669.19 1,527,751.57 2.77 192.32 MWD+IFR-AK-CAZ-SC(3) 1,330.98 28.20 345.89 1,291.99 1,242.87 216.36 -92.38 6,003,708.45 1,527,741.96 5.63 230.22 MWD+IFR-AK-CAZ-SC(3) 1,377.32 31.42 347.29 1,332.19 1,283.07 238.77 -97.70 6,003,730.93 1,527,736.97 7.11 251.63 MWD+IFR-AK-CAZ-SC(3) 1,421.01 30.24 347.61 1,369.71 1,320.59 260.62 -102.57 6,003,752.86 1,527,732.43 2.73 272.32 MWD+IFR-AK-CAZ-SC(3) 1,515.28 34.39 351.00 1,449.36 1,400.24 310.13 -111.83 6,003,802.49 1,527,723.92 4.80 318.19 MWD+IFR-AK-CAZ-SC(3) 1,611.93 37.55 354.83 1,527.59 1,478.47 366.44 -118.76 6,003,858.90 1,527,717.84 4.01 368.29 MWD+IFR-AK-CAZ-SC(3) 1,706.68 37.56 356.81 1,602.70 1,553.58 424.03 -122.97 6,003,916.54 1,527,714.50 1.27 417.88 MWD+IFR-AK-CAZ-SC(3) 1,800.83 41.32 6.06 1,675.46 1,626.34 483.67 -121.28 6,003,976.14 1,527,717.09 7.40 465.76 MWD+IFR-AK-CAZ-SC(3) 1,848.28 43.60 10.34 1,710.48 1,661.36 515.35 -116.69 6,004,007.75 1,527,722.15 7.75 489.08 MWD+IFR-AK-CAZ-SC(3) 1,895.19 43.23 11.92 1,744.55 1,695.43 546.98 -110.47 6,004,039.28 1,527,728.85 2.45 511.42 MWD+IFR-AK-CAZ-SC(3) 1,989.27 45.20 16.54 1,812.00 1,762.88 610.53 -94.31 6,004,102.57 1,527,745.97 4.01 554.21 MWD+IFR-AK-CAZ-SC(3) 2,084.47 47.26 22.32 1,877.88 1,828.76 675.28 -71.40 6,004,166.96 1,527,769.85 4.89 594.11 MWD+IFR-AK-CAZ-SC(3) 2,178.59 47.75 27.18 1,941.48 1,892.36 738.26 -42.35 6,004,229.50 1,527,799.84 3.84 629.04 MWD+IFR-AK-CAZ-SC(3) 2,273.39 49.47 32.23 2,004.18 1,955.06 799.98 -7.10 6,004,290.67 1,527,836.02 4.39 659.37 MWD+IFR-AK-CAZ-SC(3) 2,367.82 53.11 36.13 2,063.24 2,014.12 860.87 34.33 6,004,350.92 1,527,878.36 5.02 685.49 MWD+IFR-AK-CAZ-SC(3) 2,415.77 54.92 37.46 2,091.41 2,042.29 891.93 57.57 6,004,381.63 1,527,902.06 4.39 697.61 MWD+IFR-AK-CAZ-SC(3) 2,462.23 56.48 38.46 2,117.59 2,068.47 922.19 81.18 6,004,411.52 1,527,926.12 3.80 708.85 MWD+IFR-AK-CAZ-SC(3) 2,556.15 59.99 40.46 2,167.03 2,117.91 983.81 131.94 6,004,472.37 1,527,977.80 4.15 730.21 MWD+IFR-AK-CAZ-SC(3) 2,650.78 63.05 42.23 2,212.15 2,163.03 1,046.23 186.89 6,004,533.95 1,528,033.68 3.63 749.83 MWD+IFR-AK-CAZ-SC(3) 2,746.62 66.54 44.40 2,252.97 2,203.85 1,109.30 246.38 6,004,596.10 1,528,094.11 4.18 767.36 MWD+IFR-AK-CAZ-SC(3) 2,840.08 69.42 45.36 2,288.00 2,238.88 1,170.68 307.52 6,004,656.55 1,528,156.16 3.23 782.58 MWD+IFR-AK-CAZ-SC(3) 2,936.52 69.04 49.56 2,322.22 2,273.10 1,231.63 373.93 6,004,716.48 1,528,223.48 4.09 794.41 MWD+IFR-AK-CAZ-SC(3) 3,028.95 67.59 51.65 2,356.37 2,307.25 1,286.14 440.30 6,004,769.98 1,528,290.65 2.62 801.00 MWD+IFR-AK-CAZ-SC(3) 3,124.43 67.67 51.38 2,392.71 2,343.59 1,341.09 509.41 6,004,823.88 1,528,360.58 0.27 806.37 MWD+IFR-AK-CAZ-SC(3) 3,217.46 67.26 50.87 2,428.36 2,379.24 1,395.02 576.31 6,004,876.79 1,528,428.28 0.67 812.17 MWD+IFR-AK-CAZ-SC(3) • 3,288.10 67.57 51.09 2,455.49 2,406.37 1,436.08 626.98 6,004,917.08 1,528,479.56 0.52 816.75 MWD+IFR-AK-CAZ-SC(3) 3,353.62 67.73 50.04 2,480.41 2,431.29 1,474.57 673.78 6,004,954.86 1,528,526.93 1.50 821.43 MWD+IFR-AK-CAZ-SC(4) 10.3/4"x 13-1/2" 3,383.04 67.80 49.57 2,491.54 2,442.42 1,492.15 694.58 6,004,972.11 1,528,548.00 1.50 823.90 MWD+IFR-AK-CAZ-SC(4) 3,452.46 69.13 50.92 2,517.03 2,467.91 1,533.44 744.23 6,005,012.65 1,528,598.25 2.63 829.25 MWD+IFR-AK-CAZ-SC(4) 3,545.73 66.99 46.85 2,551.89 2,502.77 1,590.29 809.40 6,005,068.51 1,528,664.27 4.65 838.44 MWD+IFR-AK-CAZ-SC(4) 3,640.04 67.18 45.90 2,588.61 2,539.49 1,650.22 872.28 6,005,127.48 1,528,728.04 0.95 851.46 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 3:53:23PM Page 3 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,735.07 67.68 48.12 2,625.08 2,575.96 1,710.05 936.46 6,005,186.33 1,528,793.12 2.22 863.66 MWD+IFR-AK-CAZ-SC(4) 3,828.50 67.02 50.16 2,661.07 2,611.95 1,766.46 1,001.67 6,005,241.74 1,528,859.16 2.14 872.46 MWD+IFR-AK-CAZ-SC(4) 3,924.08 66.83 48.92 2,698.53 2,649.41 1,823.52 1,068.57 6,005,297.78 1,528,926.91 1.21 880.83 MWD+IFR-AK-CAZ-SC(4) 4,019.23 66.30 50.36 2,736.37 2,687.25 1,880.05 1,135.09 6,005,353.30 1,528,994.27 1.50 888.99 MWD+IFR-AK-CAZ-SC(4) 4,114.31 66.18 53.52 2,774.69 2,725.57 1,933.69 1,203.60 6,005,405.89 1,529,063.57 3.04 893.63 MWD+IFR-AK-CAZ-SC(4) 4,206.94 66.19 52.98 2,812.09 2,762.97 1,984.39 1,271.50 6,005,455.56 1,529,132.22 0.53 896.22 MWD+IFR-AK-CAZ-SC(4) 4,301.89 66.10 53.17 2,850.49 2,801.37 2,036.56 1,340.92 6,005,506.68 1,529,202.41 0.21 899.14 MWD+IFR-AK-CAZ-SC(4) 4,395.70 66.18 50.77 2,888.44 2,839.32 2,089.41 1,408.49 6,005,558.50 1,529,270.77 2.34 903.67 MWD+IFR-AK-CAZ-SC(4) 4,488.94 66.07 48.83 2,926.19 2,877.07 2,144.44 1,473.61 6,005,612.53 1,529,336.70 1.91 911.40 MWD+IFR-AK-CAZ-SC(4) 4,583.30 66.13 48.40 2,964.41 2,915.29 2,201.48 1,538.33 6,005,668.58 1,529,402.28 0.42 920.99 MWD+IFR-AK-CAZ-SC(4) 4,678.39 66.18 51.48 3,002.86 2,953.74 2,257.44 1,604.89 6,005,723.53 1,529,469.66 2.96 928.66 MWD+IFR-AK-CAZ-SC(4) 4,772.54 66.25 51.89 3,040.84 2,991.72 2,310.86 1,672.49 6,005,775.91 1,529,538.05 0.41 933.64 MWD+IFR-AK-CAZ-SC(4) 4,866.26 66.13 54.96 3,078.68 3,029.56 2,361.94 1,741.33 6,005,825.95 1,529,607.66 3.00 936.00 MWD+IFR-AK-CAZ-SC(4) 4,960.79 66.16 55.68 3,116.91 3,067.79 2,411.13 1,812.43 6,005,874.06 1,529,679.48 0.70 935.52 MWD+IFR-AK-CAZ-SC(4) 5,060.59 66.12 55.17 3,157.28 3,108.16 2,462.93 1,887.58 6,005,924.71 1,529,755.39 0.47 934.84 MWD+IFR-AK-CAZ-SC(4) 5,156.56 65.96 54.51 3,196.25 3,147.13 2,513.43 1,959.28 6,005,974.12 1,529,827.84 0.65 935.09 MWD+IFR-AK-CAZ-SC(4) 5,251.36 66.22 51.63 3,234.68 3,185.56 2,565.50 2,028.54 6,006,025.13 1,529,897.88 2.79 938.01 MWD+IFR-AK-CAZ-SC(4) 5,344.94 66.31 50.36 3,272.35 3,223.23 2,619.41 2,095.11 6,006,078.03 1,529,965.24 1.25 943.99 MWD+IFR-AK-CAZ-SC(4) 5,438.10 66.89 51.30 3,309.35 3,260.23 2,673.41 2,161.39 6,006,131.02 1,530,032.33 1.12 950.21 MWD+IFR-AK-CAZ-SC(4) 5,533.44 66.33 51.53 3,347.20 3,298.08 2,727.99 2,229.79 6,006,184.56 1,530,101.54 0.63 955.68 MWD+IFR-AK-CAZ-SC(4) 5,628.04 66.63 50.05 3,384.95 3,335.83 2,782.82 2,297.00 6,006,238.36 1,530,169.56 1.47 962.05 MWD+IFR-AK-CAZ-SC(4) 5,723.34 66.56 49.04 3,422.81 3,373.69 2,839.57 2,363.55 6,006,294.10 1,530,236.95 0.98 970.36 MWD+IFR-AK-CAZ-SC(4) 5,816.94 66.67 49.21 3,459.96 3,410.84 2,895.79 2,428.51 6,006,349.33 1,530,302.75 0.20 979.15 MWD+IFR-AK-CAZ-SC(4) 5,911.09 66.55 48.87 3,497.33 3,448.21 2,952.43 2,493.77 6,006,404.98 1,530,368.84 0.36 988.13 MWD+IFR-AK-CAZ-SC(4) 6,005.66 66.99 50.07 3,534.64 3,485.52 3,008.90 2,559.82 6,006,460.44 1,530,435.73 1.26 996.50 MWD+IFR-AK-CAZ-SC(4) 6,100.11 66.81 52.58 3,571.70 3,522.58 3,063.19 2,627.63 6,006,513.69 1,530,504.36 2.45 1,002.07 MWD+IFR-AK-CAZ-SC(4) 6,194.65 66.94 51.85 3,608.83 3,559.71 3,116.46 2,696.35 6,006,565.92 1,530,573.86 0.72 1,006.29 MWD+IFR-AK-CAZ-SC(4) 6,288.51 66.62 50.65 3,645.83 3,596.71 3,170.45 2,763.62 6,006,618.88 1,530,641.93 1.22 1,011.93 MWD+IFR-AK-CAZ-SC(4) 6,383.07 66.98 51.07 3,683.08 3,633.96 3,225.31 2,831.03 6,006,672.71 1,530,710.15 0.56 1,018.21 MWD+IFR-AK-CAZ-SC(4) 6,477.62 66.79 54.00 3,720.21 3,671.09 3,278.20 2,900.04 6,006,724.55 1,530,779.95 2.86 1,021.95 MWD+IFR-AK-CAZ-SC(4) 6,571.94 66.86 57.16 3,757.34 3,708.22 3,327.20 2,971.55 6,006,772.47 1,530,852.19 3.08 1,021.07 MWD+IFR-AK-CAZ-SC(4) 6,666.05 66.68 57.62 3,794.46 3,745.34 3,373.81 3,044.40 6,006,817.96 1,530,925.72 0.49 1,017.46 MWD+IFR-AK-CAZ-SC(4) 6,761.07 66.99 55.86 3,831.84 3,782.72 3,421.72 3,117.45 6,006,864.76 1,530,999.48 1.73 1,014.81 MWD+IFR-AK-CAZ-SC(4) 6,853.68 66.59 53.64 3,868.34 3,819.22 3,470.84 3,186.95 6,006,912.82 1,531,069.71 2.25 1,015.18 MWD+IFR-AK-CAZ-SC(4) 6,949.58 66.70 50.93 3,906.36 3,857.24 3,524.69 3,256.59 6,006,965.61 1,531,140.14 2.60 1,019.35 MWD+IFR-AK-CAZ-SC(4) 7,044.55 66.60 50.73 3,944.00 3,894.88 3,579.76 3,324.19 6,007,019.66 1,531,208.56 0.22 1,025.69 MWD+IFR-AK-CAZ-SC(4) 7,136.17 66.91 50.51 3,980.16 3,931.04 3,633.17 3,389.25 6,007,072.07 1,531,274.42 0.40 1,032.12 MWD+IFR-AK-CAZ-SC(4) 7,232.25 66.69 50.61 4,018.01 3,968.89 3,689.27 3,457.46 6,007,127.14 1,531,343.45 0.25 1,038.96 MWD+IFR-AK-CAZ-SC(4) 7,327.48 66.72 49.59 4,055.67 4,006.55 3,745.38 3,524.56 6,007,182.22 1,531,411.39 0.98 1,046.43 MWD+IFR-AK-CAZ-SC(4) 7,421.49 66.97 48.71 4,092.64 4,043.52 3,801.91 3,589.94 6,007,237.76 1,531,477.61 0.90 1,055.24 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 3:53:23PM Page 4 COMPASS 2003.16 Build 69 0 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (It) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,514.69 66.72 48.92 4,129.29 4,080.17 3,858.34 3,654.43 6,007,293.20 1,531,542.94 0.34 1;064.47 MWD+IFR-AK-CAZ-SC(4) 7,610.78 66.68 48.12 4,167.30 4,118.18 3,916.80 3,720.55 6,007,350.65 1,531,609.92 0.77 1,074.43 MWD+IFR-AK-CAZ-SC(4) 7,704.43 66.85 48.44 4,204.24 4,155.12 3,974.06 3,784.78 6,007,406.93 1,531,675.01 0.36 1,084.50 MWD+IFR-AK-CAZ-SC(4) 7,799.45 66.72 50.92 4,241.70 4,192.58 4,030.56 3,851.35 6,007,462.42 1,531,742.42 2.40 1,092.60 MWD+IFR-AK-CAZ-SC(4) 7,893.38 66.88 51.97 4,278.71 4,229.59 4,084.37 3,918.87 6,007,515.20 1,531,810.73 1.04 1,097.95 MWD+IFR-AK-CAZ-SC(4) 7,988.00 66.72 53.23 4,315.98 4,266.86 4,137.19 3,987.95 6,007,566.97 1,531,880.60 1.24 1,101.60 MWD+IFR-AK-CAZ-SC(4) 8,082.53 66.65 52.74 4,353.40 4,304.28 4,189.46 4,057.27 6,007,618.17 1,531,950.69 0.48 1,104.65 MWD+IFR-AK-CAZ-SC(4) 8,176.47 66.91 52.48 4,390.43 4,341.31 4,241.88 4,125.86 6,007,669.55 1,532,020.06 0.38 1,108.25 MWD+IFR-AK-CAZ-SC(4) 8,271.16 66.54 52.12 4,427.85 4,378.73 4,295.07 4,194.68 6,007,721.70 1,532,089.67 0.52 1,112.34 MWD+IFR-AK-CAZ-SC(4) 8,364.84 66.97 52.06 4,464.82 4,415.70 4,347.96 4,262.59 6,007,773.55 1,532,158.37 0.46 1,116.71 MWD+IFR-AK-CAZ-SC(4) 8,459.62 66.66 52.27 4,502.14 4,453.02 4,401.40 4,331.40 6,007,825.94 1,532,227.97 0.39 1,121.02 MWD+IFR-AK-CAZ-SC(4) 8,553.48 66.76 52.13 4,539.25 4,490.13 4,454.24 4,399.53 6,007,877.74 1,532,296.87 0.17 1,125.24 MWD+IFR-AK-CAZ-SC(4) 8,648.03 66.88 50.93 4,576.47 4,527.35 4,508.31 4,467.57 6,007,930.78 1,532,365.72 1.17 1,130.50 MWD+IFR-AK-CAZ-SC(4) 8,742.02 66.82 49.83 4,613.42 4,564.30 4,563.42 4,534.14 6,007,984.87 1,532,433.11 1.08 1,137.46 MWD+IFR-AK-CAZ-SC(4) 8,836.80 66.82 48.91 4,650.73 4,601.61 4,620.15 4,600.27 6,008,040.60 1,532,500.08 0.89 1,146.00 MWD+IFR-AK-CAZ-SC(4) 8,930.85 66.78 50.56 4,687.78 4,638.66 4,676.02 4,666.23 6,008,095.46 1,532,566.86 1.61 1,153.94 MWD+IFR-AK-CAZ-SC(4) 9,026.05 66.75 51.24 4,725.33 4,676.21 4,731.19 4,734.11 6,008,149.60 1,532,635.57 0.66 1,160.19 MWD+IFR-AK-CAZ-SC(4) 9,119.64 66.81 52.29 4,762.23 4,713.11 4,784.42 4,801.67 6,008,201.80 1,532,703.92 1.03 1,165.04 MWD+IFR-AK-CAZ-SC(4) 9,213.88 66.71 51.72 4,799.42 4,750.30 4,837.73 4,869.91 6,008,254.06 1,532,772.95 0.57 1,169.57 MWD+IFR-AK-CAZ-SC(4) 9,308.74 66.79 51.57 4,836.87 4,787.75 4,891.81 4,938.26 6,008,307.10 1,532,842.10 0.17 1,174.67 MWD+IFR-AK-CAZ-SC(4) 9,402.78 66.77 52.33 4,873.94 4,824.82 4,945.08 5,006.31 6,008,359.33 1,532,910.94 0.74 1,179.27 MWD+IFR-AK-CAZ-SC(4) 9,497.26 66.79 51.76 4,911.19 4,862.07 4,998.48 5,074.77 6,008,411.69 1,532,980.19 0.55 1,183.74 MWD+IFR-AK-CAZ-SC(4) 9,591.75 66.72 51.92 4,948.48 4,899.36 5,052.12 5,143.04 6,008,464.29 1,533,049.25 0.17 1,188.53 MWD+IFR-AK-CAZ-SC(4) 9,686.09 66.74 51.86 4,985.76 4,936.64 5,105.61 5,211.23 6,008,516.74 1,533,118.24 0.06 1,193.23 MWD+IFR-AK-CAZ-SC(4) 9,779.88 66.69 51.71 5,022.83 4,973.71 5,158.90 5,278.92 6,008,569.01 1,533,186.72 0.16 1,198.06 MWD+IFR-AK-CAZ-SC(4) 9,874.95 66.61 50.83 5,060.51 5,011.39 5,213.51 5,347.01 6,008,622.58 1,533,255.62 0.85 1,203.74 MWD+IFR-AK-CAZ-SC(4) 9,969.46 66.32 49.56 5,098.25 5,049.13 5,268.98 5,413.57 6,008,677.03 1,533,323.00 1.27 1,211.00 MWD+IFR-AK-CAZ-SC(4) 10,064.16 67.78 49.07 5,135.18 5,086.06 5,325.83 5,479.70 6,008,732.87 1,533,389.97 1.61 1,219.64 MWD+IFR-AK-CAZ-SC(4) 10,157.71 67.27 48.49 5,170.94 5,121.82 5,382.79 5,544.72 6,008,788.84 1,533,455.84 0.79 1,229.00 MWD+IFR-AK-CAZ-SC(4) 10,252.37 67.12 48.97 5,207.63 5,158.51 5,440.35 5,610.30 6,008,845.40 1,533,522.28 0.49 1,238.53 MWD+IFR-AK-CAZ-SC(4) 10,347.03 67.37 50.97 5,244.25 5,195.13 5,496.49 5,677.14 6,008,900.52 1,533,589.95 1.97 1,246.19 MWD+IFR-AK-CAZ-SC(4) 10,441.03 67.49 52.78 5,280.33 5,231.21 5,550.07 5,745.42 6,008,953.06 1,533,659.03 1.78 1,250.92 MWD+IFR-AK-CAZ-SC(4) 10,535.67 68.00 54.67 5,316.17 5,267.05 5,601.89 5,816.03 6,009,003.80 1,533,730.40 1.93 1,252.86 MWD+IFR-AK-CAZ-SC(4) 10,629.43 68.55 55.28 5,350.88 5,301.76 5,651.88 5,887.36 6,009,052.71 1,533,802.47 0.84 1,252.90 MWD+IFR-AK-CAZ-SC(4) 10,724.10 68.57 54.10 5,385.48 5,336.36 5,702.81 5,959.27 6,009,102.54 1,533,875.13 1.16 1,253.38 MWD+IFR-AK-CAZ-SC(4) 10,818.37 _68.88 53.26 5,419.69 5,370.57 5,754.84 6,030.04 6,009,153.50 1,533,946.68 0.89 1,255.40 MWD+IFR-AK-CAZ-SC(4) 10,912.78 69.47 51.94 5,453.26 5,404.14 5,808.44 6,100.14 6,009,206.03 1,534,017.57 1.45 1,259.10 MWD+IFR-AK-CAZ-SC(4) 11,007.74 70.06 51.78 5,486.10 5,436.98 5,863.47 6,170.22 6,009,259.98 1,534,088.46 0.64 1,263.98 MWD+IFR-AK-CAZ-SC(4) 11,101.53 69.97 51.87 5,518.15 5,469.03 5,917.94 6,239.51 6,009,313.41 1,534,158.56 0.13 1,268.86 MWD+IFR-AK-CAZ-SC(4) 11,195.95 70.88 50.27 5,549.79 5,500.67 5,973.84 6,308.71 6,009,368.25 1,534,228.59 1.86 1,274.96 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 3:53:23PM Page 5 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 11,290.93 70.55 50.16 5,581.16 5,532.04 6,031.21 6,377.60 6,009,424.57 1,534,298.33 0.36 1,282.44 MWD+IFR-AK-CAZ-SC(4) 11,384.87 70.84 50.04 5,612.22 5,563.10 6,088.08 6,445.61 6,009,480.40 1,534,367.19 0.33 1,290.01 MWD+IFR-AK-CAZ-SC(4) 11,479.42 70.95 49.71 5,643.16 5,594.04 6,145.66 6,513.93 6,009,536.94 1,534,436.36 0.35 1,297.99 MWD+IFR-AK-CAZ-SC(4) 11,573.10 71.03 49.91 5,673.68 5,624.56 6,202.82 6,581.59 6,009,593.06 1,534,504.87 0.22 1,306.01 MWD+IFR-AK-CAZ-SC(4) 11,668.92 71.69 50.04 5,704.30 5,655.18 6,261.21 6,651.12 6,009,650.39 1,534,575.26 0.70 1,313.96 MWD+IFR-AK-CAZ-SC(4) 11,762.21 71.41 49.94 5,733.83 5,684.71 6,318.10 6,718.90 6,009,706.26 1,534,643.89 0.32 1,321.69 MWD+IFR-AK-CAZ-SC(4) 11,857.35 71.27 50.73 5,764.27 5,715.15 6,375.64 6,788.28 6,009,762.73 1,534,714.13 0.80 1,329.02 MWD+IFR-AK-CAZ-SC(4) 11,950.71 71.88 50.21 5,793.77 5,744.65 6,432.01 6,856.60 6,009,818.07 1,534,783.28 0.84 1,336.01 MWD+IFR-AK-CAZ-SC(4) 12,045.73 72.48 50.38 5,822.85 5,773.73 6,489.80 6,926.19 6,009,874.80 1,534,853.74 0.65 1,343.43 MWD+IFR-AK-CAZ-SC(4) 12,139.47 71.94 50.70 5,851.49 5,802.37 6,546.53 6,995.11 6,009,930.47 1,534,923.49 0.66 1,350.37 MWD+IFR-AK-CAZ-SC(4) 12,234.00 71.89 48.55 5,880.84 5,831.72 6,604.74 7,063.56 6,009,987.63 1,534,992.81 2.16 1,358.79 MWD+IFR-AK-CAZ-SC(4) 12,328.96 71.63 47.37 5,910.56 5,861.44 6,665.13 7,130.54 6,010,047.00 1,535,060.68 1.21 1,369.84 MWD+IFR-AK-CAZ-SC(4) 12,422.95 71.86 47.27 5,940.01 5,890.89 6,725.64 7,196.16 6,010,106.51 1,535,127.20 0.26 1,381.77 MWD+IFR-AK-CAZ-SC(4) 12,516.72 71.78 46.93 5,969.26 5,920.14 6,786.28 7,261.42 6,010,166.16 1,535,193.37 0.35 1,394.02 MWD+IFR-AK-CAZ-SC(4) 12,611.42 71.02 46.15 5,999.47 5,950.35 6,848.02 7,326.57 6,010,226.90 1,535,259.43 1.12 1,407.22 MWD+IFR-AK-CAZ-SC(4) 12,705.71 71.65 46.96 6,029.65 5,980.53 6,909.44 7,391.43 6,010,287.34 1,535,325.20 1.05 1,420.34 MWD+IFR-AK-CAZ-SC(4) 12,800.93 72.07 45.30 6,059.29 6,010.17 6,972.15 7,456.66 6,010,349.05 1,535,391.36 1.71 1,434.29 MWD+IFR-AK-CAZ-SC(4) 12,894.81 72.30 42.33 6,088.02 6,038.90 7,036.64 7,518.53 6,010,412.59 1,535,454.20 3.02 1,451.63 MWD+IFR-AK-CAZ-SC(4) 12,988.85 73.05 38.28 6,116.04 6,066.92 7,105.09 7,576.58 6,010,480.15 1,535,513.27 4.19 1,474.40 MWD+IFR-AK-CAZ-SC(4) 13,083.83 72.57 34.38 6,144.12 6,095.00 7,178.17 7,630.32 6,010,552.41 1,535,568.11 3.96 1,503.44 MWD+IFR-AK-CAZ-SC(4) 13,178.07 71.24 30.74 6,173.39 6,124.27 7,253.65 7,678.53 6,010,627.14 1,535,617.44 3.93 1,537.61 MWD+IFR-AK-CAZ-SC(4) 13,271.12 70.65 27.65 6,203.78 6,154.66 7,330.41 7,721.43 6,010,703.24 1,535,661.49 3.20 1,575.89 MWD+IFR-AK-CAZ-SC(4) 13,366.63 70.34 25.46 6,235.67 6,186.55 7,410.93 7,761.68 6,010,783.14 1,535,702.94 2.19 1,618.77 MWD+IFR-AK-CAZ-SC(4) 13,459.98 70.21 23.40 6,267.18 6,218.06 7,490.93 7,798.02 6,010,862.58 1,535,740.48 2.08 1,663.46 MWD+IFR-AK-CAZ-SC(4) 13,554.94 69.58 21.16 6,299.83 6,250.71 7,573.44 7,831.83 6,010,944.56 1,535,775.53 2.31 1,711.65 MWD+IFR-AK-CAZ-SC(4) 13,649.51 69.11 17.88 6,333.19 6,284.07 7,656.83 7,861.39 6,011,027.49 1,535,806.35 3.28 1,763.00 MWD+IFR-AK-CAZ-SC(4) 13,742.82 69.67 14.32 6,366.05 6,316.93 7,740.73 7,885.60 6,011,111.00 1,535,831.82 3.62 1,817.84 MWD+IFR-AK-CAZ-SC(4) 13,837.83 69.45 11.47 6,399.23 6,350.11 7,827.50 7,905.47 6,011,197.46 1,535,852.99 2.82 1,877.52 MWD+IFR-AK-CAZ-SC(4) 13,932.61 70.22 9.44 6,431.91 6,382.79 7,914.99 7,921.61 6,011,284.68 1,535,870.45 2.17 1,939.93 MWD+IFR-AK-CAZ-SC(4) 14,026.68 71.71 8.68 6,462.59 6,413.47 8,002.80 7,935.61 6,011,372.27 1,535,885.77 1.76 2,003.83 MWD+IFR-AK-CAZ-SC(4) 14,120.90 71.24 8.03 6,492.53 6,443.41 8,091.19 7,948.59 6,011,460.45 1,535,900.08 0.82 2,068.79 MWD+IFR-AK-CAZ-SC(4) 14,216.13 72.18 9.10 6,522.41 6,473.29 8,180.60 7,962.06 6,011,549.63 1,535,914.89 1.45 2,134.30 MWD+IFR-AK-CAZ-SC(4) 14,309.29 74.03 9.40 6,549.48 6,500.36 8,268.57 7,976.39 6,011,637.37 1,535,930.54 2.01 2,198.15 MWD+IFR-AK-CAZ-SC(4) 7-5/8"X 9-7/8" 14,309.77 74.04 9.40 6,549.62 6,500.50 8,269.03 7,976.46 6,011,637.83 1,535,930.63 2.01 2,198.48 MWD+IFR-AK-CAZ-SC(4) 14,404.81 74.57 8.03 6,575.33 6,526.21 8,359.47 7,990.32 6,011,728.04 1,535,945.85 1.50 2,264.61 MWD+IFR-AK-CAZ-SC(4) 14,497.87 74.54 4.02 6,600.12 6,551.00 8,448.65 7,999.74 6,011,817.06 1,535,956.61 4.15 2,332.27 MWD+IFR-AK-CAZ-SC(4) 14,593.40 74.71 1.42 6,625.45 6,576.33 8,540.65 8,004.11 6,011,908.98, 1,535,962.36 2.63 2,405.12 MWD+IFR-AK-CAZ-SC(4) 14,686.02 74.34 0.08 6,650.17 6,601.05 8,629.90 8,005.28 6,011,998.19 1,535,964.88 1.45 2,477.56 MWD+IFR-AK-CAZ-SC(4) 14,781.94 73.97 358.63 6,676.36 6,627.24 8,722.17 8,004.24 6,012,090.46 1,535,965.23 1.50 2,553.74 MWD+IFR-AK-CAZ-SC(4) 14,876.10 74.34 356.42 6,702.07 6,652.95 8,812.66 8,000.33 6,012,180.99 1,535,962.68 2.29 2,630.11 MWD+IFR-AK-CAZ-SC(4) 3/20/2014 3:53:23PM Page 6 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130 Survey Calculation Method: Minimum Curvature Design: CD3-130 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,970.72 77.01 355.58 6,725.48 6,676.36 8,904.10 7,993.93 6,012,272.51 1,535,957.67 2.95 2,708.69 MWD+IFR-AK-CAZ-SC(4) 15,064.14 79.73 354.81 6,744.31 6,695.19 8,995.27 7,986.26 6,012,363.78 1,535,951.38 3.02 2,787.77 MWD+IFR-AK-CAZ-SC(4) 15,158.59 79.56 352.00 6,761.29 6,712.17 9,087.56 7,975.59 6,012,456.21 1,535,942.10 2.93 2,869.48 MWD+IFR-AK-CAZ-SC(4) 15,252.77 79.73 350.02 6,778.22 6,729.10 9,179.06 7,961.11 6,012,547.91 1,535,929.01 2.08 2,952.74 MWD+IFR-AK-CAZ-SC(4) 15,346.80 80.19 347.89 6,794.61 6,745.49 9,269.93 7,943.38 6,012,639.03 1,535,912.64 2.28 3,037.35 MWD+IFR-AK-CAZ-SC(4) 15,416.73 80.08 346.82 6,806.60 6,757.48 9,337.16 7,928.29 6,012,706.47 1,535,898.58 1.52 3,101.07 MWD+IFR-AK-CAZ-SC(4) 15,483.00 80.08 346.82 6,818.01 6,768.89 9,400.72 7,913.41 6,012,770.24 1,535,884.65 0.00 3,161.67 PROJECTED to TD • 3/20/2014 3:53:23PM Page 7 COMPASS 2003.16 Build 69 • SchlumbergerTransmittal#: RRn1 Drilling &Measurements MWD/LWD Log Product Delivery DATA LO2.ZBGED M K BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: CD3-130 PB1 Date Dispatched: 26-Mar-14 Job#: 13AKA0115 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Vision Service 2"MD 1 Contents on CD Vision Service 2"TVD 1 Contents on CD Vision Service 5"MD 1 Contents on CD Vision Service 5"TVD 1 Contents on CD LAS Digital Data Contents on CD SURVEYS 2 Contents on CD FINAL SURVEY NAD 27 1 each FINAL SURVEY NAD 83 1 each EOW CD 1 CD RECEIVED MAR 272014 AOGCC Please sign and email a copy to: Please sign and email/fax a copy to: afell(a�slb.com spacilloslb.com Stephanie Pacillo Arina Fell Fax:907-561-8317 907-265-6519 ATO 1525 N Received By: o--14 RECEIVE!: MAR 272014 AOGCC ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-130PB1 Definitive Survey Report N A D 2 7 20 March, 2014 • • .-- • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62©49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Project Western North Slope 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 04 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,743.55 ft Latitude: 70°25'8.970 N +El-W 0.00 ft Easting: 387,799.14 ft Longitude: 150°54'50.530 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50 ft Wellbore CD3-130PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 1/11/2014 14.84 79.83 57,361 Design CD3-130PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.62 0.00 0.00 325.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.71 1,519.32 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 1,612.45 1,612.45 CD3-130PB1 MWD I(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2014 12:00:C 1,706.53 1,751.55 CD3-130PB1 Gyro II(CD3-13OPB1) GYD-GC-SS Gyrodata gyro single shots 3/20/2014 12:00 1,801.15 3,095.78 CD3-130PB1 MWD II(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/20/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,743.55 387,799.14 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,743.46 387,799.18 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,743.36 387,799.29 0.23 -0.24 GYD-GC-SS(1) 265.12 2.21 334.14 265.10 215.98 1.34 -0.46 6,003,744.89 387,798.70 2.60 1.36 GYD-GC-SS(1) 358.32 3.07 336.64 358.20 309.08 5.24 -2.23 6,003,748.82 387,796.98 0.93 5.58 GYD-GC-SS(1) 450.68 3.42 340.45 450.41 401.29 10.11 -4.14 6,003,753.72 387,795.15 0.44 10.66 GYD-GC-SS(1) 542.74 4.16 337.25 542.27 493.15 15.78 -6.35 6,003,759.42 387,793.03 0.84 16.56 GYD-GC-SS(1) 635.62 5.94 338.90 634.78 58566 23.37 -9.38 6,003,767.05 387,790.11 1.92 24.52 GYD-GC-SS(1) 727.71 7.28 342.70 726.26 677.14 33.39 -12.83 6,003,777.12 387,786.81 1.53 34.71 GYD-GC-SS(1) 820.83 8.92 346.36 818.45 769.33 46.04 -16.29 6,003,789.82 387,783.55 1.85 47.05 GYD-GC-SS(1) 913.55 12.62 349.44 909.52 860.40 62.98 -19.84 6,003,806.82 387,780.25 4.04 62.97 GYD-GC-SS(1) 3/20/2014 4:22:15PM Page 2 COMPASS 2003.16 Build 69 . • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Fasting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,008.38 17.61 353.18 1,001.04 951.92 87.43 -23.45 6,003,831.31 387,777.01 5.36 85.06 GYD-GC-SS(1) 1,056.20 17.64 354.61 1,046.62 997.50 101.82 -24.98 6,003,845.73 387,775.69 0.91 97.74 GYD-GC-SS(1) 1,100.44 17.67 354.60 1,088.78 1,039.66 115.18 -26.25 6,003,859.10 387,774.63 0.07 109.41 GYD-GC-SS(1) 1,194.41 20.95 353.06 1,177.45 1,128.33 146.07 -29.62 6,003,890.03 387,771.72 3.53 136.64 GYD-GC-SS(1) 1,289.24 23.10 353.09 1,265.35 1,216.23 181.37 -33.91 6,003,925.39 387,767.96 2.27 168.01 GYD-GC-SS(1) 1,383.67 28.68 351.79 1,350.27 1,301.15 222.22 -39.38 6,003,966.31 387,763.11 5.94 204.61 GYD-GC-SS(1) 1,424.33 30.07 349.91 1,385.70 1,336.58 241.90 -42.55 6,003,986.04 387,760.23 4.10 222.56 GYD-GC-SS(1) 1,519.32 32.81 353.39 1,466.75 1,417.63 290.91 -49.69 6,004,035.15 387,753.83 3.46 266.80 GYD-GC-SS(1) 1,612.45 35.66 359.70 1,543.76 1,494.64 343.15 -52.74 6,004,087.42 387,751.57 4.88 311.34 MWD+IFR-AK-CAZ-SC(2) 1,706.53 38.04 6.38 1,619.07 1,569.95 399.41 -49.66 6,004,143.62 387,755.49 4.95 355.66 GYD-GC-SS(3) 1,751.55 40.07 8.60 1,654.03 1,604.91 427.52 -45.95 6,004,171.68 387,759.63 5.48 376.56 GYD-GC-SS(3) 1,801.15 40.30 9.88 1,691.92 1,642.80 459.11 -40.81 6,004,203.18 387,765.24 1.73 399.49 MWD+IFR-AK-CAZ-SC(4) 1,895.81 41.80 16.42 1,763.34 1,714.22 519.56 -26.63 6,004,263.41 387,780.32 4.80 440.88 MWD+IFR-AK-CAZ-SC(4) 1,990.70 42.87 21.04 1,833.50 1,784.38 580.04 -6.10 6,004,323.56 387,801.76 3.47 478.64 MWD+IFR-AK-CAZ-SC(4) 2,085.47 42.77 27.25 1,903.04 1,853.92 638.76 20.22 6,004,381.88 387,828.96 4.45 511.64 MWD+IFR-AK-CAZ-SC(4) 2,179.35 44.44 31.19 1,971.03 1,921.91 695.23 51.85 6,004,437.86 387,861.42 3.40 539.76 MWD+IFR-AK-CAZ-SC(4) 2,273.59 48.52 32.77 2,035.92 1,986.80 753.16 88.06 6,004,495.23 387,898.50 4.50 566.45 MWD+IFR-AK-CAZ-SC(4) 2,368.48 53.76 33.86 2,095.43 2,046.31 814.87 128.65 6,004,556.32 387,940.00 5.59 593.71 MWD+IFR-AK-CAZ-SC(4) 2,413.97 58.09 34.95 2,120.91 2,071.79 845.94 149.94 6,004,587.07 387,961.76 9.72 606.96 MWD+IFR-AK-CAZ-SC(4) 2,463.13 59.08 35.36 2,146.54 2,097.42 880.24 174.09 6,004,621.00 387,986.43 2.14 621.20 MWD+IFR-AK-CAZ-SC(4) 2,510.46 59.31 35.83 2,170.77 2,121.65 913.30 197.76 6,004,653.69 388,010.58 0.98 634.70 MWD+IFR-AK-CAZ-SC(4) 2,556.61 59.46 37.55 2,194.28 2,145.16 945.15 221.49 6,004,685.18 388,034.78 3.22 647.18 MWD+IFR-AK-CAZ-SC(4) 2,651.75 60.95 40.65 2,241.56 2,192.44 1,009.20 273.56 6,004,748.43 388,087.81 3.23 669.78 MWD+IFR-AK-CAZ-SC(4) 2,745.27 61.76 44.49 2,286.41 2,237.29 1,069.62 329.07 6,004,808.00 388,144.22 3.71 687.43 MWD+IFR-AK-CAZ-SC(4) 2,838.90 63.22 48.39 2,329.67 2,280.55 1,126.81 389.24 6,004,864.28 388,205.24 4.01 699.77 MWD+IFR-AK-CAZ-SC(4) 2,937.08 65.17 50.31 2,372.41 2,323.29 1,184.38 456.31 6,004,920.83 388,273.15 2.65 708.46 MWD+IFR-AK-CAZ-SC(4) 3,028.20 66.99 50.87 2,409.35 2,360.23 1,237.25 520.66 6,004,972.73 388,338.29 2.07 714.86 MWD+IFR-AK-CAZ-SC(4) 3,095.78 66.83 51.26 2,435.85 2,386.73 1,276.32 569.02 6,005,011.06 388,387.22 0.58 719.12 MWD+IFR-AK-CAZ-SC(4) 3,194.01 66.83 51.26 2,474.50 2,425.38 1,332.83 639.46 6,005,066.50 388,458.50 0.00 725.02 PROJECTED to TD 3/20/2014 4:22:15PM Page 3 COMPASS 2003.16 Build 69 • RECEIVED MAR 2 7 2014 AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-130PB1 Definitive Survey Report 20 March, 2014 • • N. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Project Western North Slope,North Slope Alaska,United States 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 4 Using geodetic scale factor Well CD3-130 Well Position +N/-S 0.00 ft Northing: 6,003,490.74 ft Latitude: 70°25'7.804 N +E/-W 0.00 ft Easting: 1,527,831.05 ft Longitude: 150°55'1.908 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50 ft Wellbore CD3-130PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 1/11/2014 19.06 80.86 57,595 Design CD3-130PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.62 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (1 36.62 0.00 0.00 325.00 Survey Program Date 3/20/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.71 1,519.32 CD3-130PB1 Gyro I(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 1/30/2014 12:00 1,612.45 1,612.45 CD3-130PB1 MWD I(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2014 12:00:( 1,706.53 1,751.55 CD3-130PB1 Gyro II(CD3-130PB1) GYD-GC-SS Gyrodata gyro single shots 3/20/2014 12:00 1,801.15 3,095.78 CD3-130PB1 MWD II(CD3-130PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/20/2014 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.62 0.00 0.00 36.62 -12.50 0.00 0.00 6,003,490.74 1,527,831.05 0.00 0.00 UNDEFINED 116.71 0.13 154.32 116.71 67.59 -0.08 0.04 6,003,490.66 1,527,831.09 0.16 -0.09 GYD-GC-SS(1) 174.06 0.20 113.61 174.06 124.94 -0.18 0.16 6,003,490.56 1,527,831.21 0.23 -0.24 GYD-GC-SS(1) 265.12 2.21 334.14 265.10 215.98 1.34 -0.46 6,003,492.08 1,527,830.61 2.60 1.36 GYD-GC-SS(1) 358.32 3.07 336.64 358.20 309.08 5.24 -2.23 6,003,496.02 1,527,828.90 0.93 5.58 GYD-GC-SS(1) 450.68 3.42 340.45 450.41 401.29 10.11 -4.14 6,003,500.91 1,527,827.07 0.44 10.66 GYD-GC-SS(1) 542.74 4.16 337.25 542.27 493.15 15.78 -6.35 6,003,506.61 1,527,824.94 0.84 16.56 GYD-GC-SS(1) 635.62 5.94 338.90 634.78 585.66 23.37 -9.38 6,003,514.25 1,527,822.02 1.92 24.52 GYD-GC-SS(1) 727.71 7.28 342.70 726.26 677.14 33.39 -12.83 6,003,524.31 1,527,818.73 1.53 34.71 GYD-GC-SS(1) 820.83 8.92 346.36 818.45 769.33 46.04 -16.29 6,003,537.01 1,527,815.46 1.85 47.05 GYD-GC-SS(1) 913.55 12.62 349.44 909.52 860.40 62.98 -19.84 6,003,554.01 1,527,812.16 4.04 62.97 GYD-GC-SS(1) 3/20/2014 3:50:38PM Page 2 COMPASS 2003.16 Build 69 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-130 Project: Western North Slope TVD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-130:12.5+36.62 @ 49.12ft(Doyon 19) Well: CD3-130 North Reference: True Wellbore: CD3-130PB1 Survey Calculation Method: Minimum Curvature Design: CD3-130PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,008.38 17.61 353.18 1,001.04 951.92 87.43 -23.45 6,003,578.50 1,527,808.93 5.36 85.06 GYD-GC-SS(1) 1,056.20 17.64 354.61 1,046.62 997.50 101.82 -24.98 6,003,592.92 1,527,807.61 0.91 97.74 GYD-GC-SS(1) 1,100.44 17.67 354.60 1,088.78 1,039.66 115.18 -26.25 6,003,606.29 1,527,806.55 0.07 109.41 GYD-GC-SS(1) 1,194.41 20.95 353.06 1,177.45 1,128.33 146.07 -29.62 6,003,637.22 1,527,803.64 3.53 136.64 GYD-GC-SS(1) 1,289.24 23.10 353.09 1,265.35 1,216.23 181.37 -33.91 6,003,672.58 1,527,799.89 2.27 168.01 GYD-GC-SS(1) 1,383.67 28.68 351.79 1,350.27 1,301.15 222.22 -39.38 6,003,713.50 1,527,795.03 5.94 204.61 GYD-GC-SS(1) 1,424.33 30.07 349.91 1,385.70 1,336.58 241.90 -42.55 6,003,733.24 1,527,792.15 4.10 222.56 GYD-GC-SS(1) 1,519.32 32.81 353.39 1,466.75 1,417.63 290.91 -49.69 6,003,782.34 1,527,785.76 3.46 266.80 GY0-GC-SS(1) 1,612.45 35.66 359.70 1,543.76 1,494.64 343.15 -52.74 6,003,834.61 1,527,783.50 4.88 311.34 MWD+IFR-AK-CAZ-SC(2) 1,706.53 38.04 6.38 1,619.07 1,569.95 399.41 -49.66 6,003,890.82 1,527,787.43 4.95 355.66 GYD-GC-SS(3) 1,751.55 40.07 8.60 1,654.03 1,604.91 427.52 -45.95 6,003,918.87 1,527,791.56 5.48 376.56 GYD-GC-SS(3) 1,801.15 40.30 9.88 1,691.92 1,642.80 459.11 -40.81 6,003,950.38 1,527,797.17 1.73 399.49 MWD+IFR-AK-CAZ-SC(4) 1,895.81 41.80 16.42 1,763.34 1,714.22 519.56 -26.63 6,004,010.60 1,527,812.26 4.80 440.88 MWD+IFR-AK-CAZ-SC(4) 1,990.70 42.87 21.04 1,833.50 1,784.38 580.04 -6.10 6,004,070.76 1,527,833.70 3.47 478.64 MWD+IFR-AK-CAZ-SC(4) 2,085.47 42.77 27.25 1,903.04 1,853.92 638.76 20.22 6,004,129.07 1,527,860.90 4.45 511.64 MWD+IFR-AK-CAZ-SC(4) 2,179.35 44.44 31.19 1,971.03 1,921.91 695.23 51.85 6,004,185.05 1,527,893.37 3.40 539.76 MWD+IFR-AK-CAZ-SC(4) 2,273.59 48.52 32.77 2,035.92 1,986.80 753.16 88.06 6,004,242.42 1,527,930.45 4.50 566.45 MWD+IFR-AK-CAZ-SC(4) 2,368.48 53.76 33.86 2,095.43 2,046.31 814.87 128.65 6,004,303.51 1,527,971.96 5.59 593.71 MWD+IFR-AK-CAZ-SC(4) 2,413.97 58.09 34.95 2,120.91 2,071.79 845.94 149.94 6,004,334.25 1,527,993.72 9.72 606.96 MWD+IFR-AK-CAZ-SC(4) 2,463.13 59.08 35.36 2,146.54 2,097.42 880.24 174.09 6,004,368.18 1,528,018.38 2.14 621.20 MWD+IFR-AK-CAZ-SC(4) 2,510.46 59.31 35.83 2,170.77 2,121.65 913.30 197.76 6,004,400.88 1,528,042.54 0.98 634.70 MWD+IFR-AK-CAZ-SC(4) 2,556.61 59.46 37.55 2,194.28 2,145.16 945.15 221.49 6,004,432.36 1,528,066.75 3.22 647.18 MWD+IFR-AK-CAZ-SC(4) 2,651.75 60.95 40.65 2,241.56 2,192.44 1,009.20 273.56 6,004,495.61 1,528,119.77 3.23 669.78 MWD+IFR-AK-CAZ-SC(4) 2,745.27 61.76 44.49 2,286.41 2,237.29 1,069.62 329.07 6,004,555.18 1,528,176.19 3.71 687.43 MWD+IFR-AK-CAZ-SC(4) 2,838.90 63.22 48.39 2,329.67 2,280.55 1,126.81 389.24 6,004,611.46 1,528,237.21 4.01 699.77 MWD+IFR-AK-CAZ-SC(4) 2,937.08 65.17 50.31 2,372.41 2,323.29 1,184.38 456.31 6,004,668.00 1,528,305.13 2.65 708.46 MWD+IFR-AK-CAZ-SC(4) 3,028.20 66.99 50.87 2,409.35 2,360.23 1,237.25 520.66 6,004,719.89 1,528,370.27 2.07 714.86 MWD+IFR-AK-CAZ-SC(4) 3,095.78 66.83 51.26 2,435.85 2,386.73 1,276.32 569.02 6,004,758.22 1,528,419.20 0.58 719.12 MWD+IFR-AK-CAZ-SC(4) 3,194.01 66.83 51.26 2,474.50 2,425.38 1,332.83 639.46 6,004,813.66 1,528,490.48 0.00 725.02 PROJECTED to TD 3/20/2014 3:50:38PM Page 3 COMPASS 2003.16 Build 69 e • RECEIVED STATE OF ALASKA FEB 2 Q 204 ALASKA OIL AND GAS CONSERVATION COMMISSION JS 3/5/f APPLICATION FOR SUNDRY APPROVALS 4 Grr 20 AAC 25.280 1.Type of Request: Abandon❑J. C Plug for Redril ❑ Perforate New Pool El Repair Well❑ Change Approved Program ❑ Suspend d•516rVPlug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown Q . Re-enter Susp.Wel ❑ Stimulate ❑ Alter Casing❑ Other. _ LI 2.Operator Name: 4.Currert Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 213-160 3.Address: Stratigraphic ❑ Service Q 6.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 50-103-20677-00-00. 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CD3-130 Will planned perforations require a spacing exception? Yes ❑ No Q - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 364472, 364471, 372104, 372105 Colville River Field Fiord Oil Pool 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): 15483 6818' 5 bbls on top of cement retainer N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 114' 114' Surface 3317.22' 10-3/4" 3353.62 2480.49' Intermediate —14270 7-5/8" 14307' 6549' Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A ' N/A 3-1/2" L-80 —1500' Packers and SSSV Type: Cement retainer—14153'MD Packers and SSSV MD(ft)and ND(ft): Cement retainer—14153'MD 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic El Development❑ Service Q • 14.Estimated Date for 2/26/2014 15.Well Status after proposed work: y3 4)I` Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: 2/25/2014 WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Victoria Ferguson GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Brunswick 3./9. Email Scott.A.Brunswick{a cop.com Printed Name G.L Alvord Title Drilling Manager i► Signature )4 enj, - 907-265-6120 Date 2/27/2014 rbVL A,L. A LVemz_p COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical IntegrityTest ❑ Location Clearance ❑ l Other: 5,....,)0 �'- I r / 5 Ir hit : - L at r J v iN L 1 1 D y�-ts®L �i�ri et S Gl!.-r dJ o q 5 f0 �!Q/ �j / X20.471C3c 25=U -z�b)) /� L�5vmC D e1--ot ?-f�S liv,�7i1 /6-403 v✓ r1.Lw PTO. Spacing Exception Required? Yes ❑ No gfr Subsequent Form Required: /0 —4-0 4 �/) APPROVED BY Approved by:(N4 2,:2).,./..„ COMMISSIONER THE CO(MMISSION Date: 3 3—J L1t f n V �ry thsI� Jda I Submit Form and Form 10 403( evised 10/2012) Aper v a i I f r 12 months from theate of approval. Attachments in Duplicate VLF 3/4//4- i `` .I�3/,�4i'<1 • • p TD /3 -14,0 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Friday, February 28, 2014 10:01 AM To: 'Anderson, Nina M' Cc: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: RE: CD3-130 PTD 213-160 Casing Run Update Nina, Your plan forward to suspend CD3-130 is approved. Please submit a 10-403 as soon as possible. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.00v From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Friday, February 28, 2014 7:24 AM To: Ferguson, Victoria L(DOA) Cc: Brunswick, Scott A Subject: CD3-130 PTD 213-160 Casing Run Update Victoria, We are progressing on CD3-130 and have successfully completed our first cement placement above the Qannik. We ask for your concurrence with our original plan to suspend CD3-130 for future re-entry. Below is a summary of events over the last 24-48 hours. Please see the attached schematic for reference. Operations were successful at establishing an injection rate of 8 BPM at 3700 psi with no returns into the open hole at the bottom of the 7 5/8"casing string at 14,307' MD. At 3700 psi,the stage tool at 6909' MD opened allowing full returns to surface with negligible gas throughout the circulation. The mud was conditioned with multiple bottom's up and weighted up to 10.8 ppg. For reference,the stage tool is 576' MD above the Qannik(Qannik @ 7485' MD).The cement job successfully placed 91.1 bbl of 15.8 ppg cement with D-600 gas block additive to fill a calculated height of 1700'of the 7 5/8"x 9 5/8"Annulus with 40%excess. The plug was bumped on strokes closing the stage tool and confirmed with the pressure test of 1570 psi. The floats were checked and holding. After waiting on cement the well was observed once more and found to be static. The BOPE stack was removed so that casing could be cut and set on emergency slips. Upcoming operations include a BOPE test, picking up DP, RIH to drill out the stage tool,and then RIH with cement retainer to pump cement and squeeze the shoe and open hole below the casing. Cement will be left on top of the retainer to further isolate the shoe and open-hole section. After waiting on cement,the casing will be tested to 3500 psi prior to displacing the casing with 9.8 ppg brine and running a kill string.There are no plans to perforate and attempt squeezing behind the casing at this time. The inability to circulate around the shoe indicates that the shale has collapsed. 1 • • In its final state per the plan above,the Qannik will be isolated and the open hole below the casing shoe will be isolated with the squeeze and the cement retainer above it. ConocoPhillips will communicate any changes to this plan should operations dictate them. Please let us know if you have further questions or concerns. Thank-you, Nina Anderson Senior Drilling Engineer WNS Drilling Team Office: (907)-265-6403 Cell: (907) 229-4008 2 Colville River Field CD3-130 Nechelik Injection Well Updated S.Brunswick (2/27/2013) 20"Conductor to 80' 16. 10-3/4"45.5#L-80 BTC-M 1116. Surface Casing @ 3353' MD/2480 TVD cemented to surface — Estimated TOC-5209' MD Q O O HES 7-5/8"Stage Collar @ 6909' MD Qannik Interval 7485' MD/4113'TVD Opened hole to 11"starting @ 13311' MD Packed off believed near shoe Shoe currently @ 14307' MD HRZ Top 13735' MD/6360'TVD HRZ Base Cement Retainer set :ii14370' MD/6564'TVD @14153' MD Kuparuk C 14,832' MD/ 6690' -----_;""iiii1111111111111111111 TVD 7-5/8"29.7#L-80 BTC-M Casing proposed setting @ 15,463' MD Nechelik 15,412 MD/6,806'TVD TD—15483 ft MD • • Ferguson, Victoria L (DOA) From: Anderson, Nina M <Nina.Anderson@conocophillips.com> Sent: Tuesday, February 25, 2014 6:43 PM To: Ferguson, Victoria L(DOA) Cc: Brunswick, Scott A Subject: CD3-130 PTD 213-160 Casing Run Follow Up Flag: Follow up Flag Status: Flagged Victoria The Geologist said the Qannik interval has approximately 5'of net pay although compared to the western CD3 wells, it's of poorer quality. While performing our standard circulation while staging in casing,we were circulating out gas entrained in the mud. We believed this is a function of multiple packoffs while drilling and tripping and not an influx.We did perform flow checks and confirmed the well was static multiple times. As we continue to work on our plan forward to suspend CD3-130,we have taken the above into consideration. Please let us know if you have any further questions. We will keep you updated. Thanks. Nina Anderson Senior Drilling Engineer WNS Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Tuesday, February 25, 2014 1:51 PM To: Brunswick, Scott A Subject: [EXTERNAL]RE: CD3-130 PTD 213-160 - Int Csg Run Issue Scott, What is the hydrocarbon potential of the Qannik in this well? Approval is granted to cement above the Qannik as described below and to bullhead/squeeze cement for coverage of the Nechelik/Kuparuk. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferq usonAalaska.qov 1 • • From: Brunswick, Scott A [mailto:Scott.A.Brunswick(aconocophillips.com] Sent: Tuesday, February 25, 2014 10:49 AM To: Ferguson, Victoria L (DOA) Subject: CD3-130 PTD 213-160 - Int Csg Run Issue Victoria While running our 7-5/8"intermediate casing on CD3-130,the string started taking weight around 14,200' MD in the lower HRZ formation. Casing setting depth is 15463' MD and the casing shoe is approximately 1026'from setting depth in the Kalubik/K-1 interval at 14,307' MD. The rig is unable to circulate at this time and the over pull is too high to retrieve the casing string. We will continue to attempt running the casing to bottom, but would like to begin a contingency plan if forward progress is unsuccessful. The 2nd stage tool for isolating the K-2(Qannik) is currently+/-400'above the zone at^'7085' MD. The Top of Qannik is at 7485' MD. If the 2nd stage tool cannot move any further downhole due to the casing running difficulties,the cement pumped will be placed 500 ft.above the Qannik from 7085' MD to 6085' MD. Would this be adequate to isolate the Qannik from surface? Without circulation out the shoe we would need to perform some type of bullhead or squeeze operation to attempt to get coverage of the Nechelik/Kuparuk. Once this lower cement column has been placed,there will be zonal isolation between the Qannik and the lower hydrocarbon bearing zones. See the attached schematic for reference of the current status of the well/casing. Once the 7-5/8"casing has been set and properly cemented,ConocoPhillips will be temporarily suspending CD3-130 at the intermediate casing and moving to CD3-316B. (A 10-403 suspension sundry will be submitted along with final logs and reports.) Please advise in regards to zonal isolation of the Qannik and contact me if you have any questions. Thanks Scott 907-263-4249 2 • Colville River Field i CD3-130 Nechelik Injection Well Updated S.Brunswick (2/25/2013) 20"Conductor to 80' ,dill Ilk 10-3/4"45.5#L-80 BTC-M Ji. Surface Casing @3353'MD/2480TVD cemented to surface •5 0 O O HES 7-5/8"Stage Collar N �v , 2 Qannik Interval 7485' MD/4113'TVD - Z---"----- .K _thor ec'4(11 / Q6rhh„ G ( Packed off believed near I u shoe 1L i' Shoe currently @ 14307' i MD I D2b f HRZ Top 13735' MD/6360'TVD �l\F„/N-A-7-1HRZ Base �* r� 14370' MD/6564'TVD Kuparuk C - 4ip 21 14,832' MD/ 6690' i "adi'8� OA,TVD ‘" II�f 11, -5/8"29.7#L-80 BTC-M Casing proposed setting @ 15,463' MD Nechelik 15,412 MD/6,806'TVD TD—15483 ft MD 110 Ferguson. Victoria L (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Monday, February 03, 2014 6:49 PM To: Regg,James B (DOA) Cc: Ferguson,Victoria L(DOA); DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNALIRE:CD3-130 PTD 213-160 Follow Up Flag: Follow up Flag Status: Flagged Ok thanks. We went ahead and performed another function test just to be on the safe side. Sent with Good(www.good.com) Original Message From: Regg, James B (DOA) [jim.regg(c alaska.gov] Sent: Monday, February 03, 2014 09:46 PM Central Standard Time To: Brunswick, Scott A Cc: Ferguson,Victoria L (DOA);DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: CD3-130 PTD 213-160 Scott- You are correct about no set time interval for diverter function test(no requirements for subsequent tests after the initial pre-start function test). You are still required to maintain a functional diverter system going forward with drilling the new surface hole. Another diverter function test and visual inspection of the equipment to confirm its integrity would seem to be prudent but not mandated by regulation. Sent from Samsung Mobile Original message From: "Ferguson,Victoria L (DOA)" <victoria.ferguson@alaska.gov> Date: 02/03/2014 1:17 PM(GMT-09:00) To: "Regg,James B (DOA)" <jim.regg@alaska.gov> Subject: Fwd: CD3-130 PTD 213-160 Can you answer the question about the function test on the diverter? Sent from my iPhone Begin forwarded message: 1 • • From: "Brunswick, Scott A" <Scott.A.Brunswick@conocophillips.com> To: "Ferguson, Victoria L (DOA)" <victoria.ferguson cr,alaska.gov> Subject: RE: CD3-130 PTD 213-160 Victoria I wanted to touch base with you and ensure we are still good to re-drill the surface hole so I've put together some material to illustrate what we've done with plugging back for re-drill. CD3-130 experienced issue while running the 10-3/4" surface casing on Wednesday January 29th. The casing shoe would not pass a hot gamma stringer @ 1.180 ft. MD at the base of the permafrost. Attempts of rotating&circulating the casing were attempted to no success at getting the casing past the ledge. The casing was pulled, laid down,and a clean out assembly ran in hole. The clean out assembly hit tight spots @+/-831 ft. MD;this area was slid through with difficulty, once past 831 ft. MD another tight spot was encountered 1,002 ft. MD. While attempting to work past the tight spot the hole was inadvertently sidetracked. The bit dropped inclination,this drop caused a collision avoidance risk with an offset well below the CD3-130 well path if drilling were to continue for 200 ft. longer, and the upper hole section continued to degrade driving the decision to plug back the hole and re-drill the entire surface hole section. The first plug was pumped @ 18:00 Friday January 31st. The first plug may have fallen downhole,the stinger tagged something solid at+/- 839 ft. MD. A second 200 bbl. cement plug was set. The second plug was tagged @ 697 ft. MD. This calculates to 690%hole washout over the second plug interval. A third 200 bbl. cement plug was pumped Sunday morning @ 09:00; the wait time of 8 hours was followed. The third plug was tagged @ 21:30 on Sunday @ 484 ft. MD,the calculated hole size for the third plug was greater than 31". The fourth and final plug was pumped at 02:30 Monday morning February 3rd. The fourth and final plug was seen all the way into the conductor and dressed off. The rig is currently rigging down all equipment from the cement job in preparation to pick up the BHA and commence the surface hole re-drill. Please let me know if there is further information I can supply or forms to submit. Please note that the wp10 attached is NAD83. Another question I had was diverter function tests. I can't locate a set period to function test a diverter as we would a BOP. Is there a set time? Would this be required before the re-drill? We will be within a+/-200 ft. radius of the original CD3-130 surface hole with the same mud weights and we saw no gas. Thanks Scott From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Thursday, January 30, 2014 6:14 PM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]Re: CD3-130 PTD 213-160 You have approval to proceed as outlined below. Sent from my iPhone 2 • On Jan 30,2014,at 4:51 PM, "Brunswick, Scott A" <Scott.A.Brunswick@conocophillips.com<mailto:Scott.A.Brunswick@conocophillips.com>> wrote: Victoria CD3-130 surface hole was drilled to TD. While running casing a ledge was encountered that we could not get passed. We picked up a clean out BHA to address the hole. We had tight spots in numerous location while working back in the hole, and it looks like the have dropped 2.3° inclination from the original survey at a bit depth of+1- 1034 ft MD. We will likely need to re- drill the surface hole. We currently do not have the GR tool in the clean out BHA. If we were to drill to TD of the surface section would it be approved to do so without the GR tool. We would still supply the AOGCC with the GR logs from the original drilled surface hole. Thanks Scott 3 PTO 2/3 - 6,6 Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Thursday,January 30, 2014 6:14 PM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA) Subject: Re:CD3-130 PTD 213-160 You have approval to proceed as outlined below. Sent from my iPhone On Jan 30,2014,at 4:51 PM, "Brunswick,Scott A"<Scott.A.Brunswick@conocophillips.com>wrote: Victoria CD3-130 surface hole was drilled to TD. While running casing a ledge was encountered that we could not get passed. We picked up a clean out BHA to address the hole. We had tight spots in numerous location while working back in the hole,and it looks like the have dropped 2.3°inclination from the original survey at a bit depth of+/- 1034 ft MD. We will likely need to re-drill the surface hole. We currently do not have the GR tool in the clean out BHA. If we were to drill to TD of the surface section would it be approved to do so without the GR tool. We would still supply the AOGCC with the GR logs from the original drilled surface hole. Thanks Scott • w � I 7s9 THE STATE Alaska Oil and Gas "' ALASKA. G apse nation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op 0E- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-130 ConocoPhillips Alaska, Inc. Permit No: 213-160 Surface Location: 4037' FNL, 1243' FEL, Sec. 5, T12N, R5E, UM Bottomhole Location: 4730' FNL, 5070' FEL, Sec. 21, T13N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, cgi-e Cathy P. 1 oerster Chair, Commissioner DATED thisI qday of November, 2013. y STATE OF ALASKA AEC E I m AKA OIL AND GAS CONSERVATION COM ION OCT 14 2013 PERMIT TO DRILL 20 AAC 25.005 AOGCL la.Type of Work: lb. Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q. 1c.Specify if wel is proposed for: Drill D. Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates E Redrill ❑ Reentry ❑ Exploratory ❑ Service- WAG 0• Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD3-130 r 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 100360,Anchorage,AK 99510-0360 MD: 22356.99' TVD: 6763.8' Colville River Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): S13 Surface: 4037'FNL, 1243'FEL,Sec 5,T12N, R5E,UM ' ADL 364472,364471 , 37/1041 37UJ0S '4 Fiord Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 5269'FNL, 1209'FEL,Sec 28,T13N, R5E,UM • Tobin Nos.931986,931976 1/11/2014 Total Depth 4480.Acres 575 inProperty: .?I.@ 1(, 14. Distance to Nearest Property: 4730'FNL,5070'FEL,Sec 21,T13N,R5E, UM • IS,ate, lob 8400'to IADL 391394 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: _ 48.8 feet 15.Distance to Nearest Well Open Surface: x-387,799.14' y-6,003,743.55' Zone-4 . GL Elevation above MSL: 12.5 feet to Same Pool: CD3 119 @ 1450' 16. Deviated wells: Kickoff depth: 250 feet • 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91.12 degrees Downhole: 2835. Surface: 2153 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 62.5# L-80 Welded 79' 37' 37' 114' 114' Pre-installed,5.5 sx,insulated 13.5" 10.75" 45.5# L-80 BTCM 3129.46' 37' 37' 3229.46' 2500' 316 ft3 CIsG Tail,2395 ft3 ASL Lead 9.875" 7.625" 29.7# L-80 BTCM 15322.38' 37' 37' 15359.38' 6813.8' 301 ft3 2nd stg,673 ft3 1st stg-CIsG 6.75" 4.5" 12.6# L-80 HYD521/1B18057' 14300' 6546' 22356.99' 6763.8' N/A 6.75" 3.5" 9.3# L-80 EUE 14263' 37' 37' 14300' 6546' N/A 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis Ell Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date' C4..6ze . ,_.- /6 -//-13 22. I hereby certify that the foregoing is true and correct. Scott Brunswick-263-4249 Contact Scott.A.Brunswick(a�cop.com Email Printed Name Cert( : , At,,, A_ Title o,Atll `ter Signature I L otA Phone Z.C=''5 Co 12 v Date 1''(f_(G -'e3 "'JJJ Commission Use Only Permit to Drill Number: Permit Approval % See cover letter for other Number: 4 0I cC 1API 50-(oma-4eO 4?•-0®'O•( Date: I 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: Q` Other: ./ G }, Samples req'd: Yes E No[� Directional svy req'd:Yes[�No❑ !' / V r r�r r (/l/GL i VCS d-, ��C GJpacing exception req'd: Yes ❑ No Er Inclination-only svy req'd:Yes❑ No IC eb� ✓t-tf- rl VvlK2P0 Wcrivice ��rivztcd qtr^ ( .c 71-4- c2,5---41zlb) 0 �rlww pe-LC-cd plact/n�fr-11 I 5-0' i/1'� D 9-1,-)9-1,-)la ✓e /2�r �--a ti , s / ,IU C7 CC rrVIrl�tl CBL- reGLvi "CG, beF Pra6r'G! ' /� < APPROVED BY Approved by: ar„E , f j,e�� >(. COMMISSIONER THE COMMISSION Date: //---/ •% ---/.<it /(:). Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate VL-n nt/ / l3 ,,,e /0( .�i S • RECEIVED October 11th, 2013 OCT 14 2013 Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-130 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore pre-produced/ injection well from the CD3 (Fiord) pad. The intended spud date for this well is January 11th, 2014. It is intended that Doyon Rig 19 be used to drill the well. Slot 30 will be used and the well named CD3-130. i A 20" conductor is currently set to a depth of 114' RKB. Doyon 19 will drill a 13-1/2" surface hole; 10-3/4" surface casing will be set +/- 10 ft. TVD above the C-30 formation. Intermediate will be a 9-7/8" hole section landing at +/- 83° inclination in the Nechelik formation. To combat shale instability an under-reamer will be run to open the hole from the top HRZ to TD to 11". A 7-5/8" long string of casing will be run through the intermediate hole section. The production section will be a 6-3/4" hole geo-steered through the Nechelik formation with a total measured depth of+/- 22,357 feet. The well will be completed using a 4-1/2" liner with pre-perforated pups, and tied back to surface with a 3-1/2" tubing string. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval.; This will leave a mud gap between the two stages. ) IAF car-A:4 It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2) is c��un granted. At CD3, there has not been a significant indication of shallow gas or gas 7` -?12 hydrates through the surface interval. 4Z`IJ3 Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. i • If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Rob Stinson at 263-4449. Sincerely, rf , Scott Brunswick Drilling Engineer Attachments cc: CD3-130 Well File / Sharon Allsup Drake ATO 1530 Rob Stinson ATO 1700 Lanston Chin Kuukpik Corporation • Action for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 CD3-130 Application for Permit to Drill Document ConocoPhillips m". Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (/)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25005 (c)(5)) 4 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 4 7. Diverter System Information (Requirements of20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of20AAC 25.005 (c)(13)) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 10 (Requirements of 20 AAC 25.005 (c)(14)) 10 CD3-130 APD Page 1 of 16 Printed. 11-Oct-13 • tion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 15. Attachments 10 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 10 Attachment 3 Well Schematic 10 Attachment 4 Cement Summary 10 CD3-130 APD Page 2 of 16 Printed: 11-Oct-13 A4103tion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 1. Well Name (Requirements of 20 AAC 25.005 0) The well for which this application is submitted will be designated as CD3-130. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) i This well is planned as a Nechelik pre-produced injection well supporting the offset CD3-119 well. Location at Surface 4037'FNL, 1243' FEL, Sec 5, T12N,R5E,UM, NAD 1927 RKB Elevation 48.8'AMSL Northings: 6,003,743.55' Eastings: 387,799.14' Pad Elevation 12.5'AMSL Location at top of Nechelik productive5269'FNL, 1209'FEL, Sec T12N,R5E,UM 013 horizon—INT Csg Nad 1927 Measured Depth, RKB: 15,359.38' Northings: 6,012,955.30' Eastings: 395,864.01' Total Vertical Depth, RKB: 6,813.90' Total Vertical Depth, SS: 6,765.10' Location at Total Depth 4730' FNL, 5070' FEL, Sec 21,T13N,R5E,UM Nad 1927 Measured Depth, RKB: 22,356.31' Northings: 6,018,827.70' Eastings: 392,072.45' Total Vertical Depth, RKB: 6,763.80' Total Vertical Depth, SS: 6,715.00' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 19. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Csg Setting Fracture Pore Casing Depth Gradient pressure ASP Size MD/TVD(ft) (lbs./ (psi) Drilling (in) gal) (psi) 20 114/ 114 10.9 52 53 10-3/4 3229/2500 14.5 1131 1635 7-5/8 15359/6814 12.5 2835** 2153 N/A 22356/6764 12.5 2813** N/A • NOTE:The Doyon 19 5000 psi BOP equipment is adequate.Test BOP to 3500 psi. • ** NOTE: Pore Pressure is estimated reservoir pressure I PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: CD3-130 APD Page 3 of 16 $ r) Printed: 11-Oct-13 .._� • illation for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 1) ASP=[(FG x 0.052)-0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where; FPP=Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(20"") ASP=[(FG x 0.052)—0.1]D _[(10.9 x 0.052)—0.1]x 114=53 psi OR ASP=FPP—(0.1 x D) =(.052*2500*8.7)—(0.1 x 2500')=881 psi 2. Drilling below surface casing(10-3/4") ASP=[(FG x 0.052)—0.1] D =[(14.5 x 0.052)—0.1]x 2500= 1635 psi OR ASP=FPP—(0.1 x D) =(.052*6814*8.0)—(0.1 x 2500')=2585 psi 3. Drilling below intermediate casing(7-5/8") ASP=Reservoir Pressure—(0.1 x D) =(.052*6814'*8.0)—(0.1 x 6814')=2153 psi (B)data on potential gas zones; Please see Attachment 2-Drilling Hazards Summary (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; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out casing shoes and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) CD3-130 Completion casing and cementing program: CD3-130 APD Page 4 of 16 Printed: 11-Oct-13 Action for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (!b/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 62.5 L-80 Welded 114' Surf 1147114' Pre-installed,5.5 sx,insulated Cemented to Surface with 10 3/4" 13 1/2" 45.5 L-80 BTCM 3129.46' Surf 3229.4672500' 316 ft3 15.8 ppg Class G Tail&2395 ft3 AS 3 Lite 10.7 ppg Lead 9 /8„ Qaanik 2nd stage cement with 301 ft3 7-5/8" x 11" 29.7 L-80 BTCM 15322.38' Surf 15359.38'/6813.8' 15.8 ppg Class G,Shoe cement with 673 ft3 15.8 ppg Class G HYD52Swell Packer,pre-perforated pups,HYD 4'/2" 6-3/4" 12.6 L-80 1/IBTM 8057' 14300'/ 22356.99'/6763.8' 521&IBTM connections w/torque rings 3'/2" 9.3 L-80 EUE 14263' Surf 1430073546' Tubing tie back 7. Diverter System Information (Requirements of20AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. At CD3, there has not been a significant show of shallow gas or gas hydrates. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using mud systems having the following properties: A WBM Spud mud will be used to drill the 10-3/4"hole section. A standard high viscosity fresh water gel spud mud is planned for drilling the surface interval. Flow line viscosity will be kept at+/-300 sec/qt while drilling the gravels. Viscosity to cementing will be reduced to+/- 80-100 sec/qt. Mud weight @ spud will be 8.7 ppg and weighted up to 9.6-9.8 ppg as drilling progresses. The mud system may be weighted up to 10 ppg for trip out of hole and casing run. Using cold make up water will assist in keeping the flow line temperature as low as possible. LSND Mud 114'—3239' Density(ppg) 8.7—9.8 Yield Point(cP) 30-60 Plastic Viscosity(cP) 10- 16 Funnel Viscosity 70-300 Initial Gels 8—15 10 minute gels <30 API filtrate NC- 10 cc/30 min A WBM mud system will be used to drill the 9-7/8"x 11"hole section. A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists,particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses,and lost circulation material will be introduced to the system if necessary.Good filter cake quality,hole cleaning and maintenance of low drill solids(by diluting as required)will all be beneficial in maintaining wellbore stability. MW may be increased to 10.0 ppg for tripping. LSND Mud 3229'—15359' CD3-130 APD Page 5 of 16 N ' Printed: 11-Oct-13 • Ation for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Density(ppg) 9.8- 10.0 Yield Point(cP) 13 -22 Plastic Viscosity(cP) 10- 16 Initial Gels 8 - 10 10 minute gels <1=20 API filtrate <8 cc/30 min A WBM mud system will be used to drill the 6-3/4"hole section. The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill-in fluid. The base fluid will consist of 3%KCl,with calcium carbonate bridging material to minimize formation damage.Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition.ECD's will be monitored with real time PWD data,and controlled by maintaining fluid rheology and pump rates within specifications. Flo-Thru Mud 15359'—22357' Density(ppg) 8.8—9.0 Yield Point(cP) 10- 15 Plastic Viscosity(cP) 7- 12 Initial Gels 6—9 10 minute gels 8— 12 API filtrate < 10 cc/30 min Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20AAC 25.005(c)(12)) 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)) The proposed drilling program is listed below. Please refer to Well Schematics. 1. Move&Rig up Doyon 19 rig onto slot 30,well name CD3-130. 2. Rig up riser 3. P/U 5"DS-50 drillpipe needed to drill surface hole. 4. Drill 13-1/2"hole to the surface casing point as per the directional plan. (Directional/MWD/GWD/GR/RES) CD3-130 APD Page 6 of 16 Printed: 11-Oct-13 AStion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 5. Run and cement the 10-3/4"surface casing. 6. Nipple up BOPE. 7. Perform full BOPE test to 250/3500 psi(250/2500 psi on the annular)using 5"test joint. E' 8. Pick up and rack back all 5"drillpipe needed to drill the intermediate hole section. 9. Make up the directional BHA to include RSS,MWD, GR/RES/PWD/NEUT/DENS,& 11"Reamer. ✓ 10. Test the reamer on surface to ensure activation and deactivation functions. 11. TIH with intermediate BHA. 12. Once cement is tagged, close the top pipe rams and test the casing to 3,500 psi for 30 minutes. 13. Chart and send in the pressure test. 14. Drill out shoe track and 20 ft.new formation. 15. Circulate and condition mud until even in and out. 16. Perform a leak off test, stopping if reaching 18 ppg EMW,minimum needed to drill ahead is 12.5 ppg EMW. 17. Monitor well for flow for 30 minutes. 18. Begin drilling intermediate hole section as per directional plan. Displace well from surface hole spud mud to 9.8 ppg intermediate LSND mud system while drilling ahead. 19. Drill the 9 7/8"hole to 300 ft below the Qannik formation. 20. CBU X3. 21. Perform short trip out of hole, stopping once RSS is within 30 ft of the surface shoe. 22. Trip back in hole. 23. Ream down last two stands. 24. Circulate and condition mud once back to bottom. 25. Drill ahead in the 9 7/8"hole to just above the HRZ. 26. CBU X3. 27. Perform short trip out of hole, stopping once RSS is within 30 ft of previous short trip beginning depth. 28. Trip back in hole. 29. Ream down last three stands. 30. Circulate and condition mud once back to bottom. 31. Treat the active system with wellbore stability mud additives prior to drilling into the HRZ. 32. Drop RFID chips to activate the reamer. 33. Drill 9 7/8"x 11"hole to total depth. 34. After TD,circulate hole clean with 4 BU a. A quadrant ream with the RSS may be performed based on the company representative discretion. The purpose of the quadrant ream is to open up the rat hole from the reamer to the bit, 35. Drop the RFID chips to close the reamer. 36. Weight up the system to 10.0 ppg for trip margin. 37. Pump out of hole to the top of the HRZ. 38. Trip back to bottom. 0 39. Pump out of the hole to the top of the HRZ while spotting a casing running pill with 3%lubes. CD3-130 APD Page 7of16 Printed: 11-Oct-13 • •tion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 40. POOH with directional BHA, download data,and lay down same. 41. Swap top rams to 7-5/8" solid body rams and test same 250/3500 psi. 42. Rig up 7 5/8"casing running equipment,prepare a 4 1/4"IF B X 7 5/8"BTCM Pin and make up with TIW valve for well control purposes. 43. Pull wear bushing and install casing running sleeve. 44. RIH to TD filling pipe regularly based on company representatives schedule. 45. Rig up cement equipment and test to 3500 psi. 46. Pump 1st stage cement job placing the cement top at a minimum 500 feet above Kuparuk&Nechelik formations, secondly 300 ft minimum above the packer setting depth on subsequent liner run. 47. Prior to bumping the plug land the casing on the hanger. 48. Pump 2nd stage cement job. Cement will be placed 500 feet above the top of the Qaanik sand. / 49. Lay down 7 5/8" landing joint. 50. Remove casing running ring and install the 7 5/8"pack off. 51. Test pack off to 5,000 psi for 10 minutes. 52. Swap out the 7 5/8"solid body rams for 3 'h"x 6"VBR. 53. Perform full bi-weekly BOPE test to 250/3500 psi,250/2500 psi on the annular. Test with 4 '/2"&4"test joints. 54. Install wear bushing. 55. Perform a leak off test down the 9-7/8" x 7-5/8" casing annulus to confirm the fracture pressure referenced to the surface casing shoe. a. Ensure a minimum wait on cement time of 6 hours has passed before performing the backside LOT and freeze protecting. 56. Freeze protect the 9-7/8"x 7-5/8"casing annulus. 57. Lay down 5"drillpipe. 58. Make up clean out BHA and single in hole with 4"drillpipe. 59. Before tagging the stage collar,pressure test casing integrity above the collar to 1,000 psi for 10 minutes. 60. Drill out stage tool equipment. 61. Perform casing pressure test after drilling out stage equipment to 3,500 psi for 10 minutes. 62. POOH and lay down clean out BHA. 4"z_),,.' CPV ' 63. Pick up remaining 4"drillpipe. ksS(G 64. Pick up the 6 3/4"RSS Directional BHA(LWD Program: GR/RES/PWD/SONIC). / 65. TIH with the drilling BHA. 66. Tag up on cement. 67. Displace 10 ppg LSND fluid in hole with fresh 8.8-9.0 ppg Flo-Thru. 68. Pressure test casing to 3500 psi for 10 minutes. Chart and send in. 69. Drill out cement and shoe track. 70. Drill out 20' of new hole. 71. Circulate and condition mud until even in and out. CD3-130 APD Page 8 of 16 Printed: 11-Oct-13 • A•tion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 72. Perform leak off test. Minimum leak off point required is 11.0 ppg EMW. 73. Drill to TD utilizing LWD for geosteering. 74. Once TD is reached,CBU x 4 while standing one stand back every hour. 75. Monitor the well for flow after CBU x 4. a. Be aware that past Nechelik wells have"breathed"during lateral drilling operations. If the well is flowing back due to this phenomenon, do not continue tripping operations until it is firmly established the well is breathing and flow rate back is decreasing. Perform an exhale test if necessary and contact the drilling superintendent. 76. Pump out of the hole pulling 5 to 6 stands per hour. 77. Once bit is inside the intermediate casing, CBU x 1 and monitor the well for flow. 78. POOH, ensuring hole is taking proper fluid every stand during trip. 79. Lay down the directional BHA. 80. Rig up to run completions. 81. Prepare a 4"XT 39 B X 4 '/z"IBTM&4 '/2"HYD521 Pin and make up with TIW valve for well control purposes. 82. Run lower completions to include: 4-1/2"IBTM pre-perforated pups,swell packer,XN nipple,PBR, liner top packer, and hanger. 83. Set liner top packer and release running tools. 84. POOH and lay down running tools. 85. Prepare a 4"XT 39 B X 3 '/2"EUE Pin and make up with TIW valve for well control purposes. 86. Run the upper completions to include: 3-1/2"EUE 9.3 ppf,L-80 tubing with seal assembly,X-nipple, SSSV, 3 x gas lift mandrel,BP-6i nipple. 87. Sting in, space out. 88. Pick up seal assembly out of PBR. 89. Circulate inhibited brine. 90. Sting in. 91. Run in lock down screws. 92. Back out landing joint. 93. Pressure test tubing and annulus to 3,500 psi for 30 minutes. 94. Bleed down the tubing to 2,000 psi and pressure test the annulus to 3,500 psi for 30 minutes. 95. Bleed down the tubing pressure to 0 psi. 96. Bleed the tubing and annulus pressure to 0. 97. Land tubing hanger. 98. Pressure test tubing hanger seals 250/2500 psi for 10 minutes. 99. Install the two way check valve and pressure test through the SOV to 2,500 psi for 10 minutes in the direction of flow. 100.Nipple down the BOPE. 101.Nipple up the tree. CD3-130 APD Page 9 of 16 Printed: 11-Oct-13 • A•Stion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 102.Pressure test tree to 5,000 psi. 103.Remove the two way check valve with lubricator. 104.Circulate sufficient diesel to fill the tubing plus provide 2000 ft TVD of diesel freeze protection on the annulus. 105.Set Back Pressure Valve&test in direction of flow. 106.Secure well. 107.Rig down and move off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Annular disposal candidates are currently being evaluated for the 2014 CD3 winter drilling season. If candidates are identified and permitted, CD3-130 drilling induced fluids and/or cuttings would be placed in those wells,that CD1- 01A disposal well will be the backup plan. / If annular injection exceeds allowable volume/time, or pressures exceed the maximum allowable injection pressure for the fluid pumped,then freeze protection will be pumped and the well no longer used for annular injection. If unable to inject down the annulus,dispose of waste into the class I disposal well at CD1-01A. Refer to the Alpine Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary CD3-130 APD Page 10 of 16 Printed: 11-Oct-13 • Altion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Attachment 1— Directional Plan CD3-130 APD Page 11 of 16 Printed: 11-Oct-13 • • 0 co a_. ° Q o ..... rc, ,,,, s pi. ,..40 .E y V 0 P C 0 U um a N. N ca 0 �C Q el• 2 z CO < =2 tits% Cm 1 03 �, cp 0. m � •.... — a.. 3 co M Q M M M ` o D a r r /7 N 0a800 M L Q= C i 0 c c D LL U U U o Q N co _ 15 M O CTS 03 III= V U a a a CA • S Northing (4500 ft/in) IIilliIiiiiIiiiiIiiiiItiiiIiiiiImil m iIm 1IimIiiiiIiiilIiiilIiiii o - N - _ r c) _ O CO - O. p _ - 3 Q U - < N - O C7 — cy, r) m 0 _ 7p � '1 _ CO o_ r )(V) ' - 6 c) 0 - 0 0 - 0 0 — -:. 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O2 a) + + o CL • ) Lo E (fl @ N - - c a '- C m 2. ,- 0 E d F- w 6 o .a c o t o 2 cG 47 c o c Cv R ac C) 3 c y v o 2cw _ o d) fX T R Tore cC L o o o 0 c C o t � � 2zcno N- a a 2 2 s- CI 2Q om co co v CI Z O o CO (O v CO m CV 0 a CO o6 . C) o 6 ri 6 m cv 6 °) 0)) M mis m Ez CE 0 0 O o LL LL 000 - 0 O o 0 0 U) 0n LO 00o v CO o COoO o o v 09 �+ (.) NM c • N>. M ONMOV N CO• 0) a) c � � cn : I) � cncnco0co1n . co -a (o y 5 J 3 J J J J O J M J N E a co a co 0 N- a a a N a CO a CO N.. > N n .-. E . t 'C 'C r r 'C r r r rN O O U m cO cO m CO It It CO cO CO CO CO m a 2la. a U Y cn U CO CO CI) CI) co cn co co co co co I- Q Q O CO V CO O CO CO N O) O) N CO H O) O H LO V L) L- O) O) I� H H. O) O) O O 4 O V N CO (n M co (O O) (O (0 M (0 M O CO N CO O V c W = V O O CO f- m Wco (n r W I: N N (O (n C_ O 0 U O N N 1O CO CO - CO V CO CO O) (O 1% O CO I- o o N H CO I� N CO O O O) O CO O M O) N W C- O• Cl) co Lo LU (d CO (o N- O co CU r O) N- J N H CO (O CO CO CO CO V7 CO Z . r tO (0 CO CO CO CO C + U C 00000000000 N M O CM N 4 U L co O O O co O) co O W O) VO CO co O O O O O O) O N M O 0 O) WCD N 0_ co jON CO O) O V (.No. V O OO) o0 CO0 MI� (rfl d coIiiin "6 O O o `- H N L6 CO CO (O CO O CO (O gr (O c0 CO o - a LE ac) A $ d ` a a 0 0 0) o 0 co 0 V CO N CO CO N 00 V 0) CO O O U U M O V CO O) O) CO 0 CO H CO CO CO N V O) UO A L. L _ O O C O U) r N- O) O) O) 00 CO (O (O , C N CO C C O p. G O O N 0) o CO O (O N- LO O N a N (6 a N y N (fl Cr) V m O N W M co I. N COCL U � UddU • y0 NONv (� n nrnrnN (� o T- V- <v 16 m c c G V O C Q U O d C a) N Ca E '�y 'N O �1, oa. ca 30 a 0 o • • oi4sssP V AAR - �dmmma vaazs O ',oG000C O F88888< Lf) • a °ornrnvmro,cria N '^o oa W^^�NN� T .n.n.n v�inv F0000gE , N 20mNNp ppNp t10(LCC� O Q ssst0O Z Ei annn O Woooa vi viv Ln Q �W eCIGNNCa w .eano» o u>^arna O i I O 71 „988888EN w owiviovios nnnnma T oom m.uv w O C —, O c r O T- y" f VL. . Q 443;11 C / 111 IHU v- ..- -: _ -- __.J `� J _� � y al p ryQW. W O a O �_� O2+r s G� U O (0* LC) �O� ✓1,D3 3'' . Ln to 444k \ tilitten' M ` N T 1... o`' Iiii I a) ° Q c° V o`'s o r o Lo o C(> v v O O co OJ °e N o �J $ O O O O O O t O O O O O O o LO O Lf) O Ln O c N• L) N O N LO 4 T TuOI 005z)'-H111aoNA-TulnoS • • CD3-130wp06 Surface Location j j m CPA! Coordinate Converterj From: __._____.__ To: , Datum: INAD83 I Region: lalaska . Datum: 1NAD27 ' Region: ialaska ( Latitude/Longitude Decimal Degrees Latitude/Longitude 'Decimal Degrees s � ..- - C LITM Zone: 1 r South =— UTM Zone: True (— South #: State Plane Zone: �—,1 Units: us-ft , ` State Plane Zone: True Units: us-ft r LiP al Description(rlrt.C?"227 is..:. r: Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11527831.05 Townshi r Ran e: P 012 N g 005 E ' : 16003490.74 Meridian: lU Section:15 FNL 4036.6809 FEL 11243.3766 Transform Quit I Help LCD3-130wp06 Intermediate Casing I 1 CPAI Coordinate Converter }LtiL From: _ _ ___, _._-1 To: Datum: INAD83 l Region: f alaska Datum: 1NAD27---.71 Region: alaska Latitude/Longitude Decimal Degrees T Latitude/Longitude !Decimal Degrees 17- UTM Zone: {— South " UTM Zone: True__. r South •`+ State Plane Zone: 4 Units: usft C State Plane Zone: [True 4,1 Units: .us-ft c 1 y� i Legal Description IPNrs,D27 only) ` Legal Description(NAD27 only) Starting Coordinates: _- — ------ 1 Legal Description ___.________ .—__.____-__. ---------- X! __._____X: 11535896.00 Township: 1013 N Range: 1005 E Y: 16012702.00 Meridian: lU Section: 28 _______ Fr!!!L 15268.8780 FET—C1 11209.5338 Transform Quit I Help • CD3-130wp06 TD (PA! Coordinate Converter J11-2J From: To: Datum: 1NAD83 Region: I alaska Datum: NAD 27 L. Region: alaska LatitudelLongitude IDecimal Degrees LatitudelLongitude !Decimal Degrees UTM Zone: r- South UTM Zone: True South State Plane Zone: 14 .„1 Units: ju -t State Plane Zone: Units: F7sTirs ,. Leaal Dem-iption 1rt6D27 only) (4- Legal Description(NAD 27 only) Starting Coordinates: Legal Description X: 11532104.00 Township: 1013 IN H Range: { ö rCIII Y: 16018575.00 Meridian: lu Section:!21 Fl\F 14728.7388 EE1j5070.0816 Transform Quit Help 0 roN rt !t, g `it s • Schlumberger ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-130 Plan: CD3-130 CD3-130wp06 Anticollision Summary Report 10 October, 2013 ConocoPh i l l i ps G N A L • III SchlumbergerSchlumberger Anticollision Summary Report ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD3-130 Project: Western North Slope TVD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Reference Site: CD3 Fiord Pad MD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Site Error: 0.00ft North Reference: True Reference Well: Plan:CD3-130 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:CD3-130 Database: EDM v16 Prod Reference Design: CD3-130wp06 Offset ND Reference: Offset Datum Reference CD3-130wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refen Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,432.07ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 10/10/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 36.30 1,300.00 CD3-130wp06(Plan:CD3-130) GYD-GC-SS Gyrodata gyro single shots 1,300.00 3,229.46 CD3-130wp06(Plan:CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,229.46 15,359.38 CD3-130wp06(Plan:CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15,359.38 22,356.99 CD3-130wp06(Plan:CD3-130) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC-Min centre to center distance or covergent point,SF-min separation factor, ES-min ellipse separation 10/10/2013 1:50:37PM Page 2 COMPASS 2003.16 Build 69 I a 0,.-) i • • Schlurn erg er Schlumberger Anticollision Summary Report ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD3-130 Project: Western North Slope TVD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Reference Site: CD3 Fiord Pad MD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Site Error: 0.00ft North Reference: True Reference Well: Plan:CD3-130 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:CD3-130 Database: EDM v16 Prod Reference Design: CD3-130wp06 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning CD3 Fiord Pad CD3-106-CD3-106-CD3-106 3,154.95 3,175.00 312.76 264.70 6.508 CC,ES,SF CD3-106-CD3-106L1 - CD3-106L1 3,154.95 3,175.00 312.76 264.70 6.508 CC,ES,SF CD3-107-CD3-107-CD3-107 36.30 36.20 459.75 458.79 476.893 CC CD3-107-CD3-107-CD3-107 373.92 375.00 462.96 455.63 63.109 ES,SF CD3-107-CD3-107L1 -CD3-107L1 36.30 36.41 459.75 458.79 476.893 CC CD3-107-CD3-107L1 -CD3-107L1 373.72 375.00 462.96 455.63 63.144 ES,SF CD3-108-CD3-108-CD3-108 5,421.33 4,825.00 434.53 315.71 3.657 CC, ES,SF CD3-109-CD3-109-CD3-109 199.19 200.00 419.27 415.32 105.960 CC CD3-109-CD3-109-CD3-109 3,766.65 3,325.00 464.40 388.50 6.119 ES,SF CD3-110-CD3-110-CD3-110 3,148.54 2,800.00 317.99 257.00 5.214 CC,ES,SF CD3-111 -CD3-111 -CD3-111 2,314.27 2,275.00 72.68 36.12 1.988 No Errors,CC,ES,SF CD3-111-CD3-111L1 -CD3-111L1 2,314.27 2,275.00 72.68 36.12 1.988 No Errors,CC,ES,SF CD3-112-CD3-112-CD3-112 1,798.14 1,850.00 125.79 96.64 4.314 CC,ES,SF CD3-114-CD3-114-CD3-114 1,346.57 1,425.00 297.14 272.96 12.288 CC,ES,SF CD3-115-CD3-115-CD3-115 1,320.35 1,375.00 168.97 144.81 6.992 CC,ES,SF CD3-117-CD3-117-CD3-117 1,012.39 1,050.00 206.39 187.29 10.805 CC,ES,SF CD3-118-CD3-118-CD3-118 1,162.33 1,200.00 153.13 133.37 7.748 CC CD3-118-CD3-118-CD3-118 1,183.48 1,225.00 153.48 133.35 7.624 ES,SF CD3-119-CD3-119-CD3-119 473.39 475.00 214.47 205.12 22.920 CC CD3-119-CD3-119-CD3-119 523.51 525.00 214.78 204.42 20.728 ES,SF CD3-119-CD3-119PB1 -CD3-119PB1 473.39 475.00 214.47 205.12 22.920 CC CD3-119-CD3-119PB1 -CD3-119PB1 523.51 525.00 214.78 204.42 20.728 ES,SF CD3-121 -CD3-121 -CD3-121 1,700.00 1,725.00 87.38 60.53 3.254 CC,ES,SF CD3-122-CD3-122-CD3-122 1,352.30 1,375.00 114.74 92.33 5.120 CC,ES,SF CD3-123-CD3-123-CD3-123 1,256.99 1,275.00 87.75 64.66 3.800 CC,ES,SF CD3-124-CD3-124-CD3-124 865.26 875.00 101.23 85.77 6.548 CC CD3-124-CD3-124-CD3-124 888.79 900.00 101.36 85.55 6.409 ES,SF CD3-125-CD3-125-CD3-125 1,169.87 1,175.00 39.05 17.17 1.785 No Errors,CC CD3-125-CD3-125-CD3-125 1,193.61 1,200.00 39.21 17.14 1.777 No Errors,ES,SF CD3-125-CD3-125PB1 -CD3-125PB1 1,169.87 1,175.00 39.05 17.17 1.785 No Errors,CC CD3-125-CD3-125PB1 -CD3-125PB1 1,193.61 1,200.00 39.21 17.14 1.777 No Errors,ES,SF CD3-125-CD3-125PB1 (surface)-CD3-125PB1 (surfac 1,178.50 1,175.00 38.96 17.01 1.775 No Errors,CC, ES,SF CD3-127-CD3-127-CD3-127 945.40 950.00 31.76 15.56 1.961 No Errors,CC CD3-127-CD3-127-CD3-127 969.70 975.00 31.95 15.41 1.932 No Errors,ES,SF CD3-127-CD3-127PB1 -CD3-127PB1 945.78 950.00 31.75 15.43 1.945 No Errors,CC CD3-127-CD3-127PB1 -CD3-127PB1 970.08 975.00 31.96 15.28 1.916 No Errors,ES,SF CD3-128-CD3-128-CD3-128 748.24 750.00 33.01 18.31 2.245 No Errors,CC CD3-128-CD3-128-CD3-128 772.76 775.00 33.05 17.86 2.176 No Errors, ES,SF CD3-128-CD3-128(Intermediate)-CD3-128(Intermedi 747.26 750.00 33.02 18.29 2.241 No Errors,CC CD3-128-CD3-128(Intermediate)-CD3-128(Intermedi 771.78 775.00 33.04 17.83 2.172 No Errors, ES,SF CD3-198-CD3-198-CD3-198 3,133.81 2,825.00 427.69 370.65 7.499 CC,ES,SF CD3-199-CD3-199-CD3-199 2,343.11 2,425.00 339.81 301.28 8.820 CC, ES,SF CD3-301-CD3-301 -CD3-301 3,301.96 2,900.00 249.29 197.77 4.838 CC CD3-301-CD3-301 -CD3-301 3,319.70 2,925.00 249.54 196.68 4.721 ES,SF CD3-301-CD3-301A-CD3-301A 3,308.58 2,900.00 249.24 197.23 4.792 CC CD3-301-CD3-301A-CD3-301A 3,326.31 2,925.00 249.94 196.54 4.680 ES,SF CD3-301-CD3-301APB1 -CD3-301APB1 3,308.58 2,900.00 249.24 197.23 4.792 CC CD3-301-CD3-301APB1 -CD3-301APB1 3,326.31 2,925.00 249.94 196.54 4.681 ES,SF CD3-301 -CD3-301 PB1 -CD3-301 PB1 3,301.96 2,900.00 249.29 197.85 4.846 CC CD3-301 -CD3-301 PB1 -CD3-301 PB1 3,319.70 2,925.00 249.54 196.75 4.728 ES,SF CD3-302-CD3-302A-CD3-302A 183.20 175.00 559.56 555.96 155.350 CC CD3-302-CD3-302A-CD3-302A 258.17 250.00 560.37 555.30 110.644 ES,SF CD3-320-CD3-320-CD3-320 36.30 36.75 199.55 198.54 197.389 CC CC-Min centre to center distance or covergent point,SF-min separation factor, ES-min ellipse separation 10/10/2013 1:50:37PM Page 3 COMPASS 2003.16 Build 69 ire f 1y'4 ki "4 i1 (' L • • Schiumberger Schlumberger Anticollision Summary Report ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD3-130 Project: Western North Slope TVD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Reference Site: CD3 Fiord Pad MD Reference: Plan: 12.5+36.3 @ 48.80ft(Doyon 19) Site Error: 0.00ft North Reference: True Reference Well: Plan:CD3-130 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:CD3-130 Database: EDM v16 Prod Reference Design: CD3-130wp06 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning CD3 Fiord Pad CD3-320-CD3-320-CD3-320 274.29 275.00 201.15 196.30 41.538 ES,SF CD3-320-Plan:CD3-320A-CD3-320Awp01 36.30 36.75 199.55 198.54 197.389 CC CD3-320-Plan:CD3-320A-CD3-320Awp01 274.29 275.00 201.15 196.30 41.538 ES,SF Plan:CD3-126-Plan:CD3-126-CD3-126wp06 647.42 650.00 77.74 65.03 6.116 CC Plan:CD3-126-Plan:CD3-126-CD3-126wp06 695.94 700.00 78.05 64.37 5.705 ES, SF Plan:CD3-129-Plan:CD3-129-CD3-129wp03 249.90 250.00 20.12 15.23 4.115 CC Plan:CD3-129-Plan:CD3-129-CD3-129wp03 599.02 600.09 21.24 9.51 1.810 No Errors, ES,SF Plan:CD3-131 -Plan:CD3-131 -CD3-131wp01 300.21 300.00 19.76 13.88 3.364 CC Plan:CD3-131 -Plan:CD3-131 -CD3-131wp01 425.16 425.00 20.96 12.64 2.520 No Errors, ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/10/2013 1:50:37PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips CD3-1 30wp06 Schlumberger Alaska E i 172 E m N a 4 N M g V ®U U U U hk P R ,' Pi' / 116pIlk 1 p '1 1 // 4"1111 12 I1IIII ,1�� E mourn 114 U 11i $4' \\,-) 1 !I30--,- - _AFC 1 0 1 r I I I I I I I I I I I I I I I I I I I I I I I 1 I I 1 I I 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire rangedVleasured Depth 36.30 To 22356.99 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 22356.99 Results Limited By: Centre Distance:2432.07 GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1300.00 CD3-130wp06(Plan: CD3-130) GYD-GC-SS 1300.00 3229.46 CD3-130wp06(Plan: CD3-130) MWD+IFR-AK-CAZ-SC 3229.46 15359.38 CD3-130wp06(Plan:CD3-130) MWD+IFR-AK-CAZ-SC 15359.38 22356.99 CD3-130wp06(Plan:CD3-130) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2500.00 3229.46 10-3/4" x 13-1/2" 10-3/4 6813.80 15359.38 7-5/8"X 9-7/8" 7-5/8 6763.80 22356.99 3-1/2"x 6-3/4" 3-1/2 LEGEND $- CD3-106,CD3-106,CD3-106 VO _e_ CD3-119,CD3-119,CD3-119 VO -I-- CD3-199,CD3-199,CD3-199 VO X CD3-106,CD3-106L1, CD3-106L1 VO -9- CD3-119,CD3-119PB1,CD3-119PB1 VO -El- CD3-301,CD3-301,CD3-301 V4 - CD3-107,CD3-107,CD3-107 V7 -t- CO3-121,CD3-121,CD3-121 VO $- CD3-301,CD3-301A,CD3-301A VO $- CD3-107,CD3-107L1,CD3-107L1 VO -0- CD3-122,CD3-122,CD3-122 VO -I-- CD3-301,CD3-301 APB1,CD3-301APB1 VO -A--- CD3-108,CD3-108,CD3-108 V14 -1- CD3-123,CD3-123,CD3-123 VO -6- CD3-301,CD3-301 PB1,CD3-301 PB/V1 0 CD3-109,CD3-109,CD3-109 V5 -X- CD3-124,CD3-124,CO3-124 VO -I- CD3-302,CD3-302A,CD3-302A VO - CD3-110,CD3-110,CD3-110 V12 -(er- CD3-125,CD3-125,CD3-125 VO -4- CD3-320,CD3320,CD3-320 VO $- CD3-111,CD3-111,CD3-111 V7 -9- CD3-125,CD3-125PB1,CD3-125PB1 VO -A- CD3-320,Plan:CD3-320A,CD3320Awp01 VO -- - CD3-111,CD3-111L1,CD3-111L1 V1 -e- CD3-125,CD3-125PB1(surface),CD3-125PB1(surface)VO Plan:CD3-126,Plan:CD3-126,CD3-126wp06 VO -9- CD3-112,CD3-112,CD3-112 V3 -9-- CD3-127,CD3-127,CD3-127 VO --X- Plan:CD3-129,Plan:CD3-129,CD3-129wp03 VO -X- CD3-114,CD3-114,CD3-114 V14 -8- CD3-127,CD3-127PB1,CD3-127PB1 VO -X- Plan:CD3-131,Plan:CD3-131,CD3-131wp01 VO - CD3-115,CD3-115,CD3-115 VO $- CD3-128,CD3-128,CD3-128 VO -8- CD3-130wp06 ▪ CD3-117,CD3-117,CD3-117 VO -e_ CD3-128,CD3-128(Intermediate),CD3-128(Intermediate)VO -A--- CD3-118,CD3-118,CD3-118 VO -X- CD3-198,CD3-198,CD3-198 VO Sec Inc Azi TVD +N/-S +E/-W DLeg TFa�VSec Target 1 0.00 0.00 36.30 0.00 0.00 0.00 0. 0.00 36 250 CD3-130wp06 3 .49 5.26 345.00 600.00 15.52 0.00 0.40.00 .16 1.50 345.00 15.10 4 904.50 12.86 345.00 900.00 61.72 -16.54 2.50 0.00 60.04 250 700 36.30 To 22356.99 5 1220.90 23.73 352 10 1200.00 159 07 -34.46 3 50 5.00 150.07 6 1495.90 33.35 352.10 1441.30 289.05 -52.50 3.50 10.00 266.89 700 1100 7 2911.80 67.20 50.40 2376.90 1155.26 433.13 3.80 76.27 697.90 8 10067.64 67.20 50.40 5149.90 5360.16 5515.98 0.00 0.00 1226.95 1100 1500 9 12261. 6 72.0 50.40 5900.00 6673.81 7103.92 0.26 0.00 1392.23 13:51,October 10 2013 10 14809.12 73.17 356.94 6698.80 8809.46 8038.79 2.00 -98.00 2605.43 11 15359.38 82.87 339.01 6813.80 9332.65 7925.79 3.64 -63.17 3098.81 CD3-B JB 17Sep12 Heel 1500 2000 12 15379.38 82.87 339.01 6816.28 9351.18 7918.68 0.00 0.00 3118.07 C LOBAL FILTER APPLIED: A 13 193.28 91.12 326.75 6835.69 9678.12 7751.05 4.00 -56.46 3482.03 2000 2400 14 19113.28 91.12 326.75 6769.69 124911.59 5906.35 0.00 0.00 6844.77 15 19216.44 90.09 324.96 6768.80 12576.97 5848.44 2.00 -119.91 6947.92 CO3-B 29Nov11 Mid 2400 2800 16 22356.99 90.09 324.96 6763.80 15148.29 4045.31 0.00 0.00 10088.46 CD3-B 29Nov11 Toe Depth From Depth To SurveYNlan TN! 36.30 1300.00 CO3.130,86(Kim Co3-130) GYD-GCSS 2800 3229 1300.00 3229.66 CD3-130xp06(PIan'CD3130) M0VD,IFN-AK-CAZ-SC 3229.06 15359 38 CO3.130v306 Men:CD3-130) .899,9A-AK-CAZ-SC 15359.30 22356.99 CD3.130,06(Pim CO3-130) MND•IFn-AWCAZ-SC 3229 4700 CASING DETAILS TVD MD Name Size 4700 6300 2500.00 3229.46 10-3/4"x 13-1/2" 10-3/4 6300 7800 6813.80 15359.38 7-5/8"X 9-7/8" 7-5/8 6763.80 22356.99 3-1/2"x 6-3/4" 3-1/2 7800 9300 9300 10800 10800 - 12300 12300 - 13800 0/360 13800 15359 15359 16200 150 16200 17100 -30/330 140 \ 30 17100 18000 130 18000 18900 120 18900 19700 110 `\�� 19700 20600 100 \-� N ; ` 20600 21500 � 21500 22357 -60/300 60 r� .� i_ ,, IIID .. row- 1 1,II z,F z '''- ----- 3 6 ' ,,,Agritigi",1 Tt'',. ,:x.,' ,..-:.,„„,.f.,-; :f-1 *ia�n`� t�u .�_A . -90/270 .�� Dg �.� et'- 1 .¢ ti,\ @wte zSS '', :'90 .n .§y:#�� ;I: a� � � /ilii ��\�'s`°�uT��ODA$��^�'Mi Fes" �uq it£ 1,+`I:\ ,av l �i'�0;arlt�,;d, ,a i rr se tali;% h v x s�-' � �� ..v• ri 4r dads \ ii '` *e` y . i" vdt t -�ji SM 0�� i`9 �N�;.-.a�I►�to 40 i/:iil0��r .¢ I 10 � �� it 0. itiiiiiiIipTkiVirrir iii.,4*-44-t*ele...,10,/,,,-r 1 ivaid1441kiretelgoidii,A.,;.,:,97 -sl��_ ei i,'� � iL r 9 p. I t►t, -120/ �-, �i�iil nry"1.2 a t--4 . j� 44 40, ` 7 / j}l� a o�ilF +i if 6.y:.41"20 Or tqLS‘f&tArArtb .4;ftti#7. ?1".... ....d.f=---/ -',..4":"AfatIWAP r‘ •r".t-f#;141- .,.,... 0�1 ' \ ` sem/It®!zieri ; rigroi " �-�d 11 0-3*.eltr,,ili 410-jgaM 41. �� Y 150/210 19`u ,:%,4__ X11��`yli 2 '1ji'i017 150 •-... �.r I • "Ti.t .t. ..A\sr /0=`944 1,,. ,A 0��/' .. D -122 -180/1:9 -4:- 33 - D 4- D a3 aC i- 3 -X- 33 0 $ C 1 $ C ,v0 9 C 8891191119281 CO312508119..v0 � C -E- n m"2®305 v0 } 33 - C -8- C $ c mewl.cat-mlA CD3 MA v0 A n w-120ae03V0 -X- 4_ 14,CD3-110,339'119 310 1 v0 40 Plan en.303131,3031010001 v0 } 15,333-115.333-115 40 $ 1 44 CD3 300308 w $ 33 109,336--to3 V5 e C -& C0 $ c 12139,1.313"1,CD3 129 v0$. CD3 901.CM 302A.CD9 9010 vo $ 303,10 328110.303110 V12 -6- 333116.CO3 118,CD3-118 40 94 CD3 125.CD3 125,033125V0 .4- CD3 198.CD3 IPS CO3 lea 30 $ CO3320,303320,333320 v0 • • Northing (4000 ft/in) N _ Iii ! 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 I i I I I m I I I I I Ili I I I I J I lel 1 1 1 I I I I 1 I 1 1 1 I_ _ 'k CJJ _ U Q _ 0 p — N — //' M / _ M - QQ b 7/ / - - Q - (O CO N- - 3 • r CO /411k rn f� H CO T C)M M 0 CO Hc%) 0 co c, U 0 rn - 0 , C.).... ,No.44\ CS _ U r CO \ LL M 7 __ rn co' . � U T — c_ -- ..- 6 M ` pp M 1♦�! M U ��. ___-�Vli —O Ti- U I ` r C _ Qo c�F - U r - W— c U —W N U r r ri _ v� M co P ,- ,- I11 N _ C.) C:-) tit r C.) ,"` 0 �N M 6 ,\At -E.T E - o T C7 .I - 0 Ili `'', - 0 T 1j� „ (j 7041), Q N o r :�� a• T U �r U — • U _7; 6 o U,_ r 13 0 cre 1 eco - or N - 3p C, O Uz N 1 I I I I I I I I I f 1 I 1 1 I I I I 1 1 I I I I I I I I I I I I 1 I I I 1 I I I I I I 1 I 1 1 f I I I I I I I f M (U1/31 0000 6uNtioN • Alption for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval Well collision Low Utilize gyro surveys and travelling cylinder plots Gas Hydrates Low Monitor well at base of permafrost,increase mud weight,decrease mud viscosity, increase circulating times,control drilling rates and low mud temperatures Abnormal pressure in Low Increase mud weight surface formations>_ 2000' TVD Lost circulation Low Reduce pump rates,thin mud rheology,pump LCM pills and use low density cement slurries 9-7/8"x 11" Hole / 7-5/8"Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills.Mud weight above 9.6 ppg.Flow Surface Formations checks during connections. Mud weight increase if >2000'TVD needed. Lost circulation Low Reduced pump rates and trip speeds.Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology.Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties and increased mud weight for trips.Ensure proper hole fill.Pump out of hole if needed.Monitor real time equivalent circulating density(ECD).Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight.No over Pressure pressured zones. Hydrogen Sulfide gas Low H25 drills,detection systems, alarms,and standard well control practices.Employ mud scavengers. 6-3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy _ Lost circulation Moderate Reduced pump rates and trip speeds.Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology.Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds,Pump out to 7-5/8"shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density(ECD).Use weighted sweeps. Abnormal Reservoir Medium BOPE drills.Keep mud weight above 9.0 ppg.Check CD3-130 APD Page 12 of 16 Printed: 11-Oct-13 • Action for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Pressure for flow during connections and if needed,increase mud weight.Perform well control drills.Increase mud weight if needed. Hydrogen Sulfide gas Low H2S drills.Detection systems and alarms. Use standard well control practices.Employ mud scavengers. Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the attachments. CD3-130 wp06 passes major risk analysis with offset wells. Intermediate Hole The greatest geological risk with the intermediate hole section is hole stability with regards to the Kalubik shale. Mitigating this risk begins during the planning phase of the well, when the well path is optimized to reduce unnecessary steering and dog legs in the lower,unstable shale sections. To gauge the effectiveness of the drilling program, the rig crews are to monitor and record drilling parameters such as torque and drag, ECD, drilling losses, returns at the shaker, etc. If necessary, adjustments to the drilling strategy will be discussed with the drilling engineer/drilling superintendent and implemented as needed. The use of a reamer to open the hole section through the shale to 11" from 9 7/8" will be utilized; effectively increasing the annular space for running the 7-5/8" intermediate casing. The rig crew must have heightened awareness when penetrating the Nechelik zone and be prepared for lost circulation mitigation measures. Production Hole Faulting within the Nechelik reservoir is considered to be low but presence of sub-seismic faults may exist and cause lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically.Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD3-130 APD Page 13 of 16 Printed. 11-Oct-13 Allition for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Reservoir Summary The CD3-130 wellbore is expected to have three hydrocarbon bearing formations open once drilled to TD, creating an additional risk in this hole section. These formations and their associated depths and pressures are listed below: Formation SS TVD Predicted Predicted Comments (ft) Fracture Pore Gradient Pressure (EMW-ppg) (EMW- pPg) Qannik 4065 12.50 8.9 The CD3-130 will penetrate the K-2(Qannik) reservoir approx...—4065' TVDSS in an area far from any current injection or production and so is expected to have original formation pressure and fracture gradient. The CD3 pad data sheet lists 1850- 1890 psi or 8.9 ppg EMW as Qannik pressure as measured from the CD2 pad at 4000' TVDSS. Nanuq 5940 12.5 8.9 The proposed CD3-130 will penetrate the Albian_96,Nanuq equivalent sand at approx... 5940 TVDSS. CD3 fiord field has no current injection or production in this zone and so it is expected to have original formation pressure(2740 psi)and fracture gradient and is non-reservoir quality. Kuparuk C 6700 12.50 9.2 Kuparuk presence is Sand expected,however, predicted to be cemented and non-reservoir quality. Virgin reservoir pressure of —3200 psi is predicted. Nechelik 6760 13.27 8.0 Estimated pressures Sand between 2700—3000 psi with an expected pressure drop in the middle of the lateral. Heel being the lower. All formations will be drilled overbalanced to mitigate well control risks. 1 CD3-130 APD Page 14 of 16 Printed: 11-Oct-13 • Colville River Field S CD3-130 WP06 Nechelik Injection Well Updated D.Morrow (11/5/2013) 20"Conductor to 80' Upper Completion MD TVD 1)Tubing Hanger 21.48' 21.48' 2)4-'/z'12.6#/ft IBT-Mod Tubing(2 jts), 130' 130' 0 4-1/2" 12.6# L-80 IBT-M 3) XO 4-W 12.6#IBT-M x 3-'/2'9.3#EUE-8rd-M L-80 tubing to 130' MD 4)Camco TRMAXX-5E nipple w/2.812"ID X Profile (47.2°) 2220' 2000' mm sssV with control line to surface. Cannon Cross-coupling clamps on every joint 5) 3-'h"X 1"Camco KBMG GLM w/Dv (67.2°) 5554' 3400' 10-314"45.5#L-80 BTC-M 6) 3-W X 1"Camco KBMG GLM w/Dv (70) 11231' 5600' A , Surface Casing 7)3-'/a"X 1"Camco KBMG GLM w/DCK2 (72.6°) 14600' 6637' @3229' MD/2500 TVD cemented to surface Pinned for 2500 psi casing to tbg shear 8)HES 2.813"X Profile (72.7°) 14650' 6654' O - J Planned TOC @ w/RHC plug body and Ball&Rod 500'above top of 9)BOT 80-40 GBH locator 14715' 6850' Qannik Qannik Interval Lower Completion L 7394' MD/4114'TVD/67.2° 10)Baker 5.5"X 7-5/8"HRD ZXP w/Hold Downs(73°) 14715' 6850' 0 0 0 HES 7-5/8"Stage Collar Baker 5.5"RS Nipple C 500'below bottom of Baker 5.5"x 7-5/8"Flex Lock Liner Hanger Qannik XO 5.5"Hydril 563 Box x 5"Hydril 521 Box Baker 80-40 Seal Bore Extension Hydril 521 box down Hydril 521 Pin X Pin pup joint 0 i 11)HES 2.812"XN profile w/2.75"ID(73°) 14750' 6682' 12)4-'/2',12.6#,C110 Hyd 521 Tubing 13)Swell packer,6.625"OD 4-%"12.6#C110 pipe 15400' 6819' 20'joint,10'elastomer,Hyd 521 B X P 14) 4-W, 12.6#,L-80 IBTM Tubing w/ Pre-Pert Pups Start 15420' 6820' spaced out every-350 ft. 15)4-W 12.6#,L-80 IBT-M Orange Peel 22,357' 6764' 3-1/2" 9.3#L-80 EUE-M 0 XO 3-1/2" 9.2#L-80 Hyd 563 Il �pG /Ivo v i M0 rIr✓ O b j a 7-16-1 A✓►►� P 6-3/4"Hole TD O 4 4,44- ' / @ 22,357' MD/ 6764'TVD '`Y. 11 12 13 X5.35 '"p 4°--eKuparuk C i% / G�$k�",y 14,999' MD/ 6749' 1 a 1s TVD/76.4° \ .. .. ..• .. . . •. • :: ..•. . .. .. .. .. .. Nechelik 15,321 MD/6,809'TVD 82.16° 4-1/2" 12.6#L-80 IBT-M Liner @ 7-5/8"29.7#L-80 BTC-M Casing @ 22,357' MD/6764'TVD 15,359'MD/6,814'TVD(83°) tion for Permit to Drill,Well CD3-130 Saved: 11-Oct-13 Attachment 4-Cement Summary 10-3/4"Casing Cement Job-13-1/2"hole Size Cement from 3229' MD to 2729' MD (500' of fill) with class G = adds @ 15.8 ppg, and from 2729' MD to surface with ASL @ 10.7 ppg. Assume 250% excess in permafrost and 50% excess below permafrost(1247' MD bottom permafrost). Tail: (500) x 0.3634 ft3/ft x 1.50 (50% excess) = 273 ft3 in open hole 80' x 0.5314 ft3/ft= 42.5 ft3 shoe track volume Total volume Tail = 273 +43 = 316 ft3 => 271 Sx @ 1.17 ft3/sk Lead: (2729'- 1,247') x 0.3634 ft3/ft x 1.50 (50% excess) = 808 ft3 in open hole 1247' x 0.3634 ft3/ft x 3.5 (250% excess) = 1587 ft3 in open hole Total volume Lead = 808 + 1587 = 2395 ft3 => 978 Sx @ 2.45 ft3/sk System: 271 Sx Class G @ 15.8 PPG & 978 Sx ASL 7-5/8"Casing Cement Job-9-7/8"&9-7/8"x 11"hole Size Cement from ports in an HES stage collar set 500' below the K2 interval to +1- 500' above the K2 interval with class G + additives @ 15.8 ppg. Assume 40% excess annular volume. K-2 Expected at 7,393.94' MD. Tail: (7,894' -6,894') x 0.2146 ft3/ft x 1.40 (40% excess) = 301 ft3 in open hole Total volume= 301 ft3 => 258 Sx @ 1.17 ft3/sk System: 258 Sx Class G @ 15.8 PPG Cement 7-5/8" casing from 15,359.38' MD to 14,000 'MD (minimum 300' MD above the packer & minimum of 500' above the top of the Kuparuk) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume. Hole section has been reamed opening it from 9-7/8"to 11". Tail: (15,360' - 14,000') x 0.3426 ft3/ft x 1.40 (40% excess) = 653 ft3 in open hole 80' shoe track x 0.2483 ft3/ft x 1.0 (0% excess) = 20 ft3 Total volume= 653 ft3 + 20 ft3 = 673 ft3=> 576 Sx @ 1.17 ft3/sk System: 576 Sx Class G @ 15.8 PPG CD3-130 APD Page 16 of 16 Printed: 11-Oct-13 • • Ferguson, Victoria L (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, November 05, 2013 11:24 AM To: Ferguson, Victoria L(DOA) Cc: Morrow, Dustin W Subject: RE:CD3-130 (PTD 213-160) Victoria, we will get you an updated schematic for the PTD application due to the typo of measured depth for the swell packer in open hole,this should be placed near the 7-5/8" shoe. The placement of the liner top packer(item 10) is due to ability to access due to inclination of the wellbore as mentioned on the phone. I had heard there was a waiver in place for use of 200 ft.TVD as opposed to 200 ft. MD at Alpine due to wellbore inclinations. We do plan to run the normal LWD Sonic tool for top of cement evaluation and will supply the AOGCC with those logs once we have them. With regards to the A.O.R., is this the closest well open to same pool in'A mile view? On page 20 of the directional plan there is a Quarter mile view of the CD3-130wp06 lateral to illustrates the distance to nearest well open to same pool which is CD3-119 @ closest distance of 1450' mid-way through the lateral, is this sufficient? With regards to confining formations,just above the Nechelik is the Upper Kingak shale at this location which is estimated at a TVD thickness of 58 ft.,this formation will isolate all above formations from injection into the Nechelik. 1 • • CD3-130wp06 -..-----__--- a ' V it CL+YS' la A• '7,:n 5 N'n Matti Mr SIM WM 55 xi Quarter Mile View 3a1144 SPIV'OCn ,= a I,�k(S :.� ..,� '47i 4 eon:vft IS.ii9fidX 24112•Am.,170014 r-j- CLOSEST WELL open to POOL 17500 � _ _. � ..-_ I • ; I -,---15000– 40 __ oc.,` db 1450.to CD3-119 +2500 yAt1 O ..4. ti Z G 1 10000 __� I, ' js ' cU) 11 '/ i \ /.5 ; / ;ty '34`Pte; 4k4 7500 ti N\ `r 5000– _�_. , iii ..,. - .\ ,,0 . . , _ , -2500 0 2500 5t ,0 75,,, 00 10000 12500 15000 17500 WestI.l/Fagt/.,1 125fffl Ht/int From: Ferguson, Victoria L (DOA) [mailto:victoria.fergusonCalalaska.gov] Sent: Tuesday, November 05, 2013 10:05 AM To: Brunswick, Scott A Subject: [EXTERNAL]CD3-130 (PTD 213-160) Scott, The packer depth above the productive interval is much greater(4000'MD) than the 200' allowed in the regulations(20 AAC 25.412(b). Do you plan a CBL to determine cement quality above the packer?Any information on the thickness and depth of the confining zone?What justification can you provide for this placement of the packer? For a new injection well, an Area of Review is required. Some guidelines are outlined below: Area of Review—Injection or Service Wells The construction and abandonment requirements for wells drilled in Alaska are not dependent on whether the well is a producer or injector. However, verification of the adequacy of the construction or abandonment of any 2 • • well is subject to greater scrutiny a • well is proposed as a service well. This verification process is known as the Area of Review (AOR) and it applies to all wells, whether active or abandoned, that are within % mile radius of a service well. The process also applies when annular disposal is proposed for a well. See: 20 AAC 25.080(b)(4), 25.252(c)(1) and (c)(12) and 25.402(b) and (b)(1). The verification process for the well to be drilled or converted is not very difficult. Generally sufficient information can be developed and gathered while drilling the new well or the existing information in the well file is sufficient to make the determination. For some conversions, a cement evaluation log may be needed to verify current wellbore conditions. In some cases, follow-up logs (temperature, water flow, etc.) may also be needed to confirm placement and confinement of the injected fluids. In order to perform an effective AOR, it is critical that all proximate wellbores and wellbore sections be identified including existing and abandoned wells, plugbacks and "lost" hole sections. For purposes of the assessment, the reference point used to establish an AOR for a proposed injection well is the point at which the wellbore penetrates the productive horizon or for annular disposal, the surface casing shoe. For horizontal service wells, the % mile radius continues along the well path through the reservoir to TD. Any wellbore or section identified within an AOR must not provide a pathway that could allow fluids to escape from the receiving zone. Where multiple producing formations are penetrated by a well, an AOR for each zone may need to be assessed. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(@alaska.gov 3 • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Thursday, November 07, 2013 9:14 AM To: 'Kane, Danny' Subject: RE:Additional State Regulations Regarding Managed Pressure Drilling Danny, There are no additional regulations for MPD; MPD is unregulated. The only MPD I am aware of is with coil tubing at Kuparuk and also, Pioneer utilizes MPD. Let me know if you have any other questions. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusona.alaska.gov From: Kane, Danny [ iailto:Danny.Kane@alconocophillips.com] Sent: Tuesday, November 05, 2013 3:16 PM To: Ferguson, Victoria L (DOA) Subject: Additional State Regulations Regarding Managed Pressure Drilling Victoria, I'm currently working on the preliminary engineering for CD3-316B,the second CD3 winter well to be drilled by ConocoPhillips at Alpine. This particular well will be an in-fill development well flanked by three injectors with a prognosed pore pressure curve ranging from"'10-11.5ppg EMW across the production lateral. We have identified Managed Pressure Drilling as a potential tool to assist us with drilling this well. I performed a Query search of the AOGCC regulations (on the website)to see if the state had any additional regulations regarding Managed Pressure Drilling and found none; do you know if any regulations exist? Regards, - Danny Danny Kane Drilling Engineer-WNS ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 • 0 Bettis, Patricia K (DOA) From: Brunswick, Scott A[Scott.A.Brunswick@conocophillips.com] Sent: Monday, October 28, 2013 7:18 AM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]FW: CD3-130: Permit to Drill Application Patricia The 401 form is correct: Top productive is Sec28,T13N, R5E, I'm not sure how I rnanaged to input the data incorrectly in the permit to drill docurnent. CD3-130wp06 intermediate Casing I u,Ai ,,00ldlii,.I t e 4_4.4.44 I.4„,444:1 I i *„.r,„ x ., D ol um t 1.,.:. T.T .,, , I Datum4,576--Ti s, 1 1 LatitudelLotoggis Descifriati Degrees r‘0si 1 LatritsrdelLorsoy.risie Dec Taal OegFees ,,,••l r UTM Zocts - ' Spurn — UTM ,. ts•' State Plane :_re I-4 ,S Unttst 1.us-ft '—', State Plane Zone T, , „ Units ---4 ' —4 • Legal Descrphon INAD27 oriy) , 6 tattillg Coordinate.' Legal CP Inc,ripton X:: 11535896 CO Tc/AttlltillP i-7i— :.N—.77 R;r.' gel '005 if :.;1 iiri :l 12N 533B Trasis:lcri-ST °tit Help 1 , .. . . . -"' — Thank you Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.goy] Sent: Friday, October 25, 2013 12:40 PM To: Brunswick, Scott A Subject: RE: [EXTERNAL]FW: CD3-130: Permit to Drill Application That's fine. Have a great weekend. 1 • 110 From: Brunswick, Scott A [mailto:Scott.A.BrunswickPconocophillips.com] Sent: Friday, October 25, 2013 12:36 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]FW: CD3-130: Permit to Drill Application Patricia, I apologize for the delay, I'm in Houston without access to the information. May I respond Monday when I am back in the office? Thank you Scott Sent with Good (www.good.com) Original Message From: Bettis, Patricia K (DOA) [patricia.bettisAalaska.gov] Sent: Thursday, October 24, 2013 05:21 PM Central Standard Time To: Brunswick, Scott A Subject: [EXTERNAL]FW: CD3-130: Permit to Drill Application Good afternoon Scott, Any advice? From: Bettis, Patricia K(DOA) Sent: Tuesday, October 22, 2013 3:30 PM To: 'Brunswick, Scott A' Subject: CD3-130: Permit to Drill Application Good afternoon Scott, On the Form 401, Box 4a,Top of Productive Interval is given as Section 28,Township 13 North, Range 5 East, U.M. On page 3 of the Application for Permit to Drill Document,Top of Nechelik Productive Horizon is shown as Section 13, Township 12 North, Range 5 East, U.M. Would you verify which legal description is correct for the Top of Productive Interval. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential 2 1110 • information mayviolate state or federal law. If and/or privileged information.The unauthorized review, use or disclosure ofsuch a you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, October 22, 2013 3:30 PM To: 'Brunswick, Scott A' Subject: CD3-130: Permit to Drill Application Good afternoon Scott, On the Form 401, Box 4a,Top of Productive Interval is given as Section 28,Township 13 North, Range 5 East, U.M. On page 3 of the Application for Permit to Drill Document,Top of Nechelik Productive Horizon is shown as Section 13, Township 12 North, Range 5 East, U.M. Would you verify which legal description is correct for the Top of Productive Interval. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • 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: C-A3 -/3o PTD: x,J 316 0 Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: CAI / 1_ iZsJr POOL: 6)/(./ , /P.C1/4/4„AT- /`roJ'c-) O.) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging in also required for this well: Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, if composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 iiiiim • 410 ❑ P 75 a a) 0- 06 N N > 0 a- 5ai a) a) o 0) Q a m O U H a L N N 1` • V co o W 3 o Q 0 O' W (n co) N O ca a c 2 O co '206 7 cn a) = E p co O ao 3 3, o co c — o a) a`, o a) E, co, la 03 N c 3 rn ami '5, C U 4 W M = ate)' 0 0 o - 2 3 of a U n a n i- m 3 a 0 o w 01 D v a) E n n ai � co .3 co coo m y co c aiA =a ' H' a @ acn U o 0 3 ° 0 n a as "v' O ° E J an .` X' > O'Lo C Q o io E ro "O, a '@' 5..0...5 co N, a p' oa cv o 0 p' c a): n E, •Fo, E o LL ,�- =p UA aa, °, °. O, ay • >. o J_ 0 0 O N �, Q o,. C,. cocc). a:. 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CO CO0 • U co M ! co a)I— O p SII .0 N O C 2 o C N O Ct O N 0) a a N O y W CO R O C o N'E fl. co N >4 0 0 J 2 E c O ` m U H V a s w a > a 5. a Q • • 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 infot nation. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Alpine Rig: Doyon 19 Date: March 3, 2014 Surface Data Logging End of Well Report CD3-130 CD3-130 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhilips Alaska, Inc. Rig: Doyon 19 Well: CD3-130 & CD3-130 PB1 Field: Alpine Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20677-00-00 (CD3-130) 50-103-20677-70-00 (CD3-130 PB1) Sperry Job Number: AK-AM-900966762 Job Start Date: 22 January 2014 Spud Date: 24 January 2014 Total Depth: 15483’ MD, 6806’ TVD (CD3-130) 3193‘ MD, 2474‘ TVD (CD3-130 PB1) North Reference: True Declination: 19.27° Dip Angle: 80.88° Total Field Strength: 57,572 nT Date Of Magnetic Data: 17 September 2013 Wellhead Coordinates N: North 70° 25’ 7.804” Wellhead Coordinates W: West 150° 55’ 1.908“ Drill Floor Elevation 48.8’ Ground Elevation: 12.5’ Permanent Datum: Mean Sea Level SDL Engineers: David Mckechnie, Andrew Bongard, Jeremy Tiegs, Tyler Dretke Company Representatives: Ken Harding, Josh Riley, Adam Dorr, Robert Wall, Don Mickey, Dan Lowe SSDS Unit Number: 109 DAILY SUMMARY 01/20/2014 – 01/22/2014 Rig Move. Halliburton mudlogging unit spotted and rigged up. Set up and calibrate gas equipment. 01/23/2014 Finish Diverter line. Mobilize rig. W ait on weather. Calibrate gas gear. 01/24/2014 Pick 5" heavy weight drill pipe and 5" drill pipe. Fill the conductor with low viscosity mud to check for leaks and hold pre-spud meeting during check. Pressure test mud lines to 3,500 psi. Begin drilling surface hole section. Drill down one stand of heavy weight drill pipe from 114' MD to 163' MD to accommodate remaining BHA components. Taking Gyro surveys and troubleshoot MWD. Gas: The maximum formation gas was 5 units at 157’ MD, and the average drilling background gas was 0 units. Fluids: No losses. 01/25/2014 Continue to make up BHA #2 as per directional driller. Unable to circulate. Pull out of the hole and lay down BHA looking for obstructions. Plugged jets were found on the bit. Flush all components of BHA to free any other obstructions. Make up BHA #3 and trip into the hole. Commence and continue drilling to 1052'MD. Gas: The maximum formation gas was 28 units at 1027’ MD and the average drilling background gas was 1 unit. Fluids: No losses. 01/26/2014 Drilled from 1052’ MD to 2448’ MD Gas: The maximum formation gas was 125 units at 2433’ MD and the average drilling background gas was 11 units. Fluids: No losses. 01/27/2014 Drill from 1052’ MD to TD at 3194’ MD. Circulate 3 bottoms-up. Stand back each stand every 30 minutes. Flow check the well for static conditions. Back ream out of the hole from 3030’ MD to 1709’ MD. Gas: The maximum formation gas was 170 units at 3194’ MD and the average drilling background gas was 6 units. Fluids: No losses. 01/28/2014 Back ream out of the hole to 700’ MD. Commence clean-out run and run into the hole to 830’ MD, afterwards tight spots were encountered. Continue to run into the hole to 3129’ MD. Wash down to 3193’ MD. Weigh up mud to 10.0 ppg. Flow check the well. Pull out of the hole to 2559’ MD. Pull out of the hole on pumps to 2349’ MD, afterwards another tight spot was encountered. Run into the hole to 2465’ MD. Back ream out of the hole to 2181’ MD. Pull out of the hole on elevators to 1898’ MD. Back ream out of the hole to 550’ MD, afterwards the hole unloaded. Continue to back ream out of the hole to 344’ MD. Gas: The maximum circulating gas was 116 units, and the average circulating gas was 13 units. The maximum trip gas observed was 116 units. Fluids: No losses. 01/29/2014 Back ream out of the hole to 300' MD. Stand back drill collars. Lay down BHA and then clean and clear the rig floor. Make a dummy run with the 10.75" casing. Work through a tight spot at 1180' MD. Wait on ball mill. Continue to work through the tight spot. Hold a pre-job safety meeting on laying down casing. Lay down 10.75" casing to 162' MD. Gas: The maximum circulating gas was 95 units, and the average circulating gas was 13 units. Fluids: No losses. 01/30/2014 Continue to lay down 10.75" casing. Rig down casing equipment and clean and clear the rig floor. Make-up BHA and prep the mud pits. Run into the hole to 750' MD and shallow test MWD. Run into the hole to 831' MD afterwards encountered a tight spot. Work through the tight spot to 1033' MD. Slide to 1055' MD. Attempt to control drill-pump pressure increase and lost MWD signal. Pull out of the hole with pumps to 750' MD. Pull out of the hole on trip tank to 650' until swabbing occurred. Pull out of the hole with pumps and lay down the BHA. Gas: The maximum circulating gas was 36 units, and the average circulating gas was 8 units. Fluids: No losses. 01/31/2014 Continue to lay down the BHA. Clean and clear the rig floor, and clean the pits. Make-up bent joint and mule shoe on cement assembly. Run into the hole on 4" drill pipe from shed to 1058' MD. Circulate and condition mud. Pump a mud push followed by cement. Pull out of the hole on trip tank to 473' MD. Pump spacer and then circulate 2 bottoms-up. Pull out of the hole 3 stands. Run into the hole with 3 stands and circulate a bottoms-up. Pull out of the hole 3 stands. Run into the hole with 3 stands and circulate a bottoms-up. Pull out of the hole. Clean and clear the rig floor, and then wait on cement. Gas: The maximum circulating gas was 21 units, and the average circulating gas was 2 units. Fluids: No losses. 02/01/2014 Wait on cement. Clean and clear rig floor, and complete rig work orders. Make-up 3.5" bent cement stringer and run into the hole to 314' MD. Wash down to 837' MD and tag cement. Circulate a bottoms-up and then rig up cement lines and head pin. Circulate and then pump a mud push followed by cement. Circulate another mud push and then rig down equipment. Pull out of the hole to 114' MD. Pump a space and then pull out of the hole. Wait on cement. Gas: The maximum circulating gas was 9 units, and the average circulating gas was 2 units. Fluids: No losses. 02/02/2014 Continued waiting on cement. Ran in the hole to 220' MD. Washed down to 697' MD. Circulated at 691' MD. Rigged up for cement job and pumped 201 bbls of cement. Rigged down cement equipment and laid down cement string. Flushed stands. Made up mule shoe, ran into 114' MD and waited on cement. Washed down and tagged cement at 484' MD. Holding pre-job safety meeting for pumping cement plug at report time. Gas: The maximum circulating gas was 8 units, and the average circulating gas was 2 units. Fluids: No losses. 02/03/2014 Rigged up cement equipment and pumped as per program. Pulled out of the hole to 112'. Observed green cement at the shakers while circulating. Flushed stands. Laid down 4" drill pipe. Tested gas equipment while the rig cleaned pits and tested the diverter valve. Made up BHA #5. Ran in the hole and tagged cement at 176' MD. Drilled out to 232' MD. Observed flocculation and gravel at the possum belly and shakers. Circulating/conditioning mud and flushing MWD tools of potential debris at report time. Gas: The maximum circulating gas was 3 units, and the average circulating gas was 2 units. Fluids: No losses. 02/04/2014 Circulate and condition cement contaminated mud. Work on #2 mud pump. Wash down to 231'. Drill ahead to 1200' MD. Noted max formation gas of 106 units at 1173' MD. Gas: The maximum formation gas was 106 units, and the average circulating gas was 23 units. Fluids: No losses. 02/05/2014 Continued drilling ahead to 1503. Backreamed 1 stand to work out a dogleg at 1369' MD. Reamed to bottom and resumed drilling ahead to 2731' MD Gas: The maximum circulating gas was 103 units, and the average circulating gas was 47 units. Fluids: No losses. 02/06/2014 Drill ahead from 2731’ MD to TD at 3366’ MD. Circulate 3 bottoms-up and back ream out of the hole. The hole unloaded at 2750’ MD. Continue to back ream out of the hole to 756’ MD. Flow check the well for static conditions. Pull out of hole on trip tank. Work through tight spot at 685’ MD. Continued to pull out of the hole and then lay down BHA. Gas: The maximum circulating gas was 81 units, and the average circulating gas was 43 units. Fluids: No losses. 02/07/2014 Lay down BHA and then clean and clear rig floor. Rig up TESCO tools and casing running equipment. Run into the hole with 10.75” casing to 1420’ MD and then circulate. Continue to run into the hole and work through tight spots. Change out bad casing joint and continue to run into the hole. Make-up hanger and land the casing. Circulate a bottoms-up and rig down Tesco. Make-up cement head and condition mud for cement job. Gas: The maximum circulating gas was 94 units, and the average circulating gas was 13 units. Fluids: No losses. 02/08/2014 Pump 2 spacers, mud push, and then cement. Bump the plug with spud mud and then wait for cement to return to the surface. Monitor the well. Rig down the cementing equipment and lay down landing joint. Clean and clear the rig floor. Nipple down surface stack and diverter. Rig up and perform cement top job. Nipple up BOPE and change out saver sub. Pick up drill pipe. Gas: The maximum circulating gas was 30 units, and the average circulating gas was 3 units. Fluids: No losses 02/09/2014 Continue to pick up and break in new drill pipe. Move 6 stands of heavyweight drill pipe in derrick. Continue to make-up and racking back stands in derrick. Rig up and test BOPE. Rig down testing equipment and service pipe skate. Pull up 5" drill pipe via mouse hole and rack back in derrick. Gas: The maximum circulating gas was 2 units, and the average circulating gas was 0 units. Fluids: No losses 02/10/2014 Pick up and rack back 5" drill pipe. Pick up BHA tools and make-up BHA. Plug in MWD and load nukes. Run into the hole to 95' MD. Take a mud weight measurement, Wash down to 110' MD. Continue to make-up BHA. Pick up drill pipe from pipe shed. Run into the hole to 3045' MD. Wash down to 3139' MD. Rig up testing equipment and test casing. Slip and cut drill line and then inspect top drive and service the rig. Gas: The maximum circulating gas was 1 unit, and the average circulating gas was 0 units. Fluids: No losses 02/11/2014 Calibrate block height on top drive. Drill out cement shoe track. Drill to 3386' MD and perform LOT. Drill ahead from 3386' MD while displacing to new water-based mud to 3423' MD. Drill ahead to 4509' MD. Gas: The maximum formation gas was 737 units, and the average gas was 92 units. Current drilling background gas is 79 units. Fluids: 90 barrel loss to the Ball Mill that was unaccounted for. 02/12/2014 Drill from 4460' MD to 6024' MD. Top drive gear oil light came on consequently the top drive was serviced. Drill ahead to 6091' MD. Troubleshoot top drive and service top drive. Drill from 6091' MD to 6301' MD. Gas: The maximum formation gas was 486 units, and the average gas was 112 units. Current drilling background gas is 119 units. Fluids: No losses 02/13/2014 Drilled ahead from 6301' MD, pumping 40 bbls 11.8 ppg sweeps every 3 stands. Trouble shoot intermittent WITS feed. Resolved. Noted max formation gas of 1747 units at 7500' MD. Drilling ahead to 8483' MD at report time. Gas: Maximum formation gas encountered was 1747 units. Average gas was 228 units. Fluids: No losses 02/14/14 Drilled ahead from 8483' MD. Performed dilution at 10757' MD. Noted max gas of 256 units while trouble shooting pumps at 9730' MD (12:40 PM). Gas: Maximum formation gas encountered was 256 units. Average gas was 138 units. Fluids: No losses 02/15/14 Drilled ahead from 10844' MD to 12304' MD. Backreamed 10 stands out of the hole. Tripped in the hole to approx. 12200' MD. Circulated bottoms up and performed dilution. Did not note any swab/trip gas. Broke circulation and worked on top drive. Tripped to bottom and resumed drilling ahead to 12465' MD at report time. Gas: Maximum formation gas encountered was 226 units. Average gas was 157 units. Fluids: There was 34 barrels lost down hole. 02/16/14 Drilled ahead from 12465' MD. Lost returns at 14096' MD (19:05). Regained full circulation within 5 minutes. 20 bbls lost down hole during event. Noted gas peak of 5150 units upon bottoms up of loss encounter. Collected Isotube gas sample during peak. Circulated and conditioned while reciprocating pipe. Collected additional gas sample at 5800 units. Continued circulating until gas dropped to 1300 units. Drilled ahead to 14378' MD and encountered max gas peak of 6104 units from lag depth of 14288' MD. Circulated out until gas fell to 850 units. Drilling ahead to 14382' MD with a background gas of 923 units at report time. Gas: Maximum formation gas encountered was 6104 units. Average gas was 538 units. Fluids: There was 17 barrels lost down hole. 02/17/14 Continued drilling ahead to 14754' MD. Circulated and conditioned while troubleshooting Top Drive. Continued Drilling ahead to 14,844' MD. Packed off. Circulated and conditioned using step rate method. Packed off. Stepped rates to 648 GPM. Continued drilling ahead to 15,131' MD. Pulled tight while attempting to backream for connection. Working pipe at report time. Gas: Maximum formation gas encountered was 6540 units of connection gas. Average gas was 888 units Fluids: There was 25 barrels lost down hole. 02/18/14 Attempted to establish circulation while fighting pack-offs. Stepped rates to 445 gpm. Circulated up a peak gas of 10,000 units (100% gas). Collected Isotube gas sample. Peak held for 25 minutes. Noted 7 1/2 bbl gain. Flow checked. Noted slight increase, but stabilized for 25 minutes. Circulated and conditioned while weighing mud up to 10.5. Washed down to 15032 Closed reamer and drilled ahead to 15,226' MD. Packed off while back reaming. Worked tight pipe while fighting pack offs. Lost power to the rig for 20 minutes. Stepped rates to 600 gpm and circulated gas peak of 8662 units from pack off event. Packed off while circulating out gas from prior pack off. Stepped rates to 443 gpm and washed/reamed 3 stands out of the hole. Circulating and conditioning at report time. Gas: Maximum gas was 10000 units as a result multiple pack off events. Average gas was 1094 units Fluids: There was 108 barrels lost down hole. 02/19/14 Washed down to 15150' MD. Packed off. Stepped rates to 628 GPM. Washed down to bottom at 15226' MD. Resumed drilling ahead to TD at 15483' MD 6806' TVD. Circulated bottoms up. Flow checked - Static. Spotted casing running pill to 14230' MD. Pulled 12 stands out of the hole. Pulled tight. Stepped up rates, packed off. Stepped rates to 653 GPM. Circulated 9767 units of gas as a result of multiple pack off events. Backreaming out of the hole to 14050' MD at report time with a background gas of 620 units. Gas: Maximum gas was 9767 units as a result multiple pack off events. Average gas was 465 units Fluids: There was 17 barrels lost down hole. 02/20/14 Backreamed out of the hole to 13526' MD. Reamer opened. Closed reamer and resumed pulling out of the hole on trip tank. Swabbing noted. Continued backreaming out of the hole. Packed off at 13337' MD. Staged up pumps and resumed backreaming to 12489; MD. Troubleshoot top drive. Backreamng out of the hole to 10885' MD at report time. Max gas of 1237 units noted at 13522' MD. Gas: Maximum gas was 1237 units. Average gas was 183 units. Fluids: There was 49 barrels lost down hole. 02/21/14 Backream out of the hole from 10885' MD to 9280' MD. Pull out of the hole on elevators to 7254' MD. Run in the hole to 7299' MD and then backream out of the hole. Circulate a bottoms-up and then pull out of the hole to 6112' MD. Run into the hole to 6166' MD and then backream out of the hole to 5789' MD. Pull out of the hole to 5204' MD and then circulate a bottoms-up. Backream out of the hole to 5129' MD. Pull out of the hole with pumps on to 3329' MD. Gas: Maximum gas encountered was 2787 units. Average gas was 86 units Fluids: No losses 02/22/14. Pumped 37 bbl sweep at 3329' MD. Monitor well - Static. Pull out of the hole to 790' MD. Monitored well - Static. Lay down BHA components as per SLB crew. Confirm that the under reamer is closed and locked. Continue to lay down the BHA while cleaning and clearing the rig floor of BHA tools. Flush the stack, pull WR, set the test plug, and change out the upper rams. Test the rams afterwards and then rig down the testing equipment. Fill the hole and monitor for static conditions. Rig up and test BOP's. Gas: Maximum gas was 114 units. Average gas was 10 units Fluids: There was 138 barrels lost down hole during the trip out of the hole 02/23/14 Continue to test BOP's. Change out the upper rams. Set the test joint, fill the stack, and then test rams. Drain the stack afterwards. Set the W/R and rig down the elevators and bails. Monitor the well on the trip tank. Dummy run the hanger. Rig up Tesco casing tools. Run in the hole with casing as per detail. Circulate bottoms up at 2202' MD. Noted 8 units of gas. Continue running in the hole to 3342' MD. Circulated, noting 10000 units of gas upon bottoms up. Collected Isotube gas sample. Company man registered 11% LEL reading with hand held detector from mud bucket on the rig floor. Mud pressure balance reportedly dropped from 10.5 to 9.1 ppg. Circulated gas out to a background of 160 units and continued running in the hole to 4225' MD with an average background gas of 400 units. Circulate bottoms up with gas peaking at 6944 units. Collected Isotube. Resumed running in the hole with an average background of 550 units while tripping and circulated at 5320' MD. Noted peak gas of 8668 units. Isotube gas sample collected. Circulated gas out and resumed running in the hole to 6329' MD with an average background of 800. Circulated bottoms up, noting 9084 units. Collected Isotube. Gas: Maximum gas encountered was 10000 units. Average gas was 965 units Fluids: No losses 02/24/14 Continue running in the hole from 6329' MD to 7353' MD with casing as per detail with an average background of 800 units while tripping. Circulate and condition mud, noting peak gas of 5683 upon bottoms up while performing dilution. Circulated gas out to background of 680 units and resumed running in the hole to 8369' MD with a background of 750 units. Circulated bottoms up with gas peaking at 750 units. Continue running in the hole to 9289' MD with background gas building from 800 units to 2318 units. Staged pumps up to 251 gpm, noting peak gas of 2430 units. Circulated gas out to 1000 units. Continue running in the hole to 12555' MD. Circulated up peak gas up 8220 units. Isotube sample collected. Circulated gas out to 1120 units. Continue running in the hole to 13525' MD and circulated/conditioned. Noted max gas of 10,000 units. Isotube collected. Cleaned out gas trap upon company man’s request. Continued to read 10000 units. Gas: Maximum gas encountered was 10000 units. Average gas was 1327 units Fluids: No losses 02/25/14 Continued circulating out 10,000 units peak at 13525' MD to a background of 850 units. Continued to run in the hole to 14212' MD and started taking weight at 14000' MD. Attempt to pull out of the hole was no good. Attempt to circulate was no good. Work string down to 14307' MD. Attempt to work string afterwards. Stage the scaffolding on the rig floor. Begin to rig down Tesco equipment. Gas: Maximum gas was 9407 units. Average gas was 288 units Fluids: No losses 02/26/14 Rig down Tesco and then rig up long bales. Erect scaffolding on the rig floor. Rig up cement head and circulating lines. Rig down scaffolding and then clean and clear rig floor. Wait on cementers and pressure test lines. Stage up pumps. Pump up pressure and monitor it. A slight flow was observed. Bleed off pressure and then stage up pumps again. Weigh up active system to 10.8 ppg. Pump chemical wash, spacer, and cement. Drop plug and displace with rig pumps. Bump plug and then rig down lines. Wait on cement. Gas: Maximum gas was 850 units. Average gas was 75 units Fluids: No losses 02/27/14 Continue to wait on cement to set. Clean wind walls. Change out swabs, liners, seats and valves on mud pumps. Bleed off pressure and open annulus. Observe the well. Remove flow line. Nipple down the BOPE stack. Set emergency slips. Cut hole in casing and then drain fluid. Lay down the cement head. Cut the casing and then lay down the joint. Remove the riser and set pack off. Nipple up the BOPE and then test pack off. Continue to nipple up the BOPE. Gas: There was no significant gas Fluids: No losses 02/28/14 Change out the saver sub. Rig up elevators and bales for 5" drill pipe. Lay down 5" drill pipe via the mouse hole. Add hydraulic oil to Top Drive. Continue to lay down 5" drill pipe. Rig up wireline equipment. Run in the hole with fishing magnet. Pull out of the hole with dropped equipment. Lay down 5" drill pipe. Change out rams and then rig up to test. Test upper and lower rams. Gas: There was no significant gas Fluids: No losses 03/1/14 Continue testing rams. Set wear ring. Make-up BHA #7. Re-rig counterbalance shackles on top drive. Cut and slip the drill line. Pick up 4" drill pipe from the pipe shed. Rack back 5 stands of drill pipe in the derrick. Continue to pick up 4" drill pipe. Rig up and test casing to 1000psi. Rig down testing equipment. Ream in to the hole to 6913' MD. Drill the plug and stage collar. Wash and ream to 7221' MD. Circulate 1.5 bottoms-up. Run in to the hole from the pipe shed.. The bottom of the hole took weight. Wash and ream to 7502' MD. Gas: Maximum gas was 28 units. Average gas was 15 units Fluids: No losses 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 0 5 10 15 20 25 30 35 40 45 50 55 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: CD3-130 & CD3-130 PB1 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 19 SPERRY JOB: AK-XX-0900966762 Days vs. Depth 22 January 2014 Sperry SDL Remain on Location from Previous Well LOCATION: Apline AREA: North Slope Borough STATE: Alaska SPUD: 24-Jan-2014 TD: 19-Feb-2014 Commenced 13.5" Surface Hole Section PB1 On Bot: 18:40 24 Jan 2014 TD Surface Hole Section 3193' MD, 2474' TVD Off Bot: 17:04 27 Jan 2014 Casing Failure Cement Plug Back Jan 29-Feb 2 TD Surface Hole Section 3366' MD, 2485' TVD Off Bot: 12:25 06 Feb 2014 Landed 10.75" Casing 3354' MD, 2480' TVD 07 Jan 2014 Commenced 13.5" Surface Hole Section On Bot: 22:24 03 Feb 2014 BROOH to Surface Test BOPs 22 Feb 2014 TD 9.875" Intermediate Hole Section 15483' MD, 6806' TVD Off Bot: 11:12 19 Feb 2014 Landed 7.625" Casing 14307' MD, 6548' TVD 26 Feb 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 19 HOLE SECTION:Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0900966762 Alaska CD3-130 PB1 Alpine ConocoPhillips Alaska, Inc.North Slope Borough Andrew Bongard 29-Jan-2013 What went as, or better than, planned: Rigging up the unit went as well as expected, and no issues were encountered. Difficulties experienced: The FID on the 8800 (SAP 10784028) and 8900 (SAP 10891998) both failed to auto-ignite. Recommendations: Always be sure that the backup gas gear is plugged in, and therefore, warmed up and ready to be installed if needed. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 19 HOLE SECTION:Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Jeremy Tiegs 25-Mar-2014 What went as, or better than, planned: Depth tracked well using the manual in/out of slips function on the IRIS. This led to no loss in data while drilling since there was relatively minimal weight on the drillstring. Difficulties experienced: Tracking fluids and losses being transferred to the Ball Mill. Strapping the pits at the Ball Mill is not able to be done considering the large volumes of cuttings and mud they receive during surface section. Recommendations: Coordinate with the personnel on site and try to gather information to maybe come up with a system to track fluids. Also talk to Conoco of changing out their pit sensors considering there is a ±10 bbls swing in the current pit sensor measurements. Innovations and/or cost savings: Tracking all fluids correctly at this site can lead to cost savings by accurately tracking hole volume continuously. This will help with knowing proper cement volumes to use at casing points, average hole diameter for drilling optimization, borehole stability, and proper annulus correction when adjusting gas lag times. AK-XX-0900966762 Alaska CD3-130 Alpine ConocoPhillips Alaska, Inc.North Slope Borough Surface Data Logging After Action Review CD3-130 & CD3-130 PB1 ConocoPhillips Alaska, Inc. MI Swaco Doyon 19 AK-XX-0900966762 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 23-Jan 0 8.80 97 15 31 28/44/48 N/C 61/46/40/32/20/19 2/-4.5 -/96 -0.02 9.7 25.0 0.01/0.05 350 20 Wait on Weather 24-Jan 162 8.90 344 14 83 72/78/79 N/C 111/97/91/83/71/70 2/4.5 -/96 -0.02 9.7 25.0 0.01/0.05 350 20 M/U BHA#2 25-Jan 908 8.80 364 24 48 52/59/64 9.7 96/72/68/62/44/43 2/8.0 -/92 0.25 0.02 9.0 25.0 0.01/0.03 550 80 L/D BHA#2; M/U BHA#3; Drill 26-Jan 2364 9.80 356 26 72 51/56/60 7.7 124/98/86/71/48/46 2/-11.5 1/88 0.40 0.02 8.9 30.0 0.01/0.03 450 40 Drilling surface section 27-Jan 3193 9.90 367 33 91 48/76/79 7.2 157/124/109/88/49/48 2/-12.0 1/87 0.30 0.02 8.9 27.5 0.01/0.02 450 40 TD Surface Section 28-Jan 3193 10.00 371 41 81 36/74/93 5.8 163/122/108/84/37/35 2/1 13.0 1/87 0.25 0.02 7.8 27.5 0.01/0.02 450 40 BROOH/Wiper Trip 29-Jan 3193 10.00 388 46 92 53/67/77 6.4 184/138/124/102/52/50 2/-13.0 1/87 0.30 0.02 7.8 30.0 0.01/0.02 450 40 Failed casing/BROOH 30-Jan 3193 10.00 400 51 134 57/63/71 6.2 236/185/160/128/59/56 2/-12.0 1/88 0.50 0.02 8.1 40.0 0.01/0.02 450 40 Failed clean-out/BROOH 31-Jan 3193 10.00 200 25 45 16/26/53 6.3 95/70/59/43/16/15 2/-10.0 1/90 0.40 0.02 8.8 30.0 0.01/0.02 450 40 Cementing surface 1-Feb 3193 10.00 200 24 38 20/45/63 6.4 86/62/53/40/18/17 2/-10.0 1/90 0.40 0.02 9.1 30.0 0.01/0.02 450 40 Cementing 2-Feb 3193 10.00 200 26 35 16/38/65 6.4 87/61/48/34/15/14 2/-10.0 1/90 0.40 0.02 8.3 35.0 0.01/0.02 450 40 Circulating 3-Feb 3193 8.70 47 8 11 5/17/24 n/c 27/19/15/11/5/4 1/-3.0 -/97 -0.10 10.3 20.0 0.08/0.2 500 60 Circulate and Condition, Drilled ahead 4-Feb 433 9.10 300 42 68 69/73/91 8.0 152/110/92/73/45/43 2/-6.0 -/94 0.30 0.05 9.1 32.5 0.03/0.08 500 60 Driling Surface 5-Feb 2000 9.60 300 31 66 33/54/65 7.2 128/97/85/66/31/30 2/-10.0 1/90 0.50 0.02 9.1 32.5 0.01/0.03 400 40 Drilled ahead in surface section 6-Feb 3366 10.00 300 60 84 33/62/83 5.6 204/144/119/89/34/32 2/-9.0 1/90 0.75 0.02 8.5 35.0 0.01/0.04 600 40 TD, BROOH 7-Feb 3366 10.00 300 65 106 36/53/68 5.4 236/171/142/101/37/35 2/-9.0 1/90 0.75 0.02 8.6 31.3 0.01/0.04 600 40 RIH Casing, Cement 8-Feb 3366 9.80 60 23 14 4/6/7 7.3 60/37/28/17/4/3 2/-7.5 -/93 tr 0.02 8.2 22.5 0.01/0.04 500 40 Top Job, P/U and break in drill pipe 9-Feb 3366 9.80 60 24 14 4/6/7 7.4 62/38/27/18/4/3 2/-7.5 -/93 tr 0.02 8.0 22.5 0.01/0.04 450 40 P/U pipe 10-Feb 3366 9.80 64 24 16 4/6/6 7.4 64/40/30/19/4/3 2/-7.5 -/93 tr 0.02 8.0 22.5 0.01/0.04 500 40 M/U BHA#6, LOT, Drill Ahead 11-Feb 4234 9.90 43 9 27 15/17/18 5.9 45/36/33/26/14/13 1/8.0 2/90 0.03 9.9 7.0 0.02/0.04 450 40 Drilling Intermediate 12-Feb 6095 9.80 41 9 27 12/16/20 5.9 45/36/31/25/12/11 1/8.0 3/90 tr 0.10 9.7 20.0 .08/.3 450 40 Drilling Intermediate 13-Feb 8243 9.80 43 11 23 11/19/25 5.2 45/34/29/24/11/10 1/-8.5 3/89 tr 0.10 10.1 13.8 .05/.3 450 40 Drilling Intermediate 14-Feb 10665 9.80 43 9 24 11/16/21 4.8 43/33/29/24/11/10 1/-9.9 2/88 tr 0.09 9.2 23.8 .05/.18 800 80 Drilling Intermediate 15-Feb 12301 9.90 41 7 22 11/13/14 4.9 36/29/26/21/10/9 1/-8.8 3/88 tr 0.08 9.4 11.3 .04/.15 400 80 Drilling Intermediate 16-Feb 14200 9.90 42 10 22 11/13/15 4.2 42/32/28/22/11/10 1/2 10.0 3/87 tr 0.07 9.4 11.2 .05/.35 500 60 Drilling Intermediate 17-Feb 15021 10.00 42 12 26 12/17/22 3.1 50/38/32/27/12/11 1/2 10.0 3/87 tr 0.10 9.4 20.0 .05/.3 450 60 Drilling Intermediate 18-Feb 15131 10.50 44 14 28 13/19/24 3.0 56/42/36/28/13/12 1/2 16.0 4/80 tr 0.10 9.5 25.0 .06/.3 500 60 Drilling Intermediate 19-Feb 15516 10.50 43 13 24 11/15/19 2.8 50/37/31/24/11/10 1/2 15.0 3/82 tr 0.80 9.6 22.5 .08/.29 450 60 TD, BROOH 20-Feb 15516 10.60 47 15 25 11/18/23 2.7 55/40/36/26/12/11 1/2 16.0 3/81 tr 0.20 9.5 22.5 .06/.3 450 60 BROOH 21-Feb 15516 10.60 56 17 28 15/24/30 3.3 62/45/39/30/14/13 1/2 16.5 3/81 tr 0.20 9.4 26.0 .06/.25 450 60 POOH 22-Feb 15516 10.60 53 16 29 15/24/30 3.2 61/45/39/30/14/13 1/2 16.5 3/81 tr 0.20 9.2 26.0 .05/.25 450 60 Testing BOP's 23-Feb 15516 10.50 56 14 21 12/14/20 2.5 49/35/31/24/11/10 1/2 15.5 4/81 tr 0.03 8.9 27.5 .02/.2 500 60 RIH Casing 24-Feb 15487 10.60 52 14 22 11/15/20 2.6 50/36/31/25/11/10 1/2 15.0 3/82 tr 0.06 9.3 27.5 .03/.2 500 60 RIH Casing 25-Feb 15487 10.60 53 15 26 14/17/21 2.4 56/41/35/28/13/12 1/-15.5 3/82 tr 0.06 9.7 27.5 .05/.23 550 60 RIH Casing, R/D Tesco 26-Feb 15487 10.60 55 13 26 11/15/19 2.6 52/39/33/27/11/10 1/-15.5 3/82 tr 0.05 9.2 27.5 .04/.25 500 60 R/U Cement, Wait on Cement 27-Feb 15487 10.60 60 12 26 11/15/20 2.4 50/38/32/25/11/10 1/-15.0 2/83 tr 0.07 9.5 27.5 .05/.27 550 60 N/U BOPE 28-Feb 15487 10.60 63 13 25 12/15/20 2.3 51/38/33/25/12/11 1/-15.0 2/83 tr 0.10 9.5 27.5 .06/.23 500 60 Testing BOP's 1-Mar 15487 10.60 56 14 22 11/18/28 2.3 50/36/31/25/11/10 1/-14.0 2/84 tr 0.11 10.1 27.5 .08/.22 500 60 Reaming in the hole Casing Record 24-Jan-2014 SPERRY JOB:TD:19-Feb-2014 7.625" Casing @ 14307' MD, 6548'TVD Remarks 16" Conductor @ 114' MD, 114'TVD 10.75" Casing @ 3354' MD, 2480'TVD WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD: W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Baker MXL-1X 13.50 115 163 48 0.70 0.739 -----0-0-NO-A-E-In-NO-TD Surface Section Cleanout BHA 2 200 1RR1 Baker MXL-1X 13.50 163 163 0 0.00 0.739 -----0-0-PN-A-E-In-NO-PP POOH due to bit plugged w/ gravel (changeout mud motor) 3 300 1RR2 Baker MXL-1X 13.50 163 3193 3030 31.40 0.739 96.5 51.5 72 2923 754 2-4-FC-A-1-1/6-PN-TD Surface Section BHA 4 400 2 Baker MXL-1X 13.50 3193 3193 0 0.00 0.739 0.1 25 60 2650 750 0-1-BU-A-E-In-CT-HP Cleanout surface hole after failing to get casing to bottom 5 500 2RR1 Baker MXL-1X 13.50 196 3366 3170 43.34 0.739 72.3 35 61 1820 775 3-4-FC-A-3-1/8-WT-TD Surface Section BHA 6 600 3 Smith PDC MSi516 9.88 3366 15483 12117 78.20 0.982 154.9 25 140 3345 725 1-1-CT-C-X-I-NO-TD Intermediate Section BHA WELL NAME:CD3-130 & CD3-130 PB1 LOCATION:Alpine OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0900966762 TD:19-Feb-2014 MI Swaco STATE:Alaska RIG:Doyon 19 SPUD:24-Jan-2014 B i t R e c o r d . . * 24 hr Recap:Rig Move -- RPM -- Cht Siltst Comments 20-Jan-2014 23:59 Current Pump & Flow Data: N/A Max N/A ECD (ppg) 95% D. Mickey / D. Lowe 4.19 @ Rig: Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Min N/A N/A Morning Report Report # 01 Customer: Well: Area: Location: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools -N/A ROP MWD Summary 24 hr Max Hours -- Alpine Rig Activity: Avg to- - Condition Silt - 100% Gas In Air=10,000 Units N/AN/ATrip (max)(current) ConnectionBackground(max) Type Weight Average C-4n TuffCoal Chromatograph (ppm) Gas Summary Rig Move Clyst Sh Grade C-5i CementLst Yesterday's Depth: Current Depth: 24 Hour Progress: 900966762 N/A N/A C-5nC-1 C-3 C-4i - Cor Solids % Chlorides mg/l Gvl 0' 0' 0' Max @ ft Current N/AN/A Date: N/A N/AMinimum N/A Mud Data Depth API FL ml/30minMud Type in pH - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity -- TFABit #Bit Type Size Casing Summary Lithology (%) C-2 Ss (current) DepthUnits* YP (lb/100ft2)(ppb Eq) PV cP MBT Cly Tyler Dretke/Andy Bongard 907-670-4047Unit Phone:Tyler Dretke Maximum Report By:Logging Engineers: Size Set At . . * 24 hr Recap: Report By:Logging Engineers: Size Set At 907-670-4047Unit Phone:Tyler Dretke Maximum Tyler Dretke/Andy Bongard PV cP MBT Cly Casing Summary Lithology (%) C-2 Ss (current) DepthUnits* TFABit #Bit Type Size Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity -- YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A N/A Date: N/A Gvl 0' 0' 0' - Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i 24 Hour Progress: 900966762 N/A N/A - Clyst Sh Grade C-5i CementLst Chromatograph (ppm) Gas Summary C-4n TuffCoal Type Weight Average (max) Trip (max)(current) ConnectionBackgroundN/A N/A 10,000 Units Silt - 100% Gas In Air= Alpine Rig Activity: Avg to- - Rig Move Max @ ft N/A ROP MWD Summary 24 hr Max Hours -- Condition Current - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools - ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Min N/A N/A Morning Report Report # 02 Customer: Well: Area: Location: 4.19 @ Rig: Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke N/A 21-Jan-2014 23:59 Current Pump & Flow Data: N/A Max N/A ECD (ppg) 95% D. Mickey / D. Lowe Cht Siltst Comments -- RPM -- Rig Move . . * 24 hr Recap: Report By:Logging Engineers: Size Set At 907-670-4047Unit Phone:Tyler Dretke Maximum Tyler Dretke/Andy Bongard PV cP MBT Cly Casing Summary Lithology (%) C-2 Ss (current) DepthUnits* TFABit #Bit Type Size Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity -- YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A N/A Date: N/A Gvl 0' 0' 0' - Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i 24 Hour Progress: 900966762 N/A N/A - Clyst Sh Grade C-5i CementLst Chromatograph (ppm) Gas Summary C-4n TuffCoal Type Weight Average (max) Trip (max)(current) ConnectionBackgroundN/A N/A 10,000 Units Silt - 100% Gas In Air= Alpine Rig Activity: Avg to- - Rig Move Max @ ft N/A ROP MWD Summary 24 hr Max Hours -- Condition Current - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools - ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Min N/A N/A Morning Report Report # 03 Customer: Well: Area: Location: 4.19 @ Rig: Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke N/A 22-Jan-2014 23:59 Current Pump & Flow Data: N/A Max N/A ECD (ppg) 95% D. Mickey / D. Lowe Cht Siltst Comments -- RPM -- Rig Move. Halliburton shack is now on location and rigged up. . . * 24 hr Recap: Casing Summary Lithology (%) Size Set At 907-670-4047Unit Phone:Andrew Bongard Maximum Report By:Logging Engineers:Tyler Dretke/Andrew Bongard PV cP MBT Cly C-2 Ss (current) DepthUnits* TFABit #Bit Type Size Silt Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 158.80 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A Clyst Gvl 0' 0' 0' 31 24 Hour Progress: Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i 900966762 N/A N/A 0' Type Sh Grade C-5i CementLst Chromatograph (ppm) Gas Summary C-4n TuffCoal Weight Average (max) Trip (max)(current) ConnectionBackgroundN/A N/A 10,000 Units Hours Spud 25.097- 100% Gas In Air= 23-Jan-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Wait on Weather Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools - Min N/A N/A ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 04 Customer: Well: Area: Location: 4.19 @ Rig:23:59 Current Pump & Flow Data: N/A Max N/A ECD (ppg) 95% D. Mickey / A. Dorr Flow In (gpm) Cht Siltst Comments 350.00 4.50 RPM 9.70- Condition Finish Diverter line. Mobilize rig. Wait on weather. Calibrate gas gear. . . * 24 hr Recap: HWDP from 114' MD to 163' MD to accommodate remaining BHA components. Taking Gyro surveys and troubleshooting MWD. Pick-up 5" HWDP and 5" DP. Fill the conductor with low viscosity mud to check for leaks and hold pre-spud 350.00 4.50 RPM 9.70- Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: N/A Max N/A ECD (ppg) 95% D. Mickey / A. Dorr Flow In (gpm) Morning Report Report # 05 Customer: Well: Area: Location: 4.19 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools - Min N/A N/A - ROP (ft/hr)N/A SPP (psi) M/U BHA #2 Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 24-Jan-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) Spud 25.0344- Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 0 000 (max)(current) Connection 110 0Background N/A (max) Trip Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 162' Type C-5nC-1 C-3 C-4i 114' Cor Solids % Chlorides mg/l Gvl 0' 163' 163' 83 24 Hour Progress: meeting during check. Pressure tested mud lines to 3,500 psi. Began drilling surface hole section. Drilled down one stand of 1 0 (ppb Eq) 114'Minimum 157'5 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 148.90 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 0 Jeremy Tiegs/Andrew Bongard 0 0 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 492 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: continued drilling to 1052'MD. Continued to M/U BHA #2 as per DD. Unable to circulate. POOH and L/D BHA looking for obstructions. Plugged 550.0 8.0 RPM 9.009.7 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 1293 Max N/A ECD (ppg) 96% D. Mickey / A. Dorr Flow In (gpm) Morning Report Report # 06 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 87.7 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min 592 140 ROP (ft/hr)325' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 25-Jan-2014AlpineRig Activity: Avg to 136.9 Date: 379.6 Flow In (spm) Spud 25.0364 Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 0 000 (current) Connection 633 1Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 1052' Type C-5nC-1 C-3 C-4i 114' Cor Solids % Chlorides mg/l Gvl 163' 1052' 889' 48 24 Hour Progress: jets were found on the bit. Flushed all components of BHA to free any other obstructions. M/U BHA #3 and TIH. Commenced and 9 0 (ppb Eq) 164'Minimum 1027'28 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 248.80 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 0 Jeremy Tiegs/Andrew Bongard 0 0 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 969 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap:Continued to drill ahead through the surface section from 1052' MD to 2448' MD. 450.0 11.5 RPM 8.907.7 2334' Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 2473 Max N/A ECD (ppg) 96% D. Mickey / A. Dorr Flow In (gpm) Morning Report Report # 07 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 81.6 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min 749 177 ROP (ft/hr)1933' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 26-Jan-2014AlpineRig Activity: Avg to 178.5 Date: 942.9 Flow In (spm) Spud 30.0356 Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 0 000 (current) Connection 5897 11Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 2364' Type C-5nC-1 C-3 C-4i 114' Cor Solids % Chlorides mg/l Gvl 1052' 2448' 1396' 72 24 Hour Progress: 59 0 (ppb Eq) 1029'Minimum 2433'125 2 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 21.60 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 269.80 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 10 Jeremy Tiegs/Andrew Bongard 113 0 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 15336 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap:Continued to drill ahead through the surface section from 2448' MD to TD at 3194' MD. Circulated 3 BU. Stood back 450.0 12.0 RPM 8.907.2 3080' Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 1887 Max N/A ECD (ppg) 96% D. Mickey / A. Dorr Flow In (gpm) Morning Report Report # 08 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min 694 164 ROP (ft/hr)3055' SPP (psi) BROOH Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 27-Jan-2014AlpineRig Activity: Avg to 89.0 Date: 215.6 Flow In (spm) Spud 27.5367 Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 2 000 (current) Connection 3127 6Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 41 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 3193' Type C-5nC-1 C-3 C-4i 114' Cor Solids % Chlorides mg/l Gvl 2448' 3194' 746' 91 24 Hour Progress: each stand every 30 min. Flow checked for static conditions. BROOH from 3030' MD to 1709' MD. 25 0 (ppb Eq) 3105'Minimum 3194'70 1 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 32.00 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 339.90 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 198 Jeremy Tiegs/Andrew Bongard 403 24 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 7633 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 15968 Report By:Logging Engineers: 0 Jeremy Tiegs/Andrew Bongard 0 5 PV cP MBT Cly 63 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 1 Silt 13.5 32.00 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 4110.00 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum 3141'116 0 Clyst tight spot. Continued to run into the hole to 3129' MD. Washed down to 3193' MD. Weighted up the mud to 10.0ppg. Worked the 13 unloaded. Continued to back ream out of hole to 344' MD at the time of report. 0 Gvl 3194' 3194' 0' 81 24 Hour Progress: 114' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3193' Type Sh Grade C-5i CementLst 0 0 0 0 8 0 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 1920 2Background 116 0 0 N/A 0 00 10,000 Units reamed out of the hole to 2181' MD. Pulled out of hole on elevators to 1898' MD. Back reamed out of hole to 550' MD. The hole then 0.739 Hours Spud 27.5371 Mill Tooth 100% Gas In Air= 28-Jan-2014AlpineRig Activity: Avg to Date: Flow In (spm) SPP (psi) BROOH Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min 491 116 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 09 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 1066 Max N/A ECD (ppg) 96% D. Mickey / A. Dorr Flow In (gpm) Cht Siltst Comments 450.0 13.0 RPM 7.805.8 3080' Condition of hole to 2559' MD. Pulled out of hole with pumps to 2349' MD. Encountered a tight spot. Ran into the hole to 2465' MD. Back drillstring while the ball mill repaired sand line chute. Continued to weigh up the mud to 10.0ppg. Flow checked the well. Pulled out Back reamed out of hole to 700' MD. Commenced clean-out run and ran into the hole to 830' MD. Washed through a . . * 24 hr Recap: spot. Hold a pre-job safety meeting on laying down casing. Lay down 10.75" casing to 162' MD. Back ream out of the hole to 300' MD. Stand back drill collars. Lay down BHA and then clean and clear the rig floor. 450.0 13.0 RPM 7.806.4 3080' Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 33 Max N/A ECD (ppg) 96% D. Mickey / A. Dorr Flow In (gpm) Morning Report Report # 10 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min 131 31 ROP (ft/hr) SPP (psi) L/D 10.75" Casing Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 29-Jan-2014AlpineRig Activity: Avg to Date: Flow In (spm) Spud 30.0388 Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 0 000 (current) Connection 1954 0Background 116 (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 8 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 3193' Type C-5nC-1 C-3 C-4i 114' Cor Solids % Chlorides mg/l Gvl 3194' 3194' 0' 92 24 Hour Progress: Dummy run with the 10.75" casing. Work through a tight spot at 1180' MD. Wait on ball mill. Continue to work through the tight 13 0 (ppb Eq) N/AMinimum N/A95 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 32.00 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 4610.00 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 63 Jeremy Tiegs/Andrew Bongard 0 5 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 11422 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 611 Jeremy Tiegs Maximum 4773 Report By:Logging Engineers: 0 Jeremy Tiegs/Andrew Bongard 0 31 PV cP MBT Cly 3223 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 1 Silt 13.5 32.00 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 5110.00 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A36 0 Clyst prep the mud pits. Run into the hole to 750' MD. Shallow test MWD. Run into the hole to 831' MD afterwards encountered a 8 0 Gvl 3194' 3194' 0' 134 24 Hour Progress: 114' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3193' Type Sh Grade C-5i CementLst 0 1681 688 0 1718 1836 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 995 0Background 36 15 6 N/A 16 516 10,000 Units hole with pumps and lay down the BHA. 0.739 Hours Spud 40.0400 Mill Tooth 100% Gas In Air= 30-Jan-2014AlpineRig Activity: Avg to Date: Flow In (spm) SPP (psi) L/D BHA Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 11 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Cht Siltst Comments 450.0 12.0 RPM 8.106.2 3080' Condition signal. Pull out of the hole with pumps to 750' MD. Pull out of the hole on trip tank to 650' until swabbing occurred. Pull out of the tight spot. Work through the tight spot to 1033' MD. Slide to 1055' MD. Attempt to control drill-pump pressure increase. Lost MWD Continue to lay down 10.75" casing. Rig down casing equipment. Clean and clear the rig floor. Make-up BHA and . . * 24 hr Recap: stands. Run into the hole with 3 stands and circulate a bottoms-up. Pull out of the hole 3 stands. Run into the hole with 3 stands followed by cement. Pull out of the hole on trip tank to 473' MD. Pump spacer and then circulate 2 bottoms-up. Pull out of the hole 3 Continue to lay down the BHA. Clean and clear the rig floor, and clean the pits. Make-up bent joint and mule shoe 450.0 10.0 RPM 8.806.3 3080'2-4-FC-A-1-1/6-PN-TD Condition Cht Mill Tooth Siltst Comments 23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Morning Report Report # 12 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min ROP (ft/hr) SPP (psi) Waiting on Cement Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 31-Jan-2014AlpineRig Activity: Avg to Date: Flow In (spm) Spud 30.0200 Mill Tooth 100% Gas In Air= 0.739 3193' Hours 10,000 Units and circulate a bottoms-up. Pull out of the hole. Clean and clear the rig floor, and then wait on cement. 0 N/A 0 000 (current) Connection 293 0Background 21 (max) Trip (max) Weight 13.5 Average Gas Summary 0 C-4n TuffCoal 0 0 0.739 0.00 3193' Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 3193' Type C-5nC-1 C-3 C-4i 114' 2 Cor Solids % Chlorides mg/l Gvl 72.096.5 3194' 3194' 0' 45 24 Hour Progress: on cement assembly. Run into the hole on 4" drill pipe from shed to 1058' MD. Circulate and condition mud. Pump a mud push 2 0 (ppb Eq) N/AMinimum N/A21 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 32.10 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 2510.00 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 0'3193' 7 Jeremy Tiegs/Andrew Bongard 0 0 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 1941 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 969 Report By:Logging Engineers: 0 Jeremy Tiegs/Andrew Bongard 0 0 PV cP MBT Cly 0'3193' 7 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 1 Silt 13.5 32.10 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 2410.00 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A9 0 Clyst into the hole to 314' MD. Wash down to 837' MD and tag cement. Circulate a bottoms-up and then rig up cement lines and head 2 0 Gvl 72.096.5 3194' 3194' 0' 38 24 Hour Progress: 114' 2 Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3193' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 0.739 0.00 3193' Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight 13.5 Average (max) Trip (max)(current) Connection 237 0Background 0 0 0 N/A 0 00 10,000 Units 0.739 3193' Hours Spud 30.0200 Mill Tooth 100% Gas In Air= 1-Feb-2014AlpineRig Activity: Avg to Date: Flow In (spm) SPP (psi) Waiting on Cement Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools Directional, Gamma, Resistivity Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 13 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Cht Mill Tooth Siltst Comments 450.0 10.0 RPM 9.106.4 3080'2-4-FC-A-1-1/6-PN-TD Condition of the hole to 114' MD. Pump a space and then pull out of the hole. Wait on cement. pin. Circulate and then pump a mud push followed by cement. Circulate another mud push and then rig down equipment. Pull out Wait on cement. Clean and clear rig floor, and complete rig work orders. Make-up 3.5" bent cement stringer and run . . * 24 hr Recap: Holding pre-job safety meeting for pumping cement plug at report time. Flushed stands. Made up mule shoe, ran into 114' MD and waited on cement. Washed down and tagged cement at 484' MD. Continued waiting on cement. Ran in the hole to 220' MD. Washed down to 697' MD. Circulated at 691' MD. 450.0 10.0 RPM 8.306.4 3080'2-4-FC-A-1-1/6-PN-TD Condition Cht Mill Tooth Siltst Comments 23:59 Current Pump & Flow Data: 123 Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Morning Report Report # 14 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg - Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 375 89 - ROP (ft/hr)- SPP (psi) PJSM for Cement Plug Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 2-Feb-2014AlpineRig Activity: Avg to- - Date: - Flow In (spm) Spud 35.020010.00 Mill Tooth 100% Gas In Air= 0.739 3193' Hours 10,000 Units 0 N/A 1 000 (current) Connection 126 0Background 0 (max) Trip (max) Weight 13.5 Average Gas Summary 0 C-4n TuffCoal 98 0 0.739 0.00 3193' Chromatograph (ppm) 0 77 22 0 98 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 3193' Type C-5nC-1 C-3 C-4i 114' 2 Cor Solids % Chlorides mg/l Gvl 72.096.5 3194' 3194' 0' 35 24 Hour Progress: Rigged up for cement job and pumped 201 bbls of cement. Rigged down cement equipment and laid down cement string. 2 0 (ppb Eq) N/AMinimum N/A8 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 32.10 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 2610.00 TFABit #Bit Type Size 1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 0'3193' 212 Jeremy Tiegs/David McKechnie 0 1 907-670-4047Unit Phone: 19 David McKechnie Maximum 783 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 0 David McKechnie Maximum 365 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 0 PV cP MBT Cly 0 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 2RR1 Silt 13.5 - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 88.70 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum 180'3 0 Clyst at the shakers while circulating. Flushed stands. Laid down 4" drill pipe. Tested gas equipment while the rig cleaned pits and 2 0 Gvl -- 176' 232' 56' 11 24 Hour Progress: 176' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 - - 232' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 95 0Background 0 0 0 N/A 0 00 10,000 Units at report time. 0.739 Hours Spud 20.0478.70 Mill Tooth 100% Gas In Air= 3-Feb-2014AlpineRig Activity: Avg to- 250.0 Date: 496.0 Flow In (spm) SPP (psi) Circulate/Condition Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)219' CD3-130 N/A Doyon 19 Report For: Tools N/A Min - - ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg - Depth Yesterday's Depth: Current Depth: Morning Report Report # 15 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: - Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Cht Siltst Comments 500.0 3.0 RPM 10.30- - Condition flocculation and gravel at the possum belly and shakers. Circulating/conditioning mud and flushing MWD tools of potential debris tested the diverter valve. Made up BHA #5. Ran in the hole and tagged cement at 176' MD. Drilled out to 232' MD. Observed Rigged up cement equipment and pumped as per program. Pulled out of the hole to 112'. Observed green cement . . * 24 hr Recap:Circulate and condition cement contaminated mud. Work on #2 mud pump. Wash down to 231'. Drill ahead to 500.0 6.0 RPM 9.108.0 - Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 1313 Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Morning Report Report # 16 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 73.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 494 117 - ROP (ft/hr)677' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 4-Feb-2014AlpineRig Activity: Avg to- 40.3 Date: 245.0 Flow In (spm) Spud 32.53009.10 Mill Tooth 100% Gas In Air= 0.739 Hours 10,000 Units 0 N/A 0 000 (current) Connection 2258 106Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 1200' Type C-5nC-1 C-3 C-4i 176' Cor Solids % Chlorides mg/l Gvl -- 232' 1200' 968' 68 24 Hour Progress: 1200' MD. Noted max formation gas of 106 units at 1173' MD. 23 0 (ppb Eq) N/AMinimum 1173'106 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 429.10 TFABit #Bit Type Size 2RR1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 13 Jeremy Tiegs/David McKechnie 0 1 907-670-4047Unit Phone: 0 David McKechnie Maximum 12087 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 0 David McKechnie Maximum 11550 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 1 PV cP MBT Cly 13 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 2RR1 Silt 13.5 - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 429.10 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum 1267'103 0 Clyst resumed drilling ahead to 2731' MD. 47 0 Gvl -- 1200' 2731' 1531' 68 24 Hour Progress: 176' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 - - 2731' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 4631 30Background N/A 0 0 N/A 0 00 10,000 Units 0.739 Hours Spud 32.53009.10 Mill Tooth 100% Gas In Air= 5-Feb-2014AlpineRig Activity: Avg to- 63.9 Date: 590.0 Flow In (spm) SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)1872' CD3-130 N/A Doyon 19 Report For: Tools N/A Min 410 98 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 0.0 Depth Yesterday's Depth: Current Depth: Morning Report Report # 17 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 1033 Max N/AECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Cht Siltst Comments 500.0 6.0 RPM 9.108.0 - Condition Continued drilling ahead to 1503. Backreamed 1 stand to work out a dogleg at 1369' MD. Reamed to bottom and . . * 24 hr Recap: on trip tank. Work through tight spot at 685' MD. Continue to pull out of the hole and then lay down BHA. Drill ahead from 2731' MD to TD at 3366' MD. Circulate 3 bottoms-up and back ream out of the hole. The hole 600.0 9.0 RPM 8.505.6 3190'- Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Morning Report Report # 18 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 0.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min - ROP (ft/hr)1872' SPP (psi) L/D BHA Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 6-Feb-2014AlpineRig Activity: Avg to- 63.9 Date: 590.0 Flow In (spm) Spud 35.030010.00 Mill Tooth 100% Gas In Air= 0.739 3366' Hours 10,000 Units 0 N/A 8 042 (current) Connection 4410 N/ABackground N/A (max)Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 21 0 Chromatograph (ppm) 0 14 10 0 78 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 3366' Type C-5nC-1 C-3 C-4i 176' Cor Solids % Chlorides mg/l Gvl -- 2731' 3366' 635' 84 24 Hour Progress: unloaded at 2750' MD. Continue to back ream out of the to 756' MD. Flow check the well for static conditions. Pull out of the hole 43 0 (ppb Eq) N/AMinimum 3202'81 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 6010.00 TFABit #Bit Type Size 2RR1 Silt 13.5 C-2 Ss (current) DepthUnits* PV cP MBT Cly 248 Jeremy Tiegs/David McKechnie 490 54 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 8286 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00''114' Set At . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00''114' Set At 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 10444 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 9 PV cP MBT Cly 57 C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 2RR1 Silt 13.5 - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 6510.00 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A94 0 Clyst hole with 10.75" casing to 1420' MD and then circulate. Continue to run into the hole and work through tight spots. Change out bad 13 0 Gvl -- 3366' 3366' 0' 106 24 Hour Progress: 176' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3366' Type Sh Grade C-5i CementLst 0 5 0 0 12 6 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 1455 N/ABackground 94 0 0 N/A 2 00 10,000 Units 0.739 3366' Hours Spud 31.330010.00 Mill Tooth 100% Gas In Air= 7-Feb-2014AlpineRig Activity: Avg to- Date: Flow In (spm) SPP (psi) Circulating Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools N/A Min 254 60 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 19 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 340 Max N/A ECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Cht Siltst Comments 600.0 9.0 RPM 8.605.4 3190'- Condition Make-up cement head and condition mud for cement job. casing joint and continue to run into the hole. Make-up hanger and land the casing. Circulate a bottoms-up and rig down Tesco. Lay down BHA and then clean and clear rig floor. Rig up Tesco tools and casing running equipment. Run into the . . * 24 hr Recap: down surface stack and diverter. Rig up and perform cement top job. Nipple up BOPE and change out saver sub. Pick up drill pipe. Pump 2 spacers, mud push, and then cement. Bump the plug with spud mud and then wait for cement to return to 500.0 7.5 RPM 8.207.3 3190'- Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Morning Report Report # 20 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min - ROP (ft/hr) SPP (psi) P/U Drill Pipe Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 8-Feb-2014AlpineRig Activity: Avg to- Date: Flow In (spm) Spud 22.5609.80 Mill Tooth 100% Gas In Air= 0.739 3366' Hours 10,000 Units 0 N/A 0 000 (current) Connection 308 N/ABackground 94 (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 8 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 3366' Type C-5nC-1 C-3 C-4i 176' Cor Solids % Chlorides mg/l Gvl -- L-80 3366' 3366' 0' 14 24 Hour Progress: the surface. Monitor the well. Rig down the cementing equipment and lay down landing joint. Clean and clear the rig floor. Nipple 3 0 (ppb Eq) N/AMinimum N/A30 0 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) - Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 239.80 TFABit #Bit Type Size 2RR1 Silt 13.5 Surface Line C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 32 Jeremy Tiegs/Ashlee Charters 0 3 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 3206 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 283 Report By:Logging Engineers: 0 Jeremy Tiegs/Ashlee Charters 0 0 PV cP MBT 44.3 Cly 0 Surface Line C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 2RR1 Silt 13.5 43.34 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 249.80 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A2 0 Clyst make-up and racking back stands in derrick. Rig up and test BOPE. Rig down testing equipment and service pipe skate. Pull up 0 0 Gvl 45.035.0 L-80 3366' 3366' 0' 14 24 Hour Progress: 176' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3366' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max)Trip (max)(current) Connection 37 N/ABackground 94 0 0 N/A 0 00 10,000 Units 0.739 3366' Hours Spud 22.5609.80 Mill Tooth 100% Gas In Air= 9-Feb-2014AlpineRig Activity: Avg to- Date: Flow In (spm) SPP (psi) P/U Drill Pipe Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 21 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Cht Siltst Comments 450.0 7.5 RPM 8.007.4 3190'- Condition 5" drill pipe via mouse hole and rack back in derrick. Continue to pick up and break in new drill pipe. Move 6 stands of heavyweight drill pipe in derrick. Continue to . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 151 Report By:Logging Engineers: 0 Jeremy Tiegs/Ashlee Charters 0 0 PV cP MBT 44.3 Cly 0 Surface Line C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 249.80 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) N/AMinimum N/A1 0 Clyst hole to 95' MD. Take a mud weight measurement, Wash down to 110' MD. Continue to make-up BHA. Pick up drill pipe from pipe 0 0 Gvl L-80 3366' 3366' 0' 16 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 3366' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 48 N/ABackground N/A 0 0 N/A 0 00 10,000 Units 0.863 Hours Spud 22.5649.80 PDC 100% Gas In Air= 10-Feb-2014AlpineRig Activity: Avg to- Date: Flow In (spm) SPP (psi) Servicing Rig Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr) CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: AvgDepth Yesterday's Depth: Current Depth: Morning Report Report # 22 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / D. Lowe Flow In (gpm) Cht Siltst Comments 500.0 7.5 RPM 8.007.4 Condition then inspect top drive and service the rig. shed. Run into the hole to 3045' MD. Wash down to 3139' MD. Rig up testing equipment and test casing. Slip and cut drill line and Pick up and rack back 5" drill pipe. Pick up BHA tools and make-up BHA. Plug in MWD and load nukes. Run into the . . * 24 hr Recap:Calibrate block height on top drive. Drill out cement shoe track. Drill to 3386' MD and perform LOT. Drill ahead from 450.0 8.0 RPM 9.905.9 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 2000 Max N/A ECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Morning Report Report # 23 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 167.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 711 168 - ROP (ft/hr)4456' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 11-Feb-2014AlpineRig Activity: Avg to- 120.7 Date: 238.3 Flow In (spm) WBM 7.043 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 13 N/A 105 92137 (current) Connection 7817 79Background 152 (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 315 0 Chromatograph (ppm) 0 441 138 0 1217 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 4234' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 3366' 4509' 1143' 27 24 Hour Progress: 3386' MD while displacing to new water-based mud to 3423' MD. Drill ahead to 4509' MD. 92 0 (ppb Eq) 3367'Minimum 4463'737 2 Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 99.90 TFABit #Bit Type Size 3 Silt 9.875 Surface Line C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 3068 Jeremy Tiegs/Ashlee Charters 36 296 907-670-4047Unit Phone: 145 Jeremy Tiegs Maximum 76602 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 88 Jeremy Tiegs Maximum 54185 Report By:Logging Engineers: 0 Jeremy Tiegs/Ashlee Charters 46 429 PV cP MBT 44.3 Cly 1547 Surface Line C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 99.80 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) 4464'Minimum 4509'486 2 Clyst ahead to 6091' MD. Troubleshoot top drive and service top drive. Drill from 6091' MD to 6301' MD. 112 0 Gvl L-80 4509' 6301' 1792' 27 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 6095' Type Sh Grade C-5i CementLst 0 239 95 0 613 102 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 10330 119Background N/A 67 25 N/A 165 2629 10,000 Units 0.863 Hours WBM 20.041 PDC 100% Gas In Air= 12-Feb-2014AlpineRig Activity: Avg to- 169.3 Date: 241.5 Flow In (spm) SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)4456' CD3-130 N/A Doyon 19 Report For: Tools N/A Min 711 168 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 162.0 Depth Yesterday's Depth: Current Depth: Morning Report Report # 24 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 2000 Max N/A ECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Cht Siltst Comments 450.0 8.0 RPM 9.705.9 Condition Drill from 4460' MD to 6024' MD. Top drive gear oil light came on consequently the top drive was serviced. Drill . . * 24 hr Recap:Drilled ahead from 6301' MD, pumping 40 bbls 11.8 ppg sweeps every 3 stands. Trouble shoot intermittent 450.0 8.5 RPM 10.105.2 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 2586 Max N/AECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Morning Report Report # 25 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 195.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 700 165 - ROP (ft/hr)7140' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 13-Feb-2014AlpineRig Activity: Avg to- 180.0 Date: 248.0 Flow In (spm) WBM 13.8439.95 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 93 N/A 565 12898278 (current) Connection 17760 119Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 815 0 Chromatograph (ppm) 0 2337 654 0 5535 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 6095' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 6301' 8483' 2182' 23 24 Hour Progress: WITS feed. Resolved. Noted max formation gas of 1747 units at 7500' MD. Drilling ahead to 8483' MD at report time. 228 0 (ppb Eq) -Minimum 7500'1747 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 119.80 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 9248 Ashlee Charters/David McKechnie 0 992 907-670-4047Unit Phone: 864 David McKechnie Maximum 139466 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap:Drilled ahead from 8483' MD. Performed dilution at 10757' MD. Noted max gas of 256 units while trouble shooting 800.0 9.9 RPM 9.204.8 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 2576 Max N/AECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Morning Report Report # 26 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 170.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 711 168 - ROP (ft/hr)9357' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 14-Feb-2014AlpineRig Activity: Avg to- 180.0 Date: 290.0 Flow In (spm) WBM 23.8439.80 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 93 N/A 565 12898278 (current) Connection 17760 95Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 815 0 Chromatograph (ppm) 0 2337 654 0 5535 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 10665' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 8483' 10884' 2401' 24 24 Hour Progress: pumps at 9730' MD (12:40 PM). 138 0 (ppb Eq) -Minimum 9730'256 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 99.80 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 9248 Ashlee Charters/David McKechnie 0 992 907-670-4047Unit Phone: 864 David McKechnie Maximum 139466 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: drive. Tripped to bottom and resumed drilling ahead to 12465' MD at report time. Drilled ahead from 10844' MD to 12304' MD. Backreamed 10 stands out of the hole. Tripped in the hole to approx. 400.0 8.8 RPM 9.404.9 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 2442 Max N/AECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Morning Report Report # 27 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 191.0 Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 703 166 - ROP (ft/hr)11564' SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 15-Feb-2014AlpineRig Activity: Avg to- 200.0 Date: 275.0 Flow In (spm) WBM 11.3419.90 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 31 N/A 397 3850128 (current) Connection 1565 142Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 91 0 Chromatograph (ppm) 0 247 56 0 723 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 10665' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 10884' 12465' 1581' 22 24 Hour Progress: 12200' MD. Circulated bottoms up and performed dilution. Did not note any swab/trip gas. Broke circulation and worked on top 157 0 (ppb Eq) -Minimum 11544'226 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 79.90 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 1219 Ashlee Charters/David McKechnie 0 759 907-670-4047Unit Phone: 67 David McKechnie Maximum 24280 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 999 David McKechnie Maximum 454751 Report By:Logging Engineers: 0 Ashlee Charters/David McKechnie 0 3169 PV cP MBT 44.3 Cly 27243 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 109.90 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum 14289'6104 - Clyst 20 bbls lost down hole during event. Noted gas peak of 5150 units upon bottoms up of loss encounter. Collected Isotube gas 538 units at report time. 0 Gvl L-80 12465' 14382' 1917' 22 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 - - 12301' Type Sh Grade C-5i CementLst 0 4851 1099 0 19499 2503 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 50687 923Background N/A 645 158 N/A 2190 165285 10,000 Units from lag depth of 14288' MD. Circulated out until gas fell to 850 units. Drilling ahead to 14382' MD with a background gas of 923 0.863 Hours WBM 22.5429.90 PDC 100% Gas In Air= 16-Feb-2014AlpineRig Activity: Avg to- 200.0 Date: 245.0 Flow In (spm) SPP (psi) Drilling Ahead Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)15003' CD3-130 N/A Doyon 19 Report For: Tools N/A Min 740 174 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg 138.0 Depth Yesterday's Depth: Current Depth: Morning Report Report # 28 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 3090 Max N/AECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Cht Siltst Comments 500.0 10.0 RPM 9.404.2 Condition Continued circulating until gas dropped to 1300 units. Drilled ahead to 14378' MD and encountered max gas peak of 6104 units sample during peak. Circulated and conditioned while reciprocating pipe. Collected additional gas sample at 5800 units. Drilled ahead from 12465' MD. Lost returns at 14096' MD (19:05). Regained full circulation within 5 minutes. . . * 24 hr Recap: GPM. Continued drilling ahead to 15,131' MD. Pulled tight while attempting to backream for connection. Working pipe at report time Continued drilling ahead to 14754' MD. Circulated and conditioned while troubleshooting Top Drive. Continued 450.0 10.0 RPM 9.403.1 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 0 Max N/AECD (ppg) 96% D. Mickey / D. Lowe Flow In (gpm) Morning Report Report # 29 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 0 0 - ROP (ft/hr)15003' SPP (psi) Working Pipe Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 17-Feb-2014AlpineRig Activity: Avg to- 200.0 Date: 245.0 Flow In (spm) WBM 20.04210.05 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 460 6540 4366 4707181545 (current) Connection 58592 270Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 4341 0 Chromatograph (ppm) 0 8848 2347 0 29424 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 15021' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 14382' 15132' 750' 26 24 Hour Progress: Drilling ahead to 14,844' MD. Packed off. Circulated and conditioned using step rate method. Packed off. Stepped rates to 648 888 0 (ppb Eq) -Minimum 15048'6540 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1210.00 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 32610 Ashlee Charters/David McKechnie 0 4709 907-670-4047Unit Phone: 2379 David McKechnie Maximum 413920 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 3908 David McKechnie Maximum 585825 Report By:Logging Engineers: 0 Ashlee Charters/David McKechnie 0 5260 and conditioning at report time. PV cP MBT 44.3 Cly 66847 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1410.50 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum 14950'10000 - Clyst of 10,000 units (100% gas). Collected Isotube gas sample. Peak held for 25 minutes. Noted 7 1/2 bbl gain. Flow checked. Noted 1094 while circulating out gas from prior pack off. Stepped rates to 443 gpm and washed/reamed 3 stands out of the hole. Circulating 0 Gvl L-80 15132' 15227' 95' 28 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 - - 15131' Type Sh Grade C-5i CementLst 0 15606 3904 0 58848 7734 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 71434 600Background N/A 1588 508 N/A 4419 544714 10,000 Units power to the rig for 20 minutes. Stepped rates to 600 gpm and circulated gas peak of 8662 units from pack off event. Packed off 0.863 Hours WBM 25.04410.60 PDC 100% Gas In Air= 18-Feb-2014AlpineRig Activity: Avg to- 120.0 Date: 162.0 Flow In (spm) SPP (psi) Circulate/Condition Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)15156' CD3-130 N/A Doyon 19 Report For: Tools N/A Min 598 141 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 30 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 2295 Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Cht Siltst Comments 500.0 16.0 RPM 9.505.8 Condition Closed reamer and drilled ahead to 15,226' MD. Packed off while back reaming. Worked tight pipe while fighting pack offs. Lost slight increase, but stabilized for 25 minutes. Circulated and conditioned while weighing mud up to 10.5. Washed down to 15032 Attempted to establish circulation while fighting pack-offs. Stepped rates to 445 gpm. Circulated up a peak gas . . * 24 hr Recap: 9767 units of gas as a result of multiple pack off events. Backreaming out of the hole to 14050' MD at report time with a pill to 14230' MD. Pulled 12 stands out of the hole. Pulled tight. Stepped up rates, packed off. Stepped rates to 653 GPM. Circulated Washed down to 15150' MD. Packed off. Stepped rates to 628 GPM. Washed down to bottom at 15226' MD. 450.0 15.0 RPM 9.605.4 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 1085 Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Morning Report Report # 31 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 355 84 - ROP (ft/hr)15427' SPP (psi) Backreaming out hole Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 19-Feb-2014AlpineRig Activity: Avg to- 100.0 Date: 134.0 Flow In (spm) WBM 22.54310.60 PDC 100% Gas In Air= 0.863 Hours 10,000 Units background gas of 620 units. 248 N/A 2018 275329759 (current) Connection 31042 620Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 5725 0 Chromatograph (ppm) 0 11137 2694 0 43764 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 15483' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 15227' 15483' 256' 24 24 Hour Progress: Resumed drilling ahead to TD at 15483' MD 6806' TVD. Circulated bottoms up. Flow checked - Static. Spotted casing running 465 0 (ppb Eq) -Minimum 14300'9767 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1310.50 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 52283 Ashlee Charters/David McKechnie 0 2378 907-670-4047Unit Phone: 2629 David McKechnie Maximum 534019 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: noted at 13522' MD. backreaming to 12489; MD. Troubleshoot top drive. Backreamng out of the hole to 10885' MD at report time. Max gas of 1237 units Backreamed out of the hole to 13526' MD. Reamer opened. Closed reamer and resumed pulling out of the hole on 450.0 16.0 RPM 9.502.7 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 1415 Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Morning Report Report # 32 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 448 106 - ROP (ft/hr)15427' SPP (psi) Backreaming out hole Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 20-Feb-2014AlpineRig Activity: Avg to- 100.0 Date: 134.0 Flow In (spm) WBM 22.54710.60 PDC 100% Gas In Air= 0.863 Hours 10,000 Units 125 N/A 854 140151376 (current) Connection 12995 129Background N/A (max) Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 710 0 Chromatograph (ppm) 0 1572 479 0 4387 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 - - 15483' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 15483' 15483' 0' 25 24 Hour Progress: trip tank. Swabbing noted. Continued backreaming out of the hole. Packed off at 13337' MD. Staged up pumps and resumed 183 0 (ppb Eq) -Minimum 13522'1237 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1510.60 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 6121 Ashlee Charters/David McKechnie 0 949 907-670-4047Unit Phone: 501 David McKechnie Maximum 97537 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 124 Jeremy Tiegs Maximum 18382 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 36 356 PV cP MBT 44.3 Cly 853 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1710.60 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum -2787 - Clyst to 7299' MD and then backream out of the hole. Circulate a bottoms-up and then pull out of the hole to 6112' MD. Run into the hole 86 0 Gvl L-80 15483' 15483' 0' 28 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 15516' Type Sh Grade C-5i CementLst 0 287 103 0 643 118 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max)Trip (max)(current) Connection 6338 N/ABackground N/A 134 54 N/A 244 6352 10,000 Units 0.863 Hours WBM 26.05610.60 PDC 100% Gas In Air= 21-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Backreaming out hole Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min 415 98 ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 33 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: 1260 Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Cht Siltst Comments 450.0 16.5 RPM 9.403.3 Condition Backream out of the hole to 5129' MD. Pull out of the hole with pumps on to 3329' MD. to 6166' MD and then backream out of the hole to 5789' MD. Pull out of the hole to 5204' MD and then circulate a bottoms-up. Backream out of the hole from 10885' MD to 9280' MD. Pull out of the hole on elevators to 7254' MD. Run in the hole . . * 24 hr Recap: plug, and change out the upper rams. Test the rams afterwards and then rig down the testing equipment. Fill the hole and monitor locked. Continue to lay down the BHA while cleaning and clearing the rig floor of BHA tools. Flush the stack, pull WR, set the test At 3329' MD pump a 37 bbl sweep . Observe the well for static conditions. Pull out of the hole to 790' MD. Observe 450.0 16.5 RPM 9.203.2 Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Morning Report Report # 34 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min - ROP (ft/hr)N/A SPP (psi) Testing BOP's Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 22-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) WBM 26.05310.60 PDC 100% Gas In Air= 0.863 Hours 10,000 Units for static conditions. Rig up and test BOP's. 11 N/A 19 7714 (current) Connection 350 N/ABackground N/A (max)Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 92 0 Chromatograph (ppm) 0 234 116 0 315 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 15516' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl L-80 15483' 15483' 0' 29 24 Hour Progress: the well again for static conditions. Lay down BHA components as per SLB crew. Confirm that the under reamer is closed and 10 0 (ppb Eq) -Minimum -114 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1610.60 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 452 Jeremy Tiegs/David McKechnie 0 27 907-670-4047Unit Phone: 125 Jeremy Tiegs Maximum 8867 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 3320 Jeremy Tiegs Maximum 517482 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 6033 PV cP MBT 44.3 Cly 76801 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1410.50 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum -10000 - Clyst stack afterwards. Set the W/R and rig down the elevators and bails. Monitor the well on the trip tank. Dummy run the hanger. Rig 965 condition. 0 Gvl 140.025.0 L-80 15483' 15483' 0' 21 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 15516' Type Sh Grade C-5i CementLst 0 16618 3545 0 75633 8956 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max)Trip (max)(current) Connection 55860 N/ABackground 10000 1718 447 N/A 5867 436940 10,000 Units run in the hole to 5320' MD and then circulate and condition. Continue to run in the hole to 6329' MD and then circulate and 0.863 15483' Hours WBM 27.55610.50 PDC 100% Gas In Air= 23-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Running Casing Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 35 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Cht Siltst Comments 500.0 15.5 RPM 8.902.5 12117'1-1-CT-C-X-I-NO-TD Condition to 3342' MD and then circulate and condition. Continue to run in the hole to 4225' MD and then circulate and condition. Continue to up Tesco casing tools. Run in the hole with casing as per detail. Circulate and condition at 2202' MD. Continue to run in the hole Continue to test BOP's. Change out the upper rams. Set the test joint, fill the stack, and then test rams. Drain the . . * 24 hr Recap: running in the hole to 13525' MD and then circulate and condition mud. and then circulate and condition mud. Continue running in the hole to 12555' MD and then circulate and condition mud. Continue Continue running in the hole from 6329' MD to 7353' MD with casing as per detail. Then, circulate and condition 500.0 15.0 RPM 9.302.6 12117'1-1-CT-C-X-I-NO-TD Condition Cht Siltst Comments 23:59 Current Pump & Flow Data: 474 Max N/AECD (ppg) 96% D. Mickey / A. Dore Flow In (gpm) Morning Report Report # 36 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min 251 60 - ROP (ft/hr)N/A SPP (psi) Running Casing Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 24-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) WBM 27.55210.60 PDC 100% Gas In Air= 0.863 15483' Hours 10,000 Units 520 N/A 5529 5348811809 (current) Connection 94283 N/ABackground 10000 (max)Trip (max) Weight Average Gas Summary 0 C-4n TuffCoal 4316 0 Chromatograph (ppm) 0 8427 1985 0 34775 Sh Grade C-5i CementLst Conductor Line 94.0 H-40 900966762 15487' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l Gvl 140.025.0 L-80 15483' 15483' 0' 22 24 Hour Progress: mud. Continue running in the hole to 8369' MD and then circulate and condition mud. Continue running in the hole to 9289' MD 1327 0 (ppb Eq) -Minimum -10000 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1410.60 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 44.3 Cly 51156 Jeremy Tiegs/David McKechnie 0 6734 907-670-4047Unit Phone: 1930 Jeremy Tiegs Maximum 602822 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 907-670-4047Unit Phone: 1653 Jeremy Tiegs Maximum 566779 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 1284 PV cP MBT 44.3 Cly 40460 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1510.60 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum -9407 - Clyst Continued to run in the hole to 14212' MD and started taking weight at 14000' MD. Attempt to pull out of the hole was no good. 288 0 Gvl 140.025.0 L-80 15483' 15483' 0' 26 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l C-5nC-1 C-3 C-4i Conductor Line 94.0 H-40 900966762 15487' Type Sh Grade C-5i CementLst 0 7021 1685 0 27910 3572 0 Chromatograph (ppm) Gas Summary 0 C-4n TuffCoal Weight Average (max)Trip (max)(current) Connection 19555 N/ABackground 9407 449 144 N/A 1145 156200 10,000 Units 0.863 15483' Hours WBM 27.55310.60 PDC 100% Gas In Air= 25-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Rig Down Tesco Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 37 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Cht Siltst Comments 550.0 15.5 RPM 9.702.4 12117'1-1-CT-C-X-I-NO-TD Condition rig floor. Begin to rig down Tesco equipment. Attempt to circulate was no good. Work string down to 14307' MD. Attempt to work string afterwards. Stage the scaffolding on the Continue to circulate and condition at 13525' MD. Gas spiked to 10000 units and remained for ~25 minutes. . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 7.63'' 907-670-4047Unit Phone: 438 Jeremy Tiegs Maximum 75623 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 345 PV cP MBT 45.5 Cly 3529 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1310.60 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum -850 - Clyst lines. Rig down scaffolding and then clean and clear rig floor. Wait on cementers and pressure test lines. Stage up pumps. Pump 75 0 Gvl 140.025.0 L-80 15483' 15483' 0' 26 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l L-80 C-5nC-1 C-3 C-4i Conductor Line 78.6 A53 B 900966762 15487' Type Sh Grade C-5i CementLst 0 1200 405 0 2749 515 0 Chromatograph (ppm) Gas Summary 0 Intermediate Casing C-4n TuffCoal Weight Average (max)Trip (max)(current) Connection 5016 N/ABackground N/A 178 64 N/A 358 7075 10,000 Units down lines. Wait on cement. 0.863 15483' Hours WBM 27.55510.60 PDC 100% Gas In Air= 26-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Waiting on Cement Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 38 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) 29.7 Cht 14307' Siltst Comments 500.0 15.5 RPM 9.202.6 12117'1-1-CT-C-X-I-NO-TD Condition system to 10.8 ppg. Pump chemical wash, spacer, and cement. Drop plug and displace with rig pumps. Bump plug and then rig up pressure and monitor it. A slight flow was observed. Bleed off pressure and then stage up pumps again. Weigh up active Rig down Tesco and then rig up long bales. Erect scaffolding on the rig floor. Rig up cement head and circulating . . * 24 hr Recap: set pack off. Nipple up the BOPE and then test pack off. Continue to nipple up the BOPE. hole in casing and then drain fluid. Lay down the cement head. Cut the casing and then lay down the joint. Remove the riser and Continue to wait on cement to set. Clean wind walls. Change out swabs, liners, seats and valves on mud pumps. 550.0 15.0 RPM 9.502.4 12117'1-1-CT-C-X-I-NO-TD Condition 29.7 Cht 14307' Siltst Comments 23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Morning Report Report # 39 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min - ROP (ft/hr)N/A SPP (psi) N/U BOPE Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 27-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) WBM 27.56010.60 PDC 100% Gas In Air= 0.863 15483' Hours 10,000 Units 0 N/A 0 000 (current) Connection 0 N/ABackground N/A (max) Trip (max) Weight Average Gas Summary 0 Intermediate Casing C-4n TuffCoal 0 0 Chromatograph (ppm) 0 0 0 0 0 Sh Grade C-5i CementLst Conductor Line 78.6 A53 B 900966762 15487' Type C-5nC-1 C-3 C-4i 3366' Cor Solids % Chlorides mg/l L-80 Gvl 140.025.0 L-80 15483' 15483' 0' 26 24 Hour Progress: Bleed off pressure and open annulus. Observe the well. Remove flow line. Nipple down the BOPE stack. Set emergency slips. Cut 0 0 (ppb Eq) Minimum -0 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1210.60 TFABit #Bit Type Size 3 Silt 9.875 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 45.5 Cly 0 Jeremy Tiegs/David McKechnie 0 0 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 0 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 7.63'' . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 7.63'' 907-670-4047Unit Phone: 0 Jeremy Tiegs Maximum 0 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 0 PV cP MBT 45.5 Cly 0 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size 3 Silt 9.875 78.20 Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1310.60 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) Minimum -0 - Clyst hydraulic oil to Top Drive. Continue to lay down 5" drill pipe. Rig up wireline equipment. Run in the hole with fishing magnet. Pull 0 0 Gvl 140.025.0 L-80 15483' 15483' 0' 25 24 Hour Progress: 3366' Cor Solids % Chlorides mg/l L-80 C-5nC-1 C-3 C-4i Conductor Line 78.6 A53 B 900966762 15487' Type Sh Grade C-5i CementLst 0 0 0 0 0 0 0 Chromatograph (ppm) Gas Summary 0 Intermediate Casing C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 0 N/ABackground N/A 0 0 N/A 0 00 10,000 Units 0.863 15483' Hours WBM 27.56310.60 PDC 100% Gas In Air= 28-Feb-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) Testing BOPE Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 39 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) 29.7 Cht 14307' Siltst Comments 500.0 15.0 RPM 9.502.3 12117'1-1-CT-C-X-I-NO-TD Condition rams. out of the hole with dropped equipment. Lay down 5" drill pipe. Change out rams and then rig up to test. Test upper and lower Change out the saver sub. Rig up elevators and bales for 5" drill pipe. Lay down 5" drill pipe via the mouse hole. Add . . * 24 hr Recap: Wash and ream to 7221' MD. Circulate 1.5 bottoms-up. Run in to the hole from the pipe shed.. The bottom of the hole took weight. Rig up and test casing to 1000psi. Rig down testing equipment. Ream in to the hole to 6913' MD. Drill the plug and stage collar. Continue testing rams. Set wear ring. Make-up BHA #7. Re-rig counterbalance shackles on top drive. Cut and slip 500.0 14.0 RPM 10.102.3 Condition 29.7 Cht 14307' Siltst Comments 23:59 Current Pump & Flow Data: Max N/A ECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) Morning Report Report # 41 Customer: Well: Area: Location: 4.23 @ Rig: ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth:CD3-130 N/A Doyon 19 Report For: Tools N/A Min - ROP (ft/hr)N/A SPP (psi) Reaming into hole Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current 1-Mar-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) WBM 27.55610.60 Mill Tooth 100% Gas In Air= Hours 10,000 Units Wash and ream to 7502' MD. 17 N/A 53 201543 (current) Connection 148 N/ABackground 28 (max) Trip (max) Weight Average Gas Summary 0 Intermediate Casing C-4n TuffCoal 60 0 Chromatograph (ppm) 0 157 63 0 207 Sh Grade C-5i CementLst Conductor Line 78.6 A53 B 900966762 15487' Type C-5nC-1 C-3 C-4i 14307' Cor Solids % Chlorides mg/l L-80 Gvl L-80 15483' 15483' 0' 22 24 Hour Progress: the drill line. Pick up 4" drill pipe from the pipe shed. Rack back 5 stands of drill pipe in the derrick. Continue to pick up 4" drill pipe. 15 0 (ppb Eq) -Minimum -28 - Clyst YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2) Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1410.60 TFABit #Bit Type Size 4 Silt 6.75 Surface Casing C-2 Ss (current) DepthUnits* PV cP MBT 45.5 Cly 89 Jeremy Tiegs/David McKechnie 0 26 907-670-4047Unit Phone: 70 Jeremy Tiegs Maximum 443 Report By:Logging Engineers: 0 Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 7.63'' . . * 24 hr Recap: Casing Summary Lithology (%) Size 20.00'' 3354' 114' Set At 10.75" 7.63'' 907-670-4047Unit Phone: 202 Jeremy Tiegs Maximum 3441 Report By:Logging Engineers: 0 Jeremy Tiegs/David McKechnie 0 38 PV cP MBT 45.5 Cly 669 Surface Casing C-2 Ss (current) DepthUnits* TFABit #Bit Type Size - Silt -- Depth in / out WOBFootage Density (ppg) out (sec/qt) Viscosity 1110.50 YP Mud Data Depth API FL ml/30minMud Type in pH (lb/100ft2)(ppb Eq) -Minimum -110 - Clyst Ran into the hole to 14176' MD and tagged up on bottom. Pumped sweep around and performed injectivity test. Pumped away 11 0 Gvl -- L-80 15483' 15483' 0' 23 24 Hour Progress: - Cor Solids % Chlorides mg/l L-80 C-5nC-1 C-3 C-4i Conductor Line 78.6 A53 B 900966762 - - 15487' Type Sh Grade C-5i CementLst 0 490 181 0 909 197 0 Chromatograph (ppm) Gas Summary 0 Intermediate Casing C-4n TuffCoal Weight Average (max) Trip (max)(current) Connection 202 N/ABackground 110 37 10 N/A 61 1214 10,000 Units -- Hours WBM 27.55810.50 - 100% Gas In Air= 2-Mar-2014AlpineRig Activity: Avg to- N/A Date: N/A Flow In (spm) SPP (psi) TOH Max @ ft N/A ROP MWD Summary 24 hr Max Time: Gallons/stroke Current - ROP (ft/hr)N/A CD3-130 N/A Doyon 19 Report For: Tools N/A Min ConocoPhillips Alaska, Inc. North Slope, AK Job No.: Daily Charges: Total Charges: Avg N/A Depth Yesterday's Depth: Current Depth: Morning Report Report # 42 Customer: Well: Area: Location: 4.23 @ Rig:23:59 Current Pump & Flow Data: Max N/AECD (ppg) 96% K. Harding / A. Dorr Flow In (gpm) 29.7 Cht 14307' Siltst Comments 500.0 15.0 RPM 9.803.5 -- Condition at report time. 74 bbls. Monitored pressure. Began pulling out of the hole on the trip tank. Flow checked after 10 stands. Pulling out to 3,143' MD Washed and reamed to 7,694' MD. Ran in the hole to 9,581' MD. Circulated bottoms up. Noted 22 units of gas. WELL INFORMATION Created On : Mar 25 2014 Customer :ConocoPhillips Alaska, Inc. Well Name :CD3-130 Job Number :AK-XX-0900966762 Platform :Doyon 19 Field Name :Western North Slope Country :USA Survey Report Survey dataSURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 36.62 0.00 0.00 36.62 0.00 N 0.00 E 0.00 0.00 116.71 0.13 154.32 116.71 0.08 S 0.04 E -0.09 0.16 174.06 0.20 113.61 174.06 0.18 S 0.16 E -0.24 0.23 246.80 1.48 253.68 246.79 0.50 S 0.63 W -0.05 2.25 264.41 1.99 249.47 264.39 0.67 S 1.13 W 0.10 2.98 294.69 1.78 251.65 294.66 1.00 S 2.07 W 0.37 0.73 340.33 1.68 252.62 340.28 1.42 S 3.38 W 0.77 0.23 388.36 1.95 271.93 388.28 1.60 S 4.87 W 1.48 1.38 392.86 1.85 269.39 392.78 1.60 S 5.02 W 1.57 2.90 430.88 2.33 297.40 430.78 1.25 S 6.32 W 2.60 2.93 523.41 4.55 323.70 523.14 2.57 N 10.16 W 7.93 2.88 581.12 6.81 328.21 580.56 7.32 N 13.32 W 13.64 3.99 673.16 8.88 328.76 671.74 18.04 N 19.88 W 26.18 2.25 766.65 11.82 329.96 763.69 32.50 N 28.42 W 42.92 3.15 863.45 15.51 333.17 857.74 52.64 N 39.23 W 65.62 3.89 957.79 21.32 339.17 947.22 79.95 N 51.03 W 94.76 6.47 1007.07 22.34 340.91 992.96 97.17 N 57.28 W 112.45 2.45 1050.33 20.83 341.51 1,033.19 112.24 N 62.41 W 127.73 3.53 1143.45 20.47 342.59 1,120.33 143.48 N 72.53 W 159.13 0.56 1237.29 22.95 344.74 1,207.51 176.79 N 82.25 W 192.00 2.77 1330.98 28.20 345.89 1,291.99 215.91 N 92.47 W 229.90 5.63 1377.32 31.42 347.29 1,332.19 238.32 N 97.79 W 251.31 7.11 1421.01 30.24 347.61 1,369.71 260.17 N 102.66 W 272.00 2.73 1515.28 34.39 351.00 1,449.37 309.68 N 111.92 W 317.87 4.80 1611.93 37.55 354.83 1,527.59 365.99 N 118.85 W 367.97 4.01 1706.68 37.56 356.81 1,602.70 423.58 N 123.06 W 417.56 1.27 1800.83 41.32 6.06 1,675.47 483.22 N 121.37 W 465.44 7.40 1848.28 43.60 10.34 1,710.48 514.90 N 116.78 W 488.76 7.75 1895.19 43.23 11.92 1,744.55 546.53 N 110.56 W 511.11 2.45 1989.27 45.20 16.54 1,812.00 610.08 N 94.40 W 553.89 4.01 2084.47 47.26 22.32 1,877.88 674.83 N 71.49 W 593.79 4.89 INSITE V8.0.20 Page 1Job No:AK-XX-0900966762 Well Name:CD3-130 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2178.59 47.75 27.18 1,941.48 737.81 N 42.44 W 628.72 3.84 2273.39 49.47 32.23 2,004.18 799.53 N 7.19 W 659.06 4.39 2367.82 53.11 36.13 2,063.24 860.42 N 34.24 E 685.17 5.02 2415.77 54.92 37.46 2,091.41 891.48 N 57.48 E 697.29 4.39 2462.23 56.48 38.46 2,117.59 921.74 N 81.09 E 708.53 3.80 2556.15 59.99 40.46 2,167.03 983.36 N 131.85 E 729.90 4.15 2650.78 63.05 42.23 2,212.15 1,045.78 N 186.80 E 749.51 3.63 2746.62 66.54 44.40 2,252.97 1,108.84 N 246.29 E 767.04 4.18 2840.08 69.42 45.36 2,288.00 1,170.23 N 307.43 E 782.26 3.23 2936.52 69.04 49.56 2,322.22 1,231.18 N 373.84 E 794.09 4.09 3028.95 67.59 51.65 2,356.37 1,285.69 N 440.21 E 800.68 2.62 3124.43 67.67 51.38 2,392.71 1,340.64 N 509.32 E 806.05 0.27 3217.46 67.26 50.87 2,428.37 1,394.56 N 576.22 E 811.86 0.67 3288.10 67.57 51.09 2,455.49 1,435.63 N 626.89 E 816.43 0.52 3383.04 67.80 49.57 2,491.54 1,491.69 N 694.49 E 823.58 1.50 3452.46 69.13 50.92 2,517.03 1,532.98 N 744.13 E 828.93 2.63 3545.73 66.99 46.85 2,551.89 1,589.84 N 809.31 E 838.12 4.65 3640.04 67.18 45.90 2,588.61 1,649.77 N 872.19 E 851.15 0.95 3735.07 67.68 48.12 2,625.09 1,709.60 N 936.37 E 863.34 2.22 3828.50 67.02 50.16 2,661.07 1,766.01 N 1,001.58 E 872.14 2.14 3924.08 66.83 48.92 2,698.53 1,823.07 N 1,068.48 E 880.51 1.21 4019.23 66.30 50.36 2,736.38 1,879.60 N 1,135.00 E 888.67 1.50 4114.31 66.18 53.52 2,774.69 1,933.24 N 1,203.50 E 893.31 3.04 4206.94 66.19 52.98 2,812.09 1,983.94 N 1,271.40 E 895.90 0.53 4301.89 66.10 53.17 2,850.49 2,036.11 N 1,340.83 E 898.82 0.21 4395.70 66.18 50.77 2,888.45 2,088.96 N 1,408.40 E 903.35 2.34 4488.94 66.07 48.83 2,926.19 2,143.99 N 1,473.51 E 911.08 1.91 4583.30 66.13 48.40 2,964.42 2,201.03 N 1,538.24 E 920.67 0.42 4678.39 66.18 51.48 3,002.87 2,256.99 N 1,604.80 E 928.34 2.96 4772.54 66.25 51.89 3,040.84 2,310.40 N 1,672.39 E 933.32 0.41 4866.26 66.13 54.96 3,078.68 2,361.49 N 1,741.24 E 935.68 3.00 4960.79 66.16 55.68 3,116.91 2,410.68 N 1,812.34 E 935.20 0.70 5060.59 66.12 55.17 3,157.28 2,462.48 N 1,887.49 E 934.52 0.47 5156.56 65.96 54.51 3,196.25 2,512.98 N 1,959.19 E 934.77 0.65 5251.36 66.22 51.63 3,234.68 2,565.04 N 2,028.45 E 937.69 2.79 5344.94 66.31 50.36 3,272.35 2,618.96 N 2,095.02 E 943.67 1.25 5438.10 66.89 51.30 3,309.35 2,672.96 N 2,161.30 E 949.89 1.12 5533.44 66.33 51.53 3,347.20 2,727.53 N 2,229.70 E 955.36 0.63 5628.04 66.63 50.05 3,384.95 2,782.37 N 2,296.91 E 961.73 1.47 5723.34 66.56 49.04 3,422.81 2,839.11 N 2,363.46 E 970.04 0.98 5816.94 66.67 49.21 3,459.96 2,895.34 N 2,428.42 E 978.83 0.20 5911.09 66.55 48.87 3,497.34 2,951.98 N 2,493.67 E 987.81 0.36 6005.66 66.99 50.07 3,534.64 3,008.45 N 2,559.73 E 996.18 1.26 6100.11 66.81 52.58 3,571.70 3,062.74 N 2,627.54 E 1001.75 2.45 6194.65 66.94 51.85 3,608.83 3,116.01 N 2,696.26 E 1005.97 0.72 INSITE V8.0.20 Page 2Job No:AK-XX-0900966762 Well Name:CD3-130 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6288.51 66.62 50.65 3,645.84 3,170.00 N 2,763.53 E 1011.61 1.22 6383.07 66.98 51.07 3,683.09 3,224.86 N 2,830.94 E 1017.89 0.56 6477.62 66.79 54.00 3,720.21 3,277.75 N 2,899.95 E 1021.63 2.86 6571.94 66.86 57.16 3,757.34 3,326.75 N 2,971.46 E 1020.75 3.08 6666.05 66.68 57.62 3,794.46 3,373.36 N 3,044.31 E 1017.14 0.49 6761.07 66.99 55.86 3,831.84 3,421.27 N 3,117.35 E 1014.49 1.73 6853.68 66.59 53.64 3,868.34 3,470.38 N 3,186.86 E 1014.86 2.25 6949.58 66.70 50.93 3,906.36 3,524.24 N 3,256.50 E 1019.03 2.60 7044.55 66.60 50.73 3,944.01 3,579.31 N 3,324.09 E 1025.37 0.22 7136.17 66.91 50.51 3,980.16 3,632.72 N 3,389.16 E 1031.80 0.40 7232.25 66.69 50.61 4,018.01 3,688.82 N 3,457.36 E 1038.64 0.25 7327.48 66.72 49.59 4,055.68 3,744.92 N 3,524.46 E 1046.11 0.98 7421.49 66.97 48.71 4,092.64 3,801.46 N 3,589.85 E 1054.92 0.90 7514.69 66.72 48.92 4,129.29 3,857.89 N 3,654.34 E 1064.15 0.34 7610.78 66.68 48.12 4,167.30 3,916.34 N 3,720.46 E 1074.11 0.77 7704.43 66.85 48.44 4,204.24 3,973.61 N 3,784.69 E 1084.18 0.36 7799.45 66.72 50.92 4,241.70 4,030.11 N 3,851.26 E 1092.28 2.40 7893.38 66.88 51.97 4,278.71 4,083.92 N 3,918.77 E 1097.63 1.04 7988.00 66.72 53.23 4,315.98 4,136.74 N 3,987.86 E 1101.27 1.24 8082.53 66.65 52.74 4,353.40 4,189.00 N 4,057.18 E 1104.33 0.48 8176.47 66.91 52.48 4,390.44 4,241.43 N 4,125.77 E 1107.93 0.38 8271.16 66.54 52.12 4,427.85 4,294.62 N 4,194.59 E 1112.02 0.52 8364.84 66.97 52.06 4,464.82 4,347.51 N 4,262.50 E 1116.39 0.46 8459.62 66.66 52.27 4,502.14 4,400.95 N 4,331.31 E 1120.70 0.39 8553.48 66.76 52.13 4,539.25 4,453.79 N 4,399.43 E 1124.91 0.17 8648.03 66.88 50.93 4,576.47 4,507.86 N 4,467.48 E 1130.17 1.17 8742.02 66.82 49.83 4,613.42 4,562.97 N 4,534.05 E 1137.13 1.08 8836.80 66.82 48.91 4,650.73 4,619.70 N 4,600.17 E 1145.68 0.89 8930.85 66.78 50.56 4,687.78 4,675.57 N 4,666.13 E 1153.61 1.61 9026.05 66.75 51.24 4,725.34 4,730.74 N 4,734.02 E 1159.87 0.66 9119.64 66.81 52.29 4,762.24 4,783.97 N 4,801.58 E 1164.72 1.03 9213.88 66.71 51.72 4,799.42 4,837.28 N 4,869.82 E 1169.25 0.57 9308.74 66.79 51.57 4,836.87 4,891.36 N 4,938.17 E 1174.35 0.17 9402.78 66.77 52.33 4,873.95 4,944.63 N 5,006.22 E 1178.95 0.74 9497.26 66.79 51.76 4,911.20 4,998.03 N 5,074.68 E 1183.42 0.55 9591.75 66.72 51.92 4,948.49 5,051.67 N 5,142.95 E 1188.21 0.17 9686.09 66.74 51.86 4,985.76 5,105.16 N 5,211.14 E 1192.91 0.06 9779.88 66.69 51.71 5,022.83 5,158.45 N 5,278.83 E 1197.74 0.16 9874.95 66.61 50.83 5,060.51 5,213.06 N 5,346.92 E 1203.42 0.85 9969.46 66.32 49.56 5,098.25 5,268.53 N 5,413.48 E 1210.68 1.27 10064.16 67.78 49.07 5,135.18 5,325.38 N 5,479.61 E 1219.32 1.61 10157.71 67.27 48.49 5,170.94 5,382.34 N 5,544.63 E 1228.68 0.79 10252.37 67.12 48.97 5,207.63 5,439.90 N 5,610.21 E 1238.21 0.49 10347.03 67.37 50.97 5,244.25 5,496.04 N 5,677.05 E 1245.86 1.97 10441.03 67.49 52.78 5,280.33 5,549.62 N 5,745.33 E 1250.59 1.78 INSITE V8.0.20 Page 3Job No:AK-XX-0900966762 Well Name:CD3-130 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10535.67 68.00 54.67 5,316.18 5,601.44 N 5,815.94 E 1252.54 1.93 10629.43 68.55 55.28 5,350.88 5,651.43 N 5,887.27 E 1252.58 0.84 10724.10 68.57 54.10 5,385.49 5,702.36 N 5,959.17 E 1253.05 1.16 10818.37 68.88 53.26 5,419.69 5,754.39 N 6,029.95 E 1255.08 0.89 10912.78 69.47 51.94 5,453.26 5,807.99 N 6,100.05 E 1258.77 1.45 11007.74 70.06 51.78 5,486.10 5,863.01 N 6,170.13 E 1263.65 0.64 11101.53 69.97 51.87 5,518.16 5,917.49 N 6,239.42 E 1268.54 0.13 11195.95 70.88 50.27 5,549.79 5,973.39 N 6,308.62 E 1274.64 1.86 11290.93 70.55 50.16 5,581.16 6,030.76 N 6,377.51 E 1282.12 0.36 11384.87 70.84 50.04 5,612.22 6,087.63 N 6,445.52 E 1289.69 0.33 11479.42 70.95 49.71 5,643.16 6,145.21 N 6,513.84 E 1297.67 0.35 11573.10 71.03 49.91 5,673.68 6,202.36 N 6,581.50 E 1305.68 0.22 11668.92 71.69 50.04 5,704.31 6,260.76 N 6,651.02 E 1313.63 0.70 11762.21 71.41 49.94 5,733.83 6,317.65 N 6,718.80 E 1321.36 0.32 11857.35 71.27 50.73 5,764.27 6,375.19 N 6,788.19 E 1328.69 0.80 11950.71 71.88 50.21 5,793.78 6,431.56 N 6,856.51 E 1335.69 0.84 12045.73 72.48 50.38 5,822.86 6,489.35 N 6,926.10 E 1343.11 0.65 12139.47 71.94 50.70 5,851.50 6,546.08 N 6,995.02 E 1350.05 0.66 12234.00 71.89 48.55 5,880.84 6,604.28 N 7,063.47 E 1358.47 2.16 12328.96 71.63 47.37 5,910.57 6,664.68 N 7,130.45 E 1369.52 1.21 12422.95 71.86 47.27 5,940.01 6,725.19 N 7,196.07 E 1381.45 0.26 12516.72 71.78 46.93 5,969.27 6,785.83 N 7,261.33 E 1393.69 0.35 12611.42 71.02 46.15 5,999.47 6,847.57 N 7,326.48 E 1406.90 1.12 12705.71 71.65 46.96 6,029.65 6,908.99 N 7,391.33 E 1420.01 1.05 12800.93 72.07 45.30 6,059.30 6,971.70 N 7,456.56 E 1433.97 1.71 12894.81 72.30 42.33 6,088.02 7,036.19 N 7,518.43 E 1451.30 3.02 12988.85 73.05 38.28 6,116.04 7,104.64 N 7,576.48 E 1474.08 4.19 13083.83 72.57 34.38 6,144.12 7,177.72 N 7,630.23 E 1503.11 3.96 13178.07 71.24 30.74 6,173.40 7,253.19 N 7,678.44 E 1537.29 3.93 13271.12 70.65 27.65 6,203.78 7,329.96 N 7,721.34 E 1575.56 3.20 13366.63 70.34 25.46 6,235.68 7,410.48 N 7,761.58 E 1618.44 2.19 13459.98 70.21 23.40 6,267.19 7,490.48 N 7,797.92 E 1663.13 2.08 13554.94 69.58 21.16 6,299.83 7,572.99 N 7,831.73 E 1711.32 2.31 13649.51 69.11 17.88 6,333.20 7,656.38 N 7,861.30 E 1762.67 3.28 13742.82 69.67 14.32 6,366.05 7,740.28 N 7,885.51 E 1817.51 3.62 13837.83 69.45 11.47 6,399.24 7,827.05 N 7,905.38 E 1877.20 2.82 13932.61 70.22 9.44 6,431.91 7,914.54 N 7,921.52 E 1939.60 2.17 14026.68 71.71 8.68 6,462.59 8,002.35 N 7,935.52 E 2003.51 1.76 14120.90 71.24 8.03 6,492.53 8,090.74 N 7,948.50 E 2068.46 0.82 14216.13 72.18 9.10 6,522.42 8,180.15 N 7,961.97 E 2133.98 1.45 14309.77 74.04 9.40 6,549.62 8,268.58 N 7,976.37 E 2198.15 2.01 14404.81 74.57 8.03 6,575.33 8,359.01 N 7,990.23 E 2264.29 1.50 14497.87 74.54 4.02 6,600.12 8,448.20 N 7,999.65 E 2331.94 4.15 14593.40 74.71 1.42 6,625.46 8,540.20 N 8,004.02 E 2404.80 2.63 14686.02 74.34 0.08 6,650.17 8,629.45 N 8,005.18 E 2477.24 1.45 INSITE V8.0.20 Page 4Job No:AK-XX-0900966762 Well Name:CD3-130 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14781.94 73.97 358.63 6,676.36 8,721.71 N 8,004.15 E 2553.41 1.50 14876.10 74.34 356.42 6,702.07 8,812.21 N 8,000.23 E 2629.78 2.29 14970.72 77.01 355.58 6,725.48 8,903.65 N 7,993.84 E 2708.36 2.95 15064.14 79.73 354.81 6,744.31 8,994.82 N 7,986.17 E 2787.44 3.02 15158.59 79.56 352.00 6,761.29 9,087.11 N 7,975.50 E 2869.16 2.93 15252.77 79.73 350.02 6,778.22 9,178.61 N 7,961.02 E 2952.41 2.08 15346.80 80.19 347.89 6,794.62 9,269.48 N 7,943.28 E 3037.02 2.28 15416.73 80.08 346.82 6,806.60 9,336.71 N 7,928.20 E 3100.74 1.52 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 325.00 degrees (Grid) - A total correction of 19.06 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 15,416.73 feet is 12,248.69 feet along 40.34 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.0.20 Page 5Job No:AK-XX-0900966762 Well Name:CD3-130 Survey Report WELL INFORMATION Created On : Mar 25 2014 Customer :ConocoPhillips Alaska, Inc. Well Name :CD3-130 PB1 Job Number :AK-XX-0900966762 Platform :Doyon 19 Field Name :Western North Slope Country :USA Survey Report Survey dataSURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 36.62 0.00 0.00 36.62 0.00 N 0.00 E 0.00 0.00 116.71 0.13 154.32 116.71 0.08 S 0.04 E -0.09 0.16 174.06 0.20 113.61 174.06 0.18 S 0.16 E -0.24 0.23 265.12 2.21 334.14 265.10 1.34 N 0.46 W 1.36 2.60 358.32 3.07 336.64 358.20 5.24 N 2.23 W 5.58 0.93 450.68 3.42 340.45 450.41 10.11 N 4.14 W 10.66 0.44 542.74 4.16 337.25 542.27 15.78 N 6.35 W 16.56 0.84 635.62 5.94 338.90 634.78 23.37 N 9.38 W 24.52 1.92 727.71 7.28 342.70 726.26 33.39 N 12.83 W 34.71 1.53 820.83 8.92 346.36 818.45 46.04 N 16.29 W 47.05 1.85 913.55 12.62 349.44 909.52 62.98 N 19.84 W 62.97 4.04 1008.38 17.61 353.18 1,001.04 87.43 N 23.45 W 85.06 5.36 1056.20 17.64 354.61 1,046.62 101.82 N 24.98 W 97.74 0.91 1100.44 17.67 354.60 1,088.78 115.18 N 26.25 W 109.41 0.07 1194.41 20.95 353.06 1,177.45 146.07 N 29.62 W 136.64 3.53 1289.24 23.10 353.09 1,265.35 181.37 N 33.91 W 168.01 2.27 1383.67 28.68 351.79 1,350.27 222.22 N 39.38 W 204.61 5.94 1424.33 30.07 349.91 1,385.70 241.90 N 42.55 W 222.56 4.10 1519.32 32.81 353.39 1,466.75 290.91 N 49.69 W 266.80 3.46 1612.45 35.68 359.70 1,543.75 343.16 N 52.74 W 311.35 4.90 1706.53 38.36 6.38 1,618.89 399.64 N 49.63 W 355.84 5.13 1751.55 40.07 8.60 1,653.77 427.86 N 45.91 W 376.81 4.91 1801.15 40.30 9.88 1,691.66 459.44 N 40.77 W 399.74 1.73 1895.81 41.80 16.42 1,763.08 519.89 N 26.60 W 441.13 4.80 1990.70 42.87 21.04 1,833.24 580.37 N 6.06 W 478.89 3.47 2085.47 42.77 27.25 1,902.79 639.09 N 20.26 E 511.90 4.45 2179.35 44.44 31.19 1,970.78 695.56 N 51.88 E 540.01 3.40 2273.59 48.52 32.77 2,035.66 753.49 N 88.09 E 566.70 4.50 2368.48 53.76 33.86 2,095.17 815.20 N 128.68 E 593.97 5.59 2413.97 58.09 34.95 2,120.66 846.28 N 149.97 E 607.21 9.72 2463.13 59.08 35.36 2,146.28 880.58 N 174.13 E 621.45 2.14 INSITE V8.0.20 Page 1Job No:AK-XX-0900966762 Well Name:CD3-130 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2510.46 59.31 35.83 2,170.52 913.63 N 197.79 E 634.96 0.98 2556.61 59.46 37.55 2,194.02 945.48 N 221.52 E 647.43 3.22 2651.75 60.95 40.65 2,241.30 1,009.53 N 273.59 E 670.03 3.23 2745.27 61.76 44.49 2,286.15 1,069.95 N 329.11 E 687.68 3.71 2838.90 63.22 48.39 2,329.41 1,127.14 N 389.28 E 700.02 4.01 2937.08 65.17 50.31 2,372.15 1,184.71 N 456.34 E 708.71 2.65 3028.20 66.99 50.87 2,409.09 1,237.58 N 520.69 E 715.11 2.07 3095.78 66.83 51.26 2,435.60 1,276.65 N 569.05 E 719.38 0.58 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 325.00 degrees (Grid) - A total correction of 19.06 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 3,095.78 feet is 1,397.73 feet along 24.02 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.0.20 Page 2Job No:AK-XX-0900966762 Well Name:CD3-130 PB1 Survey Report