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Home My WebLink About214-0181. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Scale Inhibition Treatment ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,492 feet None feet true vertical 6,977 feet None feet Effective Depth measured 17,492 feet 10539, 10636, 10761 feet true vertical 6,977 feet 6760, 6806, 6863 feet Perforation depth Measured depth 10563-10583' feet Measured depth 14500-14520', 15450-15470', 16000-16020'feet True Vertical depth 6771-6781' feet True Vertical depth 7018-7017', 7037-7037', 7032-7031'feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 10774' MD 6869' TVD Packers and SSSV (type, measured and true vertical depth)Packer: Baker Premier Packer 10539' MD 6760' TVD Packer: Baker Premier Packer 10636' MD 6806' TVD Packer: HRD-E ZXP Liner Top Packer 10761' MD 6836' TVD SSSV- Camco TRMAXX-5E 2116' MD 2012' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Mark Shulman Contact Name:Mark Shulman Authorized Title:Sr. Production Engineer Contact Email:mark.shulman@cop.com Contact Phone:(907) 263-3782 Perforation depth (re-perf) 2. Operator Name Senior Engineer:Senior Res. Engineer: CollapseBurst 2476 6953 6977 Casing Conductor 16" 9-5/8" 7" 4-1/2" Length 78' 2709' 10961' Surface Intermediate Liner Authorized Signature with date: Authorized Name: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 5. Permit to Drill Number: 1964 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 265 Size Colville River Field/Fiord Nechelik Gas-Mcf measuredPlugs Junk measured See Attachment 6726' 10995-17487' MD 1118 CRU CD3-316B STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-018 50-103-20559-03-00 N/A P.O. Box 100360, Anchorage, Alaska 99510 181 3. Address: 4. Well Class Before Work: 150 Representative Daily Average Production or Injection Data 2401221 Casing Pressure Tubing Pressure ADL 364471, ADL 372105, ADL 372104 1264 684 Oil-Bbl measured true vertical Packer 17487 WINJ WAG 2510 Water-Bbl MD 114 2745 10995 TVD 114 t Fra O g g g l Ot g 6. A J PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:48 am, Mar 02, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.03.01 16:36:13 -09'00' Alpine Oil DSR-3/2/21 SFD 3/2/2021 RBDMS HEW 3/2/2021 VTL 3/3/21 SFD 3/2/2021 ! !" " "# "$" " !## % " & ! '(% " ( #)&" (' *(' "" !+" ! +" &% ##' &% #,!#& (- !# ! !&*& .//0123456107839:6143107839: CD3-316B Scale Inhibition Treatment 2/2/21 – 2/3/21 Scale Inhibitor Squeeze Job pumped from 1200 hrs. on 2/2/21 to 1300 hrs. on 2/3/21. LRS = Little Red Services x Initial pressure TBG/IA/OA – 1336/1355/692 x LRS pumped 237 bbls WAW5206/Diesel pre-flush at 2.8 - 4 bpm x LRS pumped 237 bbls Seawater/SCW3001 scale inhibitor main treatment at 3-3.5 bpm x ACF pumped 2048 bbls crude/M209 over-flush at 1.8-3.5 bpm, TBG/IA/OA – 1889/1283/702 Interval treated: 10,995’ – 17,487’ Packer: Baker Premier Packer, 10540' MD, 6760' TVD Packer: Baker Premier Packer, 10636' MD, 6806' TVD Packer: Baker HRD-E ZXP Liner Top Packer, 10761' MD, 6863' TVD SSSV: Camco TRMAXX-5E, 2116' MD, 2013' TVD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD3-316B haggea Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Add Perfs 2/4/2021 CD3-316Brogerba Casing Strings Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.4 Set Depth (ftKB) 10,995.2 Set Depth (TVD)… 6,953.3 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-M Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,761.0 Set Depth (ftKB) 17,486.6 Set Depth (TVD)… 6,977.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 10,761.0 6,863.0 63.93 PACKER BAKER "HRD-E" ZXP LINER TOP PACKER 3.875 10,787.5 6,874.6 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.7 64.59 BUSHING CROSS OVER BUSHING (4.5" H521 x 4.5" IBT) 4.000 11,811.8 7,057.393.72 FRAC PORT HES FRAC SLEEVE - MILLED TO 2.702.700 12,756.7 7,030.1 90.14 FRAC PORT HES FRAC SLEEVE - MILLED TO 2.70 2.700 13,697.8 7,024.890.27FRAC PORT HES FRAC SLEEVE - MILLED TO 2.702.700 14,640.7 7,015.5 91.01 FRAC PORT HES FRAC SLEEVE - MILLED TO 2.70 2.700 15,572.2 7,039.3 89.48 FRAC PORT HES FRAC SLEEVE- MILLED TO 2.70" 3/20/2020 2.700 16,514.6 7,013.2 91.36 FRAC PORT HES FRAC SLEEVE- MILLED TO 2.70" 3/20/2020 2.700 17,457.6 6,979.0 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 17,464.1 6,978.7 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 17,470.5 6,978.3 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 17,483.16,977.7 93.04 REAMER BAKER 5.75" EZ REAM w/ float 3.890 Tubing Strings Tubing Description TUBING 4 1/2x3 1/2 @119.5 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.6 Set Depth (ft… 10,774.1 Set Depth (TVD) (… 6,868.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 31.631.60.00 HANGER FMC TUBING HANGER 4.000 119.7 119.7 0.61 XO Reducing XO - 4.5" IBT (B) x 3.5" EUE (P)2.992 2,115.9 2,012.5 35.68 SAVETY VLV CAMCO TRMAXX-5E w/ 2.812" X profile 2.812 10,512.16,746.7 60.68 GAUGE 3.5" NDPG (SOLID GAUGE MANDREL)2.992 10,539.5 6,760.1 60.85 PACKER BAKER PREMIER PACKER 2.880 10,557.7 6,769.0 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w/ 28' CARBIDE BLAST RINGS 2.992 10,619.9 6,798.6 61.98 SLEEVE - OPEN (CMD) PETROQUIP SLIDING SLEEVE **DOWN TO OPEN** (SLEEVE CLOSED 2/1/21) 2.813 10,635.9 6,806.1 62.17 PACKER BAKER PREMIER PACKER 2.870 10,687.2 6,829.8 62.76 NIPPLE HES XN NIPPLE No-Go 2.750 10,758.1 6,861.7 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 10,759.1 6,862.2 63.89 SOS SHEAR SCREW BODY (Located 1.55' up Fully Located) 3.000 10,773.1 6,868.3 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 10,563.010,583.06,771.5 6,781.1 4/20/2014 6.0 IPERF Peforate Kup C 11,811.8 11,814.2 7,057.3 7,057.2 4/19/2014 PERFP FRAC PORT 12,756.7 12,759.2 7,030.1 7,030.1 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.8 7,024.7 4/19/2014 PERFP FRAC PORT 14,500.014,520.0 7,017.9 7,017.5 2/4/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 14,640.7 14,643.1 7,015.5 7,015.5 4/19/2014 PERFP FRAC PORT 15,450.0 15,470.0 7,036.6 7,037.3 2/4/2021 6.0 APERF 20' of holes, 6 SPF, 60deg- 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 15,572.1 15,574.6 7,039.3 7,039.3 4/19/2014 PERFP FRAC PORT 16,000.016,020.0 7,031.6 7,030.7 2/3/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 16,514.6 16,517.1 7,013.2 7,013.2 4/19/2014 PERFP FRAC PORT 17,457.6 17,460.2 6,979.0 6,978.9 4/19/2014 PERFP FRAC PORT 17,464.1 17,466.8 6,978.7 6,978.5 4/19/2014 PERFP FRAC PORT Frac Summary Start Date 2/14/2015 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 2/14/2014 Top Depth (ftKB) 11,811.0 Btm (ftKB) 17,466.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) CD3-316B, 2/4/2021 10:04:50 AM Vertical schematic (actual) LINER; 10,761.0-17,486.6 PERFP; 17,464.1-17,466.8 PERFP; 17,457.6-17,460.2 PERFP; 16,514.6-16,517.1 APERF; 16,000.0-16,020.0 PERFP; 15,572.1-15,574.6 APERF; 15,450.0-15,470.0 PERFP; 14,640.7-14,643.1 FRAC; 11,811.0 APERF; 14,500.0-14,520.0 PERFP; 13,697.8-13,700.2 PERFP; 12,756.7-12,759.2 PERFP; 11,811.8-11,814.2 INTERMEDIATE; 34.5-10,995.2 MULE SHOE; 10,773.1 SOS; 10,759.1 NIPPLE; 10,758.1 NIPPLE; 10,687.2 PACKER; 10,635.9 SLEEVE - OPEN (CMD); 10,619.9 IPERF; 10,563.0-10,583.0 PACKER; 10,539.5 Intermediate Casing Cement; 10,063.0 ftKB GAUGE; 10,512.0 GAS LIFT; 10,453.1 GAS LIFT; 8,407.8 Intermediate Casing Cement; 5,155.0 ftKB GAS LIFT; 4,429.1 SURFACE; 36.3-2,744.8 VALVE; 2,125.4 SAVETY VLV; 2,115.9 CONDUCTOR Insulated; 36.0- 114.0 HANGER; 31.6 WNS PROD KB-Grd (ft) 36.63 Rig Release Date 2/12/2008 CD3-316B ... TD Act Btm (ftKB) 17,492.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032055903 Wellbore Status PROD Max Angle & MD Incl (°) 94.04 MD (ftKB) 11,722.21 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: TRDP Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 10,761.0 11,128.0 6,863.0 6,990.7 Cement Plug Pump from cementers and fill cmt line with 1.5 bbl of 12.5 ppg Mud Push II and pressure test lines to 3,100 psi. Bleed off and pump remaining 18.5 bbl of MPII at 3.5 bpm, 690 psi. Drop Nerf wiper ball. Pump 63 bbl of 17.0 ppg "G" cmt + additives (Yld= 1 ft³ per sk)(353 Sks) at 2- 4.8 bpm, 20-150 psi. Pump 6 bbl of 12.5 ppg MPII at 5.5 bpm, 70 psi. Shut down cementers. Rig displaced with 65.9 bbl of 10.9 ppg LSND at 4.5 bpm, 900 psi. Had full returns thru out job. CIP @ 15:41 hrs 4/4/2014 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 4,429.13,426.1CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,092.03/7/2015 2 8,407.8 5,606.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,120.0 3/7/2015 3 10,453.1 6,717.9 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/7/2015 Notes: General & Safety End Date Annotation 3/27/2014 NOTE: 7" 26#, L80, BTC-M from 35.29' to 9,983.36' MD 3/27/2014 NOTE: 7" 26#, L80, BTC-M from 10,860.35' to 10,993.03' MD 3/27/2014 NOTE: 7" 29#, TN110 SS, HYD 563, 6.125" S.D. from 9,983.36' to 10,860.50' MD 3/6/2014 NOTE: WELL SIDETRACKED TO "B" 3/6/2014NOTE: INTERMEDIATE CASING STRING HAS A TN-110SS TAIL (top 9983.36’ MD). CD3-316B, 2/4/2021 10:04:53 AM Vertical schematic (actual) LINER; 10,761.0-17,486.6 PERFP; 17,464.1-17,466.8 PERFP; 17,457.6-17,460.2 PERFP; 16,514.6-16,517.1 APERF; 16,000.0-16,020.0 PERFP; 15,572.1-15,574.6 APERF; 15,450.0-15,470.0 PERFP; 14,640.7-14,643.1 FRAC; 11,811.0 APERF; 14,500.0-14,520.0 PERFP; 13,697.8-13,700.2 PERFP; 12,756.7-12,759.2 PERFP; 11,811.8-11,814.2 INTERMEDIATE; 34.5-10,995.2 MULE SHOE; 10,773.1 SOS; 10,759.1 NIPPLE; 10,758.1 NIPPLE; 10,687.2 PACKER; 10,635.9 SLEEVE - OPEN (CMD); 10,619.9 IPERF; 10,563.0-10,583.0 PACKER; 10,539.5 Intermediate Casing Cement; 10,063.0 ftKB GAUGE; 10,512.0 GAS LIFT; 10,453.1 GAS LIFT; 8,407.8 Intermediate Casing Cement; 5,155.0 ftKB GAS LIFT; 4,429.1 SURFACE; 36.3-2,744.8 VALVE; 2,125.4 SAVETY VLV; 2,115.9 CONDUCTOR Insulated; 36.0- 114.0 HANGER; 31.6 WNS PROD CD3-316B ... WELLNAME WELLBORE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 214-018 50-103-20559-03-00 ADL 364471, 372105, 372104 CRU CD3-316B None Colville River Field/Fiord Oil Pool 17492 6977 10761 None 17483 6978 see attached see attached Conductor 78' 16" 114 114 Surface 2709' 9.625" 2745 2476 Intermediate 10961' 7" 10995 6953 Liner 6726' 4.5" 17487 6977 11812 - 17467 7057 - 6979 4.5"x3.5" L-80 10774 6869 see attached see attached 10774 6869 10995' - 17487' MD Please see attached summary 191 433 151 992 251 180 221 225 769 237 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ By Samantha Carlisle at 8:10 am, Apr 10, 2020 DSR-4/13/19 SFD 4/10/2020 VTL 4/14/20 RBDMS HEW 4/10/2020 CD3-316B Scale Inhibition Treatment 3/3/20 – 3/4/20 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 1200 hrs on 3/3/20 to 0230 hrs on 3/4/20. LRS = Little Red Services - Initial pressure TBG/IA/OA - 750/615/590 - LRS pumped 237 bbls Diesel/M209/WAW5206 pre-flush at 4.0 bpm, TBG/IA/OA - 1000/610/610 - LRS pumped 237 bbls 70/30 EG/Seawater and SCW3001WC scale inhibitor main treatment at 4.0 bpm, TBG/IA/OA – 1000/625/640 - LRS pumped 2040 bbls Dead Crude/M209 over-flush at 3.0 – 4.0 bpm, TBG/IA/OA – 1600/610/610 Interval treated: 10,995’ – 17,487’ Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 10540' MD, 6760' TVD Packer: Baker Premier Packer, 10636' MD, 6806' TVD Packer: Baker HRD-E ZXP Liner Top Packer, 10761' MD, 6863' TVD SSSV: Camco TRMAXX-5E, 2116' MD, 2013' TVD Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: �Y/ AOGCC '• ATTN: Natural Resources Technician II :-` Alaska Oil &Gas Conservation Commision 333 W. 7th Ave, Suite 100 ... Anchorage, AK 99501 21 4018 TRANSMITTALDATE TRANSMITTAL# RIME= l6VELL NAME ® r r50-103-20568-00 API # rrrrr SERVICE ORDER # .r rrr.. FIELD NAME • COLVILLE RIVER® SERVICE DESCRIPTION DELIVERABLE ® DESCRIPTION ��• DATA TYPE ---- ��-0 Color DATE LOGGED Prints CD's COLVILLE RIVER - r-- • ® --_-_- Print Signature Please return via courier or sign/scan and email a copy to ATransmittal Receipt signature confirms that a package (box, Venvelope, etc.) has been received and the contents of the lI "` YYY f package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this lumberger and CPAI, point. STATE OF ALASKA AL4IkA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 214-018 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20559-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364471, 372105, 372104 CRU CD3-316B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17492 feet Plugs measured 10761 feet true vertical 6977 feet Junk measured None feet Effective Depth measured 17483 feet Packer measured 10540, 10636, 10761 feet true vertical 6978 feet true vertical 6760, 6806, 6863 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2709' 9.625" 2745' 2476' Intermediate 10961' 7" 10995' 6953' Production Liner 6726' 4.5" 17487' 6977' RECEIVED Perforation depth Measured Depth: 11812- 17467 feet(treated)and 10563- 10583 feet(not treated) MAR 0 3 2017 True Vertical Depth: 7057-6979 feet(treated)and 6772-6781 feet(not treated) AOGCC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 10774' MD, 6869'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 10540' MD, 6760'TVD Packer: Baker Premier Packer, 10636' MD, 6806'TVD Packer: Baker HRD-E ZXP Liner Top Packer, 10761' MD, 6863'TVD SSSV: Camco TRMAXX-5E, 2116' MD, 2013'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10995'- 17487' MD SCANNED APR 1 7 20 j U Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 149 47 240 957 322 Subsequent to operation: 209 304 257 926 291 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I Exploratory❑ DevelopmentL Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil CI Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett Email Kavlie.B.Plunkett(ct7cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature iaL Phone 265-6450 Date �/2./20(-7 1/n- 312g11 Form 10-404 Revised 5/2015 RBDWI S \J/ (, r, - (r Li)re Submit Original Only i, 2Yf7 • • r CD3-316B Scale Inhibition Treatment 2/2/17 Hybrid Scale Inhibitor Squeeze Job pumped from 09:30 hrs on 2/2/17 to 03:30 hrs on 2/3/17. LRS= Little Red Services - Initial pressure TBG/IA/OA-575/989/485 - LRS pumped 290 bbls Diesel/M209/WAW5206 pre-flush at 2.5 bpm,TBG/IA/OA-0/1510/505 - LRS pumped 290 bbls Seawater and SCW3001WC scale inhibitor main treatment at 2.5 bpm, TBG/IA/OA—0/1608/470 - LRS pumped 2303 bbls Dead Crude/M209 over-flush at 3 -4 bpm,TBG/IA/OA—463/1637/503 Interval treated: 10,995'—17,487' STATE OF ALASKA AlkA OIL AND GAS CONSERVATION COM . ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment E 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 214-018 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20559-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364471, 372105, 372104 CRU CD3-316B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17492 feet Plugs measured 10761 feet true vertical 6977 feet Junk measured None feet Effective Depth measured 17483 feet Packer measured 10540, 10636, 10761 feet true vertical 6978 feet true vertical 6760, 6806, 6863 feet Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2709' 9.625" 2745' 2476' Intermediate 10961' 7" 10995' 6953' Production RECEIVED Liner 6726' 4.5" 17487' 6977' APR 01 2016 Perforation depth Measured Depth: 11812- 17467 feet(treated) and 10563- 10583 feet(not treated) OGCC Q(� f�(� True Vertical Depth: 7057-6979 feet(treated) and 6772-6781 feet(not treated) ° Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 10774' MD, 6869'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 10540' MD, 6760'TVD Packer: Baker Premier Packer, 10636' MD, 6806'TVD Packer: Baker HRD-E ZXP Liner Top Packer, 10761' MD, 6863'TVD SSSV: Camco TRMAXX-5E, 2116' MD, 2013'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10995'- 17492' MD W) A?K 2 I. 20 It, SCO Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 292 520 237 987 310 Subsequent to operation: 318 547 218 957 337 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerry_C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature ;AA.L.4,144.4.--- Phone 265-6579 Date (/ (I I I(, Form 10-404 Revised 5/201 ,-/L 4l/ZC�k RBDMS L-t--- APR 0 4 2016 Submit Original Only mil/P-p.45 • • CD3-3166 Scale Inhibition Treatment 3/4/16—3/5/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 01:00 on 3/4/16 to 00:25 on 3/5/16. LRS = Little Red Services - Initial pressure TBG/IA/OA- 545/900/450 - LRS pumped 290 bbls Diesel/M209/WAW5206 pre-flush at 4.1 bpm—4.5 bpm,TBG/IA/OA- 27/857/416 - LRS pumped 290 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 3.9 - 4.1 bpm, TBG/IA/OA—37/874/416 - LRS pumped 2303 bbls Dead Crude/M209 over-flush at 3 -4 bpm,TBG/IA/OA—640/824/443 Intervals treated: 10,995'—17,492' F WNS PROD • CD3-316B e ConocoPhillips Well Attributes Max Angle&MD TD Alaska.inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) -Act Btm(ftKB) Concenoltdikpy 501032055903 FIORD KUPARUK PROD 94.04 11,722.21 17,492.0 ... �u Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date CD3-3168,311920158:11.29 AM SSSV:TRDP Last WO: 36.63 2/12/2008 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:FRAC SLV ID'S,GLV C/O hipshkf 3/19/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(ND)...Wt/Len(I...Grade Top Thread HANGER;31.6-KIWI "; SURFACE 95/8 8.835 36.3 2,744.8 2,476.1 40.00 L-80 MBTC 11Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1:1 DT INTERMEDIATE 7 6.276 34.4 10,995.2 6,953.3 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 10,761.0. 17,486.6 6,977.5 12.60 L-80 IBT Lim >a Liner Details Nominal ID ,-.A.-,°-1 I".• Top(968) Top(ND)(ftKB) Top Inel CI Item Des Corn (in) CONDUCTOR Imolated136.4 J - 10,761.0 6,863.0 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 114.0 10,787.5 6,874.6 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.7 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x4.5"IBT) 4.000 11,811.8 7,057.3 93.72 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 12,756.7' 7,030.1 90.14 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 SAVETY VLV;2.115.9 -CMI 13,697.8 7,024.8 90.27 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 VALVE;2.125.4 ; 14,640.7 7,015.5 91.01 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 15,572.2 7,039.3 89.48 FRAC PORT HES FRAC SLEEVE 1.625 16,514.6 7,013.2 91.36 FRAC PORT HES FRAC SLEEVE 1.565 17,457.6 6,979.0 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 SURFACE:36.3-2.744.8- 17,464.1 6,978.7 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 GAS LIFT;4,429.1 N. 17,470.5 6,978.3 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 17,483.1 6,977.7 93.04 REAMER BAKER 5.75"EZ REAM w/float 3.890 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection GAS LIFT;8,407.8 IMI. TUBING 4 1/2x3 1/2 31/2 2.992 31.6 10,774.1 6,868.7 9.30 L-80 EUE @119.5 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.6 31.6' 0.00 HANGER -FMC TUBING HANGER 4.000 GAS LIFT;10,453.1 119.T 119.7 0.61 XO Reducing XO-4.5"IBT(B)x 3.5"EUE(P) 2.992 2,115.9 2,012.5' 35.68 SAVETY VLV CAMCO TRMAXX-5E w/2.812"X profile 2.812 GAUGE;10,5120 �� 10,512.1 6,746.7 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 10,539.5 6,760.1' 60.85 PACKER BAKER PREMIER PACKER 2.880 PACKER;10,539.5 _ 10,557.7 6,769.0 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w/28'CARBIDE BLAST RINGS 2.992 (PERF;10,563.0-105830-t • f': 10,619.9 6,798.6 61.98 SLEEVE PETROQUIP SLIDING SLEEVE CLOSED 1 30 15 2.813 .� 10,635.9 6,806.1' 62.17 PACKER BAKER PREMIER PACKER 2.870 SLEEVE;10,619.9 - - - 10,687.2 6,829.8 62.76 NIPPLE HES XN NIPPLE No-Go 2.750 PACKER;10,635.910,758.1 6,861.7 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 10,759.1' 6,862.2' 63.89:SOS 'SHEAR SCREW BODY(Located 1.55 up Fully Located) 3.000 NIPPLE;10,687.21.5-7,k.; 10,773.1 6,868.3' 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 NIPPLE;14758.1 Perforations&Slots SOS;10,759.1 Shot Dens MULE SHOE;10,773.1 Top(TVD) Btm(TVD) )shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,563.0 10,583.0 6,771.5 6,781.1 4/20/2014 6.0 IPERF Peforate Kup C 11,811.8 11,814.2 7,057.3 7,057.2 4/19/2014 PERFP FRAC PORT 12,756.7 12,759.2 7,030.1 7,030.1 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.8 7,024.7 4/19/2014 PERFP FRAC PORT :•:' ..• ., . 14,640.7- 14,643.1 7,015.5 7,015.5 4/19/2014 PERFP FRAC PORT INTERMEDIATE;34.5-10,995.2 15,572.1 15,574.6 7,039.3 7,039.3 4/19/2014 PERFP FRAC PORT 16,514.6 16,517.1 7,013.2 7,013.2 4/19/2014 PERFP FRAC PORT PERFP;11,811.8-11,814.2 Q 17,457.6 17,460.2 6,979.0 6,978.9 4/19/2014 PERFP FRAC PORT 17,464.1 17,466.8 6,978.7 6,978.5 4/19/2014 PERFP FRAC PORT Stimulations&Treatments PERFP;12,756.7-12,759.2 EU Min Top Mae Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) )ftKB) Type Date Com 11,811.0 17,466.0 7,057.4 6,978.6 FRAC 2/14/2015 PUMPED 585,000#OF 16-20 CARBOLITE PERFP;13,697.613,700.2 THROUGH 6 SLEEVES Cement Squeezes FRAC;11,811.0 Top(ND) Btm IND) PERFP;14,640.7-14,643.1 Top(ftKB) Btm(ft(B) (ftKB) (ftKB) Des Start Date Corn 10,761.0 11,128.0 6,863.0 6,990.7 Cement Plug 4/4/2014 Plugged back to cover problematic shales and kick off PERFP;15,572.1-15.574.6 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run PERFP;16,514.616,517.1 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 4,429.1 3,426.1 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,092.0 3/7/2015 2 8,407.8 5,606.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,120.0 3/7/2015 3 10,453.1 6,717.9 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/7/2015 PERFP;17,457.617,460.2 r Notes:General&Safety PERFP;17,464.1-17,466.8 End Date Annotation _ 3/6/2014 'NOTE: INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(top 9983.36'MD). 3/6/2014 NOTE:WELL SIDETRACKED TO"B" LINER;10,761.0-17,486.6 . u_ WNS PROD CD3-316B • ConocoPhillips Alaska.Inc. Cmocoti spi C D33160.3/192015 8:11:30 AM Vertical schematic(actual) Notes:General&Safety End Date Annotation 3/27/2014 NOTE. 7"296,TN110 SS,HYD 563,6.125"S.D.from 9,983.36'to 10,860.50'MD HANGER:31.6_ W 3/27/2014 NOTE: 7"26#,L80,BTC-M from 10,860.35'to 10,993.03'MD 3/27/2014 NOTE:7"266,L80,BTC-M from 3529'to 9,983.36'MD . --58.5 AY •CONDUCTOR Insulated',36 114.0 SAVETY VW;2.115.9 VALVE;2,125.4 SURFACE;36.3-2,744.5— A GAS LIFT;4,429.1 GAS LIFT;8,407.8 GAS LIFT;10,453.1 GAUGE;10,512.0 PACKER;10.539.5 •`• IPERF;10,563.0-10,563.0—, 1 ¶1 SLEEVE;10.619.9 PACKER;10,635.9 ,. NIPPLE;10,687.2 NIPPLE;10,758.1 SOS;10,759.1 MULE SHOE;10,773.1 { INTERMEDIATE;34.5-10,995.2— PERFP;11,811.8-11,814.2---- PERFP; 1,811.8-11,814.2 PERFP;12,756.7-12,759.2— PERFP; 2,756.7-12,759.2 PERFP;13,697.8-13,700.2 FRAC;11,811.0 PERFP;14,640.7-14,643.1 j 5 PERFP;15,572.1-15,574.6 1C PERFP;16,514.6-16,517.1 I I PERFP;17,457.6.17,460.2 , I PERFP;17,464.1-17,466.8 LINER;10,761.0-17,486.6 0 STATE OF ALASKA - AL/-OKA OIL AND GAS CONSERVATION COR iSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed' Abandon Repair w ellP conductor r P r Rug Perforations r Perforate r Other Alter CasingV Pull Tubingextension r Stimulate- Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 214-018 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20559-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364471, 372105, 372104 CRU CD3-316B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10 Field/Pool(s): Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary. Total Depth measured 17492 feet Plugs(measured) 10761 true vertical 6977 feet Junk(measured) None Effective Depth measured 17482 feet Packer(measured) 10540, 10636 true vertical 6977 feet (true vertical) 6760,6806 Casing Length Size MD TVD Burst Collapse CONDUCTOR II 78 16 114 114 1640 630 SURFACE 2709 15 2745 2476 5750 3090 INTERMEDIATE 10961 11 10995 6953 7240 5410 LINER 6726 5.75 17487 6977 8430 7500 Perforation depth: Measured depth: 10,563'-17,469' RECEIVED True Vertical Depth: 6,771'-6,979' , APR 2 3 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 10773 MD, 6868 TVD AcGCC Packers&SSSV(type,MD,and TVD) PACKER= BAKER PREMIER PACKER @ 10540 MD and 6760 TVD SSSV=CAMCO TRMAXX-5E @ 2116' MD and 2013 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MA" 1 8 20 5 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F.7 Service r Stratigraphic r 16 Well Status after work. Oil F Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-200 Contact MJ Loveland/Martin Walters Email n1878(aconocophillips.com Printed Name Martin Walters Title NSK Well Integrity Proj Supervisor Signature / a )7 vvGizfc Phone:659-7043 Date:04/22/15 >,rt— 5 )4115 RBDMS4-k APR 2 8 2015 . S? /.✓/`- Form 10-404 Revised 10/2012 Submit Original Only CD3-3168 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/16/15 Welders installed a 9"conductor extension with 16"62.5# .375 wall - H-40 04/20/15 T/I/O= 340/1142/40. Pumped 5.1 gallons of RG-2401 sealant into conductor. CD3-3168 DESCRIPTION OF WORK COMPLETED SUMMARY 2ty - o t' �j3. - 3 /4B RECEIVED ConocoPhillips EGFR 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 7th Avenue, Suite 100SUMO IA y 0 1 2015 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, /27/ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Con000Ph mmpE i-Ma k i 1a . Surface Casing by Conductor/Annulus Cernenn';., Corrosion inhibitor, Sealant Top-of; Report of Sundry Operations(10404) Alpine Field Date 4/23/2015 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 3/12/2015 CD3-130 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 I 4/20/2015 CD3-320 50103206670000 2130060 6" NA 6" NA 1.7 3/24/2015 • VOF T4, ��w\�� THE STATE Alaska Oil and Gas • • °fALASKA Conservation Commission Wei 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov SCOW APR 22015 MJ Loveland NSK Well Integrity Project Supervisor I f li,r)1 ConocoPhillips Alaska, Inc. l J� P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-316B Sundry Number: 315-200 Dear Ms. Loveland: 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, a4C4/— Daniel T. Seamount, Jr. Commissioner DATED this / r day of April, 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI:.,ION APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: conductor extension �' 2.Operator Name: 4 Current Well Class. 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. ' Exploratory r Development r. 214-018 ` 3 Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20559-03 • 7.If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CR V /G l.3 v 1w CD3- 3 141/1" Will planned perforations require spacing exception'? Yes r No F ✓ CRU-G93-361 B • 4 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 364471,372105,372104 • 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)• 17492. 6977 " 17482'• 6977' • 10761' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2709 15 2745' 2476' /'h INTERMEDIATE 10961 11 10995' 6953' RECEIVED LINER 6726 5.75 17487' 6977' PR 0 3 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft)• 10563-10583 4 6771-6781 3.5 L-80 10773 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER MD=10540 TVD=6760 ' PACKER-BAKER PREMIER PACKER MD=10636 TVD=6806 " SSSV-CAMCO TRNAXX-5E MD=2115.9'TVD=2012 • 12.Attachments: Description Summary of Proposal 7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p'• Service r 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil r P . Gas r WDSPL r Suspended r 16 Verbal Approval. Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to est of my knowledge. Contact: MJ Loveland/Martin Walters Email. n1878( conocophillips.com Printed Name MJJLLovel d Ti . NSK Well Integrity Proj Supervisor Signature .,•• Phone.659-7043 Date 0/ e . 1 ...5— _ orCommission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 315-2-00 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No 12K Subsequent Form Required. /(% —_ 4__C Il- APPROVED BY [' Approved by: "� COMMISSIONER THE COMMISSION Date: 47/5L1 i 1/1 if/go-Approved application Is valid tor 12 rryppth�� jthe date of approval.nfi6 �N—, Form 10-403(Revised 10/2II ORIGINAL r'� Submit Form and Attachments in Duplicat �/is RBDMS APR 1 8 2015 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 1, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-316B, PTD 214-018 conductor extension. Please contact me or Martin Walters at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Colville River Well CD3-316B (PTD 214-018) SUNDRY NOTICE 10-403 APPROVAL REQUEST April 1, 2015 This application for Sundry approval for Colville River Well CD3-316B is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 8". / With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • NS PROD CD3-316B ConocoPhillips Drilling Vii Attributes Max Angle&MD TD Alaska,Inc. Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Mtn(ftKB) r,,,,,,,1„,I 501032055903 FIORD KUPARUK PROD 94.04 11,722.21 17,492.0 a ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CO3-3166.31192015 8 11 29 AM SSSV:TRDP Last WO: 36.63 2/12/2008 Venal schemeln(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:FRAC SLV ID'S,GLV C/O hipshkf 3/19/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _..._.._......._.........................................._.............................._._CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread HANGER;31.6 SURFACE 95/8 8.835 36.3 2,744.8 2,476.1 40.00 L-80 MBTC - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread ' INTERMEDIATE 7 6.276 34.4 10,995.2 6,953.3 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...-Wt/Len(I...Grade Top Thread LINER 41/2 3.958 10,761.0 17,486.6 6,977.5 12.60 L-80 IBT analli.,",.",.,-.1,11",.111=11.. IL Liner Details Nominal ID '°.^�'0 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Dec Com (in) CONDUCTOR Insulated;35.0-J1 1 .> 10,761.0 6,863.0 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 114.0 I 1 r 10,787.5 6,874.6 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.7 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x 4.5"IBT) 4.000 • 11,811.8 7,057.3 93.72 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 I12,756.7 7,030.1 90.14 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 SAVETY VLV;2,115.9 r: 13,697.8 7,024.8 90.27 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 VALVE;2,125.4 i 14,640.7 7,015.5 91.01 FRAC PORT HES FRAC SLEEVE-MILLED TO 2.70 2.700 I 15,572.2 7,039.3 89.48 FRAC PORT HES FRAC SLEEVE 1.625 16,514.6 7,013.2 91.36 FRAC PORT HES FRAC SLEEVE 1.565 3.860 17,457.6 6,979.0 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE SURFACE;36.3-2,744.8- 17,464.1 6,978.7 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 GAS LIFT;4,429.1 fiS 17,470.5 6,978.3 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 17,483.1 6,977.7 93.04 REAMER BAKER 5.75"EZ REAM w/float ,( t 3.890 Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection GAS LIFT;8,407.8 TUBING 4 1/2x3 1/2 31/2 2.992 31.6 10,774.1 6,868.7 9.30 L-80 EUE @119.5 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Corn (In) 31.6 31.6 0.00 HANGER FMC TUBING HANGER 4.000 GAS LIFT;10,453.1 r 119.7 119.7 0.61 XO Reducing X0-4.5"IBT(B)x 3.5"EUE(P) 2.992 2,115.9 2,012.5 35.68 SAVETY VLV CAMCO TRMAXX-5E w/2.812"X profile 2.812 GAUGE;10,51?.0 10,512.1 6,746.7 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 10,539.5 6,760.1 60.85 PACKER BAKER PREMIER PACKER.. 2.880 • PACKER;10,539.5 .. ];! 10,557.7 6,769.0 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w/28'CARBIDE BLAST RINGS 2.992 !PERE;10563.0-10,583.0-S I 10,619.9 6,798.6 61.98 SLEEVE . PETROQUIP SLIDING SLEEVE CLOSED 1 30 15 2.813 i 10,635.9 6,806.1 62.17 PACKER BAKER PREMIER PACKER 2.870 SLEEVE;10,619.9 r III l 10,687.2 6,829.8 62.76 NIPPLE HES XN NIPPLE No-Go 2.750 PACKER;10,635.9 . -In'? 10,758.1 6,861.7 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 11 "r i 10,759.1 6,862.2 63.89 SOS SHEAR SCREW BODY(Located 1.55'up Fully Located) 3.000 NIPPLE;10,687.2 1 . 1' ;', 10,773.1 6,868.3 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 NIPPLE;10,758.1 ,;4. ; .. Perforations&Slots sos 1oas.1 IISnot Dens MULE SHOE;10,773.1 Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Com 10,563.0 10,583.0 6,771.5 6,781.1 4/20/2014 6.0 IPERF Peforate Kup C i 11,811.8 11,814.2 7,057.3 7,0572 4/19/2014 PERFP FRAC PORT 12,756.7 12,759.2 7,030.1 7,030.1 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.8 7,024.7 4/19/2014 PERFP FRAC PORT .1 l; 14,640.7 14,643.1 7,015.5 7,015.5 4/19/2014 PERFP FRAC PORT INTERMEDIATE;34.5.10,995.2-''. 15,572.1 15,574.6 7,039.3 7,039.3 4/19/2014 PERFP FRAC PORT 16,514.6 16,517.1 7,013.2 7,013.2 4/19/2014 PERFP FRAC PORT PERFP;11,811.8-11,814.2 i 15 17,457.6 17,4602 6,979.0 6,978.9 4/19/2014 PERFP FRAC PORT I 17,464.1 17,466.8 6,978.7 6,978.5 4/19/2014 PERFP FRAC PORT (Stimulations&Treatments PERFP;12,756.7-12,759.2 1 11 Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 11,811.0 17,466.0 7,057.4 6,978.6 FRAC '2/14/2015 PUMPED 585,000 N OF 16-20 CARBOLITE PERFP;13,697.6-13,700.2 i t THROUGH 6 SLEEVES • Cement Squeezes FRAC;11,811.0 Top(ND) Btm(ND) PERFP;14,640.7-14,643.1 1 8 Top(10(13) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 10,761.0 11,128.0- 6,863.0 6,990.7 Cement Plug 4/4/2014 Plugged back to cover problematic shales and kick off PERFP;15,572,1-15,574.6 a to Mandrel Inserts St I on i Top(ND) Valve Latch Pod Size TRO Run PERFP;76,514.6-16,517.1 N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com -1' 4,429.1 3,426.1 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,092,0 3/7/2015 2 8,407.8 5,606.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,120.0 3/7/2015 • 3 10,453.1 6,717.9 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/7/2015 PERFP;17,457.6-17,460'2 Notes:General&Safety PERFP;17,464.1-17,466.8 End Date Annotation 3/6/2014 NOTE: INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(lop 9983.36'MD). I 3/6/2014 NOTE:WELL SIDETRACKED TO"B" UNER;10,761.0-17,486.6 NS PROD CD3-3168 ConocoPhillips -s • Alaska,Inc. CrelnmPhdlirn 003.3168.3/19/2015 8'11-.30 AM Venccal schematic(aclual) Notes:General&Safety End Date Annotation 3/27/2014 NOTE:7"299,TN710 SS,HYD 563,6.125"S.D.from 9,983.36'to 10,860.50'MD HANGER;31.6— 3/27/2014 NOTE:7"269,180,BTC-M from 10,860.35'to 10,993.03'MD NOTE:7"268,L80,BTC-M from 35.29'to 9,983.36'MD mumsammuummuummunum—LLll 1Tal--le. dd.�.. N� CONDUCTOR Insulated;360-1 L 114.0 4 I' SAVETY VLV;2,115.9 iffla VALVE;2,125.4 4. SURFACE;36.3.2,744.8— A A GAS LIFT;4,429.1 GAS LIFT;8,407.8 l d( • • GAS LIFT;10,453.1 _ if::: GAUGE;10,512.0 PACKER;10,539.5 1 -'ill 1. 'PERF;10,563.0-10,583.0;.- 1 f.; SLEEVE;10,619.9 I PACKER;10,635.9 )+? NIPPLE;10,657.2 :[ NIPPLE;10,758.1 SOS;10,759.1 MULE SHOE;10,773.1 C. Ira INTERMEDIATE;34.5.10,995.2—'+ PERFP;11,811.8-11,814.2 ■ I PERFP;12,756.7.12,759.2 I I PERFP;13,697.813,7002 I II FRAC;11,811.0 PERFP;14,640.7-14,643.1 I I PERFP;15,572.1-15.574.6 e I PERFP;16,514.6-16,517.1 I PERFP;17,457.6-17,4602 PERFP;17,464.1-17,466.8 l LINER;10,761.0.17,486.6 — Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a4- - D J '"Well History File Identifier Organizing(done) I4Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: Coor Items: ❑ Maps: Grayscale Items: , gs: Li Poor Quality Originals: {/❑ Other: ❑ Other: BY: Maria Date: 3/cz,s-//s-' /s/ VYIP Project Proofing BY: 11=0Date: 3/g..61/6— /s/ vv Scanning Preparation la x 30 6 = 130 + a, 3 = TOTAL PAGES a 03 3)a 5 ��. (Count does not include cover sheet) BY: Maria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: cd 1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ✓YES NO BY: 42. Date: 3/a SPY' /s/ ro f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: q 1 Digital version appended by: Meredith Michal Date: 3/311(5' /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: a,75- Scanning is complete at this point unless rescanning is required. 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O I — II 0 it E O .o v' W Z a> Co CD a 0 0 Q E J E Z - CO y vi Q z o• o 0 t0 J p N C J a) w J E O U - 2 0 0 O. c y 2 0 0 0 N a) Oa V N E wTr e- co U C w J `� M } E Q M p c-° ° to o a @ V o r CZ TrI Nli 0 0 N a) CO C Jr. 2 com @ > N d aNi E CO CZ v c o• ~ E I W 3 co Cn _ A J a5 f/1 )• a) c p ❑ C C o Q JC \ CO 0 C Co N r V a) C C n Qci 43 1 a ° m O coE co U z m m N V V v 31-.. L Q N N CM '= C Z C 10 16 �� K}\ T N C ❑ IJ £ p 13 w O �J G H N C 1 03 f0 N re 'O v W E n 1 0 d W O o 1— c71 N d r N £ co Z o N N = a; .5 • NE O a�ce a) W mCC p d z Q o oo Q o o � c c� « o C d U E U 0 0 c 0. m o E U cD rn — 0 E 2 o E m E E a 2 J 3 i 0ci ac� 0 0 C ° 0 0 21 4018 RECEIVED ConocoPhiiiips MAR 19 2015 2 5 5 3 g TRANSMITTAL A000 2 5 5 4 0 CONFIDENTIAL DATA DATA LOGGED FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender 3i�v2of R ConocoPhillips Alaska, Inc. AOGCC M.K.Zap P.O. Box 100360 333 W. 7`"Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD3-316B/CD3-316BPB1 DATE: 03/18/2015 Transmitted: Colville River Unit, Alaska CD3-316B/CD3-316BPB1 1 CD and hardcopy report Halliburton-Surface data logging and End of Well report- mud logging data for CD3-315B & CD3-316BPB1; 04/21/2014; 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 color log print each: CD3-3168 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD CD3-316BPB 1 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCOP.com CC: CD3-316B - transmittal folder, production well files, eSearch Receipt 17) O4te: 1 .7 .37- GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COIF 3SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Plug Perforations r Perforate rOther Fracture Pull TubingStimulation Alter Casing r r. Stimulate- Frac rr Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well f 2.Operator Name: 4.Well Class Before Work: I 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fj Exploratory r 214-018 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20559-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364471,372105,372104 CRU CD3-316B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17492 feet Plugs(measured) 10761 true vertical 6977 feet Junk(measured) none Effective Depth measured 17482 feet Packer(measured) 10540, 10636, 10761 true vertical 6977 feet (true vertical) 6760,6806,6863 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2709 9.625 2745 2476 INTERMEDIATE 10961 7 10995 6953 LINER 6726 4.5 17487 6977 RECEIVED MAR 0 9 2015 Perforation depth: Measured depth: 10563-10583 F True Vertical Depth: 6771-6781 (�G CC Tubing(size,grade,MD,and ND) 4.5 x 3.5, L-80, 10774 MD,6869 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 10540 MD and 6760 ND PACKER-BAKER PREMIER PACKER @ 10636 MD and 6806 ND PACKER-BAKER HRD-E ZXP LINER TOP PACKER @ 10761 MD and 6863 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2116 MD and 2013 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11811'-17466' Treatment descriptions including volumes used and final pressure: pumped 585,000#of 16/20 carbolate 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil I✓ Gas r WDSPL 1--- Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r 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. 315-032 Contact Robert Blakney 265-6417 Email Robert.G.Blaknev(a conocophillips.com Printed Name Robert Bla,ne Title Sr. Completions Engineer Signature Phone:265-6417 Date 3/57x005`5/x0 /� 1/1-l- 3/i I./tS RBDMS ,A\-"MAR 1 1 2015 Form 10-404 Revised 10/2012 Alf. rz _/,,..--- Submit Original Only CD3-3168 FRAC SUMMARY DATE ' SUMMARY 1/22/2015 REMOVE HYDRATES FROM 769'-—1600'SLM. GAUGE TBG TO 2.78"TO 3000' SLM. RAN FB-BLB &2.79" LIB TO 10493' SLM (-200'ABOVE PLUG).. UNABLE TO GET DEEPER. **FILL MARKS ON LIB**. IN PROGRESS. 1/23/2015 RAN 2.5" DD BAILER TO 10687' RKB. **RECOVERED --2 CUPS FORMATION SAND**. BRUSH & FLUSH SSD @ 10620' RKB. CLOSED SSD @ SAME. MITT TO 2500 psi. **PASS**. SET CATCHER ASSY( 3" BAIT SUB,XO,STEM,XO &2.78"G.RING/OAL=75.5")@ 12620' RKB. IN PROGRESS. 1/24/2015 PULL GLV's @ 4429' &8408' RKB. REPLACE WITH DV's. PULL OV @ 10453' RKB. LEAVE POCKET OPEN FOR CIRC OUT. IN PROGRESS. 1/25/2015 PUMPED 276 BBLS OF INHIBITED SEAWATER TO CIRC OUT WELL FOLLOWED BY 91 BBLS DSL DOWN TBG. U-TUBED TBG AND IA FOR FREEZE PROTECT. JOB COMPLETE. 1/26/2015 MONITOR WIND SPEED. SET DV @ 10453' RKB. DRAW DWN IA FROM 1200»»620 psi TO VERIFY VLV SET. PULLED CATCHER ASSY @ 10620' RKB. READY FOR LRS. 1/26/2015 MIT-T TO 3500 PSI PASS MIT-IA TO 3500 PSI PASS BLEED IA AND TBG TO 1500 PSI JOB COMPLETE 1/28/2015 SET FRAC SLEEVE @ 2116' RKB. MITT TO 4000 psi. **PASS**. PULL FRAC SLEEVE @ 2116' RKB. PULL PRONG @ 10682' RKB. PROCEDURE CHANGE PER PRODUCTION ENGINEER. RAN 10'X 2.5" PUMP & 1.75" DD BAILERS TO 10668' SLM. **NO SAMPLE**. SET DWN IN SSD & PARTIALLY OPENED SSD @ 10620' RKB WITH BAILER. SET 72" PRONG @ 10687'RKB. ATTEMPT TO CLOSE SSD @ 10620' RKB. MAINTAIN INJ RATE OF .3 BPM. IN PROGRESS. 1/30/2015 OPENED PETROQUIP SLEEVE AT 10620' RKB, TBG PRESSURE FELL FROM 500- 100 PSI, INDICATING THAT SLEEVE WAS SHUT. CLOSE SLEEVE @ SAME. PINS IN 4260 INDICATES THAT SLEEVE IS FULLY CLOSED. SHUT DOWN DUE TO WIND, FIELD IN PHASE 2. IN PROGRESS 1/31/2015 SET FRAC SLEEVE @ 2116' RKB, MIT-T w/4000 PSI DIFFERENTIAL T x IA, **PASS**. SHUT DOWN DUE TO WIND. IN PROGRESS 2/1/2015 PULLED FRAC SLEEVE @ 2116' RKB. PULLED PXN PLUG @ 10687' RKB. DRIFT TBG w/2.69" CENT, SAMPLE BAILER TO 11324' SLM, STOPPED FALLING DUE TO DEV. (80 DEGREES). RESET FRAC SLEEVE @ 2116' RKB. DRIFT TREE TO 40' SLM w/3.89"G-RING. COMPLETE 2/2/2015 PUMP 150 BBLS 100* CRUDE DOWN TUBING FOR INJECTIVITY TEST JOB COMPLETE 2/5/2015 PUMPED 50 BBLS OF ARCTIC DIESEL/M209/5206, 50 BBLS OF 70/30 EG/WATER/3001, FOLLOWED BY 300 BBLS OF DEAD OIL/M209 DOWN TBG FOR A SCALE INHIBITION TREATMENT. JOB COMPLETE. 2/12/2015 DRIFT TUBING W/2.25" SWEDGE THROUGH AVA FRAC SLEEVE 2/14/2015 Performed fracture stimulation treatment @ 20 bpm placing 585,000#of 16/20 frac sand, 100% of design. Well freeze protected w/ 17 bbls of diesel. 2/17/2015 RECOVERED 3" PIECE OF SEAL FROM TREE SAVER. PULLED FRAC SLEEVE @ 2110' RKB. READY FOR COIL. 2/17/2015 FINISH RIGGING COIL UNIT FROM CD4. RIG EQUIP ON CD3-316. WILL START JOB IN THE MORNING, IN PROGRESS. 2/18/2015 MILL OUT FRAC SLEEVE @ 11,811' RKB. BACK REAM SEVERAL TIMES& DRY DRIFT CLEAN. RIH TO PREP TO MILL SLEEVE @ 12756' RKB. PULLED HEAVY @ 12,700'CTMD. COIL WAS HUNG UP IN MULTIPLE PLACES.ATTEMPTED TO PUMP A GEL SWEEP BUT GEL PILL CLOGGED OFF THE BHA. HAD TO SHEAR THE CIRC SUB DISC TO ALLOW CIRCULATION TO FREEZE PROTECT COIL. TOOLS FINALLY CAME FREE @—12,100'CTMD BUT STILL WAS DRAGGING SUSPECTED FRAC BALL DEBRIS. WELL FREEZE PROTECTED FROM 2000'TO SURFACE, IN PROGRESS. 2/19/2015 RUN BAKER 2 5/8"VENTURI BASKET, WASHING SLEEVE AREA @ 11,811' RKB TO SLEEVE @ 12,756' RKB. HAD VERY MINIMAL RETURNS OF FRAC SAND IN VENTURI BASKET. SUSPEND JOB TO GO TO CD4-96 FRAC PREP, IN PROGRESS. 2/23/2015 LATE START DUE TO PHASE 2 ON THE ICE ROAD. RIG UP ON WF' L, PERFORM WEEKLY BOPE TEST. TOO LATE IN TF =TERNOON TO START JOB. DECISIOI DE TO GO TO CD4-96 FOR NEXT COIL JOB. RIG OFr WELL. F WNS PROD CD3-316B ConocoPhillips o Well Attributes Max Angle&MD TD Alii-0- 1110 Wellbore APIIUWI Field Name Wellbore Status ncl(1 MD IftKB) Act Btm(ftKB) C hp.. 501032055903 FIORD KUPARUK PROD 94.04 11,722.21 17,492.0 .-. .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-3168.22620153.09.27 PM SSSV:TRDP Last WO: 36.63 2/12/2008 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation •Last Mod By End Date Last Tag'. Rev Reason:FRAC lehallf 2/26/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded „'1��vl��. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(TVD)...WVLen(I...Grade Top Thread HANGER;31.6- SURFACE 95/8 8.835 36.3 2,744.8 2,476.1 40.00 L-80 MBTC If] r-Tr Casing Description OD(in) ID(in) Top(MB) Set Depth(ftK8) Set Depth(TVD)...WVLen(I...Grade Top Thread [�� INTERMEDIATE 7 6.276 34.4 10,995.2 6,953.3 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ftKB) 'Set Depth(ND)...WVLen(I...Grade 'Top Thread LINER 41/2 1958 10,761.0 17.486.6 6,977.5 12.60 L-80 IBT • amer Liner Details �. ^ Nominal ID -- Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) CONDUCTOR Insulated;3640- s 10,761.0 6,863.0 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 11.0 1 i' i 10,787.5 6,874.6 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.7 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x 4.5"IBT) 4.000 11,811.8 7,057.3 93.72 FRAC PORT 'HES FRAC SLEEVE 1.866 SLEEVE;2,110.0 it` 12,756.7 7,030.1 90.14 FRAC PORT HES FRAC SLEEVE 1.805 13,697.8 7,024.8 90.27 FRAC PORT HES FRAC SLEEVE 1.745 SAVETY VW;2,115.9 - • 14,640.7 7,015.5 91.01 FRAC PORT HES FRAC SLEEVE 1.685 VALVE;2125.4 15,572.2 7,039.3 89.48 FRAC PORT HES FRAC SLEEVE 1.625 16,514.6 7,013.2 91.36 FRAC PORT HES FRAC SLEEVE 1.565 3.860 17,457.6 6,979.0 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 17,464.1 6,978.7 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 SURFACE;36.3.2.744.8 A 17,470.5 6,978.3 93.04-VALVE 'WELLBORE ISOLATION VALVE 1.500 GAS LIFT;4,429.1 17,483.1 6,977.7 93.04 REAMER BAKER 5.75"EZ REAM w/float 3.890 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 4 1/2x3 1/2 I 3 1/2 2.9921 31.61 10,774.11 6,868.7 9.301 L-80 I EUE GAS LIFT;8.407.6 @119.5 Ill I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.6 31.6 0.00 HANGER FMC TUBING HANGER 4.000 GAS UFT;10.453.1 119.7 119.7 0.61 XO Reducing X0-4.5"IBT(B)x 3.5"EUE(P) 2.992 Y. I XX 2,115.9 2,012.5 35.68 SAVETY VLV CAMCO TRMA -5E w/2.812"X profile 2.812 10,512.1 6,746.7 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 GAUGE;10,512.0 �- 10,539.5 6,760.1 60.85 PACKER BAKER PREMIER PACKER 2.880 PACKER;10,539.5 .,1". 10,557.7 6,769.0 61.10'BLAST RING TN-110 Hyd 563 R2 tbg w/28'CARBIDE BLAST RINGS 2.992 10,619.9 6,798.6 61.98 SLEEVE PETROQUIP SLIDING SLEEVE CLOSED 1 30 15 2.813 IPERF;10563.0-10583.0-•: 10,635.9 6,806.1 62.17 PACKER BAKER PREMIER PACKER 2.870 SLEEVE;10,619.9 i . •7 10,687.2 6,829.8 62.76 NIPPLE HES XN NIPPLE No-Go 2.750 PACKER;10,635.9 f 3:,i5; 10,758.1 6,861.7 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 10,759.1 6,862.2 63.89'SOS SHEAR SCREW BODY(Located 1.55'up Fully Located) ' 3.000 NIPPLE;10,687.2 - 10,773.1 6,868.3 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 NIPPLE-107581 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SOS;10,759.1 Top(ND) Top Incl Top(ftKB) (ftKB) ft Des Com Run Date ID(in) 2,110.0 2,007.7 35.61 SLEEVE GS FRAC SLEEVE SET AT 2116'OAL 79",TO 2/1/2015 - 2.310 MULE SHOE;10,773.1SSSV • 4 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotstt -+I Top(ftKB) Btm(ftKB) 10,563.0 10,583.0 (ftKB) (ttKB) 6,781.1 Zone Date t) Type Com 6,771.5 4/20/2014 6.0 IPERF Peforate Kup C 11,811.8 11,814.2 7,057.3 7,057.2 4/19/2014 PERFP FRAC PORT INTERMEDIATE;34.6-10,995.2 - 12,756.7 12,759.2 7,030.1 7,030.1 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.8 7,024.7 4/19/2014 PERFP FRAC PORT PERFP;11511.641,814.2 14,640.7 14,643.1 7,015.5 7,015.5 4/19/2014 PERFP FRAC PORT 15,572.1 15,574.6 7,039.3 7,039.3 4/19/2014 PERFP FRAC PORT PERFP;12,756.7-12.759.2 16,514.6 16,517.1 7,013.2 7,013.2 4/19/2014 PERFP FRAC PORT 17,457.6 17,460.2 6,979.0 6,978.9 4/19/2014 PERFP FRAC PORT 17,464.1 17,466.8 6,978.7 6,978.5 j 4/19/2014 PERFP FRAC PORT PERFP;13.197.843.700.2 Stimulations&Treatments Min Top Max Btm FRAC;11,811.0 Depth Depth Top(TVD) Btm(ND) PERFP;14.640.7-14,643.1 (ftKB) (51(13) (ftKB) (ftKB) Type Date Corn 11,811.0 17,466.0 7,057.4 6,978.6 FRAC 2/14/2015 PUMPED 585,000#OF 16-20 CARBOLITE THROUGH 6 SLEEVES PERFP;15,572.1-15,574.6 Cement Squeezes Top(ND) Btm(ND) Top(ttKB) Btm(ftKB) (ttKB) (ttKB) Des Start Date Con, 10,761.0 11,128.0 6,863.0 6,990.7 Cement Plug 4/4/2014 Plugged back to cover problematic shales and kick off PERFP;16,514.6-16,517.1 Mandrel Inserts St ati PERFP;17.457.6-17,4602 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 PERFP;17,464.1-17,466.8 1 f { 4,429.1 3,426.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/24/2015 2 8,407.8 5,606.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1242015 3 10,453.1 6,717.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/26/2015 LINER;10,761.0-17,480.6 WNS PROD CD3-316B ConocoPhillips a Kaska,Inc. 003-3168,2262015 3'.09'.28 PM Vertical schematic Tactual) Notes:General&Safety End Date Annotation 3/6/2014 NOTE: INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(top 9983.36'MD). HANGER;31.6- 7,;_ 'S 3/6/2014 NOTE:WELL SIDETRACKED TO"B" in it... 3/27/2014 NOTE: 7"29#,TN710 SS,HYD 563,6.125"S.D.from 9,983.36'to 10,860.50'MD 3/27/2014 NOTE:7"26#,L80,BTC-M from 10,860.35'to 10,993.03'MD 3/27/2014 NOTE:7"26#,L80,BTC-M from 35.29'to 9,983.36'MD AtmatitanuamMimmtadammatuatumua Mw IAS_^: CONDUCTOR Insulated.36.0- 1140 SLEEVE;2,110.0 t♦p(; SAVETY VLV;2,1159 VALVE:2,125.4 SURFACE;36b2.744.8—• GAS LIFT,4,429.1 GAS LIFT;8.407 8 GAS LIFT;10.453.1 III 1 11.11GAUGE.10,512.0 PACKER;10,539.5 IPERF;10.563.0-10.583.0—, ir SLEEVE;10,619.9 PACKER;10,635.9 1.1 NIPPLE;10,687.2 � •� NIPPLE;10,758.1 SOS;10.759.1 1; Alit MIRE SHOE;10,773.1 .I I.. INTERMEDIATE;34.540,995.2 PERFP;11.811.&11,814.2 PERFP;12,756.7-12,759.2 PERFP; 2---- FRAC; FRAC;11,811.0 PERFP;14,640.7-14,643.1 PERFP; 6-- PERFP, PERFP;16,514 6-16,517.1 PERFP;17,457.6-17.4602— PERFP; 7,457.6-17.4602 PERFP;17,464.1-17.466.8 LINER,10.761 0-17 486 6 4.11 Z 0 0 m co V 0o 0 0 0 Lo 3 ,-( I) O(O •. CO. a 0 > N m oO c>I a n n n n n no N � y .:0 0. 0 � NN- muN F- - gn = CO N- O N NN CO 0 0a3 O N N O O 2 a a a .. a ro x a LL 3 C dE N o, m o , 0) 0, a O r` N COo] O C CD d 0 0 0 0 0 0 7 441, CN s, alE ii y O U I C L d = v C a) '.0 a A L- — m 7 E = E LL 0 7 c0 n O x c _ a7 o U 2v N C3 c C c E c a y N m '. ,> 2 o a e o 0 0 0 0 0 0 E y 73 E 0. 0 0 0 0 0 CO 2 71cO) Q � rn v o 0 C O U L O 4— as v m Zr, n (n S u0 a — myE Q w m 05 - ° 4-1 2m4 U coUQcnZM a m 2 r N- r_ v CD rn N- CO CO C O SD_ 2 c E E O1 C N U d 1 +� d w � U CO g a `o _- aE o `o m 0 E O c!,:=2. m E c L = � E o -a cc Q_ N NNLO N C -0 a 3 0 3 2 x c, y a, co 12 m o c O u LL O r Oi' O LIZ h/1 O (:, Y 0 ;5 0. a (m c_ 0 0.0 a z 0 L 1iu �'a a EE m c d u v +a d g 3 a a U zz a CB Aa.Q U) o L w a U i'z"1 1 73 •— ;3' 3 c o 13 U _ .) LL v _ U •f 7 U 7 O1 7 OCa N m co jc � . E OEo - 6- 73 _ a _ u_ o 1 Na) Operator: ConocoPhillips Well: CD3-316b Basin/Field: Colville-Prudhoe Basin / Alpine Disclosure Type: Post-Job Well Completed: 2/14/2015 Chemical provider: Baker Hughes SCW-720 Disclosure Chemical name CAS number Mass Fraction Scale inhibitor Water 7732-18-5 48.4% Ethylene glycol 107-21-1 30.0% Polymer Nonhazardous Trade Secret 19.4% 5,080 gals Calcium chloride (CaCl2) 10043-52-4 2.0% Potassium chloride 7447-40-7 0.1% Sodium chloride 7647-14-5 0.1% Client: ConocoPhillips Alaska Inc. Schlumberger Well: CD3-316b Basin/Field: Colville-Prudhoe Basin/ Alpine State: Alaska County/Parish: North Slope Borough Case: 631534433 Disclosure Type: Post-Job Well Completed: 2/14/2015 Date Prepared: 3/4/2015 12:20 PM Report ID: RPT-35382 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 6.6 Gal/1000 Gal 2,080.0 Gal F103 Surfactant 1.2 Gal/1000 Gal 367.0 Gal J134 Breaker 0.1 Lb/1000 Gal 25.0 Lb J532 Crosslinker 5.1 Gal/1000 Gal 1,600.0 Gal PROPPANT 313,488 Gal J569 Breaker 5.4 Lb/1000 Gal 1,705.0 Lb TRANSPORT L065 Scale Inhibitor 2.1 Gal/1000 Gal 659.0 Gal M002 Additive 0.8 Lb/1000 Gal 263.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 102.0 Lb S522-1620 Propping Agent varied concentrations 583,587.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* 80.81503 % 66402-68-4 Ceramic materials and wares,chemicals 18.20963 % 64742-47-8 Distillates(petroleum),hydrotreated light 0.29750 % - -- - - 9000-30-0 Guar gum 0.26820 % 56-81-5 1,2,3-Propanetriol 0.11666 % 1303-96-4 - Sodium tetraborate decahydrate 0.07000 % 107-21-1 Ethylene glycol 0.04111 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.03846 % 7727-54-0 Diammonium peroxodisulphate 0.03559 % 111-76-2 2-butoxyethanol 0.01720 % 67-63-0 Propan-2-ol 0.01720 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01716 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) 0.00860 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00860 % 3439801-1(7EO) Linear C11 alcohol ethoxylate(7eo) 0.00860 % 1310-73-2 Sodium hydroxide(impurity) 0.00841 % 7647-14-5 Sodium chloride 0.00777 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite 0.00775 % 7631-86-9 Silicon Dioxide 0.00477 % 10043-52-4 CALCIUM CHLORIDE 0.00392 % 108-32-7 _ 4-methyl-1,3-dioxolan-2-one 0.00238 % 91053-39-3 Diatomaceous earth,calcined 0.00159 % 9012-54-8 Hemicellulase enzyme '0.00078 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00042 % 10377-60-3 Magnesium nitrate 0.00032 % 68153-30-0 Amine treated smectite clay 0.00030 % 9002-84-0 poly(tetrafluoroethylene) 0.00024 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00020 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol 3 one 0.00017 % 7786-30-3 Magnesium chloride 0.00016 % ..._.-_........... 7447-40-7 Potassium chloride(impurity) 0.00012 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00005 % 14808-60-7 Crystalline silica(impurity) 0.00003 % 14464-46-1 Cristobalite 0.00003 % Total 100% Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 STATE OF ALASKA AL _ A OIL AND GAS CONSERVATION CON, _3ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate r Other Scale Inhibitor Alter Casing r Pull Tubing E Stimulate Frac WaiverTreatment r f Tme Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r214-018 _ 3.Address: 6.API Number. P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20559-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364471,372105,372104 CRU CD3-316B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17492 feet Plugs(measured) 10761 true vertical 6977 feet Junk(measured) None Effective Depth measured 17482 feet Packer(measured) 10540, 10636, 10761 true vertical 6977 feet (true vertical) 6760,6806,6863 Casing Length Size MD ND Burst Collapse Conductor 78 16 114 114 Surface 2709 9.625 2745 2476 Intermediate 10961 7 10995 6953 Liner 6726 4.5 17487 6977 RECEIVED MAR 0 3 2Q1w Perforation depth: Measured depth: 10563-10583 True Vertical Depth: 6772-6781 A, GCC Tubing(size,grade,MD,and ND) 4.5 x 3.5, L-80, 10774 MD and 6869 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 10540 MD and 6760 TVD I PACKER-BAKER PREMIER PACKER @ 10636 MD and 6806 ND PACKER-BAKER HRD-E ZXP LINER TOP PACKER @ 10761 MD and 6863 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2116 MD and 2103 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10995'-17487' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic E 16.Well Status after work: Oil l Gas r VVDSPL r 1 Daily Report of Well Operations XXX GSTOR r WINJ E WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt none Contact Jack Walker(,265-6268 Email Jack.A.Walkerna coo.com Printed Name Jack Walker Title WNS Production Engineering Supervisor Signature phone:265-6268 Date _ A- i %_ k 03 )rl az 2G! 5 ItIL 3/11/1," RBDMS< M'.R - 5 2015 Form 10-404 Revised 10/2012 i& 71isr Submit Original Only I." f WNS PROD CD3-316B ConocoPhillips a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UW Field Name Wellbore Status Ilnel(1) MD(ftKB) Act Btm(ftKB) Cm0rr 1ilk, 501032055903 FIORD KUPARUK PROD 94.04 11,722.21 17,492.0 "". - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD3-3168,2/262015309:27 PM SSSV:TRDP Last WO: 36.63 2/122008 Vertical schematic(actual (ftK- - Annotation Depth B) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:FRAC lehallf 2/26/2015 Casing Strings .. .............................................................................................. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded HANGER;31.8- �u Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt./Len(I...Grade Top Thread rU1s SURFACE 95/8 8.835 36.3 2,744.8 2,476.1 40.00 L-80 MBTC - - "" Ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread '' --- Ir INTERMEDIATE 7 6.276 34.4 10,995.2 6,953.3 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread LINER 412 3.958 10,761.0 17,486.6 6,977.5 12.60 L-80 IBT Liner Details il A. ^ A- 'A It^ Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) CONDUCTOR Insulated.130140 0-_, 0. 10,761.0 0863.0 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 10,787.5 6,874.6 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.7 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x 4.5"IBT) 4.000 - 11,811.8 7,057.3 93.72 FRAC PORT HES FRAC SLEEVE 1.866 SLEEVE;2,110.012,756.7 7,030.1 90.14 FRAC PORT HES FRAC SLEEVE 1.805 {. --- 13,697.8 7,024.8 90.27 FRAC PORT HES FRAC SLEEVE 1.745 SAVETY VLV;2,115.9 14,640.7 7,015.5 91.01 FRAC PORT HES FRAC SLEEVE 1.685 VALVE;2.125.4 15,572.2 7,039.3 89.48 FRAC PORT HES FRAC SLEEVE 1.625 16,514.6 7,013.2 91.36 FRAC PORT HES FRAC SLEEVE 1.565 17,457.6 6,979.0 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 SURFACE;36.3-2,744.8- a 17,464.1 6,978.7 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 17,470.5 6,978.3 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 GAS LIFT;4,429.1 17,483.1 6,977.7 93.04 REAMER BAKER 5.75"EZ REAM w/float 3.890 :.( Tubing Strings Tubing Description I String Ma...l ID(in) I Top(ftKB) I Set Depth(ft..,Set Depth(ND)(...I Wt(lb/ft) I Grade 'Top Connection TUBING 41/2x312 1 312 2.992 31.6 10,774.11 6,868.7 9.30 L-80 EUE GAS LIFT;8.407.8 @119.5 Completion Details Nominal ID Top(MB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 31.6 31.6 0.00 HANGER FMC TUBING HANGER 4.000 GAS LIFT;10,453.1 .r 119.7 119.7 0.61 XO Reducing XO-4.5"IBT(B)x 3.5"EUE(P) 2.992 2,115.9 2,012.5 35.68 SAVETY VLV CAMCO TRMAXX-5E w/2.812"X profile 2.812 i 10,512.1 6,746.7 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 GAUGE;10,512.0 till ? 10,5 9.5 6,760.1 60.85 PACKER BAKER PREMIER PACKER 2.880 PACKER;10,539.5 ' 1',i 10,557.7 6,769.0 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w/28'CARBIDE BLAST RINGS 2.992 (PERF;f0,563.Q10,583.0�q 10,619.9 6,798.6 61.98 SLEEVE PETROQUIP SLIDING SLEEVE CLOSED 1 30 15 2.813 at a 5 10,635.9 6,806.1 62.17 PACKER BAKER PREMIER PACKER 2.870 SLEEVE;10,619.9 I t 10,687.2 6,829.8 62.76 NIPPLE HES XN NIPPLE No-Go 2.750 PACKER:10,635.9 '.-_-_-- 10,758.1 6,861.7 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 10,759.1 6,862.2 63.89 SOS SHEAR SCREW BODY(Located 1.55'up Fully Located) 3.000 NIPPLE;10.687.7 `I 10,773.1 6,868.3 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 NIPPLE;10,758.1Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • SOS;10,759.1 L; Top(ND) Top Incl Top(11KB) (f1KB) (3 Des Com Run Date ID(in) 2.110.0 2,007.7 35.61 SLEEVE GS FRAC SLEEVE SET AT 2116'OAL 79",TO 2/1/2015 2.310 MULE SHOE;10.773.1 " SSSV Perforations&Slots Shot Dens Top(TVD) Burr(TVD) (shotslf•1_-_ Top(ftKB) Btm(ftKB) (ftKB) (11KB) Zone Date t) Type Com ',1 10,563.0 10,583.0 6,771.5 6,781.1 4/20/2014 6.0 IPERF Peforate Kup C j • 11,811.8 11,814.2 7,057.3 7,057.2 4/19/2014 PERFP FRAC PORT I • INTERMEDIATE;34.5.10,995.2-: 12,756.7 12,759.2 7,030.1 7,030.1 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.8- 7,024.7 4/19/2014 PERFP FRAC PORT PERFP;11,811.6-11,814.2 14,640.7 14,643.1 7,015.5 7,015.5 4/19/2014 PERFP FRAC PORT 15,572.1 15,574.6 7,039.3 7,039.3 4/19/2014 PERFP FRAC PORT PERFP;12.756.7-12,759.2 16,514.6 16,517.1 7,013.2 7,013.2 4/19/2014 PERFP FRAC PORT 17,457.6 17,460.2 6,9790 6,978.9 4/192014 PERFP FRAC PORT 17,464.1 17,466.8 6,978.7 6,978.5 4/19/2014 PERFP FRAC PORT PERFP;13,697.8-13,700.2 Stimulations&Treatments Min Top Max Btm FRAC;11,811.0 Depth Depth Top(ND) Btm(ND) PERFP;14,640.7-14,643.1 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com . 11,811.0 17,466.0 7,057.4 6,978.6 FRAC 2/142015 PUMPED 585,000#OF 16-20 CARBOLITE I THROUGH 6 SLEEVES PERFP;15.5721-15,574.6-10Cement Squeezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 10,761.0 11,128.0 6,863.0 6,990.7 Cement Plug 4/42014 Plugged back to cover problematic shales and kick off PERFP;16,514.6-16,517.1 Mandrel Inserts st • ati PERFP;17.457.6-17,4602 ' 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 $ PERFP;17,464.1-17,4668 it 4,429.1 3,426.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/24/2015 2 8,407.8 5,606.9 CAMCO KBMG 1 GAS LIFT DMY BK 0000 0.0 1/24/2015 3 10,453.1 6,717.9 CAMCO KBMG 1 GAS LIFT DMY BK 0000 0.0 1262015 LINER;10,761.0-17,486.6 f WNS PROD CD3-316B Conoco-Phillips a Alaska.Inc. c cmoRallirr1 003-3168,2/262015 3.09:28 PM Vertical schematic(actual) Notes:General&Safety End Date Annotation 3/6/2014 NOTE. INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(top 9983.36'MD). HANGER;31.6- 'L;, 3/&2014 NOTE:WELL SIDETRACKED TO"B" i�- � -+,t 327/2014 NOTE:7"29q,TN710 SS,HYD 563,6.125"S.D.from 9,983.36'to 10,860.50'MD i 3/27/2014 NOTE:7"26#,L80,BTC-M from 10,860.35'to 10,993.03'MD 3/27/2014 NOTE:7"26#,L80,BTC-M from 35.29'10 9,983.36'MD lit i lA _ CONDUCTOR Insulated;36.0- 114.0 SLEEVE;2,110.0 1e', SAVETY VLV;2,115.9 :1'`+ VALVE;2,125.4 SURFACE;36.3-2.744.8 GAS LIFT;4,429.1 MB GAS LIFT:8,407.8 411/ GAS UFT;10453.1 ! • GAUGE;10,512.0 PACKER;10,539.5 r �.;. IPERF;10.563.0.10.583.0-"" a ii'.. SLEEVE;10,619.9 i 1 ., PACKER;10.635.9 Y. .._ NIPPLE;10,687.2 NIPPLE;10,758.1 SOS;10,759.1 `- MULE SHOE;10,773.1 '' .I 1 1. INTERMEDIATE;34.5-10.985.2- PERFP;11.811.8-11,814.2 = 9E PERFP;12.756.7-12,759.2 PERFP;19697.613,700.2 I FRAC;11,811.0 PERFP;14,640.7-14.643.1 j" PERFP;15,572.1-15,574.6 IY PERFP;16,514.6-16.517.1 PERFP;17,457.617480.2 I PERFP;17,464.1-17466.8 1 LINER;10.761.0.17,486.6 CD3-3168 Scale Inhibition Treatment 2/6/15 Non-Aqueous Scale Inhibitor Squeeze Job pumped 2/6/15 from 00:00 to 18:00. LRS= Little Red Services - Initial pressure TBG/IA/OA- 1999/922/315 - LRS pumped 50 bbls Diesel/M209/WAW5206 pre-flush at .6 bpm—1.0 bpm,TBG/IA/OA- 1983/935/367 - LRS pumped 50 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at.4- .45 bpm,TBG/IA/OA—1502/1030/442 - LRS pumped 300 bbls Dead Crude/M209 over-flush at .35- .4 bpm,TBG/IA/OA—2100/1300/225 Intervals treated: 10,995'—17,487' 4,41',\\V/77,v THE STATE Alaska Oil and Gas �►-s�i -- of/� � �r" /�1� Conservation Commission /0 t "' 1Z 1` � " #= 333 West Seventh Avenue OF �T GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax• 907.276.7542 www.aogcc.alaska.gov Robert Blakney �O � (� Sr. Completions Engineer 1 11_ o ConocoPhillips Alaska, Inc. - P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-316B Sundry Number: 315-032 Dear Mr. Blakney: 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. Asrovided in AS 31.05.080, within 20 days after written notice of this decision, or such further p 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, Cathy . Foerster Chair DATED this 3O day of January, 2015 Encl. :4 STATE OF ALASKA I A CA OIL ANC GAS CONSERVATION COMMI )N APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280- - • - - - 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate p. Alter casing r Other:Fracture Stimulation r• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development 1, 214-018 . 3 Address: Stratigraphic r Service 6 API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20559-03 • 7.If perforating, What 8 Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? I Will planned perforations require spacing exception? Yes r No 1.7 i CRU CD3-316B 9.Property Designation(Lease Number) 10 Field/Pool(s): ADL 364471,372105,372104 • 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): 17492 ' 6977 • 17482' • 6977' . 10687' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2709 9.625 2745' 2476' RECEIVED INTERMEDIATE 10961 7 10995' 6953' RECEIVED LINER 6726 4.5 17487' 6977' JAN 2 0 2015 °A-id6665. Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10563-10583 , 6771-6781 4.5 x 3.5 L-80 10774 Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER PREMIER PACKER • MD=10540 TVD=6760 PACKER-BAKER PREMIER PACKER • MD=10636 TVD=6806 PACKER-BAKER'HRD-E'ZXP LINER TOP PACKER MD=10761 TVD=6863 SSSV-CAMCO TRMAXX-5E SSSV • MD=2116 TVD=2012 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r -Service r 14.Estimated Date for Commencing Operations- 15 Well Status after proposed work. 2/1/2015 Oil F.T. Gas r WDSPL r Suspended r 1 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Blakney 265-6417 Email: Robert.G.Blaknev(o).conocoi hillios corn Printed Name R.ee ' ne Title: Sr. Completions Engineer / Signature ` T!' Phone:265-6417 Date" ,//Z,0 /15 Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 3\5- 03 2..... Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r .other: pa.5f l.-))fo -rvi e2,-17 o v- rccl tfi'r-ccf fo 1-1,7c Frac FocLJ5 C1)C -iI'C_ I -r DISeh,5ore 1,--t-,/5try www, Fra cI,6 5. iv 1-3 q �5 'v 1/ a5 reT1.,i'rCwres-r f-5 d a oAr4c2.).273. Spacing Exception Required? Yes ❑ No II Subsequent Form Required: /Q — 4 0 4 APPROVED BY Approved by: 0 COMMISSIONER THE COMMISSION Date: /— `l Approved application is valid for 12 mII`onth$/]from the date of approval. //��,//A /1_,...:32,,,45-, Form 10-403(Revised 10/2012) 9� II`�I/S Submit Form an Attachments in Duplicate VrL //z7-//5- ORIGINAL , �/ -- B - 42015 RBDM� FE CD3-316b Hydraulic Fracturing Sundry Application Section 1 See signed affidavit. • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) VERIFICATION OF FACTS AND Commission in the Matter of the ) AFFIDAVIT OF DORA I.SORIA. Request of Conoco Alaska, Inc.for ) Hydraulic fracturing for CPAI ) CD3-316B under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Dora I. Soria, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Dora Soria. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI"). 3. I am acquainted with the facts associated with the drilling of CD3-316B Well ("Well"). 4. I have reviewed the Application for Sundry Approvals for the proposal that the Well be stimulated by hydraulic fracturing as defined in 20 AAC 25.283(m). To the best of my knowledge and belief all facts therein are true and accurate. 5. Pursuant to 20 AAC 25.283 (1), CPAI, the well operator, prepared a Notice of Operations that is in compliance with the Provision of 20 MC 25.283. A copy of this notice is attached hereto ("Notice Letter") and includes a plat attached as Exhibit 1 in compliance with 20 MC 25.283(2). 7. On January 20, 2015, pursuant to 20 MC 25.283 (1), CPAI sent a copy of the Notice Letter by certified mail to the last known address of all owners, landowners, surface owners, and operators of within a one-half mile radius of the current proposed trajectory stating that upon request CPAI will make a complete copy of the application available and providing CPAI's contact information. These names and addresses are set forth on Exhibit 2 attached to CPAI's Request the Application for Sundry Approvals under 20 MC 25.283 dated January 20, 2015. Subscribed and sworn to this 20th day of January,2015. GL. J . �.QA L Dora I. Soria STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 20th day of January, 2015,by Dora I.Soria. STATE OF ALASKA Notary Public, State of Alaska NOTARY PUBLIC ' "'� REBECCA SWENSEN * My Commission Expires: A LAs aal 201 So My Commission Expires Aug.27,2016 4 a CD3-316b Hydraulic Fracturing Sundry Application Section 2 CD3-119 7_FIORD 4 ADL 1394 CD8-109 ADL364470 CD3-1 I• ! , CD3-108 CD3-106L1 ADL364472 CD3-110 i CD3-119PB1 CD3-111L1 1 ' 301 I -- CD 107L1 CD3-111 I 4 Co r A . • C' 1107 CD3-130 • Ti,5 ('\6.471 * CD3-302A C _: •'3- 1APB11 \1/4 CD3-302 A 1 SII '„� D I r-..4 •3-302P62 CD3-307 li /t3- 12P81 I I��.,, CD3-316:.- • %`�/ Co err-� =IFAry .000- -wwer 14111116), � Cji nit Unit AISPIIIIiisais„,...... .. ' '• ��,1„. n3: Legend S 316 �� •-41� � AD 372104 • Producer:Oil II . CD3 198 1 INJ:MWAG .L372105 P+A Other \ • FRAC PORT • CD3 199 • PERF PUP/SLOT LINER ■ OPEN HOLE CD3-304 CD3-121 CD3-125 • WINDOW * IPERF • PERF PUP/SLOT LINER / SQUEEZED CD3-123 —1132015WeIISurvey • —CD3-3168 CD3 22 Reservoir Section 1/2 Mile Radius Well Trajectory 1/2 mile Radius II\ oCPAI Operated Units AK Leases 70&148 CD3-128 ADL391577 CPA! ADL025538 REPSOL REFERENCES: `/ ufi Data:ConocoPhillipsAlaska IMells Database ConocoPhil lips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Colville River Unit. N CD3-3168 Plat Analysis >No Potable Water Aquifers are in the Colville River Unit 1/13/2015 1 0.5 a Mian 003318b mxd CSR 1/132015 • W Q. I•- 0 0 0 0 0 0 0 0 0 JI D D O w w w w w 0 w w w 0 0 0 0 0 0 0 D D 0 D D O w W 0 0 0 a a a a Cl_ 0 a a a 0 0 0 0 0 0 0 0 0 0 0 0 0 a 3 C K K X X 2 2 X X X 2 K 2 X 2 2 X X K , K E E 2 tY 2 E E 2 K 2 cc K z K a a a w w _ — w w w — d — w _ — w w a a d a d a — d — d a — a _ a a — d w O N .--I ci c-1 ci N N N N N m d' 111 LI7 LD l0 LD LD LD O LD LD N N CO O1 O c-I c-I N M d LI) N CO 01 al —100 0 0000000 0 O 0 0 e1 c-I r-1 e-1 c-I N 0 0 0 O 0 O e1 ci c-1 ci L1 e 1 e-1 .--I e-1 •-1 .1 J e1 en M en en en en en en en en M en en en en en M en en L1 e-I ri e1 e-I e1 c-1 L-I ci i1 c I .--I c-I c-I c I cit 1-1J M cn cn en fn M Mcr1 cn rn rn M M cnn M ccr1 m M M m M cn cn M M M c1'1 M M M M M M c1'1 w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000 U 0 0 U 0 0 0 U 0 0 0 U 0 0 0 0 0 0 0 0 0 0 0 U U U U 0 0 0 0 U 0 0 H w LU w w w w w w w w w w w w w w w LU LU LU w LU > > > > > > 0- < > > > > > > > > > > > > > > > > H < U< < U < < U UU < < UpUUUUU00UUvuuuuUU < V1 D_ D_ < D_ D_ D_ < 0_ 0_ a < < < a a a 0_ 0_ < V) < Q < < < Q < < <1 < < < < < < < 0,- 2 2 D ZI 99 0 LD o N N O O 11) 0 0 0 en co en en N a1 r-I CO CO LD c-I N 01 c-1 en al c-1 o N N Tr M LD LD V1 N N — a' N c-1 c-1 N c-1 en '-1 c-1 r1 ri N D1 D1 N r1 .-1 c-1 e-i O O O co Ln en to - CO d" M 0 M O N N O O 0 0 0 0 0 0 0 99 0 0 0 .--1 .-1 L-19 0 0 0 0 0 0 c-1 O O O 99 90 O 9999 90 cc up LD O O t.0 tD O t0 La LD o0 al 00 CO N co Co d' d' en O O LD 00 LI) u1 L1) LD lD LD N N a) al 00 N N W O O .-1 c-1 O O e1 0 0 0 0 0 0 0 0 0 0 e1 .-1 c-1 e1 c-1 0 0 0 0 0 0 0 0 0 C 0 0 0 c-I e-1 d N N N N N N N N N N N NNNNSIN SINNNSINSINNNSIN SINNSINSINN W 0- ›.. >- 3.. 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(13 = > a1 a1 00 ci Cl m m m CL LL 0_ d Y 73 N N N N N N N N N C11 CO O O C) 01 N Y c-I ci i ca1 <-1c-I c-I cc-I c-I a1 e-1c-I ca1 0 0 'a O Irl 41 41 011 M 41 NI (41 M 0'1 Pr1 cil (41 — a 0 0 0 0 0 0 0 0 0 0 0 0 0 Q Q CU 03 U U U U LI Z U U U U U U U U U LL CD3-316b Hydraulic Fracturing Sundry Application Section 3 There are no freshwater aquifers or underground sources of drinking water within a one-half ✓ mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." CD3-316b Hydraulic Fracturing Sundry Application Section 4 There are no water wells located within on-half mile of the current or proposed wellbore trajectory and fracturing interval. CD3-316b Hydraulic Fracturing Sundry Application Sections 5 All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. CD3-316b Hydraulic Fracturing Sundry Application Section 6 Casing & Cement Assessments: CD3-316: 9 5/8" casing cement pump report on 1/08/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.9 ppg mud. Reciprocated pipe during the job and full returns were seen throughout the job. The plug bumped @ 1000 psi and the floats were checked and they held. 7" casing cement pump report on 2/04/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.8 ppg mud. Reciprocated pipe and full returns were seen throughout the job. The plug bumped @ 1000 psi and the floats were checked and they held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a 1/4 mile radius or any other nearby well. CD3-316b Hydraulic Fracturing Sundry Application Section 7 Pressure test details: On 2/4/2008, the 7" casing was pressure tested to 3500 psi for 30 mins and it passed. On 4/22/2014 the 3.5" tubing was pressure tested to 3700psi for 30 mins and it passed. The 3.5" tubing will be pressure tested to 4,000 psi prior to frac'ing. The 7" casing will be pressure tested to 3,500 psi prior to frac'ing. CD3-316b Hydraulic Fracturing Sundry Application Section 8 Stimulation Surface Rig-Up C Bleed!Tattle Tale Tank 1101 PC100 2/ m 1 11 a1°i>/• a � 1,1 8 • Minimum pressure rating on all surface t.V111Z1 01:1 Da] treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi ��0�1 • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 .r =E is psi. 1'/ d 11Co1 U W L Noruidwnd Pop-OH Tank m E C Pop-Off Tanker Pump Truck ooEi �'/ / I--, C J 54Frac Pump hal )81— Frac Pump d ��1 Frac Pump rAI — N —{-- Frac Pump Frac Pump h:41 - Frac Pump ' CD3-316b Hydraulic Fracturing Sundry Application Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON CONNECTION ,....... i yi a i ..( I , • , .•,. .,•. J /REMOTE OPERATED ....1.c... , ..TT.•,, , IIMIIMIMMINI MASTER VALVE 1 rO� MANUAL OPERATED �•�U�` MASTER VALVE , .4...t....., .1111111111 111111111111•1111111111M el ofrop.:747 Stinger \t / Stinger \ MANDREL [ 111 it. ki VENT it �:*I•-VALVE -I- ,Q OPEN I y iittt III MIS iii/ /aiy kik . - ; ' - I,;� ��; FLOW TEE AND - -- •Vii■•II• VENT VALVE WELLHEAD ...' III !mmyfgl VALVES -__._._ .'/in� A: OPEN L WELLHEAD VALVES 1i CLOSED '..-I -4 1. * .h1(46\1- -.\ h' 6\1- 1 � QUAD PACKOFF ...I a V..._•-g. ASSEMBLY IN " • lim. - PLACE IN TUBING TUBING a \` 47r • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75"mandrel 36 bpm WNS PROD CD3-316BXX ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Fold Name Wellbore Status ncl(`) MD(RKB) Act Btm(RKB) e...,.,:aelhp. 501032055903 FIORD KUPARUK PROD 94.04 11.722.22 17.492.0 ... Comment ' ' - H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date CD3-3168X%.12/120141.33.40 PM SSSV.TRDP Last WO: 36.63 2'122008 Vertical acremanc(actual) /Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD NOTES haggea 12/1/2014 Casing Strings Casing Description OD(In) ID(in) Top(11KB) Set Depth(RKB( Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(In) ID(In) Top(R103) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread HANGER 3'0-MUM SURFACE 9 5/8 8.835 36.3 2,744.8 2,475.9 40.00 L-80 MBTC m� -. ,-„-- 'Cuing Description OD(In) ID(In) Top(MB) Set Depth(RKB) Set Depth(ND)...WULen(I...Grade Top Thread MY HT INTERMEDIATE 7 6.276 34.4 10,9952 6,953.1 26.00 L-80 BTC-M Casing Description OD(In) ID(In) Top(RKB) Set Depth(RKB) Set Depth(ND)...WI/Len(I...Grade Top Thread LINER 41/2 3.958 10,761.0 17,486.6 6.977.3 12.60 L-80 IBT .. .., , . . . L_ a.,__,u,.Liner Details Nominal ID 'W-^-, Top(RKB( Top(TVD)(RKB) Top Incl(°) Item Des Corn (In) CONDUCTOR Insulated iso-� 10,761.0 6.862.8 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 114E 10,787.5 6.874.4 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.5 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x 4.5"IBT) 4.000 11,811.8 7,057.1 93.72 FRAC PORT HES FRAC SLEEVE 1.866 12,756.7 7,029.9 90.14 FRAC PORT HES FRAC SLEEVE 1.805 SAVETY DLV;2.115.9 $T 13,697.8 7,024.5 90.27 FRAC PORT HES FRAC SLEEVE 1.745 VALVE;2.125.4 14,640.7 7,015.3 91.01 FRAC PORT HES FRAC SLEEVE 1.685 15,5722 7,039.1 89.48 FRAC PORT HES FRAC SLEEVE 1.625 16,514.6 7,013.0 91.36 FRAC PORT HES FRAC SLEEVE 1.565 17,457.6 6,978.8 93,04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 SURFACE:36.3-2.744x- 17 464.1 6,978.5 93.04 FRAC PORT BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 GAS LIFT,4.425.1 IS 17,470.5 6,978.1 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 17 483.1 6,977.5 93.04 REAMER BAKER 5.75"EZ REAM w/float 3.890 • Tubing Strings Tubing Description String Ma...I ID(in) I Top(RKB) I Set Depth(ft..I Set Depth(ND)(...I 9.30 L WI(IbmR) Grade I Top Connection GAS LIFT;840]8 TUBING 4 1/203 1/2 31/2 2.992 31.6 10,7741 6,060 5 -80 EUE I Qa 119.5 Completion Details Nominal ID Top(11118) Top(ND)(RKB) Top Incl(°) Item Des Com (In) 31.6 31.6 0.00 HANGER FMC TUBING HANGER 4.000 GAS UFT;10,453.1 : 119.7 119.7 0.61 XO Reducing XO-4.5"IBT(B)x 3.5"EUE(P) 2.992 2.115.9 2,012.4 35.69 SAVETY VLV CAMCO TRMAXX-5E w/2.812"X profile 2.812 GAUGE;10,5120 10,512.1 6,746.5 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 10,539.5 6,759.9 60.85 PACKER BAKER PREMIER PACKER 2.880 PACKER;10,539.5 10,557.7 6,768.8 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w128'CARBIDE BLAST RINGS 2.992 (PERF;10.563,0-10.583.0-ii .i _.,... 10,619.9 6,798.4 61.98 SLEEVE-O PETROQUIP SLIDING SLEEVE OPEN 7/6/2014 2.813 10,635.9 6,805.9 62.17 PACKER BAKER PREMIER PACKER 2.870 SLEEVE.0,10819.9 '` 10,687.2 6,829.6 62.76 NIPPLE •HES XN NIPPLE No-Go 2.750 PACKER,70.635.9 - _- 10,758.1 6.861.5 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000, 10,759.1 6,862.0 63.89 SOS SHEAR SCREW BODY(Located 1.55'up Fully Located) 3.000 NIPPLE;10.6872 PLUG W/P-PRONG;10,687.2, N 10,773.1 6,868.1 64.15 MULE SHOE 'FLUTED MULESHOE WLEG 2.990' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE;10,758.1Top(NO) Top Incl SOS.10,7591 - Top(RKB) (RKB) (*) Des Corn Run Date ID(In) 10,687.2 6,829.6 62.76 PLUG W/P- 2.81"PXN PLUG BODY 6/22/2014 PRONG MULE SHOE:10.773.1 _ Perforations&Slots i Shot Dens Top(ND) Bhn(TVD) (shots/f Top(ROB) Btm(RKB) (MB) (RKB) Zone Date t) Type Com r __ __1 l,. 10,563.0 10,583.0 6,771.3 6,780.9 4/20/2014 • 6.0 IPERF Peforate Kup C .'.l I:• 11.811.8 11,814.2 7,057.1 7,057.0 4/19/2014 PERFP I FRAC PORT INTERMEDIATE;34.5.10,995.2`' • 12,756.7 12,759.2 7,029.9 7,029.9" 4/19/2014 PERFP FRAC PORT 13,697.8 13,700.2 7,024.5 7,024.5' 4/19/2014 PERFP FRAC PORT PERFP;11.8116-1 1.914.2 ■ ■ 14,640.7 14,643.1 7,015.3 7,015.3 4/19/2014 PERFP FRAC PORT 15,572.1 15,574.6 7,039.1 7,039.1 4/19/2014 ' PERFP FRAC PORT ' 16,514.6 16,517.1 7,013.0 7,013.0- 4/19/2014 PERFP FRAC PORT PERFP;12.756.7-12,758.2 17,457.6 17,460.2 6,978.8 6,978.7 4/19/2014 PERFP FRAC PORT 17.464.1 17,466.8 6,978.5 6,978.3 4/19/2014 " PERFP FRAC PORT PERFP:13.697.8-13,700.2 ■ ■ Cement Squeezes Top(TOD) Btm(ND) Top(ftKB) Btm(RKB) (RKB) (ROB) Des Start Date Com PERFP;14,640.7-14,643.1 10,761.0 11,128.0 6,862.8 6,990.5 Cement Plug 4/4/2014 Plugged back to cover problematic shales and kick off Mandrel Inserts - PERFP;15,572.1-15.574.6 ■ ■ St ati on Top(TVD) Valve Latch Port Size TRO Run N, Top(RKB) (RKB) Make Model OD(In) Sery Type Type In) (psi) Run Date Corn I 1 4,429.1� 3,425.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,092.0 5/4/2014 PERFP;76.574.6.76,5171 2 8.407.8" 5.606.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,120.0 5/4/2014 3 10.453.1 6,717.7 CAMCO -KBMG 1 GAS LIFT OV BK 0.313 0.0 5'5/2014 Notes:General&Safety PERFP;17.457.6-17,460.2 I I End Date Annotation 3/6/2014 NOTE. INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(top 9983.36'MD). PERFP;17,464.1-17,466.9 I I 3/6/2014 NOTE:WELL SIDETRACKED TO"B" S"' LINER;10,761.017,496.6 • WNS PROD CD3-316B)0( • ConocoPhillips Alaska,Inc. Cmocolfid6ps CD3-316UXX,12/1/20141 38:41 PM Vertical schematic/actua3 1 Notes:General&Safety End Date Annotation 3/27/2014 NOTE: 7"29#.TN 110 SS,HYD 563.6.125"S.D.from 9,983.36'to 10,860.50'MD HANGER;31.6—111[4al 3/27/2014 NOTE:7"26#,L80,BTC-M from 10,860.3510 10,993.03'MD _.--3/27/2014 NOTE:7"2671,L80,BTC-M from 35.29'to 9,983.36'MD CONDUCTOR Insulated,36 - 1140.0 _...-- 7 SAVETY VLV;2.115.9 `AU. VALVE;2,1E 4 SURFACE;36.3-2,744.8— . L GAS LIFT:4,429.1 l l ) GAS LIFT.8 407 8 ill GAS LIFT:10.453.1 GAUGE;10,512.0 1 ' PACKER;10,539.5 IPERF;1O.5633370,583.0—-'..'7. I SLEEVE-O;10.619.9 1 PACKER;10,6389 .',y • NIPPLE:10,6872 PLUG WIP-PRONG:10.6872 i NIPPLE;10.758.1 SOS;10.759.1 4 MULE SHOE;10.773.1 • 'rl l INTERMEDIATE;34.5-10.995.2—' PERFP;11,811.8-11,814.2 l j PERFP,12.756.7-12,7592 , I PERFP,13.697.613.700.2 I a PERFP;14.640.7-14,643.1 E a PERFP:15.572.1-15.5746 a a PERFP;16.514.616,517.1 I 11, PERFP;17.457.6-17.460.2 'fl ' 11 PERFP;17,464.1-17. 8 1 r LINER;10,761 017.486.6 CD3-316b Hydraulic Fracturing Sundry Application Section 9 Data for the fracturing and confining zones: CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Nechelik interval is approximately 140' TVD thick at the heel and toe of the well with the top Nechelik starting at 11,275' MD/6983' TVDSS. The Nechelik is a quartz rich, poorly sorted, lower very fine to lower fine grained coarsening upward sandstone. The HRZ, Kalubik and Kingak comprise the overlying confining layers which consist of clay rich beds interbedded with silty layers ranging in total thickness from 500' TVD at the heel to 900' TVD at the toe with the top HRZ starting at 10,100' MD/6496' TVDSS. • CD3-316b Hydraulic Fracturing Sundry Application Section 10 Casing & Cement assessments for all wells within .5 miles CD3-106: 7" casing cement pump report on 2/08/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.6 ppg mud. Reciprocated pipe throughout the job. The plug bumped @ 1200 psi and the floats were checked and they held. CD3-107: 7" casing cement pump report on 4/24/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.6 ppg brine. Full returns were seen throughout the job. The plug bumped @ 1080 psi and the floats were checked and they held. CD3-119: 7" casing cement pump report on 2/04/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 11 ppg mud. Reciprocated pipe and full returns were seen throughout the job. CD3-108: 7" casing cement pump report on 4/01/2005 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10 ppg mud. Reciprocated pipe and full returns were seen throughout the job. The plug bumped @ 1100 psi and the floats were checked and they held. CD3-130: 7 5/8" casing cement pump report on 2/26/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.5 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1570 psi and the floats were checked and they held. CD3-109: 7" casing cement pump report on 4/30/2005 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.6 ppg brine. Reciprocated pipe and full returns were seen throughout the job. The plug bumped @ 1200 psi and the floats were checked and they held. CD3-302: 7" casing cement pump report on 4/16/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.8 ppg mud. The plug bumped @ 1700 psi and the floats were checked and they held. CD3-301: 7" casing cement pump report on 3/26/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.5 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1150 psi and the floats were checked and they held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a '/2 mile radius or any other nearby well. CD3-316b Hydraulic Fracturing Sundry Application Section 11 Data on faults in the area: CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there is one fault or fracture that transects the Nechelik formation and may enter the lower portion of the confining zone within one half mile radius of the wellbore trajectory for CD3-316B. This feature is noted on the map and cross-section, occurring at approximately 16,650' MD. In addition to this feature, there may be two additional small features in the reservoir, inferred while drilling, at approximately 13,970' MD and 14,750' MD. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. CD3-316b Hydraulic Fracturing Sundry Application ADL364470 ADL364472 O -\v �( ADL364447w- 1`) Seismically ___ .15" 0C) I mapped fault L .131 Subseismic a faults inferred from drilling data Colville River Unit Unit CD3 ® •• ADL372103 ADL372105 _, ADL372104 Legend —Fault within Reservoir Buffer ••••Wel Trajectory mem Reservoir Section Reservoir Section 1/2 Mile Radius =CPA!Operated Units AK Leases Operator Lease Boundary REFERENCES: Iv' Well Data:ConocoPhillipsAlaska Wells Database AIDS lCoinocoPhl��lps Surface Facilities:North Slope 6K Survey 7/25112 Published 3/20/13 Alaska Statewide 04&Gas Leases 1/12/2015 nc. Neter Well Data:DNR-Groundwater DNision Alaska, is >No Potable Were,Wells are in the Colville River Unit. w•r N CD3-3168 Plat Analysis >No Potable Nater Aquifers are n the Cokvire RNer Unit /I\V Faults 1/16/2015 OS .mime.+.e Csv 1.1120, * Map view depiction of seismically mapped faults and sub-seismic inferred faults (orientation unknown) from drilling data faults located within 1/2 mile radius of the reservoir well section (highlighted in red) in which the hydraulic fracture is planned CD3-316b Hydraulic Fracturing Sundry Application Section 12 CD3 -316B was completed in 2014 as horizontal producer in the Nechelik formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the increased production to be 500 bpd in 2015 if a successful stimulation is achieved. Radioactive tracers will be pumped during each stage. We will come back and log the well to confirm we have good isolation between the stages and that the entire interval was effectively stimulated. Additional documentation discussing the radioactive tracers are attached. Proposed Procedure: Schlumberger Pumping Services: (Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2800 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 170 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. • 360 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 150 bbls YF125ST w/4 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 160 bbls YF125ST w/6 ppa 16/20 Carbolite • Drop ball 1 • 360 bbls YF125ST Pad CD3-316b Hydraulic Fracturing Sundry Application • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 150 bbls YF125ST w/4 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 6 ppa 16/20 Carbolite • Drop ball 2 • 360 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 150 bbls YF125ST w/4 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 160 bbls YF125ST w/6 ppa 16/20 Carbolite • Drop ball 3 • 360 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 150 bbls YF125ST w/4 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 6 ppa 16/20 Carbolite • Drop ball 4 • 360 bbls YF125ST Pad • 140 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 140 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 150 bbls YF125ST w/4 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 160 bbls YF125ST w/ 6 ppa 16/20 Carbolite • Flush with 106 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 560,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. All radioactive material will be disposed of according to ConocoPhillips and regulatory standards. (see attachment for handling guidelines). , CD3-316b Hydraulic Fracturing Sundry Application GUIDELINES FOR USE OF RADIOACTIVE TRACERS DURING WELL STIMULATIONS ALASKA OPERATIONS 1. Only licensed personnel providing radioactive (R/A) tracing services are allowed to handle R/A material to, from, or at any location or facility. 2. The licensed R/A service company representative must maintain their company's license and carry MSDS sheets on location for all R/A isotopes present or in use. 3. The following equipment and paperwork shall be present prior to beginning any tracer operation: TLD Badge-for monitoring exposure Survey Meter-currently calibrated-capable of detecting beta and gamma radiation Warning Signs- Posted at the proper restricted area ( 2mr/hr) Rubber Gloves - For protecting hands while handling radiation Trash Bags- For collecting R/A waste Sponges- For cleaning in case of spill Rad Wash (or similar surfactant) - For decontamination Current License- Contains important information and documents MSDS Sheets- Identifies safety and health concerns Operating/Emergency Manual - Contains important procedures 4. The following procedures should be followed on each job involving R/A tracers: a. Radio contact between the R/A service personnel and frac personnel must be maintained. b. Restricted area must be identified and marked with signs. Access to this area must be restricted to authorized personnel. c. Any leaks in the frac line need to be checked for radiation before being repaired. d. Bleed off lines or lines used for treesaver safety should be laid to the flow-back tank. e. Surveys to check radiation levels should be made on the following areas before the job and documented: pumps, frac line, restricted area, wellhead, flowback tank. 5 After the job, the same areas should be checked again for radiation levels to insure that no significant amounts of radiation remain in the equipment or on the location. 6. The following injection procedures should be observed: a. Multiple injection points for back-up contingency. b. Ability to isolate with a valve the radioactive injection pump if malfunction develops. c. Loading in injector not more than 30 mCi at any one time, to reduce restricted area exposure and reduce spill potential. d. Do not inject directly into blender and/or manifold. Rather, isolate pump entry points. 7. The following procedures should be utilized during flowback of a well when R/A material has been used: a. People in charge of the flowback should be made aware that the R/A material has been used. b. All people contacting flowback fluids or proppants should wash the contacted areas with soap and water. c. Hands should be cleansed thoroughly before eating, drinking or smoking. d. Fluids and proppants should not be handled unnecessarily. e. Flow any returns to holding tank. CD3-316b Hydraulic Fracturing Sundry Application EMERGENCY PROCEDURES 1. Uncontrolled Sandout or Fluid Reversal - In the event of an uncontrolled sandout or fluid reversal, the following steps shall be taken to prevent personnel and environmental contamination. a. Remove all unnecessary personnel from the area and perform a survey prior to each exit unless other hazards require immediate personnel removal. b. Establish and secure a restricted area with ropes and the proper warning signs to indicate the nature of the hazard. c. Divert all flowback to the holding tank. d. After the flowback has ceased, initiate a complete survey of the area, equipment, vehicles and personnel. Indicate, on a sketch of the area, the magnitude of the contamination and inform all personnel of the nature and extent of the contamination. All items free of contamination shall be removed from the area in a manner to prevent the spread of contamination. e. Proceed to clean contaminated items until survey results are at ambient levels. Retain all decontamination fluid, towels, etc. for later disposal. f. Obtain samples of fluids, soil, and any other media. Assay samples on a portable survey instrument(using both the end window and gamma scintillation probes). Note on the sketch of the area the degree of contamination. Remove the top six inches of soil and contain in the tank. Also divert any standing fluid to the tank. Resurvey the locations where the contamination was removed. If the survey instrument does not record any reading over ambient levels, collect samples and submit to the Houston facility for analysis. g. If the sample results indicate the release was below the prescribed limits, then no subsequent action is necessary. h. If the sample results are above the prescribed limits, the area in question will be decontaminated until the limits are met. i. The material in the tank shall be disposed class II disposal well or held for decay. 2. Routine Sandout or Fluid Reversal - Routine sandout or fluid reversal shall be handled in accordance with the following procedures. a. If the fluid is diverted to a holding tank, sample the well fluid contained in the holding tank. If the instrument readings are above unrestricted area levels, post the tank with caution signs and erect a temporary personnel barrier. Notify the Radiation Safety Officer of the situation. ProTechnics must maintain control of the tank until release can be accomplished. Submit the samples for analysis. The sample analysis will indicate which of the following is the preferred disposal method for the contents of the tank: b. Dispose into a class II disposal well 3. Sandout/Fluid Reversal Limit- Every effort shall be made to keep releases of tracer material As Low As Reasonably Achievable (ALARA). The following limits apply only to our Zero Wash®products. The activity limit for disposal in a class II disposal well will be 1,000 pCi/gm (0.001 uCi/gm) of each Zero Wash® isotope. (Sc-46, Ir-192, & Sb-124). k. ATTACHMENT I:PUMP SCHEDULE Activity 2302 MAW Slurry Rate 20 Highest Pump Tdp PYOsIA1t Denary 2.74 Well Name 003-3160 Network number Nitrogen PRV Annulus Pressure Fluid Type YR2TST Proppam Used 1620CarboUb STEP STAGE COMMENTS FLUID PIMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. PUMP TIME X a TYPE RATE RATE STAGE CUM STAGE CIPS STAGE CUM SIZE GROSS CUM Breaker STAGE CUM (BRA) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (#Mge( (hh:mm:ss) (hH:mm:ss) 1 Injection test WF127 20 20.0 170 170 7129 7129 170 170 5.0 00:08:29 00:08:29 Hard shutdown;monitor pressure. 0.0 00:00:00 00:08:29 2 Pad YF127ST 20 20.0 80 250 3360 10489 80 250 5.0 00:04:00 00:12:29 3 1 Sand YF127ST 20 19.2 50 300 2100 12589 2012 2012 1620CarboLne 48 298 5.0 00:02:30 00:14:59 a Spacer YF127ST 20 20.0 80 380 3360 15949 80 378 5.0 00:04:00 00:18:59 5 Displacement WF127 20 20.0 170 549 7129 23078 170 547 5.0 00:08:29 00:27:28 Hard shutdown;monitor pressure. FLUID PUMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME Enceps. PUMP TIME STEP ST GE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker STAGE CUM a PPA (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (OIMgal) (BBL) (BBL) 6 PAD YF127ST 20 20.0 360 909 15120 38198 0 2012 0 360 907 5.0 00:18:00 00:45:28 7 1 FLAT YF127ST 20 '9.2 140 1049 5880 44078 5633 7,645 1600 arboLne 134 1042 5.0 00:07:00 00:52:28 8 2 FLAT YF127ST 20 78.4 140 1189 5880 49958 10814 18,459 1620arboLke 129 1170 6.0 00:07:00 00:59:28 9 3 FLAT YF127ST 20 -- 150 1339 6300 56258 16707 35,166 1620 arm.. 133 1303 6.0 00:07:30 01:06:58 10 4 FLAT YF127ST 20 17.0 150 1489 6300 62558 21446 56,612 r6200.r.Lee 128 1430 7.0 00:07:30 01:14:28 1i 5 FLAT YF127ST 20 16.4 160 1649 6720 69278 27568 84,180 1620CarbaL. 131 1562 8.0 00:08:00 01:22:28 12 6 FLAT YF127ST 20 15.8 160 1809 6720 75998 31935 116,115 ism CerboL6e 127 1688 9.0 00:08:00 01:30:28 13 Ball 1.720" DISPLACE VF127ST 20 20.0 20 1829 840 76838 0 116,115 20 1708 5.0 00:01:00 01:31:28 14 PAD YF127ST 20 20.0 360 2189 15120 91958 0 116,115 360 2068 5.0 00:18:00 01:49:28 15 1 FIAT YF127ST 20 19.2 140 2329 5880 97838 5633 121,748 162oCerboLne 134 2203 5.0 00:07:00 01:56:28 16 2 FLAT YF127ST 20 18.4 140 2469 5880 103718 10814 132,562 162oarboLne 129 2331 6.0 00:07:00 02:03:28 17 3 FLAT YF12751 20 17.7 150 2619 6300 110018 16707 149,269 reap arboLte 133 2464 6.0 00:07:30 02:10:58 15 4 FLAT YF127ST 20 17.0 150 2769 6300 116318 21446 170,715 1620arboLbe 128 2592 7.0 00:07:30 02:18:28 19 5 FLAT YF127ST 20 16.4 160 2929 6720 123038 27568 198,283 16211 Carbone 131 2723 8.0 00:08:00 02:26:28 20 6 FLAT YF127ST 20 15.8 160 3089 6720 129758 31935 230,218 Isco area. 127 2850 9.0 00:08:00 02:34:28 21 Ball 1.78" DISPLACE YF127ST 20 20.0 20 3109 840 130598 0 230,218 20 2870 5.0 00:01:00 02:35:28 22 PAD YF127ST 20 20.0 360 3469 15120 145718 0 230,218 360 3230 5.0 00:18:00 02:53:28 23 1 FLAT YF127ST 20 19.2 140 3609 5880 151598 5633 235,851 160400rbokee 134 3364 5.0 00:07:00 03:00:28 24 2 FLAT YF127ST 20 18.1 140 3749 5880 157478 10814 246,665 ism CerbaOe 129 3492 6.0 00:07:00 03:07:28 25 3 FLAT YF127ST 20 150 3899 6300 163778 16707 263,371 ono Cerea. 133 3625 6.0 00:07:30 03:14:58 26 4 FLAT YF127ST 20 17.0 150 4049 6300 170078 21446 284,817 tem cerea. 128 3753 7.0 00:07:30 03:22:28 27 5 FIAT YF127ST 20 16.1 160 4209 6720 176798 27568 312,386 Nara 50re0.. 131 3884 8.0 00:08:00 03:30:28 28 6 FLAT YF127ST 20 15.8 160 4369 6720 183518 31935 344,321 NI250ark.. 127 4011 9.0 00:08:00 03:38:28 29 Ball 1.841" DISPLACE YF12751 20 20.0 20 4389 840 184358 0 344,321 20 4031 5.0 00:01:00 03:39:28 30 PAD YF127ST 20 20.0 380 4769 15960 200318 0 344,321 380 4411 5.0 00:19:00 03:58:28 31 1 FLAT YF127ST 20 19.2 110 4879 4620 204938 4426 348,747 1620 arm.. 105 4516 5.0 00:05:30 04:03:58 32 2 FLAT YF127ST 20 184 110 4989 4620 209558 8496 357,243 1620 GrbeL. 101 4617 6.0 00:05:30 04:09:28 33 3 FLAT YF127ST 20 17.7 110 5099 _ 4620 214178 12252 369,495 Into 02rboL. 97 4714 6.0 00:05:30 04:14:58 34 4 FLAT YF127ST 20 17.0 110 5209 4620 218798 15727 385,222 taloarboL. 94 4808 7.0 00:05:30 04:20:28 35 5 FLAT YF127ST 20 10.4 110 5319 4620 223418 18953 404,175 16200.reeL. 90 4898 8.0 00:05:30 04:25:58 36 6 FLAT YF127ST 20 15.8 120 5439 5040 228458 23951 428,126 teaoarbeLee 95 4993 9.0 00:06:00 04:31:58 37 7 FLAT YF127ST 20 15.3 140 5579 5880 234338 31508 459,634 1620 00rboL. 107 5101 9.0 00:07:00 04:38:58 38 Ball .904" DISPLACE YF127ST 20 20.0 20 5599 840 235178 0 459,634 20 5121 8.0 00:01:00 04:39:58 39 PAD YF127ST 20 20.0 400 5999 16800 251978 0 459,634 400 5521 8.0 00:20:00 04:59:58 40 FLAT YF127S1 20 19.2 100 6099 4200 256178 4024 463,658 1620 area. 96 5616 8.0 00:05:00 05:04:58 41 FLAT YF127ST 20 18.4 100 6199 4200 260378 7724 471,382 1620 arboLEe 92 5708 9.0 00:05:00 05:09:58 42 FLAT 1F127ST 20 17.E 100 6299 4200 264578 11138 482,520 16200.rbal. 88 5797 9.0 00:05:00 05:14:58 43 FLAT YF127ST 20 17.0 100 6399 4200 268778 14297 496.818 1620 00rtel. 85 5882 10.0 00:05:00 05:19:58 44 FLAT YF127ST 20 164 100 6499 4200 272978 17230 514,048 term arm.. 82 5964 11.0 00:05:00 05:24:58 45 FLAT YF127ST 20 15.8 100 6599 4200 277178 19959 534,007 te20 Carbollte 79 6043 12.0 00:05:00 05:29:58 46 FLAT YF127ST 20 15.3 100 6699 4200 281378 22506 556,513 faro area. 77 6120 11.0 00:05:00 05:34:58 47 FLAT YF127ST 20 14.8 120 6819 5040 286418 29865 586,378 two area. 89 6209 12.0 00:06:00 05:40:58 88 FLUSH WF127 20 20.0 89 6908 3721 290139 89 6297 16.0 00:04:25 05:45:23 49 FLUSH Freezeprotecl 20 20.0 17 6925 731 290870 17 6315 00:00:52 05:46:15 TOTALS 6925 586378 6315 05/46/15 SO and obtain ISIP a 5 min SIP. WATER VOL FLUSH INFORMATION WFU AND TREATINGPRESSURF INFORMATION WELL AND RESERVOIR INFORMATION DataFRAC- 547 bbls VOL TO TOP PORT=109.6 BIP GRADIENT- 0.70 BHP=4927 psi MAIN JOB- 5750 bbls Extra 450 bbls -UNDERFLUSH>,Q FLUID SG- 1.03 a TBG ERIC=5430 psi TOTAL JOB- 6297 bbls FLUSH VOL=106 FRICTION LOSS- 0.35 a PERF FRIG=0000 psi 6747 bbls -DOD contingency MD TO TN Tal- 10761 -RYE HEAD=3144 psi Angle Through Peds-92° GENERAL JOB INFO TAD BTM SLEEVE- 7039 EST.MAX WHP=7213 psi WOO Azimuth(f/North).320° TANKS REQUIRED PIPE TIME(mm).5.5 MD FIRST SLEEVE- 15568 14.99 <-450 bbl per tank pumpable PAD/SLURRY RATIO Parity=18% TOTALS FOR ALL STAB Stage l 29% UPP.TUBING SIZE= 3.5000 0.0087 SUIC,Y Stage 229% Rsserwir Pressure-3210 Water 6747 bels Stage 329% Permeability-1 Xlink fluid 5869 bele Stage 432% CASING SIZE- 4.5000 04152 bbisAt Temperature-150 IJnear fluid 428 bbls Stage 533% Proppam 586,378 lb Freeze Pmt 70 obis Pump time 0546:15 bh:mm:es Stage Ports MD Dbplact M275 75 lb name it volume Seat Size D047 45 gal Stage 1 15568 166.7 bels 1.625 1475 1,806 lb Stage 2 14637 152.6 ebb 1.685 LOTS 530 gal Stage 3 13695 1383 bels 1.785 F103 265 gal Stage 4 12753 123.9 ebb 1.805 J532 1,251 gal Stage 5 11808.6 109.6 bob 1.866 M002 150 lb 8882 1,671 gal • 13-01-15 t Schlumberger Client: ChillipsAlaskalnc. Well: CD3-316B Basin/Field: Colville-Prudhoe Basin Alpine State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 1/14/2015 4:18 PM Report ID: RPT-33820 Fluid Name&Volume Additive Additive Description Concentration B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 1,671.0 Gal D047 AntiFoam Agent 0.2 Gal/1000 Gal 45.0 Gal F103 Surfactant 1 Gal/1000 Gal 265.0 Gal J475 Breaker 6.8 Lb/1000 Gal 1,806.0 Lb YF13OST:WF130 264,478 Gal J532 Crosslinker 4.7 Gal/1000 Gal 1,251.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 530.0 Gal M002 Additive 0.6 Lb/1000 Gal 150.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 75.0 Lb S522-1620 Propping Agent varied concentrations 586,378.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* -78% 66402-68-4 Ceramic materials and wares,chemicals -21% 64742-47-8 Distillates(petroleum),hydrotreated light <1% 9000-30-0 Guar gum <1% 56-81-5 1,2,3-Propanetriol <1% 1303-96-4 Sodium tetraborate decahydrate <0.1% 7727-54-0 Diammonium peroxodisulphate <0.1% 107-21-1 Ethylene glycol <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 67-63-0 Propan-2-ol <0.1% 111-76-2 2-butoxyethanol <0.1% 25322-69-4 Polypropylene glycol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 34398-01-1(7E0, Linear C11 alcohol ethoxylate(7eo, <0.01% 34398-01-1(3E0: Linear C11 alcohol ethoxylate(3eo; <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 7647-14-5 Sodium chloride <0.01 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01 % 1310-73-2 Sodium hydroxide(impurity) <0.01 % 7631-86-9 Silicon Dioxide <0.01 % 10043-52-4 CALCIUM CHLORIDE <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 68153-30-0 Amine treated smectite clay <0.001% 10377-60-3 Magnesium nitrate <0.001% 9002-84-0 poly(tetrafluoroethylene) <0.001% 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001% 7786-30-3 Magnesium chloride <0.001% 7447-40-7 Potassium chloride(impurity) <0.001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001% 14808-60-7 Crystalline silica(impurity) <0.0001% 14464-46-1 Cristobalite <0.0001% Total 1Cu *Mur water is supplied by the client Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 I -,--; -5 2 TD ,- -E 3 ' o a) _c 0 V N co Z L COa_ s) (ci oci) N- 0) I (13 CO7) a 0 O. c a o 0 0 0 0 0 0 0 a V d ,— hi C v L6 (0 O a) a) a) a) m CD _Co J J J J J J a) U U U U U U 2 o 0 0 0 0 0 'p NNNNNN 0/111%, al CO CD CO CO CO C.0 U) CD 0. F- Cl) TD o E O O o 0 0 0 0 0 tri .E.i ID V) O U - 1.(5 N N N N N N N CD(1) C. Co 0 0) N a, O O O Q CD .w, a;g = -- o v rn o7 0o N co 0 0 0) U) y 7 7 CO co N ch N ch N ,// COLO x-- O CZ U CCS u) coH )-- H H H H N- co N- N- N- co N- N- SII Z NNNNNNNN LL LL LL LL LL LL LI_ LL 5 >- >- >- >- >- >- >- } I I I LLLL C y Q� E a E O 0000000 O d Q. E N N N N N N N N F- L (/) a < < < CL � < = ti N U as CL CL CL 0 _� aE O co o 0 0 0 o CV r— O N-- .5 Z N M CO N LL CO N-- ,. • 1= :4..c, 0 (f) p 0la) � 0 MOO C L .W C C6 E to O O O COM `}' .- —co 0 J w p 73 O O)� OO NO _� c c (D c 'L L O .c O (6 O = p eg c2) Q -� L U) 0 4- 0 CO U C(1) 0 •0) Q � 0- -I-0 I2 .5) — Ci I— —I — -C -0 -CD 8 -sczo a) > E 41 •TD -15 p Q = ♦Ocam OU O C O Q ~ °° L }' w . . C � p� E � (?) 2 2 2 t3 a) cl. V C) LL = G. o ca Q. _ L vi V. 2 -0 -a 0 Z 0 0 mc }, � - LL LL CD >+ — U) o 2 co _ — " -0 = — — L Rf Rf Q 0 "0 0) L cu to N co a) O 0 c 'O O •_ W Q •- E •O -4 c O O to v) -0O = •- -00 — E O u) O O O �- N . 0 I r CD3-316b Hydraulic Fracturing Sundry Application Section 13 Post-fracture wellbore cleanup: Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) RECEIVED JAN 222015 Victoria, AOGCC Attached are 2 copies of the notification we sent out for the land owners affected by the CD3-316b frac. Our Land and Legal groups thought you might want a copy. Let me know if you have any questions. Thanks, -Robbie Robert Blakney ConocoPhillips Senior Completions Engineer 907 -265 -6417 (office) 505—804 - 5246 (cell) ATO 1740, 700 G st. Anchorage, AK P.0.Box 100360 Anchorage,AK 99510-0360 ConocoPh i I I i ps Phone:: 907-263-6297 January 20,2015 CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) CD3-316B Well Colville River Unit,Alaska CPAI No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. as Operator and on behalf of the Colville River Unit working interest owners ("CPAI"), hereby notifies you that it is submitting an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.055 ("Application")for the CD3-316B Well(the "Well"). The Well has been drilled as a directional horizontal well on leases ADLs 364471, 37210, and 372104 as depicted on Exhibit 1 and has locations as follows: Surface Location: 'FNL, 'FEL, Section 5,T12N,R5E,UM; Target Location: _'FNL, 'FEL, Section 4,T12N,R5E,UM; Bottomhole Location: 'FNL, 'FEL, Section 32,T13N,R5E,UM. Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section, as ellipses ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Upon request CPAI is glad to make a complete copy of the Application available to you. If you have any questions or require any additional information, please contact me at the address or phone number shown below. Sincerely, Dora I. Soria Staff Landman ConocoPhillips Alaska Inc 700 G Street Anchorage,AK 99510 Phone: (907)265 6297 Attachments: Exhibits 1 &2 & ...e Exhibit 1 • Unit all t ADL364470 ADL39139•1.. ADL364472 ADL3885271 ADL389725 ADL364471 r ADL384215 Colville COQ River zp, Unit Unit 1 0� i -- • AD 380092 C 3 I .... 1 mit a -. ADL372105 , ADL372104 ADL372103 • • AL025528_.... Legend ••..Mbll Trajectory a>•Reservoir Section Reservoir Section 1/2 Mile Radius A DL391577 All Trajectory 1/2 mile Radius • Unit DCPAI Operated Units ADL025538 Q Other Operated Units _ Lease Owner 708148 CPAI _ ADL392969 E:::::REPSOL REFERENCES: Ills.' Nall Data:ConocoPhillips Alaska Nklls Database Ac ConocoPh i I I i ps Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil 8 Gas Leases 1/12/2015 Alaska,Inc. Nater Well Data:DNR-Groundwater Division N W s No Potable Nater ens are in the Coknle River Unit. CD3-316B Plat Analysis s No Potable Water Aquifers are in the Colville River Unit A Leases 1116/2015 0.5 .mstee,oacaa ms,mre Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator& Owner: ConocoPhillips Alaska,Inc. 700 G Street(Zip 99501) P. O. Box 100360 Anchorage,AK 99510 Attention: Patrick J. Wolfe, Manager North Slope Development Owners(Non-Operators): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver, CO 80202 Attention: Mike Nixson,Director Land -Alaska Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage,AK 99503-5948 Attention: Paul Decker,Acting Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage,AK 99503-5948 Attention: Paul Decker,Acting Director Cc: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa Imm, Resource Development Manager Mr. Isaac Nukapigak, President Kuukpik Corporation P.O. Box 89187 Nuiqsut,AK 99789 • :onocoPh �' P.0.Box 100360 i l l u ps Anchorage,P : 026K6297 99510-0360 Phone: 907-263-6297 January 20,2015 CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) CD3-316B Well Colville River Unit,Alaska CPAI No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. as Operator and on behalf of the Colville River Unit working interest owners ("CPAI"), hereby notifies you that it is submitting an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.055 ("Application")for the CD3-316B Well(the "Well"). The Well has been drilled as a directional horizontal well on leases ADLs 364471, 37210, and 372104 as depicted on Exhibit 1 and has locations as follows: Surface Location: 'FNL, 'FEL, Section 5,T12N,R5E,UM; Target Location: _'FNL, 'FEL, Section 4,T12N,R5E,UM; Bottomhole Location: 'FNL, 'FEL, Section 32,T13N,R5E,UM. Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section, as ellipses ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Upon request CPAI is glad to make a complete copy of the Application available to you. If you have any questions or require any additional information, please contact me at the address or phone number shown below. Sincerely, Dora I. Soria Staff Landman ConocoPhillips Alaska Inc 700 G Street Anchorage,AK 99510 Phone: (907)265 6297 Attachments: Exhibits 1 &2& r Exhibit 1 u��1rr�k A t.,fy, oADL391394 ni nitADL364470 ADL364472 tt...........tt..m. ADL388527 ADL389725 ..-......... _ __ l ADL364471 ADL384215 , Colville CION River \Uflit Unit • • CD3 ADL380092 4kcp3. I ADL372105 ADL372104 ADL372103 1 I 1 I Legend AC.026626.......... ••••VIII Trajectory swim Reservoir Section Reservoir Section 1/2 Mile Radius ADL391577 NMI Trajectory 1/2 mile Radius Unit CPAI Operated Units ADL025538 Other Operated Units _.. Lease Owner 70 8 148 CPAI . ADL392969 REPSOL CAT *7 Nall Data:CanocoPhillips Alaska Walls DatabaseATDB ConocoPh i I lips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide us Gas Leases 1/12/2015 Alaska,Inc. Nater Well Data:DNR-Groundwater Division >No Potable Nater Walls are in the CON�IIe River Unit. N CD3-316B Plat Analysis >No Potable Water Aquifers are in the Colville Rarer Unit /I\V NG• Leases 1/16/2015 q"}2 0'+ 1'! Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator& Owner: ConocoPhillips Alaska,Inc. 700 G Street(Zip 99501) P. O. Box 100360 Anchorage,AK 99510 Attention: Patrick J. Wolfe,Manager North Slope Development Owners(Non-Operators): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver, CO 80202 Attention: Mike Nixson,Director Land-Alaska Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage,AK 99503-5948 Attention: Paul Decker,Acting Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage,AK 99503-5948 Attention: Paul Decker,Acting Director Cc: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa Imm,Resource Development Manager Mr. Isaac Nukapigak,President Kuukpik Corporation P.O. Box 89187 Nuiqsut,AK 99789 WNS PROD CD3-316B ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status II no!(°) MD(ftKB) Act Btm(ftKB) torr w" 501032055903 FIORD KUPARUK PROD 94.04 11.722.22 17,492.0 ,.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-3168,5/21/20141108.08 PM SSSV:TRDP Last WO: 36.63 2/122008 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason SIDETRACK,GLV C/O haggea 5/12/2014 Casing 84n'ngs- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ..- - --- --- CONDUCTOR Insulated 16 15.250 36.0 114.0 114.0 62.50 Hd0 Welded • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER.316- ;I�� SURFACE 95/8 8.835 36.3 2,744.8 2,475.9 40.00 L-80 MBTC --Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade 'Top Thread In HT INTERMEDIATE 7 6.276 344 10,995.2 6,953.1 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D(...WI/Len(I...Grade 'Top Thread • LINER 4 12 3.958 10,761.0 17,486.6 6,977.3 12.60 L-80 IBT 1..,Liner Details Nominal ID _ ^ Top(MO) Top(TVD)(ftKB) Topineil") Item Des Com (in) 10,761.0 6.862.8 63.93 PACKER BAKER"HRD-E"ZXP LINER TOP PACKER 3.875 CONDUCTOR Insulated,36 0- ll 114.0 10,787.5 6.874.4 64.42 HANGER BAKER FLEX-LOCK LINER HANGER 3.920 10,797.1 6,878.5 64.59 BUSHING CROSS OVER BUSHING(4.5"H521 x 4.5"IBT) 4.000 11,811.8 7,057.1 93.72 FRAC SLV HES FRAC SLEEVE 1.866 12,756.7 7,029.9 90.14 FRAC SLV HES FRAC SLEEVE 1.805 SAVETY VLV;2,115.9 _7( 13,697.8 7,024.5 90.27 FRAC SLV HES FRAC SLEEVE 1.745 14,640.7 7,015.3 91.01 FRAC SLV HES FRAC SLEEVE 1.685 VALVE;21254 - 15,572.2 7,039.1 89.48 FRAC SLV HES FRAC SLEEVE 1.625 16,514.6 7,013.0 91.36 FRAC SLV HES FRAC SLEEVE 1.565 17,457.6 6,978.8 93.04 FRAC SLV BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 SURFACE;36.3-2.744,6- • . 17,464.1 6,978.5 93.04 FRAC SLV BAKER-PRESSURE ACTIVATED FRAC SLEEVE 3.860 17,470.5 6,978.1 93.04 VALVE WELLBORE ISOLATION VALVE 1.500 GAS LIFT;4,429.1 MI 17,483.1 6,977.5- 93.04 REAMER BAKER 5.75"EZ REAM w/float 3.890 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(It..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/2x3 1/2 312 2.992 31.6 10.774.1 6,868.5 9.30 L-80 EUE GAS LIFT;8,407.8 ._. @119.5 Completion Details Nominal ID Top(11KB) Top(TVD)(MB) Top Ind(•) Item Des Com (in) • • 31.6 31.6 0.00 HANGER FMC TUBING HANGER 4.000 119.7 119.7 0.61 XO Reducing XO-4.5"IBT(B)x 3.5"EUE(P) 2.992 GAS LIFT;10,453.1 -- 2,115.9 2,012.4 35.69 SAVETY VLV CAMCO TRMAXX-5E w/2.812"X profile 2.812 1 10,512.1 6,746.5 60.68 GAUGE 3.5"NDPG(SOLID GAUGE MANDREL) 2.992 GAUGE;10,512.0 L i 10,539.5 6,759.9 60.85 PACKER BAKER PREMIER PACKER 2.880 Vail !; 10,557.7 6,768.8 61.10 BLAST RING TN-110 Hyd 563 R2 tbg w/28'CARBIDE BLAST RINGS 2.992 PACKER;10,539.5 __ 10,619.9 6,798.4 61.98 SLEEVE-O PETROQUIP SLIDING SLEEVE OPEN 5/14/14 2.813 IPERF;10,563,0-10583.0-Y 1 10,635.9 6,805.9 62.17 PACKER BAKER PREMIER PACKER 2.870 >', 10,687.2 6,829.6 62.76 NIPPLE HES XN NIPPLE No-Go w/RHC 2.750 SLEEVE-O;10,619.9 5i- ¶111 10,758.1 6,861.5 63.87 NIPPLE SHEAR PINNED FLUTED NO-GO SUB 3.000 PACKER;10,635.9 'F ® 1? 10,759.1 6,862.0 63.89 SOS SHEAR SCREW BODY(Located 1.55'up Fully Located) 3.000 ). i as 'r 10,773.1 6,868.1 64.15 MULE SHOE FLUTED MULESHOE WLEG 2.990 NIPPLE;10,687.2 i I '- Perforations&Slots NIPPLE;10,758.1 1>1F., . Shot SOS;10,759.1 Dens Top(NB) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,563.0 10,583.0 6,771.3 6,780.9 4/20/2014 6.0 IPERF Peforate Kup C MULE SHOE;10,773,1 Cement Squeezes --- Top(ND) Btm(ND) 1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn r 10,761.0 11,128.0 6,862.8 6,990.5 Cement Plug 4/4/2014 Plugged back to cover problematic shales and kick off • Mandrel Inserts `i I'`, St ati INTERMEDIATE;34.5-10,995.2-' s on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Corn i 1' 4,429.1 3,425.9'CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,092.0 5/4/2014 2 8,407.8 5,606.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,120.0 5/4/2014 3' 10,453,1 6,717.7 CAMCO -KBMG 1 GAS LIFT OV BK 0.313 0.0 5/5/2014 ■ Notes:General&Safety End Date _ Annotation 3/6/2014 NOTE: INTERMEDIATE CASING STRING HAS A TN-110SS TAIL(top 9983.36'MD). a 3/6/2014 NOTE:WELL SIDETRACKED TO"B" I Ii (♦ I I I I LINER;10,761.0.17,486.6 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. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but isart of the historyfile. P To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Alpine Rig: Doyon 19 Date: April 21, 2014 Surface Data Logging End of Well Report CD3-316B CD3-316B PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. 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: CD3-316B & CD3-316B PB1 Field: Alpine Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20559-03-00 (CD3-316B) 50-103-20559-70-00 (CD3-316B PB1) Sperry Job Number: AK-AM-0901152148 Job Start Date: 06 March 2014 Spud Date: 15 March 2014 Total Depth: 17942’ MD, 6975’ TVD (CD3-316B) 11496’ MD, 7045’ TVD (CD3-316B PB1) North Reference: True Declination: 18.96° Dip Angle: 80.86° Total Field Strength: 57593 nT Date Of Magnetic Data: 15 March 2014 Wellhead Coordinates N: North 70° 25’ 9.315” Wellhead Coordinates W: West 150° 54’ 41.768“ Drill Floor Elevation 49.5’ Ground Elevation: 13.2’ Permanent Datum: Mean Sea Level SDL Engineers: David McKechnie, Jeremy Tiegs, Ashlee Charters, Tyler Dretke SDL Sample Catchers: Ben Birky, Danielle Dawson, Chris Ward, David Durst, Ashley Wilderom Company Geologist: Justine Boccanera Company Representatives: D. Mickey, K. Harding, A. Dorr, D. Lowe SSDS Unit Number: 109 DAILY SUMMARY 03/06/2014 Completed rig move to CD3-316B. Gas: No significant gas data was collected. Fluids: No losses. 03/07/2014 Took on brine to pits. Rigged up hard lines to the tree. Tested the mud lines and tested the lines to the tiger tank. Pumped on tubing. Pumped down the inner annulus and tested to 2000 pounds per square inch (psi). Pulled the back pressure valve. Rigged and displaced well to 9.6 pounds per gallon (ppg) brine. Observed well and then rigged down the lines. Set the back pressure valve and then tested it. Nippled down the tree and then nippled up and tested the blow out preventer. Gas: No significant gas data was collected. Fluids: No losses. 03/08/2014 Finished testing blow out preventer. Pulled blank plug and back pressure valve. Made up landing joint. Rigged up casing tools. Pulled hanger to the rig floor. Laid down landing joint and hanger. Laid down 4.5” tubing, removed clamps and spooled control line. Rigged down casing equipment. Set 9” inner diameter wear bushing. Made up cast iron bridge plug bottom hole assembly (BHA). Ran in to the hole to 3120’ MD. Set cast iron bridge plug. Pulled out of hole to 3078’ MD. Circulated bottoms up. Rigged up and tested the plug. Slipped and cut the drill line. Serviced the top drive and drawworks. Circulated another bottoms up. Gas: No significant gas data. Fluids: No losses. 03/09/2014 The well was observed for static conditions. Pulled out of the hole and laid down BHA. Rig floor was cleaned and cleared. Made up casing cutter BHA. Ran in to the hole. Tagged up on plug. Cut the 7” casing at 3120’ MD. The well was observed to have flowing conditions. Mud weight was increased in the active system to 10.0 ppg. The well was observed to have slower flowing conditions. Mud weight was increased in the active system to 10.5 ppg. The well was observed to have static conditions. Circulated diesel out of 9 ⅝” × 7” annulus to tiger tank. The well was observed to have static conditions still. Pulled out of the hole and laid down BHA. The well was observed to still have static conditions. Gas: The maximum circulating gas was 14 units, and the average gas was 3 units. Fluids: No losses. 03/10/2014 Changed out upper rams to 7”. Pulled wear ring and set test plug. Tested the rams. Rigged down testing equipment. Set the wear ring. Made up spear BHA. Ran in to the hole and engage 7” casing. Pulled up casing tools. Pulled the hanger to the floor. Broke hanger and set down the spear. Pumped a dry job. Laid down 7” casing. Rigged down casing equipment. Clean and cleared the rig floor. Changed out top pipe rams. Rigged up and test the blow out preventer. Rigged down testing equipment. Gas: The maximum circulating gas was 14 units, and the average gas was 5 units. Fluids: No losses. 03/11/2014 Rigged up 5” drill pipe elevator. Made up spear BHA. Serviced Iron Roughneck and drawworks. Laid down 1 stand of 4” heavy weight drill pipe. Ran in to the hole with spear BHA to 2517’ MD. Circulated and conditioned mud. Ran in to the hole and engaged 7” casing. Casing was grappled, jarred and worked with a max pull of 445k multiple times, but the casing was not dislocated. Pulled out of the hole and laid down the spear BHA. Made up 7” casing cutter BHA. Ran in to the hole to 2860’ MD. Cut 7” casing again. Confirmed the cut and circulated bottoms up. Pulled out of the hole and laid down 7” casing cutter BHA. Picked up spear BHA. Gas: The maximum circulating gas was 552 units, and the average gas was 34 units. Fluids: No losses. 03/12/2014 Ran in to the hole to 2517’ MD with spear BHA. Pulled casing at 160-445k, and fired jars multiple times. After stretching, the pipe broke free. From 2860’ MD to 2720’ MD, a 30 barrel return was noted. Pulled out bad 4” drill pipe from 2720’ MD to 2689’ MD. Circulated and conditioned mud at 7 barrels per minute (bpm). Observed well for static conditions. Pulled out of the hole to 543’ MD. Laid down BHA and 7” cutting joint. Rigged up casing equipment. Cut off 7” casing up to 215’ MD. Rigged down casing equipment. Rigged up tubing equipment. Ran in to the hole with 3.5” cement string to 3149’ MD. Circulated and conditioned mud. Gas: The maximum circulating gas was 4695 units, and the average gas was 491 units. Fluids: No losses. 03/13/2014 Pumped cement as per program. Pulled out of the hole to 2537’ MD and pumped nut plug sweep. Noted max gas of 369 units. Monitored well to be static. Pulled out of the hole to surface and rigged down cement equipment. Laid down 4” drill pipe. Picked up 5” drill pipe at report time. Gas: The maximum circulating gas was 369 units, and the average gas was 9 units. Fluids: No losses. 03/14/2014 Continued picking up 5” drill pipe. Tested blow out preventer. Rigged down testing equipment and picked up BHA. Calibrated and tested gas equipment. Began running in the hole with drillout assembly. Gas: The maximum circulating gas was 96 units, and the average gas was 17 units. Fluids: No losses. 03/15/2014 Shallow tested MWD tools. Could not establish communication. Tripped out of the hole for MWD tool swap. Ran in to the hole and achieved satisfactory shallow test. Ran in to the hole to 2346’ MD and tested casing to 3500 psi with satisfactory results. Washed and reamed to 2760’ MD, drilled out cement and 20’ of formation to 2830’ MD. Encountered 9212 units of formation gas at 2818’ MD. Isotube sample was collected. Troubleshot gas chromatograph. Pulled out of the hole to 2724’ MD and displaced to 10.5 ppg LSND. Performed formation integrity test to 14.4 ppg. Rigged down test equipment and washed down to bottom to drill out. Drilled ahead to 2913’ MD and encountered 10,000 units of formation gas. Isotube sample collected. Gas: The maximum formation gas was 10,000 units, and the average gas was 431 units. Fluids: No losses. Geology: Samples primarily consisted of 80% white to gray, fine to very fine grained, rounded to sub rounded, moderately sorted, loose, friable sandstone with traces of pyrite, and 20% siltstone. 03/16/2014 Continued tripping to bottom and drilled ahead to 2894’ MD. Encountered 9500 units of formation gas. Isotube sample was collected. Circulated and conditioned gas to a background of 300 units while reciprocating pipe. Increased mud weight to 10.7 ppg. Drilled stand to bottom, exposing 19’ of formation. Encountered max gas of 10000 units. Isotube sample was collected. Conditioned to a background of 170 units. Drilled ahead two stands and encountered 10000 units at bottoms up for each stand. Isotube samples were collected for each peak. Formation samples consisted of 100% sandstone. Continued drilling ahead, noting a drop in gas reading from 10000 units to 750 units at lag depth of 3068’ MD. Noted formation change, respectively. Samples consisted of 70% clay and 30% sandstone. Continued drilling ahead. Encountered 9830 units as a result of a pack off at 3076’ MD. Isotube sample was collected. Continued drilling ahead to 3725’ MD with an average gas of 122 units. Backreamed out of the hole to surface. Noted gas peak of 2016 units at 2980’ MD. Gas: The maximum formation gas was 10000 units, and the average gas was 567 units. Fluids: No losses. Geology: Samples primarily consisted of 70% gray, gummy clay and 30% white to gray, fine to very fine grained, rounded to sub rounded, moderately sorted, loose, friable sandstone. 03/17/2014 Continued backreaming out of the hole to 2980’ MD. Noted peak gas of 2016 units. Isotube sample was collected. Resumed backreaming to 2724’ MD. Circulated 3 bottoms up at the shoe. Monitored the well to be static. Pulled out of the hole on elevators to 647’ MD. Flow check was static. Pulled out of the hole to surface and laid down BHA. Made up BHA #3 and tripped in to the hole to 1389’ MD. Performed a satisfactory shallow MWD tool test. Continued running in to the hole to 3655’ MD. Washed stand to bottom. Noted 1040 units of trip gas. Gas: The maximum connection gas was 1040 units, and the average gas was 50 units. Fluids: No losses. Geology: Samples primarily consisted of 80% light gray to brown, amorphous, very soft, sandy and silty clay, 10% white to gray, fine to very fine grained, rounded to sub rounded, moderately sorted, loose, friable sandstone with traces of pyrite, and 10% gray, very fine grained, brittle siltstone. 03/18/2014 Continued drilling ahead to 4418’ MD with an average background gas of 46 units. Pulled out of the hole to change out BHA. Backreamed out of the hole to the casing shoe, noting max gas of 424 units at 2813’ MD. Circulated bottoms up inside casing. Pulled out of the hole on elevators to 620’ MD. Flow check was static. Continued pulling to surface and laid down BHA. Tested and calibrated gas equipment. Gas: The maximum circulating gas was 424 units, and the average gas was 46 units. Fluids: No losses. Geology: Samples primarily consisted of 55% light gray to brown, argillaceous, amorphous, very soft, sandy and silty clay, 35% white to gray, fine to very fine grained, rounded to sub rounded, moderately sorted, unconsolidated, friable sandstone with traces of pyrite, and 10% light gray, very fine grained, brittle siltstone. 03/19/2014 Made up BHA and tripped in the hole to 2662’ MD. Slipped and cut drill line. Performed satisfactory shallow pulse MWD tool test. Ran in the hole to 3609’ MD and measurement after drilling (MAD) passed to 4418’ MD. Noted max gas of 436 units at 3609’ MD. Continued drilling ahead. Gas: The maximum circulating gas was 436 units, and the average gas was 46 units. Fluids: No losses. Geology: Samples primarily consisted 55% light gray, sticky, amorphous clay, 35% white to gray, fine to very fine grained, rounded to sub rounded, moderately sorted, unconsolidated sandstone, and 10% light gray, very fine grained, brittle siltstone. 03/20/2014 Drilled ahead to 6455’ MD at an average rate of penetration of 145 feet per hour and average background gas of 114 units. Encountered max formation gas of 1112 units at 5633’ MD. Formation sample at gas peak consisted of 65% fine grained sandstone, 25% clay and 10% siltstone. Back reamed full stands prior to making up connections. No significant connection gas noted. Samples in K-2 formation consisted of 55% very fine grained sandstone, 35% silt, and 10% siltstone. Gas: The maximum formation gas was 1112 units, and the average gas was 114 units. Fluids: No losses. Geology: Samples primarily consisted of 55% white, light gray to gray, translucent, amber, light brown, fine to very fine grained, rounded to sub rounded, moderately sorted, unconsolidated sandstone, 35% light gray to gray, brown, very fine grained, gritty, unconsolidated silt, and 10% light gray to gray, very fine grained, blocky, subangular, friable siltstone. 03/21/2014 Drilled ahead from 6455’ MD to 7575’ MD. Rig performed mud pump maintenance while reciprocating pipe. Noted max formation gas of 253 units at 7900’ MD. Formation sample consisted of 35% sandstone, 30% silt, 35% siltstone. Continued drilling ahead to 8142’ MD. Formation samples consisted of 20% sandstone, 65% silt, 15% siltstone. Gas: The maximum formation gas was 253 units, and the average gas was 93 units. Fluids: No losses. Geology: Samples primarily consisted of 65% light gray to gray, brown, very fine grained, gritty, unconsolidated silt, 20% white, light gray to gray, translucent, light brown, very fine grained, rounded to sub rounded, moderately to well sorted, unconsolidated sandstone with traces of pyrite and mica, 15% light gray to gray, very fine grained, blocky, subangular, friable siltstone. 03/22/2014 Drilled ahead from 8142’ MD to 9368’ MD with an average background of 91 units. Noted 449 units of connection gas at 9184’ MD. Performed a short trip to 5683’ MD with a background gas of 53 units. Formation samples at 9368’ MD consisted of 60% silt, 25% sandstone and 15% siltstone with traces of shale. Gas: The maximum connection gas was 449 units, and the average gas was 91 units. Fluids: No losses. Geology: Samples primarily consisted of 60% light gray to gray, brown, very fine grained, gritty, unconsolidated silt, 25% white, light gray to gray, translucent, light brown, very fine grained, rounded to sub rounded, moderately to well sorted, unconsolidated sandstone with traces of pyrite and mica, and 15% light gray to gray, light brown, very fine grained, subangular, soft to moderately firm siltstone with traces of shale. 03/23/2014 Continued to back ream out of the hole from 5595’ MD to 5062’ MD. Inspected the ghost reamer and then ran in to the hole from 5062’ MD to 5216’ MD. Circulated and conditioned the hole. A sweep of 130 barrels returned late. Blew down the top drive, observed the well for flow and serviced the top drive. Ran in to the hole from 5216’ MD to 9085’ MD. Washed down from 9085’ MD to 9368’ MD and then circulated bottoms up. Drilled ahead from 9368’ MD to 9969’ MD. Activated the RipTide under reamer. Waited on Ball Mill to repair drag chain. Continued to drill from 9969’ MD to 10029’ MD and then took a survey. Drill ahead from 10029’ MD to 10123’ MD. Gas: The maximum formation gas was 371 units, and the average gas was 118 units. Fluids: No losses. Geology: Samples primarily consisted of 50% light gray to gray, light brown, very fine grained, gritty, unconsolidated silt, 40% light gray to gray, light brown, very fine grained, subangular, soft to moderately firm siltstone, 10% light brown, translucent to opaque, fine to very fine grained, sub rounded to rounded, unconsolidated quartz sandstone with traces of shale. 03/24/2014 Drilled ahead from 10123’ MD to 10675’ MD. Performed pore pressure test. Drilled ahead from 10675’ MD to 11184’ MD. Gas: The maximum formation gas was 600 units, and the average gas was 145 units. Fluids: No losses. Geology: Samples primarily consisted of 30% light gray to gray, light brown, very fine grained, subangular, soft to moderately firm siltstone, 30% light gray to gray, light brown, very fine grained, gritty, unconsolidated silt, 20% light brown, translucent to opaque, fine to very fine grained, sub rounded to rounded, unconsolidated quartz sandstone, and 20% light gray, very fine grained, friable, subangular, platy and fissile shale. 03/25/2014 Drilled ahead from 11184’ MD to 11471’ MD. Took formation pressure sample. Drilled ahead from 11471’ MD to 11496’ MD and then took a survey. Retracted reamer blades and circulated two bottoms up. Monitor well for flow. Pumped pill to spot casing. Back reamed out of the hole from 9610’ MD to 6820’ MD. Gas: The maximum formation gas was 874 units, and the average gas was 136 units. Fluids: No losses. Geology: Samples primarily consisted of 90% translucent to opaque, green, fine to very fine grained, sub rounded to rounded, unconsolidated quartz sandstone with traces of glauconite, and 10% light gray to gray, light brown to brown, very fine grained, moderately firm to firm siltstone. 03/26/2014 Backreamed out of hole and then circulated and conditioned at the shoe. Pumped sweep. Pulled out of hole on elevators. Laid down BHA. Tested the blow out preventers. Gas: The maximum circulating gas was 319 units, and the average gas was 32 units. Fluids: Loss of 40 barrels while backreaming out of hole. Geology: No geological samples were collected. 03/27/2014 Continued to run in to the hole with 7” casing. Circulated and diluted at 5500’ MD. Continued to run in to the hole. Gas: The maximum circulating gas was 310 units, and the average gas was 114 units. Fluids: No losses. 03/28/2014 Continued to run 7” casing into the hole. Tight spots were encountered at 9981’ MD and 10460’ MD. Continued running casing to 10962’ MD. Gas: The maximum circulating gas was 254 units, and the average gas was 57 units. Fluids: No losses. 03/29/2014 Worked casing to 10995’ MD and was unable to achieve TD. Landed the 7” casing early at 10995’ MD. Rigged down TESCO casing tools and made up the cement head. Circulated and conditioned mud for cement job by decreasing mud weight from 11.2 ppg to 10.9 ppg. Gas: The maximum circulating gas was 1039 units, and the average gas was 280 units. Fluids: No losses. 03/30/2014 Ran centrifuge and added water to reduce mud weight from 11.2 ppg to 10.9 ppg. Completed first stage cement job with full returns throughout cement job. Finished second stage cement job. Gas: The maximum circulating gas was 90 units, and the average gas was 37 units. Fluids: No losses. 03/31/2014 Laid down 5” drill pipe and changed out saver sub to 3.5”. Installed Bell Guide. Picked up 3.5” drill pipe and racked in derrick. Tested 3.5” full opening safety valve and 3.5” Dart. Gas: The maximum circulating gas encountered was 3 units, and the average gas was 1 units. Fluids: No losses. 04/01/2014 Ran in hole with 3.5” drill pipe from 5516’ MD to 7419’ MD. Filled pipe and blew down top drive. Inspected hanging line, slipped and cut 75’ drill line. Serviced top drive and draw works. Tripped in the hole with 10 barrels over calculated displacement. Gas: The maximum circulating gas encountered was 10 units, and the average gas was 3 units. Fluids: No losses. 04/02/2014 Continued to run in the hole from 8370’ MD to 10478’ MD while filling drill pipe each 20 stands. Circulated 250 gallons per minute at 10751’ MD. Tested 7” casing to 3500 psi for 30 minutes. Bled off, blew down lines, and rigged down test equipment. Obtained slow pump rates. Drilled cement and shoe track. Continued to work pipe down from 10990’ MD to 11006’ MD at 250 gallons per minute and 1930 psi. Encountered several slight pack offs with an increase of pressure to 2200 psi. Drilled cement and shale from 11006’ MD to 11128’ MD. Pulled out of the hole from 11035’ MD to 10995’ MD to attempt to reestablished prior pump rates. Pulled up to shoe to circulate. Gas: The maximum circulating gas was 166 units, and the average gas was 12 units. Fluids: No losses. 04/03/2014 Circulated and conditioned mud at 10995’ MD. Ran in to the hole from 10995’ MD to 11225’ MD. A gas peak of 447 units was noted after circulating bottoms up from 11123’ MD. Back reamed out of the hole from 11225’ MD to 10995’ MD. At 10995’ MD, staged pump to 305 gallons per minute to circulate and condition at the shoe. Blew down top drive and flow checked. Pulled out of the hole from 10940’ MD to 9990’ MD on trip tank. Pumped 28 barrels of 12.4 pounds per gallon dry job. Continued pulling out of hole. Gas: The maximum circulating gas was 447 units, and the average gas was 31 units. Fluids: No losses. 04/04/2014 Made up mule shoe and ran in the hole with 3.5” tubing to 922’ MD. Changed out elevators to 3.5” drill pipe. Made up crossover and rigged down casing tongs. Ran in the hole with 3.5” drill pipe from 922’ MD to 10906’ MD. From 10906’ MD to 11301’ MD, washed down at 5 barrels per minute. Pulled out of the hole from 11301’ MD to 11287’ MD. Circulated and conditioned at 11287’ MD and cemented per Dowel. Had full returns throughout entire cement job. Pulled out of the hole from 10775’ MD. Pumped nut plug sweep. Saw 20 barrels of 12.5 ppg mud push and 100 barrels of 12.8 ppg cement that contaminated mud at shakers. Mud push came back 40 barrels early. Pulled out of the hole on elevators. Gas: The maximum circulating gas was 137 units, and the average gas was 17 units. Fluids: No losses. 04/05/2014 Continued to pull out of the hole. Pumped a 10 barrel 12.4 ppg dry job to balance mud weight at 5481’ MD. Continued to pull out of the hole on the trip tank to 3106’ MD. Singled in from 3106’ MD to 10620’ MD. Washed down from 10620’ MD to 10792’ MD. Tagged cement at 10792’ MD. From 10792’ MD to 10715’ MD, pumped dry job, blew down top drive and flow checked. Pulled out of the hole from 10715’ MD to 922’ MD on the trip tank. Continued to pull out of the hole. Rigged down tubing equipment and cleared rig floor. Rigged up to test blow out preventer. Gas: The maximum circulating gas was 6 units, and the average gas was 2 units. Fluids: No losses. 04/06/2014 Tested the blow out preventer. The accumulator hydraulic holding tank failed. Closed blind rams. Rigged up and tested blinds, casing and cement plug. Monitored pressure under blinds. Gas: The maximum circulating gas was 3 units, and the average gas was 1 unit. Fluids: No losses. 04/07/2014 Repaired accumulator. Calibrated gas equipment. Gas: No significant gas data was collected. Fluids: No losses. 04/08/2014 Repaired accumulator. Made up BHA. Ran in to the hole from surface to 10740’ MD. Circulated bottoms up. Slipped and cut drill line, and serviced top drive and draw works. Washed down from 10740’ MD to 10792’ MD. Drilled out cement from 10792’ MD to 10930’ MD. Gas: The maximum drilling gas was 5 units, and the average gas was 2 units. Fluids: No losses. Geology: Bottoms up samples were 100% cement. 04/09/2014 Drilled cement plug from 10930’ MD to 11080’ MD. Pulled back to the shoe and performed formation integrity test. Ran in the hole and drilled to 11173’ MD while displacing to new FLOTHRU mud. Gas: The maximum drilling gas was 27 units, and the average gas was 15 units. Fluids: No losses. Geology: Samples primarily consisted of 85% light gray to gray, light brown to brown, green, very fine grained, sub angular, soft and occasionally moderately firm siltstone and 15% white, translucent to opaque, green, very fine grained, sub rounded to rounded, unconsolidated quartz sandstone with traces of glauconite. 04/10/2014 Drilled from 11754’ MD to 12257’ MD. Gas: The maximum drilling gas was 4244 units, and the average gas was 618 units. Fluids: No losses. Geology: Samples primarily consisted of 90% white, translucent to opaque, light brown to brown, very fine to fine grained, sub rounded to rounded, unconsolidated quartz sandstone and 10% light gray to gray, light brown to brown, very fine grained, sub angular, soft and occasionally moderately firm siltstone. 04/11/2014 Drilled from 12257’ MD to 13760’ MD. Gas: The maximum drilling gas was 4704 units, and the average gas was 1218 units. Fluids: No losses Geology: Samples primarily consisted of 95% white, translucent to opaque, light brown to brown, amber, very fine to fine grained, sub rounded to rounded, unconsolidated quartz sandstone and 5% light gray to gray, light brown to brown, very fine grained, sub angular, soft and occasionally moderately firm siltstone. 04/12/2014 Drilled from 13760’ MD to 15023’ MD. Gas: The maximum drilling gas was 6301 units, and the average gas was 2040 units. Fluids: No losses. Geology: Samples primarily consisted of 100% white, translucent to opaque, light brown to brown, amber, very fine to fine grained, sub rounded to rounded, unconsolidated quartz sandstone with occasional traces of siltstone. 04/13/2014 Drilled from 15023’ MD to 16534’ MD. Gas: The maximum drilling gas was 5413 units, and the average gas was 1505 units. Fluids: No losses. Geology: Samples primarily consisted of 100% white, translucent to opaque, light brown to brown, amber, very fine to fine grained, sub rounded to rounded, unconsolidated quartz sandstone with occasional traces of siltstone. 04/14/2014 Drilled from 16534 MD to 16824’ MD. Circulated and conditioned due to gas, flow checked bottoms up, and observed well flowing. Weighted up from 10 ppg to 10.4 ppg drilling fluid and observed well flow. Performed exhale test, shut in well and bled down. Broke down choke line and manifold. Circulated and conditioned bottoms up. Drilled ahead from 16824’ MD to 17942’ MD. Observed slight flow on connection. Circulated bottoms up. Racked stand back, circulated to weight up from 10.4 ppg to 10.6 ppg. Gas: The maximum drilling gas was 7290 units, and the average gas was 1565 units. Fluids: No losses Geology: Samples primarily consisted of 100% white, translucent to opaque, light brown to brown, amber, very fine to fine grained, sub rounded to rounded, unconsolidated quartz sandstone with occasional traces of siltstone. 04/15/2014 Circulated and conditioned, weighted up from 10.4 ppg to 10.6 ppg. Performed exhale test. Circulated and conditioned bottoms up. Performed exhale test. Circulated and conditioned bottoms up, and observed well continuing to flow. Shut in well, circulated and conditioned. Pulled out of the hole from 17492’ MD to 13019’ MD. Circulating gas of 10000 units was observed after circulating bottoms up, following the second exhale test. Gas: The maximum drilling gas was 7436 units, and the average gas was 4666 units. Fluids: No losses. 04/16/2014 Pulled out of the hole with pumps on from 13019’ MD to 10930’ MD. Circulated and conditioned bottoms up. Weighted up from 10.6 ppg to 10.8 ppg. Flow checked and observed well flowing. Circulated and conditioned. Performed exhale test. Shut in the well, and circulated and conditioned. Weighted up from 10.8 ppg to 11.0 ppg. Observed well. Pulled out of the hole from 10930’ MD to 5319’ MD on the trip tank. Gas: The maximum circulating gas was 307 units, and the average gas was 56 units. Fluids: No losses. 04/17/2014 Ran in the hole with 4.5” liner. Began displacing FLOTHRU system to 11.0 ppg NaCl/NaBr brine completion fluid. Gas: The maximum circulating gas was 25 units, and the average gas was 13 units. Fluids: No losses 04/18/2014 Ran in the hole with 4.5” liner from 5339’ MD to 6672’ MD. Made up packer and ran in the hole with heavy weight drill pipe from 6709’ MD to 8357’ MD. Continued to run in the hole from 8357’ MD to 17492’ MD. Circulated and conditioned bottoms up. Gas: The maximum circulating gas was 33 units, and the average gas was 21 units. Fluids: 41.75 barrels lost while tripping in the hole. Geology: No geological samples were collected. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 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: CD3-316B & CD3-316B PB1 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 19 SPERRY JOB: AK-XX-0901152148 Days vs. Depth 05 Mar 2014 Sperry SDL Remains on Location from Previous Well LOCATION: Alpine AREA: North Slope Borough STATE: Alaska SPUD: 15-Mar-2014 TD: 15-Apr-2014 Commenced 9.875" Intermediate Hole Section On Bot: 16:44 15 Mar 2014 POOH for MWD Tool Failure 15 March 2014 BROOH 16-17 March 2013 BROOH due to low ROP 18-19 March 2014 TD 8.75" Intermediate Hole Section 11496' MD, 7045' TVD Off Bot: 09:52 25 Mar 2014 Landed 9.625" Casing 2755' MD, 2483' TVD 29 Mar 2014 Casing Failure Cement Plug Back 4-7 Apr 2014 Commenced 6.125" Production Hole Section On Bot: 17:14 8 Apr 2014 TD Production Hole Section 17493' MD, 6975' TVD Off Bot: 14:40 15 Apr 2014 Landed 4.5" Production Liner 17493' MD, 6977' TVD 18 Apr 2014 WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough SPERRY JOB:STATE:Alaska RIG:Doyon 19 HOLE SECTION Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: While performing the second stage of the intermediate cement job, the pit sensor monitoring cement returns (Pit 1 sensor) displayed erratic readings throughout the entire process, reaching upward to 40 barrel swings in volume readings. Fortunately, the pit watcher was strapping the pits for every 20 barrels of cement pumped to confirm sufficient returns. Recommendations: Innovations and/or cost savings: Communication between all rig personnel during the cement job was very effective and restored confidence in the results of the job being performed while reliability of the pit sensors were in question. Difficulties experienced: Faulty volume data has been reported and efforts have been made to repair problematic pit sensors respectively throughout several projects in the past, but the issues are recurring. I would recommend implementing an additional sensor for each pit in question for redundancy and reliability, especially during critical operations pertinent to the success of the well. Going forward, all trip sheets generated will be reviewed by all personnel tracking volume (pit watcher, mud engineer, and Ball Mill) and the company man, then submitted with SDL's daily morning reports. ConocoPhillips Alaska, Inc AK-XX-0900978218 David McKechnie 1-Apr-2014 CD3-316B Surface Data Logging After Action Review WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough SPERRY JOB:STATE:Alaska RIG:Doyon 19 HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ConocoPhillips Alaska, Inc AK-XX-0900978218 Tyler Dretke 16-Apr-2014 CD3-316B What went as, or better than, planned: WITSing SPM continues to be problematic. The sensors will occasionally malfunction in Totco, sending the garbage data to IRIS. IRIS then intprets the data and our lag jumps ahead by 20-30 feet. This offsets our gas data until we lag up the current bit depth. Recommendations: Innovations and/or cost savings: Our gas equipment worked well thoughout the production zone with no failures or malfunctions. Difficulties experienced: Installing a Halliburton pump stroke counter would make it so that we are not dependant on WITS data. This would eliminate the issue. N/A Surface Data Logging After Action Review WELL NAME:CD3-316B & CD3-316B PB1 LOCATION:Alpine OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 19 SPUD:15-Mar-2014 SPERRY JOB:AK-XX-0901152148 TD:15-Apr-2014 MD TVD TVDSS 2,768.0 2,492.0 2,443.0 3,365.0 2,874.0 2,825.0 5,300.0 3,890.0 3,841.0 5,590.0 4,040.0 3,991.0 5,655.0 4,074.0 4,025.0 5,845.0 4,177.0 4,128.0 9,047.0 5,757.0 5,708.0 9,117.0 5,998.0 5,949.0 10,100.0 6,545.0 6,496.0 10,268.0 6,628.0 6,579.0 10,360.0 6,670.0 6,621.0 10,440.0 6,710.0 6,661.0 10,563.0 6,772.0 6,723.0 10,583.0 6,782.0 6,733.0 10,705.0 6,838.0 6,789.0 10,941.0 6,935.0 6,886.0 11,336.0 7,035.0 6,986.0 Top Kuparuk C LCU/Top Kingak Top Nuiqsut Base Nuiqsut/Kingak Top Nechelik Albian 96 Top HRZ Base HRZ/Top Upper Kalubik K-1/Top Lower Kalubik Top Kuparuk D/Base Kalubik K-3 K-3 Basal K-2 (Qannik) K-2 Basal Albian 97 Formation Tops Marker C-30 C-20 CD3-316B & CD3-316B PB1 ConocoPhillips Alaska, Inc MI Swaco Doyon 19 AK-XX-0901152148 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++ 9-Mar 3130 10.50 44 9 17 9/10/11 9.3 35/26/21/17/8/7 1/NA 11.0 /89 0.00 0.03 9.0 0.0 .01/.05 95000 20 M/U BHA, POOH, L/D BHA 10-Mar 3130 10.50 41 7 14 7/8/10 9.1 28/21/18/14/7/6 1/-11.0 /89 0.00 0.03 8.7 0.0 .01/.05 95000 20 Test rams, M/U BHA, test BOPE 11-Mar 3130 10.50 40 7 15 7/8/9 9.3 29/22/19/14/6/6 1/-11.0 /89 0.00 0.03 8.5 0.0 .01/.05 95000 20 Failed Pull Casing, M/U BHA 12-Mar 3300 10.60 38 8 14 6/7/9 9.3 30/22/19/14/5/5 1/-11.0 /89 0.00 0.03 8.1 0.0 .01/.05 95000 20 Pulled Casing 13-Mar 3300 10.60 38 8 14 6/7/9 9.3 30/22/19/14/5/5 1/-11.0 /89 0.00 0.03 8.1 0.0 .01/.05 95000 20 L/D, P/U Pipe 14-Mar 3300 10.50 40 9 14 6/10/12 14.7 32/23/19/14/6/5 1/NA 11.0 /89 0.00 0.02 10.4 0.0 .01/.05 95000 550 RIH 15-Mar 3300 10.50 47 5 17 16/22/23 8.0 27/22/21/19/13/13 1/NA 9.0 2/89 0.00 0.04 9.5 0.0 .02/.1 9000 80 POOH, TIH, Drilled Intermediate 16-Mar 3725 10.70 40 11 22 14/22/28 5.2 44/33/28/23/13/13 1/NA 11.3 3/86 0.00 0.02 9.4 10.0 .01/.05 2250 20 Drilled Intermediate, BROOH 17-Mar 3725 10.70 43 11 21 15/30/36 5.1 43/32/28/14/14 1/NA 11.5 3/86 0.10 0.04 9.8 15.0 .02/.05 2500 60 Drilled Intermediate 18-Mar 4418 10.70 39 11 19 8/30/47 5.1 41/30/25/19/9/8 2/NA 12.3 3/85 0.00 0.02 9.6 22.5 .01/.08 2300 32 Drilled Intermediate, POOH low ROP 19-Mar 4417 10.70 40 12 20 10/31/42 5.0 44/32/27/25/9/8 2/NA 11.0 2/87 0.00 0.02 9.6 20.0 .01/.02 1800 40 M/U BHA, TIH, Drilled Intermediate 20-Mar 6240 10.70 38 9 20 8/17/19 4.9 38/29/24/19/7/7 2/-13.0 2/85 0.10 0.05 9.7 15.0 .01/.07 800 60 Drilled Intermediate 21-Mar 7870 10.70 38 12 22 11/13/16 4.6 46/34/268/23/10/9 1/-15.0 3/82 0.40 0.04 9.1 20.0 .0/.03 500 40 Drilled intermediate 22-Mar 9368 10.70 38 12 21 10/14/19 4.7 45/33/29/23/11/10 1/-14.0 4/83 0.30 0.01 9.1 22.5 .01/.03 500 40 Drilled Intermediate/Short Wiper trip 23-Mar 10030 11.20 39 12 22 9/14/16 3.3 46/34/28/21/9/8 1/1 7.0 3/81 tr 0.01 9.0 16.3 .01/.04 600 40 Drilled Intermediate 24-Mar 11220 11.20 40 14 25 10/15/20 2.7 53/39/33/26/11/10 1/-17.5 3/80 0.40 0.03 9.1 22.5 .01/.05 500 40 Drilled Intermediate 25-Mar 11496 11.20 42 14 24 10/13/15 2.8 52/38/33/25/10/9 1/1 17.0 4/80 0.40 0.02 9.3 18.8 .01/.04 500 40 Drilled Intermediate 26-Mar 11496 11.20 50 13 22 8/10/13 2.5 48/35/31/23/10/9 1/2 17.5 3/80 0.50 0.02 9.4 18.8 .01/0.04 600 40 Tested BOPE 27-Mar 11496 11.20 52 15 21 8/10/12 5.6 51/36/30/23/9/8 1/2 17.0 3/80 0.50 0.04 9.6 12.0 .02/.20 400 40 Ran 7" Casing 28-Mar 11496 11.20 54 13 23 9/10/11 2.0 49/36/31/23/9/9 1/2 17.0 4/80 0.50 0.04 9.2 15.0 .01/.20 550 40 Ran 7" Casing 29-Mar 11496 11.20 48 13 22 8/10/11 2.3 48/35/30/22/9/8 1/2 17.0 4/80 0.50 0.04 9.2 18.3 .01/.28 650 40 Rigged Down Tesco 30-Mar 11496 10.90 48 12 19 8/9/11 2.3 43/31/26/20/8/7 1/2 17.0 4/80 0.50 0.03 8.8 16.8 .01/.15 650 40 L/D 5" DP 31-Mar 11496 10.90 50 11 20 9/10/12 2.7 42/31/26/20/8/7 1/2 16.0 4/81 0.50 0.04 9.4 16.8 .01/.3 650 40 P/U 3.5" DP 1-Apr 11496 10.90 46 11 16 6/8/12 3.5 38/27/23/17/6/5 1/2 16.0 4/81 0.50 0.07 10.0 15.0 .04/.3 700 80 RIH w/3.5" DP 2-Apr 11496 10.90 44 15 21 7/20/24 4.7 51/36/30/22/7/7 1/1 17.0 3/80 0.50 0.07 10.4 15.0 .02/26 600 100 Drilled into Open Hole 3-Apr 11496 10.90 42 10 15 6/10/14 4.8 35/25/20/14/5/4 1/2 17.0 3/80 0.50 0.07 10.5 17.5 .04/.3 600 80 POOH 4-Apr 11496 10.90 50 14 14 7/20/24 5.4 42/28/23/17/6/5 1/2 17.0 3/80 0.50 0.07 11.0 16.3 .05/.03 650 80 RIH with stinger, Cement, POOH 5-Apr 11496 10.90 42 7 18 6/8/110 4.2 32/25/16/11/3/2 1/2 12.0 4/85 0.50 0.03 9.7 12.0 .02/.27 600 80 TIH, Tagged Cement, POOH 6-Apr 11496 10.00 42 8 12 5/7/12 9.5 28/20/17/12/5/4 1/2 12.0 3/85 0.50 0.03 9.8 11.3 .02/.25 600 80 BOPE Test, Accumulator Repair 7-Apr 11496 10.00 44 8 12 5/7/13 9.5 28/20/16/12/5/4 1/2 12.0 3/85 0.50 0.03 9.9 11.3 .02/.25 600 80 Accummulator Repair 8-Apr 11496 10.00 40 9 17 7/9/10 5.0 35/26/22/17/7/6 1/2 10.5 3/87 0.50 0.02 10.2 9.3 .01/.20 600 80 TIH, Drill Cement 9-Apr 11175 10.00 54 13 11 3/3/3 2.5 37/24/18/12/3/2 1/-8.0 /92 0.10 0.01 8.7 2.5 .01/.10 10600 168 Drilled Production 10-Apr 12250 10.00 53 18 13 5/7/8 3.2 49/31/25/17/4/4 1/2 11.0 3/86 0.01 0.01 8.9 2.0 .01/.03 101000 80 Drilled Production 11-Apr 13540 10.00 76 17 16 5/7/8 9.0 50/33/27/18/5/4 1/2 10.5 3/87 0.10 0.04 8.9 3.0 .01/.09 104000 60 Drilled Production 12-Apr 13971 10.00 81 20 16 5/6/8 8.6 56/36/29/18/4/4 1/2 10.5 2/88 0.10 0.01 9.0 3.5 .01/.13 94000 48 Drilled Production 13-Apr 16313 10.10 53 20 16 4/6/7 2.1 56/36/28/18/4/3 1/2 11.0 3/87 0.20 0.02 9.4 3.8 .01/.13 95000 80 Drilled Production 14-Apr 17380 10.40 53 19 14 3/4/5 1.9 52/33/25/17/3/3 1/2 13.5 3/84 0.20 0.02 9.2 2.5 .01/.13 138000 80 Drilled Production/Circulated 15-Apr 17942 10.60 54 20 16 4/7/7 1.6 56/36/29/19/4/4 1/2 14.0 3/83 0.20 0.02 9.4 2.5 .01/.15 141000 80 POOH 16-Apr 17492 11.05 77 26 30 9/11/13 1.4 82/56/45/32/9/8 1/2 16.5 2/82 0.10 0.04 9.8 3.0 .01/.08 166000 80 POOH 17-Apr 17492 10.85 83 27 32 8/12/16 1.6 86/59/48/35/9/8 1/2 16.5 2/82 0.10 0.01 9.1 3.0 .01/.13 165000 80 RIH w 4.5" Liner 18-Apr 17492 11.00 82 23 26 7/11/14 1.6 72/49/40/28/8/7 1/-16.5 2/82 0.10 0.01 8.9 3.0 .01/.09 163000 80 Circ & Cond B/U Casing Record Remarks 9.625" Casing @ 2755' MD, 2483'TVD 7" Casing @ 10995' MD, 6952'TVD WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:15-Mar-2014 SPERRY JOB:TD:15-Apr-2014 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 1 200 1 MXL-1X Mill Tooth 8.75 2704 2744 40 0.00 0.785 0.0 0 0 1000 550 0-0-NO-A-O-I-NO-DTF MWD Failed to Demodulate 2 300 1rr1 MXL-1X Mill Tooth 8.75 2744 3725 981 13.40 0.785 73.4 20 100 1490 525 3-3-BT-A-E-1-CT-BHA POH - Poor ROP 3 400 1rr1 MXL-1X Mill Tooth 8.75 3725 4418 693 6.50 0.785 107.4 20 110 1720 525 0-1-WT-A-E-I-NO-BHA POH - MWD Drillstring Interference 4 500 3 SKH5 19 PDC 9.75 4418 11496 7078 68.20 0.863 103.8 25 150 2650 650 1-1-NO-G-X-I-NO-TD TD Intermediate Hole Section 5 560 4 QH1R MT 6.13 11496 11496 0 92.70 0.665 -----1-2-WT-A-E-I-NO-BHA Drill Shoe Track - POH due to pack off 6 600 5 MDI513 PDC 6.13 11020 17492 6472 220 0.296 77.2 10 150 3120 185 2-1-CT-M-X-I-HC-TD Sidetrack Production Section WELL NAME:CD3-316B & CD3-316B PB1 LOCATION:Alpine OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901152148 TD:15-Apr-2014 MI Swaco STATE:Alaska RIG:Doyon 19 SPUD:15-Mar-2014 B i t R e c o r d . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Completing rig move to 316B. N/A 10,000 Units =100% Gas In Air (current)(max)(max)Background N/A Trip N/A Connection 0 0 0000Average00 0 0 0000Minimum--0 0 0 0000 C-5i C-5n Maximum 0 -0 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade CommentsCasing Summary Size Set At Type Weight ---- WOB RPM Condition ------- Bit #Bit Type Size TFA Hours Depth in / out Footage % WBM (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg SPP (psi) Flow In (spm) ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:R/U on 316B Date:6-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:0' Morning Report Report # 1 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:0' . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Take on brine to the pits. Rig up hard lines to the tree. Test the mud lines. Then test the lines to the tiger tank. Pump on tubing. Pump down the inner annulus and test to 2000 psi. Pull the back pressure valve. Rig and displace well to 9.6 ppg brine. Observe well and then rig down the lines. Set the back pressure valve and then test it. Nipple down the tree and then nipple up the BOPE. Test BOPE. N/A 10,000 Units =100% Gas In Air (current)(max)(max)Background N/A Trip N/A Connection 0 0 0000Average00 0 0 0000Minimum--0 0 0 0000 C-5i C-5n Maximum 0 -0 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade CommentsCasing Summary Size Set At Type Weight ---- WOB RPM Condition ------- Bit #Bit Type Size TFA Hours Depth in / out Footage % Sea Water 9.60 9.60 27 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg SPP (psi) Flow In (spm) ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:Testing BOPE Date:7-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:0' Morning Report Report # 2 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:0' . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Finish testing BOPE. Pull blank plug and back pressure valve. Make up landing joint. Rig up casing tools. Pull hanger to the rig floor. Lay down landing joint and hanger. Lay down 4.5" tubing removing clamps and spooling control line. Rig down casing equipment. Set 9" inner diameter wear bushings. Make-up cast iron bridge plug BHA. Run in to the hole to 3120' MD. Set cast iron bridge plug. Pull out of the hole to 3078' MD. Circulate a bottoms-up. Rig up and test the plug. Slip and cut the drill line. Service the top drive and drawworks. Circulate another bottoms-up. N/A 10,000 Units =100% Gas In Air (current)(max)(max)Background N/A Trip N/A Connection 0 0 0000Average00 0 0 0000Minimum--0 0 0 0000 C-5i C-5n Maximum 0 -0 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments Casing Summary Size Set At Type Weight ---- WOB RPM Condition ------- Bit #Bit Type Size TFA Hours Depth in / out Footage % Sea Water 9.60 9.60 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg SPP (psi) Flow In (spm) ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:Circulating Date:8-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:0' Morning Report Report # 3 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:0' . . * 24 hr Recap: Morning Report Report # 4 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:0' Well:CD3-316B Daily Charges:Current Depth:0' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:Flow Checking Well Date:9-Mar-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 2800'Sea Water 10.50 10.50 44 0.0 9 17 9.3 9.00 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ----------- Casing Summary Size Set At Type Weight Grade Comments Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 14 -1152 60 20 6 13 0 0 Minimum --0 0 0 0 0 0 0 Average 3 56 1 1 0 1 0 0 (current)(max)(max)Background N/A Trip N/A N/A 10,000 Units =100% Gas In AirConnection The well was observed for static conditions. Pull out of the hole and lay down BHA. Rig floor was cleaned and cleared. Make-up casing cutter BHA. Run in to the hole. Tag up on plug. Cut the 7" casing at 3120' MD. The well was observed to have flowing conditions. Weight up active system to 10.0ppg. The well was observed to have slower flowing conditions. Weight up active system to 10.5ppg. The well was observed to have static conditions. Circulate diesel out of 9-5/8" x 7" annulus to Tiger tank. The well was observed to have static conditions still. Pull out of the hole and lay down BHA. The well was observed to still have static conditions. Pre-job safety meeting on changing out rams. Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Change out upper rams to 7". Pull wear ring and set test plug. Test the rams. Rig down testing equipment. Set the wear ring. Make-up spear BHA. Run in to the hole and engage 7" casing. Pull up casing tools. Pull the hanger to the floor. Break hanger and set down the spear. Pump a dry job. Lay down 7" casing. Rig down casing equipment. Clean and clear the rig floor. Change out top pipe rams. Rig up and test the BOPE. Rig down testing equipment. N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background N/A Trip N/A 1 0 041101Average5459 0 0 0000Minimum--0 115 28 953811420130 C-5i C-5n Maximum 14 -62799 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments Casing Summary Size Set At Type Weight ---- WOB RPM Condition ------- 8.70 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 3130'Sea Water 10.50 10.50 41 0.0 7 14 9.1 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg SPP (psi) Flow In (spm) ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:R/D Testing Equipment Date:10-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:3130' Morning Report Report # 5 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3130' . . * 24 hr Recap: Morning Report Report # 6 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3130' Well:CD3-316B Daily Charges:Current Depth:3130' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:P/U BHA Date:11-Mar-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 3130'Sea Water 10.50 10.50 40 0.0 7 15 9.3 8.50 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ----------- Casing Summary Size Set At Type Weight Grade Comments Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 552 -49922 4796 1671 170 151 32 18 Minimum --0 0 0 0 0 0 0 Average 34 1424 146 57 7 6 4 0 (current)(max)(max)Background N/A Trip 552 N/A 10,000 Units =100% Gas In AirConnection Rig up 5" drill pipe elevator. Make-up spear BHA. Service Iron Roughneck and drawworks. Lay down 1 stand of 4" heavy weight drill pipe. Run in to the hole with spear BHA to 2517' MD. Circulate and condition mud. Run in to the hole and engage 7" casing. Casing was grappled, jarred, and worked with a max pull of 445k multiple times. This proved to be no good at dislocating the casing. Pull out of the hole and lay down the spear BHA. Make-up 7" casing cutter BHA. Run in to the hole to 2860' MD. Cut 7" casing again. Confirm the cut and circulate a bottoms-up. Pull out of the hole and lay down 7" casing cutter BHA. Pick up spear BHA. Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs/Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Run in to the hole to 2517' MD with spear BHA. Engaged casing pulling 160-445k, firing jars multiple time, working it, and pulling again to 440k. After stretching the pipe broke free. From 2860' MD to 2720' MD a 30 bbl return was noted. From 2720' MD to 2689' MD pulled out bad 4" drill pipe. Circulate and condition mud at 7 bpm. Observe well for static conditions. Pull out of the hole to 543' MD. Lay down BHA and 7" cutting joint. Rig up casing equipment. From 215' MD cut off 7" casing . Rig down casing equipment. Rig up tubing equipment. Run in to the hole with 3.5" cement string to 3149' MD. Circulate and condition mud. N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background N/A Trip 4695 66 25 1975435748Average49113049 0 0 0000Minimum--0 1561 637 5232227493031124 C-5i C-5n Maximum 4695 -422740 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments Casing Summary Size Set At Type Weight ---- WOB RPM Condition ------- 8.10 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 3300'Sea Water 10.60 10.60 38 0.0 8 14 9.3 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg SPP (psi) Flow In (spm) ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 Location:Alpine Rig Activity:Circulating Date:12-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:3300' Morning Report Report # 7 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3300' . . * 24 hr Recap: Morning Report Report # 8 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3300' Well:CD3-316B Daily Charges:-Current Depth:3300' Area:North Slope, AK Total Charges:-24 Hour Progress:0' Location:Alpine Rig Activity:P/U 5" Drill Pipe Date:13-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 3300'Sea Water 10.50 10.50 40 -9 13 14.7 10.10 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ----------- Casing Summary Size Set At Type Weight Grade Comments Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 369 -29327 2884 2174 290 377 107 86 Minimum --0 0 0 0 0 0 0 Average 9 595 51 37 6 9 3 2 (current)(max)(max) Background N/A Trip N/A N/A 10,000 Units =100% Gas In AirConnection Pumped cement as per program. Pulled out of the hole to 2537' MD and pumped nut plug sweep. Noted max gas of 369 units. Monitored well- static. Pulled out of the hole to surface and rigged down cement equipment. Laid down 4" drill pipe. Picking up 5" drill pipe at report time. Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 Continued picking up 5" drill pipe. Tested BOP. Rigged down testing equipment and picked up BHA. Calibrated and tested gas equipment. Running in the hole with drillout assembly at report time. N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max) Background N/A Trip 96 13 3 180589Average17797 0 0 0000Minimum--0 90 32 2250638668 C-5i C-5n Maximum 96 -5075 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments Casing Summary Size Set At Type Weight ---- WOB RPM Condition 1 MXL-1X Mill Tooth 8.75 0.785 --- 10.10 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 3300'Sea Water 10.50 10.50 40 -9 13 14.7 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 Location:Alpine Rig Activity:TIH W/Drillout Assy Date:14-Mar-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:0' Well:CD3-316B Daily Charges:-Current Depth:3300' Morning Report Report # 9 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3300' . . * 24 hr Recap: Morning Report Report # 10 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:2760' Well:CD3-316B Daily Charges:-Current Depth:2913' Area:North Slope, AK Total Charges:-24 Hour Progress:153' Location:Alpine Rig Activity:Drilling Ahead Date:15-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 3300'Sea Water 10.50 10.50 47 -5 17 8.0 9.50 9000.0 9.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL-1X Mill Tooth 8.75 0.785 ------- Casing Summary Size Set At Type Weight Grade Comments 9.63''2813'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)80 20 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 10000 2911'791595 60563 45178 4865 4701 1936 1181 Minimum --0 0 0 0 0 0 0 Average 431 12837 1478 983 246 278 67 72 (current)(max)(max) Background N/A Trip N/A N/A 10,000 Units =100% Gas In AirConnection Shallow tested MWD. Could not establish communication. Tripped out of the hole for tool swap. Tripped out of the hole and changed out MWD. Ran into the hole and achieved good shallow test. Ran in the hole to 2,346' MD and tested casing to 3500 psi with satisfactory results. Washed and reamed to 2,760' MD, drilled out cement and 20' of formation to 2,830' MD. Encountered 9212 units of formation gas at 2818' MD. Isotube sample collected Trouble shoot gas chromatograph. Pulled out of the hole to 2,724' MD and displaced to 10.5 ppg LSND. Performed FIT to 14.4 ppg. Rigged down test equipment and washing down to bottom to drill out at report time. Update: Drilled ahead to 2913' MD and encountered 10,000 units formation gas. Isotube sample collected Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 the hole to surface. Backreaming out of the hole with an average background of 70 units at report time. Noted gas peak of 2016 units at 2980' MD. Continued tripping to bottom and drilled ahead to 2894' MD. Encountered 9500 units of formation gas. Isotube sample collected. Circulated and conditioned gas to a backround of 300 units while reciprocating pipe. Increased mud weight to 10.7 ppg. Drilled stand to bottom exposing 19' of formation. Encountered max gas 10,000 units. Gas sample collected. Conditioned to a backround of 170 units. Drilled ahead two stands and encountered 10,000 units at bottom's up for each stand. Gas sample collected for each peak. Formation samples consisted of 100% sandstone. Continued drilling ahead, noting a drop in gas readings from 10,000 units to 750 units at a lag depth of 3068' MD. Noted formation change, respectively. Samples consisted of 70% clay and 30% sandstone. Continued drilling ahead. Encountered 9830 units as a result of a pack off at 3076' MD. Gas sample collected. Continued drilling ahead to 3725' MD with an average of 122 units. Decision was made to backream out of N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max) Background N/A Trip N/A 419 85 7826551793277Average56742489 0 0 0000Minimum--0 8000 1981 205466547507595751 C-5i C-5n Maximum 10000 3068'837457 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)30 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0Casing Summary Size Set At Type Weight 970'--- WOB RPM Condition 1 MXL-1X Mill Tooth 8.75 0.785 -2755' 3725' 9.40 2250.0 11.3 Bit #Bit Type Size TFA Hours Depth in / out Footage % 3300'Sea Water 10.70 10.70 40 10.0 11 22 5.2 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 498 SPP (psi)1480 Flow In (spm)117 ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 Location:Alpine Rig Activity:Backream Out Hole Date:16-Mar-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:812' Well:CD3-316B Daily Charges:-Current Depth:3725' Morning Report Report # 11 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:2913' . . * 24 hr Recap: Morning Report Report # 12 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3725' Well:CD3-316B Daily Charges:-Current Depth:3806' Area:North Slope, AK Total Charges:-24 Hour Progress:81' Location:Alpine Rig Activity:Drilling Ahead Date:17-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)N/A N/A N/A N/A Flow In (gpm)519 SPP (psi)1588 Flow In (spm)122 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 3806'LSND 10.70 10.70 43 15.0 11 21 5.1 9.80 2500.0 11.5 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL-1X Mill Tooth 8.75 0.785 -2755' 3725' 970'--- 2 MXL-1X Mill Tooth 8.75 0.785 3725' Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)10 10 80 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1040 2980'120612 3752 1333 153 255 80 87 Minimum --0 0 0 0 0 0 0 Average 50 1775 74 40 7 13 4 5 (current)(max)(max) Background N/A Trip 1040 N/A 10,000 Units =100% Gas In AirConnection Continued backreaming out of the hole to 2980' MD. Noted peak gas of 2016 units. Isotube sample collected. Resumed backreaming to 2724' MD. Circulated 3 bottom's up at the shoe. Monitored the well - Static. Pulled out of the hole on elevators to 647' MD. Flow checked - Static. Pulled out of the hole to surface and laid down BHA. Made up BHA #3 and tripped in the hole to 1389' MD. Shallow test MWD - Good Test. Continued running in the hole to 3655' MD. Washed stand to bottom. Noted 1,0400 units of trip gas. On bottom drilling at 22:47. Drilling ahead at report time. Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 Continued drilling ahead to 4418' MD with an average background gas of 46 units. Decision was made to pull out of the hole. Backreamed out of the hole to the casing shoe, noting max gas of 424 units at 2813' MD. Circulated bottoms up inside casing. Pulled out of the hole on elevators to 620' MD. Flow Checked - Static. Continued pulling to surface and laid down BHA. Testing and calibrating gas equipment at report time. N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max) Background N/A Trip 424 26 11 1222310515Average464137 0 0 0000Minimum--0 287 93 8625051175161 C-5i C-5n Maximum 424 2813'43270 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)35 10 55 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693'--- Casing Summary Size Set At Type Weight 970'--- 3 MXL-1X Mill Tooth 8.75 0.785 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 -2755' 3725' --- Bit #Bit Type Size TFA Hours Depth in / out Footage % 4418'LSND ------- (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)N/A 130.0 187.0 3926' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 Location:Alpine Rig Activity:Laying Down BHA Date:18-Mar-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:612' Well:CD3-316B Daily Charges:-Current Depth:4418' Morning Report Report # 13 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:3806' . . * 24 hr Recap: Morning Report Report # 14 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:4418' Well:CD3-316B Daily Charges:-Current Depth:4593' Area:North Slope, AK Total Charges:-24 Hour Progress:175' Location:Alpine Rig Activity:Drilling Ahead Date:19-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)132.0 145.0 188.0 4446' Flow In (gpm)523 SPP (psi)1500 Flow In (spm)123 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 4417'LSND 10.70 10.75 40 20.0 12 20 5.0 9.60 1800.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)35 10 55 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 436 3609'52181 1974 868 111 179 53 52 Minimum --0 0 0 0 0 0 0 Average 46 4667 170 69 10 19 6 5 (current)(max)(max) Background 45 Trip 436 N/A 10,000 Units =100% Gas In AirConnection Made up BHA and tripped in the hole to 2662' MD. Slip and cut drill line. Shallow pulse tested MWD - Good test. Ran in the hole to 3609' MD and MAD passed to 4418' MD. Noted max gas of 436 units at 3609' MD. On bottom drilling at 21:50. Drilling ahead to 4593' MD at report time with a background of 45 units. Logging Engineers:David McKechnie/Ashlee Charters Report By:David McKechnie Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Ashlee Charters Report By: David McKechnie Unit Phone: 907-670-4047 Drilled ahead to 6,455' MD at an average ROP of 145'/hour and an average background gas of 114 units. Encountered max formation gas of 1112 units at 5633' MD. Formation samples at gas peak consisted of 65% fine grain sandstone, 25% clay and and 10% siltstone. Backreaming full stands prior to making up connections. No significant connection gas noted. Current samples in K-2 formation consist of 55% very fine grain sandstone, 35% silt and 10% siltstone. N/A 10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background 97 Trip N/A 198 60 79695402 72Average11412411 0 0 0000Minimum--0 1253 349 45258453205 475 C-5i C-5n Maximum 1112 5633'94188 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)55 35 10 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693' 20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 981' 20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 9.70 800.0 13.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 4417'LSND 10.70 10.85 38 15.0 9 20 4.9 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max - to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 527 SPP (psi)1625 Flow In (spm)124 ROP (ft/hr)150.0 145.0 193.0 4664' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 Location:Alpine Rig Activity:Drilling Ahead Date:20-Mar-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:1862' Well:CD3-316B Daily Charges:-Current Depth:6455' Morning Report Report # 15 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:4593' . . * 24 hr Recap: Morning Report Report # 16 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:6455' Well:CD3-316B Daily Charges:-Current Depth:8142' Area:North Slope, AK Total Charges:-24 Hour Progress:1687' Location:Alpine Rig Activity:Drilling Ahead Date:21-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)120.0 140.0 185.0 7580' Flow In (gpm)544 SPP (psi)2000 Flow In (spm)128 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max - to -N/A N/A N/A N/A Mud Data Density (ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2) ml/30min mg/l % 4417'LSND 10.70 10.85 38 20.0 12 22 4.6 9.10 500.0 15.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 981' 20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' 4418' 693' 20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)20 65 15 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 253 7900'25695 1447 738 105 186 57 71 Minimum --0 0 0 0 0 0 0 Average 93 8840 462 210 34 73 19 22 (current)(max)(max) Background 125 Trip N/A N/A 10,000 Units = 100% Gas In AirConnection Drilled ahead from 6455' MD to 7575' MD. Rig performed mud pump maintenace whlie reciprocating pipe. Noted max formation gas of 253 units at 7900' MD. Formation sample consisted of 35% sandstone, 30% silt and 35% siltstone. Drilling ahead to 8142' MD at report time with a background gas of 125 units. Formation samples consist of 20% sandstone, 65% silt and 15% siltstone. Logging Engineers:David McKechnie/Ashlee Charters Report By: David McKechnie Unit Phone: 907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Ashlee Charters Report By: David McKechnie Unit Phone: 907-670-4047 Drilled ahead from 8142' MD to 9368' MD with an average background of 91 units. Noted 449 units of connection gas at 9184' MD. Short tripping to 5683' MD with a background gas of 53 units at report time. Current formation samples at 9368' MD consist of 60% silt, 25% sandstone and 15% siltstone with traces of shale. 449 10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background 53 Trip N/A 139 34 43543360 54Average918127 0 0 0000Minimum--0 731 190 20428482110 332 C-5i C-5n Maximum 449 9184'37245 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)25 60 15 Tr Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693' 20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 981' 20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 9.10 500.0 15.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 4417'LSND 10.70 10.85 38 20.0 12 22 4.6 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max - to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 599 SPP (psi)1750 Flow In (spm)141 ROP (ft/hr)N/A 130.0 153.0 8612' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 Location:Alpine Rig Activity:Drilling Ahead Date:22-Mar-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:1226' Well:CD3-316B Daily Charges:-Current Depth:9368' Morning Report Report # 17 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:8142' . . * 24 hr Recap: Morning Report Report # 18 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:9368' Well:CD3-316B Daily Charges:Current Depth:10147' Area:North Slope, AK Total Charges:24 Hour Progress:779' Location:Alpine Rig Activity:Drilling Ahead Date:23-Mar-2014 Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)90.0 104.0 158.0 9749' Flow In (gpm)646 SPP (psi)2688 Flow In (spm)125 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 10030'LSND 11.20 11.25 39 16.3 12 22 3.3 9.00 600.0 16.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)10 50 40 Tr Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 371 9184'31014 2404 1810 261 563 144 149 Minimum 2 -52 0 0 0 0 0 0 Average 118 8418 642 505 86 202 56 64 (current)(max)(max)Background 72 Trip N/A 313 10,000 Units =100% Gas In AirConnection Continued to back ream out of the hole from 5595' MD to ~5062' MD. Inspect the ghost reamer and then run in to the hole from 5062' MD to 5216' MD. Circulate and condition the hole. A sweep of 130 bbl late was noted. Blow down the Top Drive, observe the well for flow, and then service the Top Drive. Run in to the hole from 5216' MD to 9085' MD. Wash down from 9085' MD to 9368' MD and then circulate a bottoms-up. Drill ahead from 9368' MD to 9969' MD. Activate the Rip Tide under reamer. Wait on Ball Mill to repair drag chain. Continue to drill from 9969' MD to 10029' MD and then take a survey. Drill ahead from 10029' MD to 10123' MD. Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 Drill from 10123' MD to 10675' MD. Perform bore psi test as per Schlumberger. Drill ahead from 10675' MD to 11184' MD. 253 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 94 Trip N/A 261 85 86783630116Average14510545 0 0 0000Minimum3-79 3276 985 9051006393401869 C-5i C-5n Maximum 600 11177'137718 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)20 30 30 20 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 9.10 500.0 17.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11085'LSND 11.20 11.25 40 22.5 14 25 2.7 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 645 SPP (psi)2708 Flow In (spm)125 ROP (ft/hr)86.3 75.0 136.0 10885' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey / A. Dorr Time:23:59 Location:Alpine Rig Activity:Drilling Ahead Date:24-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:1069' Well:CD3-316B Daily Charges:Current Depth:11216' Morning Report Report # 19 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:10147' . . * 24 hr Recap: Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 Drill from 11184' MD to 11471' MD. Take formation pressure sample. Drill from 11471' MD to 11496' MD and then take a survey. Retract reamer blades and circulate two bottoms up. Monitor well for flow. Spot casing running pill. Back ream out of hole from 9610' MD to 6820' MD. 818 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 0 Trip N/A 297 106 108726668135Average1368984 0 0 0000Minimum0-0 1440 456 44149564103713 C-5i C-5n Maximum 874 11538'64928 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)90 10 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 9.30 500.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'LSND 11.20 11.30 42 18.8 14 24 2.8 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg 645 SPP (psi)2708 Flow In (spm)125 ROP (ft/hr)0.0 74.0 128.0 11480' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 Location:Alpine Rig Activity:Drilling Ahead Date:25-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:280' Well:CD3-316B Daily Charges:Current Depth:11496' Morning Report Report # 20 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11216' . . * 24 hr Recap: Morning Report Report # 21 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:RIH with casing Date:27-Mar-2014 Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'LSND 11.20 11.20 52 12.0 15 21 2.4 9.60 400.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'40.0 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 310 -30569 785 243 35 70 23 23 Minimum 0 -0 0 0 0 0 0 0 Average 114 9419 279 102 16 33 6 4 (current)(max)(max)Background 0 Trip --10,000 Units =100% Gas In AirConnection Continue to run in to the hole with 7" casing. Circulate and dilute at 5500' MD. Continue to run in to the hole. Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 Running 7" casing into the hole. Tight spots were encountered at 9981' MD and 10460' MD. Continue running casing, currently at 10962' MD. -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 0 Trip 254 27 1 12017811Average575873 0 0 0000Minimum0-30 91 23 2891031440 C-5i C-5n Maximum 254 -28855 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade Comments 9.63''2755'40.0 4418' 693'20 110 0-1-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 981'20.0 100.0 3-3-BT-A-E-1-CT-BHA 3 MXL-1X Mill Tooth 8.75 0.785 6.50 3725' WOB RPM Condition 2 MXL-1X Mill Tooth 8.75 0.785 13.40 2744' 3725' 9.20 550.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'LSND 11.20 11.20 54 15.0 13 23 2.0 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 42 SPP (psi)427 Flow In (spm)10 ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 Location:Alpine Rig Activity:RIH with casing Date:28-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:11496' Morning Report Report # 22 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' . . * 24 hr Recap: Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 Worked casing to 10995' MD and was unable to run to TD. A decision was made to land the 7" casing. Rig down Tesco casing tools and make up the cement head. Circulate and condition mud for cement job by decreasing mud weight from 11.2 ppg to 10.9 ppg. -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 0 Trip 1039 169 35 30133267485Average28029115 0 0 0000Minimum0-22 413 83 6944772030234 C-5i C-5n Maximum 1039 -109354 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80Casing Summary Size Set At Type Weight 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 9.20 650.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'LSND 11.20 11.20 48 18.3 13 22 2.3 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 Location:Alpine Rig Activity:R/D Casing Tools Date:29-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:11496' Morning Report Report # 23 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' . . * 24 hr Recap: Morning Report Report # 24 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:L/D 5" DP Date:30-Mar-2014 Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'LSND 10.90 10.90 48 16.8 12 19 2.3 8.80 650.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 90 -7435 504 376 61 140 37 34 Minimum 0 -31 0 0 0 0 0 0 Average 37 2764 183 152 26 63 14 11 (current)(max)(max)Background 0 Trip --10,000 Units =100% Gas In AirConnection Ran centrifuge and added water to reduce mud weight from 11.2 ppg to 10.9 ppg. Completed first stage cement job with full returns throughout cement job. Finished second stage cement job. Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 Lay down 5" drill pipe and change out saver sub to 3.5". Install Bell Guide. Pick up 3.5" drill pipe and rack in derrick. Test 3.5" full opening safety valve and 3.5" Dart. -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 0 Trip - 0 0 0000Average123 0 0 0000Minimum0-0 0 0 0000 C-5i C-5n Maximum 3 -143 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80Casing Summary Size Set At Type Weight 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 9.40 650.0 16.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'LSND 10.90 10.90 50 16.8 11 20 2.7 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / A. Dorr Time:23:59 Location:Alpine Rig Activity:P/U 3.5" DP Date:31-Mar-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:11496' Morning Report Report # 25 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' . . * 24 hr Recap: Morning Report Report # 26 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:RIH with Cleanout BHA Date:1-Apr-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'GLYDRIL 10.90 10.90 46 15.0 11 16 3.5 10.00 700.0 16.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 -11496' ----- Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 10 -100 9 18 4 14 0 0 Minimum 0 -0 0 0 0 0 0 0 Average 3 51 3 6 1 4 0 0 (current)(max)(max)Background 2 Trip 10 -10,000 Units =100% Gas In AirConnection Run in hole with 3.5" drill pipe from 5516' MD to 7419' MD. Fill pipe, blow down top drive. Inspect hanging line, slip and cut 75' drill line. Service top drive and draw works. Trip in hole with 10 bbls over calculated displacement at report time. Logging Engineers:David McKechnie/Jeremy Tiegs Report By:David McKechnie Unit Phone:907-670-4047 . . * 24 hr Recap: Morning Report Report # 27 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:Clean out Rathole Date:2-Apr-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm)220 SPP (psi)2635 Flow In (spm)52 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'GLYDRIL 10.90 10.90 44 15.0 15 21 4.7 10.40 600.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 -11496' ----- Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)70 30 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 166 -15972 884 516 63 125 26 15 Minimum 0 -0 0 0 0 0 0 0 Average 12 884 51 35 4 11 0 0 (current)(max)(max)Background -Trip 166 -10,000 Units =100% Gas In AirConnection Continue to run in hole from 8370' MD to 10478' MD while filling drill pipe each 20 stands. Circulated 250 gallons per minute at 10751' MD. Test 7" casing to 3500 psi for 30 minutes. Bleed off, blow down lines, and rig down test equipment. Obtain slow pump rates. Drill cement and shoe track. Continue to work pipe down from 10990' MD to 11006' MD with 250 gallons per minute at 1930 psi. Had several slight pack offs with an increase of psi to 2200. Drill cement and shale from 11006' MD to 11128' MD. Pulled out of the hole from 11035' MD to 10995' MD to attempt to reestablish prior pump rates. Pulled up to shoe to circulate. Logging Engineers:David McKechnie/Jeremy Tiegs Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:Jeremy Tiegs / Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 Circulate and condition mud at 10995' MD. Run in to the hole from 10995' MD to 11225' MD. A gas peak of 447u was noted after circulating a bottoms-up from 11123' MD. Back ream out of the hole from 11225' MD to 10995' MD. At 10995' MD, stage pump to 305 gallons per minute to circulate and condition at the shoe. Blow down top drive and flow check. Pull out of the hole from 10940' MD to 9990' MD on trip tank. Pump 28 barrels 12.4 pound per gallon dry job. Continue pulling out of hole. -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background -Trip 447 36 6 316511316Average312702 0 0 0000Minimum0-0 254 49 4420971141131 C-5i C-5n Maximum 447 -41102 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 -11496' WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 10.50 600.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'GLYDRIL 10.90 10.90 42 17.5 10 15 4.8 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max -to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg SPP (psi) Flow In (spm) ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:POOH Date:3-Apr-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:11496' Morning Report Report # 28 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' . . * 24 hr Recap: Morning Report Report # 29 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:POOH Date:4-Apr-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'GLYDRIL 10.90 10.90 50 16.3 14 14 5.4 11.00 650.0 17.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' #VALUE!--1-2-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 137 -13108 591 274 34 66 3 0 Minimum 0 -0 0 0 0 0 0 0 Average 17 1125 67 48 7 17 1 0 (current)(max)(max)Background -Trip 137 -10,000 Units =100% Gas In AirConnection Make up mule shoe and run in the hole with 3.5" tubing to 922' MD. Change out elevators to 3.5" drill pipe. Make up crossover and rig down casing tongs. Run in the hole with 3.5" drill pipe from 922' MD to 10906' MD. From 10906' MD to 11301' MD, wash down with 5 barrels per minute. Pull out of the hole from 11301' MD to 11287' MD. Circulate and condition at 11287' MD and cement per Dowel. Had full returns throughout cement job. Pull out of the hole from 10775' MD. Pumped nut plug sweep. Saw 20 barrels of 12.5 ppg mud push and 100 barrels of 12.8 ppg cement that contaminated mud at shakers. Mud push came back 40 barrels early. Pull out of the hole on elevators. Logging Engineers:Jeremy Tiegs / Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Morning Report Report # 30 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' Well:CD3-316B Daily Charges:Current Depth:11496' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:Test BOP Date:5-Apr-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max -to -N/A N/A N/A N/A Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 11496'GLYDRIL 10.90 10.90 42 12.0 7 18 4.2 9.70 600.0 12.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078'25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' ---1-2-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 6 -161 16 30 9 24 5 0 Minimum 0 -0 0 0 0 0 0 0 Average 2 32 0 0 0 0 0 0 (current)(max)(max)Background -Trip --10,000 Units =100% Gas In AirConnection Continue to pull out of the hole. Pump a 10 barrel 12.4 ppg dry job to balance mud weight at 5481' MD. Continue to pull out of the hole on trip tank to 3106' MD. Single in from 3106' MD to 10620' MD. Wash down from 10620' MD to 10792' MD. Tag cement at 10792' MD. From 10792' MD to 10715' MD, pump dry job, blow down top drive, and flow check. Pull out of the hole from 10715' MD to 922' MD on trip tank. Continue to pull out of the hole. Rig down tubing equipment, clear rig floor. Rig up to test BOP. Logging Engineers:Jeremy Tiegs / Ashlee Charters Report By:Jeremy Tiegs Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 Tested BOP. The accumulator hydraulic holding tank failed. Closed blind rams. Rigged up and tested blinds, casing and cement plug. Monitor PSI under blinds. -10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background -Trip - 0 0 0000Average132 0 0 0000Minimum0-0 0 0 0000 C-5i C-5n Maximum 3 -50 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 11496' --- 1-2-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight 7078' 25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 92.70 11496' WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 9.80 600.0 12.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11496'GLYDRIL 10.00 10.00 42 12.0 8 12 4.0 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max - to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg SPP (psi) Flow In (spm) ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 Location:Alpine Rig Activity:Repair Accumulator Date:6-Apr-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:-195' Well:CD3-316B Daily Charges:-Current Depth:11301' Morning Report Report # 31 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11496' . . * 24 hr Recap: Morning Report Report # 32 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11301' Well:CD3-316B Daily Charges:-Current Depth:11301' Area:North Slope, AK Total Charges:-24 Hour Progress:0' Location:Alpine Rig Activity:Repair Accumulator Date:7-Apr-2014 Rig:Doyon 19 Report For:K. Harding / D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max - to -N/A N/A N/A N/A Mud Data Density (ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2) ml/30min mg/l % 11301'GLYDRIL 10.00 10.00 44 11.3 8 12 4.0 9.90 600.0 12.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC 8.75 0.863 68.20 4418' 11496' 7078' 25.0 150.0 1-1-NO-G-X-I-NO-TD 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' --- 1-2-WT-A-E-I-NO-BHA Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 -0 0 0 0 0 0 0 Minimum 0 -0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 (current)(max)(max) Background -Trip --10,000 Units = 100% Gas In AirConnection Repair Accumulator. Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 Repaired accumulator. Made up BHA per Schlumberger. Ran in to the hole from surface to 10740' MD. Circulated bottoms up. Slipped and cut drill line, and serviced top drive and draw works. Washed down from 10740' MD to 10792' MD. Drilled out cement from 10792' MD to 10930' MD. -10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background -Trip - 7 3 31487Average268 0 0 0000Minimum0-0 8 0 09110 C-5i C-5n Maximum 5 -121 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) 100% Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight --- 1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 - 11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' 10.20 600.0 10.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 11301'GLYDRIL 10.00 10.10 40 9.3 9 17 5.0 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max - to -N/A N/A N/A N/A Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg SPP (psi) Flow In (spm) ROP (ft/hr)0.0 0.0 0.0 - Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:J. Welsh / E. Grazulis Time:23:59 Location:Alpine Rig Activity:Drilling Cement Date:8-Apr-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:0' Well:CD3-316B Daily Charges:-Current Depth:11301' Morning Report Report # 33 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11301' . . * 24 hr Recap: Morning Report Report # 34 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:10930' Well:CD3-316B Daily Charges:-Current Depth:11174' Area:North Slope, AK Total Charges:-24 Hour Progress:244' Location:Alpine Rig Activity:Drilling Date:9-Apr-2014 Rig:Doyon 19 Report For:J. Welsh / E. Grazulis Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)22.0 37.0 89.0 11091' Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max - to -N/A N/A N/A N/A Mud Data Density (ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2) ml/30min mg/l % 11128'FLOTHRU 10.00 5.00 54 2.5 13 11 2.5 8.70 10600.0 8.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' --- 1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 - 11301' ----- Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)20 80 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 27 11085'2177 130 72 7 16 0 0 Minimum 2 11100'35 0 0 0 0 0 0 Average 15 1046 68 42 4 9 0 0 (current)(max)(max) Background 35 Trip -0 10,000 Units = 100% Gas In AirConnection Drilled cement plug from 10930' to 11080. Pull back to the shoe and perform FIT. Run in and drill to 11173' while d displacing to new FLOTHRU mud. Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 Drill from 11754' to 12257'. d 2774 10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background 1900 Trip - 862 224 22135722841 419Average61844202 0 0 0000Minimum00'0 4600 1093 10542223016988 2263 C-5i C-5n Maximum 4244 11941'295424 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)90 10 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight --- 1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 - 11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' 8.90 101000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage % 12045'FLOTHRU 10.00 10.00 53 2.0 18 13 3.2 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max 11174' to 12257'Gamma, Res 10.95 10.62 11.24 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 188 SPP (psi)2558 Flow In (spm)45 ROP (ft/hr)105.3 83.6 119.4 12090' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:J. Welsh / E. Grazulis Time:23:59 Location:Alpine Rig Activity:Drilling Date:10-Apr-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:1083' Well:CD3-316B Daily Charges:-Current Depth:12257' Morning Report Report # 35 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:11174' . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 Drilled from 12257' MD to 13754' MD. d 1881 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background Trip - 2447 675 671901175661158Average1218110708 0 0 0000Minimum00'0 6721 1836 178823147208713211 C-5i C-5n Maximum 4704 13344'275658 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)95 5 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 -11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496'11496' 8.90 104000.0 10.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 12045'FLOTHRU 10.00 10.00 55 3.0 17 16 2.1 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max 11174' to 13760'Gamma, Res 11.15 10.88 11.32 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)Avg 189 SPP (psi)2650 Flow In (spm)44 ROP (ft/hr)75.0 92.2 181.6 13118' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey/D. Lowe Time:23:59 Location:Alpine Rig Activity:Drilling Date:11-Apr-2014 Area:North Slope, AK Total Charges:24 Hour Progress:1503' Well:CD3-316B Daily Charges:Current Depth:13760' Morning Report Report # 36 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:12257' . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 Drilled from 13754' to 13970', circulated and conditioned due to mud cut, drilled from 13970' to 15023'. d N/A 10,000 Units = 100% Gas In AirConnection (current)(max)(max) Background 3000 Trip - 4379 1317 6711484912956 2031Average2040177294 891 414 4546731132 356Minimum17614071'3481 9248 2457 23913215429455 4352 C-5i C-5n Maximum 6301 13821'384603 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)100 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight --- 1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 - 11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' 9.00 94000.0 10.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 13971'FLOTHRU 10.10 10.10 55 3.5 20 16 1.9 (ppb Eq)cP (lb/100ft2) ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg) Viscosity MBT PV Min Max 11174' to 15023'Gamma, Res 11.21 10.90 11.38 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 190 SPP (psi)2818 Flow In (spm)45 ROP (ft/hr)101.0 95.3 128.5 13821' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey/D. Lowe Time:23:59 Location:Alpine Rig Activity:Drilling Date:12-Apr-2014 Area:North Slope, AK Total Charges:-24 Hour Progress:1263' Well:CD3-316B Daily Charges:-Current Depth:15023' Morning Report Report # 37 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:13760' . . * 24 hr Recap: Morning Report Report # 38 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:15023' Well:CD3-316B Daily Charges:-Current Depth:16534' Area:North Slope, AK Total Charges:-24 Hour Progress:1511' Location:Alpine Rig Activity:Drilling Date:13-Apr-2014 Rig:Doyon 19 Report For:D. Mickey/D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)106.1 96.0 139.3 15400' Flow In (gpm)183 SPP (psi)2855 Flow In (spm)44 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 11174' to 16534'Gamma, Res 11.33 11.10 11.57 Mud Data Density (ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2) ml/30min mg/l % 16313'FLOTHRU 10.10 10.25 53 3.8 20 16 2.1 9.40 95000.0 11.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496' 11496' --- 1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 - 11301' ----- Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)100 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 5413 15284'320442 28012 26120 4035 8496 2375 2345 Minimum 332 15782'13509 1553 1876 449 1035 421 457 Average 1505 109297 9827 9088 1559 3352 1046 1075 (current)(max)(max) Background 2185 Trip -N/A 10,000 Units = 100% Gas In AirConnection Drilled from 15023' to 16534'. Samples have been primarily sandstone with occasional to trace amounts of d siltstone. Logging Engineers:Tyler Dretke / Ashlee Charters Report By: T. Dretke Unit Phone: 907-670-4047 . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 Drilled from 16534' MD to 16824' MD. Circulated and conditioned due to gas, flow checked bottoms up, and d observed well flowing. Weighted up from 10 ppg to 10.4 ppg drilling fluid and observed well flow. Performed exhale test, shut in well and bled down. Broke down choke line and manifold. Circulated and conditioned bottoms up. Drilled ahead from 16824' MD to 17942' MD. Observed slight flow on connection. Circulated bottoms up. Racked stand back, circulated to weight up from 10.4 ppg to 10.6 ppg. N/A 10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 202 Trip - 3188 944 9841172298711494Average1565136922 712 313 3607191244318Minimum22817112'4029 10513 2882 278234922331375133 C-5i C-5n Maximum 7290 16637'448000 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current)100 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 -11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496'11496' 9.20 138000.0 13.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 16313'FLOTHRU 10.40 10.40 53 2.5 19 14 1.9 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max 11174' to 17493'Gamma, Res 11.67 11.22 11.99 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 183 SPP (psi)3148 Flow In (spm)45 ROP (ft/hr)0.0 93.0 214.4 17208' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey/D. Lowe Time:23:59 Location:Alpine Rig Activity:Circulating Date:14-Apr-2014 Area:North Slope, AK Total Charges:24 Hour Progress:959' Well:CD3-316B Daily Charges:Current Depth:17493' Morning Report Report # 39 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:16534' . . * 24 hr Recap: Morning Report Report # 40 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:17493' Well:CD3-316B Daily Charges:Current Depth:17493' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:POOH Date:15-Apr-2014 Rig:Doyon 19 Report For:D. Mickey/D. Lowe Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)---- Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 11174' to 17493'Gamma, Res 11.67 11.22 11.99 Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 17942'FLOTHRU 10.60 10.60 54 2.5 20 16 1.6 9.40 141000.0 14.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496'11496' ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 -11301' ----- Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current)100 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 7436 17493'433923 54747 51059 4904 7868 1054 1067 Minimum 320 17410'17412 1714 2249 406 741 223 248 Average 4666 276494 33408 29448 3049 5140 856 878 (current)(max)(max)Background 154 Trip --10,000 Units =100% Gas In AirConnection Circulated and conditioned, weighted up from 10.4 ppg to 10.6 ppg. Performed exhale test. Circulated and d conditioned bottoms up. Performed exhale test. Circulated and conditioned bottoms up, and observed well continuing to flow. Shut in well, circulated and conditioned. Pulled out of the hole from 17492' MD to 13019' MD. Circulating gas of 10000 units was observed after circulating bottoms up following the second exhale test. Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 Pulled out of the hole with pumps on from 13019' MD to 10930' MD. Circulated and conditioned bottoms up. d Weighted up from 10.6 ppg to 10.8 ppg. Flow checked and observed well flowing. Circulated and conditioned. Performed exhale test. Shut in the well, and circulated and conditioned. Weighted up from 10.8 ppg to 11.0 pgg. Observed well. Pulled out of the hole from 10930' MD to 5319' MD on the trip tank. -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 0 Trip - 77 32 4017514834Average563036 0 0 0000Minimum20 348 119 1231295934170 C-5i C-5n Maximum 307 24573 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 ----- Casing Summary Size Set At Type Weight ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 -11301' WOB RPM Condition 4 QH1R Mill 6.125 0.665 92.70 11496'11496' 9.80 166000.0 16.5 Bit #Bit Type Size TFA Hours Depth in / out Footage % 17942'FLOTHRU 11.05 11.05 77 3.0 26 30 1.4 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max 11174' to 17493'Gamma, Res --- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)---- Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey/A. Dorr Time:23:59 Location:Alpine Rig Activity:POOH Date:16-Apr-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:17493' Morning Report Report # 41 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:17493' . . * 24 hr Recap: Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 Ran in the hole with 4.5" liner. Began displacing FLOTHRU system to 11.0 ppg NaCl/NaBr brine completion fluid. d -10,000 Units =100% Gas In AirConnection (current)(max)(max)Background 31 Trip - 9 1 1872Average13302 0 0 0000Minimum0-22 19 12 1732187 C-5i C-5n Maximum 25 -1261 C-2 C-3 C-4i C-4nUnits*Depth C-1 Chromatograph (ppm) Gas Summary Cement (current) Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 7"10995'Intermediate Line 26.0 L-80 Grade Comments 9.63''2755'Surface Line 40.0 L-80 17492' 6472'10 150 2-1-CT-M-X-I-HC-TD Casing Summary Size Set At Type Weight ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 220.00 11020' WOB RPM Condition 4 QH1R Mill 6.125 0.666 92.70 11496'11496' --- Bit #Bit Type Size TFA Hours Depth in / out Footage % 17942'FLOTHRU 10.90 10.90 -3.0 27 32 1.6 (ppb Eq)cP (lb/100ft2)ml/30min mg/l YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt) Mud Data Density (ppg)Viscosity MBT PV Min Max 11174' to 17493'Gamma, Res --- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg - SPP (psi)- Flow In (spm)- ROP (ft/hr)---- Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Rig:Doyon 19 Report For:D. Mickey/A. Dorr Time:23:59 Location:Alpine Rig Activity:RIH with 4.5" Liner Date:17-Apr-2014 Area:North Slope, AK Total Charges:24 Hour Progress:0' Well:CD3-316B Daily Charges:Current Depth:17493' Morning Report Report # 42 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:17493' . . * 24 hr Recap: Morning Report Report # 43 Customer:ConocoPhillips Alaska, Inc.Job No.:901152148 Yesterday's Depth:17493' Well:CD3-316B Daily Charges:Current Depth:17493' Area:North Slope, AK Total Charges:24 Hour Progress:0' Location:Alpine Rig Activity:Circ & Cond B/U Date:18-Apr-2014 Rig:Doyon 19 Report For:D. Mickey/A. Dorr Time:23:59 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)---- Flow In (gpm)- SPP (psi)- Flow In (spm)- Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 11174' to 17493'Gamma, Res --- Mud Data Density (ppg)Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in out (sec/qt)(ppb Eq)cP (lb/100ft2)ml/30min mg/l % 17942'FLOTHRU 11.00 11.00 82 3.0 23 26 1.6 8.90 163000.0 16.5 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 QH1R Mill 6.125 0.666 92.70 11496'11496' ---1-2-WT-A-E-I-NO-BHA 5 MDi513 PDC 6.125 0.296 220.00 11020' 17492' 6472'10 150 2-1-CT-M-X-I-HC-TD Casing Summary Size Set At Type Weight Grade Comments 9.63''2755'Surface Line 40.0 L-80 7"10995'Intermediate Line 26.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 33 -2163 63 31 10 23 15 18 Minimum 8 -58 0 0 0 0 0 0 Average 21 993 34 17 4 14 2 2 (current)(max)(max)Background 25 Trip --10,000 Units =100% Gas In AirConnection Ran in the hole with 4.5" liner from 5339' MD to 6672' MD. Made up packer and ran in the hole with heavy weight d drill pipe from 6709' MD to 8357' MD. Continued to run in the hole from 8357' MD to 17492' MD. Circulated and conditioned bottoms up. Logging Engineers:Tyler Dretke / Ashlee Charters Report By:T. Dretke Unit Phone:907-670-4047 WELL INFORMATION Created On : May 27 2014 Customer :ConocoPhillips Alaska Inc. Well Name :CD3-316B Job Number :AK-XX-0901152148 Rig Name :Doyon 19 Field Name :Alpine 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') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 36.30 0.00 0.00 36.30 0.00 N 0.00 E 0.00 0.00 81.00 0.50 96.00 81.00 0.02 S 0.19 E -0.13 1.12 170.00 0.75 89.00 169.99 0.05 S 1.16 E -0.71 0.29 261.00 0.47 186.50 260.99 0.41 S 1.72 E -1.32 1.03 352.00 0.85 238.00 351.99 1.14 S 1.10 E -1.57 0.73 442.00 2.10 210.00 441.95 2.92 S 0.29 W -2.23 1.56 511.39 2.79 213.39 511.28 5.43 S 1.85 W -3.39 1.02 570.41 3.42 203.43 570.21 8.25 S 3.35 W -4.84 1.40 661.03 4.81 186.49 660.60 14.50 S 4.85 W -9.10 2.02 750.35 7.04 183.45 749.44 23.69 S 5.60 W -16.19 2.52 842.09 9.94 173.87 840.17 37.18 S 5.09 W -27.53 3.51 937.40 13.85 161.21 933.43 56.17 S 0.54 W -45.70 4.91 1032.37 14.69 158.37 1,025.47 78.12 S 7.56 E -68.33 1.15 1127.59 13.77 159.22 1,117.77 99.94 S 16.03 E -91.06 0.99 1222.36 14.55 151.34 1,209.67 120.93 S 25.74 E -113.83 2.19 1317.17 16.66 143.19 1,300.99 142.27 S 39.60 E -139.26 3.20 1412.12 18.90 133.16 1,391.42 163.69 S 58.98 E -167.92 3.99 1507.41 23.04 123.18 1,480.41 184.47 S 85.87 E -200.36 5.72 1559.89 24.40 117.74 1,528.46 195.14 S 104.06 E -219.53 4.91 1602.63 24.66 113.37 1,567.34 202.79 S 120.06 E -234.97 4.29 1697.43 26.02 104.09 1,653.05 215.70 S 158.40 E -267.54 4.42 1792.80 27.17 94.65 1,738.37 222.56 S 200.41 E -297.26 4.59 1888.04 29.60 91.16 1,822.16 224.80 S 245.61 E -325.02 3.09 1983.30 33.48 91.98 1,903.33 226.18 S 295.41 E -354.72 4.10 2079.19 35.22 92.57 1,982.50 228.34 S 349.47 E -387.49 1.85 2174.01 36.44 91.96 2,059.37 230.53 S 404.93 E -421.10 1.34 2269.16 38.15 90.67 2,135.06 231.84 S 462.56 E -455.23 1.98 2363.95 41.92 92.60 2,207.63 233.62 S 523.50 E -491.63 4.19 2458.85 46.27 92.62 2,275.77 236.62 S 589.45 E -531.92 4.58 2553.86 46.29 92.52 2,341.43 239.70 S 658.04 E -573.79 0.08 INSITE V8.0.20 Page 1Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2651.35 44.92 93.02 2,409.64 243.06 S 727.62 E -616.45 1.45 2704.99 44.85 92.93 2,447.64 245.03 S 765.42 E -639.75 0.18 2741.52 44.61 92.81 2,473.59 246.32 S 791.10 E -655.53 0.70 2838.79 44.14 92.18 2,543.12 249.28 S 859.06 E -696.93 0.66 2932.20 44.04 90.51 2,610.21 250.81 S 924.03 E -735.45 1.25 3029.17 45.20 89.56 2,679.24 250.84 S 992.14 E -774.55 1.38 3120.64 50.25 90.00 2,740.75 250.59 S 1,059.80 E -813.15 5.53 3168.34 53.60 89.50 2,770.16 250.42 S 1,097.34 E -834.55 7.07 3215.90 57.12 89.27 2,797.19 250.00 S 1,136.46 E -856.64 7.41 3264.67 59.06 87.79 2,822.97 248.94 S 1,177.85 E -879.50 4.74 3309.28 58.64 88.04 2,846.04 247.55 S 1,216.00 E -900.25 1.06 3404.23 60.59 89.06 2,894.07 245.48 S 1,297.87 E -945.52 2.25 3498.13 60.64 88.35 2,940.14 243.63 S 1,379.67 E -990.92 0.66 3593.06 60.73 88.34 2,986.62 241.24 S 1,462.41 E -1036.42 0.10 3619.07 60.98 88.24 2,999.29 240.56 S 1,485.12 E -1048.89 1.02 3648.15 60.83 87.80 3,013.43 239.69 S 1,510.51 E -1062.73 1.42 3727.31 59.91 87.47 3,052.57 236.85 S 1,579.26 E -1099.84 1.22 3821.63 59.52 87.69 3,100.13 233.41 S 1,660.64 E -1143.70 0.46 3916.73 58.47 86.34 3,149.12 229.17 S 1,742.03 E -1186.92 1.64 4010.76 58.05 86.39 3,198.59 224.10 S 1,821.84 E -1228.54 0.45 4104.78 56.94 86.26 3,249.11 219.02 S 1,900.97 E -1269.76 1.19 4199.73 55.64 85.80 3,301.80 213.55 S 1,979.76 E -1310.48 1.43 4294.69 57.20 86.01 3,354.33 207.90 S 2,058.67 E -1351.11 1.65 4386.76 58.13 85.75 3,403.57 202.31 S 2,136.26 E -1391.04 1.04 4481.33 58.36 86.84 3,453.34 197.12 S 2,216.50 E -1432.81 1.01 4576.21 58.45 88.76 3,503.05 194.02 S 2,297.25 E -1476.58 1.73 4671.10 58.13 91.66 3,552.94 194.31 S 2,377.97 E -1523.11 2.62 4764.62 58.28 91.88 3,602.21 196.76 S 2,457.41 E -1570.70 0.26 4859.57 58.25 91.18 3,652.16 198.92 S 2,538.14 E -1618.76 0.63 4955.77 58.35 89.24 3,702.71 199.22 S 2,619.98 E -1665.95 1.72 5056.12 58.04 88.52 3,755.60 197.55 S 2,705.24 E -1713.49 0.68 5148.81 58.12 86.47 3,804.61 194.11 S 2,783.84 E -1755.75 1.88 5243.83 57.95 85.71 3,854.91 188.62 S 2,864.26 E -1797.38 0.70 5337.28 57.86 89.00 3,904.58 184.96 S 2,943.33 E -1839.74 2.98 5431.71 57.70 91.28 3,954.93 185.16 S 3,023.21 E -1885.71 2.05 5525.59 57.71 90.66 4,005.09 186.50 S 3,102.55 E -1932.33 0.56 5620.99 57.88 89.96 4,055.93 186.94 S 3,183.27 E -1978.98 0.65 5714.36 57.86 88.17 4,105.59 185.65 S 3,262.33 E -2023.27 1.62 5809.71 57.70 87.47 4,156.43 182.58 S 3,342.93 E -2066.99 0.64 5903.69 57.64 87.03 4,206.69 178.77 S 3,422.25 E -2109.37 0.40 5997.82 57.79 86.66 4,256.97 174.39 S 3,501.71 E -2151.35 0.37 6091.92 57.82 87.24 4,307.10 170.15 S 3,581.23 E -2193.49 0.52 6186.73 57.81 87.13 4,357.61 166.21 S 3,661.37 E -2236.23 0.10 6281.24 57.70 87.40 4,408.03 162.40 S 3,741.22 E -2278.90 0.27 6375.10 58.20 86.41 4,457.84 158.10 S 3,820.65 E -2320.95 1.04 INSITE V8.0.20 Page 2Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6469.39 58.05 86.72 4,507.63 153.30 S 3,900.58 E -2362.86 0.32 6564.42 57.98 86.43 4,557.97 148.49 S 3,981.04 E -2405.07 0.27 6658.87 58.26 85.49 4,607.85 142.84 S 4,061.04 E -2446.32 0.90 6754.08 58.12 87.12 4,658.04 137.62 S 4,141.78 E -2488.36 1.46 6847.07 58.12 86.86 4,707.15 133.47 S 4,220.63 E -2530.19 0.24 6941.80 58.07 87.06 4,757.22 129.21 S 4,300.94 E -2572.76 0.19 7034.29 58.19 86.52 4,806.05 124.81 S 4,379.36 E -2614.14 0.51 7130.18 58.19 88.24 4,856.60 121.09 S 4,460.76 E -2657.78 1.52 7224.86 58.11 90.17 4,906.56 119.97 S 4,541.17 E -2702.98 1.73 7318.73 58.27 91.54 4,956.05 121.16 S 4,620.93 E -2749.71 1.25 7412.39 57.49 90.22 5,005.85 122.38 S 4,700.24 E -2796.20 1.46 7507.34 56.21 86.48 5,057.78 120.11 S 4,779.68 E -2839.91 3.56 7600.47 55.04 82.44 5,110.38 112.71 S 4,856.16 E -2877.71 3.79 7694.77 54.21 78.61 5,164.98 100.07 S 4,931.98 E -2910.85 3.43 7789.53 53.19 74.08 5,221.10 82.07 S 5,006.16 E -2938.65 4.00 7884.52 52.19 69.75 5,278.69 58.65 S 5,077.96 E -2960.64 3.77 7979.48 51.50 63.71 5,337.39 29.19 S 5,146.50 E -2975.83 5.05 8029.42 51.32 61.15 5,368.54 11.13 S 5,181.10 E -2980.87 4.02 8075.01 51.25 59.64 5,397.06 6.45 N 5,212.03 E -2984.22 2.59 8166.70 50.88 54.88 5,454.70 44.99 N 5,271.99 E -2987.04 4.06 8263.13 50.52 50.44 5,515.79 90.23 N 5,331.30 E -2984.00 3.58 8357.47 51.33 47.29 5,575.27 138.40 N 5,386.44 E -2976.16 2.73 8451.46 51.85 44.30 5,633.67 189.75 N 5,439.22 E -2964.38 2.55 8545.53 52.13 40.54 5,691.61 244.45 N 5,489.19 E -2948.24 3.16 8639.83 51.80 36.36 5,749.73 302.59 N 5,535.37 E -2927.09 3.51 8734.35 51.87 32.92 5,808.15 363.72 N 5,577.60 E -2901.24 2.86 8828.76 51.81 29.02 5,866.49 427.35 N 5,615.78 E -2871.03 3.25 8923.35 51.76 24.35 5,925.03 493.72 N 5,649.14 E -2835.79 3.88 9018.57 52.66 20.23 5,983.39 563.32 N 5,677.66 E -2795.13 3.55 9109.98 53.69 15.05 6,038.20 633.02 N 5,699.80 E -2750.74 4.67 9205.04 55.31 10.04 6,093.43 708.52 N 5,716.57 E -2698.50 4.62 9301.05 56.99 6.56 6,146.92 787.40 N 5,728.05 E -2640.47 3.48 9394.70 58.86 4.58 6,196.65 866.38 N 5,735.74 E -2580.19 2.68 9488.98 60.50 3.20 6,244.24 947.57 N 5,741.25 E -2516.85 2.15 9582.95 60.62 359.23 6,290.44 1,029.36 N 5,742.98 E -2450.84 3.68 9676.08 60.48 354.79 6,336.25 1,110.32 N 5,738.76 E -2382.10 4.15 9772.89 60.46 351.69 6,383.97 1,193.95 N 5,728.84 E -2307.91 2.79 9867.00 60.38 347.32 6,430.45 1,274.40 N 5,713.94 E -2233.46 4.04 9962.17 60.52 343.02 6,477.40 1,354.40 N 5,692.76 E -2155.77 3.93 10055.33 60.74 341.06 6,523.09 1,431.63 N 5,667.72 E -2078.16 1.85 10150.19 60.74 340.56 6,569.46 1,509.78 N 5,640.52 E -1998.53 0.46 10243.96 60.60 339.65 6,615.39 1,586.65 N 5,612.70 E -1919.61 0.86 10338.83 60.81 339.59 6,661.81 1,664.21 N 5,583.89 E -1839.55 0.23 10432.79 60.71 340.72 6,707.71 1,741.33 N 5,556.06 E -1760.41 1.05 10527.55 60.68 340.56 6,754.09 1,819.29 N 5,528.66 E -1680.84 0.15 INSITE V8.0.20 Page 3Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10620.83 61.99 339.90 6,798.84 1,896.31 N 5,500.98 E -1601.87 1.54 10716.35 63.10 340.27 6,842.88 1,976.00 N 5,472.11 E -1520.03 1.21 10809.95 64.83 339.64 6,883.96 2,055.00 N 5,443.28 E -1438.78 1.94 10904.88 68.12 338.27 6,921.85 2,136.22 N 5,412.01 E -1354.32 3.71 10998.92 71.59 336.20 6,954.23 2,217.60 N 5,377.84 E -1268.05 4.23 11056.16 75.01 335.87 6,970.68 2,267.70 N 5,355.57 E -1214.25 6.00 11114.06 73.45 338.31 6,986.41 2,319.01 N 5,333.88 E -1159.77 4.87 11154.30 71.26 342.44 6,998.62 2,355.12 N 5,321.00 E -1122.81 11.19 11207.64 72.72 341.73 7,015.11 2,403.38 N 5,305.39 E -1074.32 3.02 11249.40 75.06 343.51 7,026.69 2,441.67 N 5,293.42 E -1036.09 6.94 11303.51 77.20 342.86 7,039.67 2,491.95 N 5,278.22 E -986.18 4.12 11343.22 80.06 341.73 7,047.49 2,529.03 N 5,266.38 E -949.01 7.72 11396.16 81.97 339.48 7,055.76 2,578.35 N 5,249.01 E -898.66 5.54 11438.93 83.49 337.52 7,061.17 2,617.82 N 5,233.46 E -857.40 5.77 11488.77 85.38 336.90 7,066.01 2,663.55 N 5,214.25 E -808.92 3.99 11533.30 87.37 333.38 7,068.82 2,703.86 N 5,195.57 E -765.19 9.07 11589.55 90.62 331.42 7,069.81 2,753.69 N 5,169.52 E -709.42 6.75 11627.12 92.05 330.31 7,068.94 2,786.50 N 5,151.23 E -672.06 4.82 11677.28 93.93 329.91 7,066.32 2,829.93 N 5,126.27 E -622.17 3.83 11722.22 94.04 328.46 7,063.20 2,868.43 N 5,103.30 E -577.46 3.23 11817.86 93.70 328.98 7,056.74 2,949.98 N 5,053.76 E -482.24 0.65 11913.70 91.51 329.42 7,052.39 3,032.21 N 5,004.74 E -386.76 2.33 12007.30 90.96 329.52 7,050.37 3,112.82 N 4,957.20 E -293.47 0.60 12102.30 91.89 328.71 7,048.01 3,194.32 N 4,908.45 E -198.75 1.30 12200.50 91.83 327.33 7,044.82 3,277.57 N 4,856.47 E -100.74 1.41 12293.24 91.91 326.27 7,041.79 3,355.13 N 4,805.72 E -8.09 1.15 12388.21 91.94 326.43 7,038.60 3,434.14 N 4,753.13 E 86.80 0.17 12483.98 91.87 326.83 7,035.42 3,514.08 N 4,700.48 E 182.48 0.42 12579.41 91.72 326.74 7,032.43 3,593.88 N 4,648.23 E 277.81 0.18 12674.26 90.66 327.79 7,030.46 3,673.64 N 4,596.95 E 372.57 1.57 12770.74 90.05 329.90 7,029.86 3,756.20 N 4,547.04 E 468.82 2.28 12863.40 89.85 330.91 7,029.94 3,836.77 N 4,501.28 E 561.07 1.11 12957.66 89.78 329.91 7,030.25 3,918.74 N 4,454.73 E 654.91 1.06 13055.38 89.77 330.22 7,030.63 4,003.42 N 4,405.97 E 752.24 0.32 13148.08 90.26 329.13 7,030.61 4,083.43 N 4,359.17 E 844.63 1.29 13243.08 90.71 328.22 7,029.80 4,164.58 N 4,309.78 E 939.43 1.07 13338.71 90.84 329.10 7,028.51 4,246.25 N 4,260.05 E 1034.86 0.93 13434.15 90.77 329.91 7,027.17 4,328.48 N 4,211.62 E 1129.99 0.85 13528.58 90.78 329.24 7,025.89 4,409.90 N 4,163.80 E 1224.11 0.71 13623.67 90.36 329.18 7,024.94 4,491.58 N 4,115.13 E 1318.94 0.45 13719.34 90.25 328.86 7,024.43 4,573.60 N 4,065.89 E 1414.38 0.35 13814.90 90.67 329.15 7,023.67 4,655.51 N 4,016.68 E 1509.70 0.53 13909.41 90.81 329.58 7,022.45 4,736.83 N 3,968.52 E 1603.93 0.48 14004.50 90.67 329.74 7,021.22 4,818.89 N 3,920.49 E 1698.69 0.22 14099.53 90.71 329.04 7,020.07 4,900.67 N 3,872.11 E 1793.44 0.74 INSITE V8.0.20 Page 4Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14194.83 90.29 330.34 7,019.24 4,982.94 N 3,824.02 E 1888.41 1.43 14290.05 89.98 328.68 7,019.02 5,064.99 N 3,775.70 E 1983.33 1.77 14386.56 90.11 329.12 7,018.94 5,147.62 N 3,725.85 E 2079.62 0.48 14480.71 91.03 327.99 7,018.01 5,227.94 N 3,676.74 E 2173.58 1.55 14575.85 90.91 325.71 7,016.40 5,307.58 N 3,624.73 E 2268.65 2.40 14670.89 91.06 324.97 7,014.76 5,385.74 N 3,570.68 E 2363.68 0.79 14769.71 90.41 326.16 7,013.49 5,467.24 N 3,514.81 E 2462.48 1.37 14862.60 88.49 326.63 7,014.39 5,544.59 N 3,463.40 E 2555.33 2.13 14957.42 88.06 327.24 7,017.24 5,624.02 N 3,411.69 E 2650.06 0.79 15052.33 87.40 326.54 7,021.00 5,703.46 N 3,359.89 E 2744.84 1.01 15147.50 88.03 325.98 7,024.79 5,782.53 N 3,307.07 E 2839.91 0.89 15241.43 88.00 324.11 7,028.05 5,859.47 N 3,253.29 E 2933.78 1.99 15337.25 87.65 325.65 7,031.68 5,937.79 N 3,198.21 E 3029.53 1.65 15431.56 87.53 325.73 7,035.65 6,015.62 N 3,145.10 E 3123.75 0.15 15526.76 89.03 324.71 7,038.51 6,093.77 N 3,090.82 E 3218.90 1.91 15622.56 89.97 323.28 7,039.34 6,171.26 N 3,034.51 E 3314.68 1.79 15718.48 90.04 323.42 7,039.33 6,248.22 N 2,977.25 E 3410.56 0.16 15813.04 91.29 323.13 7,038.24 6,324.01 N 2,920.71 E 3505.07 1.36 15908.89 92.33 321.81 7,035.21 6,399.98 N 2,862.35 E 3600.77 1.75 16002.63 92.49 320.88 7,031.27 6,473.11 N 2,803.85 E 3694.24 1.01 16097.85 92.52 320.67 7,027.11 6,546.81 N 2,743.69 E 3789.11 0.22 16193.49 92.60 321.44 7,022.83 6,621.12 N 2,683.64 E 3884.43 0.81 16288.74 92.11 322.44 7,018.92 6,696.05 N 2,624.97 E 3979.46 1.17 16383.61 91.38 321.72 7,016.03 6,770.85 N 2,566.69 E 4074.16 1.08 16478.56 91.25 322.07 7,013.85 6,845.55 N 2,508.11 E 4168.94 0.39 16571.54 91.54 323.60 7,011.59 6,919.62 N 2,451.96 E 4261.83 1.67 16667.17 91.03 319.40 7,009.44 6,994.42 N 2,392.46 E 4357.23 4.42 16715.64 91.51 318.86 7,008.37 7,031.07 N 2,360.75 E 4405.44 1.49 16763.62 91.35 316.38 7,007.17 7,066.50 N 2,328.42 E 4453.00 5.18 16859.12 91.77 315.29 7,004.57 7,134.98 N 2,261.91 E 4547.25 1.22 16954.91 91.80 316.16 7,001.59 7,203.53 N 2,195.07 E 4641.74 0.91 17050.92 92.42 317.20 6,998.05 7,273.33 N 2,129.25 E 4736.67 1.26 17150.91 92.38 317.32 6,993.87 7,346.70 N 2,061.45 E 4835.66 0.13 17240.52 92.38 314.88 6,990.14 7,411.21 N 1,999.37 E 4924.11 2.72 17335.12 93.26 312.84 6,985.49 7,476.67 N 1,931.25 E 5016.81 2.35 17431.02 93.04 310.27 6,980.22 7,540.19 N 1,859.60 E 5109.93 2.69 INSITE V8.0.20 Page 5Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report 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 18.96 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 17,431.02 feet is 7,766.11 feet along 13.85 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 6Job No:AK-XX-0901152148 Well Name:CD3-316B Survey Report WELL INFORMATION Created On : May 27 2014 Customer :ConocoPhillips Alaska, Inc Well Name :CD3-316B PB1 Job Number :AK-XX-0901152148 Rig Name :Doyon 19 Field Name :Alpine 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') 2704.99 44.85 92.93 2,437.09 51.41 S 1,004.42 E -618.23 1.66 2741.52 44.61 92.81 2,463.04 52.70 S 1,030.10 E -634.01 0.70 2838.79 44.14 92.18 2,532.57 55.66 S 1,098.06 E -675.42 0.66 2932.20 44.04 90.51 2,599.66 57.19 S 1,163.03 E -713.93 1.25 3029.17 45.20 89.56 2,668.68 57.22 S 1,231.14 E -753.03 1.38 3120.64 50.25 90.00 2,730.19 56.97 S 1,298.80 E -791.63 5.53 3168.34 53.60 89.50 2,759.60 56.80 S 1,336.34 E -813.03 7.07 3215.90 57.12 89.27 2,786.63 56.38 S 1,375.46 E -835.12 7.41 3264.67 59.06 87.79 2,812.41 55.31 S 1,416.85 E -857.98 4.74 3309.28 58.64 88.04 2,835.49 53.93 S 1,455.00 E -878.73 1.06 3404.23 60.59 89.06 2,883.51 51.86 S 1,536.87 E -924.00 2.25 3498.13 60.64 88.35 2,929.59 50.01 S 1,618.67 E -969.40 0.66 3593.06 60.73 88.34 2,976.07 47.62 S 1,701.41 E -1014.90 0.10 3619.07 60.98 88.24 2,988.73 46.94 S 1,724.12 E -1027.37 1.02 3648.15 60.83 87.80 3,002.87 46.06 S 1,749.51 E -1041.22 1.42 3727.31 59.92 87.35 3,042.01 43.15 S 1,818.26 E -1078.26 1.25 3821.63 59.52 87.46 3,089.56 39.47 S 1,899.63 E -1121.91 0.44 3916.73 58.49 86.11 3,138.54 34.90 S 1,981.02 E -1164.86 1.63 4010.76 58.05 86.13 3,187.99 29.49 S 2,060.81 E -1206.19 0.47 4104.78 56.95 86.00 3,238.51 24.05 S 2,139.92 E -1247.11 1.18 4199.73 55.70 85.54 3,291.15 18.22 S 2,218.72 E -1287.53 1.38 4294.69 57.21 85.76 3,343.63 12.22 S 2,297.63 E -1327.88 1.60 4386.76 58.11 85.62 3,392.88 6.37 S 2,375.20 E -1367.58 0.99 4481.33 58.35 86.71 3,442.67 1.00 S 2,455.42 E -1409.19 1.01 4576.21 58.46 88.50 3,492.38 2.38 N 2,536.16 E -1452.74 1.61 4671.10 58.15 91.43 3,542.24 2.43 N 2,616.89 E -1498.99 2.65 4764.62 58.27 91.75 3,591.51 0.23 N 2,696.35 E -1546.38 0.32 4859.57 58.26 90.94 3,641.46 1.67 S 2,777.08 E -1594.23 0.73 4955.77 58.36 88.98 3,692.00 1.61 S 2,858.93 E -1641.14 1.74 5056.12 58.05 88.33 3,744.87 0.39 N 2,944.19 E -1688.40 0.63 5148.81 58.13 86.23 3,793.87 4.12 N 3,022.78 E -1730.42 1.93 INSITE V8.0.20 Page 1Job No:AK-XX-0901152148 Well Name:CD3-316B PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 5243.83 57.95 85.55 3,844.16 9.90 N 3,103.19 E -1771.81 0.64 5337.28 57.85 88.87 3,893.83 13.76 N 3,182.24 E -1813.99 3.01 5431.71 57.71 91.01 3,944.18 13.84 N 3,262.12 E -1859.74 1.92 5525.59 57.71 90.45 3,994.34 12.83 N 3,341.48 E -1906.09 0.50 5620.99 57.88 89.75 4,045.18 12.69 N 3,422.20 E -1952.50 0.65 5714.36 57.85 88.04 4,094.85 14.21 N 3,501.25 E -1996.59 1.55 5809.71 57.71 87.20 4,145.69 17.56 N 3,581.84 E -2040.08 0.76 5903.69 57.64 86.88 4,195.94 21.66 N 3,661.15 E -2082.21 0.30 5997.82 57.78 86.53 4,246.22 26.24 N 3,740.59 E -2124.03 0.35 6091.92 57.82 87.07 4,296.37 30.68 N 3,820.09 E -2165.99 0.49 6186.73 57.80 86.98 4,346.88 34.85 N 3,900.22 E -2208.53 0.08 6281.24 57.71 87.26 4,397.30 38.86 N 3,980.06 E -2251.04 0.27 6375.10 58.18 86.24 4,447.12 43.37 N 4,059.48 E -2292.89 1.05 6469.39 58.06 86.46 4,496.92 48.47 N 4,139.38 E -2334.55 0.24 6564.42 57.99 86.25 4,547.24 53.60 N 4,219.83 E -2376.49 0.20 6658.87 58.25 85.32 4,597.12 59.49 N 4,299.81 E -2417.54 0.88 6754.08 58.13 86.91 4,647.31 64.97 N 4,380.53 E -2459.35 1.42 6847.07 58.11 86.66 4,696.42 69.40 N 4,459.37 E -2500.94 0.23 6941.80 58.08 86.80 4,746.49 73.99 N 4,539.66 E -2543.24 0.13 7034.29 58.18 86.39 4,795.32 78.66 N 4,618.07 E -2584.39 0.39 7130.18 58.19 88.04 4,845.88 82.61 N 4,699.45 E -2627.82 1.46 7224.86 58.11 90.02 4,895.84 83.98 N 4,779.86 E -2672.83 1.78 7318.73 58.24 91.39 4,945.34 82.99 N 4,859.61 E -2719.37 1.25 7412.39 57.46 90.09 4,995.18 81.97 N 4,938.89 E -2765.69 1.44 7507.34 56.20 86.27 5,047.15 84.47 N 5,018.31 E -2809.19 3.62 7600.47 55.04 82.30 5,099.75 92.10 N 5,094.76 E -2846.79 3.73 7694.77 54.20 78.49 5,154.36 104.92 N 5,170.55 E -2879.77 3.41 7789.53 53.18 73.96 5,210.49 123.07 N 5,244.68 E -2907.42 4.00 7884.52 52.20 69.58 5,268.08 146.68 N 5,316.42 E -2929.22 3.81 7979.48 51.51 63.52 5,326.77 176.35 N 5,384.88 E -2944.18 5.07 8029.42 51.31 61.08 5,357.92 194.50 N 5,419.44 E -2949.14 3.84 8075.01 51.25 59.55 5,386.44 212.11 N 5,450.34 E -2952.44 2.62 8166.70 50.87 54.82 5,444.09 250.73 N 5,510.25 E -2955.16 4.03 8263.13 50.55 50.23 5,505.17 296.11 N 5,569.45 E -2951.95 3.70 8357.47 51.34 47.24 5,564.62 344.43 N 5,624.50 E -2943.95 2.60 8451.46 51.86 44.20 5,623.01 395.85 N 5,677.22 E -2932.06 2.59 8545.53 52.13 40.51 5,680.94 450.61 N 5,727.14 E -2915.84 3.10 8639.83 51.79 36.37 5,739.07 508.76 N 5,773.30 E -2894.68 3.48 8734.35 51.87 32.96 5,797.49 569.86 N 5,815.55 E -2868.87 2.84 8828.76 51.81 28.92 5,855.84 633.51 N 5,853.71 E -2838.61 3.37 8923.35 51.79 24.27 5,914.35 699.94 N 5,886.97 E -2803.27 3.86 9018.57 52.65 20.32 5,972.70 769.56 N 5,915.50 E -2762.61 3.40 9109.98 53.69 15.16 6,027.52 839.21 N 5,937.75 E -2718.32 4.66 9205.04 55.32 10.06 6,082.74 914.70 N 5,954.61 E -2666.15 4.69 9301.05 56.99 6.51 6,136.22 993.59 N 5,966.07 E -2608.10 3.53 INSITE V8.0.20 Page 2Job No:AK-XX-0901152148 Well Name:CD3-316B PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 9394.70 58.86 4.52 6,185.95 1,072.57 N 5,973.68 E -2547.77 2.69 9488.98 60.47 3.15 6,233.57 1,153.75 N 5,979.12 E -2484.39 2.12 9582.95 60.60 359.33 6,279.81 1,235.53 N 5,980.88 E -2418.41 3.54 9676.08 60.47 354.94 6,325.63 1,316.48 N 5,976.83 E -2349.78 4.11 9772.89 60.45 351.87 6,373.37 1,400.13 N 5,967.16 E -2275.71 2.76 9867.00 60.38 347.52 6,419.85 1,480.63 N 5,952.53 E -2201.38 4.02 9962.17 60.53 343.14 6,466.80 1,560.69 N 5,931.57 E -2123.77 4.01 10055.33 60.74 341.25 6,512.48 1,637.99 N 5,906.74 E -2046.21 1.78 10150.19 60.74 340.62 6,558.85 1,716.20 N 5,879.71 E -1966.64 0.58 10243.96 60.60 339.84 6,604.78 1,793.13 N 5,852.06 E -1887.76 0.74 10338.83 60.80 339.77 6,651.21 1,870.78 N 5,823.50 E -1807.77 0.22 10432.79 60.71 340.93 6,697.12 1,947.99 N 5,795.93 E -1728.71 1.08 10527.55 60.69 340.70 6,743.49 2,026.04 N 5,768.77 E -1649.20 0.21 10620.83 61.98 340.07 6,788.23 2,103.13 N 5,741.29 E -1570.29 1.50 10716.35 63.09 341.02 6,832.29 2,183.05 N 5,713.07 E -1488.64 1.46 10809.95 64.82 340.49 6,873.38 2,262.44 N 5,685.35 E -1407.71 1.92 10904.88 68.08 338.87 6,911.31 2,344.02 N 5,655.12 E -1323.54 3.77 10998.92 71.53 337.03 6,943.77 2,425.80 N 5,621.98 E -1237.54 4.10 11093.07 73.75 334.49 6,971.87 2,507.73 N 5,585.08 E -1149.27 3.49 11188.89 76.59 330.70 6,996.40 2,589.92 N 5,542.44 E -1057.48 4.84 11279.94 81.09 329.56 7,014.02 2,667.36 N 5,497.96 E -968.53 5.09 11376.88 84.67 330.16 7,026.03 2,750.53 N 5,449.67 E -872.70 3.74 11429.31 85.89 328.69 7,030.35 2,795.52 N 5,423.09 E -820.61 3.64 11496.00 87.19 327.65 7,034.37 2,852.08 N 5,387.98 E -754.14 2.49 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 18.96 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 11,496.00 feet is 6,096.28 feet along 62.11 degrees (Grid) INSITE V8.0.20 Page 3Job No:AK-XX-0901152148 Well Name:CD3-316B PB1 Survey Report 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 4Job No:AK-XX-0901152148 Well Name:CD3-316B PB1 Survey Report