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Home My WebLink About214-149MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-142 KUPARUK RIV UNIT 1D-142 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 1D-142 50-029-23529-00-00 214-149-0 W SPT 3766 2141490 1500 901 904 901 901 199 322 212 208 4YRTST P Austin McLeod 7/13/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-142 Inspection Date: Tubing OA Packer Depth 270 1810 1725 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220714084330 BBL Pumped:0.5 BBL Returned:0.4 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:17:09 -08'00' ! 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(!!4 &' ! & 9 =B=CD- = 8! 205 16625 6+0)5 ;#41< ))335 11625 6+0+5 @= !4 /25 1))65 * 12< 2#64;< +#34/< - ))105 3/)05 &-E -E*-!%?!& 8*!77**! !"#$"#%$& '&$&!%$!('!%$&& ) 3 % !1 ! ! ;" B"= !'*'& + ,-.) , =:* B'226)2 :E0032 6 +"$"#! = % ( *F % ;12B"% 62 2 2 0// ; ,> 12132+2:132+:G131/6. 2 ? #7 / 205 1))65 600 0 !4 & ? & 9! % % "*!@"? 2 " #B #B +*( ( (= ;6B"% 0)+ " H ,02+.1)3#)26/ "* & +)3#+)3)5:/6+1#/6++5:060#0;;5:0//1#0//+5 6/6#6/65:6/6#6/65:6/6+#6/6+5:6/;#6/65 2#;2; 24121 " 62( By Samantha Carlisle at 7:40 am, Oct 19, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.10.18 16:33:19 -08'00' SFD 10/20/2021 -00 VTL 01/24/2022 DSR-10/19/21 RBDMS HEW 10/19/2021 SFD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1D-142 smsmith Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Add Perf 10/11/2021 1D-142 appleha Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 29.5 Set Depth (ftKB) 109.5 Set Depth (TVD)… 109.5 Wt/Len (l… 94.00 Grade H-40 Top Thread Casing Description SURFACE - 10 3/4" x 11" @ 2573.47 x 10 3/4" @2576 OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 29.6 Set Depth (ftKB) 2,662.8 Set Depth (TVD)… 2,329.9 Wt/Len (l… 45.50 Grade L-80 Top Thread HYD 563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 26.1 Set Depth (ftKB) 6,655.4 Set Depth (TVD)… 3,796.5 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd 563 Casing Description LINER - 6" x 5" @ 6412.94 x 4 1/2" @6429.35 OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 6,361.0 Set Depth (ftKB) 12,230.0 Set Depth (TVD)… 3,797.1 Wt/Len (l… 12.60 Grade L-80 Top Thread HYD 563 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 6,361.0 3,766.5 82.57 PACKER BAKER ZXP LINER TOP PACKER 4.960 6,380.9 3,769.1 82.83 NIPPLE BAKER RS NIPPLE 4.900 6,383.8 3,769.4 82.87 HANGER BAKER DG FLEX-LOCK HANGER 4.860 6,393.6 3,770.6 82.99 SBE BAKER SEAL BORE EXTENTION 4.750 6,422.7 3,774.1 83.36 FLCV BAKER FLUID LOSS CONTROL VALVE W/ SLEEVE INTACT, ID: 3.32" 3.320 6,565.1 3,789.1 84.68 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 6,918.7 3,810.4 89.75 SCREEN RESINJECT ICD#8 4.000 7,285.1 3,807.6 90.50 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 7,680.9 3,814.2 88.63 SCREEN RESINJECT ICD#7 4.000 8,049.03,822.7 88.40SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 8,402.33,831.289.45 SCREEN RESINJECT ICD#6 4.000 8,812.93,833.5 89.66 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 9,169.13,836.690.40SCREEN RESINJECT ICD#5 4.000 9,579.7 3,822.4 92.23 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 9,931.63,812.7 90.94 SCREEN RESINJECT ICD#4 4.000 10,296.1 3,806.4 90.90 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 10,648.1 3,801.6 90.23 SCREEN RESINJECT ICD#3 4.000 11,057.1 3,792.7 91.39 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 11,406.5 3,787.4 90.44 SCREEN RESINJECT ICD#2 4.000 11,772.0 3,786.6 89.05 SWELL PACKER FREE CAP I FSC-11 OD SWELL PACKER 3.958 12,081.9 3,793.9 88.75 SCREEN RESINJECT ICD#1 4.000 12,158.5 3,795.688.75 BUSHING BAKER PACK OFF BUSHING3.890 12,221.23,796.988.83 WIV WELLBORE ISOLATION VALVE Tubing Strings Tubing Description Tubing – Production String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.0 Set Depth (ft… 6,406.0 Set Depth (TVD) (… 3,772.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.022.00.00 HANGER VETCO TUBING HANGER 3.980 520.9520.90.39 NIPPLE CAMCO DB NIPPLE W/ 3.875" NO GO PROFILE 3.875 4,541.7 3,182.4 64.87 NIPPLE CAMCO DB NIPPLE W/ 3.813" NO-GO PROFILE 3.813 6,365.3 3,767.1 82.63 LOCATOR GBH-22 LOCATOR (5' FROM LOCATED) 6,367.03,767.382.65 SEAL ASSY SPACER TUBES & SEALS3.870 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,651.0 7,656.03,813.4 3,813.5 WS D, 1D-14210/11/2021 6.0 APERF 2" GUN 6 SPF, 60*, 2006 PF HMX 6.4 GM .45" ENT HOLE, 4.5" PENETRATION 8,372.08,377.03,830.93,831.0 WS D, 1D-14210/11/2021 6.0 APERF 2" GUN 6 SPF, 60*, 2006 PF HMX 6.4 GM .45" ENT HOLE, 4.5" PENETRATION 9,139.0 9,144.0 3,836.7 3,836.7 WS D, 1D-142 10/11/2021 6.0 APERF 2" GUN 6 SPF, 60*, 2006 PF HMX 6.4 GM .45" ENT HOLE, 4.5" PENETRATION 9,882.09,887.03,813.63,813.5 WS D, 1D-14210/11/2021 6.0 APERF 2" GUN 6 SPF, 60*, 2006 PF HMX 6.4 GM .45" ENT HOLE, 4.5" PENETRATION 1D-142, 10/13/2021 12:59:33 PM Vertical schematic (actual) LINER - 6" x 5" @ 6412.94 x 4 1/2" @6429.35; 6,361.0- 12,230.0 APERF; 9,882.0-9,887.0 APERF; 9,139.0-9,144.0 APERF; 8,372.0-8,377.0 APERF; 7,651.0-7,656.0 INTERMEDIATE; 26.1-6,655.4 SEAL ASSY; 6,367.0 LOCATOR; 6,365.3 Intermediate Casing Cement; 3,860.0 ftKB NIPPLE; 4,541.7 GAS LIFT; 4,474.6 SURFACE - 10 3/4" x 11" @ 2573.47 x 10 3/4" @2576; 29.6- 2,662.8 Cement Squeeze; 2,480.0 ftKB Cement Squeeze; 2,458.0 ftKB NIPPLE; 520.9 CONDUCTOR; 29.5-109.5 HANGER; 22.0 KUP INJ KB-Grd (ft) 27.50 Rig Release Date 3/28/2015 1D-142 ... TD Act Btm (ftKB) 12,270.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292352900 Wellbore Status INJ Max Angle & MD Incl (°) 92.50 MD (ftKB) 9,496.69 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 2,458.0 2,708.0 2,235.4 2,351.2 Cement Squeeze Perform hesitation squeeze as follows 1: Pumped .5 bbls= 200 psi, shut in for 10 min= 25 psi 2: Pumped .4 bbls= 250 psi, shut in for 10 min= 25 psi 3: Pumped .4 bbls= 300 psi, shut in for 10 min= 75 psi 4: Pumped .5 bbls= 350 psi, shut in for 10 min= 100 psi 5: Pumped .7 bbls= 400 psi, shut in for 10 min= 125 psi 6: Pumped .6 bbls= 450 psi, shut in for 10 min= 175 psi 7: Pumped .8 bbls= 450 psi, shut in for 10 min= 250 psi 8: Pumped 1 bbls= 450 psi, shut in for 10 min= 300 psi 9: Pumped .5 bbls= 450 psi, shut in for 10 min= 325 psi 10: Pumped .5bbls= 450 psi, shut in for 10 min= 350 psi 11: Pumped .3 bbls= 450 psi, shut in for 10 min= 350 psi Bleed off was flat lined last 5 min's on#11 Squeezed a total of 6.2 bbls into the formation 4:45 hrs to 70 Bc, cement in place @ 12:20 hrs 3/5/2015 2,480.02,693.02,245.62,344.1Cement Squeeze Perform hesitation squeeze as follows: 1. Pumped .5 bbls=350 psi, shut in for 10 min=190 psi. 2. Pumped .3 bbls=400 psi, shut in for 10 min=250 psi. 3. Pumped .3 bbls=450 psi, shut in for 10 min=290 psi. 4. Pumped .2 bbls= 450 psi, shut in for 10 min=325 psi. 5. Pumped ..2 bbls=450 psi, shut in for 10 min=300 psi. Squeezed a total of 1.5 bbls into the formation. Cement in place @ 12:20 hrs 3/7/2015 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 4,474.6 3,153.4 64.14 CAMCO KBMG 1 GAS LIFT DV BK-50.000 0.06/11/2015 Notes: General & Safety End Date Annotation NOTE: 1D-142, 10/13/2021 12:59:38 PM Vertical schematic (actual) LINER - 6" x 5" @ 6412.94 x 4 1/2" @6429.35; 6,361.0- 12,230.0 APERF; 9,882.0-9,887.0 APERF; 9,139.0-9,144.0 APERF; 8,372.0-8,377.0 APERF; 7,651.0-7,656.0 INTERMEDIATE; 26.1-6,655.4 SEAL ASSY; 6,367.0 LOCATOR; 6,365.3 Intermediate Casing Cement; 3,860.0 ftKB NIPPLE; 4,541.7 GAS LIFT; 4,474.6 SURFACE - 10 3/4" x 11" @ 2573.47 x 10 3/4" @2576; 29.6- 2,662.8 Cement Squeeze; 2,480.0 ftKB Cement Squeeze; 2,458.0 ftKB NIPPLE; 520.9 CONDUCTOR; 29.5-109.5 HANGER; 22.0 KUP INJ 1D-142 ... WELLNAME WELLBORE Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for KRU well 1D-142 (PTD# 214-149) reporting on perforation operations. 1D-142 is a West Sak monobore D-Sand injector. The well was completed with 4-1/2” liner run with a series of Injection Control Devices (ICD’s) to help control fluid distribution throughout the lateral. Since it appeared the ICD’s were limiting injection, perforations were added across the liner between swell packers to allow for bypassing the flow restrictions. Perforations were added across an existing completed interval. Please contact Stefan Weingarth at (907) 265-6038 if you have any questions. Sincerely, Stefan Weingarth Sr. Wells Engineer ConocoPhillips Alaska, Inc. !" #$%##%##&%##$' ()% ** % +%&% !! " ) * #$#+$' #+$&#+$$! $* &$**)' (( ,,,,-'**,*)*!!'!' .,,, " & ! /0120345267 8/03452679::30; C:\Users\aebell\Desktop\October Data Drop 2021\CPA Data Drop 10122021\2021-10-11_15809_KRU_1D-142_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15809 KRU 1D-142 50-029-23529-00 Coil Flag 11-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM _________________________________________ Signaturururururururururrururuurururururruuruururuuurruurruuuruuuue Abby Bell 37' (6HW Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2141490 E-Set: 34720 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2141490 E-Set: 34719 I ®F ro •(y/; - . THE STATE Alaska Oil and Gas o�ALA c Conservation Commission +y �z-==iv= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Pete Fox Drillsite Production Engineer ConocoPhillips Alaska,Inc. o `ti P.O Box 100360 S�,k�t Anchorage,Alaska 99510 Re: Kuparuk River Field, Wesk Sak Oil Pool,KRU 1D-142 Permit to Drill Number: 214-149 Sundry Number: 318-043 Dear Mr. Fox: 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, 6.2S/ Hollis S. French Chair DATED this day of March,2018. L� h, €; 2f18 • • RECEIVED STATE OF ALASKA FEB 0 1 7038 ALASKA OIL AND GAS CONSERVATION COMMISSION ! 1 /! APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGGC 1.Type of Request: Abandon LJ Plug Perforations Li Fracture Stimulate H Repair Well H Operations shutdown U Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Conversion WIN to WAG❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 214-149 • 3.Address: Stratigraphic ❑ Service Q, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23529-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1D-142 ❑ Will planned perforations require a spacing exception? Yes ❑ No 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,202' 3,769' 12,202' 3,769' 2,158 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' Surface 2,633' 10.75" 2662' 2329' Intermediate 6,629' 7.625" 6655' 3797' Liner 5,869' 4.5" 12230' 3797' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ICD liner:6919'-12102'MD 3836'-3786' 4.5" L-80 6,406' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV,Baker SXP Liner Top Packer Packer:6,361'MD,6,765'MD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: 1-Mar-18 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG CI, GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Pete Fox Contact Name: Pete Fox Authorized Title: Drillsite Production Engineer Contact Email: Pete.B.Fox@cop.com Contact Phone: 907-265-6481 Authorized Signature: .P; Date: ll3 I /C4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: X18-- Oy3 Plug Integrity ❑ / BOP Test ❑ Mechanical Integrity Test Location ClearanceCI Other: DCG,/ 04 pr -55v r m o v?/:to a i vc T vi k e t afol . /<R / 2 6/ 1D-321 /0-3 4. Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No o' Subsequent Form Required: 16 —4 0 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 It lie � A0.7(5-40/ O G L R a�°"S ti� .r '128,1) ^ , Submit Form and _VJl Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 1D-142 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1D-142 (PTD# 214-149)from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1 D-142 was completed as an injector on 3/28/2015 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well supports existing producers 1C-135, 1 D- 141A, and 1D-146. The top of the Ugnu C sand was found at 4,376' MD/3,110' TVD The top of the Ugnu B sand was found at 4,883' MD/3,320'TVD The top of the Ugnu A sand was found at 5,263' MD/3,459'TVD The top of the West Sak D sand was found at 6,473' MD/3,790'TVD Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that, in addition to the offset producers (1C-135, 1D-141A, and 1D-146), there are three Kuparuk wells (1D-28, 1D-32, and 1D-34) and four West Sak wells (1C-184, 1C-190, 1D-141, and 1J- 122) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1D-142 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1D-142 is good. The injection tubing/casing annulus is isolated via a Baker ZXP liner top packer located at 6,361' MD (3,767'TVD). The last state-witnessed MITIA was performed on August 1, 2015 to 2050 psi. CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 61 sx of ASI, followed by an additional 287 sx ASI The 10-3/4" Surface casing was cemented with 453 bbl Class"G"followed by an additional 63 bbl Class "G" The 7-5/8" Intermediate casing was cemented with 153 bbl Class"G" cement. Conditions for approval (if applicable): Kuparuk wells 1D-28, 1D-32, and 1 D-34 will have OA pressure monitoring systems installed prior to initiation of gas injection at 1 D-142 in compliance with 20 AAC 25.402 (f). • = o -2 o o F^ M_ $� " N� saa`am� o M'c 0 a d an a < E,5,a L „ ra g „o L2oL agiHLL 000ogoO2aNn ,, ',,,'-'1 'n �Fm RE an �o Ho �O v0 Ln00z om 01 nO '-3 QVgo ao ucoacmFn ov oo ^ ` 2O ° ^�oErvo^ ao i ryoo d ` W- N - v o ai .v v" V ¢ l7- U7vQ °a¢ h UvQ or na =F_ l7nr ryQ « QuQ xou+ x in fa `41 :DLAT 2 22 22 0~« UuI �oNu3 ^moE � a `ryvuN` vauvoom � Ltl- aw -a - 1Oa17 aso u — vmN • xv74cxno. ^o -'c' ° t� uN J �vi .N u„0 c o O ^ `N° '^ o`u o mc° ryN Rm `oc v pOd^ 40O mr u C ? 0 N d Y^ y pry vN -op Oa H@1 dm Now w a -So 21-L.:-_' dd3 w ^ dsm - -SH .--- ,. .7,' 52, 2, @1 C y^I ”'as v av vvi uaa o Nn ° 4`,,'-',;," � v ,°,p bi Om ua ' 00-7-„ mc poo vroopaN os@J o . `27. m oc p =gc oG amCJ ~ o ".', = oN ow c xg . E -Mmjojm 0 cdctd - `c to^` jaoN mo R20 t M .� cN m c ° wco oco ° c ° y_ cc ° E d n° ° - Oc ccO n _v ''' ,2-. ga O` c n m tc? c ? n O 1t� n O O Y +Om6 0& O 0 hpO YmaOE - ^nm DO Emc .n c ?"Q OEg , fia :vnc u✓ Yd OE - cO wao ww u o tiuaE rT d ryww u 4-'7, ,,,i ,94• 1 . uun ,NdD O c uu o2 Ed ^ c CE N28 oaa 0 dN N O a ��Cu v Cd g > <di 3 V 3 O a 00 Fr,' , o Nr u u o N v u e e N Ny u t m NE— S N .'c N p Oo . a h 'O T n A: MhC tbn WM KYW M 'CO t.IS 11 41 ti- La gl F- 26 -96 G O N V 0 tO O 0 o a ^ vi N vi ^ ^ N o n ,y ,F2" . w a O m W W = Q O` O` y0 O` O° a 00 q 6 Q C° a < a m m N m m ti z N N m m3 o n o mm m cm o mm mooNo Q m o °or.vo 'o 2 n ry 0 o ry r ryry ryo rya + 1 • ADL025649 j ADL028242 West j Sak PA i I o c c� Qn 1D 04AL1 1D-04Adi , -04A iliCAL1-01 ADL028243 10-28L1 Ai0141111 la Z" " f 10-12 A -------------------_______L)-28 .. 1DLO2565O10-12L2) 1D-12L1 No1D-05 1D-41 1D-,1 1D-11L2 i4 N6 p 1 i4 I 1D-11L1 k , 1 I It,. i 1 __ 1D-37L2 10-37 1D-37L1 10-30 1D-30L1 r, ;;7,, Top of West Sak D in non-West Sak Wells 1D-32L1 Well Pad 1D-32 Well Trajectory ADL028248 Ni Open Interval(01) _ i Kuparuk .111101 Quarter Mile Radius 1 River Unit Other West Sak Well iiimilliiii Other West Sak Well WS Interval 1D-34L _,- Active 'Active non West Sak Well 1D-34 f N - ConocoPhillips - - - Inactive non-West Sak Well 1 Alaska j1 West Sak PAA Unit Boundary I 1 1 D-142 Sundry CPAI Leases 0 0.2 0.4 0.6 0.8 Injection Miles ARMSTRONG _ 10/18/2017 r A 0 KUP SVC • 1D-142 .1.- , a Conoc Phillips OP Gil Attributes Max Angle&MD TD AIMSKH If le Wellborn APYUWI FlId Item Wellbore Blatin nal(•) MD MKS) Act Bim MKS) ,-n.o„A„,rc 500292352900 WEST SAK SVC 92.50 9,496.69 12.270.0 ••• Comment 625 Ippm) Data Annotation End Sete KB.Grd(ll) --Rig Release Date 10.142,1260011 IQ'I'41 AM SSSV:NIPPLE Last WO: 27.50 3.282015 Wz1kN edemaie(sawn Annotation Depth(580) End Date Annotation LMI Mod By End Date ' RANGES;22.0--i.t... , 1111 I.sat Tag. Rey Reason NEW WELL smsmith 3/3072015 Casing Strings .��._W_.r...._........_._..�,rr.... '.......i-_..twing Deeenptlan O0 finj Ib(In) Top MKS) Set Depth MKS) 5N Depth(TVD)...Wt/Len n...Grad. Top Thread • :1 CONDUCTOR 20 12124 29,5 109.5 (09.5 94.00(1-40 Casing Description OD(In) ID(In) Top(tt(B) Set Depth(111(0) Set Depth(TVD).. WI/Len(I. Grade Top Thread • SURFACE-10 314"x 1r 103/4 9.950 29 6 2,662,8 2,329.8 45.50 I.80 HYD 563 `M^CONDUCTOR.28bf0s 5 "�It 2573.47 x 1 0 3 4" �I Casing CaNn9 Deecrlptnan OD(In) ID(In) Top(ttKB) SN Depth(ttKB) SN Depth(TVD)...Wt/Len 11...Grade Top Thread INTERMEDIATE 7 518 6.875 26.1 6,655.4 3.796.5 29.70 L-80 Hyd 563 N1PP.E;520 a I Caning Description OD(in) ID(In) Top(hKS) 5e1 Depth(hKB) Set Depth(TVD)_.WI/Len(I..Grade Top Thread LINER-6'x 5"@4 L7 3.956 6.361.0 121. 230.0 3,797.1 12.60 .80 HYD 563 641294 x4172' X7642935 ST• I . v Liner Details \I Nominal ID buitie:L-to 31Ya 11.* Top IRKS) Top(TVD)INKS) Top Inca(t) Item Dee Com (in) 21'3411 a 12 yr 02676.28.6- �' 6,361.0 3,766.5 82.57 PACKER BAKER ZXP LINER TOP PACKER 4,960 2 662 a 6,380.9 3.769.1 82.83 NIPPLE BAKER RS NIPPLE 4.900 GAS LIFT.4474.6 le '. : 6,383.8 3.769.4 82.87 HANGER BAKER DG FLEX-LOCK HANGER 4.860 6,393.6 3,770.6 82.99 SBE BAKER SEAL BORE EXTENTION 4.750 M.PPt E:Ops,a 6,422.7 3,774.1 83.36 FLCV BAKER FLUID LOSS CONTROL VALVE W/SLEEVE 3.320 r :• � � INTACT.ID.3.37 3. 6,565.1 3.789.1 84.68 SWELL FREE CAP I FSC-11 OU SWELL PACKER 958 PACKER LOCATOR 6 365 3 '..W. 6,918.7 3.810.4 89.75 SCREEN RESINJECTICDA8 4.000 SEAL ASS,,6.3670 CrI=) 1,285.1 3.807.6 90.50 SWELL FREE CAP IFSC-1100 SWELL PACKER 3.958 - PACKER 7,680.9 3.814.2 88.63 SCREEN RLSINJECTICDA7 4.010 8,049.0 3.822.7 88.40 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 PACKER 8,402.3 3,831.2 89.45 SCREEN RES8IJECTICD#6 ' 4.000 F 8,812.9 3,833.5 89.66 SWELL FREE CAP I FSC-1 I OD SWELL PACKER 3.958 PACKER 4. 9,169.1 3.836.6 90.40 SCREEN RESINJEC71CDA5 4.000 9,579.7 3.822.4 9223 SWELL FREE CAP IFSGII OD SWELL PACKER 3.958 f PACKER t,TEh MEL,ATS.2C i-16774 - 9,931.6 3612.7 90.97 SCREEN RFSINJECTICDA4 4.000 10,296-1 3.806.4 90.90 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 PACKER i 10,648.1 3.801.6 90.23 SCREEN 'RESINJFCT ICD713 4.000 1� 11,057.1 3,792.7 91.39 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 PACKER 11406.5 3.787.4 9044 SCREEN HLSINJECT ICUA2 4.000 11,772.0 3.786.6 89.05 SWELL FREE CAP IFSC-11 01)SWELL PACKER 3.!258 PACKER 1 12,081.9 3.793.9 88.75 SCREEN RESINJECT(COSI 4.000 lir 12,158.5 3.795.6 88.75 BUSHING BAKER PACK OFF BUSHING 3 890 iiiii 12,221.2 3.796.9 88.83 VW/ WELLBORE ISOLATION VALVE Tubing Strings Tubing Description String Me...ID(n) Top NUM) 561 Depth(k..,Bel Depth(TVD))...WI(16M) Grade Top Connection ITUBING 4 12 3.958 220 6,406.0 3,772.1 12.60 L-80 IBTM lir Completion Details H Top 151(81 Top(TVD)(ttKB) Top Ino/(1 Rem Des Com (I n) 22.0 22.0 0.00 HANGER VETCO TUBING HANGER 3.980 5209 4,541.7' 5209 0.39 NIPPLE CAMEO DB NIPPLE Wi 3.875'NO GO PROFILE - 3.875 3,182.4 64.81 NIPPLE CAMCO DB NIPPLE W13.813-NO-GO PROFILE WI 3813 RHC PLUG Nominal ID lit 6,365.3 3,787.1 82.63 LOCATOR GBI1.22 LOCATOR(5°FR OMLOCAIED) 1 I 6,367.0 3,767.3 82.65+SLAL ASSY SPACER TUBES&SEALS 3870 Cement Squeezes Top(TVD) tin(TVD) Top(ttKB) Bon 1189) ?MEN HIKER Dee Stan Date Com Q' 2.458.0 2,708.0 2.735.4 2.351.2 Cement Squeeze 3/512015 Pump cement squeeze job.SLR came online we 5 1 bbls of water.PT lines to 500'4000 psi.Pump 15 bbls of 12.5 ppg MudPush II,close annular.SEE batch up cemenL Open annular,pump 25 bbls of 15.8 ppg cemenL close annular.Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. IDisplace cement w/rig pumps @5 bpm.Displaced gplug w/31 bbls of mud. ! 2.4800 2,693 0' 2.245.6 2.344.1 Cement Squeeze'3.712015 Pump cement squeeze job.SI R came online wr 5 ' 1 2 bbls of water,PT lines to 500/4000 psi.Pump 15 bbls ol 12.5 ppg MudPush II.chx a annular.SL B belch up 'zs cemenL Open annular,pump 25 bbls of 15,8 ppg cement,close annular.Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. lit Displace cement Wl rig pumps i 5 bpm.Displaced plug w/31 bbls of mud. IMandrel Inserts St atl on Top QVC) Valve Lech Port Size TRO Run il K Top(#KB) IRKS) Make Modal 0011n) Len Type Type (In) (pe) Run Date Corn 1" 4,474.6 3,153.4 CAMCO K1IMG I GAS LIFT SOV 8K-5 0.000 0.0 3/26/2015 I Notes:General&Safety • I End Date Annotation ® ROIL' LINLR-B-x 5'8 M12:24.4 12'01428.35 6.361 C-, 1 1 32300 l V ! Q1 / T r ° c O > E in ` _ LLIrW 01 O L +� V. 3 r c7 ° v sro ° r' (.... V O N 1Z C� (p <1 v a a C 0C +-+ v O Y • - n rE co vc ..--,..--, 0 >. 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Q N w M N N M M N Z CU CO VI Y 00 'r- `"1 L rp c '-' co �n 'C v F �D Q E CO .c v CO 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,August 06,2015 Jim Regg J r P.I.Supervisor t Lam( l 7 t'�i S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-142 FROM: Chuck Scheve KUPARUK RIV UNIT 1D-142 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry —j NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-142 API Well Number 50-029-23529-00-00 Inspector Name: Chuck Scheve Permit Number: 214-149-0 Inspection Date: 8/1/2015 Insp Num: mitCS150802182909 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 1D-142 Type Inj W TVD 3766Tubing 940 944 938 ' 945 ---- -- --- PTD 2141490 - Type Test SPT(Test psi 1500 - IA 73 2020 ' 1953 - 1942- Interval INITAL P/F P '/ OA 185 226 ' 209 - 197 Notes: mite ;r sc Thursday,August 06,2015 Page 1 of 1 • a. 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 b direct inspection of the file. i 4- _I 14- q Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: 'ayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: 41:130 Date: 11 r as- /3 isl Al I, Project Proofing BY: Maria Date: `f c1,5IS /s/ flijf Scanning Preparation .5' x 30 = 5a + I L+ = TOTAL PAGES 1 V/ BY: C Maria Date: ) I a S/icy (Count does not include cover sheet) �n f Production Scanning /^w ' Stage 1 Page Count from Scanned File: ) t(/S(Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: MIS Date: ' 1 I A 5//S' /s/ 144 p 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: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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In N N N N N N N N (Ni d W ` \ I NN G0 t_ cre ` = a '0 G o N. to co 1 0 h `m 0 0 o c pCV -- u) Z .I' Q o 0 0 I Q C 0 c 0 0 U U U U U U U U `o 12 a, 7 - I J a, a) •°• U 0 O a v 0 o- N C7 a) 0 0 0 0 0 0 p 0 0 E o E 0 a m LU W LU W LU W W J 3 ? 0 a 0 0 o w • • o Co" O N 9 07 0 M N } o M N o) U L csi o i O o J s w ° z 1 1 I —) II z 1p V 19 z I - co , I CI Lf J Q C N O 5co 3 CL -I 0 J W = IX a 0 0 W 0 zzz z V 00 z _a ;3 3 I /JA i °. _ as 11 1O CL c 20 0 N m O a 0 M E II 1, v U o U w T o N a> a T H °° a I- C G z N mm co M Cl) p 0 I a Yg a> ICC o a G zo Cd U G I 1 Il I ca z am ooI co I O p >, m r i— I a I 3 Na) N F. ct G N 1 w V 2 Cd C Q Uu aCl a 2 0 ci d • auc 6--I q� eta Za 41 ¢-' o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday,July 13, 2015 9:39 PM T14Ii� To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Seitz, Brian; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D;Jenkins, Lubbie Allen; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators Subject: The LPP/SSV for well 1D-142 (PTD# 214-149)was returned to service Jim: The low pressure pilot (LPP) on well 1D-142 (PTD# 214-149) was returned to service on July 7, 2015 after the wellhead injection pressure stabilized above 500 psi. The pilot had been defeated on July 4th, 2015; and notification was sent in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocoph ill ips.com 1 IC,21k 14Z 127)1. 2./414-10 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> /get/Saturday, July 04, 2015 5:42 PM 1`-�` / To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Seitz, Brian; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D;Jenkins, Lubbie Allen; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators Subject: Defeated LPP/SSV on well 1D-142 (PTD# 214-149) Jim: The low pressure pilot(LPP) on well 1D-142 (PTD#214-149)was defeated on July 4, 2015 because the wells surface injection pressure is less than 500 psi.-/The well was drilled and completed on April 12, 2015 and placed in water injection - service on the morning of July 4, 2015. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." - Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 ! 21c�- t 25-7 72- WELL 2WELL LOG TRANSMITTAL DATA LOGGED 5 2�o✓2ota . To: Alaska Oil and Gas Conservation Comm. April 7, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ;:� ;M „ V ' Anchorage, Alaska 99501 MAY (. 1 201 RE: Radial Cement Bond Log : 1D-142 AOGCC Run Date: 3/25/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-142 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-23529-00 Radial Cement Bond Log 1 Color Log 50-029-23529-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: )119,4.4...., 6_60_4 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 8 2015 WELL COMPLETIONaOR RECOMPLETION REPORT AND a oCCla.Well Status: Oil ❑ ❑ SPLUG Ill Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q , WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service Q• Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: it March 27,2015 214-149/ . 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 •February 22,2015 50-029-23529-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 252'FNL,418'FEL, Sec.23,T11N,R10E,UM • March 19,2015 KRU 1D-142 - Top of Productive Horizon: 8. KB(ft above MSL): 94'RKB 15.Field/Pool(s): 1045'FSL, 1983'FEL,Sec. 13,T11N, R10E, UM GL(ft above MSL): 66.8'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 851'FSL,560'FEL, Sec.24,T11N, R10E, UM 12270'MD/3798'TVD West Sak Oil Pool, 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-560671 y- 5959414 Zone-4 112270'MD/3798'TVD ADL 25650 TPI: x-564374 y- 5960742 Zone-4 11,SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-565845 y- 5955281 Zone-4 nipple @ 521'MD/521'TVD 468 18.Directional Survey: Yes 0 Noll 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1677'MD/1646'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron, Density, Sonic, CBL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 30' 110' 30' 110' 42" 61 sx ASI,287 sx AS I 10.75" 45.5# L-80 30' 2662' 30' 2329' 13.5" 1300 sx Class G,213 sx Class G 7.625" 29.7# L-80 26' 6655' 26' 3797' 9.875" 671 sx Class G 4.5" 12.6# L-80 6361' 12230' 3767' 3797' 6.75" ICD liner 24.Open to production or injection? Yes a No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 6406' 6361'MD/3766'TVD ICD liner completion from 6919'-12102'MD 3810'-3794'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. rlittwor Was hydraulic fracturing used during completion? Yes❑ No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED II% 2480'-2708' 25 bbls 15.8 Class G E Nr'' 2480'-2693' 25 bbls 15.8 Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up I Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes Li No O If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 evised 10/2012 !I CONTINUED ON REVER �Dms3 4. APR 1 g 2015 Submit original only d 1,1 6- �rL /tel$/s ,�/� �t((�tjj 29. GEOLOGIC MARKERS(List all formations and marlincountered): 30. • FORMATION TESTS NAME MD TVD Well tested? El Yes El No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1650' 1625' needed,and submit detailed test information per 20 AAC 25.071. Ugnu C 4376' 3110' Ugnu B 4883' 3320' Ugnu A 5263' 3459' West Sak D 6473' 3780' N/A Formation at total depth: West Sak D I 31. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, cement reports,schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1 Contact: Email: David.L.Lee(u�conocophillips.com t c Printed Name G.L.Alvord Title: Alaska Drilling Manager /. oto. � �t 0,6 INSTRUCTIONS Signature Phone 265-6120 Date . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP SVC 10-142 ConocoPhillips A ell Attributes Max Angle&MD TD Alaska Inc Wellbore APULIWI Field Name Wellbore Status III 7) MD INKS) Act Elm(ftKB) (jm.44wtps 500292352900 WEST SAK SVC 92.50 9,496.69 12.270.0 ••• Comment 925(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10.142.428201510;1141 AM SSSV:NIPPLE Last WO: 27.50 3•282015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;22.0- •„.r„ Last Tag: Rev Reason:NEW WELL smsmith 3/30/2015 .. .+.a,. Casing Strings "'•'•'•"••""".....••^-"•_'^^"'•'•••••••-5y3y-^^- - - • CCT Llan OD(In) IDI Top908Set Depth MKS) Set Depth TVD Wt/Len I Grade Ta Thread CONDUCTOR 20 19.124 29.5 109.5 109.5 94.00 H-40 Casing Description OD(in) ID(in) Top(MOB) Set Depth(kKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread --- SURFACE-10 314"x 11- 103/4 9.950 29.6 2,662.8 2,329.9 45.50 L-80 HYD 563 'M^CONDUCTOR,28.AO95 '-@ 2573.47 x 10 3/4" I Ca ` C singmg Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth ITVD)..Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.1 6,655.4 3,796.5 29.70 L-60 Flyd 563 NIPPLE;520.8I Casing Description OD(in) ID(in) Top INKS) Set Depth(500) Set Depth(TVD)...WULen(I...Grade Top Thread LINER-6'x 5'@ 4 1'2 3.958 6.3610 12,230.0 3,797.1 12.60 L-80 HYD 563 6412.94 x 4 1/2" ill.I. . , 86429.35 `'I Liner Details I Nominal ID SURFACE-10 3K'x11"e Top(ftKB) Top(11/0)1108) Top Incl(') ham Das Com (in) it%2573.47x103/4'@2576:29.6-- 6,361.0 3,766.5 82.57 PACKER BAKER ZXP LINER TOP PACKER 4.960 26626 - 6,380.9 3.769.1 82.83 NIPPLE BAKER RS NIPPLE 4.900 GAS LIFT;4,474.6 I : 6,383.8 3,769.4 82.87 HANGER BAKER DG FLEX-LOCK HANGER 4.860 6,393.6 3,770.6 82.99 SBE BAKER SEAL BORE EXTENTION 4.750 • NIPPLE;4,541.7 f r 6,422.7 3,774.1 83.36 FLCV BAKER FLUID LOSS CONTROL VALVE W/SLEEVE 3320 INTACT,ID:3.32 6,565.1 3,789.1 84.68 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 • PACKER LOCATOR:6265.3 r6,918.7 3.810.4 8975 SCREEN RESINJECTICD#8 4.000 SEAL ASSY;6.367.0 , 1 7,285.1 3.807-6 90.50 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 I®II pPACKER .: sr4s 7,680.9 3.814-2 88.63 SCREEN RESINJECTICD#7 4.000 8,049.0 3,822.7 88.40 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 PACKER 8,402.3 3,831.2 89.45 SCREEN RESINJECTICD#6 4.000 8,812.9 3,833.5 89.66 SWELL FREE CAP I FSC-11 OD SWELL PACKER ' 3.958 PACKER `' ilW 9,169.1 3,836.6 90.40 SCREEN RESINJECTICD#5 4.000 9,579.7 3,822.4 92.23 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 • PACKER INTERMEDIATE;26.1.6,655.4 - 9,931.6 3,812.7 90.94 SCREEN RESINJECTICD44 4.000 10,296.1 3,806.4 90.90 SWELL FREE CAP IFSC-11 OD SWELL PACKER 3.958 PACKER 10,648.1 3,801-6 90.23 SCREEN RESINJECTICD#3 4.000 4 11,057.1 3,792.7 91.39 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 Lit PACKER 11,406.5 3,787.4 90.44 SCREEN RESINJECTICD#2 4.000 7 11,772.0 3,786.6 89.05 SWELL FREE CAP I FSC-11 OD SWELL PACKER 3.958 PACKER 12,081-9 3.793.9 88.75 SCREEN RESINJECTICD#1 4.000 1;1" 12,158.5 3.795.6 88.75 BUSHING BAKER PACK OFF BUSHING 3.890 12,221.2 3,796.9 88.83 WIV WELLBORE ISOLATION VALVE Tubing Strings Tubing Description String Ma...ID(In) Top(Itea) Set Depth(ft...Set Depth(TVD)(...WI(Iblft) Grade Top Connection TUBING 4 1/2 3.958 220 6,406.0 3,772.1 12.60 L-80 IBTM R' Completion Details Nominal ID Top(MB) Top(TVD)(kKB) Top Incl(') Item Des Com (in) 22.0 22.0 0.00 HANGER VETCO TUBING HANGER 3.980 520.9 520.9 0.39 NIPPLE CAMCO DB NIPPLE W/3.875"NO GO PROFILE 3.875 4,541.7 3,182.4 64.87 NIPPLE CAMCO DB NIPPLE W/3.813"NO-GO PROFILE W/ 3813 RHC PLUG Lir 6,365.3 3,767.1 82.63 LOCATOR GB)I-22 LOCATOR(5'FROM LOCATED) 7 6,3670 3,767.3 82.65 SEAL ASSY SPACER TUBES&SEALS 3.870 Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 2.458.0 2,708.0 2,235.4 2,351.2 Cement Squeeze 3/5/2015 Pump cement squeeze job.SLB came online wi 5 1 bbls of water,PT lines to 500/4000 psi.Pump 15 bbls of 12.5 ppg MudPush II,close annular.SLB batch up cement Open annular,pump 25 bbls of 15.8 ppg cement,close annular.Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement wl rig pumps @ 5 bpm.Displaced plug w/31 bbls of mud. 2480.0 2.693.0 2,245.6 2,344.1 Cement Squeeze 3/7)2015 Pump cement squeeze jab,SLB came online w/5 2 bbls of water,PT Tines to 500/4000 psi-Pump 15 bbls of 12.5 ppg MudPush It,Hasa annular.SLB batch up cement Open annular,pump 25 bbls of 15.8 ppg cement,close annular.Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement w/3g pumps @ 5 bps,Displaced plug w/31 bbls of mud. Mandrel Inserts St all on Top(TVD) Valve Latch Port Sae TRO Run N Top(ftKB) INKS) Make Model OD(In)' Sem Type Type (In) (psi) Run Date Com 1 4,474.6 3,153.4 CAMCO KBMG 1 GAS LIFT SOV BK-5 0.000 00 3/26/2015 Notes:General&Safety End Date Annotation NOTL• LII'_i'-0-x 5"Q 0412.94 x1 1,72"06429.35:6,361.0- 1 12,230.0-!1 l • • ConacaPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1D-142 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 2/21/2015 2:00:00 PM Rig Release: 3/28/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/19/2015 24 hr Summary Secure well and clean out cellar box. Lay down DP.Prep rig for move. Move and stage pipe sheds. Remove MPD equip.from cellar. Change out stand jump ram. Blow down steam sys., rig down inter-connects. Change over power to cold starts. Unplug rig. Clean up location. Move and stage rock washer. Connect truck to boiler room 00:00 02:00 2.00 0 0 MIRU MOVE RURD P PJSM-Continue to secure tree. Clean out cellar box 02:00 03:30 1.50 0 0 MIRU MOVE PULD P PJSM-Lay down 4" DP. Cleanout rock washer 03:30 07:30 4.00 0 0 MIRU MOVE RURD P PJSM-Prep rig for move. Prep MPD choke skid for removal Off hi-line power @ 07:00 hrs 07:30 08:30 1.00 0 0 MIRU MOVE RURD P Remove cellar doors in preparation to remove MPD choke skid. Move pipe shed heater. 08:30 09:30 1.00 0 0 MIRU MOVE RURD P Move pipesheds and stage on pad. 09:30 10:00 0.50 0 0 MIRU MOVE RURD P Remove MPD choke skid and RCD from cellar. 10:00 11:00 1.00 0 0 MIRU MOVE RURD P Install cellar doors. Blow down water system. 11:00 16:00 5.00 0 0 MIRU MOVE RURD P PJSM-Change out drillers side stand jump ram. Change out gear oil filter on top drive. 16:00 18:15 2.25 0 0 MIRU MOVE RURD P Prep rig for move. 18:15 21:15 3.00 0 0 MIRU MOVE RURD P PJSM-Blow down steam system. Rig down inter-connects. Swap over to cold start units. Unplug rig. Jack up boiler room 21:15 22:15 1.00 0 0 MIRU MOVE RURD P Clean up location 22:15 00:00 1.75 0 0 MIRU MOVE MOB P Pull rock washer from rig and stage on pad. Hook up truck to boiler room 02/20/2015 Pull off and stage boiler and motor rooms. Repair failed hyd hose on pump room jack. Pull off and stage pump room. Move support complexes to 1D pad. Change tire on sub. Pull sub off well. Move sub and pipe sheds to 1D pad. Move rock washer to 1D pad. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Pull off and stage on pad boiler and motor rooms. 01:00 03:00 2.00 0 0 MIRU MOVE MOB T Replace failed hydraulic hose on pump room jacking system 03:00 04:00 1.00 0 0 MIRU MOVE MOB P Pull off and stage on pad pit room. 04:00 10:00 6.00 0 0 MIRU MOVE MOB P Move support complexes to and stage at 1D pad. 10:00 14:00 4.00 0 0 MIRU MOVE MOB T Change out tire on sub moving system. 14:00 16:00 2.00 0 0 MIRU MOVE MOB P Pull sub off well 32-620. Clean up location. Page 1 of 35 Time Logs • • Date From To Dur S. Depth E. Death Phase Code >- Subcode T Comment 16:00 00:00 8.00 0 0 MIRU MOVE MOB P Move sub and pipe sheds to 1D pad. Load up and move rock waher to 1D pad. 02/21/2015 MIRU on 1D-142. Complete rig acceptance check list. Rig accepted @ 14:00 hrs, 2/21/15. Nipple up diverter. Change saver sub on top drive. Take on spud mud. Load pipe shed w/5" DP 00:00 04:00 4.00 0 0 MIRU MOVE MOB P Set matting boards. Spot and set support complexes 04:00 06:00 2.00 0 0 MIRU MOVE MOB P Spot and set rock waher and pipe sheds 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Work on rig acceptance check list. Hook up inter-connects,electrical, steam and water.Sim-ops Set diverter stand and diverter line with crane.Test gas alarms. Berm boiler room and rock washer. Set all stairs. 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Complete rig acceptance checklist. Finish berming boiler room and rock washer.Set pipe shed tioga air heater. Level pipe shed and cattle chute. Berm ROC. Accept rig @ 14:00 hrs 2/21/15 14:00 22:00 8.00 0 0 MIRU MOVE NUND P Nipple up diverter system. Sim-ops: Take on spud mud. Load pipeshed w/BHA and 5" DP. 22:00 23:00 1.00 0 0 MIRU MOVE RURD P Change out saver sub on top drive to 4 1/2"IF. 23:00 23:30 0.50 0 0 MIRU MOVE SFTY P Pre spud meeting 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Continue to change out saver sub on top drive to 4 1/2"IF. Sim-ops; Continue to load pipe shed w/5"DP and take on spud mud. 32/22/2015 Complete changing out saver sub. Dress iron roughneck for 5"DP. Load and strap 5"DP in pipe shed. PU 5" DP. Perform diverter test. PU remainder of DP. 45 stds total. PU 6 stds HWDP and 1 std of flex collars. MU BHA#1. Clean out conductor.Test surface lines to 4000 psi.DDrlg new hole f/107'MD t/152' MD. Trouble shoot gas alarm sys. 00:00 02:30 2.50 0 0 MIRU MOVE RURD P PJSM. Change out saver sub. Load pipeshed with 5"DP. 02:30 03:30 1.00 0 0 MIRU MOVE RURD P Change out iron roughneck dies, mud bucket rubber inserts, SIMOPS: strap pipe in pipeshed, rig up mouse hole. 03:30 06:30 3.00 0 0 MIRU MOVE PULD P PJSM. Pick up 5"drill pipe from pipeshed and rack back in derrick. 06:30 07:30 1.00 0 0 MIRU MOVE BOPE P Perform diverter test. 16"vent line lenght=108'. Distance from closest ignition 89'.Annular closing time 19 secs. Knife valve opening time 11 secs. Koomey test: System pressure=2900psi, pressure after closure=1800 psi.200 psi attained in 33 secs. Full recharge= 160 secs. 5 bottle average=2000 psi.AOGCC waived witness of test. Page 2 of 35 Time Logs 10 410 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 10:00 2.50 0 0 MIRU MOVE PULD P Continue to pick up drill pipe and rack back in the derrick. 10:00 11:00 1.00 0 0 MIRU MOVE SFTY P Pre Spud meeting,and safety meeting with Drill Site Operator. 11:00 11:15 0.25 0 0 MIRU MOVE PULD P Continue to pick up drill pipe from pipeshed and rack back. 11:15 13:30 2.25 0 0 MIRU MOVE PULD P Strap HWDP, pick up and rack back 17 joints of HWDP and mechanical jars. PU and stand back flex collars 13:30 14:30 1.00 0 0 MIRU MOVE BHAH P Clear rig floor.Mobilize BHA tools to rig floor. 14:30 16:15 1.75 0 93 MIRU MOVE BHAH P MU clean out BHA as per SLB. Tag ice plug @93' MD. 16:15 16:30 0.25 93 107 MIRU MOVE DRLG P Flood conductor. Ream down to 107' MD.400 gpm, 150 psi,40 rpm, 1K tq, 50% FO. 16:30 19:15 2.75 107 107 MIRU MOVE SEQP P LD one jt. HWDP. RU to test surface equip. and kelly hose to 4000 psi/5 min. RD test equip. MU one jt. HWDP. RIH and tag up at 107'MD 19:15 21:00 1.75 107 152 SURFA( DRILL DDRL P DDrlg f/107' MD-t/152'MD, 152' TVD.ART=1.32,AST=0 Bit hrs=1.32. PU=52K, SO=52K, Rot=52K Tq on=1 K, Tq off= 1K, FO=60-96%,WOB=5-8K, 50 rpm, 450 gpm, 250 psi, 21:00 22:00 1.00 152 152 SURFA( DRILL SVRG P Service rig. 22:00 00:00 2.00 152 40 SURFA( DRILL RGRP T Pump OOH to 40'MD.450 gpm. Trouble shoot and repair Sierra Gas Alarm sys. Sim-ops; Test kelly hose to 5000 psi/10 min. 32/23/2015 Trouble shoot Sierra Gas Alarm sys. DDrIg f/152' MD t/221' MD.Pump OOH into conductor. Service rig. Trouble shoot Sierra Gas Alarm sys. 00:00 02:30 2.50 40 40 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Work on MP2's. Load pipe shed with 10 3/4"casing. 02:30 03:30 1.00 40 100 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Rig down circ. lines. RIH to 132'MD. Stage pumps up to 400 gpm. CBU X2. Lay down 1 jt. HWDP. Rig up circ. lines. 03:30 12:00 8.50 100 100 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Work on MP2's. Prep 10 3/4"casing. 12:00 18:00 6.00 100 100 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Work on MP2's.Adjust kelly hose. 18:00 18:30 0.50 100 152 SURFA( DRILL RGRP T Blow down and rig down circ. lines. PU one jt HWDP from pipe shed. Make connection tag btm. 18:30 20:30 2.00 152 221 SURFA( DRILL DDRL P DDrlg f/152' MD-t/221' MD,221' TVD.ART=1.81 ,AST=0 Bit hrs=3.13. PU=45K, S0=47K, Rot=45K Tq on=1.5K,Tq off= 1K, FO=58%,WOB=5-10K, 50 rpm, 450 gpm, 300 psi, 20:30 20:45 0.25 221 107 SURFA( DRILL PMPO P Pump OOH f/221'MD t/107'MD Page 3 of 35 Time Logs 110 410 Date From To Dur S. Depth E.-Depth Phase Code Subcode T Comment 20:45 21:45 1.00 107 107 SURFA( DRILL SVRG P Service Rig 21:45 00:00 2.25 107 100 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Lay down single HWDP. Blow down top drive. MU circ sub and lines. 32/24/2015 Trouble shoot Sierra Gas Alarm sys. MU BHA#2. Continue to trouble shoot Sierra Gas Alarms. 00:00 03:30 3.50 100 100 SURFA( DRILL RGRP T Trouble shoot and test Sierra Gas Alarm sys. 03:30 03:45 0.25 100 35 SURFA( DRILL TRIP P PU single HWDP. POOH one stand 03:45 05:00 1.25 35 90 SURFA( DRILL BHAH P MU BHA#2. Inspect bit. Orient motor to GWD and MWD. 05:00 12:00 7.00 100 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. 12:00 18:00 6.00 90 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Sim-ops Clean rig, shovel snow off pits and power complexes. Clean out rock washer and boiler complex spill containment. Rig on Hi-Line power @ 16:15 hrs. 18:00 00:00 6.00 90 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Sim-ops;Adjust drag chain, organize new storage cabinets, paint low pressure lines in pump room. Perform mud pump MP2's. 02/25/2015 Repair Sierra Gas Alarm sys. MU BHA#2. Flush gravel from circ. sys.Wash and ream to 210'MD. Perform gyro surveys at 119'MD and 151'MD. 00:00 06:00 6.00 90 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Sim-ops; Paint yolk in cellar. Cut and weld fitting on hot well 06:00 12:00 6.00 90 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Sim-ops;Work on 3512 gen sets fuel injectors. Paint on rig floor. 12:00 14:00 2.00 90 90 SURFA( DRILL RGRP T Trouble shoot Sierra Gas Alarm sys. Attempt to test alarm sys. under a load. Prime mud pumps and pump down drill string.. Drill string pressured up and held pressure. 14:00 18:45 4.75 90 60 SURFA( DRILL RGRP T Calibrate and test gas alarm sys. Sim-ops;Pull BHA OOH and drain motor.Break X-O above MWD and inspect. MWD packed off with fine gravel. LD MWD.Attempt to pump through gyro. Pumps would not prime. Disassemble and clean gravel from mud pump fluid ends. Clean pit #5. 18:45 19:00 0.25 60 60 SURFA( DRILL CIRC P Prime both mud pumps and clean suction screens. Gravel in both pots. 19:00 20:30 1.50 60 95 SURFA( DRILL BHAH P Make up BHA#2 20:30 21:45 1.25 95 95 SURFA( DRILL OTHR T Flush mud lines through bleeder line and cmt. line and clean suction screen pots until clear of gravel. 21:45 22:15 0.50 95 95 SURFA( DRILL SVRG P Service riig Page 4 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 95 210 SURFA( DRILL REAM P Wash and ream f/151' MD t/210' MD. Take Gyro surveys at 119'MD and 151'MD. 32/26/2015 DDrIg to 390'MD. POOH. MU BHA#3. Log hole f/230' MD t/385'MD. DDrlg f/390'MD t/1445' MD. 1434'TVD 00:00 00:30 0.50 210 210 SURFA( DRILL REAM P Cont to wash and ream down to 221' MD, pump©400 gpm=475 psi, ROT ©45 rpm w/1K Tq.WOB 3-8K. 00:30 04:45 4.25 210 390 SURFA( DRILL DDRL P Drill ahead f/210'MD to 390'MD, TVD=390'.ART=3.87,AST=0, ADT=3.87. P/U=60K, S/O=60K, ROT=60K. Pump @ 500 gpm=500 psi, Rot @ 50 rpm's= 1.5K Tq on, 1K Tq off.WOB=5-10K. 04:45 05:00 0.25 390 390 SURFA( DRILL OWFF P OWFF,static. 05:00 06:15 1.25 390 116 SURFA( DRILL PMPO P POOH w/pump f/390' MD to 116' MD, pump @ 400 gpm=300 psi, P/U=60K, S/0=60K. 06:15 06:45 0.50 116 116 SURFA( DRILL SVRG P Service rig,grease draworks,blocks and top drive. 06:45 08:00 1.25 116 116 SURFA( DRILL BHAH P Hold PJSM, C/O connection in ARC tool, P/U ADN and load nuclear sources. 08:00 08:15 0.25 116 241 SURFA( DRILL TRIP P RIH f/116'MD t/241'MD. P/U=60K, S/O-60K. 08:15 09:30 1.25 230 385 SURFA( DRILL DLOG P Log hole f/230' MD to 385'MD w/ ADN tool. Pump @ 500 gpm=500 psi, Rot @ 40 rpm's w/1K Tq. 09:30 12:00 2.50 385 513 SURFA( DRILL DDRL P Drill ahead f/390'MD to 513'MD, TVD=513'.ART= 1.76,AST=0, ADT= 1.76. Bit Hrs=8.76,Jar Hrs= 72.68 P/U=67K, S/0=65K, ROT=65K. Pump @ 500 gpm=600 psi, Rot @ 45 rpm's=3.0K Tq on, 1K Tq off.WOB=15-25K. 12:00 18:00 6.00 513 976 SURFA( DRILL DDRL P DDrIg f/513'MD t/976'MD,TVD= 976'.ART=2.79,AST=1.82,ADT= 4.61. Bit Hrs= 13.37,Jar Hrs=77.29 P/U=85K, S/O=83K, ROT=85K. Pump @ 484 gpm=650 psi, Rot @ 50 rpm's=4-7K Tq on, 1K Tq off. WOB=30-35K. 18:00 00:00 6.00 976 1,445 SURFA( DRILL DDRL P DDrlg f/976' MD t/1445' MD,TVD= 1434'.ART=2.03,AST=3.17,ADT= 5.20. Bit Hrs= 18.57, Jar Hrs=81.57 P/U=88K, S/O=86K, ROT=88K. Pump @ 493 gpm=700 psi, Rot @ 50 rpm's=5-6K Tq on, 1.5K Tq off. WOB=30-35K. 02/27/2015 Drill 13 1/2"surface hole to TD @ 2673'MD. 2335'TVD. CBU x 2. Monitor well. BROOH f/2673'MD t/886" MD. Monitor well. BROOH t/600' MD. Lay down BHA#3. Page 5 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 1,445 1,925 SURFA( DRILL DDRL P DDrIg f/1445' MD t/1925' MD,TVD= 1868'.ART=1.83,AST=3.23,ADT= 5.06. Bit Hrs=23.63, Jar Hrs=86.63 P/U= 100K, 5/0=95K, ROT=96K. Pump @ 500 gpm=900 psi, Rot @ 50 rpm's=4-7K Tq on,2-4K Tq off. WOB=25-35K. 06:00 12:00 6.00 1,925 2,357 SURFA( DRILL DDRL P DDrIg f/1925' MD t/2357' MD,TVD= 2181'.ART=.55,AST=3.48,ADT= 4.03. Bit Hrs=27.66, Jar Hrs=91.58 P/U= 101K, S/O=89K, ROT=99K. Pump @ 700 gpm=1575 psi, Rot @ 50 rpm's=6-7K Tq on,2-6K Tq off. WOB=20-25K. 12:00 15:30 3.50 2,357 2,673 SURFA( DRILL DDRL P DDrlg f/2357' MD t/2673'MD,TVD= 2335'.ART=1.28,AST=1.02,ADT= 2.30. Bit Hrs=29.96, Jar Hrs=93.88 P/U= 106K, S/0=80K, ROT=94K. Pump©657 gpm=1400 psi, Rot @ 50 rpm's=5-8K Tq on, 2-8K Tq off. WOB=5K. 15:30 16:30 1.00 2,673 2,673 SURFA( CASING CIRC P CBU x 2. 750 gpm, 1700 psi, 50 rpm, 5K tq 16:30 16:45 0.25 2,673 2,673 SURFA( CASING OWFF P Monitor well. Static. 16:45 21:45 5.00 2,673 886 SURFA( CASING BKRM P BROOH f/2673'MD t/886'MD. 650 gpm. ICP= 1400 psi. FCP=1000 psi. 50 rpm, 3-10K tq 21:45 22:00 0.25 886 886 SURFA( CASINGOWFF P Monitor well. Static 22:00 23:00 1.00 886 600 SURFA( CASING BKRM P BROOH f/886'MD t/600' MD. 650 gpm, 1000 psi, 50 rpm. Blow down TD. Line up trip tank. 23:00 00:00 1.00 600 144 SURFA( CASING BHAH P Lay down two jts. HWDP and jars. Stand back flex collars. Calc disp= 23.78 bbls.Act disp=31.35 02/28/2015 L/D BHA. R/U to run 10-3/4"casing and make dummy run. RIH w/10-3.4"to 1534'MD, CBU and Cont RIH w/ 10-3/4"casing to 2662'MD. M/U hanger and CBU. Phase III,WOW 00:00 00:30 0.50 144 144 SURFA( CASING BHAH P PJSM, Unload nuclear sources as per SLB rep. 00:30 02:30 2.00 144 0 SURFA( CASING BHAH P Cont.to L/D BHA as per SLB rep. Actual displacement=9.01 bbls, Calculated displacement=5.49 bbls. 02:30 03:30 1.00 0 0 SURFA( CASING BHAH P Clean and clear rig floor and remove SLB tools. 03:30 04:15 0.75 0 0 SURFA( CASING RURD P PJSM, M/U 10-3/4"Vetco hanger and perform dummy run as per Vetco rep. 04:15 06:45 2.50 0 0 SURFA( CASING RURD P PJSM, R/U GBR Volant casing running tool w/Baker swivel and install 6'GBR bail extensions. R/U other casing running equipment. 06:45 07:45 1.00 0 129 SURFA( CASING PUTB P PJSM, M/U 10-3/4"L-80 H563 shoe track, fill casing and test floats, good. Page6of35 0 Time Logs S' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 11:15 3.50 129 1,534 SURFA( CASING PUTB P RIH w/10-3/4"L-80,45#H563 casing f/129'MD to 1534' MD. Observed hole fill becoming off, no loss in flow out%. Decision made to CBU.Actual displacement= 19.9 bbls, Calculated displacement= 28.16 bbls. 11:15 12:30 1.25 1,534 1,534 SURFA( CASING CIRC P Circulate and condition mud, stage pumps up f/1 bpm to 5 bpm= 190psi,40%flow out, no losses observed. P/U=87K, S/O=83K. 12:30 16:30 4.00 1,534 2,662 SURFA( CASING PUTB P RIH w/10-3/4"L-80,45#H563 casing f/1534'MD to 2662' MD. M/U Vetco casing hanger and R/U cementing hose. P/U=136K, S/O= 100K. 16:30 17:00 0.50 2,662 2,662 SURFA( CEMEN-CIRC P Circulate and condition mud for cement job. Begin thinning mud f/ cement job.At 17:00 hours weather went to Phase III. 17:00 00:00 7.00 2,662 2,662 SURFA( CEMEN-WAIT T Circulate hole clean and bring mud properties back to specs. Stage pumps up f/2 bpm=200 psi to 6 bpm=400 psi. Slow pumps to 2 bpm= 100 psi, reciprocating pipe 20' while waiting on Phase III weather. 03/01/2015 WOW, 00:00 12:00 12.00 2,662 2,662 SURFA( CEMEN'WAIT T Circ @ 2 bpm= 100 psi, reciprocating pipe 20'while waiting on Phase III weather. 12:00 00:00 12.00 2,662 2,662 SURFA( CEMEN'WAIT T Circ @ 2 bpm= 100 psi, reciprocating pipe 20'while waiting on Phase III weather. 33/02/2015 WOW, Circ. and cond. mud for cement job. Perform surface cement job. Lay down landing jt. Flush diverter and riser. ND diverter. Remove diverter equip.from cellar. Prep wellhead for installation. 00:00 06:00 6.00 2,662 2,662 SURFA( CEMEN-WAIT T Circ @ 2 bpm= 100 psi, reciprocating pipe 20'while waiting on Phase III weather. 06:00 10:00 4.00 2,662 2,662 SURFA( CEMEN-CIRC P Stage pumps up f/2bpm=125 psi, 21%flow to 6 bpm=300 psi, 35% flow. Condition mud for cement job. SIMOPS,stage Vac trucks and Super suckers into position and prep for cement job. Page 7of35 Time Logs • Date From To Dur S. Depth E. Depth Phase 'Code Subcode T Comment 10:00 13:30 3.50 2,662 2,662 SURFA( CEMEN-CMNT P PJSM, Batch up as per SLB. Pump 5 bbls of CW100, pressure test lines to 1500/4000 psi. Cont pumping 45 bbls of CW100 followed by 50 bbls of 10.5 ppg Mud Push II. Shut down, drop bottom plug, SLB pumped 453 bbls of 11.0 ppg LiteCRETE and 63 bbls of 12.0 ppg Tail LiteCRETE cement. Shut down and drop top plug, kick out plug with 10 bbls of fresh water. Swap over to rig, displace cement with 9.5 ppg mud @ 7 bpm=650 psi. Slowed pumps to 3 bpm, bumped plug©2354 stokes, pressure up to 500 psi over FCP=1000 psi. Hold for 5 min, bleed off and check floats, good. Observed good circulation while performing cement job. 70 bbls of Cement returned to surface. 13:30 14:00 0.50 0 0 SURFA( CEMEN WWWH P Flush diverter and riser with black water wash. 14:00 16:15 2.25 0 0 SURFA( CEMEN-RURD P Blow down and rig down casing and cmt.tools and equip. Lay down landing jt. Install stabbing guide on top drive. Remove csg.tools from rig floor. 16:15 00:00 7.75 0 0 SURFA( CEMEN NUND P Remove riser. Rinse out diverter. Nipple down diverter. Remove equip. from cellar. Clear snow drifts from behind cellar. Prep wellhead for installation. 03/03/2015 N/U BOPE and Dutch riser. Test BOPE(good test)R/D test equipment. Install ware ring and rack back 3 stands of 5" DP. P/U 9 7/8"BHA#5 and single in the hole to 2098'. 00:00 01:00 1.00 0 0 SURFA(WHDBO NUND P PJSM, Mobilize wellhead equipment and Dutch riser to cellar. 01:00 05:00 4.00 0 0 SURFA(WHDBO NUND P Orient wellhead as per Vetco/DSO. N/U wellhead and test seals on wellhead to 2000psi for 10 min as per Vetco rep. 05:00 07:30 2.50 0 0 SURFA( WHDBO NUND P N/U BOPE and install Dutch riser. 07:30 11:00 3.50 0 0 SURFA( WHDBO RURD P Rig up to test BOPE. Page 8 of 35 Time Logs Date From - To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 14:30 3.50 0 0 SURFA( WHDBO BOPE P Test BOPE w/5"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9, and 11. Test#3: Lower IBOP, CV 5,8 and 10. Test #4: Dart„ CV 4,6 and 7. Test#5: Floor valve and CV 2. Test#6: HCR choke,4"kill line Demco and extra floor valve. Test#7: Manual choke valve and HCR kill. Test#8:Annular preventer. Test#9: Lower pipe rams. Test#10: Blind rams and CV 3. Accumulator test:system pressure= 3000 psi,After closing= 1750 psi, 200 psi attained after 47 sec, full pressure attained after 180 sec, Five bottle nitrogen avg=2050 psi. The BOP test was witnessed by AOGCC rep Lou Grimaldi. 14:30 16:00 1.50 0 0 SURFA( WHDBO RURD P Rig down BOP test equipment. 16:00 16:30 0.50 0 0 SURFA(WHDBO SVRG P Service rig. 16:30 19:30 3.00 0 0 SURFA( CEMEN-RURD T Trouble installing ware ring.Ware ring was out of round and would not seat in VETCO well head. Called Tool house for another ware ring, it also was out of round. Reshaped ware ring with a shop hammer and installed it with the weight of the bails. 19:30 20:30 1.00 0 0 SURFA( CEMEN-PULD P PU and rack back 3 stands of 5"DP. 20:30 22:30 2.00 0 701 SURFA(WHDBO BHAH P PU 9.875"BHA#5 22:30 23:00 0.50 701 1,449 SURFA( CEMEN-PULD P Single in the hole f/701't/1449'. 23:00 23:30 0.50 1,449 1,449 SURFA( CEMEN-DHEQ P Shallow test MWD tools @ 500 gpm /825 psi/1449' 23:30 00:00 0.50 1,449 2,098 SURFA( CEMEN-PULD P Continue to single in the hole f/ 1449't/2098'. PUW 95K/SOW 82K. 03/04/2015 Run in the hole to 2499'and wash and ream to 2571'.Test 10 3/4"casing to 3000 psi(good test). Perform FIT/LOT/Leak off at 210 psi. POOH to P/U 3 1/2"tubing to perform squeeze. 00:00 00:30 0.50 2,098 2,499 SURFA( CEMEN'PULD P Cont.to RIH picking up 5"DP f/ 2098'MD to 2499'MD. 00:30 01:00 0.50 2,499 2,571 SURFA( CEMEN"COCF P Wash and ream f/2499'MD to 2571' MD(Top of FC) Pump @ 200 gpm=200 psi,30%flow, Rot @ 40 rpm's w/1-7K Tq. P/U= 100K, 5/0=82K. 01:00 02:00 1.00 2,571 2,571 SURFA(CEMEN"CIRC P Circulate hole clean @ 250 gpm=300 psi, 36%flow. 02:00 02:15 0.25 2,571 2,499 SURFA( CEMEN-TRIP P Stand back one stand to 2499'MD. 02:15 03:00 0.75 2,499 2,499 SURFA( CEMEN'RURD P PJSM, Rig up to test 10-3/4"casing. Page9of35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:30 0.50 2,499 2,499 SURFA( CEMEN-PRTS P Pressure test 10-3/4" L-80 surface casing to 3000 psi for 30 minutes on chart,good. 03:30 03:45 0.25 2,499 2,499 SURFA( CEMEN-RURD P Rig down testing equipment. 03:45 06:00 2.25 2,499 2,499 SURFA( CEMEN-WAIT T Weather Phase II,circulate @ 2 bpm= 100 psi,24%flow. Mobilize Supersuckers to location,convoy due to bad weather. 06:00 11:30 5.50 2,499 2,673 SURFA( CEMEN-DRLG P Drill of FC @ 2575'MD, shoe track, FS @ 2662'MD and rat hole to 2673' MD, pump @ 480 gpm=900 psi,49% flow,60 rpm's w/2-5K Tq. 11:30 12:00 0.50 2,673 2,693 SURFA( CEMEN DDRL P Drill 20'of new hole f/2673' MD to 2693'MD. 2344'TVD,ADT=.14, Bit hrs=.14,Jar hrs=50.12, Pump @ 600 gpm= 1300 psi, ROT @ 80 rpm's w/1-10K Tq, 50%flow, ECD= 9.81ppg EWM, P/U= 100K, 5/0= 77K, ROT=88K. Observed 35-40 bph losses @—2686'MD-2893'MD 12:00 13:00 1.00 2,693 2,693 SURFA( CEMEN CIRC P Circulate hole clean and condition mud for LOT. Pump©600 gpm=1300 psi, 53%flow out, loosing 35-40 bph, ECD=9.80 ppg. Reduce pumps to 450 gpm=750 psi,47%flow out no losses. 13:00 15:00 2.00 2,693 2,693 SURFA( CEMEN FIT P Perform FIT/LOT at 2693'/Leak off at 190 psi. Perform second LOT/ Leak off at 210 psi. 15:00 17:00 2.00 2,693 2,693 SURFA( CEMEN-WAIT T Consult with drilling engineer for plan forward. Plan forward: Drill 15'to 2708', POOH and lay down the 9 7/8"BHA. P/U 900'of 3 1/2"EUE tubing and run back in the hole. Objective: set a 250'balance cement plug from 2708'to 2548'and squeeze to improve FIT(minimum 12.0-12.5 ppg). 17:00 17:30 0.50 2,693 2,708 SURFA( CEMEN-DRLG T Drill 15'of hole to 2708'.WOB 2-6K/ RPM 80/GPM 450/PSI 800. 17:30 18:00 0.50 2,708 2,708 SURFA( CEMEN-CIRC T Circulate B/U at 480 gpm/800 psi/ 9.5 ppg mud wt. 18:00 18:30 0.50 2,708 2,708 SURFA( CEMEN OWFF T Monitor the well for 30 minutes (static). 18:30 20:00 1.50 2,708 2,499 SURFA( CEMEN TRIP T POOH from 2708'to 2499'. Encountered obstruction, most likely rubber from the float shoe or float collar. 20:00 21:30 1.50 2,499 771 SURFA( CEMEN-TRIPT Continue POOH to HWDP at 771'. 21:30 22:00 0.50 771 771 SURFA( CEMEN OWFF T Monitor the well for 30 minutes (slight fluid loss, .5 bbls). 22:00 00:00 2.00 771 0 SURFA( CEMEN'BHAH T L/D 9 7/8"BHA#5. 03/05/2015 P/U 3 1/2"tubing cement string. Run tubing in the hole with 5" DP to 2313'. Standby and wait for SLB cementers. RIH to 2705'and pump cement squeeze job. POOH and perform hesitation squeeze. POOH and L/D tubing cement string. P/U 9 7/8" BHA#6 and RIH to 2313'. Page 10 of 35 Time Logs • • Date From To. Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 SURFA( CEMEN-BHAH T Clean and clear rig floor. 00:30 01:15 0.75 0 0 SURFA( CEMEN-PULD T PJSM, Mobilize casing equpiment to rig floor. Rig up to run 3-1/2" EUE cement stinger. 01:15 01:30 0.25 0 0 SURFA( CEMEN-SFTY T Hold PJSM on picking up and RIH w/ 3-1/2"EUE tbg. 01:30 02:45 1.25 0 937 SURFA( CEMEN PUTB T RIH picking up 3-1/2" EUE tbg w/ mile shoe to 937' MD 02:45 03:00 0.25 937 937 SURFA( CEMEN-RURD T R/D casing equipment and C/O handling tools. 03:00 04:00 1.00 937 2,613 SURFA( CEMEN-TRIPT RIH w/5"DP from 937'MD to 2613' MD.Actual displacement= 14.45 bbls, Calculated displacement= 17.16 bbls. 04:00 08:45 4.75 2,613 2,613 SURFA( CEMEN WAIT T Wait on SLB cement crew. SIMOPS„work on MP2's and service rig. 08:45 09:00 0.25 2,613 2,705 SURFA( CEMEN-TRIPT RIH f/2613' MD to 2705' MD. P/U= 70K, S/O=68K. 09:00 10:30 1.50 2,705 2,705 SURFA( CEMEN-CIRCT Circulate and condition mud for cement job, stage pumps up f/2 bpm to 6 bpm=350 psi, 37%flow. SIMOPS, rig up SLB cementers. 10:30 11:30 1.00 2,705 2,705 SURFA( CEMEN-RURD T PJSM on cementing. SLB cement crew flood lines, prime pumps and batch up. 11:30 12:30 1.00 2,705 2,705 SURFA( CEMEN CMNT T Pump cement squeeze job, SLB came online w/5 bbls of water, PT lines to 500/4000 psi. Pump 15 bbls of 12.5 ppg MudPush II, close annular. SLB batch up cement. Open annular, pump 25 bbls of 15.8 ppg cement, close annular. Batch up MudPush, open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement w/rig pumps @ 5 bpm. Displaced plug w/31 bbls of mud. 12:30 13:15 0.75 2,705 2,057 SURFA( CEMEN-TRIP T POOH @ 1200 fph f/2705'MD to 2057'MD.Actual displacement= 7.55 bbls, Calculated displacement= 5.25 bbls. 13:15 14:00 0.75 2,057 2,057 SURFA( CEMEN CIRC T Drop DP wiper ball, circulate surface to surface @ 650 gpm=700 psi, 57%flow. Blow down top drive and M/U cement hose. Page 11 of 35 Time Logs ill Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:00 16:00 2.00 2,057 2,057 SURFA( CEMEN-SQEZ T Perform hesitation squeeze as follows: 1. Pumped .5 bbls=200 psi,shut in for 10 min=25 psi. 2. Pumped .4 bbls=250 psi, shut in for 10 min=25 psi. 3. Pumped .4 bbls=300 psi, shut in for 10 min=75 psi. 4. Pumped.5 bbls=350 psi, shut in for 10 min=100 psi. 5. Pumped..7 bbls=400 psi,shut in for 10 min=125 psi. 6. Pumped .6 bbls=450 psi,shut in for 10 min=175 psi. 7. Pumped.8 bbls=450 psi, shut in for 10 min=250 psi. 8. Pumped 1 bbl=450 psi,shut in for 10 min=300psi. 9. Pumped.5 bbls=450 psi,shut in for 10 min=325 psi. 10. Pumped .5 bbls=450 psi, shut in for 10 min=350 psi. 11. Pumped.3 bbls=450 psi, shut in for 10 min 350 psi. Bleed off was flat lined last 5 mins on #11. Squeezed a total of 6.2 bbls into the formation. 4.45 hrs to 70 Bc. cement in place @ 12:20 hrs 16:00 17:30 1.50 2,057 937 SURFA( CEMEN-TRIP T POOH f/2057't/937' 17:30 19:30 2.00 937 0 SURFA( CEMEN-PULD T L/D 3 1/2"tubing cement string. 19:30 21:00 1.50 0 0 SURFA( CEMEN-RURD T R/D tubing running and handling equipment. Clear and clean rig floor. 21:00 22:30 1.50 0 728 SURFA( CEMEN-BHAH T P/U 9 7/8"BHA#6 per SLB Rep. 22:30 23:00 0.50 728 1,476 SURFA( CEMEN TRIP T RIH with 5"DP f/728't/1476'. 23:00 23:30 0.50 1,476 1,476 SURFA( CEMEN DHEQ T Shallow test MWD tools(test good) 23:30 00:00 0.50 1,476 2,313 SURFA( CEMEN-TRIPT RIH with 5" DP f/1476't/2313'. 03/06/2015 Wait on cement. Pressure test cement plug to 500 psi. Drill out cement from 2480'to 2693'. Perform FIT to EMW of 11.6 ppg. Pump 25 bbl FORM-A-BLOK pill. Perform FIT to EMW of 12.0 ppg. (Test unsuccessful) 00:00 08:30 8.50 2,313 2,313 SURFA( CEMEN WOC T Wait on cement to get to 500 psi compressive strength as per SLB UCA, 16:36 hours. SIMOPS,Work on MP2s, service rig and clean rig. 08:30 08:45 0.25 2,313 2,313 SURFA( CEMEN-PRTS T Pressure test cement to 500 psi for 10 min,good test. 08:45 09:30 0.75 2,313 2,313 SURFA( CEMEN-RURD T PJSM, Rig down testing equipment and blow down lines. 09:30 10:45 1.25 2,313 2,480 SURFA( CEMEN REAM T Wash and ream f/2310'MD to 2480' MD @ 450 gpm=800 psi, 50%flow, Tq=2K.Tag cement @ 2480'MD Page 12 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:00 1.25 2,480 2,693 SURFA( CEMEN-DRLG T Drill cement f/2480't/2693 MD. 800 GPM/50%flow/60 RPM/TQ 2-8K /Wt on bit 10K/PUW 100K/SOW 77K/RWT 88K(no bit weight last 10') 12:00 13:00 1.00 2,693 2,693 SURFA( CEMEN"CIRC T PJSM, circulate and condition mud at 450 GPM/800 psi/50%flow. 13:00 13:30 0.50 2,693 2,590 SURFA( CEMEN RURD T PJSM, POOH to 2590'and R/U to perform FIT. 13:30 15:15 1.75 2,590 2,590 SURFA( CEMEN'FIT T PJSM, Perform FIT, leak off at 210 psi/EMW 11.6 ppg. 15:15 15:30 0.25 2,590 2,590 SURFA( CEMEN'RURD T R/D FIT test equipment 15:30 18:30 3.00 2,590 2,683 SURFA( CEMEN-COND T PJSM, SIM/OPS:While mixing 30 bbl FORM-A-BLOD pill, run in the hole to 2683'and change ram door seal. 18:30 19:15 0.75 2,683 2,499 SURFA( CEMEN CIRC T RIH to 2693'and spot pill. Pump 25 bbl FORM-A-BIOK pill and 55 bbls of mud. POOH to 2499'pumping 3 bpm. 19:15 19:45 0.50 2,499 2,499 SURFA( CEMEN-CIRC T Circulate bottoms up at 2499'. 19:45 20:00 0.25 2,499 2,499 SURFA( CEMEN-RURD T R/U for hesitation squeeze. 20:00 21:30 1.50 2,499 2,499 SURFA( CEMEN-SQEZ T Perform FORM-A-BLOK hesitation squeeze as follows: 1: Pumped 1.0 bbls=300 psi, shut in for 10 min=75 psi 2: Pumped 1.7 bbls=350 psi, shut in for 10 min=75 psi 3: Pumped 4.0 bbls=350 psi, shut in for 10 min= 100 psi 4: Pumped.4 bbls=350 psi, shut in for 10 min= 110 psi 5: Pumped.3 bbls=350 psi, shut in for 10 min= 125 psi 6: Pumped.3 bbls=350 psi, shut in for 10 min= 125 psi Squeeze a total of 7.7 bbls of Form-A-Block into the formation. 21:30 22:30 1.00 2,499 2,665 SURFA( CEMEN-WASH T PJSM, R/D test equipment, RIH to 2665',wash down last stand. 22:30 23:00 0.50 2,665 2,583 SURFA( CEMEN-CIRCT POOH to 2583'and CBU. R/U for FIT. 23:00 23:30 0.50 2,583 2,583 SURFA( CEMEN FIT T Perform FIT/pressure to 280 psi, EMW of 12.0 ppg. Shut in and held pressure for 10 minutes. Pressure bled off from 280 psi to 120 psi. 23:30 00:00 0.50 2,583 2,693 SURFA( CEMEN-REAM T R/D test equipment and wash to bottom 2693'at 450 GPM/800 psi/ ROT 60 RPM/TQ 4-5K/PUW 100K /SOW 75K/RWT 88K. 03/07/2015 Perform FIT to 12.0 ppg EMW(test unsuccessful). POOH and L/D BHA. P/U 3 1/2"tubing string and RIH. Perform second squeeze job. POOH and L/D 3 1/2"tubing string. P/U Intermediate BHA, RIH to 2404'and WOC. Page 13 of 35 Time Logs • Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 00:00 00:45 0.75 2,693 2,693 SURFA( CEMEN-CIRC T PJSM, Cont to clean out Form-A-Blok,wash and ream down V 2693'MD, pump @ 450 gpm=800 psi, Rot @ 60 rpm's,Tq=4-5K. P/U= 100K, S/0=75K, ROT=88K. 00:45 01:00 0.25 2,693 2,593 SURFA( CEMEN-TRIP T POOH f/2693' MD to inside casing @ 2593' MD 01:00 01:30 0.50 2,593 2,593 SURFA( CEMEN-FIT T R/U and perform FIT to 12.0 ppg EWM, pressure bleed off from 280 psi to 30 psi in 10 min. 01:30 01:45 0.25 2,593 2,593 SURFA( CEMEN-RURD T Blow down lines and rig down testing equipment. 01:45 02:45 1.00 2,593 2,593 SURFA( CEMEN WAIT T Discuss options with town, decision made to POOH and pump a 2nd cement squeeze. 02:45 03:00 0.25 2,593 2,686 SURFA( CEMEN TRIP T RIH f/2593' MD to 2686' MD. 03:00 03:30 0.50 2,686 2,686 SURFA( CEMEN-CIRC T CBU @ 450 gpm=800 psi, 50% flow. 03:30 03:45 0.25 2,686 2,686 SURFA( CEMEN-OWFF T OWFF, static. 03:45 05:00 1.25 2,686 728 SURFA( CEMEN TRIP T PJSM, POOH f/2686'MD to 728' MD, OWFF last stand of 5"DP. Actual displacement=33.95 bbls, Calculated displacement=32.7 bbls. 05:00 05:45 0.75 728 176 SURFA( CEMEN-TRIP T POOH, stand back HWDP and NMFC. 05:45 07:15 1.50 176 0 SURFA( CEMEN BHAH T PJSM, L/D BHA as per SLB rep. Clean and clear rig floor. 07:15 08:15 1.00 0 0 SURFA( CEMEN PULD T PJSM, Mobilize casing equipment to rig floor and rig up to run 3-1/2"EUE cement stinger. 08:15 09:45 1.50 0 937 SURFA( CEMEN'PUTB T RIH w/3-1/2"tbg to 937' MD 09:45 11:00 1.25 937 2,693 SURFA( CEMEN-TRIPT RIH w/5" DP f/937'MD to 2693'MD. P/U=68K, S/O=67K.Actual displacement= 19.25 bbls, Calculated displacement= 17.95 bbls. 11:00 12:15 1.25 2,693 2,693 SURFA( CEMEN-CIRC T Circulate and condition mud/450 BPM/450 psi/48%flow. 12:15 13:15 1.00 2,693 2,693 SURFA( CEMEN-CMNT T Pump cement squeeze job, SLB came online w/5 bbls of water, PT lines to 500/4000 psi. Pump 15 bbls of 12.5 ppg MudPush II, close annular. SLB batch up cement. Open annular, pump 25 bbls of 15.8 ppg cement, close annular. Batch up MudPush, open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement w/rig pumps @ 5 bpm. Displaced plug w/31 bbls of mud. 13:15 14:00 0.75 2,059 2,059 SURFA( CEMEN-TRIP T POOH @ 1200 fph f/2693' MD to 2059'MD. 14:00 14:45 0.75 2,059 2,059 SURFA( CEMEN'CIRC T Drop DP wiper ball, circulate surface to surface @ 650 gpm=625 psi, 57%flow. Blow down top drive and M/U cement hose. Page 14 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 16:45 2.00 2,059 2,059 SURFA( CEMEN-SQEZ T Perform hesitation squeeze as follows: 1. Pumped.5 bbls=350 psi, shut in for 10 min=190 psi. 2. Pumped.3 bbls=400 psi, shut in for 10 min=250 psi. 3. Pumped.3 bbls=450 psi,shut in for 10 min=290 psi. 4. Pumped.2 bbls=450 psi, shut in for 10 min=325 psi. 5. Pumped ..2 bbls=450 psi,shut in for 10 min=300 psi. Squeezed a total of 1.5 bbls into the formation. Cement in place @ 12:20 hrs 16:45 18:00 1.25 2,059 937 SURFA( CEMEN"TRIP T PJSM, POOH from 2059'to 937'. 18:00 19:30 1.50 937 0 SURFA( CEMEN PULD T PJSM, L/D 3 1/2"tubing string. Cal disp=12.48 bbls/Actual=14.35 bbls. 19:30 20:15 0.75 0 0 SURFA( CEMEN'RURD T R/D tubing running tools and clear and clean floor. 20:15 21:45 1.50 0 758 SURFA( CEMEN-BHAH T PJSM, P/U 9 7/8"Intermediate BHA #6. 21:45 22:15 0.50 758 1,500 SURFA( CEMEN-DHEQ T RIH to 1500'and shallow test MWD tools. 22:15 23:15 1.00 1,500 2,404 SURFA( CEMEN-TRIP T RIH to 2404', blow down TD. Cal disp=25.54 bbls/Actual=24.87 bbls. 23:15 00:00 0.75 2,404 2,404 SURFA( CEMEN WOC T Stab safety valve and close pipe rams. Repair drag chain in rock washer while WOC. 33/08/2015 Drill cement 2480'to 2673'. Perform FIT to EMW of 12.1 ppg(successful test). Drill cement to 2708'and displace well with 9.5 ppg LSND mud. Drill ahead to TD+/-6524' 00:00 00:45 0.75 2,404 2,480 SURFA( CEMEN-REAM T PJSM,Wash and ream f/2407'MD to 2480' MD, pump @ 450 gpm=800 psi,49%flow, 50 rpm's w/1-3K tq. 00:45 02:00 1.25 2,480 2,673 SURFA( CEMEN-DRLG T Drill cement f/2480' MD to 2673'MD, pump @ 450 gpm=800 psi, 50 rpm's w/3-5K tq,50%flow,WOB 3-5K, P/U= 100K, S/O=77K, ROT=88K. 02:00 03:00 1.00 2,673 2,673 SURFA( CEMEN-OTHR P Daylight savings(move clocks ahead 1 hr) 03:00 03:45 0.75 2,673 2,673 SURFA( CEMEN CIRC T Circulate and condition for FIT. 03:45 04:00 0.25 2,673 2,650 SURFA( CEMEN RURD T PJSM, Rig up lines to perform FIT. Blow down top drive. 04:00 04:45 0.75 2,650 2,650 SURFA( CEMEN FIT T Perform FIT to 12.1 ppg EWM, good test. 04:45 05:00 0.25 2,650 2,650 INTRM1 DRILL CIRC P M/U topdrive and obtain SPR's. 05:00 07:30 2.50 2,650 2,708 INTRM1 DRILL DDRL P Drill ahead f/2673'MD to 2708'MD, drill out both cement plugs. pump @ 450 gpm=800 psi,49%flow, 50 rpm's w/5K tq,WOB=3-5K. Control ROP and WOB to avoid getting kicked off plug. Lost WOB @ 2702' MD indicating drilled off the plug. Page 15 of 35 Time Logs 1110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 2,708 2,708 INTRM1 DRILL DISP P PJSM, Displace well to 9.4 ppg LSND mud, pumped 25 bbls of High Vis spacer followed to 9.4 ppg LSND mud. Once the LSND mud was back to shakers it began to blind screens. Reduced pump to 300 gpm and staged back up to 650 gpm, stopped running over. 09:00 09:30 0.50 2,708 2,708 INTRMI DRILL CIRC P Obtain baseline ECD's @ 650 gpm and 700 gpm and SPR's. 09:30 12:00 2.50 2,708 2,883 INTRM1 DRILL DDRL P Drill f/2708't/2882'MD,2432'TVD. ADT 1.65 hrs/Bit 1.96 hrs/JARS 51.94 hrs/PUW 98K/SOW 82K/ RWT 82K/TQ on 5-8K/TQ off 5K/ ECD 10.1 ppg/FLOW56%/WOB 4fK/RPM 120/GPM 625/SPM 146/PSI 1050/MAX GAS 49 units. 12:00 18:00 6.00 2,883 3,440 INTRMI DRILL DDRL P Drill f/2883't/3440'MD,2688'TVD. ADT 4.65 hrs/Bit 6.96 hrs/JARS 56.90 hrs/PUW 104K/SOW 83K/ RWT 90K/TQ on 4-8K/TQ off 3-5K /ECD 10.13 ppg/FLOW59%/ WOB 5-8fK/RPM 120/GPM 700/ SPM 164/PSI 1500/MAX GAS 48 units. SPR's taken at 3430'/Mud wt 9.5 ppg/Time 17:30 Pump#1 at 30 spm=120 psi/40 spm=145 psi Pump#2 at 30 spm=120 psi/40 spm=140 psi 18:00 00:00 6.00 3,440 3,946 INTRM1 DRILL DDRL P Drill f/3440't/3946'MD,2919'TVD. ADT 4.47 hrs/Bit 11.39 hrs/JARS 61.37 hrs/PUW 117K/SOW 84K/ RWT 95K/TQ on 2-12K/TQ off 5-7K/ECD 10.27 ppg/FLOW 59%/ WOB 4-8fK/RPM 120/GPM 700/ SPM 164/PSI 1500/MAX GAS 56 units. SPR's taken at 3895'/Mud wt 9.5 ppg/Time 23:15 Pump#1 at 30 spm=125 psi/40 spm=160 psi Pump#2 at 30 spm=130 psi/40 spm=160 psi 03/09/2015 Drill 9 7/8"Intermediate hole from 3,946'to 6,038'. 00:00 06:00 6.00 3,946 4,451 INTRMI DRILL DDRL P Drill f/3946't/4451' MD, 3146'TVD. ADT 4.44 hrs/Bit 15.83 hrs/JARS 65.81 hrs/PUW 114K/SOW 91K/ RWT 103K/TQ on 7K/TQ off 7-8K/ ECD 10.4 ppg/FLOW 59%/WOB 5-7fK/RPM 140/GPM 700/SPM 164/PSI 1575/MAX GAS 81 units. Page 16 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 4,451 5,047 INTRM1 DRILL DDRL P Drill f/4451'U 5047' MD, 3379'TVD. ADT 4.69 hrs/Bit 20.52 hrs/JARS 70.50 hrs/PUW 123K/SOW 90K/ RWT 106K/TQ on 5-10K/TQ off 9K /ECD 10.4 ppg/FLOW 60%/WOB 3-5fK/RPM 140/GPM 700/SPM 164/PSI 1710/MAX GAS 112 units. SPR's taken at 5013' MD 3369'TVD /Mud wt 9.5 ppg/Time 11:20 hrs Pump#1 at 30 spm=160 psi/40 spm=210 psi Pump#2 at 30 spm=150 psi/40 spm=200 psi 12:00 18:00 6.00 5,047 5,591 INTRM1 DRILL DDRL P Drill f/5047't/' MD, 5591'TVD. ADT 4.32 hrs/Bit 24.84 hrs/JARS 74.82hrs/PUW 127K/SOW 93K/ RWT 104K/TQ on 8-12K/TQ off 5-6K/ECD 10.49 ppg/FLOW 60%/ WOB 10-17fK/RPM 140/GPM 700 /SPM 164/PSI 1825/MAX GAS 29 units. 18:00 00:00 6.00 5,591 6,038 INTRM1 DRILL DDRL P Drill f/5591'U 6038' MD, 3708'TVD. ADT 3.68 hrs/Bit 28.52 hrs/JARS 78.50 hrs/PUW 124K/SOW 93K/ RWT 124K/TQ on 9-11K/TQ off 6-7K/ECD 10.462 ppg/FLOW 60% /WOB 11-17K/RPM 140/GPM 700/SPM 164/PSI 1900/MAX GAS 68 units. SPR's taken at 6036'MD 3708'TVD /Mud wt 9.5 ppg/Time 23:45 hrs Pump#1 at 30 spm=200 psi/40 spm=300 psi Pump#2 at 30 spm=200 psi/40 spm=250 psi 03/10/2015 Drill 9 7/8"Intermediate hole from 6,038'to TD @ 6664'MD. Circulate 3X BU, back ream to the Shoe. Monitor ,well, static. Service TD. 00:00 06:00 6.00 6,038 6,412 INTRM1 DRILL DDRL P PJSM, Drill f/6038'U 6412' MD, 3774'TVD.ADT 5.15 hrs/Bit 33.67 hrs/JARS 83.65 hrs/PU 127K/ SO 91K/RWT 105K/TQ on 10-11K /TQ off 7K/ECD 10.6 ppg/FLOW 59%/WOB 15-19K/RPM 140/ GPM 700/SPM 164/PSI 1900. 06:00 10:15 4.25 6,412 6,664 INTRM1 DRILL DDRL P PJSM, Drill f/6412't/6664' MD, 3797'TVD.ADT 2.7 hrs/Bit 36.37 hrs/JARS 86.35 hrs/PU 130K/ SO 85K/RWT 107K/TQ on 10K/ TQ off 8K/ECD 10.58 ppg/FLOW 59%/WOB 3-5K/RPM 100/GPM 700/SPM 164/PSI 1980. Page 17 of 35 Time Logs 40 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 12:00 1.75 6,664 6,508 INTRM1 CASING CIRC P Pump hi vis sweep, CBU 3X @ 700 gpm, 1980 psi, FO 59%, 120 rpm, Tq 10K, racking back 1 stand every BU, f/6664'-6508' MD. SPR's @ 6664'MD 3797'TVD/Mud wt 9.5 ppg/Time 10:15 hrs Pump#1 at 30 spm=180 psi/40 spm=240 psi Pump#2 at 30 spm=190 psi/40 spm=230 psi 12:00 12:45 0.75 6,508 6,508 INTRM1 CASING OWFF P Monitor well, 20 rpm, blow down TD, static. 12:45 21:30 8.75 6,508 2,651 INTRM1 CASING BKRM P PJSM, BROOH f/6508'-2651'MD, 650 gpm, 1675 psi, 80 rpm, Tq 8-11K, 700-1000 fph, PU 97K, SO 88K, ROT 85K. Calculated fill 32, actual 74 bbls. 21:30 22:45 1.25 2,651 2,651 INTRM1 CASING CIRC P CBU 4X, 650 gpm, 1675 psi, 80 rpm, Tq 5-6K, reciprocating pipe. 22:45 23:15 0.50 2,651 2,651 INTRM1 CASING OWFF P Monitor well, static. 23:15 00:00 0.75 2,651 2,651 INTRM1 CASING SVRG P PJSM, service TD&Iron Roughneck. 03/11/2015 TOH f/shoe at 2660' MD to surface laying down HWDP&BHA. C/O upper rams to 7 5/8"&test. Rig up& run 7 5/8"casing as per detail f/surface to 5767'MD. 00:00 01:00 1.00 2,651 728 INTRM1 CASING TRIP P PJSM,TOH f/2651'-728' MD. 01:00 01:15 0.25 728 728 INTRM1 CASING OWFF P Monitor well, slight drop in fluid level. 01:15 02:15 1.00 728 79 INTRM1 CASING BHAH P PJSM lay down 17 jts. of HWDP, jars, &3 NMFC. 02:15 03:15 1.00 79 0 INTRM1 CASING BHAH P PJSM, lay down remaining BHA as per SLB DD. 03:15 04:00 0.75 0 0 INTRM1 CASING BHAH P PJSM, clear&clean rig floor. 04:00 05:00 1.00 0 0 INTRM1 CASING WWWH P PJSM,flush stack&well head,to clean clay. Blow down TD. 05:00 06:00 1.00 0 0 INTRM1 CASING BOPE P PJSM,change upper rams to 7.625" solid body rams. 06:00 06:45 0.75 0 0 INTRM1 CASING RURD P PJSM, pull wear bushing. 06:45 07:15 0.50 0 0 INTRM1 CASING RURD P PJSM, perform dummy run with casing hanger&landing joint. 07:15 08:00 0.75 0 0 INTRM1 CASING BOPE P PJSM, rig up to test 7 5/8"rams. 08:00 08:30 0.50 0 0 INTRM1 CASING BOPE P PJSM,test 7 5/8"joint w/annular to 250/2500 psi,w/upper 7 5/8" rams 250/3500 psi, charted for 5 min, each test. 08:30 09:00 0.50 0 0 INTRM1 CASING BOPE P PJSM, rig down test equipment. 09:00 10:30 1.50 0 0 INTRM1 CASING RURD P PJSM, mobilize&rig up casing running equipment. 10:30 10:45 0.25 0 0 INTRM1 CASING SFTY P PJSM on running 7 5/8"casing. 10:45 11:15 0.50 0 220 INTRM1 CASING PUTB P Make up shoe track&check floats, f/surface to 220'MD. Page 18 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase -Code Subcode T Comment 11:15 15:15 4.00 220 2,620 INTRM1 CASING PUTB P PJSM, run in the hole w/7 5/8", 29.7#, L-80, HYD 563, casing f/ 220'-2620' MD. Table top kick w/tripping drill held during PTSM @ 11:45 hrs. 15:15 16:00 0.75 2,620 2,620 INTRM1 CASING CIRC P CBU staging up pumps 2-4.5 bpm, 100 psi. 16:00 18:00 2.00 2,620 3,918 INTRM1 CASING PUTB P PJSM, run in the hole w/7 5/8", 29.7#, L-80, HYD 563, casing f/ 2620'-3918'MD. 18:00 19:00 1.00 3,918 3,918 INTRMI CASING CIRC P CBU staging up pumps 2-4.5 bpm, 260 psi. 19:00 21:00 2.00 3,918 5,208 INTRMI CASING PUTB P PJSM, run in the hole w/7 5/8", 29.7#, L-80, HYD 563, casing f/ 3918'-5208' MD. 21:00 22:45 1.75 5,208 5,208 INTRM1 CASING CIRC P CBU 2X staging up pumps 2-5.5 bpm, 325 psi. Circulated extra BU to condition heavy,thick mud coming back to surface. 22:45 00:00 1.25 5,208 5,767 INTRM1 CASING PUTB P PJSM, run in the hole w/7 5/8", 29.7#, L-80, HYD 563, casing f/ 5208'-5767' MD, PU 144K, SO 95K. 03/12/2015 Continue running intermediate casing f/5767'-6655'MD. C&C mud for cement. Cement as per plan. Install pack off&test to 5000 psi. Flush&freeze protect annulus. Lay down 5"DP&pick up 4"DP. 00:00 01:15 1.25 5,767 6,623 INTRM1 CASING PUTB P PJSM, run in the hole w/7 5/8", 29.7#, L-80, HYD 563, casing f/ 5767'-6623'MD, PU 144K, SO 95K. Calculated displacement 11.2, actual 12.6 bbls. 01:15 01:30 0.25 6,623 6,655 INTRM1 CASING HOSO P Make up hanger&landing joint, land hanger @ 6655'MD. 01:30 03:15 1.75 6,655 6,655 INTRM1 CEMEN"CIRC P C&C mud for cementing staging up pumps 2-5 bpm, 380 psi, FO 40%, PU 155K, SO 105K 03:15 03:45 0.50 6,655 6,655 INTRM1 CEMEN-RURD P PJSM, blow down TD, rig up cement line to Baker swivel head on Volant CRT. 03:45 05:45 2.00 6,655 6,655 INTRM1 CEMEN CIRC P Continue C&C mud for cementing @ 5.5 bpm, 500 psi, FO 38%, PU 155K, SO 105K 05:45 08:30 2.75 6,655 0 INTRMI CEMEN-CMNT P PJSM, pump 5 bbl H2O&test lines 500/4000 psi. Batch up 11.5 ppg MudPush&pump 55 bbls @ 4.5 bpm, 315 psi. Drop bottom plug. Pump 153 bbls of 15.8 ppg Tail slurry cement @ 5 bpm,250 psi. Drop top plug. Chase with 10 bbls of H2O @ 5 bpm, 90 psi. Swap to rig&chase w/ 9.5 ppg mud @ 6 bpm, 250-1000 psi, Bump plug with 2896 strokes&psi up to 1500 psi, holding for 5 min. Bleed off pressure, floats check good. CIP @ 08:22 hrs. 08:30 09:45 1.25 0 0 INTRM1 CEMEN-RURDP PJSM, rig down Volant CRT, cement lines,drain stack, lay down landing joint, &clean equipment. Page 19 of 35 0 Time Logs • 411 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:15 1.50 0 0 INTRM1 CEMEN"WWSP P PJSM, set pack off&test to 5000 psi for 10 min. Good test. Sim-ops rig up to flush&freeze protect OA. 11:15 11:30 0.25 0 0 INTRM1 CEMEN-SFTY P PJSM on rigging up&work scope to flush&freeze protect OA. 11:30 13:45 2.25 0 0 INTRM1 CEMEN-FRZP P PT lines to 500/3500 psi. Flush OA w/117 bbls of H2O staging up pumps .5-3 bpm, 600-825 psi. Swap over to Little Red. Pump 90 bbls of Isotherm .5- 1.4 bpm, 500- 1100 psi. SIP 1100 psi. 13:45 18:45 5.00 0 0 INTRM1 CEMEN-PULD P PJSM, lay down 67 stands of 5"DP. 18:45 20:00 1.25 0 0 INTRM1 CEMEN-OTHR P PJSM, load BHA&remaining 4"DP in pipe shed. Strap 22 joints of 4" DP. 20:00 00:00 4.00 0 0 INTRM1 CEMEN'PULD P PJSM, pick up&rack back 32 stands of 4" DP in the derrick. Spill drill CRT 92 sec @ 23:30 hrs OA pressure 300 psi. 03/13/2015 Continue to P/U 4"DP. Cut&slip drill line. C/O upper&lower rams.Test BOPE. 00:00 03:45 3.75 0 0 INTRMI CEMEN PULD P PJSM, pick up 38 stands of 4" DP and rack back in derrick. 03:45 04:15 0.50 0 0 INTRM1 CEMEN-RURD P PJSM, pull mousehole&clear rig floor. 04:15 05:30 1.25 0 0 INTRM1 CEMEN"SLPC P PJSM, slip&cut 67'of drill line. 05:30 06:00 0.50 0 0 INTRM1 CEMEN-SVRG P PJSM, service rig. 06:00 09:15 3.25 0 0 INTRMI CEMEN BOPE P PJSM, change out upper&lower rams to 2 7/8"X 5"VBR's. Sim-ops install bolts on Dutch Riser. 09:15 12:30 3.25 0 0 INTRM1 CEMEN-RURD P PJSM, dress TD for 4"DP. 12:30 13:30 1.00 0 0 INTRM1 WHDBO BOPE P PJSM, rig up to test BOPE. 13:30 18:00 4.50 0 0 INTRM1 WHDBO BOPE P Test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe VBR's, CV 1,12,13, 14 and manual kill.Test#2: Upper IBOP, HCR kill, CV 9, and 11. Test#3: Lower IBOP, CV 5,8 and 10. Test #4: Dart„ CV 4,6 and 7. Test#5: Floor valve and CV 2.Test#6: HCR choke,4"kill line Demco and extra floor valve. Test#7: Manual choke valve and HCR kill. Test#8:Annular preventer. Test#9: Lower pipe VBR's. Accumulator test: system pressure=2950 psi,After closing= 1800 psi, 200 psi attained after 48 sec, full pressure attained after 171 sec, Five bottle nitrogen avg=2000 psi. Witnessed was waived by AOGCC rep Bob Noble. 18:00 19:30 1.50 0 0 INTRM1 WHDBO BOPE P PJSM, C/O to 4.5"test joint. Test 250/3500 psi, 5 min each with upper &lower VBR's. Test annular tested to 250/2500 psi 5 min each. Page 20 of 35 Time Logs , Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 19:30 20:45 1.25 0 0 INTRM1 WHDBO BOPE P PJSM, C/O to 2.875"test joint. Test 250/3500 psi, 5 min each with upper VBR's.Test annular tested to 250/2500 psi 5 min each. 20:45 00:00 3.25 0 0 INTRMI WHDBO BOPE T Attempt to test lower VBR's w/ 2.875"joint. Trouble shoot VBR'S& decide to change out elements. OA pressure 90 psi. 03/14/2015 C/0 lower rams&finish BOP test. P/U BHA 5. Single in the hole w/4"DP to 1806' MD. MWD failed testing. TOH to 390'&C/O Impulse MWD. TIH to 1806'MD&shallow test, good. Continue singling in the hole,w/ MAD pass 2600'-4706'MD. 00:00 01:00 1.00 0 0 INTRM1 WHDBO BOPE T PJSM, continue attempting to do elements on 2 7/8"X 5"VBR's. Decide to install 3 1/2"X 6"VBR's. 01:00 02:00 1.00 0 0 INTRM1 WHDBO BOPE T PJSM, install 3 1/2"X 6"VBR's on bottom. 02:00 02:30 0.50 0 0 INTRM1 WHDBO BOPE T PJSM, rig up test equipment. 02:30 03:15 0.75 0 0 INTRM1 WHDBO BOPE T PJSM, Continue testing BOPE to 250/3500 psi for 5 min each. Test blind rams&CV 3;test w/4"test joint the lower VBR's&FOSV. Witness waived by AOGCC Rep Bob Noble. 03:15 04:00 0.75 0 0 INTRMI WHDBO RURD P PJSM, pull test plug&install 9"ID wear bushing. 04:00 04:30 0.50 0 0 INTRM1 WHDBO RURD P PJSM, rig down test equipment, & blow down all lines. 04:30 05:30 1.00 0 0 INTRM1 CEMEN'BHAH P PJSM, mobilize SLB tools to rig floor. 05:30 06:00 0.50 0 0 INTRMI CEMEN-SVRG P PJSM, lubricate rig. 06:00 07:30 1.50 0 0 INTRM1 CEMEN-BHAH P PJSM, pick up HWDP w/JARS&3 joints of NMFC, racking back in derrick. Kick w/Tripping Drill CRT 120 sec @ 06:30hrs. 07:30 09:30 2.00 0 380 INTRM1 CEMEN BHAH P PJSM, make up BHA 5 as per SLB DD. 09:30 11:30 2.00 380 1,806 INTRM1 CEMEN-PULD P PJSM, single in the hole w/4"DP& BHA 5 f/390'-1806'MD, calculated displacement 21.6,actual 18.6 bbls. 11:30 13:30 2.00 1,806 1,806 INTRMI CEMEN-DHEQ T Shallow test MWD @ 240 gpm, 1000 psi.Attempt to troubleshoot Impulse. Decision made to TOH&C/O Impulse MWD tool. 13:30 13:45 0.25 1,806 1,336 INTRMI CEMEN-TRIPT PJSM,TOH f/1806'-1336'MD. 13:45 14:30 0.75 1,336 1,336 INTRM1 CEMEN SVRG P PJSM,service Top Drive. 14:30 14:45 0.25 1,336 390 INTRM1 CEMEN-TRIP T PJSM, TOH f/1336'-390' MD. 14:45 17:00 2.25 390 390 INTRM1 CEMEN"BHAH T PJSM, lay down Impulse MWD as per SLB. Download&prep back up tool. Pick up back Impulse MWD as per SLB. 17:00 17:45 0.75 390 1,806 INTRM1 CEMEN-TRIPT PJSM,TIH f/390'-1806'MD. Page 21 of 35 Time Logs • • _Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:45 18:30 0.75 1,806 1,806 INTRM1'CEMEN-DHEQ P Shallow test MWD @ 210 gpm, 950 psi,20 rpm, Tq 1K,tested good. 18:30 19:15 0.75 1,806 2,600 INTRM1 CEMEN'PULD P PJSM, single in the hole f/ 1806-2600' MD. 19:15 00:00 4.75 2,600 4,706 INTRM1 CEMEN-QEVL P PJSM, single in the hole logging f/ 2600'-4706' MD, 900 fph, calculated displacement 29, actual 29 bbls. Kick w/Tripping Drill CRT 85 sec @ 23:45 hrs. 33/15/2015 Continue to single in the hole to 6343' MD,Wash down to 6532' MD. CBU for even 9.5 ppg MW. Test 7 5/8" casing to 3500 psi. Drill out shoe track&20'of new hole to 6685'MD. CBU&perform FIT to 12.5 ppg EMW. Displace mud system to FloPro 9.4ppg. Directional drill f/6685-7257' MD. 00:00 02:15 2.25 4,706 5,500 INTRMI CEMEN.QEVL P Continue singling in the hole making MAD pass(recorded data)from 4705' MD to 5500' MD at 900 fph maximum string speed 02:15 03:00 0.75 5,500 6,343 INTRM1 CEMEN-PULD P Continue singling in the hole to 6343' MD, SOW=65 kips. Actual displacement= 14.7 bbl. Calculated displacement= 10.8 bbl. 03:00 03:45 0.75 6,343 6,532 INTRM1 CEMEN COCF P Break circulation and wash and ream from 6343'to 6532'. 210 gpm, 50 spm 1450 psi, 40 rpm, Torque=5-6000 ft-lbs Rotating weight=83 kips 03:45 04:45 1.00 6,532 6,532 INTRM1 CEMEN'CIRC P Circulate bottoms up at 210 gpm, 1400 psi, 40 rpm,torque=6000 ft-lbs 04:45 06:15 1.50 6,532 6,532 INTRMI CEMEN'PRTS P Rig up and test casing to 3500 psi for 30 minutes. Rig down test equipment 06:15 06:30 0.25 6,532 6,565 INTRMI CEMEN COCF P Break circulation. Wash and ream from 6532'MD to 6543'MD. Drill cement stringers from 6543' MD to 6565'. 210 gpm, 1300 psi,40 rpm, 6000 ft-lbs, ECD= 10.57 ppg, WOB =5-15 kips SPR's @ 6533'MD, 3785'TVD, MW 9.4+, 06:15 hrs. Pump#1 at 20 spm=380 psi/30 spm=580 psi Pump#2 at 20 spm=380 psi/30 spm=580 psi 06:30 10:15 3.75 6,565 6,665 INTRM1 CEMEN DRLG P Drill shoe track f/6565'-6665'MD, 210 gpm, 1300 psi,40 rpm, 6000 ft-lbs, ECD= 10.57 ppg, WOB= 5-15 kips 10:15 10:30 0.25 6,665 6,685 INTRM1 CEMEN DDRL P Drill 20'of new holef/6665'-6685' MD, ART=.09 hrs, bit hrs= .09 hrs,Jar hrs=52.17 hrs, 210 gpm, 1300 psi,40 rpm,6000 ft-lbs, ECD= 10.57 ppg, WOB=5-15 kips 10:30 11:30 1.00 6,685 6,685 INTRM1 CEMEN-CIRC P CBU @ 215 gpm, 1300 psi,40 rpm, Tq 8K, ECD 10.5 ppg. Page 22 of 35 Time Logs 41, Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:30 12:00 0.50 6,685 6,685 INTRM1 CEMEN-RURD P Blow down top drive and rig up test equipment 12:00 12:30 0.50 6,685 6,685 INTRM1 CEMEN-LOT P Perform LOT. Test pressure=600 psi, Mud weight=9.45 ppg, Shoe @ 3797'TVD. 12.50 ppg EMW 12:30 13:15 0.75 6,685 6,685 PROD1 DRILL CIRC P Displace well with 9.4 ppg flo-pro mud 13:15 18:00 4.75 6,685 6,909 PROD1 DRILL DDRL P DDrill from 6685'-6909'MD, 3810 TVD,ADT 3.52, BIT 3.52,JARS 56.14, PU 115K, SO 75K, ROT 60K, Tq on 7-8K, off 7K, ECD 11.03, FO 40%,WOB 3-6K, RPM 120, GPM 250, 1850 PSI, Max Gas 567. SPR's @ 6715'MD, 3801'TVD, MW 9.4+, 14:00 hrs. Pump#1 at 20 spm=450 psi/30 spm=655 psi Pump#2 at 20 spm=465 psi/30 spm=660 psi 18:00 00:00 6.00 6,909 7,257 PROD1 DRILL DDRL P DDrill from 6909'-7257'MD,3808' TVD,ADT 4.44, BIT 4.44,JARS 60.58, PU 123K, SO 54K, ROT 79K, Tq on 7-8K, off 6-7K, ECD 11.04, FO 40%, WOB 1-6K, RPM 120, GPM 250, 1925 PSI, Max Gas 862. SPR's @ 7190'MD, 3808'TVD, MW 9.4+, 23:00 hrs. Pump#1 at 20 spm=520 psi/30 spm=750 psi Pump#2 at 20 spm=525 psi/30 spm=740 psi OA 220 psi. 33/16/2015 Directional drill production section as per plan f/7257'-8423'MD,3833 TVD. 00:00 01:30 1.50 7,257 7,382 PROD1 DRILL DDRL P DDrill from 7257'-7382'MD, 3807' TVD,ADT 1.19, BIT 9.15, JARS 61.77, PU 125K, SO 50K, ROT 80K, Tq on 8K, off 8K, ECD 11.04, FO 39%,WOB 1-3K, RPM 120, GPM 250, 1900 PSI, Max Gas 387. 01:30 02:00 0.50 7,382 7,382 PROD1 DRILL OWFF T Observed losses @ 64 bph. Stop to check well. Observed flow, perform test to establish well bore breathing. Decide to continue drilling with reduced gpm&ROP. Flow check each connection to confirm breathing. 02:00 06:00 4.00 7,382 7,657 PROD1 DRILL DDRL P DDrill from 7382'-7657'MD, 3812' TVD,ADT 3.03, BIT 12.18,JARS 64.8, PU 125K, SO 49K, ROT 82K, Tq on 8K, off 8K, ECD 11.05, FO 37%,WOB 2-4K, RPM 110, GPM 235, 1800 PSI, Max Gas 929. Spill Drill CRT 120 sec @ 08:00 hrs. Page 23 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 7,657 7,895 PROD1 DRILL DDRL P DDrill from 7657'-7895' MD, 3816' TVD,ADT 4.97, BIT 17.15,JARS 69.77, PU 110K, SO 65K, ROT 84K, Tq on 5K, off 5K, ECD 10.84, FO 38%,WOB 2-10K, RPM 110, GPM 240, 1750 PSI, Max Gas 938. SPR's @ 7820' MD, 3817'TVD, MW 9.5, 09:45 hrs. Pump#1 at 20 spm=460 psi/30 spm=660 psi Pump#2 at 20 spm=460 psi/30 spm=650 psi Losses for tour 126 bbls. 12:00 18:00 6.00 7,895 8,039 PROD1 DRILL DDRL P DDrill from 7895'-8039' MD, 3822' TVD,ADT 5.56, BIT 22.71,JARS 75.33, PU 110K, SO 60K, ROT 80K, Tq on 6-7K, off 5K, ECD 10.9, FO 38%,WOB 5-10K, RPM 120, GPM 250, 1900 PSI, Max Gas 475. SPR's @ 8043'MD, 3822'TVD, MW 9.4+, 18:00 hrs. Pump#1 at 30 spm=450 psi/40 spm=650 psi Pump#2 at 30 spm=450 psi/40 spm=660 psi 18:00 00:00 6.00 8,039 8,423 PROD1 DRILL DDRL P DDrill from 8039'-8423'MD, 3833' TVD,ADT 4.11, BIT 26.82, JARS 79.44, PU 110K, SO 57K, ROT 80K, Tq on 8-9K, off 6K, ECD 11.25, FO 39%,WOB 4-8K, RPM 120, GPM 250, 1950 PSI, Max Gas 580. SPR's©8423'MD, 3811'TVD, MW 9.5+, 23:45 hrs. Pump#1 at 20 spm=500 psi/30 spm=700 psi Pump#2 at 20 spm=500 psi/30 spm=710 psi OA 180 psi. 03/17/2015 Directional drill production section as per plan f/8423't/9794'MD, 3815 TVD. 00:00 06:00 6.00 8,423 8,896 PROD1 DRILL DDRL P Drilled 6 3/4" hole f/8423'to 8896' MD 3834'TVD ADT-4.54 hrs Footage-473' ECD - 11.30ppg WOB 4/9 k RPM 120 GPM 250 @ 2050 psi w/39%FO String wt. PU 127 SO 44 ROT 83 Torque on/off btm.-10/9 k ft/lbs Total bit hrs.-31.36 hrs Total jar hrs. -83.98 hrs Max gas 667 units SPR's @ 8895'MD 3833'TVD @ 0600 hrs. #1 20 spm @ 520 psi 30 spm @ 740 psi #2 20 spm @ 560 psi 30 spm @ 760 psi Page 24 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 8,896 9,275 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/8896'to 9275' MD 3834'TVD ADT-4.01 hrs Footage-379' ECD - 11.20 ppg WOB 4/7 k RPM 120 GPM 250 @ 2025 psi w/38% FO String wt. PU 135 SO 0 ROT 82 Torque on/off btm.- 10.5/10 k ft/lbs Total bit hrs. 35.37 hrs Total jar hrs. 87.99 hrs Max gas 764 units SPR's 9274' MD 3837'TVD @ 1130 hrs. #1 20 spm @ 525 psi 30 spm @ 760 psi #2 20 spm @ 550 psi 30 spm @ 760 psi OA=190 psi 12:00 18:00 6.00 9,275 9,495 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/9275't/9495' MD 3825'TVD ADT-5.09 hrs Footage-220' ECD - 11.33 ppg WOB 6/10 K RPM 120 GPM 250 @ 2050 psi w/38% FO String wt. PU 122 SO 46 ROT 81 Torque on/off btm.-9/6 K fUlbs Total bit hrs. 40.46 hrs Total jar hrs. 93.08 hrs Max gas 276 units 18:00 00:00 6.00 9,495 9,794 PROD1 DRILL DDRL P Drilled 6 3/4" hole f/9495'to 9794' MD 3815'TVD ADT-4.73 hrs Footage-299' ECD - 11.39 ppg WOB 7/14 k RPM 120 GPM 249 @ 2100 psi w/40%FO String wt. PU 112 SO 52 ROT 80 Torque on/off btm.-7/5 k ft/lbs Total bit hrs.45.19 hrs Total jar hrs. 97.81 hrs Max gas 981 units SPR's 9657' MD 3819'TVD @ 2030 hrs. #1 20 spm @ 545 psi 30 spm @ 755 psi #2 20 spm @ 540 psi 30 spm @ 780 psi OA=160 psi 33/18/2015 Directional drill production section as per plan f/9794't/10970'. 3796'TVD Page 25 of 35 Time Logs 40 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 9,794 10,067 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/9794'MD to 10,067' MD 3811'TVD ADT-4.28 hrs Footage-273' ECD - 11.32ppg WOB 3/6 k RPM 120 GPM 250 @ 2100 psi w/38% FO String wt. PU 113 SO 48 ROT 81 Torque on/off btm.-7/5.5 k ft/lbs Total bit hrs.-49.47 hrs Total jar hrs. 102.09 hrs Max gas- 1027 units SPR's 9842'MD 3818'TVD @ 0045 hrs. #1 20 spm @ 540 psi 30 spm @ 750 psi #2 20 spm @ 560 psi 30 spm @ 760 psi 06:00 12:00 6.00 10,067 10,420 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/10,067' MD to 10,420' MD 3805'TVD ADT-4.55 hrs. Footage-353' ECD-11.47ppg WOB 2/5 k RPM 120 GPM 250 @2175 psi w/38%FO String wt. PU 114 SO 44 ROT 79 Torque on/off btm.-7.5/5 k ft/lbs Total bit hrs. 54.02 hrs Total jar hrs. 106.64 hrs. Max gas- 1117 units SPR's 10410'MD 3804'TVD @ 1130 hrs #1 20 spm @ 600 psi 30 spm @ 780 psi #2 20 spm @ 600 psi 30 spm @ 850 psi OA=210 psi 12:00 13:30 1.50 10,420 10,550 PROD1 DRILL DDRL P Drilled 6 3/4" hole f/10,420' MD to 10,550' MD 3802'TVD ADT-1.43 hrs. Footage-130' ECD-11.56ppg WOB 3/6 k RPM 120 GPM 250 @2175 psi w/39%FO String wt. PU 118 SO 39 ROT 78 Torque on/off btm.-7.5/5-6 k ft/lbs Total bit hrs. 55.55 hrs Total jar hrs. 108.17 hrs. Max gas-842 units 13:30 15:00 1.50 10,550 10,550 PROD1 DRILL REAM T Stand back one stand of DP.Wash and ream f/10550'MD t/10410'MD due to 9 deg dog leg. Page 26 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 10,550 10,694 PROD1 DRILL DDRL P Drilled 6 3/4" hole f/10,550' MD to 10,694' MD 3800'TVD ADT-1.96 hrs. Footage-144' ECD-11.45 ppg WOB 2/4 k RPM 120 GPM 248 @ 2200 psi w/38% FO String wt. PU 117 SO 39 ROT 79 Torque on/off btm.-8/6-7 k ft/lbs Total bit hrs. 57.41 hrs Total jar hrs. 110.03 hrs. Max gas-645 units 18:00 00:00 6.00 10,694 10,970 PROD1 DRILL DDRL P Drilled 6 3/4" hole f/10,694' MD to 10,970' MD 3796'TVD ADT-4.70 hrs. Footage-276' ECD-11.55 ppg WOB 3/10 k RPM 120 GPM 250 @ 2200 psi w/38%FO String wt. PU 120 SO 36 ROT 78 Torque on/off btm.-9/6.5 k ft/lbs Total bit hrs. 62.11 hrs Total jar hrs. 114.73 hrs. Max gas-761 units SPR's 10883' MD 3797'TVD @ 2200 hrs #1 20 spm @ 600 psi 30 spm @ 800 psi #2 20 spm @ 600 psi 30 spm @ 850 psi OA=180 psi 03/19/2015 Directional drill production section as per plan f/10970'to 12270' MD. BROOH f/12270'MD t/12021' MD. 00:00 06:00 6.00 10,970 11,349 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/ 10970'to 11,349' MD 3787'TVD ADT-4.72 hrs Footage-379' ECD -11.6 ppg WOB 3/5 k RPM 120 GPM 250 @ 2225 psi w/39% FO String wt. PU 121 SO 0 ROT 78 Torque on/off btm.-9.5/7 k ft/lbs Total bit hrs-66.83 hrs Total jar hrs. 119.45 hrs Max. gas-773 units Page 27 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 11,349 11,734 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/11,349'to 11,734' MD 3785'TVD ADT-4.82 hrs Footage-385' ECD - 11.83 ppg WOB 3/5 k RPM 120 GPM 250 @ 2350 psi String wt PU 120 SO 0 ROT 79 Torque on/off btm.-7.5/6 k ft/lbs Total bit hrs. 71,65 hrs Total jar hrs. 124.27 hrs Max. gas 889 units SPR's 11,400' MD 3787'TVD @ 0630 hrs #1 20 spm @ 650 psi 30 spm @ 875 psi #2 20 spm @ 675 psi 30 spm @ 900 psi 12:00 18:00 6.00 11,734 12,018 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/11,734'to 12,018' MD 3791'TVD ADT-4.49 hrs Footage-284' ECD - 11.76 ppg WOB 2/4 k RPM 120 GPM 250 @ 2395 psi String wt PU 119 SO 0 ROT 76 Torque on/off btm.-8/6-7 k ft/lbs Total bit hrs. 76.14 hrs Total jar hrs. 128.76 hrs Max. gas 945 units 18:00 22:30 4.50 12,018 12,270 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/12,018'to i 12,270' MD 3797'TVD ADT-4.22 hrs Footage-252' ECD - 11.87 ppg WOB 4/6 k RPM 120 GPM 250 @ 2400 psi String wt PU 125 SO 0 ROT 80 Torque on/off btm.-8/7 k ft/lbs Total bit hrs. 80.36 hrs Total jar hrs. 132.98 hrs Max. gas 462 units SPR's 12,019' MD 3792'TVD @ 1845 hrs #1 20 spm @ 690 psi 30 spm @ 920 psi #2 20 spm @ 700 psi 30 spm @ 950 psi 22:30 23:00 0.50 12,270 12,208 PROD1 CASING CIRC P Circ.to clear cuttings past BHA. Establish SPR's and perform survey. BROOH f/12270 MD t/12208' MD. SPR's 12,270' MD 3797'TVD @ 2230 hrs #1 20 spm @ 750 psi 30 spm @ 1000 psi #2 20 spm @ 760 psi 30 spm @ 1000 psi Page 28 of 35 Time Logs 40 Date From To Dur S. Depth E. Depth'Phase Code Subcode T Comment 23:00 23:15 0.25 12,208 12,208 PROD1 CASING OWFF P Monitor well 23:15 00:00 0.75 12,208 12,021 PROD1 CASING BKRM P BROOH f/12208'MD t/12021'MD. 300-400 FPH. 250 gpm,2424 psi, 110 rpm,Tq 7K, PU 125K, SO OK, Rot 80K. ECD=11.79 OA=160 psi. 03/20/2015 Cont. BROOH f/12,021'MD to 6565'MD-Circ 3 x btms up @ 7/58"shoe-made 290 bbls dilution-Monitor well-RIH f/6565'MD t/10980'MD.Wash and ream f/10980't/12270'MD. Circ @ 12270'MD 00:00 12:00 12.00 12,021 6,565 PROD1 CASING BKRM P BROOH f/12,021'to 6565'@ 250 gpm @ 2300 psi w/80 rpm's w/7 k torque-ECD 11.77 ppg-Rotating wt. 80 k Calc hole fill-32.4 bbls-Actual hole fill 91 bbls 12:00 14:00 2.00 6,565 6,565 PROD1 CASING CIRC P Circ 3 X btms up @ 250 gpm, 1800 psi w/38%FO-40 rpm's w/3 k torque-performed 290 bbls whole mud dilution 14:00 14:45 0.75 6,565 6,627 PROD1 CASING OWFF P Blow down TD-Monitor well for 30 mins.(slight ooz)gained 1/2 bbls in 15 mins. -No gain last 15 mins 14:45 20:00 5.25 6,627 10,980 PROD1 CASING WPRT P RIH f/6627'MD t/10980'MD. Fill every 20 stds. Lost slack off wt. @ 10980' MD. 20:00 22:45 2.75 10,980 12,270 PROD1 CASING REAM P Wash and ream f/10980'MD t/12270' MD. 100 gpm, 800 psi,Tq 6-8K 28% FO 22:45 00:00 1.25 12,270 12,270 PROD1 CASING CIRC P Circ.to obtain acceptable PST @ 240 gpm, 2240 psi w/41%FO-80 rpm's w/8 k torque-performed 390 bbls whole mud dilution. OA=215 psi 03/21/2015 Circ&perform whole mud dilution(310 bbls)-Monitor well static POOH w/pump f/12,210'to 2566' MD. Attempt to pull on elevators @ 9940'MD, 8804'MD, 7480'MD,6627'MD and 3510'MD 00:00 02:30 2.50 12,270 12,270 PROD1 CASING CIRC P Cont. circ @ TD 2 250 gpm @ 2200 psi w/80 rpm w/8 k torque-40% FO-Perform 310 bbl whole mud dilution-Ran PST-solids @ 1.5% 02:30 03:00 0.50 12,270 12,176 PROD1 CASING CIRC P Obtain SPR's 12,270' MD 3797'TVD w/9.4+ppg mud wt @ 0230 hrs.- Std back 1 std DP to 12,176'-Blow down TD SPR's 12,270'MD 3797'TVD @ 0230 hrs #1 20 spm @ 675 psi 30 spm @ 900 psi #2 20 spm @ 675 psi 30 spm @ 900 psi 03:00 04:30 1.50 12,176 12,176 PROD1 CASINGOWFF P Monitor well-well static 04:30 04:45 0.25 12,176 12,080 PROD1 CASING TRIP P POOH on elevators f/12,176'to 12, 080'-Well swabbing Page 29 of 35 Time Logs 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 08:45 4.00 12,080 9,940 PROD1 CASING PMPO P POOH w/pump @ 2.5 bbls/min @ 700 psi f/12,210'to 9940'-PU wt 130 k 08:45 09:15 0.50 9,940 9,940 PROD1 CASING OWFF P Blow down TD-Monitior well(slight ooze)Attempt to Pull on elevators- well swabbing 09:15 11:15 2.00 9,940 8,835 PROD1 CASING PMPO P POOH w/pump @ 2.5 bbls/min @ 200 psi f/9940 to 8835' 11:15 11:45 0.50 8,835 8,835 PROD1 CASING OWFF P Blow down TD-Monitor well(static in 15 mins)-Attempt to pull on elevators-well swabbing 11:45 12:00 0.25 8,835 8,521 PROD1 CASING PMPO P POOH w/pump @ 2 bbls/min f/ 8835'to 8521'- Calc disp f/12270'to 8521=20 bbls. Act disp=36 bbls 12:00 14:15 2.25 8,521 7,480 PROD1 CASING PMPO P Con't to POOH w/pump f/8521'to 7480'. 100 gpm, 675 psi,24%FO. 14:15 14:30 0.25 7,480 7,480 PROD1 CASING OWFF P Blow down TD-Monitor well. Slight flow until static. 14:30 15:45 1.25 7,480 6,627 PROD1 CASING PMPO P Attempt to pull on elevators. Hole swabbing. POOH w/pump. f/7480' MD t/6627' MD. 100 gpm, 675 psi. 15:45 16:45 1.00 6,627 6,627 PROD1 CASING OWFF P Blow down TD-Monitor well until static. Drop 2.2"hollow drift. 16:45 17:00 0.25 6,627 6,343 PROD1 CASING TRIP P POOH on elevators f/6627' MD t/6343' MD. Hole swabbing. Monitor well. 17:00 00:00 7.00 6,343 2,660 PROD1 CASING PMPO P POOH w/pump @ 2 bbls/min f/ 6343' MD t/3510'MD. Pull one stand w/elevators. Improper hole fill observed. Con't to Pump OOH f/3510' MD t/2566'MD. 100 gpm, 315 psi. Calc disp for tour=32.94 bbls.Act disp=44.75 bbls D3/22/2015 Cont. POOH w/pump to 1809' MD.POOH without pump f/1809 t/390'MD. Monitor well. Lay do BHA. Clear rig floor. PU and stand back 55 jts HWDP. Flush BOPE. Pull wear bushing, set test plug.Test lower VBR's w/4 1/2"test jt. Set wear bushing.Rig up to run lower completion. PU 4 1/2"liner. Rig down 4 1/2"csg.equip. 00:00 01:15 1.25 2,566 1,714 PROD1 CASING PMPO P Cont. POOH w/pump f/2566'MD to 1809'-Pulled 1 std w/no pump to 1714'hole taking fluid-Blow down TD 01:15 02:30 1.25 1,714 390 PROD1 CASING TRIP P POOH on elevators f/1714'to 390'( top of BHA) 02:30 03:00 0.50 390 390 PROD1 CASING OWFF P Monitor well @ top of HWDP- (static) 03:00 03:15 0.25 390 390 PROD1 CASING SFTY P PJSM on LD BHA 03:15 04:45 1.50 390 0 PROD1 CASING BHAH P Pull&Std back HWDP 3 jts. HWDP-LD jars-PU 1 jt HWDP f/ shed to replace jars&std back remaining HWDP-LD NM flex DC's- LD MWD tools&power drive as per DD&MWD 04:45 05:30 0.75 0 0 PROD1 CASING BHAH P Clear rig floor of BHA tools&set mouse hole 05:30 07:30 2.00 0 0 COMPZ CASING PULD P PJSM-PU&std back 54 jts HWDP Page 30 of 35 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:30 08:45 1.25 0 0 COMPZ CASING WWWH P PJSM-MU stack washer&flush stack-RD washer 08:45 09:15 0.50 0 0 COMPZ CASING BOPE P Pull wear bushing-Set test plug w/ 4 1/2"test jt. 09:15 10:00 0.75 0 0 COMPZ CASING BOPE P RU&test lower VBR w/4 1/2"test jt to 250&3500 psi -Recorded on chart-RD 10:00 10:15 0.25 0 0 COMPZ CASING RURD P Pull test plug&set wear bushing 10:15 14:30 4.25 0 0 COMPZ CASING RURD P PJSM-PU casing tools&Baker equipment to rig floor SIMOPS-clean pits 14:30 23:30 9.00 0 5,796 COMPZ CASING PUTB P PJSM-PU 4 1/2"liner as per running order to 5796' MD. PU 81K, SO 63K Calc disp=25.65 bbls Act disp=19.74 23:30 00:00 0.50 5,796 5,796 COMPZ CASING RURD P Rig down 4 1/2"csg tools and equip. 03/23/2015 RU to run 2 7/8"Hyd 511 inner string-ran 196 jts 2 7/8"511 HYD inner string-Space out inner string. MU FLCV, SBE, liner hanger and liner top packer. Clear rig floor and prep to install super sliders. Brk circ. RIH w/ liner on DP to 8998' MD. 00:00 02:00 2.00 5,796 5,796 COMPZ CASING RURD P PJSM-RU to run 2 7/8"Hyd 511 inner string-MU safety valve-RU false table&Double stack tongs 02:00 11:45 9.75 5,796 5,796 COMPZ CASING PULD P PJSM-Ran 196 jts 2 7/8"6.4#Hyd. 511 inner string to 5726'-PU wt 60 SO wt 45-Calc disp. 13.4 bbls- Actual-8.6 bbls 11:45 13:00 1.25 5,796 5,796 COMPZ CASING HOSO P Fill pipe. Space out inner string.. Change out elevators. PU=60K S0=46K 13:00 15:15 2.25 5,796 5,878 COMPZ CASING OTHR P PJSM-MU FLCV, SBE, liner hanger, and liner top packer. Mix and pour pal mix.Allow to set up. PU=112K SO=80K 15:15 17:15 2.00 5,878 5,878 COMPZ CASING RURD P Rig down csg equip. Clear rig floor of csg and inner string tools. Stage WWT supersliders and tools on rig floor. 17:15 18:00 0.75 5,878 5,967 COMPZ CASING CIRC P Make up stand of DP. Break circ.2 bpm=650 psi, 15% FO. 3 bpm= 775 psi, 20% FO 18:00 00:00 6.00 5,967 8,998 COMPZ CASING RUNL P RIH w/liner on DP f/5967'MD t/8998' MD. Install supersliders midway on every jt. starting on std#3.S0=63K. Calc disp=16.2 bbls Act disp=12.6 OA=165 psi 03/24/2015 RIH w/liner on DP. Circ and cond mud. Mix hi-vis spacer. Displace w/Breakdown D breaker. Close WIV. Set and release from liner hanger. Set and test liner top packer. Pump remaining breaker.Monitor well. Clean shakers and trip tank. POOH shift FLCV closed. Displace well to 9.6 ppg brine. 00:00 05:15 5.25 8,998 12,245 COMPZ CASING RUNL P RIH w/liner on DP f/8998' MD t/12245' MD. Install supersliders midway on every jt. PU=155K .S0=40K. Calc disp=29.7 bbls Act disp=19 bbls Page 31 of 35 Time Logs 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 08:45 3.50 12,245 12,230 COMPZ CASING CIRC P PU to 12230'MD. Brk. circ @ 1.8 bpm/1000 psi. Circ and cond w/ mixing 100 bbl hi-vis 9.8 ppg brine spacer 08:45 12:00 3.25 12,230 12,230 COMPZ CASING DISP P Pump 100 bbls 9.8 ppg hi-vis brine spacer @ 1.9 bpm/1025 psi,followed with 248 bbls 9.8 ppg Breakdown D breaker. ICP=1000 psi @ 1.9 bpm. FCP=800 psi 2.5 bpm. No losses 12:00 12:45 0.75 12,230 12,230 COMPZ CASING CIRC P Drop 1 1/8"phenolic ball. Pump ball on seat w/78 bbls Breakdown D breaker. 2.5 bpm @ 500 psi. 12:45 13:00 0.25 12,230 12,230 COMPZ CASING PACK P Pressure up to 2500 psi close WIV.Con't to pressure up to 3000 psi, Slack to top drive wt.to set hanger. Pressure up to 4000 psi to release running tool.Bleed pressure to 0 psi. PU and confirm release. PU= 140K. PU additional 5'to expose dog sub. Rot 20 rpm, slack off and set liner top packer Rot=80K. Slack off to 35K setting ZXP packer w/45K down wt. 13:00 13:45 0.75 12,230 12,230 COMPZ CASING PRTS P Rig up and test liner top packer to 3500 psi/10 min 13:45 14:15 0.50 12,230 12,145 COMPZ WELLPF DISP P Lay down single DP. Pump 25 bbls Breaker D breaker followed with 50 bbls 9.6 ppg brine. 14:15 14:45 0.50 12,145 12,145 COMPZ WELLPF OWFF P Monitor well Static. Sim-ops-Clean under shakers and trip tank. 14:45 16:15 1.50 12,145 12,085 COMPZ WELLPF RURD P Lay do two jts HWDP. Clean under shakers and trip tank for TOH. 16:15 22:15 6.00 12,085 6,036 COMPZ WELLPF TRIP P POOH f/12085' MD t/6289' MD. Did not observe any over pull while pulling through FLCV. Monitor well. Con't POOH t/6036' MD. Remove all supersliders from DP. Calc disp=44.92 bbls Act disp=52.48 bbls. PU 55K. 22:15 22:30 0.25 6,036 6,383 COMPZ WELLPF TRIP P RIH t/6383'MD 22:30 00:00 1.50 6,383 6,383 COMPZ WELLPF DISP P Displace well to 9.6 ppg brine. 7 bpm, 175 psi.41%FO OA=225 psi 33/25/2015 Con't to displace well to 9.6 ppg brine. Monitor well. POOH. Lay down liner running tool. Lay down 2 7/8" inner string. Lay down DP from drillers side of derrick. Rig up Dutch riser. Rig up wireline and perform RCBL from 6331'to 4400'. 00:00 00:15 0.25 6,383 6,383 COMPZ WELLPF DISP P PJSM, Cont to displace well to 9.6 ppg brine, pump @ 7 bpm= 175 psi. Pumped 498 bbls, no losses observed. 00:15 01:00 0.75 6,383 6,383 COMPZ WELLPF OWFF P OWFF,static. SIMOPS, Hold PJSM for POOH L/D DP. 01:00 02:30 1.50 6,383 5,885 COMPZ WELLPF PULD P POOH L/D 4" DP from 6383'MD to 5885' MD, L/D Baker running tools. Page 32 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 09:00 6.50 5,885 0 COMPZ WELLPF PULD P PJSM, POOH L/D 2-7/8" Hyd 511 pipe f/5885' MD to surface. L/D B 1 shifting tool.Actual displacement= 31.7 bbls, Calculated displacement= 17 bbls, 09:00 10:00 1.00 0 0 COMPZ WELLPF RURD P Rig down casing equipment and clear rig floor. 10:00 14:45 4.75 0 0 COMPZ WELLPF PULD P PJSM-Lay down 60 jt's of HWDP and 45 jts DP from drillers side of derrick 14:45 16:15 1.50 0 COMPZ WELLPF ELOG T PJSM-Rig up and install Dutch riser 16:15 20:30 4.25 0 0 COMPZ WELLPF ELOG T PJSM-RU HES e-line, test cable head. MU tractor assy, MU RCBL tools and test connectivity. Failure on upper tractor electronics package. Change out package and retest good. 20:30 00:00 3.50 0 0 COMPZ WELLPF ELOG T RIH w/RCBL. Set down @ 5460'. PU and set down @ 5658'. Utilize tractor to RIH to 6331' Log f/6331' WLM t/4400'WLM Losses for tour=18 bbls. OA=125 psi. 03/26/2015 Rig down HES wireline and Dutch riser. Cut drlg line. Pull wear bushing. Wash out BOPE. Perform tbg hanger dummy run.Rig up to run upper completion. Run 4 1/2"IBTM upper completion to 6367'MD. Space out. MU hanger. Spot inhibited brine. OWFF. Land and test hanger. Test IA to 1000 psi. OWFF. Drop ball and rod. Test tbg to 3500 psi/30 min. Bleed to 2000 psi.Test IA to 3000 psi/30 min. Bleed tbg to 0 psi and shear SOV. 00:00 00:30 0.50 0 0 COMPZ WELLPF ELOG T Cont. POOH w/HES E-line RCBL tools. Log up from liner top ©6331' MD to 4400' MD. 00:30 02:00 1.50 0 0 COMPZ WELLPF ELOG T PJSM, Lay down HES logging tool and rig down E-line. 02:00 02:30 0.50 0 0 COMPZ WELLPF FLOG T Remove Dutch riser, SIMOPS, monitor well on trip tank.. Static loss 1-2 bph. 02:30 04:00 1.50 0 0 COMPZ RPCOM SLPC P PJSM, Slip and cut 75'of drilling line and service rig. 04:00 05:30 1.50 0 0 COMPZ RPCOM WWWH P Pull wear bushing. R/U and flush Vetco wellhead. R/D and blow down top drive. 05:30 06:30 1.00 0 0 COMPZ RPCOM RURD P Rig up and make dummy run with Vetco 06:30 07:30 1.00 0 0 COMPZ RPCOM RURD P Clear rig floor. Rig up to run upper completion 07:30 08:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM on running upper completion 08:00 08:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig 08:30 09:00 0.50 0 0 COMPZ RPCOM WAIT T Wait on replacement 4 1/2"YC elevator setting plate. 09:00 15:15 6.25 0 6,367 COMPZ RPCOM PUTB P PU and RIH 4 1/2" 12.6# IBTM L-80 upper completion as per running order to 6367'MD. Calc disp=42.7 bbls Act disp=21.85 bbls. Page 33 of 35 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T _ Comment 15:15 17:00 1.75 6,367 6,367 COMPZ RPCOM HOSO P Make up circ equip. RIH circulating @ 1 bpm to confirm seal entry and tag no-go @ 6372'MD. Lay down 4 jts tbg and make up space out pup jts. (2.06', 7.81', 9.80 and 9.82')PU 2 jts tbg. 17:00 17:30 0.50 6,367 6,367 COMPZ RPCOM THGR P MU tbg hanger and landing jt. Install dummy penetrator. MU circ equip. 17:30 18:45 1.25 6,367 6,367 COMPZ RPCOM CRIH P PJSM-Pump 130 bbls 9.6 ppg inhibited brine followed by 50 bbls 9.6 ppg uninhibited brine down tbg.4 bpm, 300 psi. 35%FO 18:45 19:15 0.50 6,367 6,367 COMPZ RPCOM OWFF P Monitor well. Static 19:15 19:30 0.25 6,367 6,367 COMPZ RPCOM RURD P Drain BOPE. Blow down kill and choke lines 19:30 21:45 2.25 6,367 6,406 COMPZ RPCOM THGR P Land hanger. RILDS. Test upper an lower hanger seals to 5000 psi/15 min. Chart test. WLEG set at 6406'MD. 21:45 22:00 0.25 6,406 6,406 COMPZ RPCOM PRTS P PJSM-Test IA to 1000 psi/10 min on chart to confirm seal placement. 22:00 22:30 0.50 6,406 6,406 COMPZ RPCOM OWFF P Observe well. Slight loss 22:30 22:45 0.25 6,406 6,406 COMPZ RPCOM PRTS P Drop ball and rod. Sim-ops Conduct PJSM on testing tbg and annulus. 22:45 00:00 1.25 6,406 6,406 COMPZ RPCOM PRTS P Test tbg to 3500 psi/30 min. Bleed tbg down to 2000 psi. Test IA to 3000 psi/30 min.All tests charted. Bleed tbg to 0 psi and shear SOV. OA=100 psi. 03/27/2015 Set TWC.Clean and inspect BOPE. ND BOPE. NU adapter and tree.Test adapter. Erect scaffold in cellar. Test tree. Pull TWC.Rig up lines and freeze protect well. Rig up lubricator and set BPV. Lay down DP. 00:00 00:30 0.50 6,406 0 COMPZ RPCOM RURD P Rig down testing equipment and LID landing joint. 00:30 01:00 0.50 0 0 COMPZ WHDBO MPSP P R/U and set TWC, Test TWC to 2000 psi from below on chart,good. 01:00 01:30 0.50 0 0 COMPZ WHDBO OWFF P Monitor well. Static 01:30 02:15 0.75 0 0 COMPZ WHDBO OTHR P Rig down circ lines. 02:15 06:30 4.25 0 0 COMPZ WHDBO OTHR P PJSm-Open, clean and inspect all BOPE rams and doors. Sim-ops/ Flush mud pumps and lines with fresh water. Clean pits. Prep mud pumps for rig move. 06:30 07:30 1.00 0 0 COMPZ WHDBO NUND P PJSM-ND BOPE 07:30 11:30 4.00 0 0 COMPZ WHDBO NUND P Dress wellhead. NU tree. Orient valves. Install SSV and pump in flange 11:30 11:45 0.25 0 0 COMPZ WHDBO PRTS P Test adapter flange to 5000 psi/10 min.. Good test. 11:45 13:30 1.75 0 0 COMPZ WHDBO OTHR P Erect scaffold in cellar. 13:30 14:15 0.75 0 0 COMPZ WHDBO PRTS P RU and test tree to 5000 psi/10 min. Good test. 14:15 15:15 1.00 0 0 COMPZ WHDBO MPSP P PJSM-RU and pull TWC as per Vetco Gray rep. Page 34 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:15 1.00 0 0 COMPZ WHDBO FRZP P Rig up lines to freeze protect well. Test lines to 2000 psi. Pump 90 bbls diesel freeze protect down IA taking returns from tbg. 2 bpm ICP=800 psi FCP=1150 psi. 16:15 17:30 1.25 0 0 COMPZ WHDBO FRZP P Blow down hoses. Line up and U-tube diesel freeze protect. Sim-ops/RU to lay down DP. 17:30 18:15 0.75 0 0 COMPZ WHDBO FRZP P PJSM-Blow down and rig down freeze protect and u-tube lines. Install blanking flanges on tbg and IA valves. Secure tree. 18:15 19:30 1.25 0 0 COMPZ WHDBO MPSP P RU Vetco Gray lubricator and test to 1000 psi. Set BPV. RD lubricator. Tbg press= 150 psi IA press=150 psi 19:30 20:00 0.50 0 0 DEMOB MOVE PULD P PJSM-Lay down 11 std of DP out of derrick. 20:00 20:30 0.50 0 0 DEMOB MOVE SVRG P Service rig 20:30 00:00 3.50 0 0 DEMOB MOVE PULD P Lay down 65 stds DP out of derrick. Release rig @ 00:00 hrs 3-28-15 Page 35 of 35 • • NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-142 Definitive Survey Report 24 March, 2015 • SchlumbergerII Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1D-142 Well Position +N/-S 0.00 usft Northing: 5,959,414.03 usft Latitude: 70°17'58.836 N +E/-W 0.00 usft Easting: 560,670.75 usft Longitude: 149°30'31.101 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 66.80 usft Wellbore` 1D-142 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/20/2015 19.07 80.92 57,570 'Resign 1D-142 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From(ND) +N/-S +E/-W ' r. '� : ' ' (usft) (usft) (usft) 7 "" 27.42 0.00 0.00 125.00 Survey Program Date �� il (; From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 74.73 339.23 1D-142 Svy1 -SLB_GYRO-MWD(1D-14 GYD-GC-SS Gyrodata gyro single shots 2/27/2015 5:1: 428.94 2,591.09 1D-142 Svy2-SLB_MWD+GMAG(1D-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/27/2015 5:1, 2,688.47 6,599.87 1D-142 Svy3 SLB_MWD+GMAG(1D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7.3: 6,695.17 12,209.20 1D-142 Svy4 SLB_MWD+GMAC(1D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7:3, Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.42 0.00 0.00 27.42 -66.80 0.00 0.00 5,959,414.03 560,670.75 0.00 0.00 UNDEFINED 74.73 0.06 196.20 74.73 -19.49 -0.02 -0.01 5,959,414.01 560,670.74 0.13 0.01 GYD-GC-SS(1) 107.77 0.19 126.26 107.77 13.55 -0.07 0.03 5,959,413.96 560,670.78 0.54 0.07 GYD-GC-SS(1) 161.09 0.26 195.74 161.09 66.87 -0.24 0.07 5,959,413.79 560,670.82 0.49 0.20 GYD-GC-SS(1) 251.60 0.21 175.02 251.60 157.38 -0.60 0.03 5,959,413.43 560,670.78 0.11 0.37 GYD-GC-SS(1) 339.23 0.34 167.54 339.23 245.01 -1.02 0.10 5,959,413.01 560,670.86 0.15 0.67 GYD-GC-SS(1) 428.94 0.06 156.04 428.94 334.72 -1.32 0.18 5,959,412.71 560,670.94 0.31 0.90 MWD+IFR-AK-CAZ-SC(2) 522.74 0.40 172.34 522.74 428.52 -1.69 0.24 5,959,412.34 560,671.00 0.37 1.17 MWD+IFR-AK-CAZ-SC(2) 613.99 1.06 109.93 613.98 519.76 -2.29 1.08 5,959,411.74 560,671.84 1.03 2.20 MWD+IFR-AK-CAZ-SC(2) 706.73 1.48 101.71 706.70 612.48 -2.83 3.05 5,959,411.23 560,673.83 0.49 4.13 MWD+IFR-AK-CAZ-SC(2) 799.48 2.69 94.30 799.38 705.16 -3.24 6.40 5,959,410.85 560,677.17 1.33 7.10 MWD+IFR-AK-CAZ-SC(2) 894.91 4.58 79.66 894.62 800.40 -2.72 12.38 5,959,411.41 560,683.15 2.19 11.70 MWD+IFR-AK-CAZ-SC(2) 989.33 7.83 72.42 988.47 894.25 -0.10 22.22 5,959,414.11 560,692.97 3.53 18.26 MWD+IFR-AK-CAZ-SC(2) 1,081.95 8.43 73.39 1,080.16 985.94 3.75 34.74 5,959,418.06 560,705.46 0.66 26.31 MWD+IFR-AK-CAZ-SC(2) 1,177.40 10.81 74.31 1,174.26 1,080.04 8.17 50.07 5,959,422.60 560,720.74 2.50 36.33 MWD+IFR-AK-CAZ-SC(2) 3/24/2015 2:34:57PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 10-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,270.49 13.75 74.96 1,265.21 1,170.99 13.40 69.16 5,959,427.99 560,739.79 3.16 48.97 MWD+IFR-AK-CAZ-SC(2) 1,364.11 16.14 73.47 1,355.66 1,261.44 19.99 92.38 5,959,434.76 560,762.96 2.59 64.21 MWD+IFR-AK-CAZ-SC(2) 1,457.17 18.33 69.91 1,444.54 1,350.32 28.70 118.53 5,959,443.68 560,789.03 2.61 80.63 MWD+IFR-AK-CAZ-SC(2) 1,548.95 20.73 67.63 1,531.03 1,436.81 39.84 147.11 5,959,455.05 560,817.52 2.74 97.65 MWD+IFR-AK-CAZ-SC(2) 1,642.01 23.10 66.62 1,617.36 1,523.14 53.35 179.10 5,959,468.82 560,849.40 2.58 116.11 MWD+IFR-AK-CAZ-SC(2) 1,736.27 22.91 66.99 1,704.13 1,609.91 67.86 212.96 5,959,483.60 560,883.14 0.25 135.52 MWD+IFR-AK-CAZ-SC(2) 1,828.13 26.35 61.61 1,787.63 1,693.41 84.55 247.37 5,959,500.57 560,917.40 4.47 154.13 MWD+IFR-AK-CAZ-SC(2) 1,920.43 29.68 57.66 1,869.11 1,774.89 106.52 284.71 5,959,522.84 560,954.56 4.13 172.12 MWD+IFR-AK-CAZ-SC(2) 2,014.42 35.73 55.60 1,948.16 1,853.94 134.50 327.05 5,959,551.16 560,996.68 6.54 190.76 MWD+IFR-AK-CAZ-SC(2) 2,106.07 42.92 54.39 2,019.02 1,924.80 167.84 374.57 5,959,584.87 561,043.91 7.89 210.56 MWD+IFR-AK-CAZ-SC(2) 2,198.32 47.76 54.81 2,083.84 1,989.62 205.83 428.04 5,959,623.29 561,097.08 5.26 232.57 MWD+IFR-AK-CAZ-SC(2) 2,291.89 53.05 55.69 2,143.46 2,049.24 246.89 487.27 5,959,664.83 561,155.97 5.70 257.54 MWD+IFR-AK-CAZ-SC(2) 2,386.29 56.06 56.29 2,198.19 2,103.97 289.90 551.02 5,959,708.34 561,219.36 3.23 285.09 MWD+IFR-AK-CAZ-SC(2) 2,479.38 63.07 55.99 2,245.32 2,151.10 334.60 617.63 5,959,753.57 561,285.59 7.54 314.01 MWD+IFR-AK-CAZ-SC(2) 2,572.74 62.63 53.83 2,287.93 2,193.71 382.34 685.60 5,959,801.86 561,353.17 2.11 342.30 MWD+IFR-AK-CAZ-SC(2) 2,591.09 62.42 55.12 2,296.39 2,202.17 391.80 698.85 5,959,811.43 561,366.34 6.34 347.73 MWD+IFR-AK-CAZ-SC(2) 2,662.00 61.93 55.01 2,329.49 2,235.27 427.72 750.26 5,959,847.75 561,417.46 0.70 369.25 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,688.47 61.75 54.97 2,341.98 2,247.76 441.10 769.37 5,959,861.29 561,436.46 0.70 377.22 MWD+IFR-AK-CAZ-SC(3) 2,762.08 62.12 58.16 2,376.62 2,282.40 476.88 823.57 5,959,897.50 561,490.36 3.86 401.10 MWD+IFR-AK-CAZ-SC(3) 2,809.05 62.24 57.93 2,398.54 2,304.32 498.87 858.81 5,959,919.77 561,525.43 0.50 417.36 MWD+IFR-AK-CAZ-SC(3) 2,903.47 62.70 57.63 2,442.18 2,347.96 543.51 929.65 5,959,964.98 561,595.89 0.56 449.78 MWD+IFR-AK-CAZ-SC(3) 2,996.56 62.66 56.62 2,484.91 2,390.69 588.40 999.11 5,960,010.42 561,664.98 0.96 480.93 MWD+IFR-AK-CAZ-SC(3) 3,088.69 62.83 54.98 2,527.10 2,432.88 634.44 1,066.84 5,960,057.00 561,732.34 1.59 510.01 MWD+IFR-AK-CAZ-SC(3) 3,183.85 62.62 54.40 2,570.71 2,476.49 683.33 1,135.86 5,960,106.44 561,800.95 0.58 538.51 MWD+IFR-AK-CAZ-SC(3) 3,277.65 62.75 54.60 2,613.75 2,519.53 731.72 1,203.71 5,960,155.38 561,868.40 0.23 566.33 MWD+IFR-AK-CAZ-SC(3) 3,370.92 62.75 53.82 2,656.46 2,562.24 780.21 1,270.97 5,960,204.40 561,935.26 0.74 593.61 MWD+IFR-AK-CAZ-SC(3) 3,465.05 62.76 52.76 2,699.55 2,605.33 830.24 1,338.06 5,960,254.96 562,001.94 1.00 619.87 MWD+IFR-AK-CAZ-SC(3) 3,557.55 62.79 52.53 2,741.87 2,647.65 880.14 1,403.44 5,960,305.39 562,066.91 0.22 644.80 MWD+IFR-AK-CAZ-SC(3) 3,650.50 62.65 53.37 2,784.47 2,690.25 929.92 1,469.38 5,960,355.69 562,132.43 0.82 670.26 MWD+IFR-AK-CAZ-SC(3) 3,744.05 62.68 54.53 2,827.43 2,733.21 978.82 1,536.56 5,960,405.13 562,199.21 1.10 697.25 MWD+IFR-AK-CAZ-SC(3) 3,836.00 62.79 54.42 2,869.56 2,775.34 1,026.32 1,603.08 5,960,453.16 562,265.34 0.16 724.50 MWD+IFR-AK-CAZ-SC(3) 3,929.48 63.01 54.93 2,912.14 2,817.92 1,074.43 1,670.98 5,960,501.81 562,332.84 0.54 752.52 MWD+IFR-AK-CAZ-SC(3) 4,021.91 63.09 54.78 2,954.03 2,859.81 1,121.86 1,738.35 5,960,549.78 562,399.82 0.17 780.50 MWD+IFR-AK-CAZ-SC(3) 4,114.75 64.06 54.20 2,995.35 2,901.13 1,170.15 1,806.03 5,960,598.61 562,467.10 1.19 808.24 MWD+IFR-AK-CAZ-SC(3) 4,207.54 63.74 54.02 3,036.17 2,941.95 1,219.00 1,873.53 5,960,648.00 562,534.20 0.39 835.52 MWD+IFR-AK-CAZ-SC(3) 4,299.13 64.01 53.94 3,076.50 2,982.28 1,267.36 1,940.04 5,960,696.89 562,600.31 0.31 862.26 MWD+IFR-AK-CAZ-SC(3) 4,393.83 63.93 55.01 3,118.06 3,023.84 1,316.80 2,009.30 5,960,746.89 562,669.16 1.02 890.63 MWD+IFR-AK-CAZ-SC(3) 4,487.00 64.17 57.95 3,158.83 3,064.61 1,363.06 2,079.13 5,960,793.70 562,738.61 2.85 921.31 MWD+IFR-AK-CAZ-SC(3) 4,581.12 65.37 62.47 3,198.97 3,104.75 1,405.33 2,153.00 5,960,836.56 562,812.13 4.53 957.57 MWD+IFR-AK-CAZ-SC(3) 4,675.15 66.22 67.26 3,237.54 3,143.32 1,441.73 2,230.62 5,960,873.58 562,889.44 4.73 1,000.27 MWD+IFR-AK-CAZ-SC(3) 4,718.78 66.37 69.85 3,255.08 3,160.86 1,456.34 2,267.80 5,960,888.49 562,926.50 5.45 1,022.35 MWD+IFR-AK-CAZ-SC(3) 4,768.05 66.51 71.61 3,274.78 3,180.56 1,471.24 2,310.43 5,960,903.73 562,969.00 3.29 1,048.72 MWD+IFR-AK-CAZ-SC(3) 4,860.41 67.41 71.98 3,310.93 3,216.71 1,497.79 2,391.17 5,960,930.93 563,049.52 1.04 1,099.63 MWD+IFR-AK-CAZ-SC(3) 3/24/2015 2:34:57PM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,953.04 68.52 71.70 3,345.68 3,251.46 1,524.55 2,472.75 5,960,958.35 563,130.88 1.23 1,151.11 MWD+IFR-AK-CAZ-SC(3) 5,047.41 68.63 71.61 3,380.15 3,285.93 1,552.20 2,556.14 5,960,986.67 563,214.03 0.15 1,203.56 MWD+IFR-AK-CAZ-SC(3) 5,139.93 68.54 74.60 3,413.94 3,319.72 1,577.23 2,638.54 5,961,012.36 563,296.22 3.01 1,256.70 MWD+IFR-AK-CAZ-SC(3) 5,234.19 68.68 78.25 3,448.33 3,354.11 1,597.83 2,723.84 5,961,033.64 563,381.34 3.61 1,314.76 MWD+IF R-AK-CAZ-SC(3) 5,327.71 69.44 83.19 3,481.77 3,387.55 1,611.90 2,810.00 5,961,048.40 563,467.38 5.00 1,377.28 MWD+IFR-AK-CAZ-SC(3) 5,420.25 69.92 88.02 3,513.92 3,419.70 1,618.54 2,896.50 5,961,055.74 563,553.81 4.92 1,444.32 MWD+I F R-AK-CAZ-SC(3) 5,512.79 70.30 91.53 3,545.41 3,451.19 1,618.88 2,983.50 5,961,056.78 563,640.80 3.59 1,515.39 MWD+IF R-AK-CAZ-SC(3) 5,606.16 71.30 97.00 3,576.14 3,481.92 1,612.31 3,071.39 5,961,050.93 563,728.73 5.63 1,591.15 MWD+IFR-AK-CAZ-SC(3) 5,699.12 71.51 101.39 3,605.79 3,511.57 1,598.23 3,158.34 5,961,037.55 563,815.78 4.48 1,670.45 MWD+IF R-AK-CAZ-SC(3) 5,791.44 71.98 106.92 3,634.73 3,540.51 1,576.80 3,243.31 5,961,016.81 563,900.91 5.71 1,752.35 MWD+IFR-AK-CAZ-SC(3) 5,883.60 72.55 110.49 3,662.81 3,568.59 1,548.65 3,326.44 5,960,989.33 563,984.26 3.74 1,836.59 MWD+IFR-AK-CAZ-SC(3) 5,976.54 74.09 114.87 3,689.50 3,595.28 1,514.32 3,408.55 5,960,955.67 564,066.64 4.81 1,923.54 MWD+IFR-AK-CAZ-SC(3) 6,069.65 75.98 119.24 3,713.55 3,619.33 1,473.40 3,488.63 5,960,915.41 564,147.03 4.97 2,012.61 MWD+IFR-AK-CAZ-SC(3) 6,118.45 77.07 122.60 3,724.93 3,630.71 1,449.02 3,529.33 5,960,891.35 564,187.93 7.06 2,059.93 MWD+IFR-AK-CAZ-SC(3) 6,164.32 78.17 125.54 3,734.77 3,640.55 1,423.92 3,566.44 5,960,866.56 564,225.23 6.70 2,104.73 MWD+IFR-AK-CAZ-SC(3) 6,214.72 79.80 127.69 3,744.40 3,650.18 1,394.41 3,606.14 5,960,837.38 564,265.17 5.29 2,154.17 MWD+IFR-AK-CAZ-SC(3) 6,256.69 80.69 130.27 3,751.51 3,657.29 1,368.40 3,638.29 5,960,811.62 564,297.53 6.42 2,195.43 MWD+IF R-AK-CAZ-SC(3) 6,302.09 81.69 132.29 3,758.46 3,664.24 1,338.80 3,672.00 5,960,782.30 564,331.47 4.92 2,240.02 MWD+IFR-AK-CAZ-SC(3) 6,351.73 82.45 135.06 3,765.31 3,671.09 1,304.85 3,707.56 5,960,748.64 564,367.30 5.73 2,288.62 MWD+IFR-AK-CAZ-SC(3) 6,397.10 83.04 137.84 3,771.04 3,676.82 1,272.23 3,738.56 5,960,716.28 564,398.56 6.22 2,332.73 MWD+IFR-AK-CAZ-SC(3) 6,445.15 83.65 140.31 3,776.61 3,682.39 1,236.18 3,769.82 5,960,680.48 564,430.11 5.26 2,379.02 MWD+IFR-AK-CAZ-SC(3) 6,494.14 84.05 142.76 3,781.86 3,687.64 1,198.04 3,800.12 5,960,642.60 564,460.71 5.04 2,425.71 MWD+IFR-AK-CAZ-SC(3) 6,537.57 84.03 145.24 3,786.37 3,692.15 1,163.10 3,825.51 5,960,607.86 564,486.38 5.68 2,466.55 MWD+IF R-AK-CAZ-SC(3) 6,599.87 85.49 147.77 3,792.06 3,697.84 1,111.37 3,859.74 5,960,556.41 564,521.02 4.67 2,524.26 MWD+IF R-AK-CAZ-SC(3) , 6,655.00 85.25 147.46 3,796.51 3,702.29 1,064.96 3,889.17 5,960,510.25 564,550.82 0.70 2,574.98 MWD+IFR-AK-CAZ-SC(4)f 7-5/8"x 9-7/8" 6,695.17 85.08 147.24 3,799.90 3,705.68 1,031.26 3,910.76 5,960,476.73 564,572.69 0.70 2,612.00 MWD+IF R-AK-CAZ-SC(4) 6,754.31 85.66 146.89 3,804.67 3,710.45 981.79 3,942.81 5,960,427.52 564,605.13 1.14 2,666.63 MWD+IF R-AK-CAZ-SC(4) 6,851.27 88.64 146.37 3,809.49 3,715.27 900.92 3,996.07 5,960,347.10 564,659.04 3.12 2,756.64 MWD+IFR-AK-CAZ-SC(4) 6,943.13 90.15 145.85 3,810.46 3,716.24 824.67 4,047.29 5,960,271.27 564,710.86 1.74 2,842.33 MWD+IFR-AK-CAZ-SC(4) 7,039.32 90.48 147.09 3,809.93 3,715.71 744.49 4,100.42 5,960,191.53 564,764.63 1.33 2,931.84 MWD+IFR-AK-CAZ-SC(4) 7,132.51 90.51 147.42 3,809.13 3,714.91 666.11 4,150.82 5,960,113.57 564,815.66 0.36 3,018.09 M WD+IF R-AK-CAZ-SC(4) 7,230.39 90.68 148.68 3,808.11 3,713.89 583.07 4,202.62 5,960,030.95 564,868.12 1.30 3,108.15 MWD+IF R-AK-CAZ-SC(4) 7,320.99 90.38 150.62 3,807.27 3,713.05 504.89 4,248.39 5,959,953.15 564,914.52 2.17 3,190.48 MWD+IFR-AK-CAZ-SC(4) 7,415.38 89.14 150.76 3,807.67 3,713.45 422.59 4,294.60 5,959,871.23 564,961.38 1.32 3,275.54 MWD+IFR-AK-CAZ-SC(4) 7,509.25 88.73 150.35 3,809.41 3,715.19 340.86 4,340.73 5,959,789.89 565,008.17 0.62 3,360.21 MWD+IFR-AK-CAZ-SC(4) 7,602.31 88.14 150.88 3,811.95 3,717.73 259.80 4,386.38 5,959,709.21 565,054.47 0.85 3,444.10 MWD+IFR-AK-CAZ-SC(4) 7,697.82 88.73 151.44 3,814.56 3,720.34 176.17 4,432.43 5,959,625.96 565,101.19 0.85 3,529.79 MWD+IFR-AK-CAZ-SC(4) 7,792.96 89.22 152.58 3,816.26 3,722.04 92.17 4,477.07 5,959,542.34 565,146.51 1.30 3,614.54 MWD+I F R-AK-CAZ-SC(4) 7,888.38 88.49 153.52 3,818.17 3,723.95 7.13 4,520.31 5,959,457.66 565,190.42 1.25 3,698.73 MWD+IFR-AK-CAZ-SC(4) 7,983.38 88.35 152.94 3,820.79 3,726.57 -77.65 4,563.08 5,959,373.23 565,233.87 0.63 3,782.40 MWD+IFR-AK-CAZ-SC(4) 8,077.59 88.42 150.04 3,823.44 3,729.22 -160.40 4,608.03 5,959,290.86 565,279.48 3.08 3,866.67 MWD+IFR-AK-CAZ-SC(4) 8,173.43 88.25 148.04 3,826.23 3,732.01 -242.54 4,657.31 5,959,209.12 565,329.42 2.09 3,954.16 MWD+IFR-AK-CAZ-SC(4) 8,268.86 88.49 148.48 3,828.94 3,734.72 -323.67 4,707.49 5,959,128.41 565,380.25 0.53 4,041.80 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:34:57PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1 D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 wrmnmrw aiwMnuwnaMIM, Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,363.21 89.28 150.55 3,830.78 3,736.56 -404.95 4,755.34 5,959,047.52 565,428.75 2.35 4,127.62 MWD+IFR-AK-CAZ-SC(4) 8,455.43 89.69 150.67 3,831.61 3,737.39 -485.30 4,800.60 5,958,967.55 565,474.65 0.46 4,210.78 MWD+IFR-AK-CAZ-SC(4) 8,547.63 89.66 150.69 3,832.13 3,737.91 -565.69 4,845.75 5,958,887.53 565,520.44 0.04 4,293.87 MWD+IFR-AK-CAZ-SC(4) 8,644.41 89.66 153.13 3,832.71 3,738.49 -651.06 4,891.31 5,958,802.54 565,566.69 2.52 4,380.16 MWD+IFR-AK-CAZ-SC(4) 8,740.54 89.79 153.46 3,833.17 3,738.95 -736.94 4,934.51 5,958,717.03 565,610.58 0.37 4,464.80 MWD+IFR-AK-CAZ-SC(4) 8,833.16 89.62 155.82 3,833.65 3,739.43 -820.62 4,974.18 5,958,633.67 565,650.91 2.55 4,545.30 MWD+IFR-AK-CAZ-SC(4) 8,929.57 89.21 158.62 3,834.63 3,740.41 -909.50 5,011.50 5,958,545.11 565,688.95 2.94 4,626.85 MWD+IFR-AK-CAZ-SC(4) 9,019.88 89.31 158.80 3,835.80 3,741.58 -993.64 5,044.29 5,958,461.24 565,722.41 0.23 4,701.97 MWD+IFR-AK-CAZ-SC(4) 9,118.37 89.72 159.50 3,836.63 3,742.41 -1,085.68 5,079.34 5,958,369.50 565,758.21 0.82 4,783.47 MWD+IFR-AK-CAZ-SC(4) 9,213.31 90.99 159.52 3,836.04 3,741.82 -1,174.61 5,112.58 5,958,280.85 565,792.15 1.34 4,861.70 MWD+IFR-AK-CAZ-SC(4) 9,307.87 92.24 160.30 3,833.38 3,739.16 -1,263.37 5,145.04 5,958,192.35 565,825.33 1.56 4,939.21 MWD+IFR-AK-CAZ-SC(4) 9,402.51 92.23 158.48 3,829.69 3,735.47 -1,351.89 5,178.33 5,958,104.12 565,859.33 1.92 5,017.25 MWD+I F R-AK-CAZ-SC(4) 9,496.69 92.50 160.45 3,825.80 3,731.58 -1,440.00 5,211.34 5,958,016.28 565,893.04 2.11 5,094.83 MWD+IFR-AK-CAZ-SC(4) 9,590.82 92.19 162.04 3,821.95 3,727.73 -1,529.06 5,241.57 5,957,927.49 565,924.00 1.72 5,170.68 MWD+IFR-AK-CAZ-SC(4) 9,686.29 91.92 163.97 3,818.52 3,724.30 -1,620.29 5,269.46 5,957,836.48 565,952.61 2.04 5,245.85 MWD+IFR-AK-CAZ-SC(4) 9,781.57 91.34 165.58 3,815.81 3,721.59 -1,712.19 5,294.47 5,957,744.80 565,978.36 1.80 5,319.05 MWD+IFR-AK-CAZ-SC(4) 9,877.24 91.20 166.90 3,813.69 3,719.47 -1,805.09 5,317.22 5,957,652.10 566,001.86 1.39 5,390.97 MWD+IFR-AK-CAZ-SC(4) 9,971.65 90.75 168.20 3,812.09 3,717.87 -1,897.26 5,337.57 5,957,560.10 566,022.95 1.46 5,460.51 MWD+IFR-AK-CAZ-SC(4) 10,066.29 90.72 171.24 3,810.87 3,716.65 -1,990.37 5,354.46 5,957,467.15 566,040.59 3.21 5,527.74 MWD+IFR-AK-CAZ-SC(4) 10,160.19 91.40 172.94 3,809.13 3,714.91 -2,083.35 5,367.38 5,957,374.28 566,054.26 1.95 5,591.66 MWD+IFR-AK-CAZ-SC(4) 10,255.10 91.03 176.02 3,807.12 3,712.90 -2,177.79 5,376.50 5,957,279.93 566,064.14 3.27 5,653.30 MWD+IFR-AK-CAZ-SC(4) 10,308.15 90.86 178.77 3,806.25 3,712.03 -2,230.77 5,378.91 5,957,226.97 566,066.98 5.19 5,685.67 MWD+IFR-AK-CAZ-SC(4) 10,349.01 90.86 179.29 3,805.63 3,711.41 -2,271.62 5,379.60 5,957,186.13 566,068.00 1.27 5,709.66 MWD+IFR-AK-CAZ-SC(4) 10,444.46 91.05 184.49 3,804.04 3,709.82 -2,366.97 5,376.46 5,957,090.77 566,065.63 5.45 5,761.78 MWD+IFR-AK-CAZ-SC(4) 10,490.22 91.69 187.38 3,802.95 3,708.73 -2,412.47 5,371.73 5,957,045.24 566,061.26 6.47 5,784.00 MWD+IFR-AK-CAZ-SC(4) 10,539.15 90.39 189.41 3,802.06 3,707.84 -2,460.86 5,364.59 5,956,996.79 566,054.51 4.93 5,805.91 MWD+IFR-AK-CAZ-SC(4) 10,634.95 90.09 189.84 3,801.66 3,707.44 -2,555.31 5,348.57 5,956,902.22 566,039.26 0.55 5,846.96 MWD+IFR-AK-CAZ-SC(4) 10,686.85 90.65 190.01 3,801.32 3,707.10 -2,606.44 5,339.62 5,956,851.04 566,030.73 1.13 5,868.95 MWD+IFR-AK-CAZ-SC(4) 10,729.46 90.96 189.98 3,800.72 3,706.50 -2,648.40 5,332.23 5,956,809.02 566,023.67 0.73 5,886.96 MWD+IFR-AK-CAZ-SC(4) 10,777.22 91.10 188.84 3,799.86 3,705.64 -2,695.50 5,324.42 5,956,761.86 566,016.25 2.40 5,907.59 MWD+IFR-AK-CAZ-SC(4) 10,823.57 91.27 187.66 3,798.91 3,704.69 -2,741.36 5,317.77 5,956,715.95 566,009.97 2.57 5,928.45 MWD+IF R-AK-CAZ-SC(4) 10,915.49 91.58 185.79 3,796.62 3,702.40 -2,832.62 5,307.01 5,956,624.62 565,999.95 2.06 5,971.97 MWD+IF R-AK-CAZ-SC(4) 11,009.89 91.64 185.21 3,793.97 3,699.75 -2,926.55 5,297.97 5,956,530.63 565,991.66 0.62 6,018.44 MWD+I F R-AK-CAZ-SC(4) 11,104.71 91.13 184.28 3,791.68 3,697.46 -3,021.01 5,290.13 5,956,436.11 565,984.59 1.12 6,066.20 MWD+IF R-AK-CAZ-SC(4) 11,199.25 91.10 184.58 3,789.84 3,695.62 -3,115.25 5,282.82 5,956,341.83 565,978.05 0.32 6,114.27 MWD+I F R-AK-CAZ-SC(4) 11,295.02 90.62 184.61 3,788.40 3,694.18 -3,210.70 5,275.15 5,956,246.33 565,971.15 0.50 6,162.74 MWD+I F R-AK-CAZ-SC(4) 11,387.67 90.41 183.44 3,787.57 3,693.35 -3,303.12 5,268.65 5,956,153.87 565,965.39 1.28 6,210.42 MWD+IFR-AK-CAZ-SC(4) 11,483.31 90.58 183.96 3,786.74 3,692.52 -3,398.56 5,262.48 5,956,058.39 565,959.99 0.57 6,260.10 MWD+IFR-AK-CAZ-SC(4) 11,577.50 90.31 185.36 3,786.01 3,691.79 -3,492.43 5,254.83 5,955,964.47 565,953.10 1.51 6,307.68 MWD+IFR-AK-CAZ-SC(4) 11,673.72 90.00 187.76 3,785.75 3,691.53 -3,588.01 5,243.84 5,955,868.81 565,942.88 2.51 6,353.50 MWD+IFR-AK-CAZ-SC(4) 11,767.87 89.07 190.49 3,786.51 3,692.29 -3,680.96 5,228.91 5,955,775.76 565,928.70 3.06 6,394.58 MWD+IFR-AK-CAZ-SC(4) 11,863.36 88.63 191.09 3,788.43 3,694.21 -3,774.74 5,211.03 5,955,681.84 565,911.59 0.78 6,433.73 MWD+IF R-AK-CAZ-SC(4) 11,957.82 88.39 190.45 3,790.88 3,696.66 -3,867.51 5,193.39 5,955,588.95 565,894.69 0.72 6,472.48 MWD+IFR-AK-CAZ-SC(4) 12,053.25 88.76 190.12 3,793.26 3,699.04 -3,961.37 5,176.36 5,955,494.96 565,878.42 0.52 6,512.37 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:34:57PM Page 5 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversionLocal Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference:r True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 12,145.63 88.73 189.54 3,795.28 3,701.06 -4,052.37 5,160.59 5,955,403.84 565,863.39 0.63 6,551.65 MWD+IFR-AK-CAZ-SC(4) 12,209.20 88.83 188.78 3,796.63 3,702.41 -4,115.12 5,150.47 5,955,341.02 565,853.78 1.21 6,579.35 MWD+IFR-AK-CAZ-SC(4) 12,270.00 88.83 188.78 3,797.88 3,703.66 -4,175.19 5,141.19 5,955,280.88 565,844.99 0.00 6,6,06.21 PROJECTED to TD Projected to TD =_'' X1,1! PI ��n . a'{"�I�i, .0 ! �u �I,� 3/24/2015 2:34:57PM Page 6 COMPASS 5000.1 Build 65 - Cement Detail Report 1D-142 ConocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL, 2/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 11/25/2014 14:30 11/25/2014 17:00 1D-142 Comment AS1 cement.Two pours.61 sx followed with 287 sx. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... r P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) 'Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/10/2015 { • Cement Detail Report 1D-142 ConocoPhil{ips String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/2/2015 10:00 3/2/2015 13:50 1D-142 Comment PJSM, Batch up as per SLB. Pump 5 bbls of CW100, pressure test lines to 1500/4000 psi.Cont pumping 45 bbls of CW100 followed by 50 bbls of 10.5 ppg Mud Push II. Shut down,drop bottom plug, SLB pumped 453 bbls of 11.0 ppg LiteCRETE and 63 bbls of 12.0 ppg Tail LiteCRETE cement.Shut down and drop top plug, kick out plug with 10 bbls of fresh water. Swap over to rig, displace cement with 9.5 ppg mud @ 7 bpm=650 psi.Slowed pumps to 3 bpm, bumped plug @ 2354 stokes, pressure up to 500 psi over FCP=1000 psi. Hold for 5 min, bleed off and check floats,good. Observed good circulation while performing cement job.70 bbls of Cement returned to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 29.9 2,673.0 No Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 7 6 500.0 1,000.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM, Batch up as per SLB. Pump 5 bbls of CW100, pressure test lines to 1500/4000 psi.Cont pumping 45 bbls of CW100 followed by 50 bbls of 10.5 ppg Mud Push II. Shut down,drop bottom plug, SLB pumped 453 bbls of 11.0 ppg LiteCRETE and 63 bbls of 12.0 ppg Tail LiteCRETE cement.Shut down and drop top plug, kick out plug with 10 bbls of fresh water.Swap over to rig,displace cement with 9.5 ppg mud @ 7 bpm=650 psi.Slowed pumps to 3 bpm, bumped plug @ 2354 stokes, pressure up to 500 psi over FCP=1000 psi. Hold for 5 min, bleed off and check floats, good. Observed good circulation while performing cement job.70 bbls of Cement returned to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush CW100 Chem Wash 50.0 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush Mud Push II 50.0 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 29.9 2,168.0 1,300 G 453.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 62.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,168.0 2,673.0 213 G 63.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.66 5.82 12.00 63.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Page 1/1 Report Printed: 4/10/2015 Cement Detail Report 1D-142 ConocoPhiiIIips String: Cement Squeeze 1 Job: DRILLING ORIGINAL, 2/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 1 3/5/2015 12:00 3/5/2015 16:00 1D-142 Comment Pump cement squeeze job,SLB came online w/5 bbls of water, PT lines to 500/4000 psi. Pump 15 bbls of 12.5 ppg MudPush II,close annular.SLB batch up cement. Open annular, pump 25 bbls of 15.8 ppg cement,close annular. Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement w/rig pumps @ 5 bpm.Displaced plug w/31 bbls of mud. Cement Stages Stage#<Stage Number?>'' Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Squeeze 2,458.0 2,708.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbll... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 4 4 580.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Perform hesitation squeeze as follows 1: Pumped.5 bbls=200 psi,shut in for 10 min=25 psi 2: Pumped.4 bbls=250 psi,shut in for 10 min=25 psi 3: Pumped.4 bbls=300 psi,shut in for 10 min=75 psi 4: Pumped.5 bbls=350 psi,shut in for 10 min=100 psi 5:Pumped.7 bbls=400 psi,shut in for 10 min=125 psi 6:Pumped.6 bbls=450 psi,shut in for 10 min=175 psi 7:Pumped.8 bbls=450 psi,shut in for 10 min=250 psi 8:Pumped 1 bbls=450 psi,shut in for 10 min=300 psi 9:Pumped.5 bbls=450 psi,shut in for 10 min=325 psi 10:Pumped.5bbls=450 psi,shut in for 10 min=350 psi 11:Pumped.3 bbls=450 psi,shut in for 10 min=350 psi Bleed off was flat lined last 5 min's on#11 Squeezed a total of 6.2 bbls into the formation 4:45 hrs to 70 Bc,cement in place @ 12:20 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 2,271.0 2,459.0 15.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Cement 2,458.0 2,708.0 119 G 24.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 2,271.0 2,459.0 3.0 Yield(fe/sack) 'Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) 0.01 gal/sx Additive Type Concentration Conc Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control 0.4 %BWOC Page 1/1 Report Printed: 4/10/2015 • • Cement Detail Report aggyz .14 PI, 1 D-142 Coix3CO hilltps String: Cement Squeeze 2 Job: DRILLING ORIGINAL,2/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 2 3/7/2015 13:45 3/7/2015 16:45 1D-142 Comment Pump cement squeeze job, SLB came online w/5 bbls of water, PT lines to 500/4000 psi. Pump 15 bbls of 12.5 ppg MudPush II,close annular.SLB batch up cement. Open annular, pump 25 bbls of 15.8 ppg cement,close annular. Batch up MudPush,open annular and pump 3 bbls of 12.5 ppg MuPush. Displace cement w/rig pumps @ 5 bpm.Displaced plug w/31 bbls of mud. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Squeeze No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 4 4 600.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Perform hesitation squeeze as follows: 1.Pumped.5 bbls=350 psi,shut in for 10 min=190 psi. 2. Pumped.3 bbls=400 psi,shut in for 10 min=250 psi. 3. Pumped.3 bbls=450 psi,shut in for 10 min=290 psi. 4. Pumped.2 bbls=450 psi,shut in for 10 min=325 psi. 5. Pumped..2 bbls=450 psi,shut in for 10 min=300 psi. Squeezed a total of 1.5 bbls into the formation.Cement in place @ 12:20 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 2,286.0 2,473.0 15.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Cement 2,286.0 2,473.0 119 G 25.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) 0.07 gal/sx Additive Type Concentration Conc Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control 0.4 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 2,286.0 2,473.0 3.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/10/2015 • • 4 , . Cement Detail Report 1D-142 C.OnoccoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/12/2015 06:05 3/12/2015 08:22 1D-142 Comment PJSM, pump 5 bbl H2O&test lines 500/4000 psi. Batch up 11.5 ppg MudPush&pump 55 bbls @ 4.5 bpm,315 psi. Drop bottom plug. Pump 153 bbls of 15.8 ppg Tail slurry cement @ 5 bpm,250 psi. Drop top plug. Chase with 10 bbls of H2O @ 5 bpm,90 psi. Swap to rig&chase w/9.5 ppg mud @ 6 bpm,250-1000 psi, Bump plug with 2896 strokes&psi up to 1500 psi, holding for 5 min. Bleed off pressure,floats check good.CIP @ 08:22 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 3,860.0 6,664.0 No Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 5 1,000.0 1,500.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM, pump 5 bbl H2O&test lines 500/4000 psi. Batch up 11.5 ppg MudPush&pump 55 bbls @ 4.5 bpm,315 psi. Drop bottom plug. Pump 153 bbls of 15.8 ppg Tail slurry cement @ 5 bpm,250 psi. Drop top plug.Chase with 10 bbls of H2O @ 5 bpm,90 psi.Swap to rig&chase w/9.5 ppg mud @ 6 bpm,250-1000 psi, Bump plug with 2896 strokes&psi up to 1500 psi, holding for 5 min. Bleed off pressure,floats check good.CIP @ 08:22 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 3,860.0 6,664.0 671 G 153.0 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 114.5 5.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.005 gal/sx Page 1/1 Report Printed: 4/10/2015 • • 214149 25602 SchlumbergerDrilling & Measurements Transmittal#: 27MAR15-SP02 DATA LOGGED MWD/LWD LogProduct Deliveryy/2.1/2015 K BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-142 Date Dispatched: 27-Mar-15 Job#: 14AKA0063 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A PTS Answer Product Top of Cement x x 0O9O - SIGZ I C eIdW LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A Nad27 As-Built Survey N/A Contents on CD N/A Nad83 CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/pds x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(&conocophillips.com AlaskaPTSPrintCenter@slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 MA V 6`��K — C Received By: 225609 SchlumbergerDrilling & Measurements Transmittal#: 27MAR15-SPO1 DATA LOGGED MWD/LWD Log Product Delivery 4 i0i201S K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-142 Date Dispatched: 27-Mar-15 Job#: 14AKA0063 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x —RECEIVED_ VISION*Service T TVDSS x x VISION*Service 5'MD x x MAR 31 2015 VISION*Service 5'TVD x x AOGCC p VISION*Service 5'TVDSS x x /`1 VV LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso@conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 i5 Received By: `/40.414L' — t "' • • X215 6149 01 RECEIVED MAR 3 1 2015 FINAL AOGCC NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-142 Definitive Survey Report NAD 27 24 March, 2015 r • - Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: WeII1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Well 1D-142 Well Position +N/-S 0.00 usft Northing: 5,959,414.03 usfi Latitude: 70°17'58.836 N +E/-W 0.00 usft Easting: 560,670.75 usfi Longitude: 149°30'31.101 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 66.80 usft Wellbore 1D-142 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/20/2015 19.07 80.92 57,570 Design 1D-142 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.42 0.00 0.00 125.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 74.73 339.23 1D-142 Svy1 -SLB_GYRO-MWD(1 D-14 GYD-GC-SS Gyrodata gyro single shots 2/27/2015 5:1: 428.94 2,591.09 1D-142 Svy2-SLB_MWD+GMAG(1D-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/27/2015 5:1, 2,688.47 6,599.87 10-142 Svy3 SLB_MWD+GMAG(1D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7:3: 6,695.17 12,209.20 1 D-142 Svy4 SLB_MWD+GMAG(1 D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7:3i Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100 (ft) Survey Tool Name 27.42 0.00 0.00 27.42 -66.80 0.00 0.00 5,959,414.03 560,670.75 0.00 0.00 UNDEFINED 74.73 0.06 196.20 74.73 -19.49 -0.02 -0.01 5,959,414.01 560,670.74 0.13 0.01 GYD-GC-SS(1) 107.77 0.19 126.26 107.77 13.55 -0.07 0.03 5,959,413.96 560,670.78 0.54 0.07 GYD-GC-SS(1) 161.09 0.26 195.74 161.09 66.87 -0.24 0.07 5,959,413.79 560,670.82 0.49 0.20 GYD-GC-SS(1) 251.60 0.21 175.02 251.60 157.38 -0.60 0.03 5,959,413.43 560,670.78 0.11 0.37 GYD-GC-SS(1) 339.23 0.34 167.54 339.23 245.01 -1.02 0.10 5,959,413.01 560,670.86 0.15 0.67 GYD-GC-SS(1) 428.94 0.06 156.04 428.94 334.72 -1.32 0.18 5,959,412.71 560,670.94 0.31 0.90 MWD+IFR-AK-CAZ-SC(2) 522.74 0.40 172.34 522.74 428.52 -1.69 0.24 5,959,412.34 560,671.00 0.37 1.17 MWD+IFR-AK-CAZ-SC(2) 613.99 1.06 109.93 613.98 519.76 -2.29 1.08 5,959,411.74 560,671.84 1.03 2.20 MWD+IFR-AK-CAZ-SC(2) 706.73 1.48 101.71 706.70 612.48 -2.83 3.05 5,959,411.23 560,673.83 0.49 4.13 MWD+IFR-AK-CAZ-SC(2) 799.48 2.69 94.30 799.38 705.16 -3.24 6.40 5,959,410.85 560,677.17 1.33 7.10 MWD+IFR-AK-CAZ-SC(2) 894.91 4.58 79.66 894.62 800.40 -2.72 12.38 5,959,411.41 560,683.15 2.19 11.70 MWD+IFR-AK-CAZ-SC(2) 989.33 7.83 72.42 988.47 894.25 -0.10 22.22 5,959,414.11 560,692.97 3.53 18.26 MWD+IFR-AK-CAZ-SC(2) 1,081.95 8.43 73.39 1,080.16 985.94 3.75 34.74 5,959,418.06 560,705.46 0.66 26.31 MWD+IFR-AK-CAZ-SC(2) 1,177.40 10.81 74.31 1,174.26 1,080.04 8.17 50.07 5,959,422.60 560,720.74 2.50 36.33 MWD+IFR-AK-CAZ-SC(2) 3/24/2015 2:34:57PM Page 2 COMPASS 5000.1 Build 65 • • . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1 D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) () (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,270.49 13.75 74.96 1,265.21 1,170.99 13.40 69.16 5,959,427.99 560,739.79 3.16 48.97 MWD+IFR-AK-CAZ-SC(2) 1,364.11 16.14 73.47 1,355.66 1,261.44 19.99 92.38 5,959,434.76 560,762.96 2.59 64.21 MWD+IFR-AK-CAZ-SC(2) 1,457.17 18.33 69.91 1,444.54 1,350.32 28.70 118.53 5,959,443.68 560,789.03 2.61 80.63 MWD+IFR-AK-CAZ-SC(2) 1,548.95 20.73 67.63 1,531.03 1,436.81 39.84 147.11 5,959,455.05 560,817.52 2.74 97.65 MWD+IFR-AK-CAZ-SC(2) 1,642.01 23.10 66.62 1,617.36 1,523.14 53.35 179.10 5,959,468.82 560,849.40 2.58 116.11 MWD+I F R-AK-CAZ-S C(2) 1,736.27 22.91 66.99 1,704.13 1,609.91 67.86 212.96 5,959,483.60 560,883.14 0.25 135.52 MWD+IFR-AK-CAZ-SC(2) 1,828.13 26.35 61.61 1,787.63 1,693.41 84.55 247.37 5,959,500.57 560,917.40 4.47 154.13 MWD+I FR-AK-CAZ-S C(2) 1,920.43 29.68 57.66 1,869.11 1,774.89 106.52 284.71 5,959,522.84 560,954.56 4.13 172.12 MWD+I F R-AK-CAZ-S C(2) 2,014.42 35.73 55.60 1,948.16 1,853.94 134.50 327.05 5,959,551.16 560,996.68 6.54 190.76 MWD+I FR-AK-CAZ-SC(2) 2,106.07 42.92 54.39 2,019.02 1,924.80 167.84 374.57 5,959,584.87 561,043.91 7.89 210.56 MWD+IFR-AK-CAZ-SC(2) 2,198.32 47.76 54.81 2,083.84 1,989.62 205.83 428.04 5,959,623.29 561,097.08 5.26 232.57 MWD+IFR-AK-CAZ-SC(2) 2,291.89 53.05 55.69 2,143.46 2,049.24 246.89 487.27 5,959,664.83 561,155.97 5.70 257.54 MWD+IFR-AK-CAZ-SC(2) 2,386.29 56.06 56.29 2,198.19 2,103.97 289.90 551.02 5,959,708.34 561,219.36 3.23 285.09 MWD+I FR-AK-CAZ-SC(2) 2,479.38 63.07 55.99 2,245.32 2,151.10 334.60 617.63 5,959,753.57 561,285.59 7.54 314.01 MWD+IFR-AK-CAZ-SC(2) 2,572.74 62.63 53.83 2,287.93 2,193.71 382.34 685.60 5,959,801.86 561,353.17 2.11 342.30 MWD+I FR-AK-CAZ-SC(2) 2,591.09 62.42 55.12 2,296.39 2,202.17 391.80 698.85 5,959,811.43 561,366.34 6.34 347.73 MWD+IFR-AK-CAZ-SC(2) 2,662.00 61.93 55.01 2,329.49 2,235.27 427.72 750.26 5,959,847.75 561,417.46 0.70 369.25 MWD+IFR-AK-CAZ-SC(3) 10 314"x 13-1/2 2,688.47 61.75 54.97 2,341.98 2,247.76 441.10 769.37 5,959,861.29 561,436.46 0.70 377.22 MWD+IFR-AK-CAZ-SC(3) 2,762.08 62.12 58.16 2,376.62 2,282.40 476.88 823.57 5,959,897.50 561,490.36 3.86 401.10 MWD+I FR-AK-CAZ-SC(3) 2,809.05 62.24 57.93 2,398.54 2,304.32 498.87 858.81 5,959,919.77 561,525.43 0.50 417.36 MWD+I F R-AK-CAZ-SC(3) 2,903.47 62.70 57.63 2,442.18 2,347.96 543.51 929.65 5,959,964.98 561,595.89 0.56 449.78 MWD+IFR-AK-CAZ-SC(3) 2,996.56 62.66 56.62 2,484.91 2,390.69 588.40 999.11 5,960,010.42 561,664.98 0.96 480.93 MWD+I FR-AK-CAZ-SC(3) 3,088.69 62.83 54.98 2,527.10 2,432.88 634.44 1,066.84 5,960,057.00 561,732.34 1.59 510.01 MWD+IFR-AK-CAZ-SC(3) 3,183.85 62.62 54.40 2,570.71 2,476.49 683.33 1,135.86 5,960,106.44 561,800.95 0.58 538.51 MWD+IFR-AK-CAZ-SC(3) 3,277.65 62.75 54.60 2,613.75 2,519.53 731.72 1,203.71 5,960,155.38 561,868.40 0.23 566.33 MWD+IFR-AK-CAZ-SC(3) 3,370.92 62.75 53.82 2,656.46 2,562.24 780.21 1,270.97 5,960,204.40 561,935.26 0.74 593.61 MWD+IFR-AK-CAZ-SC(3) 3,465.05 62.76 52.76 2,699.55 2,605.33 830.24 1,338.06 5,960,254.96 562,001.94 1.00 619.87 MWD+IFR-AK-CAZ-SC(3) 3,557.55 62.79 52.53 2,741.87 2,647.65 880.14 1,403.44 5,960,305.39 562,066.91 0.22 644.80 MWD+IFR-AK-CAZ-SC(3) 3,650.50 62.65 53.37 2,784.47 2,690.25 929.92 1,469.38 5,960,355.69 562,132.43 0.82 670.26 MWD+IFR-AK-CAZ-SC(3) 3,744.05 62.68 54.53 2,827.43 2,733.21 978.82 1,536.56 5,960,405.13 562,199.21 1.10 697.25 MWD+IFR-AK-CAZ-SC(3) 3,836.00 62.79 54.42 2,869.56 2,775.34 1,026.32 1,603.08 5,960,453.16 562,265.34 0.16 724.50 MWD+I FR-AK-CAZ-SC(3) 3,929.48 63.01 54.93 2,912.14 2,817.92 1,074.43 1,670.98 5,960,501.81 562,332.84 0.54 752.52 MWD+IFR-AK-CAZ-SC(3) 4,021.91 63.09 54.78 2,954.03 2,859.81 1,121.86 1,738.35 5,960,549.78 562,399.82 0.17 780.50 MWD+I FR-AK-CAZ-SC(3) 4,114.75 64.06 54.20 2,995.35 2,901.13 1,170.15 1,806.03 5,960,598.61 562,467.10 1.19 808.24 MWD+I FR-AK-CAZ-SC(3) 4,207.54 63.74 54.02 3,036.17 2,941.95 1,219.00 1,873.53 5,960,648.00 562,534.20 0.39 835.52 MWD+IFR-AK-CAZ-SC(3) 4,299.13 64.01 53.94 3,076.50 2,982.28 1,267.36 1,940.04 5,960,696.89 562,600.31 0.31 862.26 MWD+I FR-AK-CAZ-SC(3) 4,393.83 63.93 55.01 3,118.06 3,023.84 1,316.80 2,009.30 5,960,746.89 562,669.16 1.02 890.63 MWD+IFR-AK-CAZ-SC(3) 4,487.00 64.17 57.95 3,158.83 3,064.61 1,363.06 2,079.13 5,960,793.70 562,738.61 2.85 921.31 MWD+I FR-AK-CAZ-SC(3) 4,581.12 65.37 62.47 3,198.97 3,104.75 1,405.33 2,153.00 5,960,836.56 562,812.13 4.53 957.57 MWD+I FR-AK-CAZ-SC(3) 4,675.15 66.22 67.26 3,237.54 3,143.32 1,441.73 2,230.62 5,960,873.58 562,889.44 4.73 1,000.27 MWD+IFR-AK-CAZ-SC(3) 4,718.78 66.37 69.85 3,255.08 3,160.86 1,456.34 2,267.80 5,960,888.49 562,926.50 5.45 1,022.35 MWD+IFR-AK-CAZ-SC(3) 4,768.05 66.51 71.61 3,274.78 3,180.56 1,471.24 2,310.43 5,960,903.73 562,969.00 3.29 1,048.72 MWD+IFR-AK-CAZ-SC(3) 4,860.41 67.41 71.98 3,310.93 3,216.71 1,497.79 2,391.17 5,960,930.93 563,049.52 1.04 1,099.63 MWD+IFR-AK-CAZ-SC(3) 3/24/2015 2:34:57PM Page 3 COMPASS 5000.1 Build 65 • • . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,953.04 68.52 71.70 3,345.68 3,251.46 1,524.55 2,472.75 5,960,958.35 563,130.88 1.23 1,151.11 MWD+IFR-AK-CAZ-SC(3) 5,047.41 68.63 71.61 3,380.15 3,285.93 1,552.20 2,556.14 5,960,986.67 563,214.03 0.15 1,203.56 MWD+IFR-AK-CAZ-SC(3) 5,139.93 68.54 74.60 3,413.94 3,319.72 1,577.23 2,638.54 5,961,012.36 563,296.22 3.01 1,256.70 MWD+IFR-AK-CAZ-SC(3) 5,234.19 68.68 78.25 3,448.33 3,354.11 1,597.83 2,723.84 5,961,033.64 563,381.34 3.61 1,314.76 MWD+IFR-AK-CAZ-SC(3) 5,327.71 69.44 83.19 3,481.77 3,387.55 1,611.90 2,810.00 5,961,048.40 563,467.38 5.00 1,377.28 MWD+IFR-AK-CAZ-SC(3) 5,420.25 69.92 88.02 3,513.92 3,419.70 1,618.54 2,896.50 5,961,055.74 563,553.81 4.92 1,444.32 MWD+IFR-AK-CAZ-SC(3) 5,512.79 70.30 91.53 3,545.41 3,451.19 1,618.88 2,983.50 5,961,056.78 563,640.80 3.59 1,515.39 MWD+IFR-AK-CAZ-SC(3) 5,606.16 71.30 97.00 3,576.14 3,481.92 1,612.31 3,071.39 5,961,050.93 563,728.73 5.63 1,591.15 MWD+IFR-AK-CAZ-SC(3) 5,699.12 71.51 101.39 3,605.79 3,511.57 1,598.23 3,158.34 5,961,037.55 563,815.78 4.48 1,670.45 MWD+IFR-AK-CAZ-SC(3) 5,791.44 71.98 106.92 3,634.73 3,540.51 1,576.80 3,243.31 5,961,016.81 563,900.91 5.71 1,752.35 MWD+IFR-AK-CAZ-SC(3) 5,883.60 72.55 110.49 3,662.81 3,568.59 1,548.65 3,326.44 5,960,989.33 563,984.26 3.74 1,836.59 MWD+IFR-AK-CAZ-SC(3) 5,976.54 74.09 114.87 3,689.50 3,595.28 1,514.32 3,408.55 5,960,955.67 564,066.64 4.81 1,923.54 MW D+I FR-AK-CAZ-SC(3) 6,069.65 75.98 119.24 3,713.55 3,619.33 1,473.40 3,488.63 5,960,915.41 564,147.03 4.97 2,012.61 MWD+I FR-AK-CAZ-SC(3) 6,118.45 77.07 122.60 3,724.93 3,630.71 1,449.02 3,529.33 5,960,891.35 564,187.93 7.06 2,059.93 MW D+I FR-AK-CAZ-SC(3) 6,164.32 78.17 125.54 3,734.77 3,640.55 1,423.92 3,566.44 5,960,866.56 564,225.23 6.70 2,104.73 MWD+IFR-AK-CAZ-SC(3) 6,214.72 79.80 127.69 3,744.40 3,650.18 1,394.41 3,606.14 5,960,837.38 564,265.17 5.29 2,154.17 MWD+I FR-AK-CAZ-SC(3) 6,256.69 80.69 130.27 3,751.51 3,657.29 1,368.40 3,638.29 5,960,811.62 564,297.53 6.42 2,195.43 MWD+IFR-AK-CAZ-SC(3) 6,302.09 81.69 132.29 3,758.46 3,664.24 1,338.80 3,672.00 5,960,782.30 564,331.47 4.92 2,240.02 MWD+I FR-AK-CAZ-SC(3) 6,351.73 82.45 135.06 3,765.31 3,671.09 1,304.85 3,707.56 5,960,748.64 564,367.30 5.73 2,288.62 MWD+I FR-AK-CAZ-SC(3) 6,397.10 83.04 137.84 3,771.04 3,676.82 1,272.23 3,738.56 5,960,716.28 564,398.56 6.22 2,332.73 MWD+IFR-AK-CAZ-SC(3) 6,445.15 83.65 140.31 3,776.61 3,682.39 1,236.18 3,769.82 5,960,680.48 564,430.11 5.26 2,379.02 MWD+I FR-AK-CAZ-SC(3) 6,494.14 84.05 142.76 3,781.86 3,687.64 1,198.04 3,800.12 5,960,642.60 564,460.71 5.04 2,425.71 MWD+IFR-AK-CAZ-SC(3) 6,537.57 84.03 145.24 3,786.37 3,692.15 1,163.10 3,825.51 5,960,607.86 564,486.38 5.68 2,466.55 MWD+IFR-AK-CAZ-SC(3) 6,599.87 85.49 147.77 3,792.06 3,697.84 1,111.37 3,859.74 5,960,556.41 564,521.02 4.67 2,524.26 MWD+IFR-AK-CAZ-SC(3) 6,655.00 85.25 147.46 3,796.51 3,702.29 1,064.96 3,889.17 5,960,510.25 564,550.82 0.70 2,574.98 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 6,695.17 85.08 147.24 3,799.90 3,705.68 1,031.26 3,910.76 5,960,476.73 564,572.69 0.70 2,612.00 MWD+IFR-AK-CAZ-SC(4) 6,754.31 85.66 146.89 3,804.67 3,710.45 981.79 3,942.81 5,960,427.52 564,605.13 1.14 2,666.63 MWD+IFR-AK-CAZ-SC(4) 6,851.27 88.64 146.37 3,809.49 3,715.27 900.92 3,996.07 5,960,347.10 564,659.04 3.12 2,756.64 MWD+IFR-AK-CAZ-SC(4) 6,943.13 90.15 145.85 3,810.46 3,716.24 824.67 4,047.29 5,960,271.27 564,710.86 1.74 2,842.33 MWD+IFR-AK-CAZ-SC(4) 7,039.32 90.48 147.09 3,809.93 3,715.71 744.49 4,100.42 5,960,191.53 564,764.63 1.33 2,931.84 MWD+IFR-AK-CAZ-SC(4) 7,132.51 90.51 147.42 3,809.13 3,714.91 666.11 4,150.82 5,960,113.57 564,815.66 0.36 3,018.09 MWD+IFR-AK-CAZ-SC(4) 7,230.39 90.68 148.68 3,808.11 3,713.89 583.07 4,202.62 5,960,030.95 564,868.12 1.30 3,108.15 MWD+IFR-AK-CAZ-SC(4) 7,320.99 90.38 150.62 3,807.27 3,713.05 504.89 4,248.39 5,959,953.15 564,914.52 2.17 3,190.48 MWD+IFR-AK-CAZ-SC(4) 7,415.38 89.14 150.76 3,807.67 3,713.45 422.59 4,294.60 5,959,871.23 564,961.38 1.32 3,275.54 MWD+IFR-AK-CAZ-SC(4) 7,509.25 88.73 150.35 3,809.41 3,715.19 340.86 4,340.73 5,959,789.89 565,008.17 0.62 3,360.21 MWD+IFR-AK-CAZ-SC(4) 7,602.31 88.14 150.88 3,811.95 3,717.73 259.80 4,386.38 5,959,709.21 565,054.47 0.85 3,444.10 MWD+IFR-AK-CAZ-SC(4) 7,697.82 88.73 151.44 3,814.56 3,720.34 176.17 4,432.43 5,959,625.96 565,101.19 0.85 3,529.79 MWD+IFR-AK-CAZ-SC(4) 7,792.96 89.22 152.58 3,816.26 3,722.04 92.17 4,477.07 5,959,542.34 565,146.51 1.30 3,614.54 MWD+IFR-AK-CAZ-SC(4) 7,888.38 88.49 153.52 3,818.17 3,723.95 7.13 4,520.31 5,959,457.66 565,190.42 1.25 3,698.73 MWD+IFR-AK-CAZ-SC(4) 7,983.38 88.35 152.94 3,820.79 3,726.57 -77.65 4,563.08 5,959,373.23 565,233.87 0.63 3,782.40 MWD+IFR-AK-CAZ-SC(4) 8,077.59 88.42 150.04 3,823.44 3,729.22 -160.40 4,608.03 5,959,290.86 565,279.48 3.08 3,866.67 MWD+IFR-AK-CAZ-SC(4) 8,173.43 88.25 148.04 3,826.23 3,732.01 -242.54 4,657.31 5,959,209.12 565,329.42 2.09 3,954.16 MWD+IFR-AK-CAZ-SC(4) 8,268.86 88.49 148.48 3,828.94 3,734.72 -323.67 4,707.49 5,959,128.41 565,380.25 0.53 4,041.80 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:34:57PM Page 4 COMPASS 5000.1 Build 65 • . • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 10-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 10 Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 8,363.21 89.28 150.55 3,830.78 3,736.56 -404.95 4,755.34 5,959,047.52 565,428.75 2.35 4,127.62 MWD+IFR-AK-CAZ-SC(4) 8,455.43 89.69 150.67 3,831.61 3,737.39 -485.30 4,800.60 5,958,967.55 565,474.65 0.46 4,210.78 MWD+IFR-AK-CAZ-SC(4) 8,547.63 89.66 150.69 3,832.13 3,737.91 -565.69 4,845.75 5,958,887.53 565,520.44 0.04 4,293.87 MWD+IFR-AK-CAZ-SC(4) 8,644.41 89.66 153.13 3,832.71 3,738.49 -651.06 4,891.31 5,958,802.54 565,566.69 2.52 4,380.16 MWD+IFR-AK-CAZ-SC(4) 8,740.54 89.79 153.46 3,833.17 3,738.95 -736.94 4,934.51 5,958,717.03 565,610.58 0.37 4,464.80 MWD+IFR-AK-CAZ-SC(4) 8,833.16 89.62 155.82 3,833.65 3,739.43 -820.62 4,974.18 5,958,633.67 565,650.91 2.55 4,545.30 MWD+IFR-AK-CAZ-SC(4) 8,929.57 89.21 158.62 3,834.63 3,740.41 -909.50 5,011.50 5,958,545.11 565,688.95 2.94 4,626.85 MWD+IFR-AK-CAZ-SC(4) 9,019.88 89.31 158.80 3,835.80 3,741.58 -993.64 5,044.29 5,958,461.24 565,722.41 0.23 4,701.97 MWD+IFR-AK-CAZ-SC(4) 9,118.37 89.72 159.50 3,836.63 3,742.41 -1,085.68 5,079.34 5,958,369.50 565,758.21 0.82 4,783.47 MWD+IFR-AK-CAZ-SC(4) 9,213.31 90.99 159.52 3,836.04 3,741.82 -1,174.61 5,112.58 5,958,280.85 565,792.15 1.34 4,861.70 MWD+I FR-AK-CAZ-SC(4) 9,307.87 92.24 160.30 3,833.38 3,739.16 -1,263.37 5,145.04 5,958,192.35 565,825.33 1.56 4,939.21 MWD+IFR-AK-CAZ-SC(4) 9,402.51 92.23 158.48 3,829.69 3,735.47 -1,351.89 5,178.33 5,958,104.12 565,859.33 1.92 5,017.25 MWD+IFR-AK-CAZ-SC(4) 9,496.69 92.50 160.45 3,825.80 3,731.58 -1,440.00 5,211.34 5,958,016.28 565,893.04 2.11 5,094.83 MWD+IFR-AK-CAZ-SC(4) 9,590.82 92.19 162.04 3,821.95 3,727.73 -1,529.06 5,241.57 5,957,927.49 565,924.00 1.72 5,170.68 MWD+IFR-AK-CAZ-SC(4) 9,686.29 91.92 163.97 3,818.52 3,724.30 -1,620.29 5,269.46 5,957,836.48 565,952.61 2.04 5,245.85 MWD+I FR-AK-CAZ-SC(4) 9,781.57 91.34 165.58 3,815.81 3,721.59 -1,712.19 5,294.47 5,957,744.80 565,978.36 1.80 5,319.05 MWD+IFR-AK-CAZ-SC(4) 9,877.24 91.20 166.90 3,813.69 3,719.47 -1,805.09 5,317.22 5,957,652.10 566,001.86 1.39 5,390.97 MWD+IFR-AK-CAZ-SC(4) 9,971.65 90.75 168.20 3,812.09 3,717.87 -1,897.26 5,337.57 5,957,560.10 566,022.95 1.46 5,460.51 MW D+IFR-AK-CAZ-SC(4) 10,066.29 90.72 171.24 3,810.87 3,716.65 -1,990.37 5,354.46 5,957,467.15 566,040.59 3.21 5,527.74 MWD+IFR-AK-CAZ-SC(4) 10,160.19 91.40 172.94 3,809.13 3,714.91 -2,083.35 5,367.38 5,957,374.28 566,054.26 1.95 5,591.66 MWD+IFR-AK-CAZ-SC(4) 10,255.10 91.03 176.02 3,807.12 3,712.90 -2,177.79 5,376.50 5,957,279.93 566,064.14 3.27 5,653.30 MWD+IFR-AK-CAZ-SC(4) 10,308.15 90.86 178.77 3,806.25 3,712.03 -2,230.77 5,378.91 5,957,226.97 566,066.98 5.19 5,685.67 MWD+IFR-AK-CAZ-SC(4) 10,349.01 90.86 179.29 3,805.63 3,711.41 -2,271.62 5,379.60 5,957,186.13 566,068.00 1.27 5,709.66 MWD+IFR-AK-CAZ-SC(4) 10,444.46 91.05 184.49 3,804.04 3,709.82 -2,366.97 5,376.46 5,957,090.77 566,065.63 5.45 5,761.78 MWD+IFR-AK-CAZ-SC(4) 10,490.22 91.69 187.38 3,802.95 3,708.73 -2,412.47 5,371.73 5,957,045.24 566,061.26 6.47 5,784.00 MWD+IFR-AK-CAZ-SC(4) 10,539.15 90.39 189.41 3,802.06 3,707.84 -2,460.86 5,364.59 5,956,996.79 566,054.51 4.93 5,805.91 MWD+IFR-AK-CAZ-SC(4) 10,634.95 90.09 189.84 3,801.66 3,707.44 -2,555.31 5,348.57 5,956,902.22 566,039.26 0.55 5,846.96 MWD+IFR-AK-CAZ-SC(4) 10,686.85 90.65 190.01 3,801.32 3,707.10 -2,606.44 5,339.62 5,956,851.04 566,030.73 1.13 5,868.95 MWD+IFR-AK-CAZ-SC(4) 10,729.46 90.96 189.98 3,800.72 3,706.50 -2,648.40 5,332.23 5,956,809.02 566,023.67 0.73 5,886.96 MWD+IFR-AK-CAZ-SC(4) 10,777.22 91.10 188.84 3,799.86 3,705.64 -2,695.50 5,324.42 5,956,761.86 566,016.25 2.40 5,907.59 MWD+IFR-AK-CAZ-SC(4) 10,823.57 91.27 187.66 3,798.91 3,704.69 -2,741.36 5,317.77 5,956,715.95 566,009.97 2.57 5,928.45 MWD+IFR-AK-CAZ-SC(4) 10,915.49 91.58 185.79 3,796.62 3,702.40 -2,832.62 5,307.01 5,956,624.62 565,999.95 2.06 5,971.97 MWD+I FR-AK-CAZ-SC(4) 11,009.89 91.64 185.21 3,793.97 3,699.75 -2,926.55 5,297.97 5,956,530.63 565,991.66 0.62 6,018.44 MWD+IFR-AK-CAZ-SC(4) 11,104.71 91.13 184.28 3,791.68 3,697.46 -3,021.01 5,290.13 5,956,436.11 565,984.59 1.12 6,066.20 MWD+IFR-AK-CAZ-SC(4) 11,199.25 91.10 184.58 3,789.84 3,695.62 -3,115.25 5,282.82 5,956,341.83 565,978.05 0.32 6,114.27 MWD+IFR-AK-CAZ-SC(4) 11,295.02 90.62 184.61 3,788.40 3,694.18 -3,210.70 5,275.15 5,956,246.33 565,971.15 0.50 6,162.74 MWD+IFR-AK-CAZ-SC(4) 11,387.67 90.41 183.44 3,787.57 3,693.35 -3,303.12 5,268.65 5,956,153.87 565,965.39 1.28 6,210.42 MWD+IFR-AK-CAZ-SC(4) 11,483.31 90.58 183.96 3,786.74 3,692.52 -3,398.56 5,262.48 5,956,058.39 565,959.99 0.57 6,260.10 MWD+I FR-AK-CAZ-SC(4) 11,577.50 90.31 185.36 3,786.01 3,691.79 -3,492.43 5,254.83 5,955,964.47 565,953.10 1.51 6,307.68 MWD+IFR-AK-CAZ-SC(4) 11,673.72 90.00 187.76 3,785.75 3,691.53 -3,588.01 5,243.84 5,955,868.81 565,942.88 2.51 6,353.50 MWD+I FR-AK-CAZ-SC(4) 11,767.87 89.07 190.49 3,786.51 3,692.29 -3,680.96 5,228.91 5,955,775.76 565,928.70 3.06 6,394.58 MWD+IFR-AK-CAZ-SC(4) 11,863.36 88.63 191.09 3,788.43 3,694.21 -3,774.74 5,211.03 5,955,681.84 565,911.59 0.78 6,433.73 MWD+I FR-AK-CAZ-SC(4) 11,957.82 88.39 190.45 3,790.88 3,696.66 -3,867.51 5,193.39 5,955,588.95 565,894.69 0.72 6,472.48 MWD+IFR-AK-CAZ-SC(4) 12,053.25 88.76 190.12 3,793.26 3,699.04 -3,961.37 5,176.36 5,955,494.96 565,878.42 0.52 6,512.37 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:34:57PM Page 5 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 10-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuprauk 10 Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100.) (ft) Survey Tool Name 12,145.63 88.73 189.54 3,795.28 3,701.06 -4,052.37 5,160.59 5,955,403.84 565,863.39 0.63 6,551.65 MWD+IFR-AK-CAZ-SC(4) 12,209.20 88.83 188.78 3,796.63 3,702.41 -4,115.12 5,150.47 5,955,341.02 565,853.78 1.21 6,579.35 MWD+IFR-AK-CAZ-SC(4) 12,270.00 88.83 188.78 3,797.88 3,703.66 -4,175.19 5,141.19 5,955,280.88 565,844.99 0.00 6,606.21 PROJECTED to TD Projected to TD 3/24/2015 2:34:57PM Page 6 COMPASS 5000.1 Build 65 • • 214149 25601 RECEIVED MAR 3 1 2015 AOGCC FINAL , ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D-142 Definitive Survey Report NAD 83 24 March, 2015 Schlumberger • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1D-142 Well Position +NI-S 0.00 usft Northing: 5,959,165.54 usfl Latitude: 70°17'57.785 N +El-W 0.00 usft Easting: 1,700,702.71 usfi Longitude: 149°30'42.265 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 66.80 usft Wellbore 1D-142 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 2/20/2015 19.07 80.92 57,570 Design 1D-142 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.42 0.00 0.00 125.00 Survey Program Date 3/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 74.73 339.23 1D-142 Svy1 -SLB_GYRO-MWD(10-14 GYD-GC-SS Gyrodata gyro single shots 2/27/2015 5:1: 428.94 2,591.09 1D-142 Svy2-SLB_MWD+GMAG(1D-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/27/2015 5:1, 2,688.47 6,599.87 10-142 Svy3 SLB_MWD+GMAG(1D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7:3 6,695.17 12,209.20 1D-142 Svy4 SLB_MWD+GMAG(1D-14 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2015 7:3l Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 27.42 0.00 0.00 27.42 -66.80 0.00 0.00 5,959,165.54 1,700,702.71 0.00 0.00 UNDEFINED 74.73 0.06 196.20 74.73 -19.49 -0.02 -0.01 5,959,165.51 1,700,702.71 0.13 0.01 GYD-GC-SS(1) 107.77 0.19 126.26 107.77 13.55 -0.07 0.03 5,959,165.46 1,700,702.75 0.54 0.07 GYD-GC-SS(1) 161.09 0.26 195.74 161.09 66.87 -0.24 0.07 5,959,165.30 1,700,702.79 0.49 0.20 GYD-GC-SS(1) 251.60 0.21 175.02 251.60 157.38 -0.60 0.03 5,959,164.93 1,700,702.75 0.11 0.37 GYD-GC-SS(1) 339.23 0.34 167.54 339.23 245.01 -1.02 0.10 5,959,164.52 1,700,702.82 0.15 0.67 GYD-GC-SS(1) 428.94 0.06 156.04 428.94 334.72 -1.32 0.18 5,959,164.22 1,700,702.90 0.31 0.90 MWD+IFR-AK-CAZ-SC(2) 522.74 0.40 172.34 522.74 428.52 -1.69 0.24 5,959,163.85 1,700,702.97 0.37 1.17 MWD+IFR-AK-CAZ-SC(2) 613.99 1.06 109.93 613.98 519.76 -2.29 1.08 5,959,163.25 1,700,703.81 1.03 2.20 MWD+IFR-AK-CAZ-SC(2) 706.73 1.48 101.71 706.70 612.48 -2.83 3.05 5,959,162.73 1,700,705.79 0.49 4.13 MWD+IFR-AK-CAZ-SC(2) 799.48 2.69 94.30 799.38 705.16 -3.24 6.40 5,959,162.35 1,700,709.14 1.33 7.10 MWD+IFR-AK-CAZ-SC(2) 894.91 4.58 79.66 894.62 800.40 -2.72 12.38 5,959,162.92 1,700,715.11 2.19 11.70 MWD+IFR-AK-CAZ-SC(2) 989.33 7.83 72.42 988.47 894.25 -0.10 22.22 5,959,165.61 1,700,724.94 3.53 18.26 MWD+IFR-AK-CAZ-SC(2) 1,081.95 8.43 73.39 1,080.16 985.94 3.75 34.74 5,959,169.56 1,700,737.42 0.66 26.31 MWD+IFR-AK-CAZ-SC(2) 1,177.40 10.81 74.31 1,174.26 1,080.04 8.17 50.07 5,959,174.10 1,700,752.71 2.50 36.33 MWD+IFR-AK-CAZ-SC(2) 3/24/2015 2:39:15PM Page 2 COMPASS 5000.1 Build 65 • • Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1 D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,270.49 13.75 74.96 1,265.21 1,170.99 13.40 69.16 5,959,179.49 1,700,771.76 3.16 48.97 MWD+IFR-AK-CAZ-SC(2) 1,364.11 16.14 73.47 1,355.66 1,261.44 19.99 92.38 5,959,186.27 1,700,794.93 2.59 64.21 MWD+IFR-AK-CAZ-SC(2) 1,457.17 18.33 69.91 1,444.54 1,350.32 28.70 118.53 5,959,195.18 1,700,821.00 2.61 80.63 MWD+IFR-AK-CAZ-SC(2) 1,548.95 20.73 67.63 1,531.03 1,436.81 39.84 147.11 5,959,206.55 1,700,849.49 2.74 97.65 MWD+IFR-AK-CAZ-SC(2) 1,642.01 23.10 66.62 1,617.36 1,523.14 53.35 179.10 5,959,220.32 1,700,881.36 2.58 116.11 MWD+IFR-AK-CAZ-SC(2) 1,736.27 22.91 66.99 1,704.13 1,609.91 67.86 212.96 5,959,235.10 1,700,915.10 0.25 135.52 MWD+IFR-AK-CAZ-SC(2) 1,828.13 26.35 61.61 1,787.63 1,693.41 84.55 247.37 5,959,252.06 1,700,949.37 4.47 154.13 MWD+IFR-AK-CAZ-SC(2) 1,920.43 29.68 57.66 1,869.11 1,774.89 106.52 284.71 5,959,274.33 1,700,986.53 4.13 172.12 MWD+IFR-AK-CAZ-SC(2) 2,014.42 35.73 55.60 1,948.16 1,853.94 134.50 327.05 5,959,302.65 1,701,028.65 6.54 190.76 MWD+IFR-AK-CAZ-SC(2) 2,106.07 42.92 54.39 2,019.02 1,924.80 167.84 374.57 5,959,336.36 1,701,075.89 7.89 210.56 MWD+IFR-AK-CAZ-SC(2) 2,198.32 47.76 54.81 2,083.84 1,989.62 205.83 428.04 5,959,374.77 1,701,129.05 5.26 232.57 MWD+IFR-AK-CAZ-SC(2) 2,291.89 53.05 55.69 2,143.46 2,049.24 246.89 487.27 5,959,416.31 1,701,187.95 5.70 257.54 MWD+IFR-AK-CAZ-SC(2) 2,386.29 56.06 56.29 2,198.19 2,103.97 289.90 551.02 5,959,459.82 1,701,251.34 3.23 285.09 MWD+IFR-AK-CAZ-SC(2) 2,479.38 63.07 55.99 2,245.32 2,151.10 334.60 617.63 5,959,505.04 1,701,317.58 7.54 314.01 MWD+IFR-AK-CAZ-SC(2) 2,572.74 62.63 53.83 2,287.93 2,193.71 382.34 685.60 5,959,553.33 1,701,385.16 2.11 342.30 MWD+IFR-AK-CAZ-SC(2) 2,591.09 62.42 55.12 2,296.39 2,202.17 391.80 698.85 5,959,562.90 1,701,398.33 6.34 347.73 MWD+IFR-AK-CAZ-SC(2) 2,662.00 61.93 55.01 2,329.49 2.235.27 427.72 750.26 5,959,599.22 1,701,449.44 0.70 369.25 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,688.47 61.75 54.97 2,341.98 2,247.76 441.10 769.37 5,959,612.76 1,701,468.45 0.70 377.22 MWD+IFR-AK-CAZ-SC(3) 2,762.08 62.12 58.16 2,376.62 2,282.40 476.88 823.57 5,959,648.97 1,701,522.35 3.86 401.10 MWD+IFR-AK-CAZ-SC(3) 2,809.05 62.24 57.93 2,398.54 2,304.32 498.87 858.81 5,959,671.23 1,701,557.42 0.50 417.36 MWD+IFR-AK-CAZ-SC(3) 2,903.47 62.70 57.63 2,442.18 2,347.96 543.51 929.65 5,959,716.44 1,701,627.88 0.56 449.78 MWD+IFR-AK-CAZ-SC(3) 2,996.56 62.66 56.62 2,484.91 2,390.69 588.40 999.11 5,959,761.88 1,701,696.98 0.96 480.93 MWD+IFR-AK-CAZ-SC(3) 3,088.69 62.83 54.98 2,527.10 2,432.88 634.44 1,066.84 5,959,808.45 1,701,764.33 1.59 510.01 MWD+IFR-AK-CAZ-SC(3) 3,183.85 62.62 54.40 2,570.71 2,476.49 683.33 1,135.86 5,959,857.89 1,701,832.95 0.58 538.51 MWD+IFR-AK-CAZ-SC(3) 3,277.65 62.75 54.60 2,613.75 2,519.53 731.72 1,203.71 5,959,906.82 1,701,900.40 0.23 566.33 MWD+IFR-AK-CAZ-SC(3) 3,370.92 62.75 53.82 2,656.46 2,562.24 780.21 1,270.97 5,959,955.85 1,701,967.27 0.74 593.61 MWD+IFR-AK-CAZ-SC(3) 3,465.05 62.76 52.76 2,699.55 2,605.33 830.24 1,338.06 5,960,006.40 1,702,033.94 1.00 619.87 MWD+IFR-AK-CAZ-SC(3) 3,557.55 62.79 52.53 2,741.87 2,647.65 880.14 1,403.44 5,960,056.83 1,702,098.92 0.22 644.80 MWD+IFR-AK-CAZ-SC(3) 3,650.50 62.65 53.37 2,784.47 2,690.25 929.92 1,469.38 5,960,107.12 1,702,164.44 0.82 670.26 MWD+IFR-AK-CAZ-SC(3) 3,744.05 62.68 54.53 2,827.43 2,733.21 978.82 1,536.56 5,960,156.56 1,702,231.23 1.10 697.25 MWD+IFR-AK-CAZ-SC(3) 3,836.00 62.79 54.42 2,869.56 2,775.34 1,026.32 1,603.08 5,960,204.58 1,702,297.36 0.16 724.50 MWD+IFR-AK-CAZ-SC(3) 3,929.48 63.01 54.93 2,912.14 2,817.92 1,074.43 1,670.98 5,960,253.24 1,702,364.86 0.54 752.52 MWD+IFR-AK-CAZ-SC(3) 4,021.91 63.09 54.78 2,954.03 2,859.81 1,121.86 1,738.35 5,960,301.20 1,702,431.84 0.17 780.50 MWD+IFR-AK-CAZ-SC(3) 4,114.75 64.06 54.20 2,995.35 2,901.13 1,170.15 1,806.03 5,960,350.03 1,702,499.12 1.19 808.24 MWD+IFR-AK-CAZ-SC(3) 4,207.54 63.74 54.02 3,036.17 2,941.95 1,219.00 1,873.53 5,960,399.41 1,702,566.23 0.39 835.52 MWD+IFR-AK-CAZ-SC(3) 4,299.13 64.01 53.94 3,076.50 2,982.28 1,267.36 1,940.04 5,960,448.30 1,702,632.34 0.31 862.26 MWD+I FR-AK-CAZ-SC(3) 4,393.83 63.93 55.01 3,118.06 3,023.84 1,316.80 2,009.30 5,960,498.29 1,702,701.19 1.02 890.63 MWD+IFR-AK-CAZ-SC(3) 4,487.00 64.17 57.95 3,158.83 3,064.61 1,363.06 2,079.13 5,960,545.10 1,702,770.65 2.85 921.31 MWD+IFR-AK-CAZ-SC(3) 4,581.12 65.37 62.47 3,198.97 3,104.75 1,405.33 2,153.00 5,960,587.96 1,702,844.17 4.53 957.57 MWD+IFR-AK-CAZSC(3) 4,675.15 66.22 67.26 3,237.54 3,143.32 1,441.73 2,230.62 5,960,624.98 1,702,921.48 4.73 1,000.27 MWD+IFR-AK-CAZ-SC(3) 4,718.78 66.37 69.85 3,255.08 3,160.86 1,456.34 2,267.80 5,960,639.88 1,702,958.54 5.45 1,022.35 MWD+IFR-AK-CAZ-SC(3) 4,768.05 66.51 71.61 3,274.78 3,180.56 1,471.24 2,310.43 5,960,655.12 1,703,001.05 3.29 1,048.72 MWD+IFR-AK-CAZSC(3) 4,860.41 67.41 71.98 3,310.93 3,216.71 1,497.79 2,391.17 5,960,682.32 1,703,081.56 1.04 1,099.63 MWD+IFR-AK-CAZ-SC(3) 3/24/2015 2:39:15PM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,953.04 68.52 71.70 3,345.68 3,251.46 1,524.55 2,472.75 5,960,709.73 1,703,162.92 1.23 1,151.11 MWD+IFR-AK-CAZ-SC(3) 5,047.41 68.63 71.61 3,380.15 3,285.93 1,552.20 2,556.14 5,960,738.05 1,703,246.07 0.15 1,203.56 MWD+IFR-AK-CAZ-SC(3) 5,139.93 68.54 74.60 3,413.94 3,319.72 1,577.23 2,638.54 5,960,763.73 1,703,328.26 3.01 1,256.70 MWD+IFR-AK-CAZ-SC(3) 5,234.19 68.68 78.25 3,448.33 3,354.11 1,597.83 2,723.84 5,960,785.01 1,703,413.38 3.61 1,314.76 MWD+IFR-AK-CAZ-SC(3) 5,327.71 69.44 83.19 3,481.77 3,387.55 1,611.90 2,810.00 5,960,799.77 1,703,499.43 5.00 1,377.28 MWD+IFR-AK-CAZ-SC(3) 5,420.25 69.92 88.02 3,513.92 3,419.70 1,618.54 2,896.50 5,960,807.10 1,703,585.86 4.92 1,444.32 MWD+IFR-AK-CAZ-SC(3) 5,512.79 70.30 91.53 3,545.41 3,451.19 1,618.88 2,983.50 5,960,808.14 1,703,672.85 3.59 1,515.39 MWD+IFR-AK-CAZ-SC(3) 5,606.16 71.30 97.00 3,576.14 3,481.92 1,612.31 3,071.39 5,960,802.28 1,703,760.78 5.63 1,591.15 MWD+IFR-AK-CAZ-SC(3) 5,699.12 71.51 101.39 3,605.79 3,511.57 1,598.23 3,158.34 5,960,788.90 1,703,847.83 4.48 1,670.45 MWD+IFR-AK-CAZ-SC(3) 5,791.44 71.98 106.92 3,634.73 3,540.51 1,576.80 3,243.31 5,960,768.15 1,703,932.96 5.71 1,752.35 MWD+IFR-AK-CAZ-SC(3) 5,883.60 72.55 110.49 3,662.81 3,568.59 1,548.65 3,326.44 5,960,740.67 1,704,016.30 3.74 1,836.59 MWD+IFR-AK-CAZ-SC(3) 5,976.54 74.09 114.87 3,689.50 3,595.28 1,514.32 3,408.55 5,960,707.00 1,704,098.68 4.81 1,923.54 MWD+IFR-AK-CAZ-SC(3) 6,069.65 75.98 119.24 3,713.55 3,619.33 1,473.40 3,488.63 5,960,666.74 1,704,179.07 4.97 2,012.61 MWD+IFR-AK-CAZ-SC(3) 6,118.45 77.07 122.60 3,724.93 3,630.71 1,449.02 3,529.33 5,960,642.68 1,704,219.97 7.06 2,059.93 MWD+IFR-AK-CAZ-SC(3) 6,164.32 78.17 125.54 3,734.77 3,640.55 1,423.92 3,566.44 5,960,617.88 1,704,257.27 6.70 2,104.73 MWD+IFR-AK-CAZ-SC(3) 6,214.72 79.80 127.69 3,744.40 3,650.18 1,394.41 3,606.14 5,960,588.70 1,704,297.21 5.29 2,154.17 MWD+IFR-AK-CAZ-SC(3) 6,256.69 80.69 130.27 3,751.51 3,657.29 1,368.40 3,638.29 5,960,562.94 1,704,329.56 6.42 2,195.43 MWD+IFR-AK-CAZ-SC(3) 6,302.09 81.69 132.29 3,758.46 3,664.24 1,338.80 3,672.00 5,960,533.62 1,704,363.51 4.92 2,240.02 MWD+IFR-AK-CAZ-SC(3) 6,351.73 82.45 135.06 3,765.31 3,671.09 1,304.85 3,707.56 5,960,499.96 1,704,399.33 5.73 2,288.62 MWD+IFR-AK-CAZ-SC(3) 6,397.10 83.04 137.84 3,771.04 3,676.82 1,272.23 3,738.56 5,960,467.60 1,704,430.59 6.22 2,332.73 MWD+IFR-AK-CAZ-SC(3) 6,445.15 83.65 140.31 3,776.61 3,682.39 1,236.18 3,769.82 5,960,431.80 1,704,462.14 5.26 2,379.02 MWD+IFR-AK-CAZ-SC(3) 6,494.14 84.05 142.76 3,781.86 3,687.64 1,198.04 3,800.12 5,960,393.91 1,704,492.74 5.04 2,425.71 MWD+IFR-AK-CAZ-SC(3) 6,537.57 84.03 145.24 3,786.37 3,692.15 1,163.10 3,825.51 5,960,359.17 1,704,518.40 5.68 2,466.55 MWD+IFR-AK-CAZ-SC(3) 6,599.87 85.49 147.77 3,792.06 3,697.84 1,111.37 3,859.74 5,960,307.72 1,704,553.04 4.67 2,524.26 MWD+IFR-AK-CAZ-SC(3) 6,655.00 85.25 147.46 3,796.51 3,702.29 1,064.96 3,889.17 5,960,261.56 1,704,582.84 0.70 2,574.98 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 6,695.17 85.08 147.24 3,799.90 3,705.68 1,031.26 3,910.76 5,960,228.04 1,704,604.70 0.70 2,612.00 MWD+IFR-AK-CAZ-SC(4) 6,754.31 85.66 146.89 3,804.67 3,710.45 981.79 3,942.81 5,960,178.83 1,704,637.14 1.14 2,666.63 MWD+IFR-AK-CAZ-SC(4) 6,851.27 88.64 146.37 3,809.49 3,715.27 900.92 3,996.07 5,960,098.40 1,704,691.05 3.12 2,756.64 MWD+IFR-AK-CAZ-SC(4) 6,943.13 90.15 145.85 3,810.46 3,716.24 824.67 4,047.29 5,960,022.57 1,704,742.87 1.74 2,842.33 MWD+IFR-AK-CAZ-SC(4) 7,039.32 90.48 147.09 3,809.93 3,715.71 744.49 4,100.42 5,959,942.83 1,704,796.64 1.33 2,931.84 MWD+IFR-AK-CAZ-SC(4) 7,132.51 90.51 147.42 3,809.13 3,714.91 666.11 4,150.82 5,959,864.86 1,704,847.66 0.36 3,018.09 MWD+IFR-AK-CAZ-SC(4) 7,230.39 90.68 148.68 3,808.11 3,713.89 583.07 4,202.62 5,959,782.24 1,704,900.12 1.30 3,108.15 MWD+IFR-AK-CAZ-SC(4) 7,320.99 90.38 150.62 3,807.27 3,713.05 504.89 4,248.39 5,959,704.44 1,704,946.51 2.17 3,190.48 MWD+IFR-AK-CAZ-SC(4) 7,415.38 89.14 150.76 3,807.67 3,713.45 422.59 4,294.60 5,959,622.52 1,704,993.37 1.32 3,275.54 MWD+IFR-AK-CAZ-SC(4) 7,509.25 88.73 150.35 3,809.41 3,715.19 340.86 4,340.73 5,959,541.17 1,705,040.16 0.62 3,360.21 MWD+IFR-AK-CAZ-SC(4) 7,602.31 88.14 150.88 3,811.95 3,717.73 259.80 4,386.38 5,959,460.49 1,705,086.45 0.85 3,444.10 MWD+IFR-AK-CAZ-SC(4) 7,697.82 88.73 151.44 3,814.56 3,720.34 176.17 4,432.43 5,959,377.24 1,705,133.17 0.85 3,529.79 MWD+IFR-AK-CAZ-SC(4) 7,792.96 89.22 152.58 3,816.26 3,722.04 92.17 4,477.07 5,959,293.61 1,705,178.48 1.30 3,614.54 MWD+IFR-AK-CAZ-SC(4) 7,888.38 88.49 153.52 3,818.17 3,723.95 7.13 4,520.31 5,959,208.93 1,705,222.39 1.25 3,698.73 MWD+IFR-AK-CAZ-SC(4) 7,983.38 88.35 152.94 3,820.79 3,726.57 -77.65 4,563.08 5,959,124.50 1,705,265.84 0.63 3,782.40 MWD+IFR-AK-CAZ-SC(4) 8,077.59 88.42 150.04 3,823.44 3,729.22 -160.40 4,608.03 5,959,042.13 1,705,311.44 3.08 3,866.67 MWD+IFR-AK-CAZ-SC(4) 8,173.43 88.25 148.04 3,826.23 3,732.01 -242.54 4,657.31 5,958,960.39 1,705,361.37 2.09 3,954.16 MWD+IFR-AK-CAZ-SC(4) 8,268.86 88.49 148.48 3,828.94 3,734.72 -323.67 4,707.49 5,958,879.68 1,705,412.20 0.53 4,041.80 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:39:15PM Page 4 COMPASS 5000.1 Build 65 • . Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100) (ft) Survey Tool Name 8,363.21 89.28 150.55 3,830.78 3,736.56 -404.95 4,755.34 5,958,798.78 1,705,460.70 2.35 4,127.62 MWD+IFR-AK-CAZ-SC(4) 8,455.43 89.69 150.67 3,831.61 3,737.39 -485.30 4,800.60 5,958,718.81 1,705,506.59 0.46 4,210.78 MWD+IFR-AK-CAZ-SC(4) 8,547.63 89.66 150.69 3,832.13 3,737.91 -565.69 4,845.75 5,958,638.79 1,705,552.38 0.04 4,293.87 MWD+IFR-AK-CAZ-SC(4) 8,644.41 89.66 153.13 3,832.71 3,738.49 -651.06 4,891.31 5,958,553.80 1,705,598.62 2.52 4,380.16 MWD+IFR-AK-CAZ-SC(4) 8,740.54 89.79 153.46 3,833.17 3,738.95 -736.94 4,934.51 5,958,468.28 1,705,642.51 0.37 4,464.80 MWD+IFR-AK-CAZ-SC(4) 8,833.16 89.62 155.82 3,833.65 3,739.43 -820.62 4,974.18 5,958,384.92 1,705,682.84 2.55 4,545.30 MWD+IFR-AK-CAZ-SC(4) 8,929.57 89.21 158.62 3,834.63 3,740.41 -909.50 5,011.50 5,958,296.36 1,705,720.87 2.94 4,626.85 MWD+IFR-AK-CAZ-SC(4) 9,019.88 89.31 158.80 3,835.80 3,741.58 -993.64 5,044.29 5,958,212.49 1,705,754.33 0.23 4,701.97 MWD+I FR-AK-CAZ-SC(4) 9,118.37 89.72 159.50 3,836.63 3,742.41 -1,085.68 5,079.34 5,958,120.75 1,705,790.12 0.82 4,783.47 MWD+I FR-AK-CAZ-SC(4) 9,213.31 90.99 159.52 3,836.04 3,741.82 -1,174.61 5,112.58 5,958,032.09 1,705,824.06 1.34 4,861.70 MWD+I FR-AK-CAZ-SC(4) 9,307.87 92.24 160.30 3,833.38 3,739.16 -1,263.37 5,145.04 5,957,943.60 1,705,857.23 1.56 4,939.21 MWD+I FR-AK-CAZ-SC(4) 9,402.51 92.23 158.48 3,829.69 3,735.47 -1,351.89 5,178.33 5,957,855.36 1,705,891.23 1.92 5,017.25 MWD+I FR-AK-CAZ-SC(4) 9,496.69 92.50 160.45 3,825.80 3,731.58 -1,440.00 5,211.34 5,957,767.52 1,705,924.94 2.11 5,094.83 MWD+I FR-AK-CAZ-SC(4) 9,590.82 92.19 162.04 3,821.95 3,727.73 -1,529.06 5,241.57 5,957,678.72 1,705,955.88 1.72 5,170.68 MWD+I FR-AK-CAZ-SC(4) 9,686.29 91.92 163.97 3,818.52 3,724.30 -1,620.29 5,269.46 5,957,587.72 1,705,984.50 2.04 5,245.85 MWD+I FR-AK-CAZ-SC(4) 9,781.57 91.34 165.58 3,815.81 3,721.59 -1,712.19 5,294.47 5,957,496.04 1,706,010.24 1.80 5,319.05 MWD+I FR-AK-CAZ-SC(4) 9,877.24 91.20 166.90 3,813.69 3,719.47 -1,805.09 5,317.22 5,957,403.33 1,706,033.73 1.39 5,390.97 MWD+I FR-AK-CAZ-SC(4) 9,971.65 90.75 168.20 3,812.09 3,717.87 -1,897.26 5,337.57 5,957,311.33 1,706,054.82 1.46 5,460.51 MWD+IFR-AK-CAZ-SC(4) 10,066.29 90.72 171.24 3,810.87 3,716.65 -1,990.37 5,354.46 5,957,218.38 1,706,072.45 3.21 5,527.74 MWD+IFR-AK-CAZ-SC(4) 10,160.19 91.40 172.94 3,809.13 3,714.91 -2,083.35 5,367.38 5,957,125.51 1,706,086.12 1.95 5,591.66 MWD+IFR-AK-CAZ-SC(4) 10,255.10 91.03 176.02 3,807.12 3,712.90 -2,177.79 5,376.50 5,957,031.16 1,706,096.00 3.27 5,653.30 MWD+IFR-AK-CAZ-SC(4) 10,308.15 90.86 178.77 3,806.25 3,712.03 -2,230.77 5,378.91 5,956,978.20 1,706,098.83 5.19 5,685.67 MWD+IFR-AK-CAZ-SC(4) 10,349.01 90.86 179.29 3,805.63 3,711.41 -2,271.62 5,379.60 5,956,937.36 1,706,099.85 1.27 5,709.66 MWD+I FR-AK-CAZ-SC(4) 10,444.46 91.05 184.49 3,804.04 3,709.82 -2,366.97 5,376.46 5,956,842.00 1,706,097.47 5.45 5,761.78 MWD+I FR-AK-CAZ-SC(4) 10,490.22 91.69 187.38 3,802.95 3,708.73 -2,412.47 5,371.73 5,956,796.47 1,706,093.11 6.47 5,784.00 MW D+I FR-AK-CAZ-SC(4) 10,539.15 90.39 189.41 3,802.06 3,707.84 -2,460.86 5,364.59 5,956,748.02 1,706,086.36 4.93 5,805.91 MWD+IFR-AK-CAZ-SC(4) 10,634.95 90.09 189.84 3,801.66 3,707.44 -2,555.31 5,348.57 5,956,653.46 1,706,071.10 0.55 5,846.96 MW D+I FR-AK-CAZ-SC(4) 10,686.85 90.65 190.01 3,801.32 3,707.10 -2,606.44 5,339.62 5,956,602.27 1,706,062.56 1.13 5,868.95 MW D+I FR-AK-CAZ-SC(4) 10,729.46 90.96 189.98 3,800.72 3,706.50 -2,648.40 5,332.23 5,956,560.26 1,706,055.51 0.73 5,886.96 MWD+IFR-AK-CAZ-SC(4) 10,777.22 91.10 188.84 3,799.86 3,705.64 -2,695.50 5,324.42 5,956,513.09 1,706,048.08 2.40 5,907.59 MWD+I FR-AK-CAZ-SC(4) 10,823.57 91.27 187.66 3,798.91 3,704.69 -2,741.36 5,317.77 5,956,467.18 1,706,041.80 2.57 5,928.45 MWD+I FR-AK-CAZ-SC(4) 10,915.49 91.58 185.79 3,796.62 3,702.40 -2,832.62 5,307.01 5,956,375.85 1,706,031.77 2.06 5,971.97 MWD+I FR-AK-CAZ-SC(4) 11,009.89 91.64 185.21 3,793.97 3,699.75 -2,926.55 5,297.97 5,956,281.86 1,706,023.48 0.62 6,018.44 MWD+I FR-AK-CAZ-SC(4) 11,104.71 91.13 184.28 3,791.68 3,697.46 -3,021.01 5,290.13 5,956,187.35 1,706,016.40 1.12 6,066.20 MWD+I FR-AK-CAZ-SC(4) 11,199.25 91.10 184.58 3,789.84 3,695.62 -3,115.25 5,282.82 5,956,093.06 1,706,009.85 0.32 6,114.27 MWD+IFR-AK-CAZ-SC(4) 11,295.02 90.62 184.61 3,788.40 3,694.18 -3,210.70 5,275.15 5,955,997.56 1,706,002.95 0.50 6,162.74 MWD+IFR-AK-CAZ-SC(4) 11,387.67 90.41 183.44 3,787.57 3,693.35 -3,303.12 5,268.65 5,955,905.10 1,705,997.19 1.28 6,210.42 MWD+I FR-AK-CAZ-SC(4) 11,483.31 90.58 183.96 3,786.74 3,692.52 -3,398.56 5,262.48 5,955,809.63 1,705,991.78 0.57 6,260.10 MWD+I FR-AK-CAZ-SC(4) 11,577.50 90.31 185.36 3,786.01 3,691.79 -3,492.43 5,254.83 5,955,715.71 1,705,984.89 1.51 6,307.68 MWD+I FR-AK-CAZ-SC(4) 11,673.72 90.00 187.76 3,785.75 3,691.53 -3,588.01 5,243.84 5,955,620.05 1,705,974.66 2.51 6,353.50 MWD+I FR-AK-CAZ-SC(4) 11,767.87 89.07 190.49 3,786.51 3,692.29 -3,680.96 5,228.91 5,955,527.00 1,705,960.48 3.06 6,394.58 MWD+IFR-AK-CAZ-SC(4) 11,863.36 88.63 191.09 3,788.43 3,694.21 -3,774.74 5,211.03 5,955,433.08 1,705,943.36 0.78 6,433.73 MWD+I FR-AK-CAZ-SC(4) 11,957.82 88.39 190.45 3,790.88 3,696.66 -3,867.51 5,193.39 5,955,340.19 1,705,926.46 0.72 6,472.48 MWD+I FR-AK-CAZ-SC(4) 12,053.25 88.76 190.12 3,793.26 3,699.04 -3,961.37 5,176.36 5,955,246.20 1,705,910.19 0.52 6,512.37 MWD+IFR-AK-CAZ-SC(4) 3/24/2015 2:39:15PM Page 5 COMPASS 5000.1 Build 65 • • . 1.- Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-142 Project: Kuparuk River Unit TVD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 2L-328:66.8+27.42 @ 94.22usft(Doyon 141) Well: 1D-142 North Reference: True Wellbore: 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,145.63 88.73 189.54 3,795.28 3,701.06 -4,052.37 5,160.59 5,955,155.08 1,705,895.15 0.63 6,551.65 MWD+IFR-AK-CAZ-SC(4) 12,209.20 88.83 188.78 3,796.63 3,702.41 -4,115.12 5,150.47 5,955,092.26 1,705,885.54 1.21 6,579.35 MWD+IFR-AK-CAZ-SC(4) 12,270.00 88.83 188.78 3,797.88 3,703.66 -4,175.19 5,141.19 5,955,032.12 1,705,876.74 0.00 6,606.21 PROJECTED to TD Projected to TD 3/24/2015 2:39:15PM Page 6 COMPASS 5000.1 Build 65 • P T IJ Z11— t 41 Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Sunday, March 22, 2015 9:57 AM To: Loepp,Victoria T (DOA) Cc: Schwartz, Guy L (DOA) Subject: Re: [EXTERNAL]Re: 1D-142 (PTD 214-149)Intermediate Cement Log Follow Up Flag: Follow up Flag Status: Flagged Ok,thanks ! Will send full log once we have it . David On Mar 22, 2015,at 9:48 AM, "Loepp, Victoria T(DOA)"<victoria.loepp@alaska.gov<mailto:victoria.loepp@alaska.gov>> wrote: David, Option 2 sounds acceptable. Please run the wireline CBL after running the lower completion and prior to running tubing. Thanx, Victoria On Mar 22, 2015,at 8:27 AM, Lee, David L<David.L.Lee@conocophillips.com<mailto:David.L.Lee@conocophillips.com» wrote: Morning Victoria,this morning we downloaded our lateral drilling BHA once we got it to surface after TD'ing our well. We had a sonic tool in our string that we were going to use for cement evaluation as 1D-142 is an injector. The results show that we have good cement coverage from 2670 to 4500' MD but at 4500'the tools memory ran out(damaged memory chip). The cement bond log that we did receive is attached below. The tool was supposed to be recording all the way to TD of our intermediate casing shoe. Currently we are picking up HWDP to run our lower completion. We will be ready to run our lower completion around lunch time today. I see it as we have 3 options: 1. Delay running our lower completion to run a wireline CBL. This would get our CBL right to our intermediate casing shoe however it would add addition risk to getting our already challenge heavy ICD liner to TD 2. We could run our lower completion and run another wireline CBL after we set our liner hanger and top packer prior to running tubing. This would allow us to get our ICD liner to TD in a timely fashion however we would not have a log over where our liner lap would be 3. We can use this log as proof of a good cement job and not do a dedicated wireline run. We can justify it by knowing we pumped enough cement to bring cement that high in our annulus. Also since the cement log shows we have good cement from^2700'to 4500' (1800'of annulus length)we could assume we also have good cement from 4500' -6600' MD. 1 • • Please advise on what your thoughts are. I will call to discuss this morning. Thanks in advance David <ConocoPhillips_1D-142_SonicScope_Top_of_Cement.pdf> 2 • • PTO 2/4 - /4q Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Saturday, March 07, 2015 2:13 PM To: Lee, David L Cc: Schwartz, Guy L (DOA) Subject: Re: 1D-142 - 214-149 Surface Casing LOT You have approval to proceed as outlined below. Let me know your FIT on your next attempt. Thanx, Victoria Sent from my iPhone On Mar 7, 2015, at 9:13 AM, Lee, David L<David.L.Lee@conocophillips.com>wrote: Morning Victoria,to follow up with our operation. We performed our LCM squeeze yesterday afternoon (we used FORMABLOK). After drilling out the FORMABLOK squeeze we were still not able to get the leak off we wanted to drill ahead. We were able to get up to 12.0 ppg EMW but then our pressure bled off to 30 psi. We have decided to pump another cement plug to try and allow us to get a decent FIT on our shoe. We will be pumping another 25 bbl cement plug starting at our current TD of 2693' MD. We should be pumping cement early afternoon. After our cement is pumped we are going to wait till it reaches 100 psi compressive strength prior to drilling out(a little softer than last time to try and stay drilling the cement plug and not kicking off and drilling formation)and once it reaches 100 psi drill down to 2673' MD (the depth of our original surface hole). At this depth we would like approval to do our leak off test (will not be 20' of new hole) and consider a valid LOT(leak off test will probably be being performed tonight around midnight). The reason being, if we try to drill the 20' again to get to our LOT depth of 2693' we are at risk of slipping off the plug again and opening up the weak formation that is below our shoe. If we got a good test at 2673' MD and have your approval to consider it a valid FIT we would drill ahead and deal with the weak formation with LCM as we are drilling. Would the AOGCC consider allowing us to perform our LOT at 2673' MD? If you would like to discuss on the phone please call my cell—231-7613 Thanks David From: Lee, David L Sent: Wednesday, March 04, 2015 4:46 PM To: Loepp, Victoria L(DOA) (victoria.loepp@alaska.gov) Subject: 1D-142 - 214-149 Surface Casing LOT Good afternoon Victoria, as we discussed on the phone, Doyon 141 is currently drilling 1D-142. We have drilled our surface hole down to 2673' MD and ran and cemented our surface casing to 2662' MD. • This afternoon we drilled out our surface casing(down to 2662') and drilled our rat hole (down to 2673') with no issues. We continued drilling ahead to drill our 20'in order to do our LOT. We drilled down to 2683'with no issues, after we drilled to 2684' MD we started seeing losses @ 40 BPH. We continued drilling ahead to 2693' MD so that we had our 20' in order to do our leak off test. Even though we had dynamic losses (no losses when static)we tried to do leak off test with no luck,we picked our LOT at an 11.2 ppg EMW. Since we were able to drill 10' prior to seeing losses we think that our losses are going into formation (geologically related) and are not due to a poor cement job and a poor surface casing shoe. Plan Forward Here is our current plan forward. We want to drill 15' more down to 2708' MD. The purpose of this is to get through the sandy interval where we think we are losing to. We would then pull out of hole and run in hole with a cement stinger and pump a cement plug. We would pull above the cement plug and perform a hesitation squeeze to try and squeeze cement into formation. We would then pull out of hole with cement stinger, and run back in hole with our drilling BHA. We would drill down to 2693' MD and do another LOT(up to 12.0 ppg EMW(Required to drill ahead)). This is to confirm the integrity of our surface casing shoe. After this LOT we would drill down through the rest of our cement plug to 2708' MD and 15' of new hole to 2723' MD. At this point we would do another LOT to confirm we have cured our loss interval. Are you ok with the plan forward? Any questions? Thanks David 2 SOF Titzr, 0 ,,i, //7;.7 ,.v., THE STATE 1,'a;t�� Cirz� ,-+ �/ice r►T'A �� , �.� rye,., (''- ---177- .f‘. i9" x - - 333 West Seventh Avenue L'I ✓' s GOVERNOR Si ELL AN PARNAnchorage, Alaska 99501-3572 �'� Main: 907 279 1433 4LAS, FC;:: 907.?7c.75,12 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1D-142 ConocoPhillips Alaska, Inc. Permit No: 214-149 Surface Location: 250' FNL, 416.6' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 4731' FNL, 611' FEL, SEC. 24, T11N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ) ' e.),,,./t.(-- Cathy P. Foerster Chair DATED this day of October, 2014. • 11 [RECEIVED STATE OF ALASKA UT 0 .i ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILLAO CC 20 AAC 25.005 _Vi t - tO /4 3 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 0 Service- Win) ❑D • Single Zone 0, lc.Specify if well i proposed for: Drill. 0 Lateral ❑ Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Redril 0 Reentry 0 Exploratory 0 Service- WAG 0 Service-Disp 0 Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket El Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 1 D-142 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12641' • TVD: 3769'. Kuparuk River Field' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 250'FNL 416.6'FEL,Sec.23 Twn 11N Rng 10 E,UM • ADL 25650 ' West Sak Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4176'FNL 2036'FEL,Sec.13 Twn 11N Rng 10E,UM ALK 468 11/1/2014 Total Depth: 9.Acres In Property: 14.Distance to Nearest Property: 4731'FNL 611'FEL,Sec.24 Twn 11N Rng 10E,UM . 2560 280 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 98.7 feet 15.Distance to Nearest Well Open Surface: x-560673 y- 5959416 Zone-4 • GL Elevation above I 70.7 feet to Same Pool: 550 ft 16.Deviated wells: Kickoff depth: 600 feet. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle:It 5141,4.7 degrees Downhole: 1867 psi • Surface: 1447 psi ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 24" 16' 62.5# H40 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2707' 28' 28' 2707' 2350' 1270 sx DeepCRETE,205 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 6578' 28' 28' 6578' 3777' 730 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 6263' 6378' 3757' 12641' 3769' ICD Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program ❑� Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 4'' i• 22. I hereby certify that the foregoing is true and correct. David Lie 0-26-741 Contact '' Email david.I.Ieeaconocoph it lips.com Printed Name G.Alvord Title Alaska Drilling Manager Signature /4•06"e^t2.. Phone 265-6120 Date (4 t(14_ Commission Use Only Permit to Drill API Number: q Permit Approval /� See cover letter for other Number: OLt- '� 50-09\9-02on -00 -00 Date: 101 "f�,i requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: [✓]/ Other: Samples req'd: YesRNo 1E1 Mud log req'd:Yes❑ No ,7 jj o P t e J t v SD s, • H2S measures: Yes No❑ Directional svy req'd:Yes[/( No❑ Nhr 5 4vf4. feif to 2aO P5i Sf"ectc- v✓i to r 5 5 CC//Lt 1 T-/4 t-e ,,,r_e.,cing exception req'd: Yes❑ NO[3� Inclination-only svy req'd:Yes❑ No[.g a ft-c-)-- 5 t b.1/Jtc) .Y1Jccti -, • n,. APPROVED BY C / Approved by: .1--•-•/( I COMMISSIONER THE COMMISSION Date:�� / Cubmit form and Form 10-401(Re iced 10/2012) This permit is valid fo 24 months from the date of a v )) Attachments in Duplicate VI- /a/3///' ? i0/&IIII � � �y !0 °I` 11 AL STATE OF ALASKA RECEIVED VD 4 ALGA OIL AND GAS CONSERVATION COMMON SEP 19 2014 PERMIT TO DRILL 20 AAC 25.005 � la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑✓ • Single Zone 0. 1 c.Specify if�is rop ed or: Drill . 0 Lateral ❑ Stratigraphic Test El Development-Gas 0 Service-Supply El Multiple Zone ❑ Coalbed Gas 0 Ga Hydrates ❑ Redril❑ Reentry ❑ Exploratory 0 Service- WAG 0 Service-Disp ❑ Geothermal ❑'ale Gas El2.Operator Name: 5. Bond: Blanket 0, Single Well El 11.Well Name an Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 • 1D-142 % / 3.Address: 6.Proposed Depth: 12.Field/Pool ): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12665' • ND: 3769' . Kuparuk Ri>r Field . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): / yr Surface: 267.6'FNL 419.3'FEL,Sec.23 Twn 11N Rng 10 E,UM` ADL 25650 • West .•k Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.41proximate Spud Date: 4172'FNL 2042'FEL,Sec.13 Twn 11N Rng 10E,UM - ALK 46811/1/2014 Total Depth: 9.Acres in Property: 1 Distance to Nearest Property: 4731'FNL 611'FEL,Sec.24 Twn 11N Rng 10E,UM • i 2560/ 280 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 98.7 feet / 15.Distance to Nearest Well Open Surface: x- 560670 y- 5959398.5 Zone-4 - GL Elevation above I 70.7 feet'. to Same Pool: 550 ft 16.Deviated wells: Kickoff depth: 600 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91.17 degrees% Downhole: 1867 psi• Surface: 1447 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottp1 Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD /`r ND (including stage data) 24" 16" 62.5# H40 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE / 13.5" 10.75" 45.5# L-80 Hydril 563 2667' 28' 28' 2667' / 2350' 1270 sx DeepCRETE,205 sx / DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 6601' 28' 28' 641' 3777' 730 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 6264' 6401' 3755' /0665' 3769' ICD Liner Completion(no cement) \/ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Re. ilt id Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.,i,' h MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cent Volume MD TVD Conductor/Structural 4/ \'..b Intermediate CY Production Liner Perforation Depth MD(ft): r rforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch rilling Program 0 Time v.Depth Plot Shallow Hazard Analysis❑ Diverter Sketch❑ ,-/ Seabed Report ❑ Drilling Fluid Program ❑ 20 P4c 2 .050 requirements0 21. Verbal Approval: Commission Representative: /� Date 9_ ,-11 26 22. I hereby certify that the foregoing is true and correct. / David Lee @ 263-3741 Contact david.I.Iee4conocophiilips.com Email Printed Name G.Alvord ✓� Title Alaska Drilling Manager Signature .1-0 / D Phone 265-6120 Date `�`16(Z.a (4- ' Commission Use Only Permit to Drill Numb/r: _ Permit Approval See cover letter for other Number: P(.11-1- I f /50-0Z9 "�,3 S 49 -0D -00 Date: requirements. Conditions of approval: If box is chec9ed,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [� Other: 80 p f es3 to 350O P5 i - Samples req'd: Yes No[a' Mud log req'd:Yes EL No[d� O 19 5 r : H2S measures: Yes No Directional svyreq'd:Yes No ,�}� rrul ar �'t5f°'to 25 p � ❑ q' � ❑ , "/II-a_.1 c ra/r;n<55,'c M 17-/!l rtel�i r' Spacing exception req'd: Yes❑ NOM Inclination-only svy req'd:Yes❑ No g afttr sta bi•l,3 CGI I'n fc-cA-ici i _ APPROVED BY Approved by: ,,,��pppp� I I N�j{JAR THE COMMISSION Date: G. � Subs in dorm and Form 10-401(Revised 10/2012) This permit is v- f r 4 n.p,IT� r It of approval( 0AAC 25.005(g)) Attachments in Duplicate VL /0/2/j4 el<3 q/i o �i-ll _,./ • Conoco?'hiIIips RECEIVED Alaska SEP 19 2014 Post Office Box 100360 AOGCC Anchorage, Alaska 99510-0360 David Lee Phone (907) 263-3741 July 16, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1D-142 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore injector well, a horizontal well in the West Sak"D"sand. The expected spud date for 1D-142 is, November 1St 2014. The West Sak in the 1D area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1D-142 well will be drilled in the D Sand, up structure to the South with a planned lateral length of approximately 6065'. No fault crossings have been identified along the planned well path. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 9.4 ppg equivalent during the drilling of this well. A FIT test to a minimum of 12.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 12.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1D-142. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi)and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sinc ely, David Lee Kuparuk Drilling Engineer • /Dation for Permit to Drill,Well 1D-142 Revision No.O Saved: 18-Sep-14 Permit It - West Sak Well #1D-142 r., Application for Permit to Drill Document •;~� MaxWell M i x i in i a g Well VcIVe Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (t) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005 (c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 5. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI Flo-Pro WBM) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 9. Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 10.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005 (c)(11) 6 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 10-142 PERMIT.doc Page 1 of 7 Printed: 18-Sep-14 • P ation for Permit to Drill,Well 1 D-142 Revision No.0 Saved: 18-Sep-14 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Program Summary 7 Attachment 4 Well Schematic 7 Attachment 5 Injection Documentation 7 1. Well Name Requirements of 20 AAC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-142.' 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 267.6' FNL 419.3' FEL Sec. 23 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 98.7'AMSL Northings 5,959,398.5 Eastings:560,670.0 Pad Elevation 70.7'AMSL Location at Top of Productive Interval 4172' FNL 2042'FEL Sec. 13 Twn 11N Rng 10E UM (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6376' Northings: 5,960,804.7 Eastings:564,314.6 Total Vertical Depth, RKB: 3752' Total Vertical Depth, SS:: 3653' Location at Total Depth 4731' FNL 611.2' FEL Sec. 24 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12665' Northings: 5,954,978.5 Eastings: 565,796.9 Total Vertical Depth, RKB: 3769' Total Vertical Depth, SS:: 3670' and (D)other information required by 20 AAC 25.050(6); 10-142 PERMIT.doc RIGINAL Page2of7 Printed: 18-Sep-14 Ailkation for Permit to Drill,Well 1 D-142 Revision No.0 Saved: 18-Sep-14 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1D-142 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1D-142. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1D area are 0.489 psi/ft, or 9.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,447 psi, calculated thusly: MPSP = (3818 ft TVD)(0.489 - 0.11 psi/ft) = 1,447 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1D-142 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(1); 1D-142 will be completed with a 7-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1D-142 PERMIT.doc `R S" n I Page 3 of 7 1 G I N H L Printed: 18-Sep-14 isakation for Permit to Drill,Well 1D-142 Revision No.0 Saved: 18-Sep-14 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H40 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 10.75 13.5 45.5 L-80 Hydril 563 2667 28/ 28 2667/ 2350 1270 sx it ppg DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 3900' 7.625 9.875 29.7 L-80 Hydril 563 6601 28/ 28 6601 / 3777 MD/2873'TVD Cemented w/ 730 sx 15.8 ppg Class 4.5 6.75 11.6 L-80 Hydril 563 6264 6401 / 3755 12665 / 3769 ICD—no cement ICD 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-142 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1D-142 PERMIT.doc Page 4 of 7 0 -RIGINAL Printed: 18-Sep-14 illation for Permit to Drill,Well 1D-142 Revision No.0 Saved: 18-Sep-14 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 - 9.2 LSYP 30 - 50 (cP) API Fluid Loss No Control (mL/30 min) Chlorides(mg/L) <1000 pH 10.8 — 11.2 Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI Flo-Pro WBM) Value 10,75"Csg Shoe to 7-5/8"Csg Point Density(ppg) 9.6—9.8 Value Fann 35 6 RPM Density(ppg) 9.2 - 9.6 (lb/100 ft2) 4 -8 Fann 35 6 RPM 10 12 HTHP Fluid Loss <5 (lb/100 ft2) (m1/30min) API Filtrate <6 Kla-Stop 2-3% (cc/30 min) pH 9.5 - 10.0 pH 9.5 — 10.0 Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1D-142 PERMITdoc Page 5 of 7 Printed: 18-Sep-14 U R I G I N A L 110 ( tion for Permit to Drill,Well 1D-142 Revision No.0 Saved: 18-Sep-14 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box; set and cement 16"x 24"insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13.5"hole to casing point at +/- 2667'MD/ 2350'TVD as per directional plan. Run MWD tools as required for directional monitoring. 6 '..' 4 , TESTSfivI�� I /►f..„,ra11 cl7css.1-7 '" 4. Run and cement 10.75", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9.875"bit and 6.75"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 4.cn`1 ; 1L S;Skv, 7. Drill out cement and between 20'and 50' of new hole. Perform formatio integrity test to 12.0ppg EMW, recording results. 8. Directionally drill to 7-5/8"casing point at 6601' MD/ 3777'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 7.625", 29.7# L80, Hydril 563 casing to surface. (top of cement to be 3900' MD/ 2873'TVD which corresponds to 566'above the Ugnu C formation). 11. Install wellhead x 7.625" packoff and test to 3500 psi. 12. Flush 10.75"x 7.625"annulus with water, followed by diesel. 13. PU 6.75" PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to jta top of float equipment. Test casing to 3000 psi for 30 minutes. <„w�hu�Jc,, fts4;.,),',ti stin��i s�scar�� 14. A sonic tool will be in the BHA so after casing test perform MAD pass with sonic tool in memory mode to ensure cement quality. 15. Drill out cement and 20'of new hole. Displace hole to lateral drilling Flo-Pro WBM system. Perform formation integrity test to 12.0ppg EMW, recording results. 1D-142 PERMIT.doc Page 6 of 7 rd (•-• I N A L Printed: 18-Sep-14 . tion for Permit to Drill,Well 1 D-142 Revision No.0 Saved: 18-Sep-14 16. Directionally drill 6.75" hole to West Sak D Sand to TD at +/- 12665'MD/ 3769'TVD as per directional plan. 17. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 18. PU and run 4-1/2"ICD liner. 19. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 20. Finish running liner to TD to land liner, then displace well to MI breaker through washpipe. 21. Set liner hanger @ +/- 6401'MD/3755'TVD, set liner top packer. POOH. 22. PU 4.5"tubing as required and RIH to depth. Land tubing. Set BPV 23. Nipple down BOPE, nipple up tree and test. Pull BPV. 24. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 25. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Injection Documentation 1D-142 PERMIT.doc Page 7 of 7 ORIGINAL Printed: 18-Sep-14 • Ferguson, Victoria L (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 01, 2014 5:25 PM To: Loepp, Victoria L(DOA) Cc: Hallford, Kelsey Subject: RE: KRU 1D-142(PTD 214-149)West Sak Follow Up Flag: Follow up Flag Status: Flagged vl -1 ..._ Crl1 - ) Seo ►---) Hi Victoria, answers to questions are below: 1. 1D-142 did not fail anti-collision with 1D-12, it just failed with 1D-117. Did you have a different question regarding 1D-12. 1D-117 went through the Tolerable Collision Risk(TCR) process which is a ConocoPhillips Alaska process. This process accesses the risk of what would happen if we collided with the well that is a concern,and if the risk is deemed acceptable (based on NPV and environmental and safety risks)then the well can be drilled. 1D-117 is an active injector, but ConocoPhillips is going to shut this well in prior to starting drilling 1D-142 and it will stay shut in for the entire length of drilling the well. Since the well will be shut in there will be no risk of a well control issue because if 1D-117 is hit we would be colliding with the well with kill weight fluid in the hole. 2. 1 0 D!`tom' i— 1—c I-- R G v t`c ,w Roti Q ®.S._ 1—D 1 t • ,� 75' Diverter Line 1i,. PM• 140 . _ 165 1q '0, 141 Iv 4 t's" 14 1 a 412. a 2.3It4 . u2 a t ,14 I15 Cf 48 410 u e 4 3D-145 a;ii1 0 28 , k82124 G 59 rf" "31 156 Q?F ,..:k- 1f 133 19 r3 h e4 4. t3+ 19 37 : t 1223 s3 40 io ,.#i a 24 8 11 : .s7 13R 36 R 11) Wile 3. I did not include the mechanical conditions for the West Sak wells as if it is a West Sak well then we will have cement over the west Sak interval, meaning injection from 1D-142 (West Sak Injector)will not get into the annulus of the other West Sak wells as they have cement across that zone. For all the 1D wells that I looked at the cement jobs went as planned. I will have to pull the well file again to get the cement info. 1D-12 had it surface casing set through the west Sak, and then the production section was drilled and cemented. What information are you looking for? Surface? Please let me know about 1D-12 if you want me to re-pull file and what information you are after. 2 Also,just let me know if there any other questions or concerns. You can give me a shout to discuss also. 907-263-3741 is my desk Thanks David Lee From: Loepp, Victoria L(DOA) [ nailto:victoria.lopp©alaska.gov] Sent: Wednesday, October 01, 2014 3:02 PM To: Lee, David L Subject: [EXTERNAL]KRU 1D-142(PTD 214-149)West Sak David, 1. Anti-collision analysis: 1D-117, 1D-12 laterals are major risk failures that are now pass-minor. Please explain this process. What steps will be taken with these wells to mitigate risk of collision during drilling 1D-142? 2. Please provide a pad schematic showing the rig at the well location and the route of the diverter line including approximate lengths. 3. Area of Review: Why aren't the mechanical conditions of the West Sak wells reviewed? For the cement jobs on the 1D wells, did the cement jobs go as planned? Plugs bumped,floats held? For Well 1D-12, is there cement data available? Thanx in advance for addressing these questions, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusenaalaska.aov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 3 I 0 --hoisd- /oh 1/y 1 0-1 42wp06 DDI 6 . 913 Plan Summary SURVEY PROGRAM �\ AM t �-,-- ---4'::%,epth From Depth To Survey/Plan Tool � '�� 28.00 1300.00 1 D 142wp06(Plan 1D-142) GYD GC SS ie / \ �: 1300.00 2700.00 1D-142wp06(Plan 1D-142) MWD \�� 1300.00 2700.00 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC , ` .e 2700.00 3700.00 1D-142wp06(Plan 1D-142) MWD I 'r`\ \� 2700.00 6577.72 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC �t 6577.72 7577.00 1D-142wp06(Plan 1D-142) MWD / �//j1 ' ' 6577.72 12641.71 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC 1 '��i.. i Al l�� 0 CASING DETAILS °° 10-3/4"x13-1/2" 7-5/8"x9-7/8" oWO1 TVD MD Name Size o .°"�> 4-1/2"x6-3/4" 2349.70 2706.76 10-3/4"x13-1/2" 10-3/4 o 3776.70 6577.72 7-5/8"x9-7/8" 7-5/8 n' <�� a o0 3768.70 12641.71 4-1/2"x6-3/4" 4-1/2 0 h� ga o ° S M �� m o0 n w am mrn Iiim4eC>I` 0 1500 3000 4500 6000 754) 9000 S 16500 Horizontal Departure 0 A 1 .. 330 8 _ Ili' _ p -:. ifep•30 cz ri 3031 MO 60 NIP it ISI1100 - Iwo 300 i� • 'AO �/'I„-.#,P --A-. law -1330 ��I ,...:13"l�o-�npro. - a �/ _- 30 27o 4.4 ''; ®■ �! r f 90 m I WC. ., �.� , rRt i' ♦I _ 4) . 240 v0 It ':,:,...,..4.; 120 303. _TWO U - - .. esao 0500 MO 0 11111111111 I I I 1 1 I I I 1 1 I I I I I 210 ' W�13 00 - 0 0 1500 3000 4500 6000 7500 9000 10500 12000 Iola, ..-... ""° 180 SECTION DETAILS "'°° - "°" Sec MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLeg TFace Vsec Target - 1650.7 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5959167.65 1700704.55 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 501.30 0.00 0.00 5959167.65 1700704.55 0.00 0.00 0.00 Base permafrost 3 850.18 3.75 85.00 850.00 751.30 0.71 8.16 5959168.43 1700712.70 1.50 85.00 6.27 1859.7 4 1359.49 16.89 73.23 1350.00 1251.30 23.62 96.01 5959192.04 1700800.36 2.60 -15.00 65.10 5 1417.55 18.32 71.59 1405.34 1306.64 28.94 112.75 5959197.49 1700817.05 2.60 -20.00 75.76 6 1517.55 18.32 71.59 1500.27 1401.57 38.87 142.57 5959207.66 1700846.79 0.00 0.00 94.49 T3 7 2650.00 65.00 52.63 2325.71 2227.01 429.58 755.36 5959603.23 1701456.37 4.23 -23.38 372.36 8 4590.00 65.00 52.63 3145.59 3046.89 1496.76 2152.69 5960681.48 1702844.96 0.00 0.00 904.88 -2114.7 9 5400.00 65.00 92.00 3499.33 3400.63 1713.74 2833.21 5960903.90 1703523.64 4.39 98.60 1337.87 10 5837.33 75.54 110.63 3647.93 3549.23 1631.35 3233.67 5960824.74 1703924.72 4.67 62.44 1713.16 11 5837.33 75.54 110.63 3647.93 3549.23 1631.35 3233.67 5960824.74 1703924.72 0.00 0.00 1713.16 12 6577.72 85.00 145.00 3776.70 3678.00 1189.03 3798.48 5960387.00 1704493.00 4.74 77.86 2429.53 1D-142 01Apr14 DL D1 13 6597.72 85.00 145.00 3778.44 3679.74 1172.71 3809.90 5960370.77 1704504.56 0.00 0.00 2448.25 14 6860.35 89.07 148.33 3792.03 3693.33 953.66 3953.97 5960152.91 1704650.37 2.00 39.33 2691.91 15 7949.24 89.07 148.33 3809.72 3711.02 27.07 4525.65 5959231.03 1705229.41 0.00 0.00 3691.67 16 8192.40 90.00 153.10 3811.70 3713.00 -184.93 4644.56 5959020.00 1705350.00 2.00 78.99 3910.68 1D-142 01Apr14 DL D2 17 8215.89 89.86 153.55 3811.73 3713.03 -205.93 4655.11 5958999.09 1705360.71 2.00 107.74 3931.36 k15 18 9107.29 89.86 153.55 3813.96 3715.26 -1004.00 5052.18 5958204.31 1705764.14 0.00 0.00 4714.38 19 9699.96 90.00 165.40 3814.70 3716.00 -1558.04 5259.62 5957652.00 1705976.00 2.00 89.32 5202.09 1D-142 01Apr14 DL D3 20 9757.62 91.52 165.31 3813.93 3715.23 -1613.83 5274.20 5957596.34 1705991.02 2.65 -3.29 5246.03 21 9768.29 91.52 165.31 3813.65 3714.95 -1624.15 5276.91 5957586.04 1705993.81 0.00 0.00 5254.16 22 10359.96 90.00 184.65 3805.70 3707.00 -2210.68 5328.40 5957000.00 1706050.00 3.28 94.34 5632.76 1D-142 01Apr14 DL D4 23 10390.18 90.60 184.60 3805.54 3706.84 -2240.81 5325.96 5956969.85 1706047.80 2.00 -4.67 5648.05 24 11239.70 90.60 164.60 3796.61 3697.91 -3087.54 5257.82 5956122.69 1705986.47 0.00 0.00 6077.90 25 11362.96 91.17 187.00 3794.70 3696.00 -3210.14 5245.37 5956000.00 1705975.00 2.00 76.68 6138.02 10-142 08Jan14 DL D5 26 11363.87 91.17 187.02 3794.68 3695.98 -3211.05 5245.26 5955999.09 1705974.90 2.00 105.69 6138.45 -3112.7 27 12641.71 91.17 187.02 3768.70 3670.00 -4479.05 5089.17 5954730.00 1705829.00 0.00 0.00 6737.88 10-142 08Jan14 DL D6 ugc -3323.7 ugb -3454.7 4 u a -3551.7 N --..._ --0730 W Co* Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 T M Depth Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Magnets Model Date: 30-Jul-14 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.38° AStl- North/Y: 5959167.65 Ground Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.38°East East/X: 1700704.55 Rig: Doyon 141 NO GLOBAL FILTER:Using user defined selection&filtering criteria 410 1110 P\ i SLJ— 19143 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-142 Plan 1D-142 Plan: 1 D-142wp06 3 Failed Anti-Collision Plan Summary E T(7 required 30 September,2014 r'ib, 1D-117(Minor 1/50) • 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit ND Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 1D Pad,KRU Site Position: Northing: 5,959,421.20 usft Latitude: 70°18'0.267 N From: Map Easting: 1,701,118.42 ash Longitude: 149°30'30.085 W Position Uncertainty: 0.00 usft Slot Radius: 36" Grid Convergence: 0.46° Well Plan:1D-142 Well Position +N/-S 0.00 usft Northing: 5,959,167.65 usft Latitude: 70'17'57.805 N +E/-W 0.00 usft Easting: 1,700,704.55 usft Longitude: 149°30'42.211 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 70.70 usft Wellbore Plan 1D-142 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) BGGM2014 7/30/2014 19.38 80.92 57,588 Design 1D-142wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction , (usft) (usft( (usft) (°) 28.00 0.00 0.00 125.00 9/302014 5:30:33PM COMPASS 5000.1 Build 61 • 1 D-142wp06 Plan View 1D-142 01Apr14 DL D1 1000- 10-3/4"x13-1/2" 0 -'�` pO ,f00 7-5/8"x9-7/8" oOO 1D-142 01Apr14 DL D2 0— - - o 'NM. C 0 U) o 9°Q113 0 000- - 1D-142 01Apr14 DL D3 117 X000-1 10000 1D-142 01Apr14 DLJ114 yr_- 0 11000 -3000— ik - 1D-142 08Jan14 DL DE \I -4000— 1D 142wp06 12000 1D-142 08Jan14 DL D6 4-1/2"x6-3/4" �► 2642 I I I I 1- I I I - -1000 0 1000 2000 3000 4000 5000 6000 7000 West(-)/East(+) (1000 usft/in) 0 I 1 D-1 42wp06 Section View 0-A 00 750- 1000 c U) 01500- N- s 30° m 2.000 10-3/4"x13-1/2" 0 0 ,- 2250- 6� --- r \N.-- p6 > 30 26h To_,_I- be N 3000- is ,00 0 0 0 0 0 N 0 0 0 0 ° ° 0 CO 0 NCO 0 0 0 CO 0) CT) rn 3750- • od o a. O N 7-5/8"x9-7/8" 0 4-1/2"x6-3/4 I I I I I I I I I I 0 750 1500 2250 3000 3750 4500 5250 6000 6750 Vertical Section at 125.00°(750 usft/in) • III Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1 D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Survey Tool Program Date 9/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,300.00 1D-142wp06(Plan 1D-142) GYD-GC-SS Gyrodata gyro single shots 1,300.00 2,700.00 1D-142wp06(Plan 1D-142) MWD MWD-Standard 1,300.00 2,700.00 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,700.00 3,700.00 1D-142wp06(Plan 1D-142) MWD MWD-Standard 2,700.00 6,577.72 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,577.72 7,577.00 1D-142wp06(Plan 1D-142) MWD MWD-Standard 6,577.72 12,641.71 1D-142wp06(Plan 1D-142) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°l100usft) (°) (usft) (usft) (usft) (usft) 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5,959,167.65 1,700,704.55 0.00 0.00 100.00 0.00 0.00 100.00 1.30 0.00 0.00 5,959,167.65 1,700,704.55 0.05 1.15 200.00 0.00 0.00 200.00 101.30 0.00 0.00 5,959,167.65 1,700,704.55 0.20 1.15 300.00 0.00 0.00 300.00 201.30 0.00 0.00 5,959,167.65 1,700,704.55 0.34 1.15 400.00 0.00 0.00 400.00 301.30 0.00 0.00 5,959,167.65 1,700,704.55 0.49 1.15 500.00 0.00 0.00 500.00 401.30 0.00 0.00 5,959,167.65 1,700,704.55 063 1.15 600.00 0.00 0.00 600.00 501.30 0.00 0.00 5,959,167.65 1,700,704.55 0.78 1.16 Start Build 1.50 700.00 1.50 85.00 699.99 601.29 1.50 85.00 5,959,167.77 1,700,705.85 0.89 1.16 800.00 3.00 85.00 799.91 701.21 1.50 0.00 5,959,168.15 1,700,709.76 0.99 1.16 850.18 3.75 85.00 850.00 751.30 1.50 0.00 5,959,168.43 1,700,712.70 1.04 1.16 Start DLS 2.60 IPO-15.00 900.00 5.02 81.16 899.67 800.97 2.60 -15.00 5,959,168.94 1,700,716.47 1.10 1.17 1,000.00 7.58 77.34 999.06 900.36 2.60 -11.17 5,959,171.14 1,700,727.21 1.22 1.17 1,100.00 10.17 75.45 1,097.86 999.16 2.60 -7.38 5,959,174.92 1,700,742.16 1.36 1.17 1,200.00 12.76 ' 74.32 1,195.86 1,097.16 2.60 -5.51 5,959,180.28 1,700,761.30 1.51 1.16 1,300.00 15.35 73.57 1,292.85 1,194.15 2.60 -4.40 5,959,187.19 1,700,784.57 1.68 1.16 9/30/2014 5:30:33PM Page 3 COMPASS 5000.1 Build 61 i • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kupl Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)Q 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 1,359.49 16.89 73.23 1,350.00 1,251.30 2.60 -3.67 5,959,192.04 1,700,800.36 1.74 1.16 Start DLS 2.60 TFO-20.00 1,400.00 17.89 72.06 1,388.66 1,289.96 2.60 -20.00 5,959,195.75 1,700,811.88 1.77 1.15 1,417.55 18.32 71.59 1,405.34 1,306.64 2.60 -18.88 5,959,197.49 1,700,817.05 1.78 1.15 Start 100.00 hold at 1417.55 MD 1,500.00 18.32 71.59 1,483.61 1,384.91 0.00 0.00 5,959,205.87 1,700,841.57 1.91 1.16 1,517.55 18.32 71.59 1,500.27 1,401.57 0.00 0.00 5,959,207.66 1,700,846.79 1.95 1.16 Start DLS 4.23 TFO-23.38 1600.00 21.56 67.82 1,577.77 1,479.07 423 -23.38 5,959,217.68 1,700,873.04 2.18 1.16 1,679.32 24.74 65.10 1,650.70 1,552.00 4.23 -19.84 5,959,230.41 1,700,901.50 2.59 1.15 Base permafrost 1,700.00 25.58 64.50 1,669.41 1,570.71 4.23 -17.34 5,959,234.21 1,700,909.42 2.59 1.15 1,800.00 29.65 62.03 1,758.01 1,659.31 4.23 -16.79 5,959,255.45 1,700,950.60 3.15 1.15 1,900.00 33.76 60.11 1,843.07 1,744.37 4.23 -14.61 5,959,281.27 1,700,996.34 3.85 1.16 1,920.10 34.59 59.78 1,859.70 1,761.00 4.23 -12.97 5,959,287.00 1,701,006.07 4.67 1.18 T3 2,000.00 37.89 58.57 1,924.14 1,825.44 4.23 -12.70 5,959,311.54 1,701,046.41 4.67 1.18 2,100.00 42.04 57.29 2,000.77 1,902.07 4.23 -11.72 5,959,346.10 1,701,100.52 5.61 1.24 2,200.00 46.20 56.19 2,072.55 1,973.85 4.23 -10.74 5,959,384.75 1,701,158.39 6.64 1.32 2,262.40 48.80 55.59 2,114.70 2,016.00 4.23 -9.95 5,959,410.85 1,701,196.26 7.77 1.45 615 2,300.00 50.36 5525 2,139.08 2,040.38 4.23 -9.54 5,959,427.28 1,701,219.69 7.77 1.45 2,400.00 54.54 54.41 2,200.01 2,101.31 4.23 -9.32 5,959,473.47 1,701,284.10 8.97 1.61 2,500.00 58.72 53.65 2,255.00 2,156.30 4.23 -8.81 5,959,523.06 1,701,351.26 10.25 1.81 2,600.00 62.91 52.96 2,303.76 2,205.06 4.23 -8.39 5,959,575.78 1,701,420.82 11.58 2.04 2,650.00 65.00 52.63 2,325.71 2,227.01 4.23 -8.06 5,959,603.23 1,701,456.37 12.27 2.17 Start 1940.00 hold at 2650.00 MD 2,700.00 65.00 52.63 2,346.84 2,248.14 0.00 0.00 5,959,631.02 1,701,492.16 12.97 2.31 9/302014 5:30:33PM Page 4 COMPASS 5000.1 Build 61 S • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1 D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)(�98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)ll 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°i100usft) (°) (usft) (usft) (usft) (usft) 2,706.76 65.00 52.63 2,349.70 2,251.00 0.00 0.00 5,959,634.78 1,701,497.00 5.91 1.47 10-3/4"o13-1/2" 2,800.00 65.00 52.63 2,389.10 2,290.40 0.00 0.00 5,959,686.60 1,701,563.73 5.91 1.47 2,900.00 65.00 52.63 2,431.37 2,332.67 0.00 0.00 5,959,742.18 1,701,635.31 6.71 1.53 3,000.00 65.00 52.63 2,473.63 2374.93 0.00 0.00 5,959,797.76 1,701,706.89 7.70 1.65 3,100.00 65.00 52.63 2,515.89 2,417.19 0.00 0.00 5,959,853.34 1,701,778.46 8.81 1.81 3,200.00 65.00 52.63 2,558.15 2,459.45 0.00 0.00 5,959,908.92 1,701,850.04 10.00 2.01 .3,300.00 65.00 52.63 2,600.41 2501.71 0.00 0.00 5,959,964.50 1,701,921.62 11.25 2.23 3,400.00 65.00 52.63 2,642.67 2,543.97 0.00 0.00 5,960,020.08 1,701,993.19 12.54 2.47 3,500.00 65.00 52.63 2,684.94 2,586.24 0.00 0.00 5,960,075.66 1,702,064.77 13.85 2.72 3,600.00 65.00 52.63 2,727.20 2,628.50 0.00 0.00 5,960,131.24 1,702,136.35 15.19 2.99 3,700.00 65.00 52.63 2,769.46 2,670.76 0.00 0.00 5,960,186.82 1,702,207.92 16.54 3.26 3,800.00 65.00 52.63 2,811.72 2,713.02 0.00 0.00 5,960,242.40 1,702,279.50 9.16 2.20 3,900.00 65.00 52.63 2,853.98 2,755.28 0.00 0.00 5,960297.98 1,702,351.08 9.61 2.32 4,000.00 65.00 52.63 2,896.25 2,797.55 0.00 0.00 5,960,353.56 1,702,422.65 10.08 2.45 4,100.00 65.00 52.63 2,938.51 2,839.81 0.00 0.00 5,960,409.14 1,702,494.23 10.55 2.57 4,200.00 65.00 52.63 2,980.77 2,882.07 0.00 0.00 5,960,464.72 1,702,565.81 11.03 2.70 4,300.00 65.00 52.63 3,023.03 2,924.33 0.00 0.00 5,960,520.30 1,702,637.38 11.51 2.83 4,400.00 65.00 52.63 3,065.29 2,966.59 0.00 0.00 5,960,575.88 1,702,708.96 12.00 2.97 4,500.00 65.00 52.63 3,107.55 3,008.85 0.00 0.00 5,960,631.46 1,702,780.54 12.50 3.11 4,512.17 65.00 52.63 3,112.70 3,014.00 0.00 0.00 5,960,638.23 1,702,789.25 12.95 3.23 ugc 4,590.00 65.00 52.63 3,145.59 3,046.89 0.00 0.00 5,960,681.48 1,702,844.96 12.95 3.23 Start DLS 4.39 TFO 98.60 4,600.00 64.94 53.11 3,149.82 3,051.12 4.39 98.60 5,960,687.01 1,702,852.13 12.99 3.24 4,700.00 64.37 57.93 3,192.65 3,093.95 4.39 98.39 5,960,738.75 1,702,926.17 13.28 3.38 4,800.00 63.97 62.78 3,236.24 3,137.54 4.39 96.33 5,960,783.88 1,703,004.00 13.49 3.52 9/302014 5:30:33PM Page 5 COMPASS 5000.1 Build 61 II 111 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1 D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (11100usft) (°) (usft) (usft) (usft) (usft) 4,900.00 63.73 67.66 3,280.34 3,181.64 4.39 94.22 5,960,822.14 1,703,085.15 13.64 3.66 4,997.79 63.65 72.45 3,323.70 3,225.00 4.39 92.06 5,960,852.68 1,703,167.27 13.72 3.80 ugb 5,000.00 63.65 72.56 3,324.68 3,225.98 4.39 89.94 5,960,853.29 1,703,169.15 13.72 3.80 5,100.00 63.74 77.45 3,369.01 3,270.31 4.39 89.89 5,960,877.17 1,703,255.52 13.72 3.93 5,200.00 64.00 82.34 3,413.07 3,314.37 4.39 87.72 5,960,893.61 1,703,343.73 13.64 4.07 5,295.61 64.40 86.98 3,454.70 3,356.00 4.39 85.57 5,960,902.31 1,703,429.33 13.50 4.22 uga 5,300.00 64.42 87.19 3,456.59 3,357.89 4.39 83.55 5,960,902.54 1,703,433.28 13.50 4.22 5,400.00 65.00 92.00 3,499.33 3,400.63 4.39 83.46 5,960,903.90 1,703,523.64 13.28 4.36 Start DLS 4.67 TFO 62.44 5,500.00 67.23 96.49 3,539.84 3,441.14 4.67 62.44 5,960,897.84 1,703,614.83 13.07 4.50 5,531.10 67.95 97.85 3,551.70 3,453.00 4.67 60.62 5,960,894.48 1,703,643.38 12.83 4.65 N 5,600.00 69.58 100.83 3,576.66 3,477.96 4.67 60.10 5,960,884.55 1,703,706.81 12.83 4.65 5,700.00 72.03 105.04 3,609.56 3,510.86 4.67 59.02 5,960,864.14 1,703,798.98 12.56 4.80 5,800.00 74.57 109.13 3,638.30 3,539.60 4.67 57.63 5,960,836.73 1,703,890.71 12.27 4.95 5,837.33 75.54 110.63 3,647.93 3,549.23 4.67 56.46 5,960,824.74 1,703,924.72 12.15 5.01 Start DLS 4.74 TFO 77.86 5,900.00 76.18 113.62 3,663.24 3,564.54 4.74 77.86 5,960,802.30 1,703,981.18 11.84 5.11 6,000.00 77.28 118.36 3,686.20 3,587.50 4.74 77.13 5,960,760.36 1,704,068.97 11.29 5.27 6,100.00 78.47 123.06 3,707.22 3,608.52 4.74 76.04 5,960,711.12 1,704,153.38 10.71 5.43 6,200.00 79.73 127.72 3,726.14 3,627.44 4.74 75.06 5,960,654.91 1,704,233.85 10.10 5.60 6,300.00 81.05 132.34 3,742.85 3,644.15 4.74 74.17 5,960,592.13 1,704,309.82 9.48 5.76 6,359.60 81.87 135.07 3,751.70 3,653.00 4.74 73.40 5,960,551.76 1,704,352.74 8.87 5.93 Top W Sak 6,400.00 82.43 136.92 3,757.22 3,658.52 4.74 73.00 5,960,523.19 1,704,380.77 8.87 5.93 6,500.00 83.86 141.48 3,769.16 3,670.46 4.74 72.74 5,960,448.58 1,704,446.22 6.30 6.09 9/30/2014 5:30:33PM Page 6 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Let.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 6,577.72 85.00 145.00 3,776.70 3,678.00 4.74 72.20 5,960,387.00 1,704,493.00 7.94 6.15 Start 20.00 hold at 6577.72 MD-7318"89-718" 6,597.72 85.00 145.00 3,778.44 3,679.74 0.00 71.86 5,960,370.77 1,704,504.56 8.09 6.15 Start DLS 2.00 TFO 39.33 6,600.00 85.04 145.03 3,778.64 3,679.94 2.00 39.33 5,960,368.93 1,704,505.87 8.10 6.15 6,700.00 86.58 146.30 3,785.95 3,687.25 2.00 39.33 5,960,287.04 1,704,562.78 8.68 6.18 6,800.00 88.13 147.56 3,790.56 3,691.86 2.00 39.23 5,960,203.78 1,704,617.94 9.47 622 6,860.35 89.07 148.33 3,792.03 3,693.33 2.00 39.18 5,960,152.91 1,704,650.37 10.03 6.26 Start 1088.90 hold at 8880.35 MD 6,900.00 89.07 148.33 3,792.68 3,693.98 0.00 0.00 5,960,119.34 1,704,671.45 10.52 629 7,000.00 89.07 148.33 3,794.30 3,695.60 0.00 0.00 5,960,034.68 1,704,724.63 11.78 6.37 7,100.00 89.07 148.33 3,795.92 3,697.22 0.00 0.00 5,959,950.01 1,704,777.81 13.13 6.48 7,200.00 89.07 148.33 3,797.55 3,698.85 0.00 0.00 5,959,865.35 1,704,830.98 14.53 6.61 7,300.00 89.07 148.33 3,799.17 3,700.47 0.00 0.00 5,959,780.69 1,704,884.16 15.98 6.75 7,400.00 89.07 148.33 3,800.80 3,702.10 0.00 0.00 5,959,696.03 1,704,937.34 17.46 6.91 7,500.00 89.07 148.33 3,802.42 3,703.72 0.00 0.00 5,959,611.37 1,704,990.51 18.96 7.08 7,600.00 89.07 148.33 3,804.05 3,705.35 0.00 0.00 5,959,526.70 1,705,043.69 10.43 6.43 7,700.00 89.07 148.33 3,805.67 3,706.97 0.00 0.00 5,959,442.04 1,705,096.87 10.88 6.49 7,800.00 89.07 148.33 3,807.30 3,708.60 0.00 0.00 5,959,357.38 1,705,150.04 11.33 6.55 7,900.00 89.07 148.33 3,808.92 3,710.22 0.00 0.00 5,959,272.72 1,705,203.22 11.80 6.61 7,949.24 89.07 148.33 3,809.72 3,711.02 0.00 0.00 5,959,231.03 1,705,229.41 12.04 6.65 Start DLS 2.00 TFO 78.99 8,000.00 89.26 149.32 3,810.46 3,711.76 2.00 78.99 5,959,187.82 1,705,256.02 12.06 6.68 8,100.00 89.65 151.29 3,811.41 3,712.71 2.00 78.97 5,959,101.37 1,705,306.25 12.11 6.75 8,192.40 90.00 153.10 3,811.70 3713.00 2.00 78.96 5,959,020.00 1,705,350.00 12.16 6.82 Start DLS 2.90 TFO 107.74 8,200.00 89.95 153.24 3,811.70 3,713.00 2.00 107.74 5,959,013.25 1,705,353.48 12.16 6.83 9/302014 5:30:33PM Page 7 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)(g 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) (usft) 8.215.89 89.86 153.55 3,811 73 3713.03 2.00 107.74 5,958,999.09 1,705,360.71 12.17 6.84 Start 891.40 hold at 8215.89 MD 8,300.00 89.86 153.55 3,811.94 3,713.24 0.00 0.00 5,958,924.10 1,705,398.78 12.54 6.91 8,400.00 89.86 153.55 3,812.19 3,713.49 0.00 0.00 5,958,834.94 1,705,444.04 13.04 6.99 8,500.00 89.86 153.55 3,812.44 3,713.74 0.00 0.00 5,958,745.78 1,705,489.29 13.55 7.08 8,600.00 89.86 153.55 3,812.69 3,713.99 0.00 0.00 5,958,656.62 1,705,534.55 14.06 7.17 8,700.00 89.86 153.55 3,812.94 3,714.24 0.00 0.00 5,958,567.46 1,705,579.81 14.58 7.26 8,800.00 89.86 153.55 3,813.19 3,714.49 0.00 0.00 5,958,478.30 1,705,625.07 15.11 7.36 8,900.00 89.86 153.55 3,813.44 3,714.74 0.00 0.00 5,958,389.14 1,705,670.33 15.64 7.46 9,000.00 89.86 153.55 3,813.69 3,714.99 0.00 0.00 5,958,299.98 1,705,715.58 16.17 7.56 9,100.00 89.86 153.55 3,813.94 3,715.24 0.00 0.00 5,958,210.81 1,705,760.84 16.71 7.67 9,107.29 89.86 153.55 3,813.96 3,715.26 0.00 0.00 5,958,204.31 1,705,764.14 16.75 7.68 Start DLS 2.00 TFO 89.32 9,200.00 89.88 155.40 3,814.17 3,715.47 2.00 89.32 5,958,120.99 1,705,804.76 16.86 7.78 9,300.00 89.90 157.40 3,814.36 3,715.66 2.00 89.31 5,958,029.69 1,705,845.52 16.92 7.89 9,400.00 89.93 159.40 3,814.51 3,715.81 2.00 89.31 5,957,937.02 1,705,883.07 16.99 8.00 9,500.00 89.95 161.40 3,814.62 3,715.92 2.00 89.31 5,957,843.10 1,705,917.36 17.06 8.12 9,600.00 89.98 163.40 3,814.68 3,715.98 2.00 89.30 5,957,748.04 1,705,948.35 17.12 8.24 9,699.96 90.00 165.40 3,814.70 3,716.00 2.00 89.30 5,957,652.00 1,705,976.00 17.19 8.36 Start OLS 2.65 TFO-3.29 9,700.00 90.00 165.40 3,814.70 3,716.00 0.00 0.00 5,957,651.96 1,705,976.01 17.19 8.36 9,757.62 91.52 165.31 3,813.93 3,715.23 2.65 -3.29 5,957,596.34 1,705,991.02 17.48 8.43 Start 10.67 hold at 9757.62 MD 9,768.29 91.52 165.31 3,813.65 3,714.95 0.00 0.00 5,957,586.04 1,705,993.81 17.54 8.44 Start DLS 3.28 TFO 94.34 9,800.00 91.45 166.35 3,812.83 3,714.13 3.28 94.34 5,957,555.38 1,706,001.81 17.49 8.48 9,900.00 91.19 169.62 3,810.52 3,711.82 3.28 94.36 5,957,457.79 1,706,023.41 17.29 8.60 10,000.00 90.94 172.89 3,808.66 3,709.96 3.28 94.44 5,957,359.12 1,706,039.40 17.08 8.73 91302014 5:30:33PM Page 8 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)@ 98.70usfl(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usfl(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1 D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 10,100.00 90.68 176.16 3,807.25 3,708.55 3.28 94.50 5,957,259.69 1,706,049.74 16.87 8.86 10,200.00 90.42 179.42 3,806.29 3,707.59 3.28 94.55 5,957,159.82 1,706,054.40 16.67 8.99 10,300.00 90.16 182.69 3,805.78 3,707.08 3.28 94.58 5,957,059.85 1,706,053.36 16.46 9.12 10,359.96 90.00 184.65 3,805.70 3,707.00 3.28 94.59 5,957,000.00 1,706,050.00 16.34 9.20 Start DLS 2.00 TFO-4.67 10,390.18 90.60 184.60 3,805.54 3,706.84 2.00 -4.67 5,956,969.85 1,706,047.80 16.46 9.24 Start 849.51 hold at 10390.18 MD 10,400.00 90.60 184.60 3,805.44 3,706.74 0.00 0.00 5,956,960.07 1,706,047.10 16.49 9.25 10,500.00 90.60 184.60 3,804.39 3,705.69 0.00 0.00 5,956,860.34 1,706,039.88 16.88 9.39 10,600.00 90.60 184.60 3,803.33 3,704.63 0.00 0.00 5,956,760.62 1,706,032.66 17.28 9.52 10,700.00 90.60 184.60 3,802.28 3,703.58 0.00 0.00 5,956,660.89 1,706,025.44 17.69 9.66 10,800.00 90.60 184.60 3,801.23 3,702.53 0.00 0.00 5,956,561.17 1,706,018.22 18.11 9.80 10,900.00 90.60 184.60 3,800.18 3,701.48 0.00 0.00 5,956,461.45 1,706,011.00 18.54 9.94 11,000.00 90.60 184.60 3,799.13 3,700.43 0.00 0.00 5,956,361.72 1,706,003.78 18.97 10.08 11,100.00 90.60 184.60 3,798.08 3,699.38 0.00 0.00 5,956,262.00 1,705,996.56 19.42 10.23 11,200.00 90.60 184.60 3,797.02 3,698.32 0.00 0.00 5,956,162.27 1,705,989.34 19.87 10.37 11,239.70 90.60 184.60 3,796.61 3,697.91 0.00 0.00 5,956,122.69 1,705,986.47 20.05 10.43 Start DLS 2.00 TFO 76.68 11,300.00 90.88 185.77 3,795.83 3,697.13 2.00 76.68 5,956,062.60 1,705,981.50 20.07 10.51 11,362.96 91.17 187.00 3,794.70 3,696.00 2.00 76.69 5,956,000.00 1,705,975.00 20.07 10.61 Start DLS 2.00 TFO 105.69 11,363.87 91.17 187.02 3,794.68 3,695.98 2.00 105.69 5,955,999.09 1,705,974.90 20.07 10.61 Start 1277.83 hold at 11363.87 MD 11,400.00 91.17 187.02 3,793.95 3,695.25 0.00 0.00 5,955,963.21 1,705,970.77 20.20 10.66 11,500.00 91.17 187.02 3,791.91 3,693.21 0.00 0.00 5,955,863.89 1,705,959.35 20.65 10.81 11,600.00 91.17 187.02 3,789.88 3,691.18 0.00 0.00 5,955,764.58 1,705,947.94 21.10 10.96 11,700.00 91.17 187.02 3,787.85 3,689.15 0.00 0.00 5,955,665.26 1,705,936.52 21.56 11.10 11,800.00 91.17 187.02 3,785.81 3,687.11 0.00 0.00 5,955,565.95 1,705,925.10 22.02 11.25 9/302014 5:30:33PM Page 9 COMPASS 5000.1 Build 61 0 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)(Q 98.70usfl(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)(4)98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 10-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) 11 (1 (usft) (usft) ("1100usft) (°) (usft) (usft) (usft) (usft) 11,900.00 91.17 187.02 3,783.78 3,685.08 0.00 0.00 5,955,466.63 1,705,913.68 22.50 11.40 12,000.00 91.17 187.02 3,781.75 3,683.05 0.00 0.00 5,955,367.32 1,705,902.27 22.97 11.56 12,100.00 91.17 187.02 3,779.71 3,681.01 0.00 0.00 5,955,268.00 1,705,890.85 23.45 11.71 12,200.00 91.17 187.02 3,777.88 3,678.98 0.00 0.00 5,955,168.68 1,705,879.43 23.94 11.86 12,300.00 91.17 187.02 3,775.65 3,676.95 0.00 0.00 5,955,069.37 1,705,868.01 24.43 12.01 12,400.00 91.17 187.02 3,773.61 3,674.91 0.00 0.00 5,954,970.05 1,705,856.60 24.92 12.17 12,500.00 91.17 187.02 3,771.58 3,672.88 0.00 0.00 5,954,870.74 1,705,845.18 25.42 12.32 12,600.00 91.17 187.02 3,789.55 3,870.85 0.00 0.00 5,954,771.42 1,705,833.76 25.92 12.48 12,641.71 91.17 187.02 3,768.70 3,670.00 0.00 0.00 5,954,730.00 1,705,829.00 26.13 12.54 TD at 12641.71 9/30/2014 5:30:33PM Page 10 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:10-142 Project: Kuparuk River Unit ND Reference: Plan:(70.7+28) 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1 D-142wp06 Database: EDM Alaska Prod Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +El-W Northing , Easting -Shape (°) (°) (usft) (usft) (usft) (usft) usft ,;mow:. ) `°,�!: (usft) Latitude Longitude 10-142 01Apr14 DL 03 0.00 0.00 3,814.70 -1,558.04 5,259.62 5,957,652.00 1,705,976.00 70°17'42.464 N 149°28'8.907 W -plan hits target center -Point 10-142 08Jan14 DL 06 0.00 0.00 3,768.70 -4,479.05 5,089.17 5,954,730.00 1,705,829.00 70°17'13.736 N 149°28'13.933 W -plan hits target center -Point 1D-142 01Apr14 DL D2 0.00 0.00 3,811.70 -184.93 4,644.56 5,959,020.00 1,705,350.00 70°17'55.972 N 149°28'26.809 W -plan hits target center -Point 1D-142 01Apr14 DL D4 0.00 0.00 3,805.70 -2,210.68 5,328.40 5,957,000.00 1,706,050.00 70°17'36.044 N 149°28'6.916 W -plan hits target center -Point 1D-142 08Jan14 DL D5 0.00 0.00 3,794.70 -3,210.14 5,245.37 5,956,000.00 1,705,975.00 70°17'26.215 N 149°28'9.356 W -plan hits target center -Point 1D-142 01Apr14 DL D1 0.00 0.00 3,776.70 1,189.03 3,798.48 5,960,387.00 1,704,493.00 70°18'9.490 N 149°28'51.455 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole • Depth Depth Diameter Diameter • (usft) (usft) Name I') (") • 2,706.76 2,349.70 10-3/4"x13-1/2" 10-3/4 13-1/2 12,641.71 3,768.70 4-1/2"x6-3/4" 4-1/2 6-3/4 6,577.72 3,776.70 7-5/8"x9-7/8" 7-5/8 9-7/8 • 9/302014 5:30:33PM Page 11 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28) 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)Tp 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1 : 5,531.10 3,551.70 N 0.00 6,359.60 3,751.70 Top W Sak 0.00 5,295.61 3,454.70 uga 0.00 2,262.40 2,114.70 k15 0.00 4,512.17 3,112.70 ugc 0.00 1,679.32 1,650.70 Base permafrost 0.00 4,997.79 3,323.70 ugb 0.00 1,920.10 1,859.70 T3 0.00 9/30/2014 5.30:33PM Page 12 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-142 Project: Kuparuk River Unit TVD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.7+28)@ 98.70usft(Doyon 141) Well: Plan:1D-142 North Reference: True Wellbore: Plan 1D-142 Survey Calculation Method: Minimum Curvature Design: 1D-142wp06 Database: EDM Alaska Prod Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) t (usft) (usft) Comment .4.11t(trttWallttAt 600.00 600.00 0.00 0.00 Start Build 1.50 850.18 850.00 0.71 8.16 Start DLS 2.60 TFO-15.00 1,359.49 1,350.00 23.62 96.01 Start DLS 2.60 TFO-20.00 1,417.55 1,405.34 28.94 112.75 Start 100.00 hold at 1417.55 MD 1,517.55 1,500.27 38.87 142.57 Start DLS 4.23 TFO-23.38 2,650.00 2,325.71 429.58 755.36 Start 1940.00 hold at 2650.00 MD 4,590.00 3,145.59 1,496.76 2,152.69 Start DLS 4.39 TFO 98.60 5,400.00 3,499.33 1,713.74 2,833.21 Start DLS 4.67 TFO 62.44 5,837.33 3,647.93 1,631.35 3,233.67 Start DLS 4.74 TFO 77.86 6,577.72 3,776.70 1,189.03 3,798.48 Start 20.00 hold at 6577.72 MD 6,597.72 3,778.44 1,172.71 3,809.90 Start DLS 2.00 TFO 39.33 6,860.35 3,792.03 953.66 3,953.97 Start 1088.90 hold at 6860.35 MD 7,949.24 3,809.72 27.07 4,525.65 Start DLS 2.00 TFO 78.99 8,192.40 3,811.70 -184.93 4,644.56 Start DLS 2.00 TFO 107.74 8,215.89 3,811.73 -205.93 4,655.11 Start 891.40 hold at 8215.89 MD 9,107.29 3,813.96 -1,004.00 5,052.18 Start DLS 2.00 TFO 89.32 9,699.96 3,814.70 -1,558.04 5,259.62 Start DLS 2.65 TFO-3.29 9,757.62 3,813.93 -1,613.83 5,274.20 Start 10.67 hold at 9757.62 MD 9,768.29 3,813.65 -1,624.15 5,276.91 Start DLS 3.28 TFO 94.34 10,359.96 3,805.70 -2,210.68 5,328.40 Start DLS 2.00 TFO-4.67 10,390.18 3,805.54 -2,240.81 5,325.96 Start 649.51 hold at 10390.18 MD 11,239.70 3,796.61 -3,087.54 5,257.82 Start DLS 2.00 TFO 76.68 11,362.96 3,794.70 -3,210.14 5,245.37 Start DLS 2.00 TFO 105.69 11,363.87 3,794.68 -3,211.05 5,245.26 Start 1277.83 hold at 11363.87 MD 12,641.71 3,768.70 -4,479.05 5,089.17 TD at 12641.71 Checked By. Approved By: Date: 9/302014 5:30:33PM Page 13 COMPASS 5000.1 Build 61 • • ?IW ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-142 Plan 1D-142 1 D-142wp06 Clearance Summary Anticollision Report 30 September,2014 Ta required Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 10 Pad-Plan:1D-142-Plan 10-142-1D-142wp06 Well Coordinates: 5,959,167.65 N,1,700,704.55 E (70°17'57.81"N,149°30'42.21"W) Datum Height: Plan:(70.7+28)@ 98.70usft(Doyon 141) Scan Range: 0.00 to 12,641.71 usft.Measured Depth. ��, Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ,v J.111111.,3 1D-117(Minor 1/50) Geodetic Scale Factor Applied Version: 5000.1 Build: 61 Scan Type: Scan Type: 25.00 111, • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-142-1 D-142wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 10 Pad-Plan:1D-142-Plan 10-142-1D-142wp06 Scan Range: 0.00 to 12,641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (ustt) (usft) (usft) usft Kuparuk 1C Pad 1C-135-1C-135-1C-135 5,490.66 250.18 5,490.66 138.39 9,325.00 2.238 Clearance Factor Pass-Major Risk 1C-135-1C-135-10-135 5,495.42 250.10 5,495.42 138.52 9,350.00 2.241 Centre Distance Pass-Major Risk 1C-135-1C-135PB1-1C-135PB1 5,486.22 245.76 5,486.22 132.98 9,325.00 2.179 Clearance Factor Pass-Major Risk 1C-190-1C-190-1C-190 6,205.55 324.88 6,205.55 15.18 10,466.00 1.049 Clearance Factor Pass-Major Risk Kuparuk 1D Pad 1D-04-1D-04-1D-04 617.91 222.30 617.91 207.85 625.00 15.389 Centre Distance Pass-Major Risk 10-04-10-04-1D-04 713.65 223.41 713.65 206.59 725.00 13.287 Clearance Factor Pass-Major Risk 1D-04-1D-04A-1D-04A 617.91 222.30 617.91 207.85 625.00 15.389 Centre Distance Pass-Major Risk 10-04-1D-04A-1D-04A 713.65 223.41 713.65 206.59 725.00 13.287 Clearance Factor Pass-Major Risk 10-04-1D-04AL1- 1D-04AL1 617.91 222.30 617.91 207.85 625.00 15.389 Centre Distance Pass-Major Risk 10-04-1D-04AL1- 1D-04AL1 713.65 223.41 713.65 206.59 725.00 13.287 Clearance Factor Pass-Major Risk 10-04-1D-04AL1-01-1D-04AL1-01 617.91 222.30 617.91 207.85 625.00 15.389 Centre Distance Pass-Major Risk 10-04-1D-04AL1-01-1D-04AL1-01 713.65 223.41 713.65 206.59 725.00 13.287 Clearance Factor Pass-Major Risk 10-04-10-04AL1-02-1 D-04AL1-02 617.91 222.30 617.91 207.85 625.00 15.389 Centre Distance Pass-Major Risk 10-04-10-04AL1-02-1 D-04AL1-02 713.65 223.41 713.65 206.59 725.00 13.287 Clearance Factor Pass-Major Risk 10-05-10-05-1D-05 641.74 178.91 641.74 163.87 650.00 11.894 Centre Distance Pass-Major Risk 10-05-1D-05-1D-05 1,800.00 202.07 1,800.00 159.62 1,925.00 4.760 Clearance Factor Pass-Major Risk 10-06-1D-06-10-06 98.70 213.78 98.70 211.93 105.00 115.573 Centre Distance Pass-Major Risk 10-06-1D-06-1 0-06 712.98 215.42 712.98 198.78 725.00 12.942 Clearance Factor Pass-Major Risk 1D-09-1D-09-10-09 1,137.92 198.80 1,137.92 178.89 1,175.00 9.984 Centre Distance Pass-Major Risk 10-09-1D-09-10-09 1,234.14 199.72 1,234.14 177.91 1,275.00 9.158 Clearance Factor Pass-Major Risk 1D-11-1D-11-1D-11 443.12 381.43 443.12 374.01 450.00 51.421 Centre Distance Pass-Major Risk 1D-11-1D-11-1D-11 517.94 381.92 517.94 373.25 525.00 44.040 Clearance Factor Pass-Major Risk 1D-11-1D-11L1-1D-11L1 443.12 381.43 443.12 374.01 450.00 51.421 Centre Distance Pass-Major Risk 1D-11-1D-11L1-1D-11L1 517.94 381.92 517.94 373.25 525.00 44.040 Clearance Factor Pass-Major Risk 1D-11-113-11L2-1D-11L2 443.12 381.43 443.12 374.06 450.00 51.748 Centre Distance Pass-Major Risk 10-11-1D-11L2-1D-11L2 517.94 381.92 517.94 373.30 525.00 44.280 Clearance Factor Pass-Major Risk 30 September,2014- 17:31 Page 2 of 9 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 10-142-1 D-142wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 113 Pad-Plan:1D-142-Plan 1D-142-1D-142wp06 Scan Range: 0.00 to 12,641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-11-1D-11L2PB1-1D-11L2PB1 443.12 381.43 443.12 374.01 450.00 51.421 Centre Distance Pass-Major Risk 1D-11-1D-11L2PB1-1 D-11L2PB1 517.94 381.92 517.94 373.25 525.00 44.040 Clearance Factor Pass-Major Risk 1 D-113-1D-113-1D-113 98.70 283.87 98.70 282.02 112.10 153.465 Centre Distance Pass-Major Risk 1D-113-ID-113-ID-113 186.59 284.58 186.59 281.28 200.00 86.176 Clearance Factor Pass-Major Risk 10.114-1D-114-1D-114 586.59 272.18 586.59 262.26 600.00 27.448 Centre Distance Pass-Major Risk 1 D-114-1D-114-1D-114 635.07 272.41 635.07 261.71 650.00 25.478 Clearance Factor Pass-Major Risk 1D-115-1D-115-1D-115 98.70 261.47 98.70 259.62 111.50 141.357 Centre Distance Pass-Major Risk 1D-115-1D-115-1D-115 212.20 261.83 212.20 258.11 225.00 70.545 Clearance Factor Pass-Major Risk 10-116-1D-116-1D-116 98.70 250.93 98.70 249.08 112.10 135.658 Centre Distance Pass-Major Risk 10.116-1D-116-1D-116 186.60 251.66 186.60 248.36 200.00 76.332 Clearance Factor Pass-Major Risk 1D-117-1D-117-1D-117 3,801.08 168.44 3,801.08 148.86 3,600.00 8.601 Clearance Factor Pass-Minor 1/50 10-118-1D-118-10.118 412.30 230.83 412.30 223.97 425.00 33.651 Centre Distance Pass-Major Risk 10.118-1D-118-1D-118 851.24 231.44 851.24 217.57 875.00 16.684 Clearance Factor Pass-Major Risk 1D-119-1D-119-10.119 487.14 203.32 487.14 194.89 500.00 24.132 Centre Distance Pass-Major Risk 10-119-1D-119-1D-119 611.62 204.29 611.62 193.83 625.00 19.532 Clearance Factor Pass-Major Risk 1D-12-10.12-1D-12 2,685.61 118.51 2,685.61 47.01 2,700.00 1.657 Clearance Factor Pass-Major Risk 1D-12-10.12-1D-12 2,726.72 114.46 2,726.72 55.37 2,750.00 1.937 Centre Distance Pass-Major Risk 1D-12-1D-12L1-1D-12L1 2,685.61 118.51 2,685.61 46.81 2,700.00 1.653 Clearance Factor Pass-Major Risk 1D-12-1D-12L1-1D-12L1 2,726.72 114.46 2,726.72 55.24 2,750.00 1.933 Centre Distance Pass-Major Risk 1D-12-1D-12L1PB1-1D-12L1 PB1 2,685.61 118.51 2,685.61 46.81 2,700.00 1.653 Clearance Factor Pass-Major Risk 1D-12-1D-12L1PB1-1D-12L1 PB1 2,726.72 114.46 2,726.72 55.24 2,750.00 1.933 Centre Distance Pass-Major Risk 1D-12-1D-12L2-1D-12L2 2,685.61 118.51 2,685.61 46.81 2,700.00 1.653 Clearance Factor Pass-Major Risk 1D-12-1D-12L2-10.12L2 2,726.72 114.46 2,726.72 55.24 2,750.00 1.933 Centre Distance Pass-Major Risk 1 D-120-1D-120-10.120 98.70 199.83 98.70 197.98 111.60 108.032 Centre Distance Pass-Major Risk 1D-120-1D-120-10-120 659.38 202.42 659.38 191.37 675.00 18.323 Clearance Factor Pass-Major Risk 1D-121-1D-121-1D-121 98.70 194.14 98.70 192.29 112.00 104.957 Centre Distance Pass-Major Risk 10-121-1D-121-10.121 658.98 196.11 658.98 184.99 675.00 17.645 Clearance Factor Pass-Major Risk 1D-122-1D-122-10.122 61.60 189.42 61.60 187.94 75.00 128.276 Centre Distance Pass-Major Risk 1D-122-10-122-10.122 311.59 191.28 311.59 185.60 325.00 33.714 Clearance Factor Pass-Major Risk 1D-123-1D-123-10.123 211.59 184.81 211.59 181.11 225.00 49.984 Centre Distance Pass-Major Risk 30 September,2014- 17:31 Page 3 of 9 COMPASS 0 ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-142-1 D-142wpO6 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 1D Pad-Plan:1D-142-Plan 1D-142-1D-142wp06 Scan Range: 0.00 to 12,641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1 D-123-1D-123-1D-123 261.59 185.06 261.59 180.55 275.00 40.972 Clearance Factor Pass-Major Risk 1D-124-1D-124-1D-124 562.34 180.44 562.34 170.92 575.00 18.948 Centre Distance Pass-Major Risk 1D-124-1D-124-1D-124 635.64 180.93 635.64 170.23 650.00 16.905 Clearance Factor Pass-Major Risk 10-125-1D-125-10-125 236.89 185.46 236.89 181.02 250.00 41.811 Centre Distance Pass-Major Risk 1D-125-10-125-1D-125 461.88 185.93 461.88 177.80 475.00 22.888 Clearance Factor Pass-Major Risk 1D-125-1D-125A-1D-125A 223.44 185.46 223.44 181.46 225.00 46.410 Centre Distance Pass-Major Risk 1D-125-1D-125A-1D-125A 473.43 186.11 473.43 178.01 475.00 22.987 Clearance Factor Pass-Major Risk 1D-126-1D-126-1D-126 187.40 189.27 187.40 186.09 200.00 59.557 Centre Distance Pass-Major Risk 1D-126-1D-126-1D-126 237.39 189.69 237.39 185.68 250.00 47.328 Clearance Factor Pass-Major Risk 1D-126-Plan:1 D-126A-1D-126A(wp02) 187.40 189.27 187.40 185.96 200.00 57.213 Centre Distance Pass-Major Risk 10-126-Plan.1D-126A-1D-126A(wp02) 237.39 189.69 237.39 185.55 250.00 45.840 Clearance Factor Pass-Major Risk 1D-127-1D-127-1 0-127 86.90 193.95 86.90 191.93 100.00 96.342 Centre Distance Pass-Major Risk 1D-127-1D-127-1D-127 186.89 194.51 186.89 191.24 200.00 59.461 Clearance Factor Pass-Major Risk 1D-128-1D-128-1D-128 98.70 199.65 98.70 197.80 111.80 107.934 Centre Distance Pass-Major Risk 1 D-128-1D-128-1D-128 461.89 201.07 461.89 193.24 475.00 25.663 Clearance Factor Pass-Major Risk 1D-129-1D-129-1D-129 212.20 230.35 212.20 226.64 225.00 61.989 Centre Distance Pass-Major Risk 10-129-1D-129-1D-129 262.19 230.75 262.19 226.21 275.00 50.843 Clearance Factor Pass-Major Risk 1D-130-1D-130-1D-130 562.20 239.02 562.20 229.54 575.00 25.213 Centre Distance Pass-Major Risk 10-130-1D-130-10-130 587.19 239.24 587.19 229.35 600.00 24.195 Clearance Factor Pass-Major Risk 1D-131-1D-131-1D-131 98.70 250.40 98.70 248.55 112.00 135.369 Centre Distance Pass-Major Risk 10-131-10-131-1D-131 186.70 250.98 186.70 247.68 200.00 76.134 Clearance Factor Pass-Major Risk 1 D-132-10-132-10-132 98.70 260.88 98.70 259.03 111.90 141.035 Centre Distance Pass-Major Risk 1D-132-10-132-1D-132 161.80 261.24 161.80 258.36 175.00 90.757 Clearance Factor Pass-Major Risk 1D-133-10-133-1D-133 262.16 271.46 262.16 266.92 275.00 59.776 Centre Distance Pass-Major Risk 10-133-10-133-1D-133 462.15 272.89 462.15 265.07 475.00 34.894 Clearance Factor Pass-Major Risk 10-133-1D-133PB1-1D-133PB1 262.16 271.46 262.16 266.92 275.00 59.776 Centre Distance Pass-Major Risk 10-133-1D-133PB1-1D-133PB1 462.15 272.89 462.15 265.07 475.00 34.894 Clearance Factor Pass-Major Risk 10-141-1D-141-1D-141 1,585.01 77.04 1,585.01 39.83 1,650.00 2.070 Clearance Factor Pass-Major Risk 10-141-1D-141A-1D-141A 1,575.21 77.14 1,575.21 39.58 1,650.00 2.054 Clearance Factor Pass-Major Risk 1D-141-1D-141APB1-1D-141APB1 1,575.21 77.14 1,575.21 39.71 1,650.00 2.061 Clearance Factor Pass-Major Risk 30 September,2014- 17:31 Page 4 of 9 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup1 Kuparuk River Unit Anticollision Report for Plan: 1D-142-1 D-142wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-142-Plan 1D-142-1D-142wp06 Scan Range:0.00 to 12,641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1 D-141-1 D-141APB2-1 D-141APB2 1,575.21 77.14 1,575.21 39.71 1,650.00 2.061 Clearance Factor Pass-Major Risk 1 D-141-1 D-141APB3-1 D-141AP63 1,575.21 77.14 1,575.21 39.71 1,650.00 2.061 Clearance Factor Pass-Major Risk 1 D-141-1D-141L1-1D-141L1 1,585.01 77.04 1,585.01 39.83 1,650.00 2.070 Clearance Factor Pass-Major Risk 1D-141-1D-141L1 PB1-1D-141L1PB1 1,585.01 77.04 1,585.01 39.83 1,650.00 2.070 Clearance Factor Pass-Major Risk 1D-141-1D-141L1 PB2-10-141L1PB2 1,585.01 77.04 1,585.01 39.83 1,650.00 2.070 Clearance Factor Pass-Major Risk 1D-141-1D-141PB1-1D-141PB1 1,585.01 77.04 1,585.01 39.70 1,650.00 2.063 Clearance Factor Pass-Major Risk 1D-28-1 D-28-1 D-28 664.82 94.53 664.82 8324 675.00 8.377 Centre Distance Pass-Major Risk 1D-28-1D-28-1D-28 714.18 95.02 714.18 82.96 725.00 7.873 Clearance Factor Pass-Major Risk 1 D-28-1 D-28L1-1 D-28L1 664.82 94.53 664.82 83.24 675.00 8.377 Centre Distance Pass-Major Risk 1D-28-1D-28L1-1D-28L1 714.18 95.02 714.18 82.96 725.00 7.873 Clearance Factor Pass-Major Risk 1D-30-1D-30-1D-30 98.70 137.17 98.70 135.32 105.30 74.157 Centre Distance Pass-Major Risk 1D-30-1D-30-1D-30 767.75 141.13 767.75 128.58 775.00 11.244 Clearance Factor Pass-Major Risk 1D-30-1D-30L1-1D-30L1 98.70 137.17 98.70 135.32 105.30 74.157 Centre Distance Pass-Major Risk 1D-30-1D-30L1-1D-30L1 767.75 141.13 767.75 128.58 775.00 11.243 Clearance Factor Pass-Major Risk 1D-32-1D-32-1D-32 518.90 165.57 518.90 156.66 525.00 18.580 Centre Distance Pass-Major Risk 1D-32-1D-32-1D-32 643.07 166.44 643.07 155.42 650.00 15.110 Clearance Factor Pass-Major Risk 1D-32-1D-32L1-1D-32L1 518.90 165.57 518.90 156.79 525.00 18.846 Centre Distance Pass-Major Risk 1D-32-1 D-32L1-1 D-32L1 643.07 166.44 643.07 155.55 650.00 15.282 Clearance Factor Pass-Major Risk 1D-32-1 D-32L1 PB1-1 D-32L1 PB1 518.90 165.57 518.90 156.66 525.00 18.576 Centre Distance Pass-Major Risk 10-32-1 D-32L1 PB1-1D-32L1PB1 643.07 166.44 643.07 155.42 650.00 15.105 Clearance Factor Pass-Major Risk 10-34-1D-34-1 D-34 468.53 196.02 468.53 187.97 475.00 24.340 Centre Distance Pass-Major Risk 1D-34-1D-34-1D-34 543.18 196.56 543.18 187.23 550.00 21.088 Clearance Factor Pass-Major Risk 1D-34-1D-34L1-1D-34L1 467.54 196.02 467.54 187.87 475.00 24.062 Centre Distance Pass-Major Risk 10-34-1D-34L1-1D-34L1 542.18 196.54 542.18 187.12 550.00 20.876 Clearance Factor Pass-Major Risk 10-34-1D-34L1 PB1-10-34L1 PB1 467.54 196.02 467.54 187.98 475.00 24.390 Centre Distance Pass-Major Risk 1D-34-1D-34L1 PB1-1D-34L1 PB1 542.18 196.54 542.18 187.23 550.00 21.122 Clearance Factor Pass-Major Risk 1 D-36-1D-36-1D-36 243.40 226.88 243.40 222.68 250.00 53.969 Centre Distance Pass-Major Risk 1D-36-1D-36-1D-36 542.75 228.66 542.75 219.47 550.00 24.871 Clearance Factor Pass-Major Risk 1D-36-1D-36-1D-36WP4(Baker) 393.35 227.21 393.35 220.42 400.00 33.473 Centre Distance Pass-Major Risk 1D-36-1D-36-1D-36WP4(Baker) 616.84 228.54 616.84 217.94 625.00 21.555 Clearance Factor Pass-Major Risk 30 September,2014- 17:31 Page 5 of 9 COMPASS II • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-142-1 D-142wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-142-Plan 10-142-1 D-142wp06 Scan Range:0.00 to 12641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-36-1 D-36L1-1 D-36Lt 242.70 226.88 242.70 222.69 250.00 54.117 Centre Distance Pass-Major Risk 1D-36-1 D-36L1-1 D-36L1 542.06 228.65 542.06 219.46 550.00 24.898 Clearance Factor Pass-Major Risk 1D-36-1 D-36L2-1D-36L2 242.70 226.88 242.70 222.69 250.00 54.117 Centre Distance Pass-Major Risk 1D-36-1 D-36L2-1 D-36L2 542.06 228.65 542.06 219.46 550.00 24.898 Clearance Factor Pass-Major Risk 1D-37-1D-37-1D-37 790.34 236.57 790.34 223.57 800.00 18.198 Centre Distance Pass-Major Risk 1D-37-1D-37-1D-37 862.82 237.13 862.82 223.00 875.00 16.791 Clearance Factor Pass-Major Risk 1D-37-1 D-37L1-1 D-37L1 789.27 236.57 789.27 223.59 800.00 18.222 Centre Distance Pass-Major Risk 1D-37-1D-37L1-1D-37L1 861.79 237.11 861.79 223.00 875.00 16.809 Clearance Factor Pass-Major Risk 1 D-37-1 D-37L2-1 D-37L2 789.27 236.57 789.27 223.59 800.00 18.222 Centre Distance Pass-Major Risk 1D-37-1D-37L2-1D-37L2 861.79 237.11 861.79 223.00 875.00 16.809 Clearance Factor Pass-Major Risk 1D-37-1D-37L2PB1-1D-37L2PB1 789.27 236.57 789.27 223.59 800.00 18.222 Centre Distance Pass-Major Risk 1D-37-1D-37L2PB1-1D-37L2PB1 861.79 237.11 861.79 223.00 875.00 16.809 Clearance Factor Pass-Major Risk 1D-38-1D-38-1D-38 889.77 254.31 889.77 239.64 900.00 17.343 Centre Distance Pass-Major Risk 1 D-38-1D-38-1D-38 937.34 254.48 937.34 239.06 950.00 16.501 Clearance Factor Pass-Major Risk 1 D-39-1D-39-1D-39 712.25 268.75 712.25 256.52 825.00 21.973 Centre Distance Pass-Major Risk 1 D-39-1D-39-1D-39 859.32 270.48 859.32 256.16 975.00 18.889 Clearance Factor Pass-Major Risk 1 D-40-1 D-40-1D-40 692.68 284.71 692.68 273.10 700.00 24.530 Centre Distance Pass-Major Risk 1D-40-1D-40-1D-40 791.78 285.25 791.78 272.14 800.00 21.757 Clearance Factor Pass-Major Risk 1 D-40-1 D-40A-1 D-40A 693.53 284.71 693.53 273.09 700.00 24.502 Centre Distance Pass-Major Risk 1D-40-1D-40A-1D-40A 792.62 285.27 792.62 272.14 800.00 21.737 Clearance Factor Pass-Major Risk 1D-41-1D-41-1D-41 9,559.62 244.71 9,559.62 137.00 7,050.00 2.272 Centre Distance Pass-Major Risk 1D-41-1D-41-1D-41 9,583.34 248.24 9,583.34 132.51 7,100.00 2.145 Clearance Factor Pass-Major Risk 1D-41-1 D-41 PB1-10-41P131 9,559.62 244.71 9,559.62 137.26 7,050.00 2.277 Centre Distance Pass-Major Risk 1D-41-10-41 PB1-1 D-41 P81 9,583.34 248.24 9,583.34 132.77 7,100.00 2.150 Clearance Factor Pass-Major Risk 1D-41-1D-41PB2-1D-41PB2 9,559.62 244.71 9,559.62 137.26 7,050.00 2.277 Centre Distance Pass-Major Risk 1D-41-1 D-41 PB2-1 D-41 PB2 9,583.34 248.24 9,583.34 132.77 7,100.00 2.150 Clearance Factor Pass-Major Risk Plan:1D-143-Plan:1D-143-1 D-143wpt3 450.00 30.00 450.00 21.78 450.00 3.648 Centre Distance Pass-Major Risk Plan:1D-143-Plan:1D-143-1D-143wp13 599.95 30.52 599.95 19.87 600.00 2.867 Clearance Factor Pass-Major Risk Plan:1D-143-Plan:1D-143L1-1D-143L1wp13 450.00 30.00 450.00 21.78 450.00 3.648 Centre Distance Pass-Major Risk Plan:1D-143-Plan:1 D-143L1-1 D-143L1 wp 13 30 September,2014- 17:31 Page 6 of 9 COMPASS • III ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-142-1 D-142wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk ID Pad-Plan:1D-142-Plan 10-142-1D-142wp06 Scan Range:0.00 to 12,641.71 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:1 D-143-Plan:1 D-143L2-1D-143L2wp13 450.00 30.00 450.00 21.78 450.00 3.648 Centre Distance Pass-Major Risk Plan:1D-143-Plan:1 D-143L2-1 D-143L2wp13 599.95 30.52 599.95 19.87 600.00 2.867 Clearance Factor Pass-Major Risk Plan:1 D-143-Plan:1 D-143L3-1 D-143L3wp13 450.00 30.00 450.00 21.78 450.00 3.648 Centre Distance Pass-Major Risk Plan:1 D-145-Plan:1D-145-1 D-145wp06 1.588 Centre Distance Plan:1 D-145-Plan:1 D-145-1 D-145wp06 1,077.28 28.44 1,077.28 10.53 1,075.00 Pass-Major Risk 1,152.70 28.99 1,152.70 9.90 1,150.00 1.519 Clearance Factor Pass-Major Risk Plan:1 D-146-Plan:1 D-146-1 D-146wp04 300.00 60.01 300.00 54.51 300.00 10.923 Centre Distance Pass-Major Risk Plan:1 D-146-Plan:1D-146-1 D-146wp04 524.95 61.47 524.95 52.32 525.00 6.715 Clearance Factor Pass-Major Risk Sun'eV tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 1,300.00 1D-142wp06 GYD-GC-SS 1,300.00 2,700.00 1D-142wp06 MWD 1,300.00 2,700.00 1D-142wp06 MWD+IFR-AK-CAZ-SC 2,700.00 3,700.00 1D-142wp06 MWD 2,700.00 6,577.72 1D-142wp06 MWD+IFR-AK-CAZ-SC 6,577.72 7,577.00 1D-142wp06 MWD 6,577.72 12,641.71 1 D-142wp06 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 30 September,2014- 17:31 Page 7 of 9 COMPASS MD Inc Az TVD +N/-S +E/-W DLeg TFace VS gel 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0 1 D-142wp06 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0. 28 600 3 850.18 3.75 85.00 850.00 0.71 8.16 1.50 85.00 6.27 41359.49 16.89 73.23 1350.00 23.62 96.01 2.60 -15.00 65.10 _ 28.00 To 12641.71 51417.55 18.32 71.59 1405.34 28.94 112.75 2.60 -20.00 75.76 600 900 61517.55 18.32 71.59 1500.27 38.87 142.57 0.00 0.00 94.49 7 2650.00 65.00 52.63 2325.71 429.58 755.36 4.23 -23.38 372.36 900 1100 8 4590.00 65.00 52.63 3145.59 1496.76 2152.69 0.00 0.00 904.88 IFF. le 9 5400.00 65.00 92.00 349933 1713.74 2833.21 439 98.60 1337.87 1100 - 1400 105837.33 75.54 110.63 3647.93 1631.35 3233.67 4.67 62.44 1713.16 11 5837.33 75.54 110.63 3647.93 1631.35 3233.67 0.00 0.00 1713.16 1400 1700 12 6577.72 85.00 145.00 3776.70 1189.03 3798.48 4.74 77.86 2429.53 1D-142 01Apr14 DL D1 GLOBAL FILTER APPLIED: 146860.35 85.00 148.33 3792.03 1172.71533809.90 0.00 9.33 26 .95 14 6860.35 89.07 148.33 3792.03 953.66 3953.97 2.00 39.33 269181.91 1700 _� - 2000 15 7949.24 89.07 148.33 3809.72 27.07 4525.65 0.00 0.00 3691.67 168192.40 90.00 153.10 3811.70 -184.93 4644.56 2.00 78.99 3910.68 1D-142 01Apr14 DL D2 2000 2200 17 8215.89 89.86 153.55 3811.73 -205.93 4655.11 2.00 107.74 3931.36 epin Rom Depth TO senarivan roof 18 9107.29 89.86 153.55 3813.96 -1004.00 5052.18 0.00 0.00 4714.38 2200 2500 19 9699.96 90.00 165.40 3814.70 -1558.04 5259.62 2.00 89.32 5202.09 1D-142 01 r14 DL D3 1300.00 2770000.00 1D-102wpp06 M Men 16102)Ran 16102) WDcc-ss 209757.62 91.52 165.31 3813.93 -1613.83 5274.20 2.65 -3.29 5246.03 2500 3100 1300.00 2700.00 16102wp061Pkn 16102) o.1Fa.nx-COS.eC 21 9768.29 91.52 165.31 3813.65 -1624.15 5276.91 0.00 0.00 5254.16 2700.00 3700.00 me-102wp06(Plan 16102) 2700.00 6677.72 16102wp06(Ran 6B/DdFRAKA7SdC 220359.96 90.00 184.65 3805.70 -2210.68 5328.40 3.28 94.34 5632.76 1D-142 01Apr14 DL D4 3100 3600 6577.72 7577.00 o-102wp06( n- Plan 1102) 01X0 230390.18 90.60 184.60 3805.54 -2240.81 5325.96 2.00 -4.67 5648.05 r 6577.72 17601.71 16112w606(Plan 107702) 188I13,11N(6026C 241239.70 90.60 184.60 3796.61 -3087.54 5257.82 0.00 0.00 6077.90 291362.96 91.17 187.00 3794.70 -3210.14 5245.37 2.00 76.68 6138.02 1 D-142 08Jan14 DL 05 3600 4200 281363.87 91.17 187.02 3794.68 -3211.05 5245.26 2.00 105.69 6138.45 CASING DETAILS 272641 71 91.17 187.02 3768.70 -4479.05 5089.17 0.00 0.00 6737.88 1D-142 08Jan14 DL D6 4200 4800 TVD MD Name Sae 4800 5300 2349.70 2706.76 10-3/4•'x13-1/2•' 10-3/4 3776.70 6577.72 7-5/8"x9-7/8•' 7-5/8 5300 5900 3768.70 12641.71 4-1/2"x6-3/4•' 4-1/2 5900 6500 0/360 6500 7029 ie Off,2� /nen,,. 7029 7800 -30/330 `t"�i.�� Z ��r ylittle 30 7800 8500 ,-:%!/I�,�� .rjar�iw•.. ♦ ,*Si="c ar. ')T•4" psiIts Oi 8500 9300 �.. wi.. �a rrr, - 21:" ��. 9300 10100 i 1`'',1 `1fiti .'�9 y �1ileiti 10100 10800 .I�.•�,'�' ,�,44 •rte//r rr:r.; : �0/ ...`,,l,A►I�e �® 10800 11600 /to : 1��ii/✓IJr 1,.afe I�,gall,'$4V' \ 11600 12300 ✓�� 1 iy�__�/��irpg1 11,13lr.. I� - 12300 13092 -60/300 Al �� ..r��- �'`7e►I,R� �� ®\ AMR_reAh,....44. , .,40110.-__...,--4-c---Ivitiri.,:.,,,peAlfrif,"0,-0471,..4"-* Ill �.,.�1.1� L,'1,... 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ViV itil 1M��F,''Veilli r i(41040:t ei/ii.,`9 •-150/210 .��1� ;(v`` 'tGirF '14,• I�1r 150 ``aa 1 r�',4s , ��•�\V` r!A�'� 6,,,,v\`ami,, 110.143wp1 -- -- rte'•-- e:: ._ - . /10.143L3wp13 -180/180 ', 11D-3a1 110-30L1 ho-145w h143L a2wp11 110.143L1wp19 _ i . - 11/ ConocoPhillips 1 D-142wp06 Schlumberger Alaska m v a D o 6 d 60 / t E eL / rn c a) - 'A U a 30— i� d c - U Equivelant Magnetic Distance 0 I I I I I I I I I I 1 1 I I t I I I I I I I 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire raptured Depth 28.00 To 12641.71 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 12641.71 Results Limited By: Centre Distance:2383.08 NO GLOBAL FILTER:Using user defined selection&filtering criteria SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1300.00 1D-142wp06 (Plan 1D-142) GYD-GC-SS 1300.00 2700.00 1D-142wp06 (Plan 1D-142) MWD 1300.00 2700.00 1 D-142wp06 (Plan 1 D-142) MWD+IFR-AK-CAZ-SC 2700.00 3700.00 1D-142wp06 (Plan 1D-142) M W D 2700.00 6577.72 1D-142wp06 (Plan 1D-142) MWD+IFR-AK-CAZ-SC 6577.72 7577.00 1D-142wp06 (Plan 1D-142) MWD 6577.72 12641.71 1D-142wp06 (Plan 1D-142) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2349.70 2706.76 10-3/4"x13-1/2" 10-3/4 3776.70 6577.72 7-5/8"x9-7/8" 7-5/8 3768.70 12641.71 4-1/2"x6-3/4" 4-1/2 • SDD0 11 D-1 42wp05 6 . 909 Plan Summary SURVEY PROGRAM )ept 1 From Depth To Survey/Plan T 28.00 1200.00 1D-142wp05 (Plan 1D-142) GYD-GC- 1 200.00 2667.34 1D-142wp05 (Plan 1D-142) M\ 1 200.00 2667.34 1D-142wp05 (Plan 1D-142) MWD+IFR-AK-CAZ-- /- ,NN 067.34 4167.34 1D-142wp05 (Plan 1D-142) M\ �� j 2,`` ,- 867.34 6601.04 1D-142wp05 (Plan 1D-142) MWD+IFR-AK-CAZ ''` �.., 8501.04 8101.04 1 D-142wp05 (Plan 1D-142) MV (Viiii\\ASII.:411k�`na nn .1nrrA nn 1n 4An.....nr mi. . 4n 4An, \Ilnm Irn nl,,A,1. CASING DETAILS 1I�t. \ ' -TVD MD Name Size \.. _ �Iii4 `\ 2349.70 2667.34 10-3/4"x13-1/2" 10-3/4 I* 3776.70 6601.04 7-5/8"x9-7/8" 7 5/8 - w-. 3768.70 12664.92 4-1/2"x6-3/4" 4-1/2 "r'' - _ Base permafrost ugc ugb NTop W Sak o 5- 1 T3 k15 1 i uga1 I.a 7-5/8"x9-7/8" 0° > , ' { -5 „,r-3/4"x13-1/2" l i , 1 , , o AV° 4-1/2"x6-3/4" - , , �-a 1 i 1 4-1/2"x6-3/4" - 0 2 cu - J - Y �� ° o N / tph p0 / ' 00 m - n.../ 1 - S 7 O _(t o / O O O 1 O / II,pl11 1 O h0 O O O ° O 1 10-3/4"x13-1/2" _ -11 - co /` , n m m m hilli 0 i i i i i r i i ill III 1 f r 0 .�; d 0 3000 6000 9000 12000 0 1500 3000 4500 6000 75(% 000 o0 16500 Measured Depth Horizontal Departure w il. --r .': 0 330 f. 30 o ppIA iry 11 - Q60 0on��l„I1& 1 ` . ��io = 1700 L a 171,3 2000 300 -4��b �. 2203 dRI 2500 3,00 CS▪30 44' �t4 -_ 4200 20 a all 2703600 �I►�IjyII, s .zoo - 4200 2 MIPI "��pi •.ire 4w° .. 4 2200 c ..• �`, / �,�'t 222° U - 240 g$ 1 t'//'. . i. 120 - 93000 1 1 I I I I I I ' I I I I I I I I I .( I 210�( ;' I = '•iefiwp°1'" 0 1500 3000 4500 6000 7500 9000 10500 12000 74."1p,2 10000 11600 - 18011600 - 12300 SE • ,DETAILS 127 - ' Sec MD Inc Azi TVD TVDSS +N/-S +E/- lip Northing Northing Basting DLeg TFace VSec Target -1650.7 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.I , 5959150.00 1700702.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 501.30 0.00 ,.J11 5959150.00 1700702.00 0.00 0.00 0.00 Base permafrost 3 850.18 3.75 85.00 850.00 751.30 0.71 ; 6 5959150.78 1700710.15 1.50 85.00 6.27 4 1571.94 22.41 72.39 1550.00 1451.30 44.80 164.22 5959196.11 1700865.84 2.60 -15.00 108.82 -1859.7 5 2750.00 65.00 49.50 2386.63 2287.93 482.01 847.91 5959638.51 1701515.94 3.81 -29.99 393.52 6 4302.88 65.00 49.50 3042.90 2944.20 1396.04 88.09 5960561.01 1702578.65 0.00 0.00 745.90 T3 7 5400.88 65.00 92.00 3525.08 3426.38 1713.77 797.93 5960885.99 1703485.83 3.49 99.33 1308.96 8 5677.00 76.11 100.01 3616.99 3518.29 1685.98 3056.14 5960860.28 1703744.23 4.86 35.64 1536.41 -21147 9 5679.33 76.11 100.01 3617.55 3518.85 1685 58 3058.37 5960859.90 1703746.46 0.00 0.00 1538.46 10 6601.04 85.00 145.00 3776.70 3678.00 1206.66 3801.17 5960387.00 1704493.00 4.90 83.15 2421.62 10-142 01Apr14 DL D1 11 6621.04 85.00 145.00 3778.44 3679.74 1190,34 3812.59 5960370.77 1704504.56 0.00 0.00 2440.34 12 6829.71 89.01 148.35 3789.35 3690.65 1016.28 3927.03 5960197.66 1704620.38 2.50 39.93 2633.92 13 8021.34 89.01 148.35 3810.01 3711.31 `2.08 4552.29 5959188.60 1705253.69 0.00 0.00 3727.82 14 8215.59 90.00 153.10 3811.70 3713.00 67.30 4647.25 5959020.00 1705350.00 2.50 78.22 3902.77 1D-142 01Apr14 DL D2 15 8243.15 89.66 153.53 3811.78 3713.08 191.93 4659.63 5958995.48 1705362.57 2.00 128.56 3927.03 16 9127.01 89.66 153.53 3817.08 3718.38 -983.13 5053.57 5958207.54 1705762.81 0.00 0.00 4703.54 17 9723.19 90.80 165.40 3814.70 3716.00 -1540.41 5262.32 5957652.00 1705976.00 2.00 84.49 5194.18 1D-142 01Apr14 DL D3 k15 18 9723.37 90.79 165.40 3814.70 3716.00 -1540.58 5262.36 5957651.83 1705976.05 3.03 165.48 5194.32 19 9794.53 90.79 165.40 3813.71 3715,01 -1609.44 5280.29 5957583.13 1705994.53 0.00 0.00 5248.50 20 10383.16 90.75 184.65 3805.70 3707.00 -2193.05 5331.09 5957000.00 1706050.00 3.27 90.00 5624.85 1D-142 01Apr14 DL D4 21 10391.48 90.59 184.60 3805.60 3706.90 -2201.34 5330.42 5956991.71 1706049.40 2.00 -161.93 5629.06 22 11261.70 90.59 184.60 3796.61 3697.91 -3068.70 5260.66 5956123.89 1705986.60 0.00 0.00 6069.41 23 11386.16 91.17 187.02 3794.70 3696.00 -3192.51 5248.06 5956000.00 1705975.00 2.00 76.55 6130.11 1D-142 08Jan14 DL D5 24 12664.92 91.16 187.02 3768.70 3670.00 -4461.42 5091.86 5954730.00 1705829.00 0.00 -154.70 6729.97 1D-142 08Jan14 DL D6 -3112.7 / ugc -3323.7 ugb 3454.7 -35u N 3738p7W S:k Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 T M Depth Reference: Plan:(70.7+28)@ 98.70ft(Doyon 141) Magnetic Model Date: 18-Oct-13 System(SS) Reference: Mean Sea Level Magnetic Declination: 19.77° -1Eti- North /Y: 5959150.00 Ground Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.77°East East/X: 1700702.00 Rig: Doyon 141 NO GLOBAL FILTER:Using user defined selection&filtering criteria URIUINAL • 4. ` ... Ykq gitlii 1lq@VVeM>ltt .F..„ La 4.* ?..�„�ke *0u,��„ Ii N� U H c 0 cn 0 U Q r m ^ LLa Q. / a MC O I U O . \ ° V No C U o ca /\ IF CU 00 k,?/)//''' ( p 0 Q (i) / CL CU E Co an � E as (..) R0et4 e � � r V) r O Y Y O N L 1-. T r >, as ORf CCS RS E V = 1 a a a a N U \ dam { ` AL , • • 1 coa z m z NW = CO 00 CO fq C, 4ItiM. N O (O I,- r M o N 0 C v o O Uo ch O a On N o co CC V) i. p M O 6 O V V I� _ co a n , Q O O T( 0 V 0 0 0 0 o 0 ❑ c O 4, O O O U Ua] CO O a) O W V v v p O U (0:E W 2 a ta > ' U S- + + 3 m J a• = y r.-- N- O N = a •• (./1 H m o o E m ami m > Q Cl) 0) ci m Cl- c c al — c cn rn ui ' ,a, O a TDm m ` p d N m U 3 . c E a 1- 2 w 2 D D aci of (NC O J 0 0 m > ac -o = o oo c ° rn U ,- y L J J C9 L ILa ` dN C) v 5 x L F m p (p cca co lccij , a 2 C 0 6 U -0u. Q i w 6 a w O at U y E o O o U >, a) ro - O ❑ v- O i- E Z (n ❑ co v a= J o O r ❑ °)) o CD 0 LO O I- O N O (0 0 (0 6) 0 al CO c E a L ❑ Q N C a a CO a. CZ." 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Tom o of 0 0co00 N o 0 O 0 T _o 1 0 0 0 0I O oI cp Lc) N. in N o N. 05L) gTdea laa N- CV anal CO CO !/� ORIuINAL " Northing (3500 ft/in) • � � � I � � � � I � � � � I � � � , IiiiiIi ( iiIii , ' L1111 � � � 11 , 11 , Iiii , IiiiiI [ iijI � � � iIli ' - a - • 0 j- N aJ m — 1 a ;� T O — a o El n M 0 i - /■■ .I - 3- : ,..Ca _ C _ N 1 ',..1,,i, r _ CI i ,I= . 'P;' Ari4V a.) 4-. - al C _ 1 t d, - CO - CO t. i„„, _........ .. ,,,,_,. A — Ertl N N ! I c. ";.") (Airr P—. ___ 0 C13- co T Q O _ a CS _ fr- oo"' 'If: Q o — ys T '.......0 4' CLS . �� o ch -0 _ - CI M —0, Cti -_ - �, M\•tt • T '4"' N S. _ \ N.N — r r _ = stip - Z� - Oa i. - y� W - Q� RTrn _ .4. 7 3 8 - N - o - N — — 4 I I1111Y Iiiiiiiii1111111111111111111iiiiiiI111111111111111 • i O N N N N N co co co (O N N- N- (O (O N CO • • • • • • a O r r r r r r ,- r r r r r r r r 0 O m NL E. 'C O 7 N 0) 0) O N O 7 W CO 00 O) a) 7 0 N (O N C C O O N CO 7 CO C--- 00 0) O N CO )O CO(O O O O O O O O O O O O o ( 0U O 0 O 0 0 W 0 0 N` N` O J.. 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N d t LL' a O C r CL r N N 7 CO W Y Y o s, ~ O O (• 0 as C C r O La 6 0• y y a a - E 0 0 0 7 7 7 7 0 0 0 0 0 0 0 o o CO r 0 0 0 0 0 0 E O O O co M O O• 0 0 0 0 0 L•100 ,- 00000 0 C00000 00 •= O O O J C] O O O 0 6 �. N N 'C'3,1 O (O (O (O d N O o O O 00 0 0 O N 0 00000 O O. r N CO 7 N (D f- N CO 0) O N M 7 N E r r N N O O V t G O` eg Co 0 .2 .cc r r r r r isi c .. m E- u .g 2 ,- m (n v m u p c ' comm m d = to C O a. ul 0 40 0. ORIGINAL • i cn ". N N IN IN Z"71CO V co V V O N- O CC CO r O V CO O0 0 o co co V (O f` a • r r• • r r r r r r r r r r N N r r r r r 3 O co h 6 W• r r (ti 3 N 0 NI- IN V CO CO (O (` O O CO V30 l() CO CO Q) CO CO r V CO CO O Q 6) N CO co co V N N O O 6) 6) O CO CO CO M N- s- M p C C • N N N N M V V (O (O (O (O o3 O) O (O V) (O r (O C O O ,— ,— ,— O 0 0 W O O .4 N- IN R W 00 (O J 6) O) 0) > N V a O O • CO CO 0 O V N- 6) 63 N CO V CO 1` N W N V N 63 IN V (O 0) N 0 N N r CO r N VCO CO lO (O 00 N r CO. 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Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti-Collision Moderate Follow real time surveys very closely, shut in 1D-117. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. Attachment 2-1D-142 Drilling Hazards Summary.doc 9/18/20142:37:12 PM • 1 D-142 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casin. (V1 Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Nabors 9ES Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2168' MD. Client:CPAI Revision Date: July 10,2014 Prepared by:Jenna Houston Location:Anchorage,AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -240 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11.00 ppg-1.91 ft3/100 lb sk email:jhouston2@slb.com 1.339 ft3/ft x 122 x 1.0 (0%excess) = 164 ft3 7 < TOC at Surface 0.3637 ft3/ft x (1682-122) x 3.50 (250%excess) = 1986 ft3 0.3637 ft3/ft x (2168-1682) x 1.50 (50%excess) = 266 ft3 1986 ft3+ 164 ft3+266 fti= 2416 ft3 2416 ft3/ 1.91 ft3/sk= 1265 sks(1270 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (2668-2168) x 1.50 (50%excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk= 195 sks Round up to 205 sks BHST=69°F, Estimated BHCT=76°F. (Based on 2.1¶1100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,682'MD(1,650'TVD) Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 7.0 50.0 7.1 7.1 MUDPUSH H 7.0 50.0 7.1 14.2 Pause 0.0 0.0 5.0 19.2 < Top of Tail at 11 ppg DeepCRETE 7.0 430.0 61.4 80.6 2,168'MD Lead Surface Tail 7.0 56.3 8.0 88.6 DeepCRETE Slurry Pause 0.0 0.0 5.0 93.6 Fresh Water 5.0 10.0 2.0 95.6 Pause 0.0 0.0 5.0 100.6 Mud 8.0 228.9 28.6 129.2 Mud 3.0 10.0 3.3 132.5 < 10 3/4",45.5#casing in 13.5"OH MUD REMOVAL Expected Mud Properties:10.0 ppg, Pv<20, Ty<20 TD at 2,668 MD Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21,Ty=20-25 (2,350'TVD) Centralizers: As per CPAi program. Mark of Schlumberger 1 D-142 Schlumberger CemCADE Preliminary Job Design 7 5/8" Intermediate (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nabors 9ES Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: July 10,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -215 min. (pump time plus 120 min.) Phone:(907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@s1b.com 0.2148 ft3/ft x (6601'-3900') x 1.4(40%excess) = 813 ft3 Shoe Volume: 0.2578 ft3/ft x 80'x 1.00 (no excess) = 21 ft3 Totals: 813 ft3+21 ft3= 834 ft3 834 ft3/1.16 ft3/sk= 719 sks(730 sks) BHST= 99 °F, Estimated BHCT=82 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.0 50.0 10.0 10.0 10 3/4",45.5#casing Pause 0.0 0.0 5.0 15.0 at 2668'MD Tail Slurry 5.0 148.3 29.7 44.7 Pause 0.0 j 0.0 5.0 49.7 Fresh Water 5.0 10.0 2.0 51.7 Pause 0.0 0.0 5.0 56.7 Mud 6.0 279.4 46.6 103.3 Top of Tail at Mud 3.0 10.0 3.3 106.6 end of pumping < 3900'MD MUD REMOVAL Recommended Mud Properties:9.6 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. 7 5/8",29.7# ins 7/8"hole Spacer Properties:10.5 ppg MudPUSH* II, Pv=25- 30, Ty=30 -40 Centralizers: As per CPAi program TD at-6601 'MD (3778'TVD) * Mark of Schlumberger ORIGINAL . • • > \[/ ( ) , \ / \\. 0 ,,,..4 SD 1 ( E-. ) •I • III \ ) • / 00 1 / a . • 3 I � . ¢ \ \ } . 2 . E ` 2 '/a \/ 1 • \ 4> =` iI /2 7, TI" ; • // r � . A , HI ».3 ))t ® / rn \ 110 \/\\- r[ (/Q ) §* /` /k - - ) ; ` ` t \\\ » d, 2 « \\ \ Ir' 2/ \ƒ !33§ - /:%\ \\\\ * / »\ Cono£0Ph1l Alaska \ \Draft#R�\�- �ƒeo m1D-142+ _a \ ; | \ i§ • Ap•ion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 West Sak Well #1 D-142 66 f.A Injection Documentation A. MaxWell M p x i rrt i a E Well Volae Table of Contents 1. Plat of All Wells Within 1/4 Mile Radius of Injection Well 2 Requirements of 20 AAC 25.402 (c) (1) 2 2. List of Operators / Surface Owners 2 Requirements of 20 AAC 25.402 (c) (2) 2 3. Affidavit to Operators / Surface Owners Proving Notice of Injection 2 Requirements of 20 AAC 25.402 (c) (3) 2 4. Description of Operation 2 Requirements of 20 AAC 25.402 (c) (4) 2 5. Name and Descrcption of Affected Pools 2 Requirements of 20 AAC 25.402 (c) (5) 2 6. Name and Description of Affected Formations 3 Requirements of 20 AAC 25.402 (c) (6) 3 7. Logs of Off-Set Injection Wells 3 Requirements of 20 AAC 25.402(c) (7) 3 8. Casing Design and Mechanical Integrity 3 Requirements of 20 AAC 25.402(c) (8) 3 9. Fluid Injection Data 4 Requirements of 20 AAC 25.402 (c) (9) 4 10.Injection Pressure 4 Requirements of 20 AAC 25.402 (c) (10) 4 11.Reservoir Containment 4 Requirements of 20 AAC 25.402 (c) (11) 4 12.Formation Water Analysis 5 Requirements of 20 AAC 25.402 (c) (12) 5 1D-142 Injection PERMIT.doc k G I N AL Page 1 of 7 Printed: 18-Sep-14 • ApOtion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 13.Freshwater Exemptions 6 Requirements of 20 AAC 25.402 (c) (13) 6 14.Increase in Hydrocarbon Recovery 6 Requirements of 20 AAC 25.402 (c) (14) 6 15.Offset Wells Mechanical Conditions 7 Requirements of 20 AAC 25.402 (c) (15) 7 1. Plat of All Wells Within 1/4 Mile Radius of Injection Well Requirements of 20 AAC 25.402 (c) (1) An application for injection must include:(1)a plat showing the location of each proposed injection well,abandoned or other unused well,production well,dry hole,and other well within one-quarter mile of each proposed injection well; The plot for 1D-142 quarter-mile injection review can be found in attachment #1 2. List of Operators / Surface Owners Requirements of 20 AAC 25.402(c) (2) An application for injection must include:(2)a list of all operators and surface owners within a one-quarter mile radius of each proposed injection well; N/A since we are in the existing Kuparuk unit. 3. Affidavit to Operators / Surface Owners Proving Notice of Injection Requirements of 20 AAC 25.402 (c) (3) An application for injection must include:(3)an affidavit showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for injection; N/A since we are in the existing Kuparuk unit. 4. Description of Operation Requirements of 20 AAC 25.402 (c) (4) An application for injection must include:(4)a full description of the particular operation for which approval is requested; Enhanced recovery injection well 1D-142 will be used for the introduction of additional fluids into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 1D-105A and 1C-135 and planned producer 1D-146. As of December 31, 2013, there were 102 active wells in the West Sak Pool —49 producers, 50 water injectors, and 3 water alternating gas injectors (1E-117, 13-122 and 13-170). Produced water from the Kuparuk Central Processing Facilities (CPFs) and treated seawater from the Saltwater Treatment Plant (STP) were used for the West Sak waterflood. 1D-142 will inject produced water and/or treated seawater into the West Sak Pool. 5. Name and Descroption of Affected Pools Requirements of 20 AAC 25.402 (c) (5) An application for injection must include:(5) the names,descriptions,and depths of the pools to be affected; 1D-142 Injection PERMIT.doc Page 2T. of Printed: 18-Sep-14 . ApOtion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 The D Sand interval of the West Sak Formation, within the Kuparuk Unit, will be affected by the 1D-142 injection well. The West Sak Pool is defined by Rule 2 of Conservation Order No. 406 as the strata that are common to, and correlated with, the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. 6. Name and Description of Affected Formations Requirements of 20 AAC 25.402 (c) (6) An application for injection must include:(6) the name,description,depth,and thickness of the formation into which fluids are to be injected,and appropriate geological data on the injection zone and confining zone,including/ithologic descriptions and geologic names; The West Sak Formation is overlain by a 100-140 thick mudstone and clay formation (Ugnu A). The West Sak Pool is defined by Rule 2 of Conservation Order No. 406 as the strata that are common to, and correlated with, the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnue sequence, and no injection or fraction propagation below the West Sak is anticipated. 7. Logs of Off-Set Injection Wells Requirements of 20 AAC 25.402 (c) (7) An application for injection must include:(7) logs of the injection wells if not already on file with the commission; All injection wells previously drilled will have the logs on file with the commission. 8. Casing Design and Mechanical Integrity Requirements of 20 AAC 25.402 (c) (8) An application for injection must include:(8) a description of the proposed method for demonstrating mechanical integrity of the casing and tubing under 20 AAC 25.412 and for demonstrating that no fluids will move behind casing beyond the approved injection zone,and a description of In order to ensure that no fluids will move behind the casing and beyond the approved injection zone the intermediate casing will be set into the West Sak D and cemented. To demonstrate the integrity of the cement job a sonic cement bond log has been run in order to prove the top of cement is covering all the required zones. To demonstrate the mechanical integrity of the intermediate casing and tubing strings, both strings will be pressured tested. The intermediate casing will be pressure tested to 3000 psi for 30 minutes and the tubing will be pressure tested to 3500 psi for 30 minutes. Also pressure test tubing x intermediate casing annulus to 1000 psi for 30 minutes. (A) the casing of the injection wells if the wells are existing;or N/A as 1D-142 is a new well. (B) the proposed casing program,if the injection wells are new; Casing and cementing program for the new 1D-142 well. 1D-142 Injection PERMIT doc µ /t Page 3 of 7 /[�, Printed: 18-Sep-14 • ApOon for Permit to Inject,Well 1 D-142 Revision No.0 Saved: 18-Sep-14 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H40 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 10.75 13.5 45.5 L-80 Hydril 563 2667 28/ 28 2667/ 2350 1270 sx 11 ppg DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 3900' 7.625 9.875 29.7 L-80 Hydril 563 6601 28/ 28 6601 / 3777 MD/2873'TVD Cemented w/ 730 sx 15.8 ppg Class 4.5 6.75 11.6 L-80 Hydril 563 6264 6401 / 3755 12665 / 3769 ICD-no cement ICD 9. Fluid Injection Data Requirements of 20 AAC 25.402(c) (9) An application for injection must include:(9) a statement of the type of fluid to be injected, the fluid's composition, the fluid's source, the estimated maximum amounts to be injected daily,and the fluid's compatibility with the injection zone; Produced water from the Kuparuk Centeral Processing Facilities (CPFs) and treated seawater from the Saltwater Treatment Plant (STP) were used for the West Sak waterflood. 1D-142 will inject produced water and/or treated seawater into the West Sak Pool. Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. The estimate maximum amount to be injected daily is 2000 bbl/day. 10.Injection Pressure Requirements of 20 AAC 25.402 (c) (10) An application for injection must include:(10) the estimated average and maximum injection pressure; West Sak Water Injection: Estimated Bottomhole Pressure: 2590 psi (average) and 2960 psi (maximum) Estimated Wellhead Pressure: 980 psi (average) and 1350 psi (maximum) (based on a well depth of 3700'TVDSS, Average injection gradient is 0.7 psi/ft and maximum injection gradient is 0.8 psi/ft) 11.Reservoir Containment Requirements of 20 AAC 25.402 (c) (11) An application for injection must include:(11) evidence to support a commission finding that each proposed injection well will not initiate or propagate fractures through the confining zones that might enable the injection fluid or formation fluid to enter freshwater strata; 1D-142 Injection PERMIT.doc ORIGINALPage4of7 Printed: 18-Sep-14 A.tion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 The estimated maximum injection rates for the 1D-142 injection well will not initiate or propagate fractures through the confining strata and, therefore, will not allow injection or formation fluid to enter any freshwater strata. There are no indications of injection out of zone for the current water injectors at West Sak. Existing water injection operations in the West Sak Oil Pool have been at or above formation parting pressure to improve oil recovery of oil. In no instance have such injection pressures breached the integrity of the confining zone. The West Sak Formation is overlain by a 100-140 thick mudstone and clay formation (Ugnu). This confining sequence tends to behave as a plastic medium and can be expected to contain significantly higher pressures than the West Sak formation sandstones. Extensive fracture testing confirmed that even at the bottom hole pressure significantly above the initial parting pressure, the fluids continued to be confined by a relative thin (' 15-20 ft) shale/mudstone interval, provided that an adequate casing cement bond is present. All injectors that are currently online have had a cement bond log to confirm adequate cement isolation between the West Sak formation and the above strata prior to commencing water injection service. Fracture stimulation data from the West Sak Formation indicate a fracture gradient between 0.6 and 0.7 psi/ft under initial conditions. Proppant injection pressures as high as 7,000 psi (about 2.0 psi/ft injection gradient) showed to fracture growth across any confining shale zones. In addition, long-term water injection above 0.9 psi/ft in the West Sak sands tend to part the formation horizontally, rather than fracture vertically, thus keeping all injection fluids within the intended interval. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnu sequence, and no injection or fraction propagation below the West Sak is anticipated. 12.Formation Water Analysis Requirements of 20 AAC 25.402(c) (12) An application for injection must include:(12) a standard laboratory water analysis, or the results of another method acceptable to the commission, to determine the quality of the water within the formation into which fluid injection is proposed; Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. The West Sak Oil Pool connate water composition is provided below. West Sak Oil Pool Connate Water Composition Kuparuk Lab Analytical Report Date: June 4th, 1998 DS 1D Water Sample (#AA43724) Component Concentration (ppm) Chloride 1290 Fluoride <10 Iodide 4.8 1D-142 Injection PERMIT.doc Page 5 of 7 OR I G I A A j Printed: 18-Sep-14 • Ap ion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 Sulfate 18 Calcium 9.8 Iron <1.0 Magnesium 19 Sodium 3480 Barium 3 Strontium 1.4 Silicon 8 Potassium 62 Aluminum 0.3 Chromium <.1 Manganese <.1 Lithium 1 Boron 15 Phosphorus 1 PH 7.7 Bicarbonate 6538 13.Freshwater Exemptions Requirements of 20 AAC 25.402 (c) (13) An application for injection must include:(13) a reference to any applicable freshwater exemption issued under 20 AAC 25.440; All aquifers or portions of aquifers lying below and within one-quarter mile of the Kuparuk River Unit are exempted aquifers. (ref. 40 CFR 147.1092(b)(3) and 20 ACC 25.440(c).) 14.Increase in Hydrocarbon Recovery Requirements of 20 AAC 25.402 (c) (14) An application for injection must include:(14) the expected incremental increase in ultimate hydrocarbon recovery;and The 1D-142 WRWAG pattern is expected to yield oil recovery of 18% to 26% OOIP in the West Sak Oil Pool. This includes approximately 15% to 20% OOIP recovery due to waterflooding and 3% to 6% OOIP of incremental VRWAG benefits over waterflood. 1D-142 Injection PERMIT.doc Page 6 of 7 0 R I G I N A L Printed: 18-Sep-14 • Apletion for Permit to Inject,Well 1D-142 Revision No.0 Saved: 18-Sep-14 15.Offset Wells Mechanical Conditions Requirements of 20 AAC 25.402 (c) (15) An application for injection must include:(15) a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well. 1C-135 is permitted as a West Sak Producer. 1C-190 is permitted as a West Sak injector., 1C-184 is permitted as a West Sak producer. 1J-122 is permitted as a West Sak WAG injector. 1D-141 is permitted as a West Sak producer. 1D-32 - 9 5/8"surface casing set at 9007' MD (4577'ND). 7"casing set at 13324' MD (6331'TVD) and 38 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 1D-34 - 9 5/8"surface casing set at 9463' MD (4315'TVD). 7"casing set at 15164' MD (6438'TVD) and 36 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 1D-28 — 10 3/4"surface casing set at 6591' MD (4,421'ND). 7 5/8"casing set at 11075' MD (6585'ND) and 52 bbl of class G cement pumped (1034'annular height). Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 1D-41 - 10 3/4"surface casing set at 9655' MD (4504'TVD). 7 5/8"casing set at 15695' MD (6611'ND) and 65 bbl of class G cement pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 1D-12 —9 5/8"surface casing set at 5641' MD (4328'TVD). 7"casing set at 8696' MD (6323'ND). 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WA L /�� ' ( 0 • Ferguson, Victoria L (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 01, 2014 5:25 PM To: Loepp,Victoria L (DOA) Cc: Hallford, Kelsey Subject: RE: KRU 1D-142(PTD 214-149)West Sak Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, answers to questions are below: 1. 1D-142 did not fail anti-collision with 1D-12, it just failed with 1D-117. Did you have a different question regarding 1D-12. 1D-117 went through the Tolerable Collision Risk(TCR) process which is a ConocoPhillips Alaska process. This process accesses the risk of what would happen if we collided with the well that is a concern, and if the risk is deemed acceptable (based on NPV and environmental and safety risks)then the well can be drilled. 1D-117 is an active injector, but ConocoPhillips is going to shut this well in prior to starting drilling 1D-142 and it will stay shut in for the entire length of drilling the well. Since the well will be shut in there will be no risk of a well control issue because if 1D-117 is hit we would be colliding with the well with kill weight fluid in the hole. 2. 1 • • 470.17 clC 0.s- 1-13 z ; 1; 75' Diverter Line lir to: ' !co• 140 2 1e4. P03 no- ZL ,-18:: I. m. 141 5 1,11 '�- 1• 13 a t it,i 113 4 23 2. t 114 it6 IID i, -II it b is Ile ' 1D-145 too; 11. 1D-112 . 12 1D-14 3t '�; 12s a 13 1D-146 424: S 126 a a Mr 42i ,28 $3 e a 2e 4P4 !2i 890 / tat !30 O.!2 3 4, Jf ,31 e2 CS 3a U�Q'C? 134 191 �7 t{dd� 13.3 .101 25 2i7 A [ z, .may 91 42 1 IA t57 156 in 1071.--*-46'414' F'l 3. I did not include the mechanical conditions for the West Sak wells as if it is a West Sak well then we will have cement over the west Sak interval, meaning injection from 1D-142 (West Sak Injector)will not get into the annulus of the other West Sak wells as they have cement across that zone. For all the 1D wells that I looked at the cement jobs went as planned. I will have to pull the well file again to get the cement info. 1D-12 had it surface casing set through the west Sak, and then the production section was drilled and cemented. What information are you looking for? Surface? Please let me know about 1D-12 if you want me to re-pull file and what information you are after. 1 2 • Also,just let me know if there any other questions or concerns. You can give me a shout to discuss also. 907-263-3741 is my desk Thanks David Lee From: Loepp, Victoria L (DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Wednesday, October 01, 2014 3:02 PM To: Lee, David L Subject: [EXTERNAL]KRU 1D-142(PTD 214-149) West Sak David, 1. Anti-collision analysis: 1D-117, 1D-12 laterals are major risk failures that are now pass-minor. Please explain this process. What steps will be taken with these wells to mitigate risk of collision during drilling 1D-142? 2. Please provide a pad schematic showing the rig at the well location and the route of the diverter line including approximate lengths. 3. Area of Review: Why aren't the mechanical conditions of the West Sak wells reviewed? For the cement jobs on the 1D wells, did the cement jobs go as planned? Plugs bumped,floats held? For Well 1D-12, is there cement data available? Thanx in advance for addressing these questions, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferq usonna.a laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 3 i i Bettis, Patricia K (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Friday, September 26, 2014 6:34 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1D-142: Permit to Drill Application Morning Patricia, ConocoPhillips will not be pre producing 1D-142 (because we have ICD's in the lower completion). If you need anything else please let me know. David From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, September 24, 2014 4:51 PM To: Lee, David L Subject: [EXTERNAL]KRU 1D-142: Permit to Drill Application David, Will ConocoPhillips pre-produce KRU 1D-142 and if so,what will be the duration. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) -1 )�( From: Bettis, Patricia K (DOA) Sent: Wednesday, September 24, 2014 4:51 PM To: Lee, David L (David.L.Lee@conocophillips.com) Subject: KRU 1D-142: Permit to Drill Application David, Will ConocoPhillips pre-produce KRU 1D-142 and if so,what will be the duration. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 F Bettis, Patricia K (DOA) Pm l y -M c From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Thursday, September 18, 2014 2:20 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1D-145: Permit to Drill Application Morning Patricia, here are the logging program for each of the 1D Wells: D142� u a ce—Gamma, Resistivity, Density, Neutron Intermediate—Gamma, Resistivity Lateral—Gamma, Resistivity, sonic (for cement top evaluation) and periscope 1D-143 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, density, neutron Lateral x 4—Gamma, Resistivity and periscope 1D-146 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity Lateral x 4—Gamma, Resistivity and periscope 1D-145 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, Lateral x 4—Gamma, Resistivity and periscope Please let me know if you need anything else. Thanks David From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, September 18, 2014 9:12 AM To: Lee, David L Subject: [EXTERNAL]KRU 1D-145: Permit to Drill Application Good morning David, Please submit the logging program for each section of the proposed well. Thank you, Patricia 1 ,. • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: <RL, Ii — /'4 PTD: 21L/ - /y7 Development / Service _ Exploratory Stratigraphic Test _Non-Conventional FIELD: gy6„I'ck.` , I 1/44,4- POOL: K y6..JW( �1V f W F,Si SA'K 01) Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging in also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 • • -;❑ TO0 a) o- U N N Q Uj 0 a) _ C a) C (0 c Q 0 a d 1E W. o a) U C. c o 6 H O U c' VO fY L L. N a "O, w. : 0) w U) -0 '@ ' _ `� 0) 0) d (n p 0 a w' O c 3 c 0 . -a'o cc of o 0 3 m 0 a E O > ° cci O. C 0 c0 d C C) 3 U) Lo a0 c C. M. r. • o a > D 3, a) 0 TO N N' N r a), a O, M i s ° a N o 3. — CO a) c o a a) 0 N a); D a) - m' n w. 3 v L a g O E o`o y-o a Q a o Y o- E, 2, m co N 3 °0 0_ 2 Q co m o o. 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