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215-070
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-02 KUPARUK RIV UNIT 2S-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-02 50-103-20710-00-00 215-070-0 W SPT 6229 2150700 1557 2537 2538 2538 2538 270 380 365 352 4YRTST P Brian Bixby 7/2/2022 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 2S-02 Inspection Date: Tubing OA Packer Depth 540 1980 1940 1930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704082435 BBL Pumped:2.6 BBL Returned:2.6 Friday, July 22, 2022 Page 1 of 1 • • 2 1 - c)-1 ConocoPhillips Alaska NOV 10 20 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 .. E November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED MAR 2 12017, Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of foirn 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • 9 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 2S-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 STATE OF ALASKA ALI,OIL AND GAS CONSERVATION COMItION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG I✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J' Exploratory r 215-070-0 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-103-20710-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025603; ADL025604 KRU 2S-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 18410 feet Plugs(measured) None true vertical 6330 feet Junk(measured) None Effective Depth measured 18383 feet Packer(measured) 11844 true vertical 6333 feet (true vertical) 6238 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 109' 109' SURFACE 3616' 10 3/4 3644' 2653' INTERMEDIATE 11955' 7 5/8 11981' 6274' SLOTTED LINER 6567' 4 1/2 18383' 6331' RECEWED Perforation depth: Measured depth: 12446-14916; 15193-16124; 16284-17382; 17578-18339 JUL 14 2016 True Vertical Depth: 6361-6337; 6340-6368;6379-6360;6364-6334 O G GC Tubing(size,grade,MD,and ND) 3 1/2 ,L-80, 11873 MD, 6238 TVD Packers&SSSV(type,MD,and TVD) SSSV=None SEAL ASSY=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY @ 11844 MD and 6238 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: N E�� � Z01 SCA 13. 7 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 441 256 1 979 240 Subsequent to operation 0 0 4091 600 1819 14.Attachments(required per 20 AAC 25.070,25.071,&25.293) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service p Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG p GINJ r SUSP f SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-317 Contact Darrell Humphrey/Bob Christensen Email: n1139(c�conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date7. , Z` 1 VTt Al ,.' q!z /lc. RBDMS LL JUL 1 4 2016 Form 10-404 Revised 5/2015 Submit Original Only - • 2S-02 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/24/16 Open Well- return to service- PWI KUP PROD • 2S-02 ConocoPhillips ilf Well AttributesMax Angle&MD TD Alaska Inc Wellbore API/UNI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) np1: 501032071000 KUPARUK RIVER UNIT PROD 93.50 18,322.24 18,410.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-02,687/2016324.51 PM SSSV:NIPPLE 100 10/20/2015 Last WO: 27.50 7/20/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,..,.._.,,,,_.._Last Tag: SLM 12,520.0 6113/2016 Rev Reason:H2S,GLV C/O,TAG pproven 6/17/2016 HANGER;25.0 + Casing Strings -------••-•••--••-•• -••----••••••• •••••••••••--•• '" -••- ••••••• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread r. CONDUCTOR 16 15.250 29.0 109.0 109.0 62.50 H-40 , Casing Description OD(in) ID(in) Top(000) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 28.2 3,644.0 2,653.4 45.50 L-80 HYD 563 II 4 it Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread . 11 INTERMEDIATE 7 5/8 6.875 26.2 11,981.2 6,274.2 29.70 L80 Hyd 563 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread SLOTTED LINER 41/2 3.958 11,815.6 18,382.8 6,331.3 11.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top!WC) Item Des Com (in) 11,815.6 6,229.2 72.50 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 CONDUCTOR;29.0-109.0 - 11,835.5 6,235.1 72.96 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.767 11,838.3 6,235.9 73.03 HANGER DG FLEX-LOCK LINER HANGER 4.870 11,848.1 6,238.8 73.26 LOCATOR LOCATOR SUB 4.410 11,859.5 6,242.0 73.49 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;513.8 a 12431.7 6,359.4 82.47 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 PACKER PACKER II i Tubing Strings i Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(n..Set Depth(TOD)(...Wt(lb/ft) Grade Top Connection I '1 TUBING 1 31/21 2.9921 25.01 11,872.51 6,245.71 9.301L-80 IEUE-M Completion Details Nominal ID SURFACE;28.2-3.644.0 IL Top(MB) Top(ND)(ftKB) Top!noir) Item Des Corn (in) 25.0 25.0 0.00 HANGER CAMERON TUBING HANGER 3.900 70.2 70.2 0.18 XO Reducing XO-31/2"EUE 8 RD(p)x41/2"IBT(B)5.22 OD Ser 3.000 GAS LIFT;6,118.0 I (#10511947 513.8 513.1 6.19 NIPPLE CAMCO DS NIPPLE 2.875 11,755.8 6,210.5 71.13 SLIDING BAKER CMU SLIDING SLEEVE W/DS NIPPLE- 2.810 SLEEVE CLOSED h11,780.2 6,218.3 71.69 NIPPLE CAMCO D NIPPLE 2.750 11,843.7 6,237.5 73.15 LOCATOR LOCATOR SUB 3.000 11,844.2 6,237.6 73.16 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;11,726.5 I: Perforations&Slots Shot SLIDING SLEEVE;11,755.8 Dens I Top(ND) Btm(TVD) )shots/f Top(ftKB) Bter(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 12,446.4 14,916.3 6,361.3 6,337.4 7/16/2015 SLOTS Slotted Liner NIPPLE;11,780.2 15,193.1 16,124.3 6,339.7 6,368.4 7/16/2015 SLOTS Slotted Liner 16,284.0 17,382.0 6,378.6 6,359.7 7/16/2015 SLOTS Slotted Liner I 17,578.2 18,339.1 6,364.2 6,333.9 7/16/2015 SLOTS Slotted Liner II Mandrel Inserts st a6 Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD)in) Sery Type Type (in) (psi) Run Date Com 6,118.0 3,495.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 7/15/2015 2 11,726.5 6,200.9 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/16/2016 Notes:General&Safety End Date Annotation LOCATOR;11,843.7 �, .1 NOTE. SEAL ASSY;11,844.1 I 1 0 S El 1 INTERMEDIATE;26.2-11,981.2 III e SLOTS;12,446.4-14,916.3 SLOTS;15,193.1-16,124.3 SLOTS;16,284.0-17.382.0- SLOTS;17,578.2-18,339.1-- SLOTTED LINER;11.815.6- 18,382.8 • ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,July 13,2016 P.I.Supervisor Zr t' 1(3/16 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2S-02 FROM: Brian Bixby KUPARUK RIV UNIT 2S-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-02 API Well Number 50-103-20710-00-00 Inspector Name: Brian Bixby Permit Number: 215-070-0 Inspection Date: 7/10/2016 Insp Num: mitBDBl60711140641 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 25-02 Type Inj W 'TVD 6228 -1 Tubing I 1805 1800 _ ! 1800 - 1800 - 1800 PTD 2150700 ' Type Test SPT(Test psi 1557 - IA 720 3300 _ 3250 3240- 3240- Interval INITAL P/F P ,/ OA 370 500 _ 485 - 465 465 Notes: QED NOV 2 2 2016 Wednesday,July 13,2016 Page 1 of 1 • 8,OF zit, . g \\ 1yy, s THE STATE Alaska Oil and Gas tv ig*," 1 p fA jSKA Conservation Commission 333 West Seventh Avenue x ' GOVERNOR BILL WALKER g�� Anchora e, Alaska 99501-3572 Main: 907.279.1433 OFA :"gybe' Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen 1 ;1 r� �, NSK Production Engineering Specialistscow Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-02 Permit to Drill Number: 215-070 Sundry Number: 316-317 Dear Ms. Christensen: 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, a47 '4444 Cathy P. Foerster Chair DATED this 1 ay of June, 2016. RBDMS JUN 1 3 2016 • • FlECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,JUN 0 7 2016 APPLICATION FOR SUNDRY APPROVALS D—z-s 6/dal (, 20 AAC 25.280 O 1.Type of Request: Abandon r Rug Irforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG P- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development 17. 215-070-0 3.Address: Stratigraphic r Service r 6.API Number: P. 0. Box 100360,Anchorage, Alaska 99510 50-103-20710-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? AI lc Will planned perforations require spacing exception? Yes r No ,� -10 KRU 2S-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025603;ADL025604 , Kuparuk River Field/Kuparuk River 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): 18410 6330 18383' 6333' 2901 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 109' 109' SURFACE 3616' 10 3/4 3644' 2653' INTERMEDIATE 11955' 7 5/8 11981' 6274' SLOTTED LINER 6567' 4 1/2 18383' 6331' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12446-14916; 15193-16124; 16284- 17382; 17578-18339 6361-6337;6340-6368;6379-6360;6364-6334 3 1/2 L-80 11873 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=Nipple ‘ MD=514 TVD=513 PKR=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY t MD=11844 TVD=6238 12.Attachments: Proposal Summary WellBore Schematic 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Ft 14.Estimated Date for 15. Well Status after proposed work: 06/10/16 OIL r WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r + GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139Aconocophillips.com Title: NSK Production Engineering Specialist Signatureiyztee..t_)4)) Date: (Q/s,/j f Commission Use Only (c„ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \fie.— `-1 Rug Integrity r BOP Test chanical Integrity Test r Location Clearance r Other: RBDMS L'-- JUN 1 3 20'6 Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No Subsequent Form Required: /0 — 4 U APPROVED BY Approved by: COMMISSIONER44,4%...._ f(0.01/— Submit COMMISSION Date: .._/0—,/,‘ Vr7-76//o//b Cllr� ti is fa/4 ( 01/— Submit Form and Form 10-403 Revised 11/2015 Gala' i ti is for 12 months from the date of approval. Attachments in Duplicate • • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 Con ocoPh i I I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 June 4,2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 JUN 201 Anchorage, AK 99501 A OGCC Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 2S-02 from Oil Production to Water Alternating Gas Injection service. / Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-02 (PTD# 215-0700). If you have any questions regarding this matter,please contact myself or Darrell Humphrey at 659-7535. Sincerely, ? )611,t4Z1 4111I• Robert D. Christensen Attachments Sundry application AOR Detail Area Map Well schematic • 2S-02 • • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2S-02 (PTD# 215-070) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 2S-02 was completed as an injector on 7/20/15 to provide enhanced recovery injection_i_ntt_o the reservoir to increase the ultimate recovery of oil. This well will support existing offset producers 2S-01, 03, and 2S:05 which is currently being drilled. The top of the Kuparuk C4 sand was found at 12242' and/6334'tvd The top of the Kuparuk A5 sand was found at 12271' and/6336' tvd The top of the Kuparuk A4 sand was found at 12416' and/6356' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that there are no production/injection wells located within a 1/4 mile radius of the 2S- 02 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-02 is good and is classified as a"Horizontal - Dual Casing"well. The injection tubing/casing annulus is isolated via a BAKER HRD-E ZXP Liner Top Packer I ocated at 11816' and (6229' tvd). A State-witnessed MIT-IA will be performed once well 2S-02 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 16" Conductor was cemented with 450 sx AS I. The 10-3/4" Surface casing was cemented with 1513 sx Class"G"followed by 206 sx Class"G". The 7-5/8" Intermediate casing was cemented with 501 sx Class"G"followed by 161 sx Class "G". • 0 0 ` P. } ( 3( r § \ ){! 7$ (! / _ , }(a H} / \} \ \ \/ƒ/{ )))}j \ \ I w q E! 9 _ 2 : : : � 0 ƒ8 j / / « a w \re « ` { {{ gi// \/ \ :! 0 \ }/ }\ /{ U ) d t § § § § § 3 \ / E.3 F, res \ [ / / / ft ) 8 m§\ . • • 31May16 ConocoPhillips 2S-02 Alaska, Inc. N 10-403 Sundry nn 0 0.15 0.3 0.45 0.6 N Miles ADL025590 ADLuzuooy 1 2S-01 t r 2S-05 \ , '*L025604 2S-03 ADL025603 2S-02 Trajectory ADL029607 --2S-02 Open Interval 01/4 Mi. 2S-02 Open Interval Radius — Existing Well Currently Being Drilled Well Well Pad -- Kuparuk PA LJ CPAI Lease ti . KUP PROD 2S-02 ConocoPhillips 01 Well Attributes Max Angle&MD TD P Alaska,Inc. Wellbore API/DWI Field Name Wellbore Status lIncl(7 MD(ftKB) Act Btm(ftKB) ,_ gYtl1g 501032071000 KUPARUK RIVER UNIT PROD 93.50 18,322.24 18,410.0 onocos-.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 28-02,11/17/20155:18:32 PM SSSV:NIPPLE Last WO. 27.50 7/20/2015 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..,,,,...-.............__•__,__-.,,_.-..,.-,.,__..,,,..-,..-_-,._._,.-_,..,..--,•,,,,,,,-,,.,,,,,,,,,Last Tag: SLM 12,200.0 9/10/2015 Rev Reason.GLV C/O pproven 11/17/2015 HANGER;25.0 Casing Strings .......................................................... ......... -....._Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread CONDUCTOR 16 15.250 29.0 109.0 109.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.2 3,644.0 2,653.4 45.50 L-80 HYD 563 ----•^^^^----- IC-"'•Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread F= INTERMEDIATE 7 5/8 6.875 26.2 11,981.2 6,274.2 29.70 L80 Hyd 563 111 Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SLOTTED LINER 41/2 3.958 11,815.6 18,382.8 6,331.3 11.60 L-80 IBTM Liner Details Nominal ID Top(ft)(B) lop(WD)(ftKB) Top Incl C) Item Des Com (in) 111 11,815.6 6,229.2 72.50 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 11,835.5 6,235.1 72.96 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.767 11,838.3 6,235.9 73.03 HANGER DG FLEX-LOCK LINER HANGER 4.870 „pp/-coNDucioR;29.0-to9.0 - 11,848.1 6,238.8 73.26 LOCATOR LOCATOR SUB 4.410 11,859.5 6,242.0 73.49 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;513.8 ii 12,431.7 6,359.4 82.47 SWELL PACKER FSC-124 WATER ACTIVATED TAM SWELL PACKER 3.958 III Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2992 25.0 11,872.5 6,245.7 9.30 L-80 EUE-M Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;28.2-3,644.0-A 25.0 25.0 0.00 HANGER CAMERON TUBING HANGER 3.900 70.2 70.2 0.18 XO Reducing XO-31/2"EUE 8 RD(P)x41/2"IBT(B)5.220D Ser 3.000 CD#10511947 GAS LIFT;6,118.0 ,11 513.8 513.1 6.19 NIPPLE CAMCO DS NIPPLE 2.875 11,755.8 6,210.5 71.13 SLIDING BAKER CMU SLIDING SLEEVE WI DS NIPPLE- 2.810 SLEEVE CLOSED r 11,780.2 6,218.3 71.69 NIPPLE CAMCO D NIPPLE 2.750 3.000 L 11,843.7 6,237.5 73.15 LOCATOR LOCATOR SUB 11,844.2 6,237.6 73.16 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;11,720.5 IF Perforations&Slots Shot Dena SLIDING SLEEVE;11,755.8 Top(WD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,446.4 14,916.3 6,361.3 6,337.4 7/16/2015 SLOTS Slotted Liner NIPPLE;11,780.2 /p. 15,193.1 16,124.3 6,339.7 6,368.4 7/16/2015 SLOTS Slotted Liner la 16,284.0 17,382.0 6,378.6 6,359.7 7/16/2015 SLOTS Slotted Liner 17,578.2 18,339.1 6,364.2 6,333.9 7/16/2015 SLOTS Slotted Liner Mandrel Inserts St ad on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 6,118.0 3,495.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 7/15/2015 2 11,726.5 6,200.9 CAMCO SO2- 11/2 GAS LIFT OV RK 0.313 0.0 11/12/2015 30R I Notes:General&Safety End Date Annotation LOCATOR,11,843.7 ( NOTE ►=ISEAL ASSY;11,844.1 -Mi MI 1 M 1 INTERMEDIATE;26.2-11,981.2 111 SLOTS;12,446.4-14,916.3- '- SLOTS;15,193.1-16,124.3 SLOTS;16,284.0-17,382.0 SLOTS;17,578.2-18,339.1- SLOTTED LINER;11,815.6- t 18,382.8 • Kelt z S-- OZ z45-0,700 Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Saturday, May 07, 2016 4:58 PM To: Regg, James B (DOA); Bixby, Brian D (DOA); Brooks, Phoebe L (DOA) Cc: CPF2 DS Lead Techs NSK; NSK Fieldwide Operations Supt; CPF2 Ops Supv; CPF1&2 Ops Supt Subject: 2G-11A, 2S AOGCC Deficiencies Corrected Attachments: 2G-11A -2S AOGCC deficiency response 04-22-16 .pdf; 2G-11A - 2S AOGCC sign deficiency completed 05-07-16.pdf Jim, Attached you will find the complete deficiency report for the missing/incorrect wellhouse signage on KRU 2G-11A& KRU DS2S. 7v1/4)eV.�1.0 2S-oz, -a3 / - o4-, -67 , -OS - o Bob Christensen/ Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. S�P 2 241 Kuparuk Office: 907.659.7535 SCORED Kuparuk Pager: 659.7000;#924 CPAI Internal Mail: NSK-69 This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. From: NSK Prod Engr Specialist Sent: Saturday, April 23, 2016 12:41 PM To: 'Regg, James B (DOA)' (jim.regg@alaska.gov) <iim.regg@alaska.gov>; 'Bixby, Brian D (DOA)' <brian.bixby@alaska.gov> Cc: CPF2 DS Lead Techs NSK<n1126@conocophillips.com>; CPF2 Ops Supv<n2064@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; NSK Fieldwide Operations Supt<n2072@conocophillips.com> Subject: 2G-11A, 2S AOGCC Deficiency Report response Jim - Enclosed is ConocoPhillips response to deficiencies noted by AOGCC inspector Brian Bixby on 4/18/16. Signs have been ordered for both 2G-11A and 2S pad.They will be installed as soon as they arrive and photos will be taken and submitted then. Regards, Darrell Humphrey/ Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) 1 1 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 2.G-wand 2S-Pad Date: 4/18/2016 — k PTD: Operator: Conoco Phillips Alaska Type Inspection: SVS Operator Rep: Darrell Humphrey Inspector: Brian Bixby P Position: Production Engineering Specialist 4(7_x,1t‘, Op. Phone: 907-659-7535 Correct by(date): Op. Email: Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected KRU 2G-11A has the wrong PTD number and the wrong well name on the wellhouse sign. 4/22/2016 Please order new sign and replace. •/' installed S2-Pad-None of the wellhouses have the wellsigns installed on them. Please get them 4/22/2016 installed as soon as possible. i Please take pictures of correct action and send back to AOGCC. Pending 1 } NONE ' ` Attachments: i Darrell Humphrey \ °a-,,.: It i,2,.I,aerator Rep Signatures: Brian Bixby AOGCC Inspector *After signing,a copy of this form is to be left with the operator. 11 Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. i Revised 2/2016 ) 1 • ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 2S Date: 04/18/16 AOGCC Inspector: Brian Bixby Instructions: All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered into the 'Action Taken' section below. Note - Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: KRU S2-Pa ci Nc.,r;, of the vvoilhouses have the wellsigns installed on them. Please get them installed as - soon a possible. Action Taken to Correct Problem: The Sim Ops department has placed an order for the new signs. The signs are scheduled to arrive in about a week and will be Date: 04/22/16 Initials: BMS installed as soon as they are received. Date: Initials: Date: Initials: Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod. Engr. Specialist: n1139(a�conocophillips.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops & DOT Pipelines Supt NSK Fieldwide Operations Supt • KIZ-C4Z eZ_ 2I5-07co Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Tuesday, April 19, 2016 7:05 AM 1711 (i ce To: Bixby, Brian D (DOA) Cc: Regg, James B (DOA); NSK Fieldwide Operations Supt Subject: RE: Emailing: 160418 KRU Wellhouse signs Deficiency Report.xlsx Brian, I have received your deficiency report noting the incorrect and lack of signs on 2G-11 and 2S Pad well houses and have already started corrective action on it. A reply will be submitted within 7 days. Thanks K2 tZ5 -C Darrell Humphrey/ Bob Christensen ZS -G3 ConocoPhillips Alaska, Inc. Production Engineering Specialistt< 7.5 -c4 Office (907) 659-7535 NSK-69 1(.I L i5_c 7 Pager(907) 659-7000 (924) Kiat ZS off, Original Message j U,t ZS )o From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent: Tuesday, April 19, 2016 4:34 AM Z 5- To: NSK Prod Engr Specialist <n1139@conocophillips.com> Cc: Regg,James B (DOA) <jim.regg@alaska.gov> Subject: [EXTERNAL)Emailing: 160418 KRU Wellhouse signs Deficiency Report.xlsx Darrell, I was directed to put these on a Deficiency Report. I will stop by and have you sigh a copy if time allows when I'm over there for a job today. But please reply to ALL on this email for confirmation you received it. Thanks, Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. 15- o7-o • • 0(0 / 33 4t SchlumbergerTransmittal#: 28MAR16-SPO4 Drilling & Measurements MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-02 Date Dispatched: 28-Mar-15 Job#: 14AKA0065 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A VISION*Service MicroScope Resistivity x * Previously distributed transmittal I:20AUG15-SP04*** .-t ezeloed LAS Digital Data N/A Contents on CD N/A Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS MicroScope DLIS data only x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(c�conocophillips.com AlaskaPTSPrintCenter(c�slb.com Tom Osterkamp Attn:Stephanie Pacillo 907- •_-4795 Received : ' , /11//b SCANNED MAY 0 2 2016 • • 21 5070 26 130 Seh�urnber �� Transmittal#: 20AUG15-SP04 g AUG 2 1 2uli Drilling&Measurements D41/).1z LOGGED 4,0/—, MWD/LWD Log Product Delivery .10,g 1(1 \- nl.K BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC:Makana Bender Well No: 2S-02 Date Dispatched: 20-Aug-15 Job#: 14AKA0065 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 7 Contents on CD N/A VISION*Service 2"MD x x VISION*Service 2"WD x x VISION*Service 2"TVDSS x x VISION*Service 5"MD x x VISION*Service 5"TVD x x VISION*Service 5"WDSS x x VISION*Service 5'MD MicroScope Resistivity x x 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 c(i).conocophillips.com AlaskaPTSPrintCenter anslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 ir)/) Received By: "5,,,,,,ezt .: .--,2,u'Be— ,,,,,ii t 2 2016 0 i o I O N O 9 _ co ` co O o " , '00 J 0 N 0 N 0 p CO\ c _c M 0 O p a)es 0 N N N N LL w N o N O �I w 9 9 9 0 0 E E E -0 -0 -0 _ o Q a) Q Z 6 CO N N N N a) a) �? 0- 0' 4 " " `, N O0 U ca CL c>y; Lc) Z J J J J J J J J J N 'D Z E E E E -1 O LL O O LL 0 0 LL 0 Z E � Eu) o in c co co co < 0 0 0 0 0 0 0 0 0 O CO E CO Q ?? a) a) cv a) > a) a)J N LL N N N N N N N N N 0 co LL LL LL LL N N N N N N N N N NCL LL G it o ^ N - - - O O O O O O O O O O U J 0 O fn l0 fn fn o7 Cn (n (n (n (n co co (n co (n Q (n.' 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Q = 0 01111 Q e G 1-0 z E U caZ a) • p l M M CO N I m o N 'O .- 3 N N .` p ix Od a w w p 1 c U U a`1 0 I�i O 0¢ a 2 1 o • s s - o o 5561 TRANSMITTAL TO: AOGCC DATE: 11/12/2015 333 W 7TH AVE AIRBILL: N/A Anchorage,AK 99501 ABV#: COPA2015111201 CHARGE CODE#: NA OPERATOR: PAI WELL: 2S-02 SAMPLE TYPE: DRIES NUMBER OF BOXES: 13 boxes SAMPLES SENT: 2S-02 110-18410 SENT BY: Mike McCracken UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ConocoPhillips Alaska 700 G St ATO 380 Anchorage,AK.99510 Attn: Mike McCracken RECEIVED BY: - DATE: 44.,E1lVE [V O V 1 2 .''' AOGCC • S Guhl, Meredith D (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, November 04, 2015 9:21 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-02, PTD 215-070, 10-407 issues Attachments: 2S-02_MudLog_18410ft_MD.PDF Meredith/Patricia, Here are the formation tops recorded from 2S-02. I have attached the mud log for all three hole sections. Schlumberger informed me that they sent over the neutron/density logs with the rest of the logs that were sent to you. If you still do not have a copy of those logs let me know and I will make sure they get re-sent. Again, I apologize for the delay in getting you this data. Please let me know if this covers what you need or if you would like any further information. asing Shoes,Ma ° iota Taps and g ® ,need . < Top/Marker MD actual TVD actual TVDSS 13-1/2"2S-02 Surface Section Base Permafrost 1,424' 1,396' -1,248' Top West Sak D 1,995' 1,889' -1,741' Base West Sak 3,312' 2,550' -2,402' 10 3/4"casing shoe 3,644' 2,653' -2,505' 9-7/8" 2S-02 Intermediate Section 0-80 4,507' 2,941' -2,793' 0-37 9,155' 4,858' -4,710' Top Bermuda 10,609' 5,730' -5,582' Base Bermuda 10,723' 5,787' -5,639' Top HRZ(K-2) 11,295' 6,039' -5,891' U Kalubik (Base HRZ) 11,586' 6,153' -6,005' L Kalubik (K-1) 11,846' 6,239' -6,091' 7 5/8" casing shoe 11,982' 6,275' -6,127' 6-3/4" 2S-02 (A4 lateral updated based on Intermediate Actual Tops) Kup C 12,248' 6,332' -6,184' A5 12,276' 6,337' -6,189' A4 12,421' 6,359' -6,211' Thank you for your patience. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 1 i r From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, October 30, 2015 3:33 PM To: Callahan, Mike S Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: KRU 2S-02, PTD 215-070, 10-407 issues Mike, I haven't heard back from you regarding this email. Can you please follow up regarding the questions below? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Thursday, September 24, 2015 8:15 AM To: Callahan, Mike S Cc: Bettis, Patricia K (DOA) Subject: KRU 2S-02, PTD 215-070, 10-407 issues Mike, During a review of the 10-407 form submitted for KRU 2S-02, PTD 215-070, completed 7/19/2015, it was noted that two of the boxes on the form were not filled out correctly. Box 22: Logs Obtained only lists GR/Res, when the original permit to drill application stated that a mudlog and neutron/density logs would also be obtained. Which logs were obtained in this wellbore? Box 29: Geologic Markers and Formations: Only the top of the Kuparuk C4, Kuparuk A5, and Kuparuk A4 are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the logs obtained and the complete list of formations and markers by October 19, 2015. 2 • If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 • i 215070 26359 Schlumberger Transmittal#: 150CT15-SPO3 Drilling & Measurements DATA LOGGED MWD/LWD LogProduct DeliveryId/2212015 :v1 K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-02 Date Dispatched: 15-Oct-15 Job#: 14AKA0065 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico a(�conocophillips.com AlaskaPTSPrintCenter@slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 1l+ Received By: � / ..• 4/5 • 215070 • 26130 Schlumberger Transmittal#: 20AUG15-SP04 �'UG 2 1 Drilling & Measurements D TA LOGGED i - MWD/LWD Log Product Delivery K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-02 Date Dispatched: 20-Aug-15 Job#: 14AKA0065 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 7 Contents on CD N/A VISION*Service 2'MD x x VISION*Service 2'TVD x x VISION*Service 2'TVDSS x x VISION*Service 5'MD x x VISION*Service 5'TVD x x VISION*Service 5'TVDSS x x VISION*Service 5" MD MicroScope Resistivity x x 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(aconocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: avagegizev - / i d/ • • 21 5070 26138 Recoil ,us 21 poo0 FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-02 Definitive Survey Report 23 July, 2015 NAD 27 0 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 2S-02 Well Position +N/-S 0.00 usft Northing: 5,930,029.92 usft Latitude: 70°13'11.996 N +E/-W 0.00 usft Easting: 481,279.68 usft Longitude: 150°9'3.690 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 6/25/2015 18.71 80.87 57,491 Design 2S-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 11.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.33 104.97 2S-02 Srvy#1 (2S-02) INC+TREND Inclinometer+known azi trend 6/15/2015 9:0 201.82 3,578.11 2S-02 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2015 9:2 3,648.89 3,648.89 2S-02 Srvy#3 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 6/23/2015 9:0. 3,742.01 11,912.22 2S-02 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 9:1. ' 11,989.16 11,989.16 2S-02 Srvy#5 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 7/9/2015 9:53 12,041.60 18,322.24 2S-02 Srvy#6 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/9/2015 9:55 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,029.92 481,279.68 0.00 0.00 UNDEFINED 79.33 0.22 264.90 79.33 -68.17 -0.01 -0.10 5,930,029.91 481,279.58 0.42 -0.03 INC+TREND(1) 104.97 0.18 264.90 104.97 -42.53 -0.02 -0.19 5,930,029.90 481,279.49 0.16 -0.05 INC+TREND(1) 109.00 0.18 264.90 109.00 -38.50 -0.02 -0.20 5,930,029.90 481,279.48 0.10 -0.06 MWD+IFR-AK-CAZ-SC(2) NOT an Actual Survey 16"x20" 201.82 0.28 264.90 201.82 54.32 -0.05 -0.58 5,930,029.87 481,279.10 0.10 -0.16 MWD+IFR-AK-CAZ-SC(2) 293.09 1.07 157.53 293.08 145.58 -0.86 -0.47 5,930,029.06 481,279.21 1.30 -0.93 MWD+IFR-AK-CAZ-SC(2) 384.26 3.66 146.85 384.17 236.67 -4.08 1.45 5,930,025.83 481,281.11 2.87 -3.73 MWD+IFR-AK-CAZ-SC(2) 476.47 6.34 145.93 476.02 328.52 -10.76 5.91 5,930,019.14 481,285.56 2.91 -9.44 MWD+IFR-AK-CAZ-SC(2) 567.55 5.97 145.89 566.57 419.07 -18.85 11.38 5,930,011.04 481,291.01 0.41 -16.33 MWD+IFR-AK-CAZ-SC(2) 7/23/2015 8:05:57AM Page 2 COMPASS 5000.1 Build 74 • 0 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 659.98 7.27 139.59 658.39 510.89 -27.29 17.87 5,930,002.59 481,297.48 1.61 -23.37 MWD+IFR-AK-CAZ-SC(2) 752.38 8.71 141.01 749.89 602.39 -37.18 26.06 5,929,992.68 481,305.64 1.57 -31.52 MWD+IFR-AK-CAZ-SC(2) 845.09 9.73 140.31 841.40 693.90 -48.66 35.48 5,929,981.18 481,315.04 1.11 -41.00 MWD+IFR-AK-CAZ-SC(2) 938.89 10.68 143.21 933.71 786.21 -61.72 45.75 5,929,968.09 481,325.27 1.15 -51.86 MWD+IFR-AK-CAZ-SC(2) 1,031.83 12.50 143.30 1,024.76 877.26 -76.68 56.92 5,929,953.10 481,336.40 1.96 -64.41 MWD+IFR-AK-CAZ-SC(2) 1,127.07 16.06 144.48 1,117.04 969.54 -95.68 70.74 5,929,934.08 481,350.17 3.75 -80.42 MWD+IFR-AK-CAZ-SC(2) 1,218.14 17.24 144.24 1,204.29 1,056.79 -116.88 85.94 5,929,912.84 481,365.32 1.30 -98.33 MWD+IFR-AK-CAZ-SC(2) 1,311.27 22.51 148.58 1,291.85 1,144.35 -143.31 103.31 5,929,886.37 481,382.63 5.87 -120.97 MWD+IFR-AK-CAZ-SC(2) 1,404.33 25.25 148.70 1,376.93 1,229.43 -175.48 122.91 5,929,854.15 481,402.15 2.94 -148.80 MWD+IFR-AK-CAZ-SC(2) 1,496.94 25.18 149.30 1,460.72 1,313.22 -209.30 143.23 5,929,820.29 481,422.38 0.29 -178.12 MWD+IFR-AK-CAZ-SC(2) 1,590.92 26.52 150.42 1,545.29 1,397.79 -244.74 163.80 5,929,784.80 481,442.86 1.52 -208.99 MWD+IFR-AK-CAZ-SC(2) 1,683.02 28.77 149.69 1,626.87 1,479.37 -281.76 185.14 5,929,747.73 481,464.10 2.47 -241.25 MWD+IFR-AK-CAZ-SC(2) 1,776.78 30.32 149.47 1,708.44 1,560.94 -321.62 208.55 5,929,707.81 481,487.41 1.66 -275.92 MWD+IFR-AK-CAZ-SC(2) 1,870.07 32.51 148.39 1,788.05 1,640.55 -363.26 233.65 5,929,666.11 481,512.41 2.42 -312.01 MWD+IFR-AK-CAZ-SC(2) 1,917.29 34.22 149.35 1,827.49 1,679.99 -385.49 247.07 5,929,643.85 481,525.77 3.79 -331.27 MWD+IFR-AK-CAZ-SC(2) 1,963.14 38.74 150.89 1,864.34 1,716.84 -409.13 260.63 5,929,620.18 481,539.27 10.06 -351.88 MWD+IFR-AK-CAZ-SC(2) 2,008.07 40.31 150.65 1,899.00 1,751.50 -434.08 274.60 5,929,595.20 481,553.17 3.51 -373.71 MWD+IFR-AK-CAZ-SC(2) 2,055.84 39.97 150.56 1,935.52 1,788.02 -460.91 289.71 5,929,568.33 481,568.22 0.72 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,150.11 41.79 151.87 2,006.79 1,859.29 -514.99 319.41 5,929,514.19 481,597.78 2.13 -444.58 MWD+IFR-AK-CAZ-SC(2) 2,242.85 46.57 154.41 2,073.29 1,925.79 -572.65 348.54 5,929,456.46 481,626.76 5.50 -495.62 MWD+IFR-AK-CAZ-SC(2) 2,286.63 48.32 156.29 2,102.89 1,955.39 -601.96 361.98 5,929,427.12 481,640.13 5.10 -521.83 MWD+IFR-AK-CAZ-SC(2) 2,335.33 49.78 156.21 2,134.81 1,987.31 -635.63 376.80 5,929,393.42 481,654.86 3.00 -552.05 MWD+IFR-AK-CAZ-SC(2) 2,428.08 53.30 158.80 2,192.50 2,045.00 -702.72 404.54 5,929,326.27 481,682.43 4.38 -612.62 MWD+IFR-AK-CAZ-SC(2) 2,521.26 57.96 160.39 2,245.09 2,097.59 -774.79 431.32 5,929,254.13 481,709.03 5.20 -678.26 MWD+IFR-AK-CAZ-SC(2) 2,569.60 59.50 161.11 2,270.18 2,122.68 -813.80 444.94 5,929,215.10 481,722.55 3.43 -713.95 MWD+IFR-AK-CAZ-SC(2) 2,613.01 61.40 161.94 2,291.59 2,144.09 -849.62 456.90 5,929,179.26 481,734.43 4.68 -746.83 MWD+IFR-AK-CAZ-SC(2) 2,705.53 62.56 161.79 2,335.05 2,187.55 -927.23 482.32 5,929,101.58 481,759.65 1.26 -818.17 MWD+IFR-AK-CAZ-SC(2) 2,798.27 65.76 161.39 2,375.47 2,227.97 -1,006.42 508.68 5,929,022.34 481,785.81 3.47 -890.87 MWD+IFR-AK-CAZ-SC(2) 2,891.22 67.27 161.00 2,412.51 2,265.01 -1,087.11 536.16 5,928,941.59 481,813.09 1.67 -964.84 MWD+IFR-AK-CAZ-SC(2) 2,984.44 69.93 162.04 2,446.52 2,299.02 -1,169.42 563.66 5,928,859.22 481,840.39 3.04 -1,040.39 MWD+IFR-AK-CAZ-SC(2) 3,078.50 71.80 159.42 2,477.35 2,329.85 -1,253.29 593.00 5,928,775.28 481,869.51 3.30 -1,117.12 MWD+IFR-AK-CAZ-SC(2) 3,172.25 70.97 160.32 2,507.28 2,359.78 -1,336.71 623.58 5,928,691.80 481,899.88 1.27 -1,193.17 MWD+IFR-AK-CAZ-SC(2) 3,264.83 72.52 159.74 2,536.28 2,388.78 -1,419.34 653.60 5,928,609.10 481,929.70 1.78 -1,268.55 MWD+IFR-AK-CAZ-SC(2) 3,358.77 72.44 159.49 2,564.56 2,417.06 -1,503.31 684.81 5,928,525.06 481,960.69 0.27 -1,345.02 MWD+IFR-AK-CAZ-SC(2) 3,451.37 72.53 160.02 2,592.43 2,444.93 -1,586.16 715.36 5,928,442.15 481,991.04 0.55 -1,420.52 MWD+IFR-AK-CAZ-SC(2) 3,546.33 71.19 159.61 2,621.99 2,474.49 -1,670.86 746.50 5,928,357.38 482,021.96 1.47 -1,497.72 MWD+IFR-AK-CAZ-SC(2) 3,578.11 71.31 159.61 2,632.21 2,484.71 -1,699.07 756.98 5,928,329.15 482,032.37 0.38 -1,523.41 MWD+IFR-AK-CAZ-SC(2) 3,644.00 71.11 159.61 2,653.43 2,505.93 -1,757.54 778.72 5,928,270.63 482,053.96 0.31 -1,576.66 INC+TREND(3) NOT an Adual Slevey 10 3/4"x 13-1/2 3,648.89 71.09 159.61 2,655.02 2,507.52 -1,761.87 780.33 5,928,266.29 482,055.56 0.31 -1,580.61 INC+TREND(3) 7/23/2015 8:05:57AM Page 3 COMPASS 5000.1 Build 74 4110 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 3,742.01 71.54 159.30 2,684.85 2,537.35 -1,844.47 811.29 5,928,183.62 482,086.31 0.58 -1,655.78 MWD+IFR-AK-CAZ-SC(4) 3,834.63 71.75 158.62 2,714.02 2,566.52 -1,926.52 842.85 5,928,101.51 482,117.66 0.73 -1,730.30 MWD+IFR-AK-CAZ-SC(4) 3,928.68 70.66 158.64 2,744.32 2,596.82 -2,009.43 875.29 5,928,018.52 482,149.90 1.16 -1,805.50 MWD+IFR-AK-CAZ-SC(4) 4,021.82 70.21 157.67 2,775.51 2,628.01 -2,090.89 907.95 5,927,936.99 482,182.35 1.09 -1,879.23 MWD+IFR-AK-CAZ-SC(4) 4,116.49 70.22 157.64 2,807.55 2,660.05 -2,173.28 941.81 5,927,854.52 482,216.00 0.03 -1,953.65 MWD+IFR-AK-CAZ-SC(4) 4,208.85 70.08 157.94 2,838.92 2,691.42 -2,253.71 974.65 5,927,774.02 482,248.64 0.34 -2,026.33 MWD+IFR-AK-CAZ-SC(4) 4,301.47 70.19 158.12 2,870.39 2,722.89 -2,334.49 1,007.24 5,927,693.17 482,281.03 0.22 -2,099.41 MWD+IFR-AK-CAZ-SC(4) 4,395.70 70.15 158.11 2,902.35 2,754.85 -2,416.75 1,040.28 5,927,610.84 482,313.86 0.04 -2,173.85 MWD+IFR-AK-CAZ-SC(4) 4,490.64 67.56 160.37 2,936.60 2,789.10 -2,499.53 1,071.68 5,927,527.99 482,345.05 3.52 -2,249.12 MWD+1FR-AK-CAZ-SC(4) 4,582.81 62.88 164.08 2,975.23 2,827.73 -2,579.16 1,097.26 5,927,448.30 482,370.43 6.25 -2,322.41 MWD+IFR-AK-CAZ-SC(4) 4,630.09 60.60 165.42 2,997.62 2,850.12 -2,619.33 1,108.22 5,927,408.11 482,381.28 5.43 -2,359.75 MW D+I FR-AK-CAZ-SC(4) 4,676.10 58.54 167.88 3,020.92 2,873.42 -2,657.92 1,117.38 5,927,369.50 482,390.36 6.43 -2,395.88 MWD+IFR-AK-CAZ-SC(4) 4,725.53 59.59 166.29 3,046.34 2,898.84 -2,699.25 1,126.86 5,927,328.16 482,399.73 3.48 -2,434.64 MWD+1FR-AK-CAZ-SC(4) 4,772.57 61.65 164.84 3,069.41 2,921.91 -2,738.94 1,137.08 5,927,288.44 482,409.85 5.14 -2,471.65 MWD+IFR-AK-CAZ-SC(4) 4,864.70 65.99 161.23 3,110.06 2,962.56 -2,817.97 1,161.24 5,927,209.36 482,433.82 5.88 -2,544.62 MWD+IFR-AK-CAZ-SC(4) 4,900.29 66.83 160.26 3,124.30 2,976.80 -2,848.76 1,172.00 5,927,178.55 482,444.49 3.44 -2,572.79 MWD+IFR-AK-CAZ-SC(4) 4,958.75 68.93 159.28 3,146.32 2,998.82 -2,899.57 1,190.73 5,927,127.70 482,463.09 3.91 -2,619.09 MWD+IFR-AK-CAZ-SC(4) 5,053.27 71.58 158.24 3,178.25 3,030.75 -2,982.48 1,222.96 5,927,044.72 482,495.12 2.99 -2,694.33 MWD+IFR-AK-CAZ-SC(4) 5,145.24 73.20 158.71 3,206.07 3,058.57 -3,064.02 1,255.12 5,926,963.10 482,527.07 1.83 -2,768.24 MWD+1FR-AK-CAZ-SC(4) 5,239.23 73.24 158.10 3,233.21 3,085.71 -3,147.69 1,288.24 5,926,879.36 482,559.98 0.62 -2,844.05 MWD+IFR-AK-CAZ-SC(4) 5,333.60 72.65 158.08 3,260.88 3,113.38 -3,231.39 1,321.91 5,926,795.58 482,593.44 0.63 -2,919.79 MWD+IFR-AK-CAZ-SC(4) 5,426.03 72.23 157.84 3,288.77 3,141.27 -3,313.08 1,354.97 5,926,713.82 482,626.30 0.52 -2,993.67 MWD+IFR-AK-CAZ-SC(4) 5,518.53 71.93 157.99 3,317.23 3,169.73 -3,394.63 1,388.07 5,926,632.19 482,659.18 0.36 -3,067.41 MWD+IFR-AK-CAZ-SC(4) 5,612.19 72.30 159.66 3,346.00 3,198.50 -3,477.74 1,420.26 5,926,549.01 482,691.17 1.74 -3,142.85 MWD+IFR-AK-CAZ-SC(4) 5,705.92 72.76 160.94 3,374.14 3,226.64 -3,561.92 1,450.40 5,926,464.77 482,721.09 1.39 -3,219.73 MWD+IFR-AK-CAZ-SC(4) 5,797.08 72.74 161.57 3,401.17 3,253.67 -3,644.36 1,478.37 5,926,382.27 482,748.86 0.66 -3,295.31 MWD+IFR-AK-CAZ-SC(4) 5,891.34 72.85 161.49 3,429.05 3,281.55 -3,729.76 1,506.90 5,926,296.80 482,777.17 0.14 -3,373.71 MWD+IFR-AK-CAZ-SC(4) 5,984.46 72.80 161.75 3,456.55 3,309.05 -3,814.19 1,534.95 5,926,212.31 482,805.01 0.27 -3,451.23 MWD+IFR-AK-CAZ-SC(4) 6,079.38 73.01 161.81 3,484.45 3,336.95 -3,900.37 1,563.32 5,926,126.07 482,833.16 0.23 -3,530.41 MW D+I FR-AK-CAZ-SC(4) 6,171.92 73.48 161.79 3,511.13 3,363.63 -3,984.55 1,591.00 5,926,041.84 482,860.63 0.51 -3,607.76 MWD+I FR-AK-CAZ-SC(4) 6,264.70 73.23 163.38 3,537.70 3,390.20 -4,069.36 1,617.60 5,925,956.96 482,887.02 • 1.66 -3,685.94 MWD+IFR-AK-CAZ-SC(4) 6,357.62 72.81 164.24 3,564.84 3,417.34 -4,154.70 1,642.38 5,925,871.57 482,911.59 0.99 -3,764.99 MWD+IFR-AK-CAZ-SC(4) 6,452.00 71.09 165.34 3,594.08 3,446.58 -4,241.29 1,665.93 5,925,784.93 482,934.91 2.13 -3,845.49 MWD+IFR-AK-CAZ-SC(4) 6,546.56 70.82 164.30 3,624.94 3,477.44 -4,327.55 1,689.33 5,925,698.62 482,958.10 1.08 -3,925.71 MWD+IFR-AK-CAZ-SC(4) 6,639.39 71.21 163.09 3,655.14 3,507.64 -4,411.80 1,713.97 5,925,614.32 482,982.54 1.30 -4,003.70 MWD+IFR-AK-CAZ-SC(4) 6,733.34 71.59 162.16 3,685.11 3,537.61 -4,496.78 1,740.56 5,925,529.28 483,008.91 1.02 -4,082.05 MWD+IFR-AK-CAZ-SC(4) 6,825.99 71.56 160.77 3,714.39 3,566.89 -4,580.12 1,768.51 5,925,445.88 483,036.64 1.42 -4,158.52 MW D+I FR-AK-CAZ-SC(4) 6,919.67 71.13 160.08 3,744.36 3,596.86 -4,663.75 1,798.24 5,925,362.19 483,066.17 0.84 -4,234.94 MWD+IFR-AK-CAZ-SC(4) 7,012.84 70.59 159.36 3,774.91 3,627.41 -4,746.31 1,828.75 5,925,279.56 483,096.47 0.93 -4,310.16 MWD+IFR-AK-CAZ-SC(4) 7,106.80 69.91 158.28 3,806.66 3,659.16 -4,828.77 1,860.70 5,925,197.03 483,128.21 1.30 -4,385.01 MWD+IFR-AK-CAZ-SC(4) 7/23/2015 8:05:57AM Page 4 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 7,199.18 69.17 156.41 3,838.95 3,691.45 -4,908.64 1,894.03 5,925,117.09 483,161.34 2.06 -4,457.05 MWD+IFR-AK-CAZ-SC(4) 7,244.76 69.03 154.84 3,855.21 3,707.71 -4,947.42 1,911.60 5,925,078.26 483,178.82 3.23 -4,491.77 MWD+IFR-AK-CAZ-SC(4) 7,291.38 68.76 153.04 3,872.00 3,724.50 -4,986.49 1,930.71 5,925,039.15 483,197.82 3.65 -4,526.48 MWD+IFR-AK-CAZ-SC(4) 7,383.77 68.23 150.58 3,905.87 3,758.37 -5,062.25 1,971.31 5,924,963.30 483,238.23 2.54 -4,593.10 MWD+IFR-AK-CAZ-SC(4) 7,432.28 67.46 150.46 3,924.17 3,776.67 -5,101.36 1,993.42 5,924,924.14 483,260.24 1.60 -4,627.27 MWD+IFR-AK-CAZ-SC(4) 7,476.60 66.79 148.64 3,941.40 3,793.90 -5,136.56 2,014.11 5,924,888.89 483,280.84 4.07 -4,657.88 MWD+IFR-AK-CAZ-SC(4) 7,523.30 65.95 148.04 3,960.12 3,812.62 -5,172.98 2,036.57 5,924,852.42 483,303.21 2.15 -4,689.34 MWD+IFR-AK-CAZ-SC(4) 7,569.49 64.77 146.66 3,979.37 3,831.87 -5,208.33 2,059.21 5,924,817.02 483,325.76 3.73 -4,719.72 MWD+IFR-AK-CAZ-SC(4) 7,661.87 62.68 144.63 4,020.27 3,872.77 -5,276.71 2,105.94 5,924,748.53 483,372.32 3.00 -4,777.93 MWD+IFR-AK-CAZ-SC(4) 7,708.63 61.42 143.44 4,042.19 3,894.69 -5,310.14 2,130.20 5,924,715.04 483,396.49 3.51 -4,806.12 MWD+IFR-AK-CAZ-SC(4) 7,754.64 60.43 143.18 4,064.54 3,917.04 -5,342.39 2,154.22 5,924,682.74 483,420.43 2.21 -4,833.19 MWD+IFR-AK-CAZ-SC(4) 7,847.12 58.64 141.38 4,111.43 3,963.93 -5,405.44 2,202.98 5,924,619.57 483,469.02 2.56 -4,885.78 MWD+IFR-AK-CAZ-SC(4) 7,941.74 57.14 140.05 4,161.73 4,014.23 -5,467.47 2,253.71 5,924,557.42 483,519.60 1.98 -4,936.99 MWD+IFR-AK-CAZ-SC(4) 8,033.51 55.79 138.38 4,212.43 4,064.93 -5,525.39 2,303.67 5,924,499.38 483,569.41 2.11 -4,984.32 MWD+IFR-AK-CAZ-SC(4) 8,126.93 54.30 137.04 4,265.95 4,118.45 -5,582.04 2,355.18 5,924,442.61 483,620.78 1.98 -5,030.09 MWD+IFR-AK-CAZ-SC(4) 8,219.65 54.14 135.68 4,320.16 4,172.66 -5,636.47 2,407.09 5,924,388.06 483,672.54 1.20 -5,073.62 MWD+IFR-AK-CAZ-SC(4) 8,311.71 53.98 133.46 4,374.20 4,226.70 -5,688.77 2,460.18 5,924,335.63 483,725.50 1.96 -5,114.83 MWD+IFR-AK-CAZSC(4) 8,405.19 54.41 131.05 4,428.90 4,281.40 -5,739.74 2,516.29 5,924,284.52 483,781.48 2.14 -5,154.16 MWD+IFR-AK-CAZ-SC(4) 8,498.51 55.01 129.12 4,482.81 4,335.31 -5,788.78 2,574.57 5,924,235.34 483,839.63 1.81 -5,191.18 MWD+IFR-AK-CAZ-SC(4) 8,589.66 55.80 126.01 4,534.57 4,387.07 -5,834.51 2,634.04 5,924,189.47 483,898.98 2.94 -5,224.72 MWD+IFR-AK-CAZ-SC(4) 8,683.20 56.08 124.26 4,586.96 4,439.46 -5,879.11 2,697.41 5,924,144.73 483,962.23 1.58 -5,256.40 MWD+IFR-AK-CAZSC(4) 8,776.27 55.77 122.48 4,639.11 4,491.61 -5,921.51 2,761.79 5,924,102.17 484,026.49 1.62 -5,285.74 MWD+IFR-AK-CAZ-SC(4) 8,871.20 55.23 119.36 4,692.89 4,545.39 -5,961.71 2,828.88 5,924,061.81 484,093.49 2.77 -5,312.40 MWD+IFR-AK-CAZ-SC(4) 8,964.80 55.26 115.26 4,746.26 4,598.76 -5,996.98 2,897.19 5,924,026.37 484,161.70 3.60 -5,333.98 MWD+IFR-AK-CAZ-SC(4) 9,058.92 54.33 110.96 4,800.54 4,653.04 -6,027.16 2,967.89 5,923,996.01 484,232.31 3.86 -5,350.13 MWD+IFR-AK-CAZ-SC(4) 9,151.26 53.08 107.55 4,855.21 4,707.71 -6,051.72 3,038.12 5,923,971.29 484,302.48 3.27 -5,360.83 MWD+IFR-AK-CAZ-SC(4) 9,244.59 51.90 103.86 4,912.05 4,764.55 -6,071.77 3,109.37 5,923,951.06 484,373.67 3.38 -5,366.92 MWD+IFR-AK-CAZ-SC(4) 9,339.64 51.68 101.01 4,970.85 4,823.35 -6,087.85 3,182.29 5,923,934.80 484,446.54 2.37 -5,368.79 MWD+IFR-AK-CAZ-SC(4) 9,433.65 52.18 96.95 5,028.83 4,881.33 -6,099.39 3,255.36 5,923,923.08 484,519.58 3.44 -5,366.17 MWD+IFR-AK-CAZ-SC(4) 9,527.85 52.70 93.07 5,086.27 4,938.77 -6,105.90 3,329.73 5,923,916.39 484,593.92 3.31 -5,358.37 MWD+IFR-AK-CAZ-SC(4) 9,622.63 53.06 89.50 5,143.48 4,995.98 -6,107.59 3,405.26 5,923,914.51 484,669.44 3.03 -5,345.62 MWD+IFR-AK-CAZ-SC(4) 9,714.35 53.01 86.72 5,198.64 5,051.14 -6,105.17 3,478.50 5,923,916.75 484,742.68 2.42 -5,329.27 MWD+IFR-AK-CAZ-SC(4) 9,807.43 52.81 82.83 5,254.79 5,107.29 -6,098.42 3,552.41 5,923,923.32 484,816.60 3.34 -5,308.54 MWD+IFR-AK-CAZ-SC(4) 9,900.31 52.10 79.93 5,311.39 5,163.89 -6,087.39 3,625.21 5,923,934.16 484,889.42 2.59 -5,283.82 MWD+IFR-AK-CAZ-SC(4) 9,993.05 51.94 77.10 5,368.47 5,220.97 -6,072.84 3,696.83 5,923,948.53- 484,961.07 2.41 -5,255.87 MWD+IFR-AK-CAZ-SC(4) 10,084.97 52.38 74.60 5,424.87 5,277.37 -6,055.09 3,767.21 5,923,966.11 485,031.49 2.20 -5,225.02 MWD+IFR-AK-CAZ-SC(4) 10,177.14 52.85 71.05 5,480.84 5,333.34 -6,033.46 3,837.16 5,923,987.56 485,101.48 3.10 -5,190.45 MWD+IFR-AK-CAZ-SC(4) 10,270.67 53.68 68.96 5,536.79 5,389.29 -6,007.83 3,907.59 5,924,013.01 485,171.96 2.00 -5,151.85 MWD+IFR-AK-CAZ-SC(4) 10,363.78 54.22 67.13 5,591.58 5,444.08 -5,979.68 3,977.40 5,924,040.99 485,241.84 1.69 -5,110.90 MWD+IFR-AK-CAZ-SC(4) 10,458.74 55.60 65.62 5,646.17 5,498.67 -5,948.54 4,048.58 5,924,071.95 485,313.09 1.95 -5,066.74 MWD+IFR-AK-CAZ-SC(4) 7/23/2015 8:05:57AM Page 5 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 10,552.81 57.15 64.24 5,698.27 5,550.77 -5,915.34 4,119.52 5,924,104.97 485,384.11 2.05 -5,020.62 MWD+IFR-AK-CAZ-SC(4) 10,645.30 59.32 63.18 5,746.95 5,599.45 -5,880.51 4,190.02 5,924,139.62 485,454.68 2.54 -4,972.97 MWD+IFR-AK-CAZ-SC(4) 10,738.02 60.40 61.18 5,793.51 5,646.01 -5,843.08 4,260.92 5,924,176.87 485,525.67 2.20 -4,922.71 MWD+IFR-AK-CAZ-SC(4) 10,829.90 61.81 59.02 5,837.91 5,690.41 -5,802.98 4,330.64 5,924,216.79 485,595.49 2.57 -4,870.04 MWD+IFR-AK-CAZ-SC(4) 10,922.36 63.14 56.63 5,880.65 5,733.15 -5,759.31 4,400.03 5,924,260.28 485,664.98 2.71 -4,813.93 MWD+IFR-AK-CAZ-SC(4) 11,015.52 64.31 54.14 5,921.89 5,774.39 -5,711.86 4,468.77 5,924,307.56 485,733.82 2.71 -4,754.24 MWD+IFR-AK-CAZ-SC(4) 11,108.81 65.52 51.16 5,961.45 5,813.95 -5,660.60 4,535.91 5,924,358.65 485,801.09 3.17 -4,691.11 MWD+IFR-AK-CAZ-SC(4) 11,200.77 65.87 48.49 5,999.30 5,851.80 -5,606.54 4,599.94 5,924,412.55 485,865.24 2.67 -4,625.82 MWD+IFR-AK-CAZ-SC(4) 11,294.57 66.41 45.46 6,037.25 5,889.75 -5,548.01 4,662.64 5,924,470.91 485,928.08 3.01 -4,556.41 MWD+IFR-AK-CAZ-SC(4) 11,392.75 67.00 43.08 6,076.08 5,928.58 -5,483.44 4,725.58 5,924,535.32 485,991.17 2.31 -4,481.02 MWD+IFR-AK-CAZ-SC(4) 11,480.49 66.94 40.75 6,110.41 5,962.91 -5,423.36 4,779.51 5,924,595.26 486,045.25 2.44 -4,411.75 MWD+IFR-AK-CAZ-SC(4) 11,573.13 67.76 38.17 6,146.09 5,998.59 -5,357.36 4,833.84 5,924,661.12 486,099.73 2.72 -4,336.59 MWD+IFR-AK-CAZ-SC(4) 11,666.15 69.27 36.07 6,180.17 6,032.67 -5,288.34 4,886.06 5,924,730.00 486,152.12 2.65 -4,258.88 MWD+IFR-AK-CAZ-SC(4) 11,760.11 71.22 34.01 6,211.93 6,064.43 -5,215.94 4,936.82 5,924,802.27 486,203.06 2.93 -4,178.12 MWD+IFR-AK-CAZ-SC(4) 11,853.07 73.37 32.41 6,240.20 6,092.70 -5,141.85 4,985.31 5,924,876.23 486,251.73 2.83 -4,096.14 MWD+IFR-AK-CAZ-SC(4) 11,912.22 74.51 31.42 6,256.56 6,109.06 -5,093.61 5,015.36 5,924,924.40 486,281.89 2.51 -4,043.05 MWD+IFR-AK-CAZ-SC(4) 11,981.20 75.85 29.70 6,274.21 6,126.71 -5,036.19 5,049.26 5,924,981.73 486,315.93 3.09 -3,980.21 INC+TREND(5) 7-5/8"x 9-7/8" NOT aoActM Surrey 11,989.16 76.00 29.50 6,276.14 6,128.64 -5,029.47 5,053.07 5,924,988.43 486,319.76 3.09 -3,972.89 INC+TREND(5) 12,041.60 76.56 29.08 6,288.58 6,141.08 -4,985.04 5,078.00 5,925,032.80 486,344.79 1.32 -3,924.52 MWD+IFR-AK-CAZ-SC(6) 12,085.66 77.20 27.55 6,298.58 6,151.08 -4,947.27 5,098.35 5,925,070.52 486,365.23 3.68 -3,883.56 MWD+IFR-AK-CAZ-SC(6) 12,180.07 78.74 25.28 6,318.26 6,170.76 -4,864.58 5,139.42 5,925,153.10 486,406.50 2.86 -3,794.55 MWD+IFR-AK-CAZ-SC(6) 12,273.61 80.14 25.32 6,335.40 6,187.90 -4,781.44 5,178.71 5,925,236.12 486,446.00 1.50 -3,705.45 MWD+IFR-AK-CAZ-SC(6) 12,366.85 81.43 24.24 6,350.34 6,202.84 -4,697.88 5,217.29 5,925,319.58 486,484.78 1.79 -3,616.06 MWD+IFR-AK-CAZ-SC(6) 12,462.43 82.97 21.75 6,363.31 6,215.81 -4,610.72 5,254.27 5,925,406.64 486,521.98 3.04 -3,523.45 MWD+IFR-AK-CAZ-SC(6) 12,558.53 86.12 17.32 6,372.45 6,224.95 -4,520.59 5,286.24 5,925,496.68 486,554.16 5.64 -3,428.87 MWD+IFR-AK-CAZ-SC(6) 12,652.45 89.07 15.26 6,376.39 6,228.89 -4,430.54 5,312.56 5,925,586.66 486,580.70 3.83 -3,335.45 MWD+IFR-AK-CAZ-SC(6) 12,748.08 91.43 14.83 6,375.97 6,228.47 -4,338.19 5,337.38 5,925,678.93 486,605.75 2.51 -3,240.07 MWD+IFR-AK-CAZ-SC(6) 12,840.91 90.82 13.06 6,374.15 6,226.65 -4,248.12 5,359.74 5,925,768.94 486,628.34 2.02 -3,147.38 MWD+IFR-AK-CAZ-SC(6) 12,936.69 90.23 11.54 6,373.27 6,225.77 -4,154.55 5,380.14 5,925,862.46 486,648.97 1.70 -3,051.63 MWD+IFR-AK-CAZ-SC(6) 13,031.39 91.04 10.76 6,372.22 6,224.72 -4,061.64 5,398.46 5,925,955.31 486,667.51 1.19 -2,956.94 MWD+IFR-AK-CAZ-SC(6) 13,125.78 89.77 10.33 6,371.55 6,224.05 -3,968.85 5,415.73 5,926,048.05 486,685.01 1.42 -2,862.56 MWD+IFR-AK-CAZ-SC(6) 13,217.62 91.25 9.42 6,370.74 6,223.24 -3,878.38 5,431.48 5,926,138.47 486,700.98 1.89 -2,770.74 MWD+IFR-AK-CAZ-SC(6) 13,313.95 90.50 9.24 6,369.27 6,221.77 -3,783.33 5,447.09 5,926,233.47 486,716.83 0.80 -2,674.47 MWD+IFR-AK-CAZ-SC(6) 13,408.13 91.40 8.19 6,367.70 6,220.20 -3,690.26 5,461.36 5,926,326.50 486,731.33 1.47 -2,580.38 MWD+IFR-AK-CAZ-SC(6) 13,501.25 91.16 8.66 6,365.62 6,218.12 -3,598.16 5,475.00 5,926,418.55 486,745.19 0.57 -2,487.38 MWD+IFR-AK-CAZ-SC(6) 13,597.30 90.78 8.52 6,364.00 6,216.50 -3,503.20 5,489.35 5,926,513.46 486,759.77 0.42 -2,391.42 MWD+IFR-AK-CAZ-SC(6) 13,692.32 91.13 9.21 6,362.41 6,214.91 -3,409.33 5,503.99 5,926,607.28 486,774.65 0.81 -2,296.48 MWD+IFR-AK-CAZ-SC(6) 13,787.60 90.12 9.85 6,361.38 6,213.88 -3,315.38 5,519.76 5,926,701.19 486,790.65 1.25 -2,201.24 MWD+IFR-AK-CAZ-SC(6) 13,881.69 90.71 9.54 6,360.69 6,213.19 -3,222.63 5,535.61 5,926,793.89 486,806.72 0.71 -2,107.18 MWD+IFR-AK-CAZ-SC(6) 7/23/2015 8:05:57AM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) 0100') (ft) Survey Tool Name 13,975.95 91.64 9.54 6,358.76 6,211.26 -3,129.70 5,551.22 5,926,886.78 486,822.57 0.99 -2,012.97 MWD+IFR-AK-CAZ-SC(6) 14,070.90 92.19 9.51 6,355.59 6,208.09 -3,036.11 5,566.93 5,926,980.32 486,838.51 0.58 -1,918.11 MWD+IFR-AK-CAZ-SC(6) 14,165.40 92.19 9.82 6,351.98 6,204.48 -2,943.02 5,582.78 5,927,073.36 486,854.59 0.33 -1,823.70 MWD+IFR-AK-CAZ-SC(6) 14,260.57 91.85 10.70 6,348.62 6,201.12 -2,849.43 5,599.72 5,927,166.89 486,871.76 0.99 -1,728.60 MWD+IFR-AK-CAZ-SC(6) 14,355.12 90.84 12.39 6,346.40 6,198.90 -2,756.82 5,618.64 5,927,259.44 486,890.90 2.08 -1,634.08 MWD+IFR-AK-CAZ-SC(6) 14,450.54 91.47 12.88 6,344.48 6,196.98 -2,663.73 5,639.51 5,927,352.47 486,912.00 0.84 -1,538.72 MWD+1FR-AK-CAZ-SC(6) 14,542.74 91.33 13.52 6,342.23 6,194.73 -2,574.00 5,660.55 5,927,442.15 486,933.27 0.71 -1,446.62 MWD+IFR-AK-CAZ-SC(6) 14,637.09 91.72 13.33 6,339.72 6,192.22 -2,482.26 5,682.45 5,927,533.82 486,955.39 0.46 -1,352.39 MWD+IFR-AK-CAZ-SC(6) 14,729.99 90.51 13.65 6,337.91 6,190.41 -2,391.94 5,704.12 5,927,624.08 486,977.28 1.35 -1,259.59 MW D+I FR-AK-CAZ-SC(6) 14,825.07 90.27 14.80 6,337.26 6,189.76 -2,299.78 5,727.48 5,927,716.17 487,000.87 1.24 -1,164.67 MWD+1FR-AK-CAZ-SC(6) 14,918.24 89.50 14.89 6,337.45 6,189.95 -2,209.72 5,751.35 5,927,806.16 487,024.96 0.83 -1,071.71 MWD+IFR-AK-CAZ-SC(6) 15,012.99 91.06 16.71 6,336.98 6,189.48 -2,118.56 5,777.15 5,927,897.25 487,050.98 2.53 -977.30 MWD+IFR-AK-CAZ-SC(6) 15,109.46 88.90 21.71 6,337.02 6,189.52 -2,027.49 5,808.88 5,927,988.23 487,082.93 5.65 -881.85 MWD+IFR-AK-CAZ-SC(6) 15,155.64 88.11 24.11 6,338.22 6,190.72 -1,984.97 5,826.85 5,928,030.70 487,101.01 5.47 -836.69 MWD+1FR-AK-CAZ-SC(6) 15,203.05 87.35 26.99 6,340.10 6,192.60 -1,942.24 5,847.28 5,928,073.38 487,121.54 6.28 -790.84 MW D+I FR-AK-CAZ-SC(6) 15,266.54 86.85 26.23 6,343.31 6,195.81 -1,885.55 5,875.68 5,928,129.99 487,150.08 1.43 -729.77 MW D+I FR-AK-CAZ-SC(6) 15,296.93 87.70 25.29 6,344.76 6,197.26 -1,858.21 5,888.87 5,928,157.30 487,163.34 4.17 -700.42 MW D+I FR-AK-CAZ-SC(6) 15,390.37 90.51 24.83 6,346.22 6,198.72 -1,773.58 5,928.44 5,928,241.82 487,203.11 3.05 -609.80 MWD+IFR-AK-CAZ-SC(6) 15,485.53 89.69 24.19 6,346.05 6,198.55 -1,687.00 5,967.92 5,928,328.29 487,242.80 1.09 -517.27 MW D+I FR-AK-CAZ-SC(6) 15,580.57 88.86 23.36 6,347.25 6,199.75 -1,600.03 6,006.23 5,928,415.15 487,281.32 1.24 -424.59 MW D+I FR-AK-CAZ-SC(6) 15,675.57 88.06 21.93 6,349.81 6,202.31 -1,512.39 6,042.79 5,928,502.70 487,318.10 1.72 -331.58 MW D+I FR-AK-CAZ-SC(6) 15,724.65 88.94 21.15 6,351.09 6,203.59 -1,466.75 6,060.80 5,928,548.28 487,336.22 2.40 -283.35 MW D+I FR-AK-CAZ-SC(6) 15,767.01 87.75 20.42 6,352.32 6,204.82 -1,427.17 6,075.83 5,928,587.83 487,351.34 3.30 -241.63 MW D+I FR-AK-CAZ-SC(6) 15,864.87 87.80 19.71 6,356.12 6,208.62 -1,335.32 6,109.38 5,928,679.59 487,385.12 0.73 -145.06 MW D+I FR-AK-CAZ-SC(6) 15,959.89 87.63 18.52 6,359.90 6,212.40 -1,245.61 6,140.47 5,928,769.21 487,416.43 1.26 -51.07 MW D+I FR-AK-CAZ-SC(6) 16,052.49 86.51 16.98 6,364.64 6,217.14 -1,157.54 6,168.66 5,928,857.20 487,444.84 2.05 40.76 MWD+IFR-AK-CAZ-SC(6) 16,146.49 87.77 16.02 6,369.33 6,221.83 -1,067.52 6,195.32 5,928,947.14 487,471.72 1.68 134.21 MWD+IFR-AK-CAZ-SC(6) 16,240.28 85.24 13.28 6,375.05 6,227.55 -976.97 6,219.00 5,929,037.63 487,495.62 3.97 227.62 MWD+IFR-AK-CAZ-SC(6) 16,334.34 85.78 9.18 6,382.41 6,234.91 -885.01 6,237.26 5,929,129.53 487,514.10 4.38 321.37 MWD+IFR-AK-CAZ-SC(6) 16,430.14 90.29 6.68 6,385.70 6,238.20 -790.22 6,250.46 5,929,224.28 487,527.54 5.38 416.95 MWD+IFR-AK-CAZ-SC(6) 16,476.84 91.41 7.34 6,385.00 6,237.50 -743.87 6,256.16 5,929,270.61 487,533.35 2.78 463.53 MWD+IFR-AK-CAZ-SC(6) 16,524.03 91.86 8.10 6,383.66 6,236.16 -697.13 6,262.49 5,929,317.33 487,539.80 1.87 510.62 MW D+I FR-AK-CAZ-SC(6) 16,619.23 91.23 12.22 6,381.09 6,233.59 -603.48 6,279.28 5,929,410.93 487,556.81 4.38 605.75 MWD+IFR-AK-CAZ-SC(6) 16,714.90 90.93 13.77 6,379.29 6,231.79 -510.28 6,300.79 5,929,504.07 487,578.55 1.65 701.35 MWD+IFR-AK-CAZ-SC(6) 16,807.93 89.21 16.20 6,379.17 6,231.67 -420.42 6,324.84 5,929,593.86 487,602.82 3.20 794.14 MWD+IFR-AK-CAZ-SC(6) 16,903.20 91.24 16.21 6,378.80 6,231.30 -328.94 6,351.42 5,929,685.26 487,629.63 2.13 889.01 MWD+IFR-AK-CAZ-SC(6) 16,997.43 91.57 15.13 6,376.49 6,228.99 -238.24 6,376.87 5,929,775.89 487,655.30 1.20 982.90 MWD+IFR-AK-CAZ-SC(6) 17,090.93 92.88 13.92 6,372.86 6,225.36 -147.80 6,400.30 5,929,866.26 487,678.95 1.91 1,076.15 MWD+IFR-AK-CAZ-SC(6) 17,185.76 93.46 14.22 6,367.61 6,220.11 -55.96 6,423.32 5,929,958.04 487,702.20 0.69 1,170.70 MWD+IFR-AK-CAZ-SC(6) 17,281.26 92.89 13.76 6,362.33 6,214.83 36.57 6,446.37 5,930,050.49 487,725.48 0.77 1,265.92 MWD+IFR-AK-CAZ-SC(6) 7/23/2015 8:05:57AM Page 7 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 17,376.53 90.30 13.48 6,359.67 6,212.17 129.11 6,468.79 5,930,142.97 487,748.13 2.73 1,361.04 MWD+IFR-AK-CAZ-SC(6) 17,470.54 88.45 14.53 6,360.70 6,213.20 220.32 6,491.54 5,930,234.11 487,771.10 2.26 1,454.91 MWD+IFR-AK-CAZ-SC(6) 17,566.45 87.79 10.85 6,363.85 6,216.35 313.82 6,512.59 5,930,327.55 487,792.38 3.90 1,550.71 MWD+IFR-AK-CAZ-SC(6) 17,659.47 92.74 9.04 6,363.42 6,215.92 405.41 6,528.65 5,930,419.09 487,808.67 5.67 1,643.68 MWD+IFR-AK-CAZ-SC(6) 17,754.57 92.40 9.19 6,359.15 6,211.65 499.21 6,543.70 5,930,512.85 487,823.95 0.39 1,738.64 MWD+IFR-AK-CAZ-SC(6) 17,849.50 92.77 8.66 6,354.87 6,207.37 592.90 6,558.42 5,930,606.49 487,838.89 0.68 1,833.41 MWD+IFR-AK-CAZ-SC(6) 17,942.67 92.88 8.82 6,350.28 6,202.78 684.87 6,572.56 5,930,698.42 487,853.26 0.21 1,926.39 MWD+IFR-AK-CAZ-SC(6) 18,038.13 92.09 10.28 6,346.14 6,198.64 778.92 6,588.38 5,930,792.42 487,869.31 1.74 2,021.73 MWD+IFR-AK-CAZ-SC(6) 18,131.74 91.78 9.35 6,342.98 6,195.48 871.10 6,604.33 5,930,884.55 487,885.49 1.05 2,115.26 MWD+IFR-AK-CAZ-SC(6) 18,226.54 92.19 9.48 6,339.69 6,192.19 964.57 6,619.83 5,930,977.97 487,901.22 0.45 2,209.97 MWD+IFR-AK-CAZ-SC(6) 18,322.24 93.50 8.80 6,334.95 6,187.45 1,058.94 6,635.01 5,931,072.29 487,916.63 1.54 2,305.50 MWD+IFR-AK-CAZ-SC(6) 18,382.80 93.50 8.80 6,331.25 6,183.75 1,118.67 6,644.26 5,931,132.00 487,926.03 0.00 2,365.90 NOT an Actual Survey 4 1/2"x 6-3/4" 18,410.00 93.50 8.80 6,329.59 6,182.09 1,145.50 6,648.41 5,931,158.81 487,930.25 0.00 2,393.03 PROJECTED to TD 7/23/2015 8:05:57AM Page 8 COMPASS 5000.1 Build 74 • • 215070 26 138 RECEIVED AUG 21 2(ii5 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-02 Definitive Survey Report 22 July, 2015 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 2S-02 Well Position +N/-S 0.00 usft Northing: 5,929,779.51 usfl Latitude: 70° 13'10.875 N +E/-W 0.00 usft Easting: 1,621,313.00 usfl Longitude: 150°9'14.840 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 6/25/2015 18.71 80.87 57,491 Design 2S-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 11.00 Survey Program Date 7/22/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.33 104.97 2S-02 Srvy#1 (2S-02) INC+TREND Inclinometer+known azi trend 6/15/2015 9:0 201.82 3,578.11 2S-02 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2015 9:2 3,648.89 3,648.89 2S-02 Srvy#3 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 6/23/2015 9:0, 3,742.01 11,912.22 2S-02 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 9:1: 11,989.16 11,989.16 2S-02 Srvy#5 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 7/9/2015 9:53 12,041.60 18,322.24 2S-02 Srvy#6 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/9/2015 9:55 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,779.51 1,621,313.00 0.00 0.00 UNDEFINED 79.33 0.22 264.90 79.33 -68.17 -0.01 -0.10 5,929,779.50 1,621,312.90 0.42 -0.03 INC+TREND(1) 104.97 0.18 264.90 104.97 -42.53 -0.02 -0.19 5,929,779.49 1,621,312.81 0.16 -0.05 INC+TREND(1) 109.00 0.18 264.90 109.00 -38.50 -0.02 -0.20 5,929,779.49 1,621,312.79 0.10 -0.06 MWD+IFR-AK-CAZ-SC 2) NOT war en neap Survey 16"x 20" 201.82 0.28 264.90 201.82 54.32 -0.05 -0.58 5,929,779.46 1,621,312.42 0.10 -0.16 MWD+IFR-AK-CAZ-SC(2) 293.09 1.07 157.53 293.08 145.58 -0.86 -0.47 5,929,778.65 1,621,312.52 1.30 -0.93 MWD+IFR-AK-CAZ-SC(2) 384.26 3.66 146.85 384.17 236.67 -4.08 1.45 5,929,775.42 1,621,314.43 2.87 -3.73 MWD+IFR-AK-CAZ-SC(2) 476.47 6.34 145.93 476.02 328.52 -10.76 5.91 5,929,768.73 1,621,318.87 2.91 -9.44 MWD+IFR-AK-CAZ-SC(2) 567.55 5.97 145.89 566.57 419.07 -18.85 11.38 5,929,760.63 1,621,324.33 0.41 -16.33 MWD+IFR-AK-CAZ-SC(2) 7/22/2015 9:17:34AM Page 2 COMPASS 5000.1 Build 74 0 0 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 659.98 7.27 139.59 658.39 510.89 -27.29 17.87 5,929,752.18 1,621,330.79 1.61 -23.37 MWD+IFR-AK-CAZ-SC(2) 752.38 8.71 141.01 749.89 602.39 -37.18 26.06 5,929,742.27 1,621,338.96 1.57 -31.52 MWD+IFR-AK-CAZ-SC(2) 845.09 9.73 140.31 841.40 693.90 -48.66 35.48 5,929,730.76 1,621,348.35 1.11 -41.00 MWD+IFR-AK-CAZ-SC(2) 938.89 10.68 143.21 933.71 786.21 -61.72 45.75 5,929,717.68 1,621,358.58 1.15 -51.86 MWD+IFR-AK-CAZ-SC(2) 1,031.83 12.50 143.30 1,024.76 877.26 -76.68 56.92 5,929,702.69 1,621,369.71 1.96 -64.41 MWD+IFR-AK-CAZ-SC(2) 1,127.07 16.06 144.48 1,117.04 969.54 -95.68 70.74 5,929,683.67 1,621,383.48 3.75 -80.42 MWD+IFR-AK-CAZ-SC(2) 1,218.14 17.24 144.24 1,204.29 1,056.79 -116.88 85.94 5,929,662.42 1,621,398.63 1.30 -98.33 MWD+IFR-AK-CAZ-SC(2) 1,311.27 22.51 148.58 1,291.85 1,144.35 -143.31 103.31 5,929,635.95 1,621,415.93 5.87 -120.97 MWD+IFR-AK-CAZ-SC(2) 1,404.33 25.25 148.70 1,376.93 1,229.43 -175.48 122.91 5,929,603.74 1,621,435.45 2.94 -148.80 MWD+IFR-AK-CAZ-SC(2) 1,496.94 25.18 149.30 1,460.72 1,313.22 -209.30 143.23 5,929,569.87 1,621,455.68 0.29 -178.12 MWD+IFR-AK-CAZ-SC(2) 1,590.92 26.52 150.42 1,545.29 1,397.79 -244.74 163.80 5,929,534.38 1,621,476.16 1.52 -208.99 MWD+IFR-AK-CAZ-SC(2) 1,683.02 28.77 149.69 1,626.87 1,479.37 -281.76 185.14 5,929,497.31 1,621,497.40 2.47 -241.25 MWD+IFR-AK-CAZ-SC(2) 1,776.78 30.32 149.47 1,708.44 1,560.94 -321.62 208.55 5,929,457.39 1,621,520.71 1.66 -275.92 MWD+IFR-AK-CAZ-SC(2) 1,870.07 32.51 148.39 1,788.05 1,640.55 -363.26 233.65 5,929,415.69 1,621,545.71 2.42 -312.01 MWD+IFR-AK-CAZ-SC(2) 1,917.29 34.22 149.35 1,827.49 1,679.99 -385.49 247.07 5,929,393.43 1,621,559.07 3.79 -331.27 MWD+IFR-AK-CAZ-SC(2) 1,963.14 38.74 150.89 1,864.34 1,716.84 -409.13 260.63 5,929,369.76 1,621,572.57 10.06 -351.88 MWD+IFR-AK-CAZ-SC(2) 2,008.07 40.31 150.65 1,899.00 1,751.50 -434.08 274.60 5,929,344.78 1,621,586.47 3.51 -373.71 MWD+IFR-AK-CAZ-SC(2) 2,055.84 39.97 150.56 1,935.52 1,788.02 -460.91 289.71 5,929,317.91 1,621,601.51 0.72 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,150.11 41.79 151.87 2,006.79 1,859.29 -514.99 319.41 5,929,263.77 1,621,631.07 2.13 -444.58 MWD+IFR-AK-CAZ-SC(2) 2,242.85 46.57 154.41 2,073.29 1,925.79 -572.65 348.54 5,929,206.04 1,621,660.05 5.50 -495.62 MWD+IFR-AK-CAZ-SC(2) 2,286.63 48.32 156.29 2,102.89 1,955.39 -601.96 361.98 5,929,176.70 1,621,673.42 5.10 -521.83 MWD+IFR-AK-CAZ-SC(2) 2,335.33 49.78 156.21 2,134.81 1,987.31 -635.63 376.80 5,929,143.00 1,621,688.14 3.00 -552.05 MWD+IFR-AK-CAZ-SC(2) 2,428.08 53.30 158.80 2,192.50 2,045.00 -702.72 404.54 5,929,075.84 1,621,715.71 4.38 -612.62 MWD+IFR-AK-CAZ-SC(2) 2,521.26 57.96 160.39 2,245.09 2,097.59 -774.79 431.32 5,929,003.70 1,621,742.31 5.20 -678.26 MWD+IFR-AK-CAZ-SC(2) 2,569.60 59.50 161.11 2,270.18 2,122.68 -813.80 444.94 5,928,964.67 1,621,755.83 3.43 -713.95 MWD+IFR-AK-CAZ-SC(2) 2,613.01 61.40 161.94 2,291.59 2,144.09 -849.62 456.90 5,928,928.82 1,621,767.70 4.68 -746.83 MWD+IFR-AK-CAZ-SC(2) 2,705.53 62.56 161.79 2,335.05 2,187.55 -927.23 482.32 5,928,851.15 1,621,792.92 1.26 -818.17 MWD+IFR-AK-CAZ-SC(2) 2,798.27 65.76 161.39 2,375.47 2,227.97 -1,006.42 508.68 5,928,771.91 1,621,819.08 3.47 -890.87 MWD+IFR-AK-CAZ-SC(2) 2,891.22 67.27 161.00 2,412.51 2,265.01 -1,087.11 536.16 5,928,691.15 1,621,846.35 1.67 -964.84 MWD+IFR-AK-CAZ-SC(2) 2,984.44 69.93 162.04 2,446.52 2,299.02 -1,169.42 563.66 5,928,608.78 1,621,873.64 3.04 -1,040.39 MWD+IFR-AK-CAZ-SC(2) 3,078.50 71.80 159.42 2,477.35 2,329.85 -1,253.29 593.00 5,928,524.85 1,621,902.76 3.30 -1,117.12 MWD+IFR-AK-CAZ-SC(2) 3,172.25 70.97 160.32 2,507.28 2,359.78 -1,336.71 623.58 5,928,441.36 1,621,933.12 1.27 -1,193.17 MWD+IFR-AK-CAZ-SC(2) 3,264.83 72.52 159.74 2,536.28 2,388.78 -1,419.34 653.60 5,928,358.66 1,621,962.94 1.78 -1,268.55 MWD+IFR-AK-CAZ-SC(2) 3,358.77 72.44 159.49 2,564.56 2,417.06 -1,503.31 684.81 5,928,274.62 1,621,993.93 0.27 -1,345.02 MWD+IFR-AK-CAZ-SC(2) 3,451.37 72.53 160.02 2,592.43 2,444.93 -1,586.16 715.36 5,928,191.70 1,622,024.27 0.55 -1,420.52 MWD+IFR-AK-CAZ-SC(2) 3,546.33 71.19 159.61 2,621.99 2,474.49 -1,670.86 746.50 5,928,106.93 1,622,055.19 1.47 -1,497.72 MWD+IFR-AK-CAZ-SC(2) 3,578.11 71.31 159.61 2,632.21 2,484.71 -1,699.07 756.98 5,928,078.70 1,622,065.60 0.38 -1,523.41 MWD+IFR-AK-CAZ-SC(2) 3,644.00 71.11 159.61 2,653.43 2,505.93 -1,757.54 778.72 5,928,020.18 1,622,087.18 0.31 -1,576.66 INC+TRNn 131 10 3/4"x 13-1/2 NOT an Actual Survey 3,648.89 71.09 159.61 2,655.02 2,507.52 -1,761.87 780.33 5,928,015.84 1,622,088.78 0.31 -1,580.61 INC+TREND(3) 7/22/2015 9:17:34AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°/100') (ft) Survey Tool Name 3,742.01 71.54 159.30 2,684.85 2,537.35 -1,844.47 811.29 5,927,933.17 1,622,119.53 0.58 -1,655.78 MWD+IFR-AK-CAZ-SC(4) 3,834.63 71.75 158.62 2,714.02 2,566.52 -1,926.52 842.85 5,927,851.06 1,622,150.88 0.73 -1,730.30 MWD+IFR-AK-CAZ-SC(4) 3,928.68 70.66 158.64 2,744.32 2,596.82 -2,009.43 875.29 5,927,768.07 1,622,183.11 1.16 -1,805.50 MWD+IFR-AK-CAZ-SC(4) 4,021.82 70.21 157.67 2,775.51 2,628.01 -2,090.89 907.95 5,927,686.54 1,622,215.55 1.09 -1,879.23 MWD+IFR-AK-CAZ-SC(4) 4,116.49 70.22 157.64 2,807.55 2,660.05 -2,173.28 941.81 5,927,604.07 1,622,249.21 0.03 -1,953.65 MWD+IFR-AK-CAZ-SC(4) 4,208.85 70.08 157.94 2,838.92 2,691.42 -2,253.71 974.65 5,927,523.56 1,622,281.84 0.34 -2,026.33 MWD+IFR-AK-CAZ-SC(4) 4,301.47 70.19 158.12 2,870.39 2,722.89 -2,334.49 1,007.24 5,927,442.71 1,622,314.22 0.22 -2,099.41 MWD+IFR-AK-CAZ-SC(4) 4,395.70 70.15 158.11 2,902.35 2,754.85 -2,416.75 1,040.28 5,927,360.38 1,622,347.05 0.04 -2,173.85 MWD+IFR-AK-CAZ-SC(4) 4,490.64 67.56 160.37 2,936.60 2,789.10 -2,499.53 1,071.68 5,927,277.53 1,622,378.23 3.52 -2,249.12 MW D+I FR-AK-CAZ-SC(4) 4,582.81 62.88 164.08 2,975.23 2,827.73 -2,579.16 1,097.26 5,927,197.84 1,622,403.61 6.25 -2,322.41 MWD+IFR-AK-CAZ-SC(4) 4,630.09 60.60 165.42 2,997.62 2,850.12 -2,619.33 1,108.22 5,927,157.64 1,622,414.47 5.43 -2,359.75 MWD+1FR-AK-CAZ-SC(4) 4,676.10 58.54 167.88 3,020.92 2,873.42 -2,657.92 1,117.38 5,927,119.03 1,622,423.54 6.43 -2,395.88 MW D+I FR-AK-CAZ-SC(4) 4,725.53 59.59 166.29 3,046.34 2,898.84 -2,699.25 1,126.86 5,927,077.69 1,622,432.91 3.48 -2,434.64 MW D+I FR-AK-CAZ-SC(4) 4,772.57 61.65 164.84 3,069.41 2,921.91 -2,738.94 1,137.08 5,927,037.98 1,622,443.03 5.14 -2,471.65 MW D+I FR-AK-CAZ-SC(4) 4,864.70 65.99 161.23 3,110.06 2,962.56 -2,817.97 1,161.24 5,926,958.89 1,622,466.99 5.88 -2,544.62 MWD+1FR-AK-CAZ-SC(4) 4,900.29 66.83 160.26 3,124.30 2,976.80 -2,848.76 1,172.00 5,926,928.08 1,622,477.66 3.44 -2,572.79 MWD+IFR-AK-CAZ-SC(4) 4,958.75 68.93 159.28 3,146.32 2,998.82 -2,899.57 1,190.73 5,926,877.23 1,622,496.26 3.91 -2,619.09 MWD+IFR-AK-CAZ-SC(4) 5,053.27 71.58 158.24 3,178.25 3,030.75 -2,982.48 1,222.96 5,926,794.24 1,622,528.28 2.99 -2,694.33 MWD+1FR-AK-CAZ-SC(4) 5,145.24 73.20 158.71 3,206.07 3,058.57 -3,064.02 1,255.12 5,926,712.63 1,622,560.23 1.83 -2,768.24 MW D+I FR-AK-CAZ-SC(4) 5,239.23 73.24 158.10 3,233.21 3,085.71 -3,147.69 1,288.24 5,926,628.88 1,622,593.14 0.62 -2,844.05 MWD+1FR-AK-CAZ-SC(4) 5,333.60 72.65 158.08 3,260.88 3,113.38 -3,231.39 1,321.91 5,926,545.10 1,622,626.59 0.63 -2,919.79 MWD+IFR-AK-CAZ-SC(4) 5,426.03 72.23 157.84 3,288.77 3,141.27 -3,313.08 1,354.97 5,926,463.34 1,622,659.44 0.52 -2,993.67 MW D+I FR-AK-CAZ-SC(4) 5,518.53 71.93 157.99 3,317.23 3,169.73 -3,394.63 1,388.07 5,926,381.71 1,622,692.33 0.36 -3,067.41 MWD+IFR-AK-CAZ-SC(4) 5,612.19 72.30 159.66 3,346.00 3,198.50 -3,477.74 1,420.26 5,926,298.53 1,622,724.31 1.74 -3,142.85 MWD+1FR-AK-CAZ-SC(4) 5,705.92 72.76 160.94 3,374.14 3,226.64 -3,561.92 1,450.40 5,926,214.29 1,622,754.23 1.39 -3,219.73 MWD+IFR-AK-CAZ-SC(4) 5,797.08 72.74 161.57 3,401.17 3,253.67 -3,644.36 1,478.37 5,926,131.78 1,622,781.99 0.66 -3,295.31 MWD+1FR-AK-CAZ-SC(4) 5,891.34 72.85 161.49 3,429.05 3,281.55 -3,729.76 1,506.90 5,926,046.32 1,622,810.30 0.14 -3,373.71 MWD+1FR-AK-CAZ-SC(4) 5,984.46 72.80 161.75 3,456.55 3,309.05 -3,814.19 1,534.95 5,925,961.83 1,622,838.14 0.27 -3,451.23 MWD+1FR-AK-CAZ-SC(4) 6,079.38 73.01 161.81 3,484.45 3,336.95 -3,900.37 1,563.32 5,925,875.59 1,622,866.28 0.23 -3,530.41 MWD+IFR-AK-CAZ-SC(4) 6,171.92 73.48 161.79 3,511.13 3,363.63 -3,984.55 1,591.00 5,925,791.35 1,622,893.74 0.51 -3,607.76 MWD+1FR-AK-CAZ-SC(4) 6,264.70 73.23 163.38 3,537.70 3,390.20 -4,069.36 1,617.60 5,925,706.47 1,622,920.13 1.66 -3,685.94 MWD+IFR-AK-CAZ-SC(4) 6,357.62 72.81 164.24 3,564.84 3,417.34 -4,154.70 1,642.38 5,925,621.08 1,622,944.69 0.99 -3,764.99 MWD+IFR-AK-CAZ-SC(4) 6,452.00 71.09 165.34 3,594.08 3,446.58 -4,241.29 1,665.93 5,925,534.44 1,622,968.01 2.13 -3,845.49 MWD+IFR-AK-CAZ-SC(4) 6,546.56 70.82 164.30 3,624.94 3,477.44 -4,327.55 1,689.33 5,925,448.13 1,622,991.20 1.08 -3,925.71 MWD+IFR-AK-CAZ-SC(4) 6,639.39 71.21 163.09 3,655.14 3,507.64 -4,411.80 1,713.97 5,925,363.82 1,623,015.63 1.30 -4,003.70 MWD+IFR-AK-CAZ-SC(4) 6,733.34 71.59 162.16 3,685.11 3,537.61 -4,496.78 1,740.56 5,925,278.79 1,623,042.00 1.02 -4,082.05 MW D+I FR-AK-CAZ-SC(4) 6,825.99 71.56 160.77 3,714.39 3,566.89 -4,580.12 1,768.51 5,925,195.39 1,623,069.73 1.42 -4,158.52 MWD+1FR-AK-CAZ-SC(4) 6,919.67 71.13 160.08 3,744.36 3,596.86 -4,663.75 1,798.24 5,925,111.69 1,623,099.25 0.84 -4,234.94 MWD+IFR-AK-CAZ-SC(4) 7,012.84 70.59 159.36 3,774.91 3,627.41 -4,746.31 1,828.75 5,925,029.06 1,623,129.54 0.93 -4,310.16 MWD+IFR-AK-CAZ-SC(4) 7,106.80 69.91 158.28 3,806.66 3,659.16 -4,828.77 1,860.70 5,924,946.53 1,623,161.28 1.30 -4,385.01 MWD+IFR-AK-CAZ-SC(4) 7/22/2015 9:17:34AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°l100') (ft) Survey Tool Name 7,199.18 69.17 156.41 3,838.95 3,691.45 -4,908.64 1,894.03 5,924,866.58 1,623,194.41 2.06 -4,457.05 MWD+IFR-AK-CAZ-SC(4) 7,244.76 69.03 154.84 3,855.21 3,707.71 -4,947.42 1,911.60 5,924,827.76 1,623,211.88 3.23 -4,491.77 MWD+IFR-AK-CAZ-SC(4) 7,291.38 68.76 153.04 3,872.00 3,724.50 -4,986.49 1,930.71 5,924,788.65 1,623,230.88 3.65 -4,526.48 MWD+IFR-AK-CAZ-SC(4) 7,383.77 68.23 150.58 3,905.87 3,758.37 -5,062.25 1,971.31 5,924,712.79 1,623,271.29 2.54 -4,593.10 MWD+IFR-AK-CAZ-SC(4) 7,432.28 67.46 150.46 3,924.17 3,776.67 -5,101.36 1,993.42 5,924,673.63 1,623,293.30 1.60 -4,627.27 MWD+IFR-AK-CAZ-SC(4) 7,476.60 66.79 148.64 3,941.40 3,793.90 -5,136.56 2,014.11 5,924,638.38 1,623,313.90 4.07 -4,657.88 MWD+IFR-AK-CAZ-SC(4) 7,523.30 65.95 148.04 3,960.12 3,812.62 -5,172.98 2,036.57 5,924,601.91 1,623,336.26 2.15 -4,689.34 MWD+IFR-AK-CAZ-SC(4) 7,569.49 64.77 146.66 3,979.37 3,831.87 -5,208.33 2,059.21 5,924,566.51 1,623,358.81 3.73 -4,719.72 MWD+IFR-AK-CAZ-SC(4) 7,661.87 62.68 144.63 4,020.27 3,872.77 -5,276.71 2,105.94 5,924,498.01 1,623,405.37 3.00 -4,777.93 MWD+IFR-AK-CAZ-SC(4) 7,708.63 61.42 143.44 4,042.19 3,894.69 -5,310.14 2,130.20 5,924,464.52 1,623,429.53 3.51 -4,806.12 MWD+IFR-AK-CAZ-SC(4) 7,754.64 60.43 143.18 4,064.54 3,917.04 -5,342.39 2,154.22 5,924,432.22 1,623,453.47 2.21 -4,833.19 MWD+IFR-AK-CAZ-SC(4) 7,847.12 58.64 141.38 4,111.43 3,963.93 -5,405.44 2,202.98 5,924,369.05 1,623,502.06 2.56 -4,885.78 MWD+IFR-AK-CAZ-SC(4) 7,941.74 57.14 140.05 4,161.73 4,014.23 -5,467.47 2,253.71 5,924,306.89 1,623,552.64 1.98 -4,936.99 MWD+IFR-AK-CAZ-SC(4) 8,033.51 55.79 138.38 4,212.43 4,064.93 -5,525.39 2,303.67 5,924,248.85 1,623,602.45 2.11 -4,984.32 MWD+IFR-AK-CAZ-SC(4) 8,126.93 54.30 137.04 4,265.95 4,118.45 -5,582.04 2,355.18 5,924,192.09 1,623,653.81 1.98 -5,030.09 MWD+IFR-AK-CAZ-SC(4) 8,219.65 54.14 135.68 4,320.16 4,172.66 -5,636.47 2,407.09 5,924,137.53 1,623,705.57 1.20 -5,073.62 MWD+IFR-AK-CAZ-SC(4) 8,311.71 53.98 133.46 4,374.20 4,226.70 -5,688.77 2,460.18 5,924,085.09 1,623,758.53 1.96 -5,114.83 MWD+IFR-AK-CAZ-SC(4) 8,405.19 54.41 131.05 4,428.90 4,281.40 -5,739.74 2,516.29 5,924,033.99 1,623,814.50 2.14 -5,154.16 MWD+IFR-AK-CAZ-SC(4) 8,498.51 55.01 129.12 4,482.81 4,335.31 -5,788.78 2,574.57 5,923,984.80 1,623,872.65 1.81 -5,191.18 MWD+IFR-AK-CAZ-SC(4) 8,589.66 55.80 126.01 4,534.57 4,387.07 -5,834.51 2,634.04 5,923,938.93 1,623,932.00 2.94 -5,224.72 MWD+IFR-AK-CAZ-SC(4) 8,683.20 56.08 124.26 4,586.96 4,439.46 -5,879.11 2,697.41 5,923,894.18 1,623,995.25 1.58 -5,256.40 MWD+IFR-AK-CAZ-SC(4) 8,776.27 55.77 122.48 4,639.11 4,491.61 -5,921.51 2,761.79 5,923,851.62 1,624,059.51 1.62 -5,285.74 MWD+IFR-AK-CAZ-SC(4) 8,871.20 55.23 119.36 4,692.89 4,545.39 -5,961.71 2,828.88 5,923,811.26 1,624,126.50 2.77 -5,312.40 MWD+IFR-AK-CAZ-SC(4) 8,964.80 55.26 115.26 4,746.26 4,598.76 -5,996.98 2,897.19 5,923,775.82 1,624,194.71 3.60 -5,333.98 MWD+IFR-AK-CAZ-SC(4) 9,058.92 54.33 110.96 4,800.54 4,653.04 -6,027.16 2,967.89 5,923,745.45 1,624,265.32 3.86 -5,350.13 MWD+IFR-AK-CAZ-SC(4) 9,151.26 53.08 107.55 4,855.21 4,707.71 -6,051.72 3,038.12 5,923,720.73 1,624,335.49 3.27 -5,360.83 MWD+IFR-AK-CAZ-SC(4) 9,244.59 51.90 103.86 4,912.05 4,764.55 -6,071.77 3,109.37 5,923,700.50 1,624,406.67 3.38 -5,366.92 MWD+IFR-AK-CAZ-SC(4) 9,339.64 51.68 101.01 4,970.85 4,823.35 -6,087.85 3,182.29 5,923,684.23 1,624,479.55 2.37 -5,368.79 MWD+IFR-AK-CAZ-SC(4) 9,433.65 52.18 96.95 5,028.83 4,881.33 -6,099.39 3,255.36 5,923,672.51 1,624,552.59 3.44 -5,366.17 MWD+IFR-AK-CAZ-SC(4) 9,527.85 52.70 93.07 5,086.27 4,938.77 -6,105.90 3,329.73 5,923,665.81 1,624,626.93 3.31 -5,358.37 MWD+IFR-AK-CAZ-SC(4) 9,622.63 53.06 89.50 5,143.48 4,995.98 -6,107.59 3,405.26 5,923,663.93 1,624,702.45 3.03 -5,345.62 MWD+IFR-AK-CAZ-SC(4) 9,714.35 53.01 86.72 5,198.64 5,051.14 -6,105.17 3,478.50 5,923,666.16 1,624,775.68 2.42 -5,329.27 MWD+IFR-AK-CAZ-SC(4) 9,807.43 52.81 82.83 5,254.79 5,107.29 -6,098.42 3,552.41 5,923,672.73 1,624,849.61 3.34 -5,308.54 MWD+IFR-AK-CAZ-SC(4) 9,900.31 52.10 79.93 5,311.39 5,163.89 -6,087.39 3,625.21 5,923,683.57 1,624,922.42 2.59 -5,283.82 MWD+IFR-AK-CAZ-SC(4) 9,993.05 51.94 77.10 5,368.47 5,220.97 -6,072.84 3,696.83 5,923,697.94 1,624,994.08 2.41 -5,255.87 MWD+IFR-AK-CAZ-SC(4) 10,084.97 52.38 74.60 5,424.87 5,277.37 -6,055.09 3,767.21 5,923,715.51 1,625,064.49 2.20 -5,225.02 MWD+IFR-AK-CAZ-SC(4) 10,177.14 52.85 71.05 5,480.84 5,333.34 -6,033.46 3,837.16 5,923,736.95 1,625,134.49 3.10 -5,190.45 MWD+IFR-AK-CAZ-SC(4) 10,270.67 53.68 68.96 5,536.79 5,389.29 -6,007.83 3,907.59 5,923,762.41 1,625,204.97 2.00 -5,151.85 MWD+IFR-AK-CAZ-SC(4) 10,363.78 54.22 67.13 5,591.58 5,444.08 -5,979.68 3,977.40 5,923,790.38 1,625,274.85 1.69 -5,110.90 MWD+IFR-AK-CAZ-SC(4) 10,458.74 55.60 65.62 5,646.17 5,498.67 -5,948.54 4,048.58 5,923,821.34 1,625,346.10 1.95 -5,066.74 MWD+IFR-AK-CAZ-SC(4) 7/22/2015 9:17:34AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°1100') (ft) Survey Tool Name 10,552.81 57.15 64.24 5,698.27 5,550.77 -5,915.34 4,119.52 5,923,854.35 1,625,417.12 2.05 -5,020.62 MWD+IFR-AK-CAZ-SC(4) 10,645.30 59.32 63.18 5,746.95 5,599.45 -5,880.51 4,190.02 5,923,889.00 1,625,487.70 2.54 -4,972.97 MWD+IFR-AK-CAZ-SC(4) 10,738.02 60.40 61.18 5,793.51 5,646.01 -5,843.08 4,260.92 5,923,926.24 1,625,558.69 2.20 -4,922.71 MWD+IFR-AK-CAZ-SC(4) 10,829.90 61.81 59.02 5,837.91 5,690.41 -5,802.98 4,330.64 5,923,966.17 1,625,628.51 2.57 -4,870.04 MWD+IFR-AK-CAZ-SC(4) 10,922.36 63.14 56.63 5,880.65 5,733.15 -5,759.31 4,400.03 5,924,009.65 1,625,698.00 2.71 -4,813.93 MWD+IFR-AK-CAZ-SC(4) 11,015.52 64.31 54.14 5,921.89 5,774.39 -5,711.86 4,468.77 5,924,056.93 1,625,766.84 2.71 -4,754.24 MWD+IFR-AK-CAZ-SC(4) 11,108.81 65.52 51.16 5,961.45 5,813.95 -5,660.60 4,535.91 5,924,108.01 1,625,834.12 3.17 -4,691.11 MWD+IFR-AK-CAZ-SC(4) 11,200.77 65.87 48.49 5,999.30 5,851.80 -5,606.54 4,599.94 5,924,161.91 1,625,898.27 2.67 -4,625.82 MWD+IFR-AK-CAZ-SC(4) 11,294.57 66.41 45.46 6,037.25 5,889.75 -5,548.01 4,662.64 5,924,220.27 1,625,961.11 3.01 -4,556.41 MWD+IFR-AK-CAZ-SC(4) 11,392.75 67.00 43.08 6,076.08 5,928.58 -5,483.44 4,725.58 5,924,284.67 1,626,024.21 2.31 -4,481.02 MWD+IFR-AK-CAZ-SC(4) 11,480.49 66.94 40.75 6,110.41 5,962.91 -5,423.36 4,779.51 5,924,344.61 1,626,078.29 2.44 -4,411.75 MWD+IFR-AK-CAZ-SC(4) 11,573.13 67.76 38.17 6,146.09 5,998.59 -5,357.36 4,833.84 5,924,410.47 1,626,132.78 2.72 -4,336.59 MWD+IFR-AK-CAZ-SC(4) 11,666.15 69.27 36.07 6,180.17 6,032.67 -5,288.34 4,886.06 5,924,479.34 1,626,185.17 2.65 -4,258.88 MWD+IFR-AK-CAZ-SC(4) 11,760.11 71.22 34.01 6,211.93 6,064.43 -5,215.94 4,936.82 5,924,551.61 1,626,236.11 2.93 -4,178.12 MWD+IFR-AK-CAZ-SC(4) 11,853.07 73.37 32.41 6,240.20 6,092.70 -5,141.85 4,985.31 5,924,625.57 1,626,284.78 2.83 -4,096.14 MWD+IFR-AK-CAZ-SC(4) 11,912.22 74.51 31.42 6,256.56 6,109.06 -5,093.61 5,015.36 5,924,673.73 1,626,314.95 2.51 -4,043.05 MWD+IFR-AK-CAZ-SC(4) 11,981.20 75.85 29.70 6,274.21 6,126.71 -5,036.19 5,049.26 5,924,731.06 1,626,348.99 3.09 -3,980.21 INC+TREND(5) 7-5/8"x 9-7/8" NOT anAdvil Survey 11,989.16 76.00 29.50 6,276.14 6,128.64 -5,029.47 5,053.07 5,924,737.77 1,626,352.82 3.09 -3,972.89 INC+TREND(5) 12,041.60 76.56 29.08 6,288.58 6,141.08 -4,985.04 5,078.00 5,924,782.13 1,626,377.85 1.32 -3,924.52 MWD+IFR-AK-CAZ-SC(6) 12,085.66 77.20 27.55 6,298.58 6,151.08 -4,947.27 5,098.35 5,924,819.85 1,626,398.30 3.68 -3,883.56 MWD+IFR-AK-CAZ-SC(6) 12,180.07 78.74 25.28 6,318.26 6,170.76 -4,864.58 5,139.42 5,924,902.43 1,626,439.57 2.86 -3,794.55 MWD+IFR-AK-CAZ-SC(6) 12,273.61 80.14 25.32 6,335.40 6,187.90 -4,781.44 5,178.71 5,924,985.45 1,626,479.08 1.50 -3,705.45 MWD+IFR-AK-CAZ-SC(6) 12,366.85 81.43 24.24 6,350.34 6,202.84 -4,697.88 5,217.29 5,925,068.91 1,626,517.86 1.79 -3,616.06 MWD+IFR-AK-CAZ-SC(6) 12,462.43 82.97 21.75 6,363.31 6,215.81 -4,610.72 5,254.27 5,925,155.97 1,626,555.06 3.04 -3,523.45 MWD+IFR-AK-CAZ-SC(6) 12,558.53 86.12 17.32 6,372.45 6,224.95 -4,520.59 5,286.24 5,925,246.00 1,626,587.25 5.64 -3,428.87 MWD+IFR-AK-CAZ-SC(6) 12,652.45 89.07 15.26 6,376.39 6,228.89 -4,430.54 5,312.56 5,925,335.98 1,626,613.79 3.83 -3,335.45 MWD+IFR-AK-CAZ-SC(6) 12,748.08 91.43 14.83 6,375.97 6,228.47 -4,338.19 5,337.38 5,925,428.25 1,626,638.84 2.51 -3,240.07 MWD+IFR-AK-CAZ-SC(6) 12,840.91 90.82 13.06 6,374.15 6,226.65 -4,248.12 5,359.74 5,925,518.26 1,626,661.43 2.02 -3,147.38 MWD+IFR-AK-CAZ-SC(6) 12,936.69 90.23 11.54 6,373.27 6,225.77 -4,154.55 5,380.14 5,925,611.77 1,626,682.07 1.70 -3,051.63 MWD+IFR-AK-CAZ-SC(6) 13,031.39 91.04 10.76 6,372.22 6,224.72 -4,061.64 5,398.46 5,925,704.62 1,626,700.62 1.19 -2,956.94 MWD+IFR-AK-CAZ-SC(6) 13,125.78 89.77 10.33 6,371.55 6,224.05 -3,968.85 5,415.73 5,925,797.36 1,626,718.12 1.42 -2,862.56 MWD+IFR-AK-CAZ-SC(6) 13,217.62 91.25 9.42 6,370.74 6,223.24 -3,878.38 5,431.48 5,925,887.78 1,626,734.10 1.89 -2,770.74 MWD+IFR-AK-CAZ-SC(6) 13,313.95 90.50 9.24 6,369.27 6,221.77 -3,783.33 5,447.09 5,925,982.78 1,626,749.95 0.80 -2,674.47 MWD+IFR-AK-CAZ-SC(6) 13,408.13 91.40 8.19 6,367.70 6,220.20 -3,690.26 5,461.36 5,926,075.81 1,626,764.46 1.47 -2,580.38 MWD+IFR-AK-CAZ-SC(6) 13,501.25 91.16 8.66 6,365.62 6,218.12 -3,598.16 5,475.00 5,926,167.86 1,626,778.33 0.57 -2,487.38 MWD+IFR-AK-CAZ-SC(6) 13,597.30 90.78 8.52 6,364.00 6,216.50 -3,503.20 5,489.35 5,926,262.77 1,626,792.91 0.42 -2,391.42 MWD+IFR-AK-CAZ-SC(6) 13,692.32 91.13 9.21 6,362.41 6,214.91 -3,409.33 5,503.99 5,926,356.60 1,626,807.79 0.81 -2,296.48 MWD+IFR-AK-CAZ-SC(6) 13,787.60 90.12 9.85 6,361.38 6,213.88 -3,315.38 5,519.76 5,926,450.50 1,626,823.80 1.25 -2,201.24 MWD+IFR-AK-CAZ-SC(6) 13,881.69 90.71 9.54 6,360.69 6,213.19 -3,222.63 5,535.61 5,926,543.20 1,626,839.87 0.71 -2,107.18 MWD+IFR-AK-CAZ-SC(6) 7/22/2015 9:17:34AM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 13,975.95 91.64 9.54 6,358.76 6,211.26 -3,129.70 5,551.22 5,926,636.08 1,626,855.73 0.99 -2,012.97 MWD+IFR-AK-CAZ-SC(6) 14,070.90 92.19 9.51 6,355.59 6,208.09 -3,036.11 5,566.93 5,926,729.62 1,626,871.67 0.58 -1,918.11 MWD+IFR-AK-CAZ-SC(6) 14,165.40 92.19 9.82 6,351.98 6,204.48 -2,943.02 5,582.78 5,926,822.66 1,626,887.75 0.33 -1,823.70 MWD+IFR-AK-CAZ-SC(6) 14,260.57 91.85 10.70 6,348.62 6,201.12 -2,849.43 5,599.72 5,926,916.20 1,626,904.93 0.99 -1,728.60 MWD+IFR-AK-CAZ-SC(6) 14,355.12 90.84 12.39 6,346.40 6,198.90 -2,756.82 5,618.64 5,927,008.75 1,626,924.08 2.08 -1,634.08 MWD+IFR-AK-CAZ-SC(6) 14,450.54 91.47 12.88 6,344.48 6,196.98 -2,663.73 5,639.51 5,927,101.78 1,626,945.18 0.84 -1,538.72 MWD+IFR-AK-CAZ-SC(6) 14,542.74 91.33 13.52 6,342.23 6,194.73 -2,574.00 5,660.55 5,927,191.45 1,626,966.45 0.71 -1,446.62 MW D+I FR-AK-CAZ-SC(6) 14,637.09 91.72 13.33 6,339.72 6,192.22 -2,482.26 5,682.45 5,927,283.13 1,626,988.58 0.46 -1,352.39 MWD+1FR-AK-CAZ-SC(6) 14,729.99 90.51 13.65 6,337.91 6,190.41 -2,391.94 5,704.12 5,927,373.38 1,627,010.47 1.35 -1,259.59 MWD+IFR-AK-CAZ-SC(6) 14,825.07 90.27 14.80 6,337.26 6,189.76 -2,299.78 5,727.48 5,927,465.47 1,627,034.07 1.24 -1,164.67 MWD+1FR-AK-CAZ-SC(6) 14,918.24 89.50 14.89 6,337.45 6,189.95 -2,209.72 5,751.35 5,927,555.46 1,627,058.16 0.83 -1,071.71 MW D+I FR-AK-CAZ-SC(6) 15,012.99 91.06 16.71 6,336.98 6,189.48 -2,118.56 5,777.15 5,927,646.55 1,627,084.19 2.53 -977.30 MWD+1FR-AK-CAZ-SC(6) 15,109.46 88.90 21.71 6,337.02 6,189.52 -2,027.49 5,808.88 5,927,737.52 1,627,116.14 5.65 -881.85 MWD+1FR-AK-CAZ-SC(6) 15,155.64 88.11 24.11 6,338.22 6,190.72 -1,984.97 5,826.85 5,927,779.99 1,627,134.22 5.47 -836.69 MWD+IFR-AK-CAZ-SC(6) 15,203.05 87.35 26.99 6,340.10 6,192.60 -1,942.24 5,847.28 5,927,822.67 1,627,154.76 6.28 -790.84 MWD+IFR-AK-CAZ-SC(6) 15,266.54 86.85 26.23 6,343.31 6,195.81 -1,885.55 5,875.68 5,927,879.29 1,627,183.30 1.43 -729.77 MWD+IFR-AK-CAZ-SC(6) 15,296.93 87.70 25.29 6,344.76 6,197.26 -1,858.21 5,888.87 5,927,906.59 1,627,196.56 4.17 -700.42 MWD+I FR-AK-CAZ-SC(6) 15,390.37 90.51 24.83 6,346.22 6,198.72 -1,773.58 5,928.44 5,927,991.11 1,627,236.34 3.05 -609.80 MWD+IFR-AK-CAZ-SC(6) 15,485.53 89.69 24.19 6,346.05 6,198.55 -1,687.00 5,967.92 5,928,077.58 1,627,276.03 1.09 -517.27 MW D+I FR-AK-CAZ-SC(6) 15,580.57 88.86 23.36 6,347.25 6,199.75 -1,600.03 6,006.23 5,928,164.44 1,627,314.56 1.24 -424.59 MWD+I FR-AK-CAZ-SC(6) 15,675.57 88.06 21.93 6,349.81 6,202.31 -1,512.39 6,042.79 5,928,251.98 1,627,351.34 1.72 -331.58 MWD+IFR-AK-CAZ-SC(6) 15,724.65 88.94 21.15 6,351.09 6,203.59 -1,466.75 6,060.80 5,928,297.57 1,627,369.46 2.40 -283.35 MW D+I FR-AK-CAZ-SC(6) 15,767.01 87.75 20.42 6,352.32 6,204.82 -1,427.17 6,075.83 5,928,337.11 1,627,384.59 3.30 -241.63 MW D+I FR-AK-CAZ-SC(6) 15,864.87 87.80 19.71 6,356.12 6,208.62 -1,335.32 6,109.38 5,928,428.87 1,627,418.37 0.73 -145.06 MW D+I FR-AK-CAZ-SC(6) 15,959.89 87.63 18.52 6,359.90 6,212.40 -1,245.61 6,140.47 5,928,518.49 1,627,449.68 1.26 -51.07 MW D+I FR-AK-CAZ-SC(6) 16,052.49 86.51 16.98 6,364.64 6,217.14 -1,157.54 6,168.66 5,928,606.48 1,627,478.09 2.05 40.76 MWD+IFR-AK-CAZ-SC(6) 16,146.49 87.77 16.02 6,369.33 6,221.83 -1,067.52 6,195.32 5,928,696.41 1,627,504.98 1.68 134.21 MWD+IFR-AK-CAZ-SC(6) 16,240.28 85.24 13.28 6,375.05 6,227.55 -976.97 6,219.00 5,928,786.90 1,627,528.88 3.97 227.62 MWD+IFR-AK-CAZ-SC(6) 16,334.34 85.78 9.18 6,382.41 6,234.91 -885.01 6,237.26 5,928,878.80 1,627,547.37 4.38 321.37 MWD+IFR-AK-CAZSC(6) 16,430.14 90.29 6.68 6,385.70 6,238.20 -790.22 6,250.46 5,928,973.55 1,627,560.81 5.38 416.95 MWD+IFR-AK-CAZ-SC(6) 16,476.84 91.41 7.34 6,385.00 6,237.50 -743.87 6,256.16 5,929,019.88 1,627,566.63 2.78 463.53 MWD+IFR-AK-CAZ-SC(6) 16,524.03 91.86 8.10 6,383.66 6,236.16 -697.13 6,262.49 5,929,066.60 1,627,573.08 1.87 510.62 MWD+IFR-AK-CAZ-SC(6) 16,619.23 91.23 12.22 6,381.09 6,233.59 -603.48 6,279.28 5,929,160.20 1,627,590.10 4.38 605.75 MWD+IFR-AK-CAZ-SC(6) 16,714.90 90.93 13.77 6,379.29 6,231.79 -510.28 6,300.79 5,929,253.34 1,627,611.84 1.65 701.35 MWD+IFR-AK-CAZ-SC(6) 16,807.93 89.21 16.20 6,379.17 6,231.67 -420.42 6,324.84 5,929,343.12 1,627,636.12 3.20 794.14 MWD+IFR-AK-CAZ-SC(6) 16,903.20 91.24 16.21 6,378.80 6,231.30 -328.94 6,351.42 5,929,434.53 1,627,662.93 2.13 889.01 MWD+IFR-AK-CAZ-SC(6) 16,997.43 91.57 15.13 6,376.49 6,228.99 -238.24 6,376.87 5,929,525.15 1,627,688.60 1.20 982.90 MWD+IFR-AK-CAZ-SC(6) 17,090.93 92.88 13.92 6,372.86 6,225.36 -147.80 6,400.30 5,929,615.52 1,627,712.26 1.91 1,076.15 MWD+IFR-AK-CAZ-SC(6) 17,185.76 93.46 14.22 6,367.61 6,220.11 -55.96 6,423.32 5,929,707.30 1,627,735.51 0.69 1,170.70 MWD+IFR-AK-CAZ-SC(6) 17,281.26 92.89 13.76 6,362.33 6,214.83 36.57 6,446.37 5,929,799.76 1,627,758.79 0.77 1,265.92 MWD+IFR-AK-CAZ-SC(6) 7/22/2015 9:17:34AM Page 7 COMPASS 5000.1 Build 74 • • 0 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°11001 (ft) Survey Tool Name 17,376.53 90.30 13.48 6,359.67 6,212.17 129.11 6,468.79 5,929,892.24 1,627,781.45 2.73 1,361.04 MWD+IFR-AK-CAZ-SC(6) 17,470.54 88.45 14.53 6,360.70 6,213.20 220.32 6,491.54 5,929,983.37 1,627,804.43 2.26 1,454.91 MWD+IFR-AK-CAZ-SC(6) 17,566.45 87.79 10.85 6,363.85 6,216.35 313.82 6,512.59 5,930,076.81 1,627,825.71 3.90 1,550.71 MWD+IFR-AK-CAZ-SC(6) 17,659.47 92.74 9.04 6,363.42 6,215.92 405.41 6,528.65 5,930,168.35 1,627,842.00 5.67 1,643.68 MWD+IFR-AK-CAZ-SC(6) 17,754.57 92.40 9.19 6,359.15 6,211.65 499.21 6,543.70 5,930,262.11 1,627,857.29 0.39 1,738.64 MWD+IFR-AK-CAZ-SC(6) 17,849.50 92.77 8.66 6,354.87 6,207.37 592.90 6,558.42 5,930,355.75 1,627,872.24 0.68 1,833.41 MWD+IFR-AK-CAZ-SC(6) 17,942.67 92.88 8.82 6,350.28 6,202.78 684.87 6,572.56 5,930,447.68 1,627,886.61 0.21 1,926.39 MWD+IFR-AK-CAZ-SC(6) 18,038.13 92.09 10.28 6,346.14 6,198.64 778.92 6,588.38 5,930,541.67 1,627,902.67 1.74 2,021.73 MWD+IFR-AK-CAZ-SC(6) 18,131.74 91.78 9.35 6,342.98 6,195.48 871.10 6,604.33 5,930,633.81 1,627,918.85 1.05 2,115.26 MWD+IFR-AK-CAZ-SC(6) 18,226.54 92.19 9.48 6,339.69 6,192.19 964.57 6,619.83 5,930,727.23 1,627,934.58 0.45 2,209.97 MWD+IFR-AK-CAZ-SC(6) 18,322.24 93.50 8.80 6,334.95 6,187.45 1,058.94 6,635.01 5,930,821.54 1,627,950.00 1.54 2,305.50 MWD+IFR-AK-CAZ-SC(6) 18,382.80 93.50 8.80 6,331.25 6,183.75 1,118.67 6,644.26 5,930,881.25 1,627,959.40 0.00 2,365.90 NOT an Actual Survey 4 1/2"x 6-3/4" 18,410.00 93.50 8.80 6,329.59 6,182.09 1,145.50 6,648.41 5,930,908.07 1,627,963.62 0.00 2,393.03 PROJECTED to TD 7/22/2015 9:17:34AM Page 8 COMPASS 5000.1 Build 74 al :� , i 5070 26125 RECEIVr ConocoPhillips 41.ili 18 t b'. TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0346 TO: ConocoPhillips Alaska, Inc. GCC Bender AOGCC P.O. Box 100360 Ave. Suite 100 888 W. y Anchorage AK 99510-0360 7th Anchorage,Alaska 99501 RE: 2S-02 DATE: 08/12/2015 MAK LOGGED S itgi2cis M.K.BENDER Transmitted: Kuparuk River Unit, Alaska 2S-02 (permit 215-070-0) 1 hardcopy report with digital data on CD 11 ii II __Halliburton Surface logging data/End of well report; table of contents: General information, daily summary, days vs. 1 n depth, after action review, mud record, bit record, morning reports, survey report. Color log imagesli lFormation Evaluation log -2"MD Gas ratio =2"MD Engineering Log-2"MD i(1l t li1 CD contains digital data of Final Log files/Final End of Well report/Final LAS exports/Halliburton LogViewer/EMF Ve er/EMF Log Viewer n 11 Please promptly sign, scan and return electronicallyto Sandra.D,Lemke000P,com 11 i CC: 2S-02 transmittal folder, production well files, eSearch Rec l ✓ - zek.. Z Date: ‘7111. 1 GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph:907265.6947 RECEWED 0 STATE OF ALASKA S AI;(; i p' 2rli ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 7 Gas❑ SPLUG u Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ ❑ WINJ Li WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Suspoi or OA 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. , Aband.: 7/2Q/2015 215-070 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 , 6/14/2015 50-103-20710-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3018'FNL, 1291'FEL, Sec. 17,T1ON, R8E, UM • 7/11/2015 KRU 2S-02 Top of Productive Interval: 9. KB(ft above MSL): •147.5' 17. Field/Pool(s): 2393'FNL, 1347'FEL, Sec.21,T1ON, R8E, UM GL(ft above MSL): 1120' Kuparuk River Field/Kuparuk River Oil Poo • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1875'FNL, 81'FWL,Sec. 15,T1ON, R8E, UM 18383'MD/6333'TVD ADL 25603, 25604 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481280 y- 5930030 Zone- 4 418410'MD/6330'TVD ALK 2677,2678 TPI: x- 486505 y- 5925364 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 487930 y- 5931159 Zone- 4 nipple @ 514'MD/513'TVD 1424'MD/1396'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) , not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 29' 109' 29' 109' 24" 450 sx AS 10.75" 45.5# L-80 28' 3644' 28' 2653' 13.5" 1513 sx Class G,206 sx Class G 7.625" 29.7# L-80 26' 11981' 26' 6276' 9.875" 501 sx Class G, 161 sx Class G 4.5" 11.6# L-80 11816' 18383' 6229' 6333' 6.75" slotted liner 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 11873' 11816'MD/6231'TVD slotted liner intervals: 12446'-14916'MD/6363'-6339'TVD and 15193'-16124' MD/6341'-6370'TVD and 16284'-17382'MD/6380'-6361'TVD and 17578'- 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 18339'MD/6366'-6336'TVD tr..4.,. 1,,.ie Was hydraulic fracturing used during completion? Yes❑ No U ie:'4 Per 20 AAC 25.283 0)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED • Iva none Lr-:---- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up ' Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -p Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate ,-lo- Form -pForm 10-407 Revised 5/2015 VT1- c'd ;,1 j S'-' CONTINUED ON PAGE 2 R DM AUG 2,15 Submit ORIGINIAL only 9/ �- 73 g`�3 5 L1 28. CORE DATA Conventional Cor Yes ❑ No 0 Sidewall Cores: I ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El Permafrost-Top 1424' 1396' If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed, and submit detailed test information, including reports,per 20 AAC 25.071. Top Kuparuk C4 12242' 6334' Kuparuk A5 12271' 6336' Kuparuk A4 12416' 6356' NONE Formation at total depth: Kuparuk A4 31. List of Attachments: Summary of Daily Operations,schematic,directional survey Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan @ 263-4180 Email: Mike.Callahan@cop.com Printed Name: Graham L.Alvord Title: Alaska Drilling Manager Signature: 4- at( Phone: 265-6120 Date: 6((7(20(15— INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • s Guhl, Meredith D (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, November 04, 2015 9:21 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-02, PTD 215-070, 10-407 issues Attachments: 2S-02_MudLog_18410ft_MD.PDF Meredith/Patricia, Here are the formation tops recorded from 2S-02. I have attached the mud log for all three hole sections. Schlumberger informed me that they sent over the neutron/density logs with the rest of the logs that were sent to you. If you still do not have a copy of those logs let me know and I will make sure they get re-sent. Again, I apologize for the delay in getting you this data. Please let me know if this covers what you need or if you would like any further information. Casing Shoes, Markers, Formation Tops and Faults (prognosed depths per wp08) Top/Marker MD actual TVD actual TVDSS 13-1/2"2S-02 Surface Section Base Permafrost 1,424' 1,396' -1,248' Top West Sak D 1,995' 1,889' -1,741' Base West Sak 3,312' 2,550' -2,402' 10 3/4"casing shoe 3,644' 2,653' -2,505' 9-7/8" 2S-02 Intermediate Section 0-80 4,507' 2,941' -2,793' C-37 9,155' 4,858' -4,710' Top Bermuda 10,609' 5,730' -5,582' Base Bermuda 10,723' 5,787' -5,639' Top HRZ(K-2) 11,295' 6,039' -5,891' U Kalubik (Base HRZ) 11,586' 6,153' -6,005' L Kalubik (K-1) 11,846' 6,239' -6,091' 7 5/8" casing shoe 11,982' 6,275' -6,127' 6-3/4" 2S-02 (A4 lateral updated based on Intermediate Actual Tops) Kup C - 12,248' 6,332' -6,184' A5 12,276' 6,337' -6,189' A4 12,421' 6,359' -6,211' Thank you for your patience. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 1 4 KUP PROD 2S-02 Ct)t�OcoP 1iiiipSB" Well Attributes Max Angle&MD TD Alaska Inc Ailoiliiii& Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blm(ftKB) clruoneonips' 501032071000 KUPARUK RIVER UNIT PROD 93.50 18,322.24 18,410.0 ••• Comment HTS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-02,7/22/201512:59;45 PM SSSV:NIPPLE Last WO: 27.50 7/20/2015 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:NEW WELL smsmith 7/21/2015 HANGER;25.0Casing Strings .._... .. ..... .. ....... ... .{ ._..._...._... Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I Grade Top Thread CONDUCTOR 16 15.250 29.0 109 0 109.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 103/4 9.950 28.2 3,644.0 2,652.9 45.50 L-80 HYD 563 -- ---- - .I ...Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread { 'gINTERMEDIATE 75/8 6.875 26.2 11,981.2 6,275.9 29.70 L80 Hyd563 j ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I_Grade Top Thread If SLOTTED LINER 41/2 3958 11,815.6 18,382.8 6,332.9 11.60 L-80 IBTM Liner Deta ii,SINN- 0. Nominal ID t it Tap(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,815.6 6,230.9 72.50 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 1 IF 11,835.5 6,236.9 72.96 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.767 11,838.3 6,237.7 73.03 HANGER DG FLEX-LOCK LINER HANGER 4.870 -AA/CONDUCTOR;29.0-109.0 - : 11,848.1 6,240.5 73.26 LOCATOR LOCATOR SUB 4.410 11,859.5 6,243.8 73.49 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 12,431.7 6,361.1 82.48 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 NIPPLE,513.8 - PACKER PACKER Tubing Strings Tubing Description 1St n9 Ma .IID(in) (Top(565) (Set Depth(k..f Set Depth(TVD)(...I Wt(Ib/Ft) (Grade (Top Connection I TUBINGL3 1/2 2.992 25 0 872 SI 6.247.4 9.30 L 80 EUE M Completion Details Nominal ID Tap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;28.2-3,844.0 I. 25.0 25.0 0.07 HANGER CAMERON TUBING HANGER 3.900 70.2 70.2 0.20 XO Reducing XO-31/2"EUE 8 RD(P)x41/2"IBT(B)5.220D Ser 3.000 @6 10511947 GAS LIFT;6,118.0 513.8 513.2 6.28 NIPPLE CAMCO DS NIPPLE 2.875 II 11,755.8 6,212.3 71.13 SLIDING BAKER CMU SLIDING SLEEVE W/DS NIPPLE- 2.810 SLEEVE CLOSED 11,780.2 6,220.1 71.69 NIPPLE CAMCO D NIPPLE 2.750 ( r 11,797.4 6,225.4 72.08 PLUG MIRAGE PLUG 2.962 11,8437 6,239.2 73.15 LOCATOR LOCATOR SUB 3.000 11,844.2 6,239.4 73.16 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;11,728.5 a- II Perforations&Slots Shot SLIDING SLEEVE;11,755.8 ' Dens Top(TVD) BM(TVD) (shotal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,446.4 14,916.3 6,363.0 6,339.1 7/16/2015 SLOTS Slotted Liner NIPPLE;11,780.2 15,193.1 16,124.3 6,341.4 6,370.2 7/16/2015 SLOTS Slotted Liner I 16,284.0 17,382.0 6,380.3 6,361.4 7/16/2015 SLOTS Slotted Liner 17,578.2 18,339.1 6,366.0 6,335.6 7/16/2015 SLOTS Slotted Liner PLUG;11,797.4UP Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Ser/ Type Type (in) (psi) Run Date Com 1 6,118.0 3,496.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 7/15/2015 2 11,726.5 6,202.7 CAMCO SO2- 1 1/2 GAS LIFT SV RKP 0.000 0,0 7/15/2015 1 II-1I. 30R Notes:General&Safety LOCATOR;11,843.7 End Date Annotation NOTE: d a .ante SEAL ASSY;11,844.1 I 1 Vii: r 4: INTERMEDIATE;262-11,9812 ,,,u j. ,,,, SLOTS;12,446.4-14,916.3 r -- SLOTS;15,193.1-16,124.3-= '- -i _ _ SLOTS;16,284.0-17,382.0-T.! ." SLOTS;17,578.2-18,339.1 SLOTTED LINER;11,815.6- 1 18,382.8 • • ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2S-02 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 6/12/2015 6:00:00 AM Rig Release: 7/20/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/30/2015 24 hr Summary Finish cleaning rig floor&cellar of OBM. Disconnect interconnects&prep for rig move to 2S-02 pad. Move pipe sheds&sub base from 1D-143&stage @ 2M pad. Move motor, boiler, pits&pump modules from 1D to 2B pad. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P PJSM,finish cleaning rig of OBM. 06:00 07:00 1.00 0 0 MIRU MOVE RURD P PJSM, prep rig for move. 07:00 09:00 2.00 0 0 MIRU MOVE RURD P PJSM, disconnect electrical, steam, water&air lines in all interconnects. Jack up pipe sheds. 09:00 11:30 2.50 0 0 MIRU MOVE DMOB P PJSM, split apart pipe sheds, power pack modules&stage on 1D to move. 11:30 12:00 0.50 0 MIRU MOVE DMOB P PJSM, prep to pull sub base off of well 1D-143. 12:00 19:00 7.00 0 0 MIRU MOVE MOB P PJSM, move sub base&pipe shed modules to 2M pad, staging for next modules. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P PJSM, return&hook up to motor, boiler, pits&pump modules. Move modules from 1D to 2B pad. 35/31/2015 Finish staging modules at 2B pad. Lay plywood on 2S access road. Spot sub base over 2S-02. Mate up all modules on 2S. Move rock washer, shop, &ROC from 1D to 2S pad. Hook up all interconnects. Continue moving all rolling stock from 1D to 2S. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P PJSM, move motor, boiler, pits& pump modules from 1D to 2B pad. SIMOPS lay plywood 2S access road from the Spine RD. 05:00 07:00 2.00 0 0 MIRU MOVE MOB P PJSM, move 1 pipe shed from 2M to 2S pad. 07:00 09:00 2.00 0 0 MIRU MOVE MOB P PJSM, move sub base from 2M to 2S pad. 09:00 13:00 4.00 0 0 MIRU MOVE MOB P PJSM, prep&spot sub base over 2S-02. 13:00 15:00 2.00 0 0 MIRU MOVE MOB P PJSM, lay mats&set pipe shed. 15:00 16:30 1.50 0 0 MIRU MOVE MOB P PJSM, move pits, pump, motor,& boiler modules from 2B to 2S pad. 16:30 19:00 2.50 0 0 MIRU MOVE MOB P PJSM, spot pits, pump, motor, & boiler modules. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P PJSM, move shop, rock washer,& ROC from 1D to 2S pad. SIMOPS hook up steam, air,water,& electrical. Hook up generator to the sub base. 06/01/2015 Finish moving rock washer, shop&ROC to 2S. Spot same modules. Finish rigging up&release the rig to rig maintenance @ 06:00 hrs. Page 1 of 40 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 00:00 06:00 6.00 0 0 MIRU MOVE MOB P PJSM, move shop, rock washer, & ROC to 2S pad. Spot same modules. Continue to hook up electrical to sub base. Continue berming around rig&ROC. Rig release @ 06:00 hrs. 36/12/2015 Accept rig from maintenance @ 0600 hrs NU starting head&diverter.Would not test. ND diverter.Weld up groove on conductor, NU diverter. Load pipe shed w/5"DP 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Set Cameron starting head-NU diverter spool-Set 20"Hydril-Install 16"diverter line(1 st section)Load BHA tools in pipe shed Accept rig from maintenance @ 0600 hrs 06:00 07:30 1.50 0 0 MIRU MOVE NUND P NU diverter line.Test diverter adapter seals to 500 psi.Would not test. 07:30 08:00 0.50 0 0 MIRU MOVE NUND T ND diverter. Frost relief groove on conductor not allowing seals to seal. 08:00 10:30 2.50 0 0 MIRU MOVE RURD P Load and strap 5" DP in pipeshed. 10:30 11:30 1.00 0 0 MIRU MOVE NUND T Weld up frost relief groove on conductor. 11:30 16:00 4.50 0 0 MIRU MOVE NUND P MU Diverter. Test diverter adapter seals to 500 psi/10 min's. Good. Install 4"valves on conductor. Install koomey hoses. Sim-ops-Load pipe shed w/5"DP. 16:00 18:00 2.00 0 0 MIRU MOVE RURD P Con't to load pipeshed w/5"DP. Sim-ops-Perform MP2's. Paint slips and handling tools. Clean rig. 06/13/2015 RU on floor to PU 5"-PU&std back 90 stds 5" DP(270 jts).Conduct pad evac drill. Load pipe shed w/126 jts 5" DP. PU 20 jts 5" HWDP+jars and 126 jts 5" DP. Clear rig floor. 00:00 03:15 3.25 0 0 MIRU MOVE RURD P PJSM-RU to pick up 5"DP- Change DP elevators 03:15 12:45 9.50 0 0 MIRU MOVE PULD P Pick up&std. back 90 stds. (270 jts)5"DP via mouse hole 12:45 13:15 0.50 0 0 MIRU MOVE SFTY P Pad evacuation drill 13:15 18:30 5.25 0 0 MIRU MOVE RURD P Load and strap pipe shed w/5" HWDP and 5"Dp. Sim-ops/Onload spud mud, remove kill line ell's and install new kill line. Calibrate and test gas monitoring sys. 18:30 23:30 5.00 0 0 MIRU MOVE PULD P Pick up&std. back 42 stds. (126 jts)5" DP and 7 stds(20 jts+jars) 5"HWDP via mouse hole.Total of 132 stds(396 jts)5" DP in derrick. 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Clear rig floor of thread protectors and bring lift subs to floor. 06/14/2015 PU&std back NMDC-function test diverter-Test mud line to 5000 psi-work on TD-Slip&cut DL-Fill hole&check for leaks-Held Pre spud with rig&third party personel-MU BHA. Clean out conductor to 109' MD. Drill to 177' MD. Trouble shoot TOTCO Rig Sense. Pick up flex collars. Drill to 641' MD 00:00 01:00 1.00 0 0 MIRU MOVE BHAH P PU (3)7 1/4" NMDC&std back in derrick Page 2 of 40 Time Logs • • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 0 0 MIRU MOVE BOPE P Perform diverter function test-Hydril closed in 28 sec. and knife valve opened in 4 secs. -Accumulator recovery test-System pressure 2900 psi-After closure 1900 psi- 200 psi in 44 secs. back to full charge ion 167 secs.-N2 bottles Average 2050 psi 02:30 03:30 1.00 0 0 MIRU MOVE SEQP P RU&pressure test mud line to 5000 psi-swivel packing leaking&2" Demco valve on stand pipe manifold 03:30 05:30 2.00 0 0 MIRU MOVE SEQP T PJSM-Change out swivel packing- Change out 2' Demco valve 05:30 06:15 0.75 0 0 MIRU MOVE SEQP T RU&Pressure test mud line to 5000 psi for 5 mins. (good test) 06:15 07:00 0.75 0 0 MIRU MOVE RGRP T Work on top drive shot pin 07:00 08:30 1.50 0 0 MIRU MOVE SLPC P PJSM-Slip&cut 78'drill line- Grease rig 08:30 10:00 1.50 0 0 MIRU MOVE RGRP T Change out shot pin on top drive 10:00 10:45 0.75 0 0 MIRU MOVE SEQP P Fill hole&check for leaks- Observed leak on knife valve-Repair leak 10:45 11:15 0.50 0 0 MIRU MOVE SFTY P Held pre-spud meeting with rig crew and third party personel 11:15 12:00 0.75 0 0 MIRU MOVE BHAH P PJSM-PU BHA components to rig floor 12:00 13:45 1.75 0 93 MIRU MOVE BHAH P MU BHA#1 as per SLB. Orient MWD. RIH and tag up @ 93' MD. 13:45 14:30 0.75 93 93 MIRU MOVE CIRC P Flood conductor and establish circulation.Trouble shoot Totco stroke counter. 14:30 14:45 0.25 93 109 MIRU MOVE DRLG P Clean out conductor f/93'MD t/109' MD ADT-.25 hrs=ART-.25 hrs . AST-0 hrs. -Footage- 16'- WOB 3-7 k RPM 70 GPM 450 @ 375 psi String wt PU 50 SO 52 ROT 50 Torque on/off btm.-1/0k Total bit hrs. .25 hrs. Total jar hrs. 0 hrs 14:45 15:45 1.00 109 177 SURFA( DRILL DDRL P Directional drill 13 1/2"hole w/motor f/109'MD t/177'MD 177'TVD ADT- 1.22 hrs=ART- 1.22 hrs. AST-0 hrs. -Footage-68'- WOB 3-7 k RPM 70 GPM 450 @ 375 psi String wt PU 50K SO 52K ROT 50K FO 82% Torque on/off btm.- 1/0K Total bit hrs. 1.47 hrs. Total jar hrs. 0 hrs 15:45 16:15 0.50 177 145 SURFA( DRILL SRVY P Perform inclination surveys @ 79' MD and 105' MD. Orient toolface to 145°. RIH to 145'MD. Page 3 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:00 0.75 145 145 SURFA( DRILL CIRC T Totco Rig Sense malfunctioning. Stroke counter, rotary torque and rpm not displaying. Consult with drilling engineer. Decision made to _ drill ahead. 17:00 17:30 0.50 145 177 SURFA( DRILL BHAH P Stand back one stand of HWDP. PU flex collars and saver sub. MU one stand HWDP 17:30 18:00 0.50 177 200 SURFA( DRILL DDRL P Directional drill 13 1/2"hole w/motor f/177' MD t/200'MD 200'TVD ADT-.43 hrs=ART-.43 hrs .AST- 0 hrs.-Footage-23'- WOB 5-7 k RPM 70 GPM 450 @ 375 psi String wt PU 52K SO 54K ROT 52K FO 80% Torque on/off btm.- 1/1K Total bit hrs. 1.9 hrs. Total jar hrs. 0 hrs 18:00 00:00 6.00 200 641 SURFA( DRILL DDRL P Directional drill 13 1/2"hole w/motor f/200' MD t/641'MD 640.7'TVD ADT-4.29 hrs ART-2.39 hrs .AST -1.90 hrs. Footage-441' WOB 5-7 k RPM 70 GPM 600 @ 875 psi String wt PU 66K SO 66K ROT 65K FO 81% Torque on/off btm.-2/1 K ECD=10.48 Max Gas=4 Total bit hrs.6.19 hrs. Total jar hrs. 0 hrs 06/15/2015 Drilled 13 1/2"hole w/motor f/641' t/2686'MD 2324'TVD 00:00 06:00 6.00 641 1,145 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/641' to 1145'MD 1134'TVD ADT-4.49 hrs.=AST.-2.67 hrs ART-1.82 hrs. ECD- 10.27 ppg Footage-504' WOB 15 k RPM 70 GPM 650 @ 1400 psi String wt. PU 81 SO 78 ROT. 80 Torque on/off btm. 2.4/2 k Max gas 8 units Total bit hrs. 10.68 hrs Total jar hrs. 4.49 hrs 06:00 12:00 6.00 1,145 1,641 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1145' to 1641'MD 1597'TVD ADT-4.61 hrs=AST- 1.76 hrs. ART-2.85 hrs ECD-10.61 ppg Footage-496' WOB-20 k RPM 70 GPM 650 @ 1575 psi String wt. PU 91 SO 85 ROT 87 Torque on/off btm.4/2 k Max gas 108 units. Total bit hrs. 15.29 hrs Total jar hrs. 9.10 hrs Page 4 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 1,641 2,195 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1641' t/2195' MD 2037'TVD ADT-3.31 hrs AST- 1.45 hrs. ART- 1.86 hrs ECD-10.37 ppg Footage-554' WOB-20-25 k RPM 70 GPM 700 @ 1750 psi String wt. PU 97 SO 87 ROT 91 Torque on/off btm.5/4 k Max gas 1172 units. Total bit hrs. 18.60 hrs Total jar hrs. 12.41 hrs 18:00 00:00 6.00 2,195 2,686 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2195' t/2686'MD 2324'TVD ADT-3.67 hrs AST-2.51 hrs. ART- 1.16 hrs ECD- 10.36 ppg Footage-491' WOB-20-25 k RPM 70 GPM 725 @ 1900 psi String wt. PU 110 SO 86 ROT 91 Torque on/off btm.6/7 k Max gas 575 units. Total bit hrs. 22.27 hrs Total jar hrs. 16.08 hrs 36/16/2015 Drill 13 1/2"surface hole section to TD @ 3654' MD. CBU x2. OWFF. Service rig. BROOH to HWDP @ 826' MD. Pump out of hole to 459' MD. 00:00 06:00 6.00 2,686 3,153 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2686' t/3153'MD 2500'TVD ADT-4.85 hrs AST-2.07 hrs. ART-2.78 hrs ECD-10.69 ppg Footage-467' WOB-20-25 k RPM 70 GPM 750 ©2300 psi String wt. PU 105 SO 81 ROT 91 Torque on/off btm. 7/6 k Max gas 952 units. Total bit hrs. 27.12 hrs Total jar hrs. 20.93 hrs 06:00 12:00 6.00 3,153 3,654 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/3153' MD t/3654'MD 2656'TVD ADT-4.52 hrs AST-.36 hrs. ART- 4.16 hrs ECD- 10.83 ppg Footage-501' WOB-20-25 k RPM 70 GPM 750 @ 2400 psi String wt. PU 105 SO 84 ROT 90 Torque on/off btm. 7/4 k Max gas 893 units. Total bit hrs. 31.64 hrs Total jar hrs. 25.45 hrs 12:00 13:45 1.75 3,654 3,528 SURFA( CASING CIRC P CBU x2. 750 gpm,2175 psi, 70 rpm, 2-3K tq, 79%FO. Stand back stand of DP on BUS. 13:45 14:15 0.50 3,528 3,528 SURFA( CASING OWFF P OWFF. Static 14:15 14:45 0.50 3,528 3,528 SURFA( CASING SVRG P Service rig. Page 5 of 40 •Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 23:00 8.25 3,528 826 SURFA( CASING BKRM P BROOH f/3528' MD t/826'MD. 700 gpm, ICP=2000 psi FCP=950 psi, 70 rpm,4-6K tq. FO 80%.Take check shot surveys @ 2079' MD& 1988' MD. 23:00 00:00 1.00 826 459 SURFA( CASING PMPO P Pump out of hole @ HWDP f/826' MD t/459'MD. 100 gpm, 150 psi. Calc disp=22.3 bbls Act disp=96.8 bbls 36/17/2015 Con't to pump out of hole to BHA. Lay down BHA. Rig up bail extensions and side door elevators. Make hanger dummy run. Rig up casing equip. Run 10 3/4"csg to 200'MD.Work on flow show. Run 10 3/4"csg to 886'MD.Work tight hole from 886' MD to 1016'MD. Run 10 3/4"csg to 1476'MD. 00:00 01:00 1.00 459 149 SURFA( CASING PMPO P Pump out of hole f/459' MD t/149' MD.2 bpm, 100 psi, Calc disp=11.7 bbls Act disp=19.5 bbls 01:00 03:15 2.25 149 0 SURFA( CASING BHAH P Monitor well. Stand back flex NMDC's. Lay down BHA. 03:15 04:15 1.00 0 0 SURFA( CASING BHAH P Clean and clear rig floor. Flush out diverter. 04:15 05:15 1.00 0 0 SURFA( CASING RURD P Picke up and rig up csg. equip.lnstall bail extensions and side door elevators. 05:15 06:15 1.00 0 0 SURFA( CASING RURD P MU hanger to landing jt. Perform hanger dummy run. Lay down hanger on rig floor. 06:15 07:45 1.50 0 0 SURFA( CASING RURD P Make up Volant CRT. Set spiders. 07:45 09:45 2.00 0 200 SURFA( CASING PUTB P Run 10 3/4",45.5#, L-80, HYD 563 casing to 200'MD. 09:45 10:45 1.00 200 200 SURFA( CASING SVRG P Trouble shoot and repair flow show. 10:45 13:30 2.75 200 886 SURFA( CASING PUTB P Run 10 3/4",45.5#, L-80, HYD 563 casing to 886' MD. 13:30 23:00 9.50 886 1,016 SURFA( CASING PUTB T Tag up @ 886' MD.Work pipe w/varying parameters f/886' MD t/1016'MD. Pump from 2 bpm to 5 bpm. Rot from10 rpm to 20 rpm. Reciprocate f/3'strokes to 20' strokes. Set down weight from 10K to 50K. 23:00 00:00 1.00 1,016 1,476 SURFA( CASING PUTB P Run 10 3/4",45.5#, L-80, HYD 563 casing f/1016' MD t/1476' MD. Calc disp=21 bbls Act disp=21 bbls. SO=66K 36/18/2015 Con't to run 10 3/4"csg to 1550'MD.Work tight hole to 1575'MD. CBU.Wash and work csg.to 1732'MD. Run 10 3/4"csg to 3613' MD. MU hanger and landing jt. Land csg @ 3644'MD Circ and cond mud. Perform _ surface cmt job. Flush diverter and flowline. Rig down cmt and csg equip. ND diverter. 00:00 00:30 0.50 1,476 1,550 SURFA( CASING PUTB P Run 10 3/4", 45.5#, L-80, HYD 563 casing f/1476' MD t/1550' MD. 00:30 01:30 1.00 1,550 1,575 SURFA( CASING PUTB T Tag up @ 1550' MD.Work pipe w/varying parameters f/1550'MD t/1575' MD. Pump from 2 bpm to 7 bpm. Rot from10 rpm to 20 rpm. Reciprocate f/3'strokes to 20' strokes. Set down weight from 10K to 50K. Page 6 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 1,575 1,575 SURFA( CASING CIRC T CBU. Stage up pump to 7 bpm. Hole unloaded w/slight pack off. 02:30 04:30 2.00 1,575 1,735 SURFA( CASING PUTB T Pump in the hole working pipe down (/1575'MD t/1735' MD.2-5 bpm. 04:30 10:30 6.00 1,735 3,644 SURFA( CASING PUTB P Run 10 3/4",45.5#, L-80, HYD 563 casing (/1735'MD t/3613" MD. Make up hanger and landing jt. Land csg. @ 3644' MD. Ran 86 jts of 10 3/4"45.5#Hyd 563 csg.2 stop rings and 86 bowstring centralizers. Calc disp=39.2 bbls Act disp=39 bbls 10:30 13:00 2.50 3,644 3,644 SURFA( CEMEN-CIRC P Break circulation. @ 2 bpm, 300 psi. Circ and cond mud for cement job. Stage rate up to 6 bpm, 250 psi. 13:00 13:30 0.50 3,644 3,644 SURFA( CEMEN-RURD P Rig up lines and valves to cement swivel. 13:30 13:45 0.25 3,644 3,644 SURFA( CEMEN'CIRC P Circ and condition mud.6.5 bpm 300 psi. Sim-ops/PJSM on cement job. 13:45 18:30 4.75 3,644 3,644 SURFA( CEMEN-CMNT P Batch up as per SLB. Pump 5 bbls of water, pressure test lines to 3500 psi. Pumping 100 bbls of CW100 followed by 100 bbls of 10.5 ppg Mud Push II. Shut down,drop bottom plug, SLB pumped 515 bbls of 11.0 ppg LiteCRETE and 59 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 9.8 ppg mud @ 7 bpm=650 psi. Slowed pumps to 3 bpm, bumped plug @ 3302 stokes, pressure up to 500 psi over FCP=1100 psi. Hold for 5 min, bleed off and check floats, good. Observed full returns while performing cement job. 112 bbls of cement returns to surface. Reciprocated pipe 20' until after dropping top plug. CIP @ 18:15 hrs. 18:30 18:45 0.25 3,644 3,466 SURFA( CEMEN-OWFFP OWFF. Sim-ops/PJSM on rigging down cmt and csg equip. 18:45 20:15 1.50 3,466 0 SURFA( CEMEN RURD P Flush stack and flow line. Rig down circ hoses and equip. Rig down Volant CRT and lay down landing jt. 20:15 21:00 0.75 0 0 SURFA( CEMEN RURD P Clear rig floor. Lay down rig tongs, 350t slips and Volant CRT. 21:00 00:00 3.00 0 SURFA( CEMEN NUND P Nippple down diverter system. Top of cement 20"down in conductor. 06/19/2015 ND diverter. NU wellhead and BOPE. 00:00 01:15 1.25 0 0 SURFA( CEMEN NUND P Nipple down diverter system. 01:15 03:00 1.75 0 0 SURFA( WHDBO NUND P Nipple up Cameron 11"5000#Type MBS wellhead.Test seals to 5000 psi/10 min. Page 7 of 40 Time Logs * • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:00 00:00 21.00 0 0 SURFA(WHDBO NUND P Nipple up BOPE. MU new choke hose and torque flanges,MU upper pipe rams to blind rams, blind rams to mud cross and lower rams. Install koomey lines. Install RCD air valve. MU adapter flange. Install kill hose. Sim-ops/Take on LSND mud, inspect mud pumps,Top drive MP2. 36/20/2015 NU BOPE.Test BOPE.Test RCD. MU 9 7/8"rotary steerable BHA to 736' MD. 00:00 01:00 1.00 0 0 SURFA(WHDBO NUND P Nipple up kill and choke hoses. 01:00 03:00 2.00 0 0 SURFA(WHDBO MPDA T Change out MPD air actuated valve 03:00 05:00 2.00 0 0 SURFA(WHDBO MPDA T Rig up scaffold in cellar. 05:00 06:45 1.75 0 0 SURFA( WHDBO RURD P Torque up bolts on MPD air actuated valve. Prep to test BOPE. 06:45 10:15 3.50 0 0 SURFA( WHDBO BOPE T Attempt to test BOPE. Choke line flange, mud cross flange,well head gland nut and test port leaking. Retorqe and tighten. Blind ram door seal leaked. Change seal. 10:15 15:15 5.00 0 0 SURFA( WHDBO BOPE P PJSM, 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 4"kill Demco valvel. Test#2: Upper IBOP, manual kill, CV 9, and 11 (Kill HCR failed). 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, Test# 7: Manual choke valve. Test#8: Annular preventer tested to 250/2500 psi.Test#9: Lower pipe rams.Test# 10: Blind rams and CV 3. Retest kill HCR. Pass.Accumulator test: system pressure=3000 psi,After closing= 1800 psi, 200 psi attained after 42 sec, full pressure attained after 167 sec, Five bottle nitrogen avg=2150 psi. The BOP test was witnessed by Chuck Sheve AOGCC. 15:15 16:30 1.25 0 0 SURFA( WHDBO RURD P RD test equip. Blow down choke. Set wear ring. 16:30 18:15 1.75 0 0 SURFA( CEMEN-MPDA P RU to test RCD. Pull wear ring. Set test plug. 18:15 18:45 0.50 0 SURFA( CEMEN-SVRG P Service rig. Replace hydraulic hose on top drive. 18:45 19:45 1.00 0 0 SURFA( CEMEN-MPDA P RU to test RCD. Pull trip nipple,trip nipple adapter. Set RCD test cap and purge lines. 19:45 20:15 0.50 0 0 SURFA( CEMEN-MPDA P Test RCD to 250 psi/5 min, 1700 psi/10 min 20:15 21:15 1.00 0 0 SURFA( CEMEN-MPDA P RD RCD test plug. Install trip nipple adapter, set trip nipple. Pull test plug. Set 10" ID wear ring. 21:15 21:45 0.50 0 0 SURFA( CEMEN BHAH P Mobilize BHA tools to rig floor. Page 8 of 40 Time Logs110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 0 736 SURFA( CEMEN-BHAH P MU 9 7/8"rotary steerable BHA as per SLB to 736' MD. 36/21/2015 RIH to 1666' MD. Shallow hole test MWD. RIH to 3535'MD. Circ and cond mud. Test casing to 3500 psi.Rig up and test MPD choke skid and lines Install RCD element. Test RCD and MPD choke skid. Install trip nipple. Service rig. Drill out shoe track and 20' new hole. Circ and cond aired up mud.Attempt to displace to 9.6 PPG LSND mud, Drill string plugged. OWFF. POOH to 1295' MD.Attempt to circ. Unsuccessful. POOH to 736' MD. OWFF. POOH to 552' MD 00:00 00:30 0.50 736 1,666 SURFA( CEMEN-TRIP P RIH f/736'MD t/1666'MD. 00:30 01:00 0.50 1,666 1,666 SURFA( CEMEN DHEQ P Perform shallow hole pulse test.450 gpm, 900 psi, 25 rpm,1-2Ktq. 01:00 02:00 1.00 1,666 3,535 SURFA( CEMEN-TRIP P RIH f/1666'MD t/3535'MD. Calc disp=36.5 bbls Act disp=32.2 bbls 02:00 02:30 0.50 3,535 3,535 SURFA( CEMEN CIRC P Circ and cond mud. 500 gpm, 1500 psi,60 rpm 4-9K tq. 02:30 03:30 1.00 3,535 3,535 SURFA( CEMEN PRTS P Rig up and test casing to 3500 psi/30 min on chart. Rig down test equip. 03:30 06:15 2.75 3,535 3,535 SURFA( CEMEN MPDA P RU Safekick MPD equip and test choke manifold and lines as per Safekick rep. 250 psi/5 min low-1700 psi/10 min high test. 06:15 07:15 1.00 3,535 3,535 SURFA( CEMEN MPDA P Pull trip nipple and adapter. Install RCD bearing. 07:15 09:30 2.25 3,535 3,535 SURFA( CEMEN-MPDA P Test MPD valves and lines w/RCD bearing installed 250 psi/5 min low- 650 psi/10 min high. Flush and blow down MPD choke manifold and lines. 09:30 10:15 0.75 3,535 3,535 SURFA( CEMEN MPDA P Install Katch Kan spill containment on annular preventer. 10:15 11:30 1.25 3,535 3,535 SURFA( CEMEN MPDA P Pull RCD bearing. Install adapter and trip nipple. Remove MPD return line. 11:30 12:15 0.75 3,535 3,535 SURFA( CEMEN SVRG P Service rig 12:15 17:30 5.25 3,535 3,654 SURFA( CEMEN DRLG P Obtain SPR's. Establish drlg parameters,tag cmt plugs©3560' MD. Drlg float collar, shoe track. Clean out rat hole.650 gpm, 1950 psi, 80 rpm,erratic torque @ 4-12K, FO 48%. SPR @ 3535' MD, 2618'TVD, MW 9.7 ppg, 12:15 hrs. #1 @ 30=70 @ 40=130 #2 @ 30=60 @ 40=130 17:30 17:45 0.25 3,654 3,674 SURFA( CEMEN-DDRL P DDrill new hole f/3654'MD t/3674' MD, 2663'TVD, ADT.21 hrs, BIT .21 hrs, JARS 25.67 hrs, PU 117K, SO 70K, ROT 89K, TQ on 5-10K,off 4-10K, ECD 10.36, FO 35%,WOB 3-7K, 80 rpm, 650 gpm,2050 psi. 17:45 18:00 0.25 3,674 3,628 SURFA( CEMEN-REAM P Back ream f/3674'MD t/3644'MD. Stand back stand of DP. 18:00 19:15 1.25 3,628 3,674 SURFA( CEMEN-CIRC T CBU @ 650 gpm,2050 psi. Lost 500 psi of pump pressure due to mud being aired up.Attempt to condition aired up mud. Decision made to displace to 9.6 ppg LSND. Page 9 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:15 1.00 3,674 3,628 SURFA( CEMEN-DISP T Displace 9.7 ppg spud mud with 9.6 ppg LSND mud. 650 gpm, 1550 psi, 80 rpm,4-10K tq, FO 32%.Attempt to work air out of pumps. Pump 24 bbl hi-vis spacer followed by 110 bbls of 9.6 ppg LSND. Pump pressure rapidly increased to 3500 psi. Shut down pumps, pressure held. Bleed pressure to zero. Pull into casing while rotating. Confirm pipe is free. Pressured up 3x to 1200 psi and surge pipe. Pump through bleed line to confirm surface circulation ability. Rack back one stand and blow through TD to confirm standpipe and TD were clear. Consult w/drilling engineer. Decision made to POOH. 20:15 20:45 0.50 3,628 3,628 SURFA( CEMEN-OWFF T OWFF. Static. Sim-ops/PJSM for POOH 20:45 23:15 2.50 3,628 736 SURFA( CEMEN-TRIPT POOH f/3628' MD t/1295' MD. Attempt to circulate. Pump at 2 bpm. Pressured up to 1000 psi and held. Con't to POOH t/736' MD. 23:15 23:45 0.50 736 736 SURFA( CEMEN-OWFF T OWFF. Static. 23:45 00:00 0.25 736 552 SURFA( CEMEN'TRIP T POOH. Rack back 8 jts HWDP and jars. Calc disp=28.2 bbls Act disp=30.6 bbls. 06/22/2015 Con't POOH. Change out MWD. Clean pits and flush lines. RIH t/1573' MD. Shallow pulse test MWD. RIH to TD @ 3674' MD. CBU. Perform FIT. Displace to 9.6 ppg LSND mud w/drilling ahead 9 7/8"intermediate hole section f/3674' MD t/4651' MD. Trouble shoot Power Drive RSS steering problem. Drill f/4651' MD t/5029'MD 00:00 02:00 2.00 552 0 SURFA( CEMEN-BHAH T Stand back 3 stands HWDP, flex collars and LD float subs. Remove nuclear sources. Lay down MWD. Break off bit. One nozzle on bit plugged. MWD not draining. 02:00 03:00 1.00 0 276 SURFA( CEMEN BHAH T Change out MWD, MU bit, install nuclear sources, RIH w/flex collars and one stand HWDP 03:00 06:45 3.75 276 276 SURFA( CEMEN'OTHR T Clean out from under shale shakers. Clean pit#5 and trip tank. Flush surface lines. 06:45 07:15 0.50 276 1,573 SURFA( CEMEN-TRIP T RIH f/276' MD t/1573'MD. Calc disp=8.02 bbls Act disp=10.71 bbls 07:15 07:30 0.25 1,573 1,573 SURFA( CEMEN-DHEQ T Shallow hole pulse test MWD.450 gpm, 800 psi. FO 30% 07:30 08:30 1.00 1,573 3,650 SURFA( CEMEN-TRIPT RIH f/1573'MD t/3650'MD. Calc disp=32.68 bbls Act disp=30.21 bbls. 08:30 08:45 0.25 3,650 3,674 SURFA( CEMEN REAM T Wash and ream(/3650'MD t/3674' MD.650 gpm, 1900 psi, FO 36%, 80 rpm, Tq 4-9K. 08:45 09:00 0.25 3,674 3,674 SURFA( CEMEN-CIRCT CBU.600 gpm, 1900 psi, FO 36%, 80 rpm, Tq 4-9K. PU 115K SO 70K ROT 89K 09:00 09:15 0.25 3,674 3,625 SURFA( CEMEN-TRIPT POOH f/3674' MD t/3625'MD. Page 10 of 40 4110 Time Logs Date From To Dur S.DepthE. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 3,625 3,625 SURFA( CEMEN"RURD P RU to perform FIT. 09:30 09:45 0.25 3,625 3,625 SURFA( CEMEN.FIT P Perform FIT to 16 ppg EMW. 09:45 10:00 0.25 3,625 3,625 INTRM1 DRILL RURD P RD test equipment and blow down kill line. 10:00 10:30 0.50 3,625 3,674 INTRM1 DRILL WASH P PJSM-Prep for displacing to 9.6 ppg LSND.Wash down f/3625'MD t/3674' MD while pumping spacer pill. 6 bpm, 300 psi, FO 20%. 10:30 12:00 1.50 3,674 3,772 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3674' t/3772' MD 2695'TVD ADT-.90 hrs ECD- 10.36 ppg Footage-98' WOB-5-10-k RPM 80 GPM 650 @ 1325 psi String wt. PU 117 SO 70 ROT 89 Torque on/off btm.7/6 k Total bit hrs. 1.32 hrs Total jar hrs. 26.78 hrs Displace to 9.6 ppg LSND w/drilling SPR @ 3720' MD, 2655'TVD, MW 9.6 ppg, 11:45 hrs. #1 ©30=80 @ 40=140 #2 @ 30=80 @ 40=120 12:00 18:30 6.50 3,772 4,651 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3772' t/4651'MD 3008'TVD ADT-4.50 hrs ECD- 11.12 ppg Footage-929' WOB- 15-18K RPM 90-140 GPM 700 @ 1775 psi String wt. PU 113K SO 82K ROT 91K Torque on/off btm. 9/5K Max gas=143 units Total bit hrs. 5.82 hrs Total jar hrs. 31.29 hrs 18:30 19:45 1.25 4,651 4,651 INTRM1 DRILL CIRC T Trouble shoot Power Drive RSS steering problem. Consult w/town engineers. Pump nut plug/SAPP sweep. 19:45 00:00 4.25 4,651 5,029 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4651' t/5029'MD 3170'TVD ADT-2.45 hrs ECD- 11.19 ppg Footage-378' WOB-8-14K RPM 140 GPM 725 @ 2050 psi String wt. PU 123K SO 81K ROT 95K Torque on/off btm. 8/5K Total bit hrs. 8.27 hrs Total jar hrs. 33.73 hrs Max gas=184 units SPR @ 4982' MD, 3156'TVD, MW 9.6 ppg, 23:30 hrs. #1 @ 30=150 @ 40=200 #2 @ 30=150 @ 40=190 Page 11 of 40 Time Logs • • Date From To Dur S. Depth E.Depth Phase Code Subcode T . Comment 06/23/2015 24 hr Summary Directional drill intermediate hole section f/5029'-6600'MD. Rig generators shut down due to overheating,with warm weather. Continue to drill form 6600'-7243'MD, 3855'TVD.Total footage 2214'. 00:00 06:00 6.00 5,029 5,868 INTRM1 DRILL DDRL P DDrilled f/5029'-5868'MD, 3423' TVD,ADT 4.01, BIT 12.28,JARS 37.74,Total Footage 840', PU 131K, SO 78K, ROT 98K, Tq on 8-10K,off 4-5K, ECD 12.31, FO 31%,WOB 10-12K, 140-120 rpm, 725 gpm,2423 psi, Max Gas 161. 06:00 12:00 6.00 5,868 6,410 INTRM1 DRILL DDRL P DDrilled f/5868'-6410'MD, 3581' TVD,ADT 4.03, BIT 16.31, JARS 41.77,Total Footage 542', PU 124K, SO 90K, ROT 104K,Tq on 8-10K, off 4-5K, ECD 12.4, FO 30%,WOB 10-12K, 120 rpm, 725 gpm, 2565 psi, Max Gas 97. SPR @ 6335'MD, 3558'TVD, MW 9.6 ppg, 11:00 hrs. #1 @ 30=240 @ 40=300 #2 @ 30=240©40=320 Kick w/Drilling CRT=58 sec @ 07:08 hrs. 12:00 14:30 2.50 6,410 6,600 INTRM1 DRILL DDRL P DDrilled f/6410'-6600'MD, 3626' TVD,ADT 2.34, BIT 18.65, JARS 44.11,Total Footage 190', PU 124K, SO 87K, ROT 100K,Tq on 6-9K, off 3-4K, ECD 12.79, FO 28%,WOB 10-17K, 140 rpm, 725 gpm, 2700 psi, Max Gas 62. 14:30 17:00 2.50 6,600 6,600 INTRM1 DRILL RGRP T PJSM, Generator motor#3 shut down due to overheating. Put #1 generator on line,with generator#2 shutting down,with same issue. Trouble shoot generators. Find with warm weather not enough cool air flow into motor room. Mobilize fans from yard to increase air flow. SIMOPS C/O swab in#1 MP&CBU 2X to lower high ECD, 350 gpm,825 psi,40 rpm, Tq 4-5K, FO 10%. 17:00 18:00 1.00 6,600 6,685 INTRM1 DRILL DDRL P DDrilled f/6600'-6685'MD, 3671' TVD,ADT.68, BIT 19.33,JARS 44.79, Total Footage 85', PU 130K, SO 94K, ROT 105K, Tq on 5-10K, off 3-5K, ECD 11.93, FO 30%,WOB 10-11K, 140 rpm, 720 gpm, 2675 psi, Max Gas 56. Page 12 of 40 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 6,685 7,243 INTRM1 DRILL DDRL P DDrilled f/6685'-7243'MD, 3855' TVD,ADT 4.28, BIT 23.61, JARS 49.07,Total Footage 558', PU 131K, SO 93K, ROT 107K,Tq on 9K, off 4K, ECD 12.12, FO 27%,WOB 9-14K, 140 rpm, 720 gpm,2775 psi, Max Gas 99. SPR @ 7191'MD, 3830'TVD, MW 9.6 ppg, 23:10 hrs. #1 @ 30=230 @ 40=290 #2©30=220 @ 40=290 Kick w/Drilling CRT=100 sec @ 20:00 hrs. 36/24/2015 Directional drill intermediate hole section f/7243'-7960' MD. C/O seat on MP 2. Continue to drill form 7960'-8362' MD. SCR 2 breaker tripped&could not reset. Change out breaker.Continue to drill form 8362'-8755' MD. Hole packed off @ 8755'MD.TOH to 8568'to establish circulation. Stage up to full rate. Observe losses, reduce rate, mix&pump LCM pill. Total footage 1512'. 00:00 06:00 6.00 7,243 7,822 INTRM1 DRILL DDRL P DDrilled f/7243'-7822'MD,4098' TVD,ADT 4.40, BIT 28.01, JARS 53.47, Total Footage 579', PU 135K, SO 96K, ROT 115K, Tq on 10K, off 4-6K, ECD 12.2, FO 28%,WOB 6-10K, 140 rpm, 723 gpm,2710 psi, Max Gas 101. Fire Drill CRT=87 sec @ 05:45 hrs. 06:00 07:30 1.50 7,822 7,960 INTRM1 DRILL DDRL P DDrilled f/7822'-7960'MD, 4172' TVD,ADT 1.01, BIT 29.02, JARS 54.48,Total Footage 138', PU 135K, SO 96K, ROT 115K,Tq on 10K, off 4-6K, ECD 12.2, FO 28%,WOB 6-10K, 140 rpm, 723 gpm, 2710 psi, Max Gas 101. 07:30 08:30 1.00 7,960 7,960 INTRMI DRILL SVRG P Lubricate rig, SIMOPS circulate @ 453 gpm, 1300 psi,40 rpm, Tq 5-6K, while changing seat on MP#2. 08:30 09:00 0.50 7,960 7,960 INTRM1 DRILL RGRP T Finish changing seat on#2 MP. 09:00 13:00 4.00 7,960 8,362 INTRM1 DRILL DDRL P DDrilled f/7960'-8362' MD,4405' TVD,ADT3.0, BIT 32.02,JARS 57.48,Total Footage 402', PU 150K, SO 100K, ROT 121K, Tq on 11K, off 2-12K, ECD 11.9, FO 27%,WOB 3-6K, 140 rpm, 723 gpm,2950 psi, Max Gas 132. SPR©8179'MD,4304'TVD, MW 9.7++ppg, 11:30 hrs. #1 @ 30=260 @ 40=350 #2 @ 30=280 @ 40=330 13:00 14:00 1.00 8,362 8,107 INTRM1 DRILL BKRM T SCR#2 breaker tripped&could not be reset, needed to be changed out. Backream f/8362'-8107'MD,360 gpm, 1000 psi, 100 rpm. 14:00 14:15 0.25 8,107 8,107 INTRM1 DRILL OWFF T Monitor well, static. 14:15 15:00 0.75 8,107 8,107 INTRMI DRILL RGRP T PJSM, change out SCR breaker. 15:00 15:30 0.50 8,107 8,362 INTRM1 DRILL TRIP T PJSM, TIH f/8107'-8362'MD. Page 13 of 40 Time Logs 411 4111 Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:30 19:45 4.25 8,362 8,755 INTRM1 DRILL DDRL P DDrilled f/8362'-8755' MD,4628' TVD,ADT 3.1, BIT 35.12,JARS 60.58,Total Footage 393', PU 151K, SO 110K, ROT 117K, Tq on 11K, off 5K, ECD 12.15, FO 28%,WOB 11-17K, 140 rpm, 723 gpm, 3175 psi, Max Gas 80. 19:45 22:00 2.25 8,755 8,568 INTRM1 DRILL CIRC T While backreaming a stand,due to high ECD,observe pack off at 8662' MD. TOH f/8662'-8568'MD,40 rpm, .5 bpm to establish circulation. Stage up pumps f/.5-700 gpm, 400-3075 psi,40-120 rpm,Tq 8K. 22:00 23:00 1.00 8,568 8,755 INTRM1 DRILL CIRC T CBU @ 700 gpm, 3075 psi, 120 rpm, Tq 8K. Stage up pump to 725 gpm, 3225 psi, 140 rpm, Tq 8K, observe losses at 90 bph. Reduce rate to 600 gpm&losses @ 60 bph. Ream in hole to 8755' MD, reduce rate to 525 gpm, 1900 psi, 140 gpm,Tq 8K, to mix LCM pill. 23:00 00:00 1.00 8,755 8,755 INTRM1 DRILL CIRC T Pump 25 bbls, LCM pill 30 ppb, 150 vis,surface to surface. Losses still at 60 bph. Decide to mix another LCM pill. 06/25/2015 Observe losses from previous LCM pill. Mix&pump 2nd LCM pill,w/losses decreasing to—35 bph. DDrill f/ 8755'-8847' MD. Pump LCM sweep. Install MPD bearing. DDrill f/8847'-9190' MD. Observe minor pack off. BROOH 2 stands. OWFF,wellbore breathing. Ream back to bottom.Control drill f/9190'-9488' MD. Observe pit gain. Confirm breathing utilizing MPD equipment. DDrill f/9488'-9630'MD. Total footage 875". 00:00 01:30 1.50 8,755 8,755 INTRM1 DRILL CIRC T PJSM, observe losses at 63 bph, @ 525 gpm, 1820 psi, FO 14%, 90 rpm, Tq 8K. Decide to mix another LCM pill. SPR @ 8754' MD, 4627'TVD, MW 10.0 ppg, 00:13 hrs. #1 @ 30=280 @ 40=360 #2 @ 30=280 @ 40=340 01:30 03:15 1.75 8,755 8,755 INTRM1 DRILL CIRC T Pump 26 bbl, 30 ppb nut plug pill @ 525 gpm, 1820 psi, FO 14%, 120 rpm. Observe losses decrease to 35 bph. 03:15 04:45 1.50 8,755 8,847 INTRM1 DRILL DDRL P DDrilled f/8755'-8847'MD,4680' TVD,ADT 1.5, BIT 36.42,JARS 61.88, Total Footage 92', PU 155K, SO 110K, ROT 125K, Tq on 11K, off 8-12K, ECD 11.21, FO 28%,WOB 5-10K, 120 rpm, 600 gpm, 2300 psi, Max Gas 164. 04:45 06:00 1.25 8,847 8,847 INTRM1 DRILL CIRC T Pump 27 bbl, 30 ppb nut plug pill surface to surface @ 600 gpm,2300 psi, FO 28%, 120 rpm. Bring on new mud to the pits. 06:00 07:30 1.50 8,847 8,847 INTRM1 DRILL OWFF P Monitor well,establish wellbore breathing. Rotate @ 15 rpm, Tq 10K. Page 14 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:45 1.25 8,847 8,847 INTRM1 DRILL MPDA P PJSM,drain stack&monitor well through annulus. Pull riser&boot adapter flange. Install MPD bearing. Hook up MPD return line&line up all valves. 08:45 09:00 0.25 8,847 8,847 INTRM1 DRILL MPDA P Circulate through MPD equipment @ 525 gpm, 1800 psi, FO 42%. Break in MPD bearing @ 30&50 rpm for 5 _ min each. 09:00 12:45 3.75 8,847 9,190 INTRM1 DRILL DDRL P DDrilled f/8847'-9190' MD,4962' TVD,ADT 2.94, BIT 39.36, JARS 64.82,Total Footage 343', PU 172K, SO 110K, ROT 125K,Tq on 13K, off 8-15K, ECD 11.45, FO 50%,WOB 5-10K, 120 rpm, 600 gpm,2400 psi, Max Gas 1360. Total losses till 12:00 hrs 223 bbls. 12:45 13:00 0.25 9,190 9,190 INTRM1 DRILL CIRC T Observe indications of hole packing off while drilling. Pick up off bottom& reduce rates to 300 gpm, 900 psi, 80 rpm, Tq 10K. Initial loss rate 90 bph. Table Top Man Down Drill @ 13:00 hrs. 13:00 13:45 0.75 9,190 9,039 INTRM1 DRILL BKRM T PJSM, BROOH f/9190'-9039'MD, 300 gpm, 900 psi, 80 rpm,Tq 10K, FO 12%. 13:45 14:45 1.00 9,039 9,039 INTRM1 DRILL OWFF T Monitor well, verify wellbore breathing. 14:45 15:15 0.50 9,039 9,039 INTRM1 DRILL CIRC T Establish loss rate at 600 gpm,2300 psi,20 rpm, Tq 11K, FO 52%, loss rate 36-40 bph. Decision made to drill ahead at slower ROP. 15:15 15:45 0.50 9,039 9,190 INTRM1 DRILL REAM T PJSM, ream to bottom 9093'-9190' MD, 575 gpm, 1900 psi, 90 rpm,Tq 8K, FO 22%. 15:45 20:45 5.00 9,190 9,488 INTRM1 DRILL DDRL P DDrilled f/9190'-9488'MD, 5062' TVD,ADT 3.78, BIT 42.93, JARS 68.60,Total Footage 298', PU 180K, SO 112K, ROT 129K, Tq on 13-15K, off 10-16K, ECD 11.27, FO 58%, WOB 5-6K, 120 rpm, 600 gpm, 2400 psi, Max Gas 228. SPR @ 9410' MD, 5013'TVD, MW 10.0 ppg, 19:15 hrs. #1 @ 30=280 @ 40=360 #2 @ 30=280 @ 40=380 20:45 21:15 0.50 9,488 9,488 INTRM1 DRILL OWFF T Observed pit gain. Utilize MPD chokes to determine wellbore breathing. 21:15 00:00 2.75 9,488 9,630 INTRM1 DRILL DDRL P DDrilled f/9488'-9630'MD, 5149' TVD,ADT 1.74, BIT 44.88, JARS 70.34,Total Footage 142', PU 182K, SO 115K, ROT 131K,Tq on 14-16K, off 6-12K, ECD 11.23, FO 53%, WOB 7-12K, 120 rpm,600 gpm, 2400 psi, Max Gas 284. Losses for tour 55 bbls. Page 15 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/26/2015 24 hr Summary Directional drill intermediate hole section f/9630'-11365' MD, 6067'TVD. Total footage 1735'. 00:00 06:00 6.00 9,630 10,125 INTRM1 DRILL DDRL P DDrilled f/9630'-10125'MD, 5450' TVD,ADT 5.13, BIT 50.01, JARS 75.47,Total Footage 495', PU 190K, SO 117K, ROT 142K, Tq on 15K, off 13K, ECD 11.4, FO 52%,WOB 7-10K, 120 rpm, 600 gpm,2450 psi, Max Gas 151. 06:00 12:00 6.00 10,125 10,553 INTRM1 DRILL DDRL P DDrilled f/10125'-10553' MD, 5700' TVD,ADT 4.62, BIT 54.63,JARS 80.09, Total Footage 428', PU 215K, SO 115K, ROT 150K, Tq on 16K,off 11K, ECD 11.41, FO 55%,WOB 6-12K, 120 rpm, 600 gpm,2420 psi, Max Gas 686. SPR @ 10529' MD, 5685'TVD, MW 10.0 ppg, 11:30 hrs. #1 @ 30=300 @ 40=390 #2 @ 30=310 @ 40=390 Total losses for tour 23 bbls. 12:00 18:00 6.00 10,553 11,020 INTRM1 DRILL DDRL P DDrilled f/10553'-11020' MD, 5924' TVD,ADT 4.72, BIT 59.35,JARS 84.81, Total Footage 467', PU 220K, SO 120K, ROT 147K, Tq on 16-17K, off 12-13K, ECD 11.31, FO 54%, WOB 7-9K, 130 rpm, 600 gpm,2525 psi, Max Gas 604. SPR @ 11020' MD, 5924'TVD, MW 10.0 ppg, 18:00 hrs. #1 @ 30=310 @ 40=395 #2 @ 30=310 @ 40=395 18:00 00:00 6.00 11,020 11,365 INTRM1 DRILL DDRL P DDrilled f/11020'-11365' MD,6067' TVD,ADT 4.78, BIT 64.13, JARS 89.59, Total Footage 345', PU 210K, SO 121K, ROT 146K, Tq on 16-17K, off 14-15K, ECD 11.67, FO 54%, WOB 9-13K, 130 rpm, 575 gpm, 2425 psi, Max Gas 367. SPR @ 11363'MD,6066'TVD, MW 10.4 ppg,23:59 hrs. #1 @ 30=340 @ 40=430 #2 @ 30=340 @ 40=430 Total losses for tour 138 bbls. 06/27/2015 Directional drill intermediate hole section to TD, f/11365'-11985' MD,6275'TVD. Total footage 620'. CBU 3X, pumping 2 high vis sweeps. TOH w/MPD f/11985'-9727'MD.Work through two tight spots @ 9727'&9644'. Decide with town to back ream to 7900'MD,then pull on elevators. BROOH f/9700'-9506' MD. 00:00 06:00 6.00 11,365 11,666 INTRM1 DRILL DDRL P DDrilled f/11365-11666' MD,6180' TVD,ADT 4.72, BIT 68.85, JARS 94.31, Total Footage 301', PU 234K, SO 114K, ROT 151K, Tq on 18-19K, off 14-15K, ECD 11.65, FO 54%, WOB 7-13K, 130 rpm, 575 gpm, 2390 psi, Max Gas 648. Page 16 of 40 Time Logs • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 11,666 11,985 INTRM1 DRILL DDRL P DDrilled f/11666'-11985' MD, 6276' TVD,ADT 4.56, BIT 73.41,JARS 98.87, Total Footage 319', PU 236K, SO 109K, ROT 152K, Tq on 19K,off 16-19K, ECD 11.60, FO 54%,WOB 7-10K, 130 rpm, 575 gpm,2450 psi, Max Gas 1046. SPR @ 11985 MD,6276'TVD, MW 10.4 ppg, 11:45 hrs. #1 @ 30=340 @ 40=440 #2 @ 30=340 @ 40=440 Total losses for tour 290 bbls. 12:00 15:30 3.50 11,985 11,985 INTRM1 CASING CIRC P CBU 3X @ 575 gpm, 2525 psi, 130 rpm, Tq 18K. Pump 2-15bbl high vis sweeps, 1 each for of the first 2 bottoms up. 15:30 16:45 1.25 11,985 11,985 INTRM1 CASING OWFF P Monitor well, perform breathing test. 16:45 20:30 3.75 11,985 9,727 INTRM1 CASING TRIP P PJSM, pump dry job, TOH w/MPD f/ 11985'-9727' MD,AP(annular psi) 160 psi, 500-1500 fph. Pulled 30K over @ 9727'MD. 20:30 22:00 1.50 9,727 9,727 INTRM1 CASING CIRC T Pull 30K over @ 9727'MD, CBU @ 550 gpm, 2150 psi, 95 rpm, Tq 13-15K, PU 195K, SO 114K 22:00 22:30 0.50 9,727 9,700 INTRM1 CASING REAM T Line up MPD&attempt to pull through tight spot w/no success. Ream through 9781'-9700' MD, 95 rpm, Tq 14K, 550 gpm, 2100 psi. 22:30 23:15 0.75 9,700 9,644 INTRM1 CASING TRIP T PJSM, TOH f/9700'-9644' MD, pull 30K over @ 9644',decide w/town to back ream out of hole to 7800'MD. 23:15 00:00 0.75 9,644 9,506 INTRM1 CASING BKRM P PJSM, BROOH f/9700'-9506'MD, 575 gpm,2150 psi, 120 rpm, Tq 15K, 800-1000 fph, PU 190K, SO 112K, ROT 135K. Losses for tour 112 bbls. 06/28/2015 BROOH f/9506'-8107'MD. Circulate hole clean for increasing MW&ECD.TOH w/MPD f/8107'-5032'MD. Backream tight spots f/5032'-4750' MD. Circulate hole clean for increasing MW&ECD. TOH f/4750'-3627' MD. CBU @ the surface shoe. Remove MPD bearing&install trip nipple. Monitor well&perform well bore breathing test showing decrease in flow. Begin to TOH&observe swabbing, decide to pump out of hole f/ 3627'-2640'MD. 00:00 03:00 3.00 9,506 8,107 INTRM1 CASING BKRM P PJSM, BROOH f/9506'-8107'MD, 450 gpm, 2000 psi,90 prm, Tq 9K. 03:00 05:00 2.00 8,107 8,107 INTRM1 CASING CIRC T Circulate hole clean,due to MW 10.6 &ECD climbing. Circulate staging up @ 350-450 gpm, 1000-1850 psi, 90 rpm, Tq 9K, FO 45%. 05:00 08:30 3.50 8,107 5,032 INTRM1 CASING TRIP P PJSM,TOH f/8107'-5032'MD, SBP 160 psi, calculated displacement 25.74, actual 2.59 bbls. 08:30 09:15 0.75 5,032 4,750 INTRM1 CASING BKRM T Overpull 30K observed @ 5032'MD. Back ream f/5032'-4750' MD, 550 gpm, 1675 psi, FO 55%, 90 rpm,Tq 5-6K. Page 17 of 40 Time Logs • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 10:15 1.00 4,750 4,750 INTRM1 CASING CIRC T Circulate hole clean,due to MW 10.6 &ECD climbing. Circulate staging up @ 550 gpm, 1675 psi, 120 rpm, Tq 5-6K, FO 55%. 10:15 11:30 1.25 4,750 3,627 INTRMI CASING TRIP P PJSM, TOH f/4750'-3627' MD, SBP 160 psi, calculated displacement 7.8, actual 9.8 bbls. 11:30 11:45 0.25 3,627 3,627 INTRM1 CASING CIRC P Obtain slow pump rates& parameters, PU 97K, SO 77K, ROT 87K. SPR @ 3627' MD, 2630'TVD, MW 10.4 ppg, 11:30 hrs. #1 @ 30=140 @ 40=200 #2 @ 30=140 @ 40=190 11:45 12:30 0.75 3,627 3,627 INTRM1 CASING CIRC P CBU @ 600 gpm, 1600 psi, 120 rpm, Tq 4-5K. 12:30 13:00 0.50 3,627 3,627 INTRM1 CASING MPDA P PJSM, drain stack, blow down MPD choke skid. Monitor well at annulus valve. 13:00 14:30 1.50 3,627 3,627 INTRM1 CASING MPDA P PJSM, remove MPD bearing, install trip nipple. Monitor well at the annulus. 14:30 17:45 3.25 3,627 3,627 INTRMI CASING OWFF T Monitor well, observe breathing decreasing from 12.9 to 5.6 bph. 17:45 21:30 3.75 3,627 3,627 INTRMI CASING OWFF T Monitor well, perform wellbore breathing test. Lined up to choke& shut in top rams. Observe 0 psi for 10 minutes. Open up to trip tank& monitor flow back for 3 hours showing rate decreasing as follows 2.17, 1.82, 1.36 bph. 21:30 21:45 0.25 3,627 3,627 INTRM1 CASING RURD P PJSM, blow down lines&line up on trip tank. 21:45 00:00 2.25 3,627 2,640 INTRM1 CASING PMPO P PJSM, begin to TOH&observe hole swabbing. Decide to pump out of the hole, f/3627'-2640'MD, 2 bpm, 120 psi, 1500-2000 fph. Losses for tour 32 bbls. 36/29/2015 Finish TOH&lay down BHA. C/O upper rams to 7-5/8"&test. Perform dummy run with hanger. Rig up&run 7 5/8"intermediate casing. 00:00 02:00 2.00 2,640 828 INTRMI CASING PMPO P PJSM, pump out of hole f/2640'-828' MD, 3 bpm, 130 psi. 02:00 03:00 1.00 828 828 INTRMI CASING OWFF P Monitor well, confirm breathing with 1.05 bbls returns. Last observed at 1.36 bph at shoe. 03:00 03:30 0.50 828 458 INTRM1 CASING TRIP P PJSM, TOH f/828'-458'MD. 03:30 03:45 0.25 458 458 INTRMI CASING SFTY P PJSM for unloading nuclear sources &laying down BHA#3. 03:45 05:00 1.25 458 0 INTRM1 CASING BHAH P Rack back 3 stands of HWDP, lay down 3 NMFC, unload sources, & lay down remaining BHA as per SLB. Total fill for trip, calculated 29.72, actual 28.84 bbls. 05:00 06:30 1.50 0 0 INTRM1 CASING BHAH P PJSM, clear&clean rig floor. 06:30 07:00 0.50 0 0 INTRM1 CASING WWWH P PJSM, make up stack washer,flush stack, &lay down stack washer. Page 18 of 40 Time Logs 111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:30 2.50 0 0 INTRM1 CASING BOPE P PJSM, remove upper VBR's&install 7-5/8"rams. SIMOPS pull wear bushing as per Cameron Rep. 09:30 10:15 0.75 0 0 INTRM1 CASING BOPE P PJSM, rig up to test 7-5/8"rams. 10:15 10:45 0.50 0 0 INTRM1 CASING BOPE P PJSM,test with 7-5/8"joint,top rams 250/3500 psi for 5 min each, test annular to 250/2500 psi 5 min each, charted. 10:45 11:00 0.25 0 0 INTRM1 CASING BOPE P Rig down test equipment. 11:00 12:00 1.00 0 0 INTRM1 CASING RURD P PJSM perform dummy run with 7-5/8"hanger&landing joint, as per Cameron Rep. 12:00 14:00 2.00 0 0 INTRM1 CASING RURD P PJSM, rig up to run 7-5/8"casing. 14:00 21:00 7.00 0 3,612 INTRM1 CASING PUTB P PJSM, run 7-5/8",29.7#, L80, Hydril 563 casing from surface to 3612'MD. Pick up shoe track&check floats, good. Ran 61 -7-5/8"x 9-3/8" Hydroform centralizers, as per detail. 21:00 22:00 1.00 3,612 3,612 INTRM1 CASING CIRC P CBU staging up the pumps to 5.5 bpm, 275 psi. Started taking losses @ 35 bph, reduce rate to 4.5 bpm. Lost 6 bbls while circulating. 22:00 00:00 2.00 3,612 4,465 INTRM1 CASING PUTB P PJSM, run 7-5/8", 29.7#, L80, Hydril 563 casing from 3612'-4465'MD. PU 115K, SO 75K. Calculated displacement 48.22, actual 44.45 bbls. 06/30/2015 Continue running in the hole w/7-5/8"casing to 11945'MD.Work through tight hole 11805'-11945'MD. 00:00 02:00 2.00 4,465 5,138 INTRM1 CASING PUTB P Cont. RIH w/7 58"29.7#L-80 Hydril 563 csg f/4465'to 5138'( 127 jts in hole) Running speed 350 to 500 ft/hr. w/slight returns Observed slack off wt. dropping by 15 K 02:00 02:15 0.25 5,138 5,152 INTRMI CASING CIRC P Break circ @ 1 bbl/min @ 150 psi- w/slight returns-string took 15 k slack off then broke free-pumped away 7 bbls during circulation-Ran the remainder of jt 127 down to 5152' 02:15 04:00 1.75 5,152 5,761 INTRM1 CASING PUTB P Cont. RIH w/7 5./8"29.7#1-80 Hydril 563 csg f/5152'to 5761'(142 jts in hole) Running @ 500 to700 ft/hr w/ slight returns 04:00 04:30 0.50 5,761 5,761 INTRMI CASING CIRC P Break circ @ 1 bbl/min @ 210 psi w/ slight returns PU wt 126 So wt 95 04:30 09:00 4.50 5,761 8,073 INTRMI CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/5761'to 8073'(199 jts. in hole) 09:00 10:15 1.25 8,073 8,073 INTRM1 CASING CIRC P Observed no returns-Work pipe- pulled 30 k over to pull free-Pumped .5 bbls/min @ 250 psi on up stroke- turn pump off on down stroke-Stage pump up to 1.5 bbls/min @ 280 psi- returns getting better(lost 40.5 bbls while circulating) Page 19 of 40 Time Logs 111 Date From To Dur S.Depth E. Depth Phase Code Subcode T ' Comment 10:15 12:00 1.75 8,073 8,803 INTRM1 CASING PUTB P Cont. Rlh w/7 5/8"29.7#L-80 hydril 563 csg f/8073'to 8803'(217 jts in hole) running speed 750 to 1000 ft/hr. -Slight returns-PU wt 190 SO wt 105 Total loss for tour 160 bbls 12:00 21:15 9.25 8,803 11,805 INTRMI CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/8803'to 11,805' (290 jts in hole)Running speed 700 to 800 ft/hr.w/slight returns-Encountered tight hole @ 11,805'(26'in on jt# 291) 21:15 00:00 2.75 11,805 11,945 INTRM1 CASING PUTB P Wash down csg f/11,805'to 11, 837" - Pressured up&got tight-Cont.to work pipe f/11,837'-11945' MD, PU 270K, SO 50K. Losses for Tour 188 bbls. 07/01/2015 Cont.working csg down f/11,945'to 11,982'(picked up jt.#295 instead of hanger&landing jt)Work pipe& establish circ @ 4.5 bbls/min w/minimal returns-RU&cmt. 7 5/8"csg(2 stage job)as per plan-RD cmt lines-Drain stack(monitor annulus-static)-Prep work in cellar to set emerency slips-Set slips&cut off csg- 00:00 01:30 1.50 11,945 11,982 INTRMI CASING PUTB P Cont.working pipe down f/11,945'to 11,982'(decision made to pick up jt #295 instead of landing jt. &hanger to be able to work pipe&establish circ). 01:30 03:45 2.25 11,982 11,982 INTRM1 CEMEN-CIRC T Working pipe f/11,982/to 11,945'- Hole got tight w/no movement up or down-unable to circ--work pipe free&establish circ 03:45 05:30 1.75 11,982 11,982 INTRM1 CEMEN'CIRC P Circ @ 1 bbl/min @ 400 psi-stage pump up to 4.5 bbls/min @ 510 psi (minimal returns)for cmt job- working pipe f/11,980'to 11,960'- PU wt 260 SO wt 115 05:30 06:00 0.50 11,982 11,982 INTRM1 CEMEN-SFTY P PJSM on cmt job 06:00 06:15 0.25 11,982 11,982 INTRM1 CEMEN-RURD P RU cement lines- 06:15 06:45 0.50 11,982 11,982 INTRM1 CEMEN-CIRCP Establish circ @ 1 bbl/min @ 200 psi&stage pump up to 3.5 bbls/min @ 500 psi 06:45 08:15 1.50 11,982 11,982 INTRM1 CEMEN-CMNT P Pumped 1st stage cmt job as follows: Dowell pumped 5 bbls CW-100-Test lines to 15000&3500 psi-Pumped 25 bbls CW-100 @ 2.6 to 4.0 bbls/min @ 434 to 619 psi- Pumped 30 bbls Mud Push @ 11.5 ppg @ 3.8 to 4.3 bbls/min @ 630 psi -Pumped 102 bbls Gasblok slurry w/ 1.5#/bbl CenNet plus additives @ 15.8 ppg @ 4 bbls/min @ 500 to 160 psi-Dropped top plug w/10 bbls water f/Dowell-Recip. pipe 12' stroke during job-w/slight returns through out job Page 20 of 40 Time Logs S S Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08:15 10:30 2.25 11,982 11,982 INTRM1 CEMEN-CMNT P Switch over to rig pump&displace cement w/10.4 ppg LSND mud @ 6.5 bbls/min for 220 stks(caught up with cmt)Cont.displacing cmt @ 4.5 to 5 bbls/min @ 200 to 300 psi- slowed pumps to 3 bbls/min@ 5000 stks @ 900 psi-slowed pump to 1 bbl/min@ 600 psi @ 5100 stks- Bumped plug @ 5284 stks(528 bbls) -Pressure up to 1500 psi&held for 5 mins. -Bled off&checked floats (Floats held)CIP @ 1018 hrs. -had slight returns through displacement 10:30 11:00 0.50 11,982 11,982 INTRMI CEMEN"CIRC P Pressure up to 3800 psi&opened stage collar-Establish circ& 1 bbl/min @ 450 psi stage pump up to 4.5 bbls/min @ 500 psi(lost 51 bbls while pumping)slight returns (SIMOPS batch up mud push&cmt for stage 2 11:00 12:00 1.00 11,982 11,982 INTRM1 CEMEN-CMNT P Pumped 2nd stage cmt job as follows: Pumped 30 bbls CW-100 4 bbls/min @ 475 psi-Pumped 30 bbls 11.5 ppg MudPush @ 4 bbls/min @ 500 psi-Pumped 33.8 bbls Gasblok slurry w/15#/bbl Cemnet plus additives @ 15.8 ppg @ 4 bbls/min @ 490 to 330 psi- Dropped closing plug w/ 10 bbls water. Kick w/Drilling Table Top Drill at PTSM. 12:00 13:30 1.50 11,982 11,982 INTRM1 CEMEN-CMNT P Switched over to rig pump& displaced cmt w/10.4 ppg LSND mud @ 5 bbls/min @ 415 to 580 psi for 3700 stks(370 bbls)slowed pump to 3 bbls/min @ 428 psi- Bumped plug @ 4014 stks(401 bbls)-pressured up to 1700 psi to close stage collar(observed shear @ 1400 psi-Held pressure for 5 mins.-Bled off-No flow back confirmed stage collar closed CIP @ 1309 hrs. 13:30 14:30 1.00 11,982 11,982 INTRM1 CEMEN-RURD P PJSM, rig down&blow down lines. Rig down scaffolding in cellar. 14:30 16:30 2.00 11,982 11,982 INTRMI CEMEN-NUND T PJSM, rig up&raise BOPE from the wellhead to cut 7-5/8"casing for emergency slips. 16:30 17:45 1.25 11,982 0 INTRM1 CEMEN-CPBO T PJSM, put casing in tension with 50K. Final PU 320K. Set casing in emergency slips. Cut off casing stub as per Cameron Rep. Lay down joint #295, original 39.85', cut joint 37.5'. 17:45 20:00 2.25 0 0 INTRMI CEMEN-NUND T PJSM, nipple up BOPE. SIMOPS lay down casing tools. 20:00 21:00 1.00 0 0 INTRM1 CEMEN-WWSP P PJSM, set 10-3/4"X 7-5/8"packoff as per Cameron Rep. Page 21 of 40 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:15 0.25 0 0 INTRM1 CEMEN-WWSP P PJSM,test 10-3/4"X 7-5/8"packoff to 3500 psi for 10 min. 21:15 23:45 2.50 0 0 INTRMI CEMEN-FRZP P PJSM, R/U lines to LRS. Flush& freeze protect 10-3/4"X 7-5/8" annulus. Pump 145 bbls of H2O w/ rig @ 3 bpm, 14.5 bbls broke over @ 782 psi=EMW 16.1 ppg. LRS pump 102 bbls of Isotherm NT @ 3 bpm, ICP=900 psi, FCP=1100 psi. Shut in 800 psi on OA. SIMOPS, cut&slip drill line. 23:45 00:00 0.25 0 0 INTRM1 CEMEN"SLPC P PJSM, continue slip&cut drill line 84'. 07/02/2015 Slip and cut drill line. Lay down 5"DP and HWDP. Change out saver sub from 5"to 4". Remove 7.625" casing rams from upper ram and install 3%"x 6"VBR's. Pick up 14 stands of 4"XT39 DP. 00:00 01:15 1.25 0 0 INTRM1 CEMEN-SLPC P PJSM. Continue to slip and cut drill line. SIMOPS: blow down cellar lines,top drive and install pressure gauge on OA. 01:15 02:00 0.75 0 0 INTRM1 CEMEN-SVRG P Service rig, remove bridge cranes from BOPE yoke, Rig up scaffolding in cellar. 02:00 11:30 9.50 0 0 INTRM1 CEMEN-PULD P PJSM. Lay down 5" DP from derrick into pipe shed. 6 stands of HWDP, 132 stands of DP. 11:30 12:00 0.50 0 0 INTRM1 CEMEN-RURDP Clear and clean rig floor. remove thread protector barrels. Crew change. OA pressure=130 psi. 12:00 12:30 0.50 0 0 INTRMI CEMEN-SFTY P Safety stand down, discussed proper reporting of all incidents&injuries. 12:30 15:15 2.75 0 0 INTRM1 CEMEN-RURD P PJSM, change out saver sub&back up wrench, on top drive,from 5"to 4". 15:15 18:00 2.75 0 0 INTRM1 CEMEN-BOPE P PJSM,change out upper rams f/ 7-5/8"to 3-1/2"X6"VBR's. 18:00 19:00 1.00 0 0 INTRM1 CEMEN RURD P PJSM, install Katch Kan on stack. SIMOPS prep pipe shed for 4"DP. 19:00 22:30 3.50 0 0 INTRM1 CEMEN OTHR P PJSM; load, strap,&tally 4" DP in the pipe shed. 22:30 00:00 1.50 0 0 INTRM1 CEMEN-PULD P PJSM, pick up&rack back 14 stands of 4"DP. OA pressure=245 psi. 37/03/2015 Pick up&rack back 185 stands of 4" DP. Rig up&test BOPE with 4"test joint.Witnessed waived by AOGCC Rep John Crisp. 00:00 08:00 8.00 0 0 INTRM1 CEMEN-PULD P Cont. PU 4"DP&stand back in derrick via mouse hole( 117 stds picked up) 08:00 11:00 3.00 0 0 INTRM1 CEMEN-OTHR P Load pipe shed w/remaining 4"DP (246 jts)&tally. Fire Drill CRT 79 sec @ 08:15 hrs. 11:00 17:30 6.50 0 0 INTRM1 CEMEN PULD P Cont. PU&std back 4"DP via mouse hole(82 Stds)- 199 stds total 4"DP in derrick 17:30 18:00 0.50 0 0 INTRM1 CEMENIRURD P PJSM,clear&clean rig floor. Page 22 of 40 Time Logs •' Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 19:30 1.50 0 0 INTRM1 WHDBO RURD P PJSM, rig up to test BOPE. 19:30 00:00 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 rams, CV 1,12,13, 14& manual kill valve.Test#2: Upper IBOP, HCR kill, CV 9, & 11.Test#3: Lower IBOP, CV 5,8& 10. Test#4: Dart„ CV 4,6&7. Test#5: FOSV valve&CV 2. Test#6: HCR choke. Test#7: Manual choke valve&HCR Kill(Fail/Pass). Test#8:Annular preventer tested to 250/2500 psi. Test#9: Lower pipe rams. Accumulator test:system pressure= 3000 psi,After closing= 1800 psi, 200 psi attained after 44 sec,full pressure attained after 181 sec, Five bottle nitrogen avg=2000 psi. The BOP test witness was waived by AOGCC Rep John Crisp. Spill Drill CRT 145 sec @ 23:45 hrs. OA pressure 625 psi. 37/04/2015 Finish testing BOPE w/3.5"&4.5"TJ. Set wear ring. Pick up BHA 4.TIH to 1385' MD&shallow hole test tools,good. TIH 1385'-8290' MD. Real time sonic log from 8290'-9065'MD. Clean out cement to stage collar. CBU&test casing to 3000 psi for 10 min. Drill cement&stage collar 9065'-9091' MD. Continue real time sonic log from 9091'-9350' MD. 00:00 04:00 4.00 0 0 INTRM1 WHDBO BOPE P Continue to test BOPE. Test#10, Upper pipe rams with 4'/2'test joint,Test#11. Lower pipe rams with 4'/2'test joint. Test#12 Annular with 4'/2'test joint. Test#13 Upper pipe rams with 3'/z'test joint. Test#14. Lower pipe rams with 3'/z'test joint. Test#15.Annular with 3%"test joint. Test#16 blind rams&CV#3. Test #17 Hyd. Super choke, Test#18 Manual choke. 04:00 04:30 0.50 0 0 INTRM1 WHDBO RURD P Rig down test equipment, blow down choke and kill lines. 04:30 05:00 0.50 0 0 INTRM1 WHDBO RURD P Set 10"ID wear bushing. 05:00 07:30 2.50 0 156 INTRM1 CEMEN-BHAH P PJSM. Pick up tools to rig floor. Make up BHA components to 156'. 07:30 08:30 1.00 156 156 INTRMI CEMEN-BHAH P PJSM. Install Neutron/Density sources. SLB adn VISION tool. 08:30 10:00 1.50 156 440 INTRMI CEMEN-BHAH P Pick up BHA to 4"XT39 DP. 10:00 10:30 0.50 440 1,385 INTRM1 CEMEN TRIP P TIH out of the derrick with stands of 4"XT39 DP. 440 to 1385' MD. 10:30 11:00 0.50 1,385 1,385 INTRM1 CEMEN DHEQ P Shallow hole test, 220 gpm, 1100 psi,good. Spill Drill CRT 60 sec @ 11:00 hrs. 11:00 14:15 3.25 1,385 7,720 INTRM1 CEMEN'TRIP P PJSM,TIH f/1385'-7720'MD, fill pipe. OA pressure 720 psi @ 12:00 hrs. Page 23 of 40 Time Logs . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 14:45 0.50 7,720 7,814 INTRM1 CEMEN-DHEQ T Establish base line for sonic MAD pass f/7720'-7814' MD, 220 gpm, 1600 psi,450 fph. 14:45 15:15 0.50 7,814 8,290 INTRM1 CEMEN-TRIP P PJSM,TIH f/7814'-8290' MD, 15:15 18:15 3.00 8,290 9,065 INTRM1 CEMEN-DLOG T PJSM, sonic Mad pass f/8290'-9065' MD, 220 gpm, 1675 psi, 350-400 fph. 18:15 18:30 0.25 9,065 9,085 INTRM1 CEMEN COCF P Clean out cement f/9065'-9085' MD. 220 gpm, 1700 psi,40 rpm,Tq 7-8K. 18:30 20:30 2.00 9,085 9,085 INTRM1 CEMEN-CIRC P Circulate&condition @ 220 gpm, 1700 psi, MW 10.4 ppg in&out. 20:30 21:00 0.50 9,085 9,085 INTRM1 CEMEN-PRTS P PJSM, rig up&test casing to 3000 psi for 10 min, charted. Rig down test equipment. 21:00 23:00 2.00 9,085 9,091 INTRM1 CEMEN DRLG P Drill out cement stage collar f/ 9085-9091' MD, 220 gpm, 1700 psi, 70 rpm, Tq 10-15K, PU 145K, SO 73K. 23:00 00:00 1.00 9,091 9,350 INTRM1 CEMEN DLOG T Continue sonic Mad pass f/ 9091'-9350'MD,220 gpm, 1625 psi, PU 145K, SO 72K. Ream stage collar 3X&trip through, good. Kick w/Tripping Drill CRT 99 sec @ 23:45 hrs. OA pressure 690 psi. 37/05/2015 Conduct Sonic MAD pass logging run to 11882'MD. Good quality cement from 8800' MD to 11,882' MD. No CBL needed. CBU&test casing to 3500 psi for 30 min. Slip&cut drill line. Install MPD&establish parameters for fingerprinting. Remove MPD&install trip nipple. Drill out shoe track to 11969' MD. 00:00 10:00 10.00 9,350 11,750 INTRMI CEMEN-DLOG T PJSM. Continue to log the casing annulus with Sonic tool to evaluate cement quality.400 fph. 220 gpm. 1600-2000 psi. Kick w/Drilling CRT 120 sec @ 04:00 hrs. 10:00 11:00 1.00 11,750 11,882 INTRM1 CEMEN'DLOG T Begin to drill cement stringers. Continue MAD pass. Good quality cement from 8800' MD to 11,882' MD. No CBL needed. 250 gpm.2500 psi. 70 rpm. TQ= 14k. 11:00 14:00 3.00 11,882 11,882 INTRM1 CEMEN CIRC P Circulate. Rotate and reciprocate. CBU. Condition mud. 250 gpm. 2400 psi. 70 rpm. 14k TQ.- 10.4 ppg mud wt in&out OA pressure=690 psi. 14:00 15:00 1.00 11,882 11,882 INTRMI CEMEN PRTS P PJSM, RU&Test 7 5/8'csg to 3500 psi for 30 mins. -Good test-RD test equipment 15:00 16:30 1.50 11,882 11,882 INTRM1 CEMEN-SLPC P PJSM-Slip and cut dril line(98' ) & service rig 16:30 17:45 1.25 11,882 11,882 INTRMI CEMEN-MPDA P PJSM-Pull master bushing&install split bushing-Pull trip nipple&air boot-Install RCD bearing 17:45 18:00 0.25 11,882 11,882 INTRM1 CEMEN'MPDA P Clean and clear rig floor-line up RCD bearing l Page 24 of 40 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 20:15 2.25 11,882 11,882 INTRMI CEMEN-jMPDA P PJSM, Obtain finger print data for MPD&run simulations 20:15 21:30 1.25 11,882 11,882 INTRM1 CEMEN-MPDA P PJSM, remove RCD&install trip nipple. 21:30 00:00 2.50 11,882 11,969 INTRMI CEMEN-DRLG P PJSM,drill out float collar&shoe track 11882'-11969' MD, 205 gpm, 1800 psi, PU 185K, SO 95K, ROT 110K,WOB 2-7K,90 rpm,Tq 4-7K. SPR @ 11968' MD,6271'TVD, MW 10.5 ppg,23:45 hrs. #1 @ 20=670 @ 40=880 #2 @ 20=660©40=880 OA pressure 748 psi. 07/06/2015 Cont. drill out shoe track&20' new hole to 12005'-Circ hole clean-Perform FIT to 16.0 ppg-Change over to 10.5 ppg FloThru system-Circ&work pipe to clear junk f/shoe track drill out-Monitor well 30 min(static). Install MPD bearing. DDrill 6-3/4"production section f/12005'-12260'MD. 00:00 03:45 3.75 11,969 11,985 INTRM1 CEMEN-DRLG P Cont. drill out shoe track f/11,969'to 11,985'@ 220 gpm @ 1725 psi w/ 60 rpm @ 14 k torque-ECD- 11.59 ppg 03:45 04:15 0.50 11,985 12,005 INTRM1 CEMEN-DDRL P Drilled 20'new hole f/11,985'to 12,005' MD 6280'TVD RPM's 60 to 80 WOB 2 to 12 k GPM 250 @ 2475 psi Torque on/off btm.- 15/16 k ft/lbs ADT-.57 hrs. 04:15 06:15 2.00 12,005 11,878 INTRMI CEMEN-CIRCP Circ btms up @ 250 gpm @ 2500 psi -rack back 2 stds to 11,878' 06:15 07:30 1.25 11,878 11,878 INTRM1 CEMEN-FIT P PJSM-RU&perform FIT to 16.0 ppg EMW w/1790 psi w/10.5 ppg mud @ 6274'TVD-RD test equip. & blow down kill line. Fire Drill CRT 120 sec @ 07:00 hrs. 07:30 10:15 2.75 11,878 12,005 PROD1 DRILL DISP P PJSM-RIH to 12,005' (PU single of DP)Circ&chnage well over f/10.4 ppg LSND to 10.5 ppg Flo-Thru mud @ 225 gpm @ 2400 psi w/100 rpm's @ 16 k torque 10:15 10:30 0.25 12,005 12,005 PROD1 DRILL OWFF P Monitor well-Observed flow out- Out of balance 10.4 ppg in/10.5 ppg _out 10:30 14:00 3.50 12,005 12,005 PROD1 DRILL CIRC T Cont.to circ&condition mud-work string to 12,005'(appears to be junk in hole f/shoe track)circ&work pie @240 gpm @2550 psi- 100 rpm's w/16.5 k torque-PU wt 210 So wt 75 ROT wt. 115-ECD-11.40 ppg 14:00 14:15 0.25 12,005 11,790 PROD1 DRILL TRIP P PJSM, TOH f/12005-11790'MD. 14:15 14:45 0.50 11,790 11,790 PROD1 DRILL OWFF P Monitor well, static. 14:45 15:30 0.75 11,790 11,790 PROD1 DRILL MPDA P PJSM, remove trip nipple&install RCD. Page 25 of 40 1110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 11,790 12,005 PROD1 DRILL WASH P PJSM,wash down f/11790'-12005' MD, 240 gpm, 2570 psi. SPR @ 12005'MD, 6276'TVD, MW 10.5 ppg, 15:30 hrs. #1 @ 20=495 @ 40=790 #2 @ 20=510 @ 40=820 16:00 18:00 2.00 12,005 12,069 PROD1 DRILL DDRL P DDrilled f/12005'-12069' MD,6298' TVD,ADT 1.80, BIT 1.80, JARS 1.80, Total Footage 64', PU 210K, SO 65K, ROT 108K,Tq on 15-18K, off 15K, ECD 11.42, FO 30%,WOB 8-13K, 110 rpm, 240 gpm, 2600 psi, Max Gas 148. 18:00 00:00 6.00 12,069 12,260 PROD1 DRILL DDRL P DDrilled f/12069'-12260' MD,6334' TVD,ADT 4.53, BIT 6.33, JARS 6.33, Total Footage 191', PU 207K, SO 67K, ROT 112K,Tq on 15K, off 16K, ECD 12.1, FO 30%,WOB 12-14K, 110 rpm, 240 gpm, 2800 psi, Max Gas 180. OA pressure 640 psi. _ 07/07/2015 Cont. Drilled 6/34" hole w/RSS f/12,260'to 12,639'-Circ btms up&perform finger print for pore pressure data-Trouble shoot MPD-Drilled 6 3/4" Hole w/RSS f/12,639' t/13,206' MD. 00:00 07:00 7.00 12,260 12,639 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 12,260'to 12,639'MD 6385'TVD ADT-5.76 hrs. ECD- 12.4 ppg Footage-379' WOB 8 to 10 k RPM 140 GPM 250 @ 3050 psi String wt. PU 205 SO 65 ROT 110 Torque on/off btm.-16/14 k ft/lbs Total bit hrs. 12.06 hrs. Total jar hrs 12.09 hrs SPR's @ 12,354' MD 6357'TVD w/ 10.5 ppg mud wt. @ 0130 hrs #1 20&30 SPM @ 570&890 psi #2 20&30 SPM @ 560&935 psi Max.gas 5704 units 07:00 08:45 1.75 12,639 12,639 PROD1 DRILL CIRC P Circ btms up @ 250 gpm @ 2950 psi w/140 rpm W 16 k torque-Perform finger print for pore pressure data 08:45 10:15 1.50 12,639 12,639 PROD1 DRILL MPDA T Trouble shoot MPD- 10:15 14:45 4.50 12,639 12,639 PROD1 DRILL MPDA T Zero Stks&circ btms up @ 270 gpm @ 3350 psi w/100 rpm w/14 k torque-Observed 204 units gas @ btms up-Circ-work pipe&trouble shoot MPD Page 26 of 40 Time Logs • i Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 18:00 3.25 12,639 12,827 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 12,639'to 12,827' MD 6375'TVD ADT-2.01 hrs. ECD- 12.28 ppg Footage- 188' WOB 10 to12 k RPM 140 GPM 243 @ 2850 psi String wt. PU 204 SO 63 ROT 105 Torque on/off btm.-16/14 k ft/lbs Total bit hrs. 14.10 hrs. Total jar hrs 14.10 hrs Max. gas 6819 units 18:00 00:00 6.00 12,827 13,206 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 12,827'to 13,206' MD 6369'TVD ADT-3.97 hrs. ECD- 12.41 ppg Footage-379' WOB 10 to13 k RPM 120 GPM 242 @ 2925 psi String wt. PU 210 SO 57 ROT 106 Torque on/off btm.- 15/13 k ft/lbs Total bit hrs. 18.07 hrs. Total jar hrs 18.07 hrs Max. gas 7071 units SPR's @ 12,922' MD 6371'TVD w/ 10.7 ppg mud wt. @ 19:00 hrs #1 20&30 SPM @ 860& 1140 psi #220&30 SPM @900& 1180 psi OA=710 psi 37/08/2015 Drilled 6 3/4" hole w/RSS&MPD f/13,206' MD to 14,926' MD 00:00 06:00 6.00 13,206 13,661 PROD1 DRILL DDRL P Drilled 6 3/4' hole w/RSS&MPD f/ 13,206'to 13,661' MD 6362'TVD ADT-4.57 hrs. ECD- 12.42 ppg Footage-455' WOB 8 to 12 K RPM 110 GPM 242 @ 3050 psi-Flow out 28% String wt. PU 201 SO 65 ROT 106 Torque on/off btm.- 14/13 k ft/lbs. Total bit hrs. 22.64 hrs. Total jar hrs. 22.64 hrs. Max gas-8898 units SPR's @ 13296'MD 6372'TVD w/ 10.7 ppg @0100 hrs #1 20/30 SPM 550/830 psi #2 20/30 SPM 610/950 psi Page 27 of 40 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 12:00 6.00 13,661 14,094 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 13,661'to 14,094'MD 6355'TVD ADT-4.19 hrs. ECD- 12.36 ppg Footage-433' WOB 8 to 12 k RPM 140 GPM 242 @ 3000 psi-Flow out 30% String wt. PU 185 SO 65 ROT 106 Torque on/off btm.- 13/11 k ft/lbs Total bit hrs. 26.83 hrs. Total jar hrs. 28.63 hrs Max gas 9877 units SPR's @ 13,961'MD 6361'TVD w/ 10.7 ppg @ 1000 hrs. #1 20/30 SPM 570/945 psi #2 20/30 SPM 605/980 psi 12:00 18:00 6.00 14,094 14,530 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 14,094'to 14,530'MD 6342'TVD ADT-4.47 hrs. ECD-12.47 ppg Footage-436' WOB 7 to 9 k RPM 140 GPM 250 @ 3200 psi-Flow out 37% String wt. PU 182 SO 65 ROT 104 Torque on/off btm.-13/10 k ft/Ibs Total bit hrs. 31.30 hrs. Total jar hrs 31.30 hrs Max gas 8078 units SPR's @ 14,432'MD 6343'TVD w/ 10.7 ppg @ 1700 hrs. #1 20/30 SPM 608/991 psi #2 20/30 SPM 620/970 psi 18:00 00:00 6.00 14,530 14,926 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 14,530'to 14,926'MD 6336'TVD ADT-4.25 hrs. ECD- 12.42 ppg Footage-396' WOB 6 to 10 k RPM 140 GPM 260 @ 3400 psi-Flow out 37% String wt. PU 183 SO 67 ROT 105 Torque on/off btm.-13/10 k ft/lbs Total bit hrs. 35.55 hrs. Total jar hrs 35.55 hrs Max gas 6920 units OA=620 psi 37/09/2015 Drilled 6 3/4"hole w/RSS&MPD f/14,926'MD to 16,549' MD Page 28 of 40 Time Logs 110 410' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 14,926 15,284 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 14,926'to 15,284' MD 6338'TVD ADT-4.77 hrs. ECD- 12.34 ppg Footage-358' WOB 8 to14K RPM 140 GPM 260 @ 3435 psi @ 27%flow out String wt. PU 190 SO 65 ROT 105 Torque on/off btm.- 13/11 k ft/lbs Total bit hrs.40.11 hrs Total jar hrs. 40.11 hrs Max. gas 9205 units SPR's @ 14,999'MD 6336'TVD w/ 10.7 ppg @ 0030 hrs #1 20/30 SPM 500/930 psi #2 20/30 SPM 655/1000 psi 06:00 12:00 6.00 15,284 15,660 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 15,284'to 15,660' MD 6347'TVD ADT-3.93 hrs ECD- 12.65 ppg Footage-376' WOB 8 to 12 k RPM 140 GPM 260 @ 3500 psi w/28%flow out String wt. PU 190 SO 65 ROT 105 Torque on/off btm.-13/11 k ft/lbs Total bit hrs.44.04 hrs Total jar hrs. 44.04 hrs Max gas 8393 units SPR's @ 15,566'MD 6344"TVD w/ 10.7+ppg @ 1030 hrs #1 20/30 SPM 677/1040 psi #2 20/30 SPM 675/1065 psi Total losses for tour 36 bbls 0/A 655 psi 12:00 18:00 6.00 15,660 16,100 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 15,660'to 16,100'MD 6363'TVD ADT-4.08 hrs ECD- 12.65 ppg Footage-440' WOB 5 to 8 k RPM 140 GPM 258 @ 3475 psi w/28%flow out String wt. PU 195 SO 62 ROT 104 Torque on/off btm.-14/10.5 k ft/lbs Total bit hrs.48.12 hrs Total jar hrs. 48.12 hrs Max gas 7200 units SPR's @ 16,037'MD 6362"TVD w/ 10.7+ppg @ 1700 hrs #1 20/30 SPM 720/1035 psi #2 20/30 SPM 710/1100 psi Page 29 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 16,100 16,549 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 16,100'to 16,549' MD 6385'TVD ADT-4.13 hrs ECD- 12.67 ppg Footage-449' WOB 59to 11 k RPM 140 GPM 257 @ 3525 psi w/28%flow out String wt. PU 195 SO 60 ROT 104 Torque on/off btm.- 14/11k ft/lbs Total bit hrs. 52.25 hrs Total jar hrs. 52.25 hrs Max gas 3841 units SPR's @ 16,508'MD 6395"TVD w/ 10.7+ppg @ 2315 hrs #1 20/30 SPM 660/1085 psi #2 20/30 SPM 743/1160 psi OA=690 psi 37/10/2015 Drilled 6 3/4"hole w/RSS&MPD f/16,549'to 17,266-Trouble shoot Power drive-Circ btms up 8900 units @ btms up-Cont.circ&attempt down link to power drive-Drilled 6 3/4"hole w/RSS&MPD f/17,266'MD to 17,831'MD 00:00 06:00 6.00 16,549 16,983 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 16,549'to 16,983' MD 6379'TVD ADT-4.87 hrs. ECD- 12.71 ppg Footage-434' WOB 8/11 k RPM 140 GPM 260 @ 3550 psi w/29%flow out String wt. PU 205 SO 59 ROT 105 Torque on/off btm.-14/12 k ft/lbs Total bit hrs. 57.22 hrs Total jar hrs. 57.22 hrs Max. gas-6744 units 06:00 10:30 4.50 16,983 17,266 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 16,983'to 17,266'MD 6362'TVD ADT-3.08 hrs ECD-12.81 ppg Footage-283' WOB 5/10 k RPM 140 GPM 260 @ 3600 psi w/28%flow out String wt. PU 195 SO 55 ROT 104 Torque on/off btm.-15/13 k ft/lbs Total bit hrs. 60.30 hrs Total jar hrs. 60.30 hrs Max gas-8750 units SPR's @ 17077'MD 6375'TVD w/ 10.7 ppg @ 0715 hrs. #1 20/30 SPM 830/1170 psi #2 20/30 SPM 830/1225 psi 10:30 10:45 0.25 17,266 17,171 PROD1 DRILL DHEQ T Trouble shoot down link problem power drive-std back 1 std DP to 17,171' Page 30 of 40 Time Logs • 4110 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:45 12:45 2.00 17,171 17,171 PROD1 DRILL CIRC T Circ btms up©250 gpm @ 3500 psi w/140 rpm w/14 k torque-8900 units gas @ btms up 12:45 18:00 5.25 17,171 17,457 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 17,266'to 17,457'MD 6359'TVD ADT-2.56 hrs ECD- 12.72 ppg Footage- 191' WOB 5/10 k RPM 140 GPM 256 @ 3500 psi w/33%flow out String wt. PU 190 SO 55 ROT 107 Torque on/off btm.-14/13 k ft/lbs Total bit hrs. 62.86 hrs Total jar hrs. 62.86 hrs Max gas-9104 units 18:00 00:00 6.00 17,457 17,831 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS&MPD f/ 17,457'to 17,831'MD 6357'TVD ADT-4.5 hrs ECD- 12.68 ppg Footage-374' WOB 5/12 k RPM 140 GPM 256 @ 3600 psi w/40%flow out String wt. PU 195 SO 45 ROT 107 Torque on/off btm.- 16/15 k ft/lbs Total bit hrs. 67.36 hrs Total jar hrs. 67.36 hrs Max gas-3473 units SPR's @ 17,549'MD 6,358'TVD w/ 10.7 ppg 19:19 hrs. #1 20/30 SPM 735/1120 psi #2 20/30 SPM 710/1105 psi OA=690 psi 07/11/2015 Drilled 6 3/4"hole w/RSS&MPD f/17,831'to 18,275'-Changed RCD bearing-Drilled 6 3/4"hole w/RSS& MPD f/18,275'to 18,410'. Circ and cond mud. BROOH to 17,838'. Replace expansion boot on MP#1. BROOH to 16,418'. 00:00 07:00 7.00 17,831 18,275 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 17,831'to 18,275'MD 6338'TVD ADT-5.04 hrs ECD- 12.78 ppg Footage-444' WOB 5/10 k RPM 140 GPM 257 @ 2750 psi w/34%flow out String wt. PU 205 SO 45 ROT 107 Torque on/off btm.- 17.5/16 k ft/lbs. Total bit hrs. 72.40 hrs Total jar hrs. 72.40 hrs. Max.gas 7840 units SPR's @ 18119'MD 6341'TVD w/ 10.7+ppg @ 0415 hrs. #1 20/30 SPM 725/1075 psi #2 20/30 SPM 765/1180 psi Page 31 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 18,275 18,213 PROD1 DRILL CIRC T Back ream 1 std to 18,213'-Circ btms up @ 257 gpm©3700 psi w/ 70 rpm @ 13 k torque ECD-12.73 ppm-PJSM on changing out RCD bearing 09:00 10:45 1.75 18,213 18,213 PROD1 DRILL EQRP T Change out RCD bearing-holding 500 psi on annulus-PU wt 205 SO _ wt 50 10:45 11:15 0.50 18,213 18,275 PROD1 DRILL WASH T Wash&ream f/18,213'to 18,275'@ 257 gpm @ 3650 psi w/140 rpm w/ 15 k torque-ECD 12.71 ppg 11:15 12:00 0.75 18,275 18,307 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 18,275'to 18,307' MD 6337'TVD ADT-.36 hrs ECD- 12.71 ppg Footage-32' WOB 5/10 k RPM 140 GPM 258© 3700 psi w/34%flow out String wt. PU 203 SO 47 ROT 107 Torque on/off btm.- 16/15 k ft/lbs Total bit hrs. 72.76 hrs Total jar hrs. 72.76 hrs Max gas 6910 units O/A 660 psi 12:00 13:30 1.50 18,307 18,410 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/18,307'to 18,410' MD 6330'TVD ADT- 1.02 hrs ECD- 12.93 ppg Footage- 103' WOB 7/11 k RPM 140 GPM 251 ©3750 psi w/34%flow out String wt. PU 213 SO 38 ROT 100 Torque on/off btm.-17.5/16 k ft/lbs Total bit hrs. 73.78 hrs Total jar hrs.- 73.78 hrs Max. gas 4271 units SPR's @ 18,401'MD 6330'TVD w/ 10.7 ppg @ 1354 hrs. #1 20/30 SPM 860/1247 psi #2 20/30 SPM 850/1283 psi Production section TD called @ 18,410' MD 6330'TVD 13:30 14:15 0.75 18,410 17,405 PROD1 CASING SRVY P Obtain TD MWD survey,torque and drag parameters and SPR's. 14:15 17:15 3.00 18,405 18,405 PROD1 CASING CIRC P Circ and cond mud increasing LSRV to 22,000 cP. 249 gpm, 3725 psi, 140 rpm,16.5 tq, 39% FO. Reduce pump rate to 240 gpm, 3600 psi and rotary top 130 rpm to reduce ECD. 17:15 19:15 2.00 18,405 17,383 PROD1 CASING BKRM P BROOH f/18,405'MD t/17,838 MD holding 12.1 ppg EMW @ shoe w/MPD.240 gpm, 3600 psi, 17k tq, 25%FO 19:15 20:00 0.75 17,383 17,383 PROD1 CASING RGRP T Replace mud pump#1 expansion boot. Page 32 of 40 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 17,383 16,418 PROD1 CASING BKRM P BROOH f/17,8385' MD t116,418 MD holding 12.1 ppg EMW @ shoe w/MPD. 240 gpm, 3500 psi, 15 k tq, 36%FO, PU 110 k. Calc disp=14.32 bbls Act disp=19.3 bbls Function test BOPE. 37/12/2015 BROOH f/16,418'to 12,100' MD.Hole packed off.Work pipe in tight hole to 12,505'MD. Establish circulation and build mud. BROOH to 12,155'MD 00:00 12:00 12.00 16,418 12,262 PROD1 CASING BKRM P Back ream out of hole f/16,418'to 12,262' MD @ 240 gpm @ 3075 psi w/130 rpm w/14ktorque-PUwt 115 ROT wt 110-Slowed rotary down to 110 rpm w/11 k torque& pulling speed to 550'/hr @ 12,500'- ECD-12.44 ppg Calc fill 28 bbls-Actual 68.3 bbls OA-630 psi 12:00 12:45 0.75 12,262 12,100 PROD1 CASING BKRM P Back ream out of hole f/12,262'to 12,100' MD @ 240 gpm @ 3075 psi w/110 rpm w/11 k torque-27%FO. Hole packed off. 12:45 13:15 0.50 12,100 12,125 PROD1 CASING CIRC T RIH f/12,100 MD t/12,125' MD. Establish rotation. Unable to circ. 100%loss rate. 13:15 14:00 0.75 12,125 12,155 PROD1 CASING OTHR T RIH f/12,125' MDt/12,155' MD. Attempt to circ. No returns. Establish rotation with frequent _ stalls. 14:00 15:15 1.25 12,155 12,505 PROD1 CASING OTHR T Work tight hole f/12,155'MD t/12,430' MD. Establish rotation. Attempt to circ. 1 bpm @ 1200 psi. No returns. RIH to 12,505'MD. Establish circ @ 1 bpm. Slight returns. 15:15 18:00 2.75 12,505 12,505 PROD1 CASING CIRC T Stage pump to 3 bpm, 2075 psi, 7k tq, Loss rate= 104 bph. Slow pump to 2 bpm, 1350 psi,7k tq. Loss rate =20 bph. Mix 100 bbls 10.7 ppg mud. Slow pump to 1.5 bpm, 1225 psi 13% FO. 18:00 18:30 0.50 12,505 12,505 PROD1 CASING CIRC T Stage pump up to 4 bpm. Loss rate to 20 bph. Slow pump to 3.5 bpm. 1950 psi, 24% FO 18:30 00:00 5.50 12,505 12,155 PROD1 CASING BKRM T BROOH f112,505'MD t112,174'MD. 3.5 bpm, 1950 psi,24% FO, 110 rpm, 11k tq. Slight reduction in returns observed. RIH to 12,184' MD. Regain full returns. Continue to BROOH t112,155'MD @ 20 fph. Total losses for tour=250 bbls. 37/13/2015 BROOH to 11,979'MD. CBU x2. Perform exhale test w/MPD. RIH to 12736'MD. Perform exhale test w/ MPD. Spot 11.6 ppg hi vis mud pill at bit. Page 33 of 40 --- ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:15 5.25 12,155 12,096 PROD1 CASING BKRM T Cont. BROOH f/12,168'to 12,018' @ 155 gpm w/110 rpm w/11 k torque @ 25 to 40 ft/hr.-Returns slow f/ 20%to 12%flow out @ 12,018'-- worked pipe down to 12,096'- Regained rotation&returns-Staged pump up to 2 bbls/min. @ 1450 psi- 110rpm @11 to12ktorque- Lost 225 bbls OA 620 psi 05:15 12:00 6.75 12,096 11,979 PROD1 CASING BKRM P Cont. BROOH f/12,096'to 11,979'- ROT wt 110( BHA inside 7 5/8"csg Lost 225 bbls OA 620 psi 12:00 15:45 3.75 11,979 11,979 PROD1 CASING CIRC P Circ 2 X btms up+ stage pump up f/ 86 gpm @ 1350 psi to 234 gpm @ 2950 psi(FCP 2800 psi) 120 rpm w/ 30%flow out-PU wt 123 SO wt 105 SPR's @ 11,944'MD 6265'TVD w/ 10.7 ppg @ 15:15 hrs. #1 20/30 SPM 700/1020 psi #2 20/30 SPM 730/1100 psi 15:45 16:00 0.25 11,979 11,979 PROD1 CASING OWFF T PJSM-Confirmed wellbore breathing w/Exhale test w/MPD 16:00 22:30 6.50 11,979 12,736 PROD1 CASING REAM P RIH f/11,979' MD t/12,736' MD. 3 bpm,1500 psi, 50 rpm, 10-14k tq. Calc disp=4.45 bbls Act disp=29.51 bbls. PU 135k SO 105k ROT 112k. Hole took 5-8k down weight @ 12,000', 12,063', 12,177', 12,272'and 12,304'. 22:30 23:15 0.75 12,736 12,736 PROD1 CASING OWFF T Confirmed wellbore breathing w/ Exhale test w/MPD 23:15 00:00 0.75 12,736 12,727 PROD1 CASING DISP P Pump 40 bbls 11.6 ppg hi vis pill to bit. 3 bpm, 1650 spm,45 rpm, 11 k tq, FO 15% 07/14/2015 Lay in 11.6 ppg mud hi vis pill from 12,736'to 11, 974'MD. Perform exhale test. Spot and lay 11.6 ppg brine hi vis pill from 11,974'to 11,505' MD. Perform exhale test. Displace well to 11.6 ppg brine. OWFF. Remove RCD and install trip nipple. Rig down circ lines. Pump out of hole to 11028'MD. POOH on elevators to 9216' MD..Work through tight hole©9216' MD. POOH to 4034'MD. 00:00 01:30 1.50 12,727 11,974 PROD1 CASING BKRM P BROOH laying in 11.6 ppg hi vis mud pill f/12727'MD t111974'MD.8 spm, 900 psi, 45 rom, 11-14k tq. PU 150k. 01:30 02:30 1.00 11,974 11,974 PROD1 CASING OWFF T Confirmed wellbore breathing w/ Exhale test w/MPD 02:30 03:30 1.00 11,974 11,974 PROD1 CASING DISP P Pump and spot 30 bbl 11.6 ppg hi vis brine pill and 30 bbl 11.6 ppg hi vis brine spacer at the bit. Page 34 of 40 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:30 04:30 1.00 11,974 11,505 PROD1 CASING PMPO P Pump out of hole laying in 30 bbl 11.6 ppg hi vis brine pill f/11,974 MD t/11,505'MD. Leave 30 bbls 11.6 ppg hi vis spacer in DP. 8 spm,600 psi. PU 225K. Calc disp=2.8 bbls Act disp=17.4 bbls. 04:30 05:30 1.00 11,505 11,505 PROD1 CASING OWFF T Confirmed wellbore breathing w/ Exhale test w/MPD. Sim-ops. PJSM on displacing well to 11.6 ppg brine. 05:30 07:30 2.00 11,505 11,505 PROD1 CASING DISP P Displace 10.7 ppg Flo Thru mud to 11.6 ppg brine. 210 gpm, 1850 psi,12.13 ECD, 50 rpm, 11K tq 07:30 11:00 3.50 11,505 11,505 PROD1 CASING OWFF P OWFF. 3.8 bph flow tapering off to static. 11:00 12:00 1.00 11,505 11,505 PROD1 CASING MPDA P Blow down MPD choke sys. Rig down circulating lines and hoses. 12:00 13:30 1.50 11,505 11,505 PROD1 CASING MPDA P Pull RCD. Install trip nipple. Drop 2.22"rabbit. 13:30 14:45 1.25 11,505 11,505 PROD1 CASING MPDA P Rig down circ hoses. Line up hoses for trip tank, bleeder line and mud bucket. Sim-ops/Clean trip tank,jet flow line and clean under shakers 14:45 16:45 2.00 11,505 11,505 PROD1 CASING SLPC P Slip and cut 71'drlg line. Monitor well w/trip tank. Establish static loss rate of 2 bph. 16:45 17:30 0.75 11,505 11,028 PROD1 CASING PMPO P Pump out of hole f/11,505 MD t/11,028' MD. 120 gpm, 525 psi. 2000 fph trip speed. 17:30 20:15 2.75 11,028 9,216 PROD1 CASING TRIP P POOH on elevators as per trip schedule. SPR's @ 10,060'MD 5409"TVD w/ 11.6+ppg @ 19000 hrs #1 20/30 SPM 540/960 psi #2 20/30 SPM 480/940 psi 20:15 21:00 0.75 9,216 9,216 PROD1 CASING OTHR T Tag tight hole @ 9216'MD.Attempt to pull through w/70k overpull x 3. Depth correlates to LWD stab hanging up on 7 5/8"stage collar. Brk circ and rotate @ 20 rpm, 10k tq, 3 bpm, 900 psi, 12% FO. Unable to pull through. Increase rotary to 50 rpm, 10k tq, Unable to pull through. Stop rotation. Pull through w/pump and 20k overpull. RIH through problem area. No issues going through area up and down. 21:00 00:00 3.00 9,216 4,034 PROD1 CASING TRIP P Pull power drive and bit through area with no issues. Con't to POOH on elevators as per trip schedule to 4034' MD. Calc disp=41.43 bbls Act disp=49.27 bbls PU 80K SO 64K Page 35 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/15/2015 24 hr Summary POOH to 440'MD. OWFF. L/D HWDP. OWFF.L/D BHA to156' MD.Remove nuclear sources. Recover debris in trip nipple. Con't to L/D BHA Work thru obstruction in wear ring. Recover debris from BOPE. L/D BHA. Flush out BOPE. Test annular preventer w/3 1/2"and 4 1/2"test joints. Rig up and run 4 1/2"slotted liner to 1000' MD. 10 joints run out of order. L/D wrong joints and P/U correct ones. Run 4 1/2"slotted liner to 6501' MD. M/U hanger/packer assy's. 00:00 02:00 2.00 4,034 440 PROD1 CASING TRIP P Cont to POOH on elevators f/4034' MD to 2700' MD pull 50K over @ 2700' MD and work pipe 50'until over pull was gone. Cont to POOH t/440' MD. 02:00 02:30 0.50 440 440 PROD1 CASING OWFF P OWFF for 30 min, slight loss. SIMOPS, hold PJSM on removing nuclear sources. 02:30 03:15 0.75 440 225 PROD1 CASING BHAH P Pick up SLB equipment from beaver slide, POOH laying down 4" HWDP 5 joints)and Jars. 03:15 03:45 0.50 225 225 PROD1 CASING OWFF P OWFF on last stand of HWDP for 30 _ min, slight loss 03:45 04:15 0.50 225 156 PROD1 CASING BHAH P Cont to L/D BHA to 156'MD.Actual displacement=32 bbls, Calculated displacement=30 bbls. 04:15 05:00 0.75 156 156 PROD1 CASING BHAH P Remove nuclear sources from LWD tools. Drain stack and observe 7 5/8" silver bullet debris at trip nipple. Retrieve debris. 05:00 06:30 1.50 156 0 PROD1 CASING BHAH P Con't to lay down BHA. Bit pulling tight through wear ring. 5k overpull. 06:30 07:30 1.00 0 0 PROD1 CASING OTHR T Observe 7 5/8"silver bullet debris at wear ring. Flood stack and retrieve debris. 07:30 08:30 1.00 0 0 PROD1 CASING BHAH P Con't to lay down BHA 08:30 09:45 1.25 0 0 COMPZ CASING WWWH P Pull wear ring. Flush out BOPE. Blow down choke and kill lines 09:45 12:00 2.25 0 0 COMPZ CASING BOPE P Rig up test equip. Test annular preventer w/4 1/2"&3 1/2"test joints. 250 psi low/2500 psi high-5 mins each on chart. Rig down test equip and set 10"ID wear ring. 12:00 13:45 1.75 0 0 COMPZ CASING RURD P Rig up to run slotted liner. 13:45 15:45 2.00 0 1,000 COMPZ CASING PUTB P Pickup 4 1/2", 11.6#, L-80 IBTM slotted/blank liner to 1000'MD. 15:45 17:00 1.25 1,000 1,000 COMPZ CASING PUTB T Ran 10 jts.slotted liner from wrong row in pipe shed. Confirm error. Lay down 10 jts. slotted liner and pick up correct pipe. 17:00 22:15 5.25 1,000 6,501 COMPZ CASING PUTB P Pick up 4 1/2", 11.6#, L-80 IBTM slotted/blank liner f/1000'MD t/6501' MD. 22:15 22:30 0.25 6,501 6,501 COMPZ CASING RURD P Bring Baker equip.to rig floor. 22:30 23:45 1.25 6,501 6,567 COMPZ CASING OTHR P Make up Baker SBE, hanger and liner top packer assy's. Mix and set pal mix. Sim-ops/Rig down casing tongs. PU 80K SO 64K 23:45 00:00 0.25 6,567 6,567 COMPZ CASING RURD P Clear rig floor. Change out elevators. PU 1 std of DP and X-O. Page 36 of 40 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07/16/2015 24 hr Summary Circ through liner hanger assy.RIH whiner on DP to 11,960' MD. Brk circ and establish parameters. RIH w/liner on DP to 18,083'MD. Tight hole,wash liner down to 18,383'MD.Circ string volume. Set hanger and liner top packer.Test packer to 3000 psi/5 min's. Release from hanger. CBU x 2. Spot corrosion inhibitor.OWFF. POOH on elevators to 3,260'MD. 00:00 00:30 0.50 6,567 6,567 COMPZ CASING CIRC P PJSM, Circulate down 4-1/2"liner @ 3 bpm=100 psi 00:30 03:45 3.25 6,567 11,960 COMPZ CASING RUNL P RIH w/4-1/2"liner on drill pipe f/ 6567' MD to casing shoe @ 11960' MD, S/O=80K. 03:45 04:15 0.50 11,960 11,960 COMPZ CASING CIRC P Establish circulation @ 3 bpm=200 psi. ROT=95K @ 15 rpms w/7K Tq, P/U= 140K, S/0=95K. 04:15 10:30 6.25 11,960 18,083 COMPZ CASING RUNL P Cont to RIH w/4-1/2"liner on drill pipe f/ 11960' MD to 18083' MD. Unable to RIH on elevators past 18083' MD after multiple attempts. 10:30 12:45 2.25 18,083 18,383 COMPZ CASING RUNL P Break circ. Stage pump to 3 bpm, 300 psi. SO=60K.Wash liner down to 18,383'MD. Calc disp=67.04 bbls. Act disp=54.7 bbls. 12:45 13:15 0.50 18,383 18,383 COMPZ CASING CIRC P Circ drill string volume.4 bpm, 550 psi. 13:15 16:00 2.75 18,383 11,773 COMPZ CASING PACK P Drop 1 3/4"phenolic ball. Pump down @ 3 bpm, 300 psi. Pump on seat @ 2 bpm, 175 psi. Pressure up and hold to 1900 psi to set hanger. Pressure up to 3000 psi and hold for 10 mins. Pressure up to 3800 psi to set liner top packer and observe shear. Bleed off and test annulus to 3000 psi/5 min.After several attempts pulled out and released seals w/50K overpull. PU=195K. Stand back one stand of DP to 11,773' MD. 16:00 17:30 1.50 11,773 11,773 COMPZ WELLPF CIRC P CBU x 2 @ 11,773' MD. Stage pump up to 8 bpm, 1425 psi, 24%FO. 17:30 18:00 0.50 11,773 11,773 COMPZ WELLPF CRIH P Pump 27 bbls brine w/Congor 303A corrosion inhibitor and spot from 11,773'MD to 11,184' MD. 18:00 19:30 1.50 11,773 11,773 COMPZ WELLPF OWFF P OWFF. Slight flow tapering off to static. Blow down TD. 19:30 00:00 4.50 11,773 3,260 COMPZ WELLPF TRIP P POOH on elevators f/11,773' MD t/3260' MD X7/17/2015 POOH. Lay down liner running tool. Pull wear ring. Rig up to test BOPE. Test BOPE w/3 1/2"test jt. Rig down test equip. Rig up to run upper completion. MU seal assy and mirage plug.Test to 1000 psi/5 min. MU D nipple, sliding sleeve and GLM. Test to 1000 psi/5 min.RIH w/3 1/2"9.3#, EUE 8rd MOD L-80 upper completion to 4837' MD. Test tbg to 3000 psi/5 min. RIH w/3 1/2"9.3#, EUE 8rd MOD L-80 upper completion to 9910'MD 00:00 01:30 1.50 3,260 64 COMPZ WELLPF TRIP P PJSM, Cont to POOH f/3260'MD to 64'MD.Actual displacement=20.4 bbls, Calculated displacement= 19 bbls. 01:30 02:15 0.75 64 0 COMPZ WELLPF PULD P L/D HRDE running tool as per Baker rep. Page 37 of 40 Time Logs • • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:15 02:45 0.50 0 0 COMPZ WELLPF RURD P Pull wear bushing. 02:45 03:45 1.00 0 0 COMPZ WHDBO RURD P Rig up to test BOPE. 03:45 04:00 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on testing BOPE. 04:00 09:00 5.00 0 0 COMPZ WHDBO BOPE P Test BOPE w/3-1/2"test joint to 250/3500 psi. for 5 minutes each. Test#1: Top rams, CV,1,12,13,14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: CV 5,8 and 10. Test#4; Dart valve, CV 4,6, and 7. Test#5; Floor valve and CV 2. Test#6: HCR choke. Test#7: Manual choke and HCR kill. Test#8:Annular preventer to 250/2500 psi. Test#9: Lower pipe rams. Test#10: Blind rams, Test#11: Lower IBOP. Accumulator test:system pressure= 2950 psi, pressure after closing= 1750 psi,200 psi attained after 46 sec,full pressure attained after 184 sec. Five bottle nitrogen avg=2025 psi.AOGCC inspector Johnnie Hill waived witness. 09:00 09:45 0.75 0 0 COMPZ WHDBO RURD P Rig down testing equipment and blow down choke/kill lines. 09:45 11:00 1.25 0 0 COMPZ RPCOM RURD P Rig up to run 3-1/2"EUE upper completion. 11:00 11:45 0.75 0 75 COMPZ RPCOM PUTB P Run 3 1/2"EUE 8rd mod 9.3#L-80 upper completion as per detail. MU seal assy, 1 jt 3 1/2"tbg and mirage plug. 11:45 12:00 0.25 75 75 COMPZ RPCOM DHEQ P Rig up and test mirage plug to 1000 psi/5 min. 12:00 12:30 0.50 75 187 COMPZ RPCOM PUTB P Con't RIH w/3 1/2"EUE 8rd mod 9.3#L-80 upper completion as per detail. PU D nipple, CMU sliding sleeve, GLM w/SOV and 1 jt 3 1/2" tbg. 12:30 12:45 0.25 187 187 COMPZ RPCOM DHEQ P Test completion components to 1000 psi/5 mins. 12:45 18:30 5.75 187 4,837 COMPZ RPCOM PUTB P RIH w/3 1/2" EUE 8rd mod 9.3# L-80 upper completion to 4837'MD. 18:30 19:15 0.75 4,837 4,837 COMPZ RPCOM DHEQ P Test tubing to 3000 psi/5 mins 19:15 00:00 4.75 4,837 9,910 COMPZ RPCOM PUTB P RIH w/3 1/2" EUE 8rd mod 9.3# L-80 upper completion to 9910' MD. PU 98K SO 58K. Calc disp=30.78 bbls Act disp=25.5 bbls 07/18/2015 RIH w/3 1/2"9.3#, EUE 8rd MOD L-80 upper completion and tag no-go @ 11,876'MD. Rig up and test tbg to 3500 psi/5 min. Bleed to 2500 psi.Test IA to 3500 psi/30 mins. Space out and land upper completion 3.90'off of no-go. RILDS and test hanger seals to 5000 psi. ND BOPE. NU tree.Erect cellar scaffold. Reorient master valve on tree. Test tree to 5000 psi. Pull BPV.Test tbg to 3500 psi/30 min. Page 38 of 40 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 9,910 11,876 COMPZ RPCOM PUTB P PJSM, Cont to RIH w/3-1/2"EUE upper completion f/9910'MD to No-Go @ 11876.40' MD.Actual displacement=5.44 bbls. Calculated displacement=7.09 bbls. 02:30 02:45 0.25 11,876 11,850 COMPZ RPCOM RURD P Lay down 1 joint of 3-1.2"tbg and rig up circulating equipment. 02:45 03:00 0.25 11,850 11,876 COMPZ RPCOM PUTS P RIH w/tbg,set down 25K @ 11876.40'MD 03:00 04:00 1.00 11,876 11,876 COMPZ RPCOM RURD P Cont to rig up to test 3-1/2"tbg and IA. 04:00 05:15 1.25 11,876 11,876 COMPZ RPCOM PRTS P Pressure test tbg to 3500 psi for 5 min, bleed tbg to 2500 psi. Pressure test IA to 3500 psi for 30 minutes on chart,good test. Bleed off IA and tbg pressure. 05:15 07:45 2.50 11,876 11,876 COMPZ RPCOM HOSO P Pick up 3-3 1/2"EUE pup joints from beaver slide. Lay down 4 joints of 3-1/2"tbg, M/U space out pups 10.26', 10.20'and 2.52'),XO and 1 joint of 4-1/2"IBTM tbg. M/U hanger and landing joint. 07:45 09:15 1.50 11,876 0 COMPZ RPCOM THGR P Land tbg hanger. RILDS. Test hanger seals 250/5000 psi/10 mins. (Tbg tail set @ 11872' MD. BPV installed and tested). Sim-ops/Clean and clear rig floor. 09:15 11:30 2.25 0 0 COMPZ WHDBO NUND P ND MPD equip, Rig down scaffold. ND BOPE. 11:30 12:00 0.50 0 0 COMPZ WHDBO OTHR P Mobilize tree adapter spool in cellar and prep to install. 12:00 14:30 2.50 0 0 COMPZ WHDBO NUND P NU tree adapter spool. Test SRL seal to 5000 psi/5 mins. RU and test adapter void to 250 psi/5 min 5000 psi/10 mins. 14:30 15:00 0.50 0 0 COMPZ WHDBO NUND P NU tree. 15:00 16:15 1.25 0 0 COMPZ WHDBO OTHR P Erect cellar scaffold around tree. 16:15 18:15 2.00 0 0 COMPZ WHDBO NUND T Reorient master valve on tree 18:15 19:15 1.00 0 0 COMPZ WHDBO PRTS P Test tree to 5000 psi/15 mins. 19:15 21:30 2.25 0 0 COMPZ WHDBO MPSP P Pull BPV test dart. Rig up lubricator and test to 2000 psi. Pull BPV and rig down lubricator. RU circ lines 21:30 22:30 1.00 0 0 COMPZ WHDBO SEQP P Flood circ lines. Test lines to 4500 psi. 22:30 00:00 1.50 0 0 COMPZ WHDBO PRTS P Test tbg to 3500 psi/30 mins on chart 07/19/2015 Test IA to 3500 psi.Activate mirage plug. Bullhead 10 bbls brine. Shear SOV. Freeze protect well. Set BPV and secure well. Lay down 4" DP. 00:00 01:00 1.00 0 0 COMPZ WHDBO PRTS P PJSM, Cont pressure testing tbg t/ 3500 psi for 30 min on chart,good. Bleed tbg down to 2500 psi and pressure test IA to 3500 psi for 30 minutes on chart, good. Page 39 of 40 Time Logs •` • Date From` To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 0 0 COMPZ WHDBO CIRC P Bleed pressure off IA. Pressure up tbg to 4500 psi, observed Mirage plug shear at 4500 psi. Bullhead 10 bbls @ 3 bpm, 900 psi to clear debris around Mirage plug. Shut down pump and bleed off pressure, pressure up IA to 3450 psi to shear SOV in GLM#2 @ 11726'MD. 01:45 02:30 0.75 0 0 COMPZ WHDBO SFTY P Hold PJSM on freeze protecting well, taking returns though rig choke. 02:30 07:30 5.00 0 0 COMPZ WHDBO FRZP P Freeze protect well, pumped 540 bbls of diesel w/LRS taking returns though rig choke. ICP=1000 psi, Pump pressure when diesel turned the corner=2400 psi, FCP=2450. Lost 26 bbls to formation while pumping freeze protect. Observed 10.9 ppg fluid back at the end diesel/brine mix. Shut in well pressure= 1600 psi. 07:30 08:30 1.00 0 0 COMPZ WHDBO MPDA P Nipple down MPD air valve to allow for mouse hole installation. SIMOPS, allow diesel to U-tube due to not getting diesel back to surface. 08:30 09:45 1.25 0 0 COMPZ WHDBO MPSP P M/U lubricator and test to 2500 psi. Install 4"H plug BPV. 09:45 12:00 2.25 0 0 DEMOB MOVE OTHR P Blow down circulating lines and rig down. Rig down scaffolding in cellar and install blank flanges on tree. SIMOPS, R/U to LID 4"drill pipe. 12:00 00:00 12.00 0 0 DEMOB MOVE PULD P Lay down 4"DP using mouse hole. IA=1176 psi OA=50 psi 07/20/2015 Cleaned rig and prep to move to 2S-07. Rig released @ 6:00 hours. 00:00 06:00 6.00 0 0 DEMOB MOVE RURD P PJSM, Clean drip pan, cellar, pits and rockwasher. SIMOPS, C/O saver sub to 5"drill pipe,4-1/2" IF. Prep to move. Page 40of40 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-02 Definitive Survey Report 23 July, 2015pi NAD 27 . Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 2S-02 Well Position +N/-S 0.00 usft Northing: 5,930,029.92 usft Latitude: 70°13'11.996 N +EI-W 0.00 usft Easting: 481,279.68 usft Longitude: 150°9'3.690 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 6/25/2015 18.71 80.87 57,491 Design 2S-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 11.00 Survey Program Date 1t�'�li�iill�h„� - v,.,:�ill;t 1 �1111°1� From To � �'� 1 (usft) (usft) Survey(Wellbore) Tool Name Description _ - Survey Date 79.33 104.97 2S-02 Srvy#1 (2S-02) INC+TREND Inclinometer+known azi trend 6/15/2015 9:0 201.82 3,578.11 2S-02 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2015 9:2' 3,648.89 3,648.89 2S-02 Srvy#3 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 6/23/2015 9:G 3,742.01 11,912.22 2S-02 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 9:1: 11,989.16 11,989.16 2S-02 Srvy#5 INC+TREND(2S-02) INC+TREND Inclinometer+known azi trend 7/9/2015 9:53 12,041.60 18,322.24 2S-02 Srvy#6 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/9/2015 9:55 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,029.92 481,279.68 0.00 0.00 UNDEFINED 79.33 0.22 264.90 79.33 -68.17 -0.01 -0.10 5,930,029.91 481,279.58 0.42 -0.03 INC+TREND(1) 104.97 0.18 264.90 104.97 -42.53 -0.02 -0.19 5,930,029.90 481,279.49 0.16 -0.05 INC+TREND(1) 109.00 0.18 264.90 109.00 -38.50 -0.02 -0.20 5,930,029.90 481,279.48 0.10 -0.06 MWD+IFR-AK-CAZ-SC(2) NOT an Actual Survey 16"x 20" 201.82 0.28 264.90 201.82 54.32 -0.05 -0.58 5,930,029.87 481,279.10 0.10 -0.16 MWD+IFR-AK-CAZ-SC(2) 293.09 1.07 157.53 293.08 145.58 -0.86 -0.47 5,930,029.06 481,279.21 1.30 -0.93 MWD+IFR-AK-CAZ-SC(2) 384.26 3.66 146.85 384.17 236.67 -4.08 1.45 5,930,025.83 481,281.11 2.87 -3.73 MWD+IFR-AK-CAZ-SC(2) 476.47 6.34 145.93 476.02 328.52 -10.76 5.91 5,930,019.14 481,285.56 2.91 -9.44 MWD+IFR-AK-CAZ-SC(2) 567.55 5.97 145.89 566.57 419.07 -18.85 11.38 5,930,011.04 481,291.01 0.41 -16.33 MWD+IFR-AK-CAZ-SC(2) 7/23/2015 8:05:57AM Page 2 COMPASS 5000.1 Build 74 ill Schlumberger III Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5©147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5©147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°1100') (ft) Survey Tool Name 659.98 7.27 139.59 658.39 510.89 -27.29 17.87 5,930,002.59 481,297.48 1.61 -23.37 MWD+IFR-AK-CAZ-SC(2) 752.38 8.71 141.01 749.89 602.39 -37.18 26.06 5,929,992.68 481,305.64 1.57 -31.52 MWD+IFR-AK-CAZ-SC(2) 845.09 9.73 140.31 841.40 693.90 -48.66 35.48 5,929,981.18 481,315.04 1.11 -41.00 MWD+IFR-AK-CAZ-SC(2) 938.89 10.68 143.21 933.71 786.21 -61.72 45.75 5,929,968.09 481,325.27 1.15 -51.86 MWD+IFR-AK-CAZ-SC(2) 1,031.83 12.50 143.30 1,024.76 877.26 -76.68 56.92 5,929,953.10 481,336.40 1.96 -64.41 MWD+IFR-AK-CAZ-SC(2) 1,127.07 16.06 144.48 1,117.04 969.54 -95.68 70.74 5,929,934.08 481,350.17 3.75 -80.42 MWD+IFR-AK-CAZ-SC(2) 1,218.14 17.24 144.24 1,204.29 1,056.79 -116.88 85.94 5,929,912.84 481,365.32 1.30 -98.33 MWD+IFR-AK-CAZ-SC(2) 1,311.27 22.51 148.58 1,291.85 1,144.35 -143.31 103.31 5,929,886.37 481,382.63 5.87 -120.97 MWD+IFR-AK-CAZ-SC(2) 1,404.33 25.25 148.70 1,376.93 1,229.43 -175.48 122.91 5,929,854.15 481,402.15 2.94 -148.80 MWD+IFR-AK-CAZ-SC(2) 1,496.94 25.18 149.30 1,460.72 1,313.22 -209.30 143.23 5,929,820.29 481,422.38 0.29 -178.12 MWD+IFR-AK-CAZ-SC(2) 1,590.92 26.52 150.42 1,545.29 1,397.79 -244.74 163.80 5,929,784.80 481,442.86 1.52 -208.99 MWD+IFR-AK-CAZ-SC(2) 1,683.02 28.77 149.69 1,626.87 1,479.37 -281.76 185.14 5,929,747.73 481,464.10 2.47 -241.25 MWD+IFR-AK-CAZ-SC(2) 1,776.78 30.32 149.47 1,708.44 1,560.94 -321.62 208.55 5,929,707.81 481,487.41 1.66 -275.92 MWD+IFR-AK-CAZ-SC(2) 1,870.07 32.51 148.39 1,788.05 1,640.55 -363.26 233.65 5,929,666.11 481,512.41 2.42 -312.01 MWD+IFR-AK-CAZ-SC(2) 1,917.29 34.22 149.35 1,827.49 1,679.99 -385.49 247.07 5,929,643.85 481,525.77 3.79 -331.27 MWD+IFR-AK-CAZ-SC(2) 1,963.14 38.74 150.89 1,864.34 1,716.84 -409.13 260.63 5,929,620.18 481,539.27 10.06 -351.88 MWD+IFR-AK-CAZ-SC(2) 2,008.07 40.31 150.65 1,899.00 1,751.50 -434.08 274.60 5,929,595.20 481,553.17 3.51 -373.71 MWD+IFR-AK-CAZ-SC(2) 2,055.84 39.97 150.56 1,935.52 1,788.02 -460.91 289.71 5,929,568.33 481,568.22 0.72 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,150.11 41.79 151.87 2,006.79 1,859.29 -514.99 319.41 5,929,514.19 481,597.78 2.13 -444.58 MWD+IFR-AK-CAZ-SC(2) 2,242.85 46.57 154.41 2,073.29 1,925.79 -572.65 348.54 5,929,456.46 481,626.76 5.50 -495.62 MWD+IFR-AK-CAZ-SC(2) 2,286.63 48.32 156.29 2,102.89 1,955.39 -601.96 361.98 5,929,427.12 481,640.13 5.10 -521.83 MWD+IFR-AK-CAZ-SC(2) 2,335.33 49.78 156.21 2,134.81 1,987.31 -635.63 376.80 5,929,393.42 481,654.86 3.00 -552.05 MWD+IFR-AK-CAZ-SC(2) 2,428.08 53.30 158.80 2,192.50 2,045.00 -702.72 404.54 5,929,326.27 481,682.43 4.38 -612.62 MWD+IFR-AK-CAZ-SC(2) 2,521.26 57.96 160.39 2,245.09 2,097.59 -774.79 431.32 5,929,254.13 481,709.03 5.20 -678.26 MWD+IFR-AK-CAZ-SC(2) 2,569.60 59.50 161.11 2,270.18 2,122.68 -813.80 444.94 5,929,215.10 481,722.55 3.43 -713.95 MWD+IFR-AK-CAZ-SC(2) 2,613.01 61.40 161.94 2,291.59 2,144.09 -849.62 456.90 5,929,179.26 481,734.43 4.68 -746.83 MWD+IFR-AK-CAZ-SC(2) 2,705.53 62.56 161.79 2,335.05 2,187.55 -927.23 482.32 5,929,101.58 481,759.65 1.26 -818.17 MWD+IFR-AK-CAZ-SC(2) 2,798.27 65.76 161.39 2,375.47 2,227.97 -1,006.42 508.68 5,929,022.34 481,785.81 3.47 -890.87 MWD+IFR-AK-CAZ-SC(2) 2,891.22 67.27 161.00 2,412.51 2,265.01 -1,087.11 536.16 5,928,941.59 481,813.09 1.67 -964.84 MWD+IFR-AK-CAZ-SC(2) 2,984.44 69.93 162.04 2,446.52 2,299.02 -1,169.42 563.66 5,928,859.22 481,840.39 3.04 -1,040.39 MWD+IFR-AK-CAZ-SC(2) 3,078.50 71.80 159.42 2,477.35 2,329.85 -1,253.29 593.00 5,928,775.28 481,869.51 3.30 -1,117.12 MWD+IFR-AK-CAZ-SC(2) 3,172.25 70.97 160.32 2,507.28 2,359.78 -1,336.71 623.58 5,928,691.80 481,899.88 1.27 -1,193.17 MWD+IFR-AK-CAZ-SC(2) 3,264.83 72.52 159.74 2,536.28 2,388.78 -1,419.34 653.60 5,928,609.10 481,929.70 1.78 -1,268.55 MWD+IFR-AK-CAZ-SC(2) 3,358.77 72.44 159.49 2,564.56 2,417.06 -1,503.31 684.81 5,928,525.06 481,960.69 0.27 -1,345.02 MWD+IFR-AK-CAZ-SC(2) 3,451.37 72.53 160.02 2,592.43 2,444.93 -1,586.16 715.36 5,928,442.15 481,991.04 0.55 -1,420.52 MWD+IFR-AK-CAZ-SC(2) 3,546.33 71.19 159.61 2,621.99 2,474.49 -1,670.86 746.50 5,928,357.38 482,021.96 1.47 -1,497.72 MWD+IFR-AK-CAZ-SC(2) 3,578.11 71.31 159.61 2,632.21 2,484.71 -1,699.07 756.98 5,928,329.15 482,032.37 0.38 -1,523.41 MWD+IFR-AK-CAZ-SC(2) 3,644.00 71.11 159.61 2,653.43 2,505.93 -1,757.54 778.72 5,928,270.63 482,053 96 0.31 -1,576.66 INC+TREND(3) 10 3/4"x 13-1/2 NOT an Actual Survey 3,648.89 71.09 159.61 2,655.02 2,507.52 -1,761.87 780.33 5,928,266.29 482,055.56 0.31 -1,580.61 INC+TREND(3) 7/23/2015 8:05:57AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 3,742.01 71.54 159.30 2,684.85 2,537.35 -1,844.47 811.29 5,928,183.62 482,086.31 0.58 -1,655.78 MWD+IFR-AK-CAZ-SC(4) 3,834.63 71.75 158.62 2,714.02 2,566.52 -1,926.52 842.85 5,928,101.51 482,117.66 0.73 -1,730.30 MWD+IFR-AK-CAZ-SC(4) 3,928.68 70.66 158.64 2,744.32 2,596.82 -2,009.43 875.29 5,928,018.52 482,149.90 1.16 -1,805.50 MWD+IFR-AK-CAZ-SC(4) 4,021.82 70.21 157.67 2,775.51 2,628.01 -2,090.89 907.95 5,927,936.99 482,182.35 1.09 -1,879.23 MWD+IFR-AK-CAZ-SC(4) 4,116.49 70.22 157.64 2,807.55 2,660.05 -2,173.28 941.81 5,927,854.52 482,216.00 0.03 -1,953.65 MWD+IFR-AK-CAZ-SC(4) 4,208.85 70.08 157.94 2,838.92 2,691.42 -2,253.71 974.65 5,927,774.02 482,248.64 0.34 -2,026.33 MWD+IFR-AK-CAZ-SC(4) 4,301.47 70.19 158.12 2,870.39 2,722.89 -2,334.49 1,007.24 5,927,693.17 482,281.03 0.22 -2,099.41 MWD+IFR-AK-CAZ-SC(4) 4,395.70 70.15 158.11 2,902.35 2,754.85 -2,416.75 1,040.28 5,927,610.84 482,313.86 0.04 -2,173.85 MWD+IFR-AK-CAZ-SC(4) 4,490.64 67.56 160.37 2,936.60 2,789.10 -2,499.53 1,071.68 5,927,527.99 482,345.05 3.52 -2,249.12 MWD+IFR-AK-CAZ-SC(4) 4,582.81 62.88 164.08 2,975.23 2,827.73 -2,579.16 1,097.26 5,927,448.30 482,370.43 6.25 -2,322.41 MWD+IFR-AK-CAZ-SC(4) 4,630.09 60.60 165.42 2,997.62 2,850.12 -2,619.33 1,108.22 5,927,408.11 482,381.28 5.43 -2,359.75 MWD+IFR-AK-CAZ-SC(4) 4,676.10 58.54 167.88 3,020.92 2,873.42 -2,657.92 1,117.38 5,927,369.50 482,390.36 6.43 -2,395.88 MWD+IFR-AK-CAZ-SC(4) 4,725.53 59.59 166.29 3,046.34 2,898.84 -2,699.25 1,126.86 5,927,328.16 482,399.73 3.48 -2,434.64 MWD+IFR-AK-CAZ-SC(4) 4,772.57 61.65 164.84 3,069.41 2,921.91 -2,738.94 1,137.08 5,927,288.44 482,409.85 5.14 -2,471.65 MWD+IFR-AK-CAZ-SC(4) 4,864.70 65.99 161.23 3,110.06 2,962.56 -2,817.97 1,161.24 5,927,209.36 482,433.82 5.88 -2,544.62 MWD+IFR-AK-CAZ-SC(4) 4,900.29 66.83 160.26 3,124.30 2,976.80 -2,848.76 1,172.00 5,927,178.55 482,444.49 3.44 -2,572.79 MWD+IFR-AK-CAZ-SC(4) 4,958.75 68.93 159.28 3,146.32 2,998.82 -2,899.57 1,190.73 5,927,127.70 482,463.09 3.91 -2,619.09 MWD+IFR-AK-CAZ-SC(4) 5,053.27 71.58 158.24 3,178.25 3,030.75 -2,982.48 1,222.96 5,927,044.72 482,495.12 2.99 -2,694.33 MWD+IFR-AK-CAZ-SC(4) 5,145.24 73.20 158.71 3,206.07 3,058.57 -3,064.02 1,255.12 5,926,963.10 482,527.07 1.83 -2,768.24 MWD+IFR-AK-CAZ-SC(4) 5,239.23 73.24 158.10 3,233.21 3,085.71 -3,147.69 1,288.24 5,926,879.36 482,559.98 0.62 -2,844.05 MWD+IFR-AK-CAZ-SC(4) 5,333.60 72.65 158.08 3,260.88 3,113.38 -3,231.39 1,321.91 5,926,795.58 482,593.44 0.63 -2,919.79 MWD+IFR-AK-CAZ-SC(4) 5,426.03 72.23 157.84 3,288.77 3,141.27 -3,313.08 1,354.97 5,926,713.82 482,626.30 0.52 -2,993.67 MWD+IFR-AK-CAZ-SC(4) 5,518.53 71.93 157.99 3,317.23 3,169.73 -3,394.63 1,388.07 5,926,632.19 482,659.18 0.36 -3,067.41 MWD+IFR-AK-CAZ-SC(4) 5,612.19 72.30 159.66 3,346.00 3,198.50 -3,477.74 1,420.26 5,926,549.01 482,691.17 1.74 -3,142.85 MWD+IFR-AK-CAZ-SC(4) 5,705.92 72.76 160.94 3,374.14 3,226.64 -3,561.92 1,450.40 5,926,464.77 482,721.09 1.39 -3,219.73 MWD+IFR-AK-CAZ-SC(4) 5,797.08 72.74 161.57 3,401.17 3,253.67 -3,644.36 1,478.37 5,926,382.27 482,748.86 0.66 -3,295.31 MWD+IFR-AK-CAZ-SC(4) 5,891.34 72.85 161.49 3,429.05 3,281.55 -3,729.76 1,506.90 5,926,296.80 482,777.17 0.14 -3,373.71 MWD+IFR-AK-CAZ-SC(4) 5,984.46 72.80 161.75 3,456.55 3,309.05 -3,814.19 1,534.95 5,926,212.31 482,805.01 0.27 -3,451.23 MWD+IFR-AK-CAZ-SC(4) 6,079.38 73.01 161.81 3,484.45 3,336.95 -3,900.37 1,563.32 5,926,126.07 482,833.16 0.23 -3,530.41 MWD+IFR-AK-CAZ-SC(4) 6,171.92 73.48 161.79 3,511.13 3,363.63 -3,984.55 1,591.00 5,926,041.84 482,860.63 0.51 -3,607.76 MWD+IFR-AK-CAZ-SC(4) 6,264.70 73.23 163.38 3,537.70 3,390.20 -4,069.36 1,617.60 5,925,956.96 482,887.02 1.66 -3,685.94 MWD+IFR-AK-CAZ-SC(4) 6,357.62 72.81 164.24 3,564.84 3,417.34 -4,154.70 1,642.38 5,925,871.57 482,911.59 0.99 -3,764.99 MWD+IFR-AK-CAZ-SC(4) 6,452.00 71.09 165.34 3,594.08 3,446.58 -4,241.29 1,665.93 5,925,784.93 482,934.91 2.13 -3,845.49 MWD+IFR-AK-CAZ-SC(4) 6,546.56 70.82 164.30 3,624.94 3,477.44 -4,327.55 1,689.33 5,925,698.62 482,958.10 1.08 -3,925.71 MWD+IFR-AK-CAZ-SC(4) 6,639.39 71.21 163.09 3,655.14 3,507.64 -4,411.80 1,713.97 5,925,614.32 482,982.54 1.30 -4,003.70 MWD+IFR-AK-CAZ-SC(4) 6,733.34 71.59 162.16 3,685.11 3,537.61 -4,496.78 1,740.56 5,925,529.28 483,008.91 1.02 -4,082.05 MWD+IFR-AK-CAZ-SC(4) 6,825.99 71.56 160.77 3,714.39 3,566.89 -4,580.12 1,768.51 5,925,445.88 483,036.64 1.42 -4,158.52 MWD+IFR-AK-CAZ-SC(4) 6,919.67 71.13 160.08 3,744.36 3,596.86 -4,663.75 1,798.24 5,925,362.19 483,066.17 0.84 -4,234.94 MWD+IFR-AK-CAZ-SC(4) 7,012.84 70.59 159.36 3,774.91 3,627.41 -4,746.31 1,828.75 5,925,279.56 483,096.47 0.93 -4,310.16 MWD+IFR-AK-CAZ-SC(4) 7,106.80 69.91 158.28 3,806.66 3,659.16 -4,828.77 1,860.70 5,925,197.03 483,128.21 1.30 -4,385.01 MWD+IFR-AK-CAZ-SC(4) 7/23/2015 8:05:57AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger , Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5©147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (°/100') (ft) Survey Tool Name 7,199.18 69.17 156.41 3,838.95 3,691.45 -4,908.64 1,894.03 5,925,117.09 483,161.34 2.06 -4,457.05 MWD+IFR-AK-CAZ-SC(4) 7,244.76 69.03 154.84 3,855.21 3,707.71 -4,947.42 1,911 60 5,925,078.26 483,178.82 3.23 -4,491.77 MWD+IFR-AK-CAZ-SC(4) 7,291.38 68.76 153.04 3,872.00 3,724.50 -4,986.49 1,930.71 5,925,039.15 483,197.82 3.65 -4,526.48 MWD+IFR-AK-CAZ-SC(4) 7,383.77 68.23 150.58 3,905.87 3,758.37 -5,062.25 1,971.31 5,924,963.30 483,238.23 2.54 -4,593.10 MWD+IFR-AK-CAZ-SC(4) 7,432.28 67.46 150.46 3,924.17 3,776.67 -5,101.36 1,993.42 5,924,924.14 483,260.24 1.60 -4,627.27 MWD+IFR-AK-CAZ-SC(4) 7,476.60 66.79 148.64 3,941.40 3,793.90 -5,136.56 2,014.11 5,924,888.89 483,280.84 4.07 -4,657.88 MWD+IFR-AK-CAZ-SC(4) 7,523.30 65.95 148.04 3,960.12 3,812.62 -5,172.98 2,036.57 5,924,852.42 483,303.21 2.15 -4,689.34 MWD+IFR-AK-CAZ-SC(4) 7,569.49 64.77 146.66 3,979.37 3,831.87 -5,208.33 2,059.21 5,924,817.02 483,325.76 3.73 -4,719.72 MWD+IFR-AK-CAZ-SC(4) 7,661.87 62.68 144.63 4,020.27 3,872.77 -5,276.71 2,105.94 5,924,748.53 483,372.32 3.00 -4,777.93 MWD+IFR-AK-CAZ-SC(4) 7,708.63 61.42 143.44 4,042.19 3,894.69 -5,310.14 2,130.20 5,924,715.04 483,396.49 3.51 -4,806.12 MWD+IFR-AK-CAZ-SC(4) 7,754.64 60.43 143.18 4,064.54 3,917.04 -5,342.39 2,154.22 5,924,682.74 483,420.43 2.21 -4,833.19 MWD+IFR-AK-CAZ-SC(4) 7,847.12 58.64 141.38 4,111.43 3,963.93 -5,405.44 2,202.98 5,924,619.57 483,469.02 2.56 -4,885.78 MWD+IFR-AK-CAZ-SC(4) 7,941.74 57.14 140.05 4,161.73 4,014.23 -5,467.47 2,253.71 5,924,557.42 483,519.60 1.98 -4,936.99 MWD+IFR-AK-CAZ-SC(4) 8,033.51 55.79 138.38 4,212.43 4,064.93 -5,525.39 2,303.67 5,924,499.38 483,569.41 2.11 -4,984.32 MWD+IFR-AK-CAZ-SC(4) 8,126.93 54.30 137.04 4,265.95 4,118.45 -5,582.04 2,355.18 5,924,442.61 483,620.78 1.98 -5,030.09 MWD+IFR-AK-CAZ-SC(4) 8,219.65 54.14 135.68 4,320.16 4,172.66 -5,636.47 2,407.09 5,924,388.06 483,672.54 1.20 -5,073.62 MWD+IFR-AK-CAZ-SC(4) 8,311.71 53.98 133.46 4,374.20 4,226.70 -5,688.77 2,460.18 5,924,335.63 483,725.50 1.96 -5,114.83 MWD+IFR-AK-CAZ-SC(4) 8,405.19 54.41 131.05 4,428.90 4,281.40 -5,739.74 2,516.29 5,924,284.52 483,781.48 2.14 -5,154.16 MWD+IFR-AK-CAZ-SC(4) 8,498.51 55.01 129.12 4,482.81 4,335.31 -5,788.78 2,574.57 5,924,235.34 483,839.63 1.81 -5,191.18 MWD+IFR-AK-CAZ-SC(4) 8,589.66 55.80 126.01 4,534.57 4,387.07 -5,834.51 2,634.04 5,924,189.47 483,898.98 2.94 -5,224.72 MWD+IFR-AK-CAZ-SC(4) 8,683.20 56.08 124.26 4,586.96 4,439.46 -5,879.11 2,697.41 5,924,144.73 483,962.23 1.58 -5,256.40 MWD+IFR-AK-CAZ-SC(4) 8,776.27 55.77 122.48 4,639.11 4,491.61 -5,921.51 2,761.79 5,924,102.17 484,026.49 1.62 -5,285.74 MWD+IFR-AK-CAZ-SC(4) 8,871.20 55.23 119.36 4,692.89 4,545.39 -5,961.71 2,828.88 5,924,061.81 484,093.49 2.77 -5,312.40 MWD+IFR-AK-CAZ-SC(4) 8,964.80 55.26 115.26 4,746.26 4,598.76 -5,996.98 2,897.19 5,924,026.37 484,161.70 3.60 -5,333.98 MWD+IFR-AK-CAZ-SC(4) 9,058.92 54.33 110.96 4,800.54 4,653.04 -6,027.16 2,967.89 5,923,996.01 484,232.31 3.86 -5,350.13 MWD+IFR-AK-CAZ-SC(4) 9,151.26 53.08 107.55 4,855.21 4,707.71 -6,051.72 3,038.12 5,923,971.29 484,302.48 3.27 -5,360.83 MWD+IFR-AK-CAZ-SC(4) 9,244.59 51.90 103.86 4,912.05 4,764.55 -6,071.77 3,109.37 5,923,951.06 484,373.67 3.38 -5,366.92 MWD+IFR-AK-CAZ-SC(4) 9,339.64 51.68 101.01 4,970.85 4,823.35 -6,087.85 3,182.29 5,923,934.80 484,446.54 2.37 -5,368.79 MWD+IFR-AK-CAZ-SC(4) 9,433.65 52.18 96.95 5,028.83 4,881.33 -6,099.39 3,255.36 5,923,923.08 484,519.58 3.44 -5,366.17 MWD+IFR-AK-CAZ-SC(4) 9,527.85 52.70 93.07 5,086.27 4,938.77 -6,105.90 3,329.73 5,923,916.39 484,593.92 3.31 -5,358.37 MWD+IFR-AK-CAZ-SC(4) 9,622.63 53.06 89.50 5,143.48 4,995.98 -6,107.59 3,405.26 5,923,914.51 484,669.44 3.03 -5,345.62 MWD+IFR-AK-CAZ-SC(4) 9,714.35 53.01 86.72 5,198.64 5,051.14 -6,105.17 3,478.50 5,923,916.75 484,742.68 2.42 -5,329.27 MWD+IFR-AK-CAZ-SC(4) 9,807.43 52.81 82.83 5,254.79 5,107.29 -6,098.42 3,552.41 5,923,923.32 484,816.60 3.34 -5,308.54 MWD+IFR-AK-CAZ-SC(4) 9,900.31 52.10 79.93 5,311.39 5,163.89 -6,087.39 3,625.21 5,923,934.16 484,889.42 2.59 -5,283.82 MWD+IFR-AK-CAZ-SC(4) 9,993.05 51.94 77.10 5,368.47 5,220.97 -6,072.84 3,696.83 5,923,948.53 484,961.07 2.41 -5,255.87 MWD+IFR-AK-CAZ-SC(4) 10,084.97 52.38 74.60 5,424.87 5,277.37 -6,055.09 3,767.21 5,923,966.11 485,031.49 2.20 -5,225.02 MWD+IFR-AK-CAZ-SC(4) 10,177.14 52.85 71.05 5,480.84 5,333.34 -6,033.46 3,837.16 5,923,987.56 485,101.48 3.10 -5,190.45 MWD+IFR-AK-CAZ-SC(4) 10,270.67 53.68 68.96 5,536.79 5,389.29 -6,007.83 3,907.59 5,924,013.01 485,171.96 2.00 -5,151.85 MWD+IFR-AK-CAZ-SC(4) 10,363.78 54.22 67.13 5,591.58 5,444.08 -5,979.68 3,977.40 5,924,040.99 485,241.84 1.69 -5,110.90 MWD+IFR-AK-CAZ-SC(4) 10,458.74 55.60 65.62 5,646.17 5,498.67 -5,948.54 4,048.58 5,924,071.95 485,313.09 1.95 -5,066.74 MWD+IFR-AK-CAZ-SC(4) 7/23/2015 8:05:57AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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) (0/100') (ft) Survey Tool Name 10,552.81 57.15 64.24 5,698.27 5,550.77 -5,915.34 4,119.52 5,924,104.97 485,384.11 2.05 -5,020.62 MWD+IFR-AK-CAZ-SC(4) 10,645.30 59.32 63.18 5,746.95 5,599.45 -5,880.51 4,190.02 5,924,139.62 485,454.68 2.54 -4,972.97 MWD+IFR-AK-CAZ-SC(4) 10,738.02 60.40 61.18 5,793.51 5,646.01 -5,843.08 4,260.92 5,924,176.87 485,525.67 2.20 -4,922.71 MWD+IFR-AK-CAZ-SC(4) 10,829.90 61.81 59.02 5,837.91 5,690.41 -5,802.98 4,330.64 5,924,216.79 485,595.49 2.57 -4,870.04 MWD+IFR-AK-CAZ-SC(4) 10,922.36 63.14 56.63 5,880.65 5,733.15 -5,759.31 4,400.03 5,924,260.28 485,664.98 2.71 -4,813.93 MWD+I F R-AK-CAZ-SC(4) 11,015.52 64.31 54.14 5,921.89 5,774.39 -5,711.86 4,468.77 5,924,307.56 485,733.82 2.71 -4,754.24 MWD+IFR-AK-CAZ-SC(4) 11,108.81 65.52 51.16 5,961.45 5,813.95 -5,660.60 4,535.91 5,924,358.65 485,801.09 3.17 -4,691.11 MWD+IFR-AK-CAZ-SC(4) 11,200.77 65.87 48.49 5,999.30 5,851.80 -5,606.54 4,599.94 5,924,412.55 485,865.24 2.67 -4,625.82 MWD+IFR-AK-CAZ-SC(4) 11,294.57 66.41 45.46 6,037.25 5,889.75 -5,548.01 4,662.64 5,924,470.91 485,928.08 3.01 -4,556.41 MWD+IFR-AK-CAZ-SC(4) 11,392.75 67.00 43.08 6,076.08 5,928.58 -5,483.44 4,725.58 5,924,535.32 485,991.17 2.31 -4,481.02 MWD+IFR-AK-CAZ-SC(4) 11,480.49 66.94 40.75 6,110.41 5,962.91 -5,423.36 4,779.51 5,924,595.26 486,045.25 2.44 -4,411.75 MWD+IFR-AK-CAZ-SC(4) 11,573.13 67.76 38.17 6,146.09 5,998.59 -5,357.36 4,833.84 5,924,661.12 486,099.73 2.72 -4,336.59 MWD+IFR-AK-CAZ-SC(4) 11,666.15 69.27 36.07 6,180.17 6,032.67 -5,288.34 4,886.06 5,924,730.00 486,152.12 2.65 -4,258.88 MWD+I F R-AK-CAZ-SC(4) 11,760.11 71.22 34.01 6,211.93 6,064.43 -5,215.94 4,936.82 5,924,802.27 486,203.06 2.93 -4,178.12 MWD+I F R-AK-CAZ-SC(4) 11,853.07 73.37 32.41 6,240.20 6,092.70 -5,141.85 4,985.31 5,924,876.23 486,251.73 2.83 -4,096.14 MWD+IFR-AK-CAZ-SC(4) 11,912.22 74.51 31.42 6,256.56 6,109.06 -5,093.61 5,015.36 5,924,924.40 486,281.89 2.51 -4,043.05 MWD+IFR-AK-CAZ-SC(4) 11,981.20 75.85 29.70 6,274.21 6,126.71 -5,036.19 5,049.26 5,924,981.73 486,315.93 3.09 -3,980.21 INC+TREND(5) NOT an Actual Survey 11,989.16 76.00 29.50 6,276.14 6,128.64 -5,029.47 5,053.07 5,924,988.43 486,319.76 3.09 -3,972.89 INC+TREND(5) 12,041.60 76.56 29.08 6,288.58 6,141.08 -4,985.04 5,078.00 5,925,032.80 486,344.79 1.32 -3,924.52 MWD+IFR-AK-CAZ-SC(6) 12,085.66 77.20 27.55 6,298.58 6,151.08 -4,947.27 5,098.35 5,925,070.52 486,365.23 3.68 -3,883.56 MWD+IFR-AK-CAZ-SC(6) 12,180.07 78.74 25.28 6,318.26 6,170.76 -4,864.58 5,139.42 5,925,153.10 486,406.50 2.86 -3,794.55 MWD+IFR-AK-CAZ-SC(6) 12,273.61 80.14 25.32 6,335.40 6,187.90 -4,781.44 5,178.71 5,925,236.12 486,446.00 1.50 -3,705.45 MWD+IFR-AK-CAZ-SC(6) 12,366.85 81.43 24.24 6,350.34 6,202.84 -4,697.88 5,217.29 5,925,319.58 486,484.78 1.79 -3,616.06 MWD+IFR-AK-CAZ-SC(6) 12,462.43 82.97 21.75 6,363.31 6,215.81 -4,610.72 5,254.27 5,925,406.64 486,521.98 3.04 -3,523.45 MWD+IFR-AK-CAZ-SC(6) 12,558.53 86.12 17.32 6,372.45 6,224.95 -4,520.59 5,286.24 5,925,496.68 486,554.16 5.64 -3,428.87 MWD+IFR-AK-CAZ-SC(6) 12,652.45 89.07 15.26 6,376.39 6,228.89 -4,430.54 5,312.56 5,925,586.66 486,580.70 3.83 -3,335.45 MWD+IFR-AK-CAZ-SC(6) 12,748.08 91.43 14.83 6,375.97 6,228.47 -4,338.19 5,337.38 5,925,678.93 486,605.75 2.51 -3,240.07 MWD+IFR-AK-CAZ-SC(6) 12,840.91 90.82 13.06 6,374.15 6,226.65 -4,248.12 5,359.74 5,925,768.94 486,628.34 2.02 -3,147.38 MWD+IFR-AK-CAZ-SC(6) 12,936.69 90.23 11.54 6,373.27 6,225.77 -4,154.55 5,380.14 5,925,862.46 486,648.97 1.70 -3,051.63 MWD+IFR-AK-CAZ-SC(6) 13,031.39 91.04 10.76 6,372.22 6,224.72 -4,061.64 5,398.46 5,925,955.31 486,667.51 1.19 -2,956.94 MWD+IFR-AK-CAZ-SC(6) 13,125.78 89.77 10.33 6,371.55 6,224.05 -3,968.85 5,415.73 5,926,048.05 486,685.01 1.42 -2,862.56 MWD+IFR-AK-CAZ-SC(6) 13,217.62 91.25 9.42 6,370.74 6,223.24 -3,878.38 5,431.48 5,926,138.47 486,700.98 1.89 -2,770.74 MWD+IFR-AK-CAZ-SC(6) 13,313.95 90.50 9.24 6,369.27 6,221.77 -3,783.33 5,447.09 5,926,233.47 486,716.83 0.80 -2,674.47 MWD+IFR-AK-CAZ-SC(6) 13,408.13 91.40 8.19 6,367.70 6,220.20 -3,690.26 5,461.36 5,926,326.50 486,731.33 1.47 -2,580.38 MWD+IFR-AK-CAZ-SC(6) 13,501.25 91.16 8.66 6,365.62 6,218.12 -3,598.16 5,475.00 5,926,418.55 486,745.19 0.57 -2,487.38 MWD+IFR-AK-CAZ-SC(6) 13,597.30 90.78 8.52 6,364.00 6,216.50 -3,503.20 5,489.35 5,926,513.46 486,759.77 0.42 -2,391.42 MWD+IFR-AK-CAZ-SC(6) 13,692.32 91.13 9.21 6,362.41 6,214.91 -3,409.33 5,503.99 5,926,607.28 486,774.65 0.81 -2,296.48 MWD+IFR-AK-CAZ-SC(6) 13,787.60 90.12 9.85 6,361.38 6,213.88 -3,315.38 5,519.76 5,926,701.19 486,790.65 1.25 -2,201.24 MWD+IFR-AK-CAZ-SC(6) 13,881.69 90.71 9.54 6,360.69 6,213.19 -3,222.63 5,535.61 5,926,793.89 486,806.72 0.71 -2,107.18 MWD+IFR-AK-CAZ-SC(6) 7/23/2015 8:05:57AM Page 6 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,975.95 91.64 9.54 6,358.76 6,211.26 -3,129.70 5,551.22 5,926,886.78 486,822.57 0.99 -2,012.97 MWD+IFR-AK-CAZ SC(6) 14,070.90 92.19 9.51 6,355.59 6,208.09 -3,036.11 5,566.93 5,926,980.32 486,838.51 0.58 -1,918.11 MWD+IFR-AK-CAZ-SC(6) 14,165.40 92.19 9.82 6,351.98 6,204.48 -2,943.02 5,582.78 5,927,073.36 486,854.59 0.33 -1,823.70 MWD+IFR-AK-CAZ-SC(6) 14,260.57 91.85 10.70 6,348.62 6,201.12 -2,849.43 5,599.72 5,927,166.89 486,871.76 0.99 -1,728.60 MWD+I F R-AK-CAZ-SC(6) 14,355.12 90.84 12.39 6,346.40 6,198.90 -2,756.82 5,618.64 5,927,259.44 486,890.90 2.08 -1,634.08 MWD+IFR-AK-CAZ-SC(6) 14,450.54 91.47 12.88 6,344.48 6,196.98 -2,663.73 5,639.51 5,927,352.47 486,912.00 0.84 -1,538.72 MWD+IFR-AK-CAZ-SC(6) 14,542.74 91.33 13.52 6,342.23 6,194.73 -2,574.00 5,660.55 5,927,442.15 486,933.27 0.71 -1,446.62 MWD+IFR-AK-CAZ-SC(6) 14,637.09 91.72 13.33 6,339.72 6,192.22 -2,482.26 5,682.45 5,927,533.82 486,955.39 0.46 -1,352.39 MWD+IFR-AK-CAZ-SC(6) 14,729.99 90.51 13.65 6,337.91 6,190.41 -2,391.94 5,704.12 5,927,624.08 486,977.28 1.35 -1,259.59 MWD+IFR-AK-CAZ-SC(6) 14,825.07 90.27 14.80 6,337.26 6,189.76 -2,299.78 5,727.48 5,927,716.17 487,000.87 1.24 -1,164.67 MWD+IFR-AK-CAZ-SC(6) 14,918.24 89.50 14.89 6,337.45 6,189.95 -2,209.72 5,751.35 5,927,806.16 487,024.96 0.83 -1,071.71 MWD+IFR-AK-CAZ-SC(6) 15,012.99 91.06 16.71 6,336.98 6,189.48 -2,118.56 5,777.15 5,927,897.25 487,050.98 2.53 -977.30 MWD+IFR-AK-CAZ-SC(6) 15,109.46 88.90 21.71 6,337.02 6,189.52 -2,027.49 5,808.88 5,927,988.23 487,082.93 5.65 -881.85 MWD+IFR-AK-CAZ-SC(6) 15,155.64 88.11 24.11 6,338.22 6,190.72 -1,984.97 5,826.85 5,928,030.70 487,101.01 5.47 -836.69 MWD+IFR-AK-CAZ-SC(6) 15,203.05 87.35 26.99 6,340.10 6,192.60 -1,942.24 5,847.28 5,928,073.38 487,121.54 6.28 -790.84 MWD+IFR-AK-CAZ-SC(6) 15,266.54 86.85 26.23 6,343.31 6,195.81 -1,885.55 5,875.68 5,928,129.99 487,150.08 1.43 -729.77 MWD+IFR-AK-CAZ-SC(6) 15,296.93 87.70 25.29 6,344.76 6,197.26 -1,858.21 5,888.87 5,928,157.30 487,163.34 4.17 -700.42 MWD+IFR-AK-CAZ-SC(6) 15,390.37 90.51 24.83 6,346.22 6,198.72 -1,773.58 5,928.44 5,928,241.82 487,203.11 3.05 -609.80 MWD+IFR-AK-CAZ-SC(6) 15,485.53 89.69 24.19 6,346.05 6,198.55 -1,687.00 5,967.92 5,928,328.29 487,242.80 1.09 -517.27 MWD+IFR-AK-CAZ-SC(6) 15,580.57 88.86 23.36 6,347.25 6,199.75 -1,600.03 6,006.23 5,928,415.15 487,281.32 1.24 -424.59 MWD+IFR-AK-CAZ-SC(6) 15,675.57 88.06 21.93 6,349.81 6,202.31 -1,512.39 6,042.79 5,928,502.70 487,318.10 1.72 -331.58 MWD+IFR-AK-CAZ-SC(6) 15,724.65 88.94 21.15 6,351.09 6,203.59 -1,466.75 6,060.80 5,928,548.28 487,336.22 2.40 -283.35 MWD+I FR-AK-CAZ-SC(6) 15,767.01 87.75 20.42 6,352.32 6,204.82 -1,427.17 6,075.83 5,928,587.83 487,351.34 3.30 -241.63 MWD+IFR-AK-CAZ-SC(6) 15,864.87 87.80 19.71 6,356.12 6,208.62 -1,335.32 6,109.38 5,928,679.59 487,385.12 0.73 -145.06 MWD+IFR-AK-CAZ-SC(6) 15,959.89 87.63 18.52 6,359.90 6,212.40 -1,245.61 6,140.47 5,928,769.21 487,416.43 1.26 -51.07 MWD+IFR-AK-CAZ-SC(6) 16,052.49 86.51 16.98 6,364.64 6,217.14 -1,157.54 6,168.66 5,928,857.20 487,444.84 2.05 40.76 MWD+IFR-AK-CAZ-SC(6) 16,146.49 87.77 16.02 6,369.33 6,221.83 -1,067.52 6,195.32 5,928,947.14 487,471.72 1.68 134.21 MWD+IFR-AK-CAZ-SC(6) 16,240.28 85.24 13.28 6,375.05 6,227.55 -976.97 6,219.00 5,929,037.63 487,495.62 3.97 227.62 MWD+IFR-AK-CAZ-SC(6) 16,334.34 85.78 9.18 6,382.41 6,234.91 -885.01 6,237.26 5,929,129.53 487,514.10 4.38 321.37 MWD+IFR-AK-CAZ-SC(6) 16,430.14 90.29 6.68 6,385.70 6,238.20 -790.22 6,250.46 5,929,224.28 487,527.54 5.38 416.95 MWD+IFR-AK-CAZ-SC(6) 16,476.84 91.41 7.34 6,385.00 6,237.50 -743.87 6,256.16 5,929,270.61 487,533.35 2.78 463.53 MWD+IFR-AK-CAZ-SC(6) 16,524.03 91.86 8.10 6,383.66 6,236.16 -697.13 6,262.49 5,929,317.33 487,539.80 1.87 510.62 MWD+I FR-AK-CAZ-SC(6) 16,619.23 91.23 12.22 6,381.09 6,233.59 -603.48 6,279.28 5,929,410.93 487,556.81 4.38 605.75 MWD+IFR-AK-CAZ-SC(6) 16,714.90 90.93 13.77 6,379.29 6,231.79 -510.28 6,300.79 5,929,504.07 487,578.55 1.65 701.35 MWD+IFR-AK-CAZ-SC(6) 16,807.93 89.21 16.20 6,379.17 6,231.67 -420.42 6,324.84 5,929,593.86 487,602.82 3.20 794.14 MWD+IFR-AK-CAZ-SC(6) 16,903.20 91.24 16.21 6,378.80 6,231.30 -328.94 6,351.42 5,929,685.26 487,629.63 2.13 889.01 MWD+IFR-AK-CAZ-SC(6) 16,997.43 91.57 15.13 6,376.49 6,228.99 -238.24 6,376.87 5,929,775.89 487,655.30 1.20 982.90 MWD+IFR-AK-CAZ-SC(6) 17,090.93 92.88 13.92 6,372.86 6,225.36 -147.80 6,400.30 5,929,866.26 487,678.95 1.91 1,076.15 MWD+IFR-AK-CAZ-SC(6) 17,185.76 93.46 14.22 6,367.61 6,220.11 -55.96 6,423.32 5,929,958.04 487,702.20 0.69 1,170.70 MWD+IFR-AK-CAZ-SC(6) 17,281.26 92.89 13.76 6,362.33 6,214.83 36.57 6,446.37 5,930,050.49 487,725.48 0.77 1,265.92 MWD+IFR-AK-CAZ-SC(6) 7/23/2015 8:05:57AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-02 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft Well: 2S-02 North Reference: True Wellbore: 2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02 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 17,376.53 90.30 13.48 6,359.67 6,212.17 129.11 6,468.79 5,930,142.97 487,748.13 2.73 1,361.04 MWD+IFR-AK-CAZ-SC(6) 17,470.54 88.45 14.53 6,360.70 6,213.20 220.32 6,491.54 5,930,234.11 487,771.10 2.26 1,454.91 MWD+IFR-AK-CAZ-SC(6) 17,566.45 87.79 10.85 6,363.85 6,216.35 313.82 6,512.59 5,930,327.55 487,792.38 3.90 1,550.71 MWD+IFR-AK-CAZ-SC(6) 17,659.47 92.74 9.04 6,363.42 6,215.92 405.41 6,528.65 5,930,419.09 487,808.67 5.67 1,643.68 MWD+IFR-AK-CAZ-SC(6) 17,754.57 92.40 9.19 6,359.15 6,211.65 499.21 6,543.70 5,930,512.85 487,823.95 0.39 1,738.64 MWD+IFR-AK-CAZ-SC(6) 17,849.50 92.77 8.66 6,354.87 6,207.37 592.90 6,558.42 5,930,606.49 487,838.89 0.68 1,833.41 MWD+IFR-AK-CAZ-SC(6) 17,942.67 92.88 8.82 6,350.28 6,202.78 684.87 6,572.56 5,930,698.42 487,853.26 0.21 1,926.39 MWD+IFR-AK-CAZ-SC(6) 18,038.13 92.09 10.28 6,346.14 6,198.64 778.92 6,588.38 5,930,792.42 487,869.31 1.74 2,021.73 MWD+IFR-AK-CAZ-SC(6) 18,131.74 91.78 9.35 6,342.98 6,195.48 871.10 6,604.33 5,930,884.55 487,885.49 1.05 2,115.26 MWD+IFR-AK-CAZ-SC(6) 18,226.54 92.19 9.48 6,339.69 6,192.19 964.57 6,619.83 5,930,977.97 487,901.22 0.45 2,209.97 MWD+IFR-AK-CAZ-SC(6) 18,322.24 93.50 8.80 6,334.95 6,187.45 1,058.94 6,635.01 5,931,072.29 487,916.63 1.54 2,305.50 MWD+IFR-AK-CAZ-SC(6) 18,382 80 93.50 8.80 6,331.25 6,183.75 1,118.67 6,644.26 5,931,132.00 487,926.03 0.00 2,365.90 NOT an Actual Survey 4 1/2"x 6-3/4" 18,410.00 93.50 8.80 6,329.59 6,182.09 1,145.50 6,648.41 5,931,158.81 487,930.25 0.00 2,393.03 PROJECTED to TD 7/23/2015 8:05:57AM Page 8 COMPASS 5000.1 Build 74 i • Cement Detail Report 2S-02 ConooRhithps AP:mkx String: Conductor Cement Job: DRILLING ORIGINAL,5/30/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 12/21/2014 09:25 12/22/2014 00:00 2S-02 Comment AS1 cement.Two pours.42 sx followed with 408 sx. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 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) 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(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 8/13/2015 i • Cement Detail Report 2S-02 Cc nocc PhiUtps a,yan String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/30/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/18/2015 13:45 6/18/2015 18.30 2S-02 Comment Batch up as per SLB. Pump 5 bbls of water, pressure test lines to 3500 psi. Pumping 100 bbls of CW100 followed by 100 bbls of 10.5 ppg Mud Push II.Shut down,drop bottom plug, SLB pumped 515 bbls of 11.0 ppg LiteCRETE and 59 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 9.8 ppg mud @ 7 bpm=650 psi.Slowed pumps to 3 bpm, bumped plug©3302 stokes, pressure up to 500 psi over FCP=1100 psi. Hold for 5 min, bleed off and check floats,good. Observed full returns while performing cement job. 112 bbls of cement returns to surface. Reciprocated pipe 10'until after dropping top plug.CIP @ 18:15 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 28.4 3,644.0 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 6 600.0 1,100.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Batch up as per SLB. Pump 5 bbls of water, pressure test lines to 3500 psi. Pumping 100 bbls of CW100 followed by 100 bbls of 10.5 ppg Mud Push II.Shut down,drop bottom plug, SLB pumped 515 bbls of 11.0 ppg LiteCRETE and 59 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 9.8 ppg mud @ 7 bpm=650 psi.Slowed pumps to 3 bpm, bumped plug @ 3302 stokes, pressure up to 500 psi over FCP=1100 psi. Hold for 5 min, bleed off and check floats,good. Observed full returns while performing cement job. 112 bbls of cement returns to surface. Reciprocated pipe 10'until after dropping top plug.CIP @ 18:15 hrs. 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 100.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush Mud Push II 100.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) 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 28.4 3,143.0 1,513 G 515.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.17 11.00, Additives Additive Type Concentration Conc Unit label Lost Circulation Additive(Kolite) ALC B439 Additive Type Concentration Conc Unit label Dispersant D145A 0.02 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,143.0 3,644.0 206 G 59.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.37 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Page 1/1 Report Printed: 8/13/2015 i Cement Detail Report 2S-02 conmothillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/30/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 7/1/2015 06:45 7/1/2015 13:30 2S-02 Comment Pumped 1st stage cmt job as follows: Dowell pumped 5 bbls CW-100-Test lines to 15000&3500 psi-Pumped 25 bbls CW-100©2.6 to 4.0 bbls/min @ 434 to 619 psi-Pumped 30 bbls MudPush @ 11.5 ppg @ 3.8 to 4.3 bbls/min©630 psi-Pumped 102 bbls Gasblok slurry w/1.5#/bbl CenNet plus additives @ 15.8 ppg @ 4 bbls/min @ 500 to 160 psi-Dropped top plug w/10 bbls water f/Dowell-Recip. pipe 12'stroke during job-w/slight returns through out job Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 10,184.0 11,985.0 No No No 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) 3 7 7 701.0 1,505.0 Yes 12.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 1st stage cmt job as follows: Dowell pumped 5 bbls CW-100-Test lines to 15000&3500 psi-Pumped 25 bbls CW-100 @ 2.6 to 4.0 bbls/min @ 434 to 619 psi-Pumped 30 bbls MudPush @ 11.5 ppg @ 3.8 to 4.3 bbls/min @ 630 psi-Pumped 102 bbls Gasblok slurry w/1.5#/bbl CenNet plus additives @ 15.8 ppg @ 4 bbls/min @ 500 to 160 psi-Dropped top plug w/10 bbls water f/Dowell-Recip.pipe 12'stroke during job-w/slight returns through out job.Switch over to rig pump&dispalce cement w/10.4 ppg LSND mud @ 6.5 bbls/min for 220 stks(caught up with cmt)Cont.displacing cmt @ 4.5 to 5 bbls/min @ 200 to 300 psi-slowed pumps to 3 bbls/min@ 5000 stks @ 900 psi-slowed pump to 1 bbl/min@ 600 psi @ 5100 stks-Bumped plug @ 5284 stks(528 bbls)- Pressure up to 1500 psi&held for 5 mins.-Bled off&checked floats(Floats held)CIP @ 1018 hrs.-had slight returns through displacement Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,184.0 11,985.0 501 G 104.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.20 15.80 82.1 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.1 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.005 gal/sx Additive Type Concentration Conc Unit label Gas Block D6000 2.0 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 8,655.0 9,095.0 No No No Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bb!/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 4 4 445.0 1,679.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 2nd stage cmt job as follows: Pumped 30 bbls CW-100 4 bbls/min @ 475 psi-Pumped 30 bbls 11.5 ppg MudPush @ 4 bbls/min @ 500 psi-Pumped 33.8 bbls Gasblok slurry w/15#/bbl Cemnet plus additives @ 15.8 ppg @ 4 bbls/min @ 490 to 330 psi-Dropped closing plug w/10 bbls water.Switched over to rig pump&displaced cmt w/10.4 ppg LSND mud @ 5 bbls/min @ 415 to 580 psi for 3700 stks(370 bbls)slowed pump to 3 bbls/min @ 428 psi-Bumped plug @ 4014 stks(401 bbls)-pressured up to 1700 psi to close stage collar(observed shear @ 1400 psi-Held pressure for 5 mins.-Bled off-No flow back confirmed stage collar closed CIP @ 1309 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 8,655.0 9,095.0 161 G 33.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 2.90 15.80 74.5 5.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Page 1/2 Report Printed: 8/13/2015 • 0 0 Cement Detail Report 2S-02 Ga10041111.hPS Ataska String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/30/2015 00:00 Additives Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.1 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 2/2 Report Printed: 8/13/2015 • • 1<;ct2 is._ 2_ Regg, James B (DOA) From: Doyon 141 Company Man <n1334@conocophillips.com> Sent: Saturday, July 11, 2015 11:13 AM �� .7(/-5/u..3" To: DOA AOGCC Prudhoe Bay Cc: Callahan, Mike 5; Whitlock, Guy D (SolstenXP); Herbert, Frederick 0; Rauchenstein, Rock D Subject: AOGCC Bulletin # 10-003. Doyon 141 use of annular preventer. 7.11.2015 AOGCC Inspectors, On Doyon 141 we used our annular preventer to hold 500 psi pressure while changing out our RCD, (rotating control device), bearing assembly. We maintained constant bottom hole pressure throughout the operation, , with no influx recorded. We are now drilling ahead with our new bearing. Date: 7.11.2015. Closed the bag @ 0923 hrs. Opened the bag 1041 hrs. Depth: 18277' MD. 6345'TVD Well: 2S-02 Kuparuk - PTD: 215-070 - Doyon 141 Contact: Robert Wall, 670-4976 Summary: While drilling ahead @ 18,277' MD, our lower seal of our dual seal Elite bearing failed. Drilling was stopped. One stand was stood back.The wellbore was circulated to the calculated bottoms up. After a safety meeting with the crew the annular was closed to keep our 480 to 500 psi constant bottom hole pressure.The bearing assembly was changed out. Annularpreventer used, HCR kill and choke were also cycled. -' Reason: Replace RCD bearing while drilling underbalanced. Actions to be taken:The annular will be tested with a 31/2", and a 41/2" test joint when we get out of the hole, and before we run our liner. Last full test:July 5th, 2015. Respectfully, Robert Wall. Please contact us if any further information is needed. Robert Wall Don Mickey Bob Finkbiner Doyon 141 Rig Supervisors 670-4963 office 670-4976 rig floor 1 • Pr) 245-- 07-v Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,July 16, 2015 10:14 AM To: 'Klem,Adam' Cc: Callahan, Mike S (Mike.Callahan@conocophillips.com) Subject: RE:25-02(PTD 215-070) Packer depth waiver Follow Up Flag: Follow up Flag Status: Flagged Adam, A waiver is granted to allow the packer to be placed 680'above the slotted liner/top of Kuparuk(20 AAC 25.412(b)) based on information provided in the waiver request. Please include this information with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepr@alaska.gov From: Klem, Adam (mailto:"-IM Klem@conocophillips.comi Sent: Wednesday, July 15, 2015 6:00 AM To: Loepp, Victoria T(DOA) Subject: 2S-02(PTD 215-070) Packer depth waiver Victoria, As per our conversation on earlier today for 2S-02,this is a synopsis of the reason ConocoPhillips requires a waiver for the AOGCC regulation stating that injection packers must be within 200 feet of the upper most perforations on injection wells. If there are any questions please call. Thanks, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska Mk= . 1111111111M111111111 imi=umnimr___111111NL16 —MI Viii iligium.". -•••=111111M , - 1 .11111111.1111 MI Will' -ilimmom --- it ..zi- . ii....,- Eirnwasimilmiumi , II- -1- . _ ,a, 9000gap _ . ..- P- — NB= aoraimmimmum W A I ii7" Viej IIIIIIIII I M• a• J T 11111MIIMM IIIIIIIIIR&ow=Mil / 11111NIENE _.41111.11111.1. 11111111 E aw Cli iVMiNEN 111111111kiliniNE rillINIMEI .4e. , 4 ' -w 1 Emir ig- Aillill nr ier SW L _,P. M I 1 I I 111 II.rAll I I I I I I I I I M III IN 111 II --....-----1..‘161111 I I I I I I I I II I I I I II I I I I I:— 1-2'":1 -'' 10000 Mir -asimeam t , IL. _ .:,.._: MIIIKM11111 -MIIM111111111111111111111 4, -- ...." IN& 411111.111IFF=111MEN ' • . ,.11111 --I.— 4 Sr - -- A If DC _ 1 AMP .a ,.,,,, VP , ' imbienfflimmimm. .. : " - ..,_ 1000 11111.11.111 , MEW 3q11111111111 Pallillil - ' 1 IIIIIIIIIIIIC illiMil • !It- & 11.11.01:or—"MP Millillill - ^^ .:. mimminimiumm. 0- 4 , 16-- . • • Request for waiver concerning the placement of the injection packer a minimum of 200' above the upper most perforation in the well. ConocoPhillips is drilling an injection well, 2S-02, in the Kuparuk field. This well has already been approved for drilling by AOGCC (PTD#: 215-070) as an injector with a seal assembly located in the liner hanger which will serve as our isolation packer. While drilling, we encountered some issues that lead to top setting the reservoir vs the original plan on landing in zone. Authorization was given for our plan to topset by the AOGCC on 6/25/2015. On 2S-02, the 7 5/8" intermediate casing is cemented fully from the casing shoe at 11,982'MD/6,275'TVD, all the way up to 8,490' MD 14,480'TVD, -600' MD above the top of the C-37, for a total a length of 3,486 feet of cement column. The sonic log shows continuous cement between the first and second stage(stage collar at 9,095' MD), with high quality cement from the shoe to 10,730' MD (-1,250')and multiple intervals of good quality above that to the TOC at 8,490' MD. A 16.0 ppg LOT was achieve after drilling out the intermediate shoe track, indicating high quality cement with no channels around the shoe. The 6 3/" production hole was drilled to 18,410'MD/6,330'TVD and a 4 %2" slotted liner will be run with an open hole swell packer at the top of the Kuparuk reservoir. ConocoPhillips requires a minimum of 150 feet of lap length once the production liner is in place and with the added open hole to the top of the Kuparuk on 2S-02, the total for the well in this case would be 653 feet from the seal assembly through the Kalubik shale to the top of the Kuparuk. Our top perforation (it is slotted liner, not perforations)will be right at the top of the reservoir which would give an over-all length of 640'-680' between the upper most perforation to the seal assembly leaving us out of compliance with the AOGCC. Therefore, we would like to request a waiver on the AOGCC regulation requiring a minimum of 200 feet from the upper most perforation to the injection packer(seal assembly) on 2S-02. • • pTD zip- UF-v Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday,July 06, 2015 9:04 AM To: Loepp,Victoria T(DOA) Subject: RE: PTD#215-070: 2S-02 Proposed Cement Evaluation/Path Forward Follow Up Flag: Follow up Flag Status: Flagged Victoria, here is an update on our status. We were able to get a real time sonic log with our drilling BHA(we didn't think we would be able to transmit it in real time and were planning on getting it in recorded mode, but we managed to get it in real time,a first for us with this tool). I've attached a screen shot of the log—the blue curve in the middle is amplitude, low amplitude indicating good cement, high amplitude less cement. It shows our TOC for the second stage at 8,490' MD,with clear high quality cement beginning at 8,800' (top of C-37,the top of the Tarn pool we are covering with the second stage, is 9,155' MD). We have continuous cement from our first stage all the way up to the stage collar(well higher than planned, indicating a fully gauge hole),with very high quality for the bottom^'1,200',from our stage collar at 11,900' up to-10,700' MD. 1 • • o cv -..� l..; r- x AMP1_CSG_Linear' Action eferenc 0 unitless 124 (ft) ^P_!.I V,',2"" AMP1_CSG SPJ_MH_RT 1:4000 c 0 unitless 124 -1 ;sift 1 1 I 1 I 1 1 it - 9000 •• . .. f . Nuierimmomemmi 1 III i i & 11111111117111111111111 El T _10000 .14 Hili Mat AIMIIIIE -"-"'dluIAMNII Il ' 1111111111N11111111111111111111N1111 - i N��ii�iii 11000 � � . 7; I! Hsrr�i - z- H111111MI INEHIMiiii-railiMMEN 4,. :4 Hi � Bii HCH - Mit. �,! —���J We are currently proceeding with our plan forward to drill ahead in our production hole. We achieved a 16.0 ppg LOT below our shoe and should be drilling ahead later this morning. Please let me know if you have any questions or would like any further information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 2 • • Cell: (907)231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, June 29, 2015 4:21 PM To: Callahan, Mike S Subject: [EXTERNAL]Re: PTD # 215-070: 2S-02 Proposed Cement Evaluation/ Path Forward Mike, Approval is granted for this modification to your plan as outlined below. Thanx, Victoria On Jun 29, 2015, at 3:48 PM, Callahan, Mike S <Mike.Callahan@conocophillips.com>wrote: Victoria, As we just discussed on the phone this afternoon, our plan forward for evaluating the intermediate cement on 2S-02 is as follows: After performing the two stage cement job,we will proceed with the original plan of running a sonic logging tool on our production BHA. That tool is only available in memory mode, so we will log the top of cement on our way in the hole, then proceed with drilling the production section. We will run liner to get the hole behind pipe as quickly as possible while concurrently evaluating the sonic log from the memory data after we get the BHA out of hole. If the sonic log shows our top of cement is at or above where planned,we will proceed with running the upper completion. If the sonic log shows a lower than planned top of cement,we will rig up and run a Cast-M/CBL on E-line to evaluate the quality of cement across our key barrier zones (very similar to well 2L-328, PTD#214-189). In the event that both the TOC is lower than planned and the Cast-M/CBL shows poor quality of cement,we will evaluate remedial options, most likely a perf and squeeze job,to obtain adequate cement prior to completing the well. Please let me know if you have any questions or would like any more information on the proposed path forward. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 3 • • PTO 2-15--o 7--0 Loepp, Victoria T (DOA) From: Bearden,J Daniel <1.Daniel.Bearden@conocophillips.com> Sent: Thursday,June 25, 2015 6:39 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re:Injector 2S-02 (PTD#215-070) Follow Up Flag: Follow up Flag Status: Flagged Thank you for working on this late into the day today,Victoria. We will perform the wireline CBL and review results with you prior to proceeding with production hole. - Daniel Sent with Good (www,good_com) From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Thursday,June 25,2015 9:30:44 PM To: Bearden,J Daniel Subject: Re: (EXTERNAL)Re: Injector 2S-02 (PTD#215-070) Daniel, Approval is granted to proceed with the proposed plan outlined below.A CBL is required prior to running in with the production hole BHA. Results of the CBL will be reviewed with the AOGCC before proceeding. Thanx, Victoria Sent from my iPhone >On Jun 25, 2015,at 6:18 PM, Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com>wrote: >Absolutely Victoria,we will run a SonicScope as part of our production BHA to log across the cemented intervals as we have done at Tarn.We can also run a wireline CBL prior to running in with production hole BHA as done on 2M-36 if desired. >Sent with Good (www.good.com<http://www.good.com>) > From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> >Sent:Thursday,June 25,2015 8:48:59 PM >To: Bearden,J Daniel >Subject: [EXTERNAL)Re: Injector 2S-02 (PTD#215-070) >Are there plans for a CBL? >Sent from my iPhone 1 • ! >On Jun 25, 2015,at 4:14 PM, Bearden,J Daniel <J.Daniel.Bearden(conocophillips.com<mailto:J.Daniel.Bearden@conocophillips.com>>wrote: >Victoria, >ConocoPhillips requests approval of our proposed plan forward to topset the Kuparuk sands per the following Alaska Administrative Codes. > 20 AAC 25.030 (c) (5) "production casing must be set and cemented through, into,or just above the production interval" >20 AAC 25.030(d) (5) "intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet above all significant hydrocarbon zones and abnormally geo- pressured strata or, if zonal coverage is not required under(a)of this section,from the casing shoe to a minimum of 500 feet above the casing shoe; if indications of improper cementing exist, such as lost returns,or if the formation integrity test shows an inadequate cement job, remedial action must be taken" >We encountered a packoff event while drilling the 9-7/8" intermediate hole section on the first Shark Tooth pad well - injection well 25-02 (PTD#215-070).This event ultimately led to lost circulation most likely in a sandstone stringer between the base of the West Sak and the top of the C-37 interval. >The drilling plan was to land the intermediate in the higher pressured (^'11.4 ppg) Kuparuk'A'sands. However, knowing that we have broken down weak zones above us,we propose to instead topset the overpressured Kuparuk'A' sands by landing^'50'ND above them, setting our 7-5/8" intermediate casing in the Lower Kalubik shale, and cementing with a minimum of 500' above the shoe. The planned cement stage tool will remain in the 7-5/8" casing to also provide an additional 500' of cement above the C-37 (Tarn area) interval. This plan is similar to our successful completion of producing well 2M-36(PTD#214-102) in late 2014—with the exception of the stage cementing tool and that our current well is a planned injector. >Successful execution of this plan,we would drill out and horizontally into the Kuparuk to planned TD and run our planned 4-1/2" slotted liner with swell packers plus an additional Heel swell packer placement; placing the swell packer at the top of the Kuparuk sands to provide pressure isolation for the 7-5/8" casing shoe. >Thank you for your response, > Daniel Bearden >Supervising Drilling Engineer >ConocoPhillips, Alaska >907-263-4864 work >907-602-7068 cell ><2S-02 Proposed Topset.pptx> 2 • i a2 2 2 •— — a �a _ f .= Wu 0 0 i : l: 2 Ca 3 a e- Y V ° v t/, o rz 8 co - ., N 0 co E Q U N I@ 0 E o c � io t N d ro O to yo p $ :1- FN u a p t O N a W w"2 O u 7 0 to r ..--7. _� c I U LI)l-i N _ giN N d: ++ 0 0 oa) aJ �-- (1) m Y n• O h N U vNi N o 0 o M 1:10O co a, Li E a)o0. a cc) 'O J a) 0 in CJ o c horn � aJ .n o E C , o �C I- as in kr) N ++ IMMO C C t L fC V 0 C • .--1 'O a. aJ Q. 7 N a 3 Cl.. 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N - m ,co —� .8 to i1 � 1.. 2 13 N : s4 L -' u 1 c VJ '�S t O 1.'� I' 1 f0 in € • m 2 a i n ; e N V w = `° 11 ` Ili n CD O N rs u ti 0 ,n = tll UA 0 Y E .� 3 E m m w •� (n N 1 11 S p Is - CD Na R � ii j aZ,B .T'.. !n m 1 1 pi : d m •N O o iP NC i CO iV i.� C 5 II W e OA I = _ O g p v n P f 3' ,1 p 2 VO 0 _ u j a R 2 u 6 F j f4 - •f0 N n W I!!V m a f 9� a � a••C a 3' yam - / g` o ro e n ✓ yam; tt t R{ � 'N •y 4 ? N •— OD 1 O .... ett-SOL 600 6 taclilp • • Bettis, Patricia K (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, June 17, 2015 10:58 AM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: PTD #215-070 (2S-02): 2S Pad Logging Plan Thank you Patricia. I have one correction, I had the wrong well in my head. It is 2S-10(which is the 3rd well on the pad, not the 4th) that is the best candidate for the surface logs and where we plan to obtain that data. My apologies for the miss information. Please let me know if you'd like any more information on the well or our logging plans. Thanks, Mike From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, June 15, 2015 3:02 PM To: Callahan, Mike S Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: PTD #215-070 (2S-02): 2S Pad Logging Plan Mike, ConocoPhillips' plans to acquire a full suite of surface logs, including density/neutron, in the 2S-13 well instead of the 2S- 02 well is approved. A mud log will not be required in the 2S-13 well. Thank you, Patricia From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.comj Sent: Monday,June 15, 2015 9:15 AM To: Bettis, Patricia K (DOA) Subject: PTD#215-070(2S-02): 2S Pad Logging Plan Patricia, as per our conversation, here is the summary of our mud logging/LWD plans for 2S pad: 2S-02 (current well, 1st on pad): We will continue taking cuttings samples every 30' MD, and 10' MD in the target Kuparuk sands. We will not obtain samples in the horizontal section. 2S-13 (4th well on pad): As this is the most vertical well through the surface hole on the pad, we will get a full suite of surface logs, including density/neutron, on this well. We will not have mud logs for surface on this well. Please let me know if you have any questions or concerns. Thanks, 1 pTD 2iS -G7-6 Loepp, Victoria T (DOA) From: Bettis, Patricia K(DOA) Sent: Monday,June 15, 2015 3:02 PM To: Callahan, Mike S Cc: Loepp,Victoria T(DOA) Subject: RE: PTD#215-070 (2S-02): 2S Pad Logging Plan Follow Up Flag: Follow up Flag Status: Flagged Mike, ConocoPhillips' plans to acquire a full suite of surface logs, including density/neutron, in the 2S-13 well instead of the 2S- 02 well is approved. A mud log will not be required in the 2S-13 well. Thank you, Patricia From:Callahan, Mike S[mailto:Mike.Callahan@conocophillips.com] Sent: Monday,June 15, 2015 9:15 AM To: Bettis, Patricia K(DOA) Subject: PTD#215-070(2S-02): 2S Pad Logging Plan Patricia,as per our conversation, here is the summary of our mud logging/LWD plans for 2S pad: 2S-02 (current well, 15t on pad): We will continue taking cuttings samples every 30' MD,and 10' MD in the target Kuparuk sands. We will not obtain samples in the horizontal section. 2S-13 (4th well on pad): As this is the most vertical well through the surface hole on the pad, we will get a full suite of surface logs, including density/neutron, on this well. We will not have mud logs for surface on this well. Please let me know if you have any questions or concerns. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 1 • • Bettis, Patricia K (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday, June 15, 2015 9:15 AM To: Bettis, Patricia K (DOA) Subject: PTD #215-070 (2S-02): 2S Pad Logging Plan Patricia, as per our conversation, here is the summary of our mud logging/LWD plans for 2S pad: 2S-02 (current well, 1st on pad): We will continue taking cuttings samples every 30' MD, and 10' MD in the target Kuparuk sands. We will not obtain samples in the horizontal section. 2S-13 (4th well on pad): As this is the most vertical well through the surface hole on the pad, we will get a full suite of surface logs, including density/neutron,on this well. We will not have mud logs for surface on this well. Please let me know if you have any questions or concerns. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 1 Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Friday,June 12,2015 9:32 AM To: Loepp,Victoria T(DOA) Cc: Jackson,Jasper C(DOA) Subject: Re: [EXTERNAL]RE:25 Pad Static BHP Measurement Methods Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria. Understood that this is not approved for other scenarios,and we will make sure that we get accurate measurements via well calibrated surface gauges,consistent mud column throughout,etc. We will make sure to communicate to you the method used and the details of obtaining the measurement for any BHP's obtained with either method. Thanks, Mike On Jun 12,2015,at 8:51 AM, "Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov<mailto:victoria.Ioepp@alaska.gov>> wrote: Mike, We have reviewed this request for two alternate methods for obtaining the required bottom hole pressures on pre- produced injectors on 2S pad. Both methods are acceptable and approved in the special circumstance you describe. Use of these methods as standard practice elsewhere is not approved. Please insure the accuracy of the surface gauges, and consistency of the mud column prior to obtaining the pressures. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov<mailto:Victoria.Loepp@alaska.gov> CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loepp@alaska.gov<mailto:Victoria.Loepp@alaska.gov> 1 • • From:Callahan,Mike S[mailto:Mike.Callahan@conocophillips.com] Sent:Tuesday,June 02,2015 3:55 PM To: Loepp,Victoria T(DOA) Cc: Klem,Adam Subject:2S Pad Static BHP Measurement Methods Victoria,as we discussed on the phone this afternoon,we are looking into a method for getting the required bottom hole pressure measurement prior to producing our pre-produced injectors at 25 pad(6 wells). This is to eliminate post- rig slickline work that could delay the production on the wells between 1-2 months(slickline access would not be possible for certain wells because of the rig footprint covering access to the previous well while it is drilling subsequent wells on the pad). The two methods we would like approval to use are: 1. If the mud weight used to drill the production lateral is below the pore pressure,we will use our managed pressure drilling system to fingerprint the pore pressure. This will involve shutting the MPD chokes and allowing the pressure to build until it levels out,giving us a static bottom hole pore pressure(the surface pressure plus the hydrostatic of our known mud weight). 2. If the mud weight used to drill the production lateral remains above pore pressure for the entire drilling portion, we will not be able to finger print with the MPD system. In that case,we would wait until the last step of the well when we are freeze protecting. Instead of pumping diesel around the top 2,000'of the well as is our standard,we would pump it around the entire tubing volume, leaving a full column of diesel in the well. We could then measure the wellhead pressure after it becomes static and add it to the hydrostatic of the diesel column to get an accurate BHP. Please let me know if you have any questions or would like any more information on either of these proposed methods. Regards, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office:(907)263-4180 Cell: (907)231-2176 2 ti of T�� • � %% s, THE STATE Alaska Oil and Gas ®fl�J JS Conservation Commission 333 West Seventh Avenue Anchorage, GOVERNOR BILL WALKER e, Alaska 99501-3572 g Main: 907.279.1433 ALIA5�P Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-02 ConocoPhillips Alaska, Inc. Permit No: 215-070 Surface Location: 3018' FNL, 1291' FEL, Sec. 17, T1ON, RO8E, UM Bottomhole Location: 1802' FNL, 5179' FEL, Sec. 15, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 ConocoPhillips Alaska, Inc. in the attached application, the following well logs are also required for this 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. Mudlog will be required from the base of conductor to 7 5/8" casing shoe depth at approximately 12,667 feet measured depth. 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, I p3,4,„z..,____ Cathy P. oerster Chair DATED this 4" day of May, 2015. 411 411 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 16 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ , Single Zone a, 1c.Specify if well is proposed for: Drill ❑✓ , Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry I Exploratory ❑ Service-WAG Cl Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: . ✓J Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180• KRU 2S-02 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 18477'- TVD: 6348' Kuparuk River Field , 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:3018'FNL, 1291'FEL,Sec. 17,T1ON, RO8E, UM ADL 25603,25604 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2153'FNL, 1328'FEL, Sec.21,T1ON, RO8E, UM • 2677,2678 6/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 1802'FNL,5179'FEL, Sec. 15,T1ON, RO8E, UM - 2560-SO?, Nearest Property: 3989' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 148 feet 15.Distance to Nearest Well Open Surface:x- 481280 y- 5930030 Zone- 4 , GL Elevation above MSL: •120 feet to Same Pool: KRU 21-10-8,633 16.Deviated wells: Kickoff depth: , 325 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: . 92° deg Downhole: 3900 psig , Surface: 3276 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 3615' 28' 28' 3643' 2650' 1442 sx ALC, 195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 12639' 28' 28' 12667' 6388' 465 sx GasBLOK, 185 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 5960' 12517' 6224' 18477' 6348' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program o Time v.Depth Plot ❑ Shallow Hazard Analysis Li Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements El 21.Verbal Approval: Commission Representative: Date: ��//�� 22. I hereby certify that the foregoing is true and correct. Contact Mike Callahan @ 263-4180 j�'/ie- Email Mike.Callahan@cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager I Signature 7- - - �� Phone:263-4372 Date '$'{«(20 t5. Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: c il5- 0 7-0 50- (J,3 c)7"/0_ o -03 I Date: ij/L4120/E for other 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: Ed Other: BO p f r-✓ i tDO 30Sp$1 -f±a 2'��(a nples req'd: Yes El No El Mud log req'd: YesiD No 0 412S measures: Yes ❑ No ❑ Directional svy req'd: Yes Er No❑ Spacing exception req'd: Yes ❑ No ❑ Inclination-only svy req'd: Yes❑ No re APPROVED BY THE Approved // COMMISSIONER COMMISSION Date:'L-- Form 10-401 (R vised 10/2012) from the datepf appro al(20 C 25. 5(g)) irr� 4,3.6,/s oimstN2Aits /CJ� � • RECEIVED APR 16 2015 April 15,2015 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-02,A Kuparuk A4 Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produced injector well from the 2S pad. The expected spud date for this well is June 1St,2015.It is planned to use rig Doyon 141. ✓ 2S-02 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-3,643'MD/2,650'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 12,667'MD/6,388'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 18,477'MD/6,348'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. Pressure information as required by 20 ACC 25.035(d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Callahan at 263-4180 (Mike.Callahan(c�ConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, A-L.0 J._ Chip Alvord Drilling Manager • Application for Permit to Drill Document Kuparuk Well 2S-02 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-02 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 3018'FNL, 1291'FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,930,029.93' Eastings: 481,279.60' Pad Elevation 120'AMSL Location at Top of 2153'FNL, 1328'FEL,Sec 21,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth,RKB: 12,614' Northings: 5,925,604.43' Eastings: 486,523.75' Total Vertical Depth,RKB: 6,383' Total Vertical Depth, SS: 6,235' Location at Total Depth 1802'FNL, 5179'FEL, Sec 15,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 18,477' Northings: 5,931,232.28' Eastings: 487,949.86' Total Vertical Depth,RKB: 6,348' Total Vertical Depth,SS: 6,200' and (D)other information required by 20 AAC 25.050(b); 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 wel!bores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are(mown 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. • 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(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 15.037,as applicable; Please reference BOP schematics on file for Doyon 141. 2 • • 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 maximum potential surface pressure (MPSP)while drilling 2S-02 is calculated using an estimated maximum reservoir pressure of 3,900 psi (12.0 ppg, 1.0 ppg higher than Shark Tooth#1 appraisal well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,383' TVD (WP08): A Sand Estimated. BHP =3,900 psi A Sand estimated depth(WP04) =6,235' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 624 psi (6,235' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,276 psi (3,900 psi—624 psi) l a l% ,PP (B)data on potential gas zones; J?,q d / � The well bore is not expected to penetrate any shallow gas zones. �S . v 5 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: See attached 2S-02 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill niust 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 fonnation integrity tests,as required under 20 AAC 25.030(I); A procedure is on file with the commission for perfoutling LOT's. 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 Cement Program Casing and Cementing Program Csg/Tbg Hole weigh Length Top MD/TVD Btm MD/TVD OD(in) Size �I t(lb/ft) Grade Conn. () (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 3,615 Surf 3,643/2,650 1,442 sx ALC Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 465 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 10,184'MD 7-5/8 9-7/8 29.7 L-80 563 12,639 Surf 12,667/6,388 Stage 2: 185 sx Class G+GASBLOK at 15.8 ppg w/TOC at 8,595'MD 4 1/2 6-3/4 12.6 L-80 IBTM 5,960 12,517/6,224 18,477/6,348 Slotted liner 3 • 4110 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. 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; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5-11.0 10.5-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10-18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. 4 I • Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 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 to attachment for proposed well schematic. 5 • 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-3,643' MD/2,650'TVD as per directional plan (wp08). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. ✓ 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIFT and clean out to 100'above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 11,212'MD/5,998'TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 12,667'MD/6,388'TVD,landing in the Kuparuk A4 sand. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to'ID at 12,436'MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 10,184'MD(top of Cairn formation),top of second stage to be 8,595'MD(500'above C37). / 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope,and 7 neutron density) ✓ 17. RIH and clean out cement to 100'above shoe. Test intermediate casing to 3000 psi for 30 minutes. 18. Drill out shoe track and 20'of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-1/2"hole geosteering though the Kuparuk A4 sand to TD 18,477'MD as per directional plan(wp08). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 12.6#slotted liner. The top of liner will be placed at 12,117'MD,allowing for 150'of overlap in the 7-5/8"casing. 6 1 i 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: 09)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 authorisation 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 (1R-18 or new facilities at DS 1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan-Pg 8 Attachment 2 Drilling Hazards Summary-Pg 54 Attachment 3 Well Schematic-Pg 56 Attachment 4 Cement Summaries-Pg 57 7 i ! Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, April 30, 2015 6:42 AM To: Loepp,Victoria T (DOA) Subject: RE: KRU 2S-02 (PTD 215-070) Attachments: DOYON 141 ON 2S-02.pdf Victoria, responses to your questions are below in red. Please let me know if this answers your questions or if you need any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, April 29, 2015 1:39 PM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2S-02 (PTD 215-070) Mike, A few questions/comments: 1. What are your contingency plans if you encounter the maximum reservoir pressure of 12.0 ppg? If we encounter pressure that high, it will be coming from the injection at 2M and 2K pads to the north of 2S. The heel of 2S-02(and all future 2S wells) is located well to the south of that injection,so if we see pressure that high it will almost certainly be closer to the toe of the well, and will not be seen in our intermediate section. If the pressure is encountered along our lateral, we will be able to see that we are underbalanced without taking an influx by shutting the MPD chokes on connections. If any pressure builds up,we will be able to adjust our mud weight to the necessary kill weight based on the pressure it builds to without ever taking any influx. If the mud weight required gets above 11.5 ppg,we will most likely use a NaBr based fluid as our kill weight before tripping(to avoid barite sag issues similar to what we just saw on 2L-32R1_ 2. Please provide a diverter route schematic showing approximate length. Also, show a 75' radius area around the diverter outlet on a pad schematic. Attached. 3. In your area of review, KRU 21-10-8 is present. What is the status and condition of this well? The well is P&A'd to surface. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 1 r 0 L., 61 1 1 1 1 1 N O O I —< N O. _ a 4a @ Z O O aa Zi O Z 1I_ J S ® O E- II1� LJ U ' I a ® j_ ED MI MI ' 1 N 6cl C ¢ iI Y coo w 1 ._.,, ® 1. O fin U p C_ ® - >- V o T q CO)E de PM 1:71i in • o 0 N m o o 4 9` bq"'2,,) N. PEI " Mir "- H ilk .i o o B4 __ 112 a a o O w ow 0 .- - w a • W nN Zazmr> J< W 3<V4.i a o V I Z Q W a g ji o — 1 a aO nW n4, 1 , Nff N o Y ' J oa§ o I • 13:54,February 25 2015 2S-02wp08 [Thresher] .Perm ikt Plan Summary 5_ ,10-31,..13-1/21' I7-5/8"X 9-7/81 _5 \.k :• 'o HRZ(top) A4 it .,✓ 1 -rr �4-12"x 6-3/4' .LS§ : ; • * _ • D lli . �l I 1 I I I I I ( T I I J 1 `'• 0 4500 9000 13500 18000 :11110110. Measured Depth • .� o--0° Geodetic Datum: North American Datum 1983 I10-3/4"x 13-1/21' Depth Reference: Plan:120+28 @ 148.00usft(Doyon 141) `x=-' o 'j,Q,`,,,o Rig: Doyon 141 ', ` ::,••'' • o oa a _.. _......_. co no 7-5/8"X 9-7/8' •.,o ` 11\ ...-""' ''' o 0 00 1 4-1/2"x 6-3/4'1 0 __.- O O o I 1 '. s_ o o oO >\0 a p I o o° 1 t _... .. ......... ... .. oy m o7'- 1 ^ ', .. I I 1 I 1 I I I I I I . '1a dl -,;i I , I IA/I - -: 28 '""",325 0 2000 4000 6000 8000 10P10 0 12000 14 0 o Pb000 0 325- 510 Horizontal Departure _sem„ 510- 690 330 ':r►:=":=2 30 'SKIN 690 -870 •. d tW eN ii e 870- 1050 0o v \ ._._. .... 4/�A.. rI< � 1050- 1240 m 60 300, 4�d4 60 1240- 1420 m s •` ♦V `R� Yt 1420- 1600 ar 2S-01wp07[Mako] _. _ _.... °moi�� f I 11 3sniwm In+axq .. .. _.. ;>/O�1 r�I,„4" 1�11�1+�,3 1600 -2300 F%1 'P. Nit o 1 2300 3000 �j 30 203wp06[Bamboo]WIR..... > '; ` \4,111",,kk1 , 3000- 3700 • v�.t.,0,.•rIr > 3700- 4400 2 _ - 2S-04wp09[Lemon]- -. _.. 270 - - ® 90 [T o /� -f 4400 • 5100 - � --""- 5100- 5800 U _ .. .... _ _ • ../.-F'-. 5800 - 6500 06500- 7200 1 I I III I I I I I I I 1 I I I 1 I I I I I 7200- 8610 0 2500 5000 7500 10000 12500 15000 17500 240 120 8610- 10020 SURVEY PROGRAM 10020- 11430 Surface Location 11430 - 12840 Depth From Depth To Survey/Plan ) Tool pad Elevation:120.0028.00 1200.00 __- - 12840- 14250 1200.00 2200.00 2S-0208 wp08[Thresher](P28-02) GYD-GC-SS 210 --- ---, 150 [Thresher](PlanMWD 1 -,•---- 14250 15660 1200.00 3643.07 2S-02wp08[Thresher](Plan.2SP04)0+IFR-AK-CAZ-SC 180 15660 - 17070 3643.07 5143.07 2S-02wp08[Thresher](Plan 2S-02) MWD CASING DETAILS 3643.07 12667.42 25-02wp08[Thresher](Plan 2SP0Yp'D+IFR-AK-CAZ-SC 17070- 18477 12667.42 14167.42 2S-02wp08[Thresher](Plan 2S-02) MWD TVD MD Name M 12667.42 18477.45 2S-02wp08[Thresher](Plan 2SP82]D+IFR-AK-CAZSC 2650,00 3643.07 10-3/4"x 13-12" Magnetic Model: BGGM2014 T 6388.00 12667.42 7-5/8"X 9-7/8" Magnetic Model Date: 01-Jun-15 - 6348.00 18477.45 4-1/2"x 6-3/4" Magnetic Declination: 18.63° To convert a Magnetic Direction to a True Direction,Add 18.63°East SECTION DETAILS Sec MD Inc Azi TVD +N/-S vE/-W Dleg TFace VSect Target Annotation 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 -5998.0 2 325.00 0.00 0.00 325.00 0.00 0,00 0.00 0,00 0.00 KOP:Start 1.5°/100'DLS,144.25°TF,for 275.24' 3 60024 4.13 144.25 600.00 -8.04 5.79 1.50 14425 -6.79 Start 2.5°/100'DLS,0°TF,for 907.6' 4 1507,84 26,82 144.25 1469,00 -203.28 146.34 2.50 0.00 -171.62 Hold for 112.05' 5 1619.89 26.82 144.25 1569.00 -244.31 175.88 0.00 0.00 -206.26 Start 3.5°/100'DLS,22.63°TF,for 1287.18' 6 2907.07 70.38 161.06 2402.87 -1097.79 562.44 3.50 22.63 -970.30 Hold for 4213.19' 7 712026 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00-4409.19 Start 2.5/100'DLS,-123.06°TF,for 5547.16' 8 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06-3328.65 20-Thresher 1.Heel 022315 PB Hold for 30' 9 12697.42 85.00 14.80 6390.61 -4383.68 5263.42 0.00 0.00-3298.83 Start 3.5°/100'DLS,-5.52°TF,for 187.25' 10 12884.67 91.52 14.17 6396.29 -4202.56 5310.21 3.50 -5.52-3112.11 Hold for 1418.34' 11 14303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00-1696.44 Start 2°/100'DLS,174.59°TF,for 26.3' 12 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2,00 174.59-1670.19 2S-Thresher 2.71 022315 PB Adjust TF to 162.36°,for 145.7' 13 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36-1524.81 Hold for 568.57' 14 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 Start 2°/100'IDLE,-3.97°TF,for 89.06' 15 15132.65 90.00 14,98 6378.00 -2026.77 5871.81 2.00 -3,97 -869.14 20-Thresher 3.72 022315 PB Adjust TF to-71.67°,for 112.1' 16 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 Hold for 350.05' 17 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00 -407.35 Start 2°/100'DLS,-18.81°TF,for 026' HRZ(top) 18 15595.06 90.71 12.85 6373.00 -1576.46 5976.68 2.00 -18.81 -407.09 2S-Thresher 4.T3 022315 PB Start 2°/100'IDLE,-18.81'TF,for 0.26' 19 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 Adjust TF to 121.42°,for 141.98' 20 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 Hold for 1090.72' 21 1686627 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 20-Thresher 5.74 022315 PB Start 2°/100'DLS,-0.23°TF,for 38.52' 22 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 Adjust TF to-11.79°,for 25.02' 23 17460,19 90,49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 Hold for 568.89' 24 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.61 1670.96 20-Thresher 6.15 022315 PB Start 2°/100'OLE,-67.61•TF,for 218.23' 25 18477.45 92,15 11,12 6348.00 1219.58 6667.68 0.00 -76.91 2469,43 2S-Thresher 7.Toe 050714 PB Hold for 799.03' -6383.0 A4 ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Ifeanyi Ifesie 8 • 0 siY co N Q 0 0 ° N Nort •�• g (4500 usff/in) , v , , , cy , aN 1- co S O p0. _ N O O • Q �i aN31 Y Y N N Y O 3 J N flQ N 3a l N C C 71 / -,r O O = _. ±S 2 ` N N a) p N N N l L i et N O i/ r,-- O r � N OL !L � N N N #:.11 Cs.i M Q coas d' 'p N co O C ,+11�\ N Q 2 2 Q o N = N N N Y Y LJ N N- Q Y N N =f MM O N N d Y N NZI Y i' o N 7 O J .�`. ., N 0 0 V N (n N N p N N .� 7 •�` N (V a (13 D 0- N o .: a 3 p ' 75o __ p 3 0 3 9 N N E N i _�; n :N NPa O d 01 N CO O N .S. 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CO E L.L. u. a u. m u. m u. _co u. _co a _ u. _co u_ LL. :E 2 VU) N N UN Cl) C ❑ c ❑ c ❑ U 0 E m c Om Lo Om OmOmOmmcommOm V E m co ' coco iocmcm c m m c m _ 0 N O N m U) 0 0 0 0 0 a NO N 0 0 2 (o U UUUUUU UUUUUU U U U U U U d N N 0 0) co O) 0 N- O O O V' (0 m_ N N m tl O CO O O m r N N- O m 0) 0) N- co 0) N. r 0 V' V' c0 O V' r r r V: N 0 N r m O) V CO V' m ...9 V V' (l1 CV tri ri O f� tri O N V N rn PO) N 00') N V N Nco N co r r r r 0 10 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 w o o id 6 ui (ri o ui Lci ui ui 6 o (ri o vi o 6 6N0..-.... N N N N O N N N N- N O N O N O N N m (0 O O m ti CO O CO V CO O m V' m <t m V' m V m V y 0 = c0 p2 V C r O O N- O O 00) O c0 O ON) O OO) 0 CO 0 0 0) m N 0 0i I N V' N V' N 4 N V N V' N V' N V' ri 7 N a N= CO N N N N O O CO CO rr- V' V' N N 0 N N - N r r r r W 2.:v CO co L r "- a 0 CO 0 N 0 0 O V' O (0 O m 0 0 0 0 O N- 0 L O 0 0 0 O O r 0 0 0 0 0 0 0 0 ONON Z �- V' O (O O V O 0) O m O m O 0 O N- O h O '�.. O N N N N V' N N N N- N 7 N 7 N V N ti m' L U) a N 4 m N m O M V' CO O C') V' m V' m V m 7 m V' in — D O b- y v N L m V O (O C) CO O m N N- N N N CO N 0 03 L a N. 0 0 0 0 0 0 O CO O r O 0 0 0 0 0 0 r N £ V N O m 0 0 0 O O : 0 0 0 0 0 0 0 0 V) = c al CO m CO m (O (O 0) 0) N N O O 0 0 N N N ,t- 0- Q $ a • E m= r r r r r r c Ul CO) 3 Q' O W O O- N A 'i0 CO 0 N 0 0 O V' 0 CO 0 CO O (0 0 0 0 N. ce . d 9 0 co0 0 0- 0 0 0 0 0 0 O CO O N O N NL O =+�-'' d O co ui V' (ti Oi ui m ui ri Id 06 u N Ili N- 6V O N N N N ,:r. N N N N. N d' N V' N V' N N -C y W y N d' CO r m O m V m O m 4 m V' (0 "t0) 0) V' N N z ,. n m ccE o c I co a 7 CO ❑ . 0) N moc Y Y as : : aa m= o i n _ g m : ` rnrn CD 0 aa oC = N a =d u v,m o o gc .0 .0 aa) 0 TO CO cInca o 'E' -0- cna) a) oo . E E .'.0 m o o N L E E 9 a EE aa) OEEEEa va � v m at (00) 0) 0) 0) 0)N D D (0 N O O 0) 0) 01 ) 00 L = a y 0' E O 2 2 m m J J ZZ (0O) OO S S E I-. 5 (.) m m d Z c' N. ti (0 (0 CO O) co 0 co 0 0 CO r r CO 0 Cl) 0) O c a v o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4- 0 N c 2 N O. O_ a. a. 0_ Q a. a. a O. a a a a a a. O. O. Eo ❑ 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 N • o Y Nm .0 a mmvv LC) N. meornrnoo y y 0 0 0 0 0 0 0 0 0 0 0 0 O 9 O O r O co 2 = o 0) co (n co co ch (n (n co co (n (b co (n (n (n ch (n (n CI a_ 00NNNNNN NNNNNN NNNNNN ' ' 1 111111 111 Iss O G) EYO a CO CO V V- (U O CO CO N. N. 0] c0 CO CO O O re X4- c E ' u) 900000 000000 000 or r .- o m (v (n CO (n (0 (n (n (n co (n (n (n (n (h (h (n co (n V) CL 435,2 Z n Y NNNNNN NNNNNN NNNNNN O O p„ CC c c c c c c c c c c c i= c m c0. 4 m y 2 m m m m m m m m m m m m m m m m m m a • Oc. C ca aaaaaa as aaaa aaaaaa 04 .... NZ C)O N C c0 a , , , . . I i . I i I , 1 1 i i i 1 6 _ j • • 0) N N ."4-' = Cl)a ca 0 H • O C • P. 04 ,� O U O U a a 0" (0 U) V) U o a U U U Cu e.. Y Y Y Q Q Q U u IX LJ- c) T T + c a 0 0 0 0 CDL p co O t `o CO co rn L CDN sco . In 0 Co as CO Cu Q Q) 0) N N N Cu N Cu N n nC n u m m n a 2 2 02 2 2 u I H1- HF- I- t- F- , -o Cl) cocCmmoOm N L 0 0 0 0 0 0 0 0L` a o. a a. a a a. O I N N N N N N N 9 0 a) 09 0 0 0 0 0 C co N NNNNNNN c0 N CO O.5. Cum c) N 0 0 I� ti N N LO C a) E ' OOOOV' V O Cu � O O M M I� N Cu -U C c C a +' O O V' V co co h Cu . N N CID CO V uj U Cu . ^_ N M lO V of p O Q Om T u) N Cu O • • _o- a —u L � a) m a ) a. Omc - c1/4d RI Cuco C0 7N-, 000NVVu) �.NO O CuCu 73 o CE ' OoVV (0 (0 U N N aro L. 0 2 UN N (0 CO cO CO co N -5, LL r c- co-m N au) U U O O O C m U re @N NONO F OOa@Qh C Cu _O m N m pIiN — u C 6vA / uE N Cu Cu `O C co- Cu a .LU O Cu - aO � _• 'N N L.L. O O O C O] C coC -2U to C O in C Q U N C N y N 4 — N N2 a) - W O U) O U Q • • ConocoPhillips 2S-02wp08 [Thresher] Schlumberger Alaska a _ 3 mo E -JC7 1 iiz 333 3 corn3nn MON C401 300 �r [. i 1 FII!4I1I�I��I1 III� id 161NiI C �i iII J O d111/'l1 !zzjiti i�ii 1,1 k, � ' 'I � 150 �l I ,11,,',';[ � o fir° I i1 9 �, ,Iihu� i I 111, 0• Or ,P,',1!f 11!I N [�.I ..Eguivelant Magnetic Distance 0 V 1 I I I I I I I I I I I [ I I I I I I I I I I I 1 I 0 3000 6000 9000 12000 15000 18000 Displayed interval could be less than entire range: Measured Deptl28.00 To 18477.78 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 18477.78 Results Limited By: Centre Distance: 2044.98 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1200.00 25-02wp08[Thresher](Plan:2S-02) GYD-GC-SS 1200.00 2200.00 25-02wp08[Thresher](Plan:2S-02) MWD 1200.00 3643.07 2S-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC 3643.07 5143.07625-02wp08- [Thresher] (Plan:2S-02) MWD 3643.07 12667.42 M WD+I FR-AK-CAZ-SC 12667.42 14167.42 25-02wp08[Thresher](Plan:2S-02) MWD 12667.42 18477.45 25-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2650.00 3643.07 10-3/4"x 13-1/2" 10-3/4 6388.00 12667.42 7-5/8"X 9-7/8" 7-5/8 6348.00 18477.45 4-1/2"x 6-3/4" 4-1/2 LEGEND - KRU 21-10-8,KRU 21-10-8,KRU 21-10-8 VO -0- Plan:2S-05,Plan:2S-05,2S-05wp06[Nurse]WIP...VO Plan:2S-09,Plan:2S-09,28-09wp06[Tiger]WIP...V0 - Plan:2S-01,Plan:2S-01,23-01wp07[Mako]VO -0- Plan:25-06,Plan:20-06,2S-06wp06[Salmon]WIP...VO— Plan:25-10,Plan:2S-10,2S-10wp09[Wobbegong]VO —X— Plan:2S-03,Plan:20-03,2S-03wp06[Bamboo]WIP...v8-e- Plan:20-07,Plan:20-07,2S-07wp08[Goblin]VO -9- 20-02wp08[Thresher] -e- Plan:2S-04,Plan:2S-04,2S-04wp09[Lemon]VO — Plan:2S-08,Plan:2S-O8,20-08wp07[Hammerhead]VO 30 • • ConocoPhillips 2S-02wp08 [Thresher] Schlumberger Alaska E £ � 4 "44 601111111111 • I? 30 111 111 - -4111 C Equivelant Magnetic Distance aJ -o I I 1 I I I Ili I I I I I I I I I 1 I I I I I I 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire range: Measured Deptt28,00 To 18477.78 ANTI-COLLISION SETTINGS Interpolation Method: MD,interval:25.00 Depth Range From: 28.00 To 18477.78 Results Limited By: Centre Distance:2044.98 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1200.00 2S-02wp08[Thresher](Plan:2S-02) GYD-GC-SS 1200.00 2200.00 2S-02wp08[Thresher](Plan:2S-02) MWD 1200.00 3643.07 25-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC 3643.07 5143.076 2S 02wp08[Thresher](Plan:2S-02) MWD 3643.07 12667.42 MWD+IFR-AK-CAZ-SC 12667.42 14167.42 2S-02wp08[Thresher](Plan:2S-02) MWD 12667.42 18477.45 25-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2650.00 3643.07 10-3/4"x 13-1/2" 10-3/4 6388.00 12667.42 7-5/8"X 9-7/8" 7-5/8 6348.00 18477.45 4-1/2"x 6-3/4" 4-1/2 LEGEND —� KRU 21-10-8,KRU 21-10-8,KRU 21-10-8 VO —181— Plan:2S-05,Plan:2S-05,2S-05wp06[Nurse]WIP...V0 Plan:2S-09,Plan:2S-09,20-09wp06[Tiger]WIP...VO - Plan:20-01,Plan:2S-01,20-01wp07[Mako]VO $- Plan:20-06,Plan:2S-06,2S-06wp06[Salmon]WIP...V0-1-- Plan:20-10,Plan:2S-10,2S-10wp09[Wobbegong]VO —X— Plan:2S-03,Plan:2S-03,2S-03wp06[Bamboo]WIP...V8-9— Plan:2S-07,Plan:2S-07,2S-07wp08[Goblin]VO -8- 2S-02wp08[Thresher] - Plan:20-04,Plan:2S-04,2S-04wp09[Lemon]VO —X— Plan:2S-08,Plan:2S-08,2S-08wp07[Hammerhead]VO 31 Milk c Azi TVD +N/-S +E/-W Oleg TFace arget 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 28 '-" 325 325.00 0.00 0.00 325.00 0.00 0,00 0.00 0.00 0.00 2S-02Wp0$ [Thresher] 1507.84 26.82 144.25 1469.00 -203.28 146.34 250 144.25. -171.62 325 -- 510 28.00 To 18477.78 1619.89 26.82 144.25 1569.0 -244.31 2907.07 70.38 161.06 2402.67 1097.79 175.88 0.00 0.00 -206.26 562.44 3.50 22.63 -970.30 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12687.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 2S-Thresher 1.Heel 022315 PB 690 870 14:16,February 25 2015 12697.42 85.00 14.80 6390.61 -4383.68 5263.42 0.00 0.00 -3298.83 12884.67 91.52 14.17 6396.29 -4202.56 5310.21 3.50 -5.52 -3112.11 870 1050 14303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696.44 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher 2.T1 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 1240 o-,m Prom Depth To surveyman tool 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 28.00 1200.00 2se2wpos[Thresher](Plan:03aAC55 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 2S-Thresher 3.72 022315 PB 1240 ' 1420 1200.00 2200.00 2302,308[000e00er](0an:8S00l 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1200.00 9614.07 25O2wy:[Thresher](Plan: RAKLAZSC 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00 -407.35 - 3649.07 6143.07 25U2wp08[thresher](Man:MS.) 15595.06 90.71 12.85 6373.00 -1576.46 5976.68 2.00 -18.81 -407.09 2S-Thresher 4.73 022315 PB 1420 1600 9643.07 12667.42 2sO2wm08]Thresher](PIan:I00809 R AKLAZSC 12667.42 14167.42 2302,08[Thresher](Maur me..) 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 67 126 .42 16477.45 2S-02wpt8[Thresher](P1an:16A®yFR-AKLAZSC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 1600 2300 16866.27 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 2S-Thresher 5.74 022315 PB CASING DETAILS 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 TVD MD Name Size 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.81 1670.98 26-Thresher 6.T5 022315 PB 3000 3700 2650.00 3643.07 103/4"z 13-1/2" 10-3/4 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 2S-Thresher 7.Toe 050714 PB 6388.00 12687.42 7-5/8"X 9-7/8" 7-5/8 6348.00 18477.45 4-1/2"0 6-3/4" 4-1/2 3700 -- 4400 4400 --- 5100 5100 -- 5800 5800 - - 6500 0/360 i` j+,/' • 6500 __.__ _ 7200 2S-03wPo6[Bamboo]WIP... �.. +�.�. 7200 8610 �o yes. -30/330.�s%,®•+ ft~ % 30 8610 -- 10020 !,400.0•ew-�� •_ - 195 _sal �of.���'s••, - 10020 11430 .,. . �.����tits.�,ilii`+ 18tJ 11430 12840 2S-05wp06[Nurse]WIP.. 1i��y�i10:...I,osie'�`�eilM 16 =.� 12840 14250 ;� �Ii �i.1,�S', ') 150 /5, �..•'#' 0184 ` 14250 15660 I2S-06wp06[Salmon]WIP. .ra✓�� ��4"i���4I[ilir% �® \ \ 15660 17070 -60/300 �� .✓ ,a ry400400;;',! 1.�,+� -120 - 60 17070 18477 0-- �i.. .7ioi 60'71"► ► `` `` ,��.s.�Awrio�s ��'i�.v_%�i w..ars' ``� � ��'1 414-'1�/Alirir y/' �Ar♦446!; i4fl� //�� 1 .�d'�• i<9 in ]I�:1�ff�1 s i , 1/ig/y ll� �� 9 Ifo •S-08wp07[Hammerhead/0;41-14:944006:.471%f*.41 !11f y/Iv��• I�i0*7--16 - s e°i 1)r/��/ ( \,,,,` s� 7/4-r0,1I,/0 o�„ ,, f �4r c=: .di71r1111r1t r'� i1T/ISr 4J C ♦ !1 �,`?4,ft i�i a*i�/Yffi r;r4M41 -6i,- ".`, r�1,1 t1 (' l�, ` 2S-01wp07[Mako] • 17,•�t' i Isar „,„,„,,,,,,4,,,,, ,,...,,,..,.„,,...„,„,....,....„..5,4� �i it0--. ` q" 1 1 I [11,+�/s]11� r 4V:. � . ,1 , .r:T +-►®aM 1 '_yVi?-' , ./,/�/' k \\ ` 171 � � 2S-04wp09[Lemon] 111*, L i��' f/� 4 n.44`�r r ` 4);;,1;00,'-':".:_;-•�lr Y \O`•'"�` Itire�''- 1 ,f riq S ,r sy y'•,'/� .' 1,,,,,I,..7,:. :'..7". ...VI. _i Il ' aYaal'� -90/270 'r.�47�_ .7 c �''p'i0p r{, ; �f,1 II I 90 /1(1.1'74 t1'�14Jrto \ / lhi iii I .•�i+pJ 7 j1 . Ill 11d P, ° \k,ti* \�r. .`� , ,, . „, „ , ..„,,„‘ 2S-07wp08[Goblin% - - _.. ,.. _... .__. � / ,/ 2S-09wp06[tiger]WIP... ` �` �- •� -12U/240 `� / 7 �� 120 120 I 10,`, &� 150 � III165 `� � 180 :____ 4%iiimmu195 } -150/210 210 _ 150 -180/180 $ KM 11.165.0.0021.1.8.as 21-105 v0 -e P 204.009 Amnon!vo $ P so740(00WSWi0 ;. P. 2s10.009[00eewrvlv0 ♦ Plan 3.01.a71..mlvo P 50541000!Nurse]NM 30 4f P, 2505 Pon:22555.2308,0110am"enpmlw $ 26orr0e 7110e1.a10 .e. Pa..2002.Part 2500 2300.ps(9052551 OIP.,v0 .e" Pan 2505 Pim'2505 2506..00615.050n1v2P..v0 "4 090 2805 Pan 2505 2505"P06112w!150P-.40 32 • • Northing (2500 usftlin) IIiiiiIi . i . IitilIiiiiIiiiiIiiiiIi . ilIiiiiIiiiiIiiiiIiii . IimIiiiiIiiiiI . co 9. 0 - - Y - _ (0 — N )_ O. O. H iu o - - Q. I� N - °, - - OO Q - N3 7 NO , x- - - z - U) CN \ CC O Y - O. _ 0 3 O 1 — - 9 a • O. N ✓ O - _ O O — a u) E N N m N CO 01 O - d '0... - rn 3 • o • o N - 3 N• N - y =- 00 O C N _ JN fillif d -CZN CD ‘qI n '� — c - 3 0 0 w co _co O co W (� N N �� — n. 3 - co _ I Ch as N - — O Cl. O. CO - CO o — N N _ Q`a (..1v�.ma - =1a G coN � - — a o _ N• j � - - 2 . — o _ a` I I I II I � � � lI I i III I I IIIIIIIil 11111 IIII IIII I III I ' III M.� (u!/14sn 005Z) 6u!LIPoN AC Flipbook MD Inc TVD +N/-S -,E/-W Dleg TFace target 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 28 `m--- 325 ��++ 325.00 0.00 0.00 325.00 0.00 0.00 0.00 0.00 0.00 2�7-02Wp08 [Thresher] 600.24 4.13 144.25 600.00 -8.04 5.79 1.50 144.25 5.79 325 - 510 1507.84 26.82 144.25 1469.00 -203.28 146.34 2.50 0.00 -171.62 175.88 0.00 0.00 28.00 To 500.00 1619.89 26.82 144.25 1569. -244.31 2907.07 70.38 161.06 2402.87 -1097.79 6.26 562.44 3.50 22.63 -970.307 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 2S-Thresher 1.Heel 022315 PB 690 870 12697.42 85.00 14. 0 6390.61 -4383.68 523.42 0.00 0.00 -3298.3 14:18,February 25 2015 12884.67 91.52 14.17 639829 -4202.56 5310.21 3.50 -5.52 -3112.11 1 43 03.0 1 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696.44 870 1050 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher2.T1 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 1240 o-u1 From Depth T. survey/Plan Tool 15043.58 88.22 15.10 6378.62 -2112.77 5848.70 0.00 0.00 -957.96 28.00 1200.00 2smwpoe[Thresher](Plan:eG0121C5s 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 2S-Thresher 3.T2 022315 PB 1240 1420 1200.00 2200.00 2642,08[Thresher](PIan:10G.as) 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1200.00 3646 07 264 12,08[Thresher](Plan:l®8327FRAKCAZSC 15594.79 90.70 12.85 8373.00 -1576.71 5976.63 0.00 0.00 -407.35 66007 6143.07 210.806[Thresher](Plan:10GM) 15595.06 90.71 12.85 6373.00 -1576.48 5976.60 2.00 -18.81 -007.09 26-Thresher 4.T3 022315 PB 1420 1608 3649.07 12662.62 26O2wp08[Thresher](Plan:RWm/FR- CAS 12667.42 14162.42 23-02WD[Thresher](PIan:RNDY) 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 12667.42 18472.46 2602wp08[Thresher](Plan:RW®/FR-AKSA2:SC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 1600 2300 16866.27 90.00 15.27 8388.00 -349.49 6308.61 2.00 -0.23 860.67 23-Thresher 5.74 022315 PB CASING DETAILS 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 TVD MD Name Size 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.61 1870.96 2S-Thresher 6.T5 022315 PB 2650.00 3643.07 10-3/4"x 13-1/2" 10-3/4 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 2S-Thresher 7.Toe 050714 PB 3000 3700 6388.00 12667.42 7-5/8"X 9-7/8" 7-5/8 3700 4400 6348.00 18477.45 4-1/2"x 6-3/4" 4-1/2 4400 5100 5100 5800 5800 ---- 6500 0/360 6500 7200 r 1 //� 7200 8610 -30/330, " 30 8610 10020 �" �f � 10020- 11430 11430 12840 7// �� 50 ` 12840___ 14250 - �� �-� � 14250 15660 � --:_,-,--7.-_-_,-,-_,,,,,,,,,`'�., � ;� ` 60 15660__.. 17070 60/300 / �� 17070 18477 7. on 3 26-03wp06[Bamboo]WI'A /7 7/if7 7 7/7-,, ,.. ,,,, ,,:;, i car , 1 \\ ,:,,„),.) iiiii: -so/270 thitli � ��% , �, i 1,, ‘'' �I �41�)114,L. \�,\, ' ikv -.,--, , ' ,,, ,,,\\•\, iii.-e-- [Makoll ��\ �; 128-041809[Lemon]I � �� -120/240 • 40 jam- 120 - -,,ss....„---„;...„..-- ,-. .,...,------ „.•:....,....„--.' - ---„--. ,/ tiosi0.000". /1/ 65 _ , -150/210 �� i iii000- / 150 -180/180 $ - U21.1ceoe $ 2511764 RnmN 40 " " 7.2s02w5010oun1w $ Fcn 2sl.R.m 04.142s1..p IwooOeym5lw Gnu2111..0 200.0.6R Pum.2sw,Mar Oss. P.n2407 Plan200 -} P262409014.2040.2501wpo71ua41w $ Pam 2402,P00240..250375010010141...m " - Pum290..P0n260.2vret051wmm,memlw $ 250,P0e 0+0.40 Pmn 2sm,Pun 2505.x03vot le.emo]WM..w $ Pum.25-06,Pum 240.2s-0s,.isnmonp000 v. $ Pen 25re,Plan 250,2O-0.1.f0w1 o1P...V. 35 M0c Azi TVD -1-N1-0 +E/-W Oleg TFace VOrget 28.00 . 0 0.00 28.00 0.00 0.00 0.00 0.00 0. 28 - '--- 325 2S-02wp08 [Thresher] 325.00 0.00 0.00 325.00 0.00 0.00 0.00 0.00 0.00 690.24 4.13 144.25 699.00 694 5.79 1.50 144.25 -6.79 1507.84 26.82 144.25 1469.00 -203.28 146.34 2.50 0.00 -171.62 325 510 500.00 To 1000.00 161 .8 26.82 144.25 1569.00 -244.31 2807.07 70.38 161.06 2402.87 -1097.79 175.88 0.00 0.00 -206.26 562.44 3.50 22.63 -970.30 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 2S-Thresher 1.Heel 022315 PB 690 870 14:20, February ZS 2015 12697.42 85.00 14.80 6390.61 -4383.68 5263.42 0.00 0.00 -3298.83 12884.67 91.52 14.17 6396.29 -4202.56 5310.21 3.50 -5.52 -3112.11 870 1050 '14303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696,44 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher2.T1 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 __u 1240 0002 From Depth To Survey/Plan Tool 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 28.00 1200.00 25502p09[20reaherl(2l2n:02e20css 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 20-Thresher 3.T2 022315 PB 1240 1420 1200.00 2200.00 25-02,608[Thresher](P1.161802) 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1200.00 3667.07 355208608[TM1ruher]lPlan:188816/FR-AKLAZS0 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00 -407.35 3642.07 2167.07 Zsozwp08[Thresher]lPlan:MsM 15595.06 90.71 12.85 6373.00 -1576,46 5976.68 2.00 -18.81 -407.09 2S-Thresher 4.T3 022315 PB 1420 1600 3662.42 12667A2 -02wp06[Thresher] ®.9D/FR-AK{AZSC(man: 12667.42 14167a2 zsazwpee[Thresher]lPlanaco.al 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 12667.62 18477.45 25-0208206[Thresher)e1n:l®IEV1R-54LAZSC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 1600 2300 16866.27 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 2S-Thresher 5.T4 022315 PB CASING DETAILS 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.61 1670,96 20-Thresher 6.T5 022315 TVD MD Name Size 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 2S-Thresher 7.Toe 050714P B 2650.00 3643.07 10-3/4"x 13-1/2" 10-3/4PB 3000 3700 6368.00 12667.42 7-5/8"X 9-7/8" 7-5/8 6348.00 18477.45 4-12"x 6-3/4" 4-1/2 3700 4400 4400 5100 5100 5800 0/360 5800 6500 y 6500 7200 ��f --_-__Z:1,2.-:- 70 7200 8610 -30/330 �, �� 8610 10020 i y�j' -- '`� 10020-- 11430 4 0,' ��F 6f1- - �� �j��''�,� ,.._---- = �`�� N30 , 11430 12840 2S-03wp06[Bamboo]WIP... i/ Ya��'��/ �/.7.91,0*. 5 0 12840----- 14250 /�//� � ♦ _- � 14250 15660 ��.� ; 15660 17070 60/300 ����/ „:"...„:":„;.it.-00. -. 40 ��� \' 60 //,Irv; - -. 17070 18477 7 r% -ice; .. :_� .,,._ :,.,.� „i/ 7- ft. I�� "I'i/rte//� 30 35 - //1/ " . '1- q// : ,,_ -,-',„,,„,,,:,\: ,__\_____.-__,\\ 1 „:::e„,--.\.,xT\1\\%‘\%\ _.,,i,,,,,,,,. i fogittv --_: -tii,----„,.:„,, ,, *--", , ) , rt 1 .O°il,Allit IN. g 1 it 4 sop.44 it. ii a:4` �,��N g �p►i 7„,4,///( iiii „,:ift:4.4 it 4�rr l'1111 / reefilly, ViiiiiArlf/VAVIFF ' i I'lliMr.rappyi lig 1 1 90 / gools 44 4 11 I, viuutio\ I , „_ ,, / --- -fo,-,14, _,,,_ I , wif..owe "is \I, , ':•11.-,-voloilio/\ \ \\3/44‘ \--::::--., ir: , - so.4 \:-,---.., _,_. i , %\\V- ‘$ /1 12S-0408,09[Lemon] � 30 iii//////i �, \ \ �� `._.._...... / 12S-01wp07[Makol 120/240 , 40 120 \\ 55 60 ��_. 65 " ...------ ":""/ -150/210 70 150 35--= -180/180 $ IOW 2,104,KM 2.0,5Ru21-mav0 $ w ..mOM4.N VO $ 4.m.0,0.008laaam1 w At- Pan 20IA P.a 2s,A 25K",E 1.52500541 v0 ♦ Pun 50,,06 imam 0867 un:25-09.2506^4nlnmvel ww..25 - n. 50e.26e0nmr(K.mmmrawIVn $ 2S000P2,rmiane,l 24.02.Pan 2502.2 2503.P w 2593,our 41- Pan 2502 Pan 2508 2606,00 leant.,VAR..VO $ Pan.24.0,Pun 2505 250e6p0lsmimnl AIR...w 44. wn 22.09.Plan 2509.26.¢6,0 Rol NAP..v0 36 111 MD Inc Azi TVD +N/-S 'cE/-W Dleg TFace VS Target 28,00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 28 "" ---. 325 325.00 0.00 0.00 325.00 0.00 0.00 0.00 0.00 0.00 2S-02wp08 [Thresher] 600.24 4.13 144.25 600.00 -8.04 5.79 1.50 144.25 6.79 325 510 1507.84 26.82 144.25 1469.00 -203.28 146.34 2.50 0.00 -171.62 175.88 0.00 0.00 -206.26 1000.00 To 2000.00 1619.89 26.82 144.25 1569.00 -244.31 2907.07 70.38 161.06 2402.87 -1097.79 562.44 3.50 22.63 -970.30 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 20-Thresher 1.Heel 022315 PB 690 870 12697.42 85.00 14.80 6390.61 -4383.68 5263.42 0.00 0.00 -3298.83 14:21.February 25 2015 12884.67 91.52 14.17 6396.29 -4202.56 5310.21 3.50 -5.52 -3112.11 870 1050 4303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696.44 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher 2.T1 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 1240 o.otc From Depth To sc,a.c,Plan Tom 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 28.00 1.0.00 26oawp09[Thresher](Plan:osmScss 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 2S-Thresher 3.T2 022315 PB 1240 1420 1200.00 .00.00 22.-011wp08[Thresher](P1an:102:102) 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1200.00 0649.07 25O2wp08]TM1raM1er]Man:lOPlm/FR-AKLPZSC 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00 -407.35 643.07 6146.07 22.-02w808[Thresher][Plan:880,06) 1420 - 1600 6643.07 12667.42 75-02w808[Thresher][PIan:103J111/814-7/11CAZSC 15595.06 90.71 12.85 6373.00 -1576.46 5976.68 2.00 -18.81 -407.09 20-Thresher 4.T3 022315 PB 12667.42 14167.42 20-0274/06[Thresher](PIan:13612l 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 12667.42 19477.45 3602wp08[Thresher](PIan:111Y.m/FR-AKCFZSC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 1600 2300 16866.27 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 20-Thresher 5.T4 022315 PB CASING DETAILS 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 TVD MD Name Size 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.61 1670.96 20-Thresher 6.T5 022315 PB 3000 3700 2650.00 3643.07 10-3/4"x 13-112 10-3/4 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 20-Thresher 7.Toe 050714 PB 6388.00 12667.42 7-5/8a X 9-7/8" 7-5/8 3700 4400 6348.00 18477.45 4-1/2"x 6-3/4" 4-1/2 4400 5100 5100 5800 0/360 5800 6500 6500 7200 - x 7200 8610 30/330 70 � 30 8610 10020 /i `65 ;\\ 10020 11430 60 `= 11430 12840 j -50 *` 12840 - 14250 14250 15660 44 /// 45 ~�� Vd .�V 15660 17070 -60/300 �� - =4� 60 7070 18477 -'------ -> ,-'- -.:.',': .' Alligl N:A041/41,11,.•'....' ,, /////00 : T:,..,'-i.ift:_-_-___-..111.7----_, ---z..---------_-_ ,--2:::, ,--„, \ ,):),;;;#11111r1(IN, 7 .,. :' l't if1iif tit/;1 :>>„0,0"':"7" 1:,:1--:;. , ;II 1 ..\\ ,\:.:4 4)1.' ,•,',\.‘ I( i 1, di PA '.,L \\\',,A\\\ V,\* -,..0. ,0 0 A ,4 90/270 i i 1I'��il��' `�'', t.:::,:‘,.\, \, 411-7 �� ��1"‘,---_,------_--_,-07,74ll � I 1 \ \ \ \ ki. W''' ,\ \ -- itio: //1 ---' ,...r'.//I/ ilk \ ` 30 / L \-�, ,/� ,, /1� ,w_ / -120/240" -�� � �` 40 / -120 \ j\`� \�_` 50 III// 60 ;� : 65 -150/210 \\� 70 150 -180/180 $ Pu osoa..µ011emnnlw $ 2s67+;µ6[Galnlw -} P 5 516.010,1nyp10120 KRU2,-16a,K926-- „16602 Plan Pan:26-27.Pon2627. Plan osc ,2.2 � P..26-07 wn2sal.smwlm Nadal 20 '0' Pian 2505.Pan 2604 sa4.4a la+a+alwiP..w � Pun 2620 Pun 2564 ts6ary17lxamm.m.zelw '$' 5607«µe f*6a.k;l -ee. Pan:4602.ran 02.050sm..Wa 12.50002 w»..20 $ Pan 22.24 Pun 2524 sm,coelsssmnlsor..w -rte Pun 2525,Pun MOO.sorry nes'w1P.,20 37 MD Azi TVD *NI-S +E/-W Oleg TFace VOrget 28.00 .00 0.00 28.00 0.00 0.00 0.00 0.00 0. 28 -"- 325 2Sn 322.00 0.00 0.00 322.00 0.00 0.00 0.00 0.00 0.00 -02wp08 [Thresher] 666.24 4.13 144.25 666.66 8.64 5.79 1.20 144.25 -6.79 n T nn n 1507.84 26.82 144.25 1469.00 -203.28 146.34 2.50 0.00 -171.62 325 510 2000.0® ®o 40vv•0L 1619.89 26.82 144.25 1569.00 -244.31 2907.07 70.38 161.06 2402.87 1097.79 175.88 0.00 0.00 -206.26 562.44 3.50 22.63 -970.30 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 2S-Thre5her1.Hee1022315 PB 690 870 12697.42 85.00 14.80 6390.61 -4383.68 523.42 0.00 0.00 -328.3 14:29,February 25 2015 12884.67 91.52 14.17 639629 -4202.56 5310.21 3.50 5.52 -3112.11 14303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696.44 870 1050 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher 2.21 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 1240 Dec,From Depth m Survey/Plan Tool 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 2500 1200.00 23a2wp49[Thresher](P(an:aam6ess 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 2S-Thresher 3.T2 022315 PB 1240 1420 1200.00 z2°.04 26-02,08[Threshed(Plan(AVM 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1x°.00 4m3.41 2202wp09[Thresher](PIan:R rFR-RKCA259 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00. -407.35 964307 2167.42 zsmwpoe[Thresher](Plan:mA@] 15595.06 90.71 12.85 6373.00 -1578.46 5976.68 2.00 -18.81 -407.09 2S-Thresher 4.T3 022315 PB 1420 1600 9669.42 1 x667.42 25-02,00[Thresher](Plan:MAW)FRANCPZSC 1z9n.4z 1416162 25-02xp00[TM1resM1er](PIan:9R@) 15737.03 89.23 15.27 6373.07 -1438.75 6011.18 2.00 121.42 -265.33 12667.42 19417.60 25472o011[Thresher](PIan:10841015R'0l(C/SSC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 0.00 0.00 822.26 1600 2300 16866.27 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 2S-Thresher 5.24 022315 PB CASING DETAILS 18891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 TVD MD Name Size 17678.42 92.15 11.13 8378.00 436.11 6513.65 2.00 -87.61 1670.96 2S-Thresher 6.15 022315 PB 3000 3700 2650.00 3643.07 10-3/4"x 13-12" 10-3/4 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 2S-Thresher 7.TDe 050714 PB 6388.00 12667.42 7-5/8"X 9-7/8" 7-5/8 6348.00 18477.45 4-12"x 6-3/4" 4-1/2 3700 4400 4400 ------ 5100 5100 5100 5800 0/360 5800 6500 _ 1 6500 7200 ....•"".'7:"------____.-1:--= Llk„71_-i1t., ~ 7200 8610 30/330 ,' `"" 30 8610 10020 h-',7:#1.0.,i1aPp/.,A,/IA/16P1.s140e,1.i,WtA#e10W_0l_0h1l_4r0a_1a_000']ei'r1l1#,E:41ii I,41'1rA•/.4'r,'"4,-,.'/i, 1'*/4"i,;4 0,;•,',.t.../,t,,\_,•- -•-.:7-:•-7-(--',_-ao01 , :sie:7-:__\-.7 ,.-l. .e; 30 '� /'0": .`-` � 10020 11430 I�i'i�S�,; 1 .-'..--]. ..."1"1.li.i\.1.i.(.\i., t-'4%'.-,'\=,,,:,-,.,','t.' ���i444, • ,\`` 11430 - 12840 /�I��iI♦ �.o.,. �: � 12840 14250 .II IS I/BVf, 104 - --\ � //moi * .I/.e9 /�/rr - 14250 15660 /////1 te#:1 ., 15660 17070 60/30 � !is'/ i,+l 80 4 : 6017070 18477 ted// //, ��, \ i�it�` I2S-01wP07[Makol /r/,,,N iii s_.:,_ - i° \ /,,•/.,,„e, '4,,'#tr,'t, "',\t,\,,"„\:\._...\6._:.:C.[._]„.,_-;:.\_„.'n,_.v.:':_ 12S-05wp06[Nurse]WIP.. ""„ 6 \\--','\,\((,e,0\\•\5\,.531•,' / \' i# , .P ,„ HI 11 1 90/270'" I- V 1 SN--.-.\®r 90 1 I 3e 111 //// 7,-----"" • -----.--::_.-z----::_----- - -,, /de i -120/240 .` `'` 80 120 100 \ -- A .,,,-..****----..-- : •••°,4",1,7 ` ftm � 1.10 .:.. 11-1ft-sm.._, --- -„ , X30 150/210 \ -1x4050 150 -180/180 $ 994 $ aoa+m 21L.,ss(vo $ zsm.,m9(00e,yv0 t P 4.1$zs,ong041004 egaagl VO 4 w solss07(Mw(w ♦ 2s0s.ws(«m,a(SOP w j(- Pm,2.04 Pa.:25042sm.w7(wmmemeas(v0 -a- 2540700[""74'I PIM 2.20,.Plan Ran 2200.P�m.:S°. -r- Plan 23.03.Plan:54.0575.03,n;(9amaayw,P..00 $ Plan 2506.Plan as0s 2s0ax6(M1w,P..vs -, P.2509.Part 0S09,25-09,433(ryerlv2P.vo 38 M• Azi ND +N/-S +E/-W Dleg TFace VSSarget 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 28 __. -'' 325 325.00 0.00 0.00 32 .00 0.00 0.00 0.00 0.00 0.00 2S-02wp08 [Thresher] 620o.2a 4.13 144:25 600.00 -0.04 5.78 1.50 144.25 6.79 325 510 1507.84 26.82 144.25 1469.00 -203.28 146.34 2.50 0.00 -171.62 175.88 0.00 0.00 -206.26 4000.00 To 18477.45 161 .89 26.82 144.25 -244.31 2907.07 70.38 161.06 2402 807 -1097.79 562.44 3.50 22.63 -970.30 510 690 7120.26 70.38 161.06 3817.53 -4851.46 1850.71 0.00 0.00 -4409.19 12667.42 85.00 14.80 6388.00 -4412.57 5255.79 2.50 -123.06 -3328.65 2S-Thresher 1.Heel 022315 PB 690 870 12697.42 85.00 14.80 6390.61 -4363.68 5263.42 0.00 0.00 -3298.83 14:31.February 25 2015 12884.67 91.52 14.17 6396.29 -4202.56 5310.21 3.50 -5.52 -3112.11 870 1050 14303.01 91.52 14.17 6358.58 -2827.86 5657.31 0.00 0.00 -1696.44 SURVEY PROGRAM 14329.31 91.00 14.22 6358.00 -2802.37 5663.76 2.00 174.59 -1670.19 2S-Thresher 2.T1 022315 PB 14475.01 88.22 15.10 6358.99 -2661.44 5700.63 2.00 162.36 -1524.81 1050 1240 orn From Depth T5 Survey/Plan roof 15043.58 88.22 15.10 6376.62 -2112.77 5848.70 0.00 0.00 -957.96 26.00 1200.00 o onspoo]Thresher](PIan:G65M3GSS 15132.65 90.00 14.98 6378.00 -2026.77 5871.81 2.00 -3.97 -869.14 2S-Thresher 3.T2 022315 PB 1240 1420 1200.00 2200.00 25-02wp60!T5re55e5](Pla5: l 15244.74 90.70 12.85 6377.31 -1917.97 5898.77 2.00 -71.67 -757.19 1200.00 5643.02 2502,68[Thresher]IPIz00:1091m90R-0KL0ZS0 15594.79 90.70 12.85 6373.00 -1576.71 5976.63 0.00 0.00 -407.35 1420 1600 5645.02 2167.02 05-0Twp06[Thresher](Pian: 1 15595.06 90.71 12.85 6373.00 -1576.46 5976.68 2.00 -18.81 -407.09 2S-Thresher 4.73 022315 PB 5645.02 12667.42 25-02wp06[Thresher](Plan:lSSMS6)R-AKLAZSG 12667.42 18461.42 25-02w606[Thresher](P1an:me.�) 15737.03 89.23 15.27 6373.07 -1438.75 62 .17 2.00 121.42 -265.33 12662.42 16an.46 25SNap00[Thresher]IPIan:10W./FR-AK CAZSC 16827.75 89.23 15.27 6387.74 -386.65 6298.47 01 2.00 0.00 860.66 1600 2300 16866.27 90.00 15.27 6388.00 -349.49 6308.61 2.00 -0.23 860.67 20-Thresher 5.74 022315 PB CASING DETAILS 16891.29 90.49 15.17 6387.89 -325.35 6315.18 2.00 -11.79 885.63 2300 3000 17460.19 90.49 15.17 6383.03 223.71 6464.02 0.00 0.00 1452.99 ND MD Name Size 17678.42 92.15 11.13 6378.00 436.11 6513.65 2.00 -67.61 1670.96 20-Thresher 6.T5 022315 PB 3000 3700 2650.00 3643.07 10-3/4"x 13-1/2" 10-3/4 18477.45 92.15 11.12 6348.00 1219.58 6667.68 0.00 -76.91 2469.43 20-Thresher 7.Toe 050714 PB 6388.00 12667.42 7-5/8"X 9-7/8" 7-5/8 3700 4400 6348.00 18477.45 4-1/2"x 6-3/4" 4-1/2 4400 5100 5100 5800 5800 6500 0/360 6500 7200 225 - ; 7200 8610 -30/330, 210 � 30 8610 10020 195 --.1.-:z.....-7-----..- 180 \ �: 10020 11430 180 ----;,;::::-... -'---\--.. 11430 12840 � 165 / 12840 14250 /j 150 `�� 14250 15660 13 ` 15660 17070 -60/300 001111.1 12 �\ ` 6017070 18477 //1/� � 10 //////1 , _. 60 ....„,,----„,: -.„•.\\ %\l% . , � ,11 1i1 90 90/270 j1�i _��' 11 \, 111 \ �� r. )/)1 75 , '0 / / 120/240 120 120 \� 13L- .fr 15if/ 195 -150/210 ��; 150 \ �� 210 225 -180/180 -8- ARO 104.KAU 3,104 rw021-,oavo a Marc20.04,Pen 3604 25044006 Aerroal tel $ or0058lcaou.]Vo .4- Rill 2.10.Ran MI.2aiem0t5o5myoOl v0 2051.Pert taw.2.01w0TIRlol V0 Pen 0x04.Pee 250.250.026104"I wP-.w en 2508 Part 2508 ssoew0071.",.m..2l00 $ 2a�,roe 1n 2.0'0. P� P�,:2ao6,Pw�.25oe, j(- Pen 2500 Pen 2000 2000.4.16am004140P...so $ Pzn:2000 Plat 2604 2s0e.4 8151 on1 WIP...VO 'd" P 20..50017x0 PAP...00 39 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Plan: Kuparuk 2S Pad Plan: 2S-02 Plan: 2S-02 Plan: 2S-02wp08 [Thresher] Error Ellipse Survey Report 25 February, 2015 0 talc 1• c. dl errors: Multiply by 2.58 40 • . Schlumberger ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-02 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Plan:Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.O0usft(Doyon 141) Well: Plan:2S-02 North Reference: True Wellbore: Plan:2S-02 Survey Calculation Method: Minimum Curvature To Output errors are at 1.00 sigma Out Design: 2S-02wp08[Thresher] p OAKEDMP2 r-Multiply by 2.58 Database: .41 Project Kuparuk River Unit,North Slope Alaska,United States MapSystem: System Datum: Mean Sea Level GUsing Well Reference Point Map Datum: Using geodetic scale factor Map Zonne:e: Site Plan:Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: LPosition Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well Plan:2S-02 Well Position +N/-S 0.00 usft Northing: usfi Latitude: +E/-W 0.00 usft Easting: usfi Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-02 Magnetics Model Name Sample Date Declination Dip )Angle Field Strength (0) BGGM2014 6/1/2015 18.63 80.80 57,540 Design 2S-02wp08[Thresher] Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 From(TVD) TVD) +N/-S +El-W Direction Vertical Section: Depth(usft) (usft) (usft) (0) 28.00 0.00 0.00 11.00 Survey Tool Program Date 2/25/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,200.00 2S-02wp08[Thresher](Plan:2S-02) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,200.00 2S-02wp08[Thresher](Plan:2S-02) MWD MWD-Standard 1,200.00 3,643.07 2S-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,643.07 5,143.07 2S-02wp08[Thresher](Plan:2S-02) MWD MWD-Standard 3,643.07 12,667.42 2S-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12,667.42 14,167.42 2S-02wp08[Thresher](Plan:2S-02) MWD MWD-Standard 12,667.42 18,477.45 2S-02wp08[Thresher](Plan:2S-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) 0) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) I°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 325.00 0.00 0.00 325.00 038 0.00 0.38 0.00 1.15 0.01 0.01 0.38 0.38 0.00 GYD-GC-SS(1,1) 600.24 4.13 14425 600.00 0.59 0.00 0.59 0.00 1.16 0.05 0.05 0.59 0.59 54.99 GYD-GC-SS(1,1) 1,507.84 26.82 144.25 1,469.00 1.50 -0.06 2.36 0.20 1.13 0.28 0.35 2.38 1.62 144.75 MWD(1,2) 1,619.89 28.82 14425 1,569.00 1.58 -0.06 2.98 0.30 1.15 0.32 0.45 2.98 1.69 144.81 MWD(1,2) 2,907.07 70.38 161.06 2,402.87 2.25 -0.49 7.00 -0.07 1.81 0.71 0.88 7.03 2.48 155.28 MWD+IFR-AK-CAZ-SC(2, 3,643.07 70.38 161.06 2,650.00 3.44 -0.49 11.36 0.09 2.91 0.84 1.22 11.37 2.89 157.81 MWD(2,3) 7,120.26 70.38 161.06 3,817.53 6.98 -0.49 25.26 -0.07 6.42 1.62 3.48 25.26 3.83 160.29 MWD+IFR-AK-CAZ-SC(3, 11,21200 64.49 46.19 5,998.00 17.96 -3.80 13.81 5.86 11.69 4.58 7.49 32.71 13.24 141.84 MWD+IFR-AK-CAZ-SC(3, 2/25/2015 4:30:40PM Page 2 COMPASS 5000.1 Build 65 41 I • Schlumberger ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-02 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Plan:Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-02 North Reference: True Wellbore: Plan:2S-02 Survey Calculation Method: Minimum Curvature To calculate actual errors: Design: 2S-02wp08[Thresher] Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) Ii (usft) (usft) (usft) (usft) (usft) (usft) lush) lush) (usft) (usft) (°) 12,614.33 84.19 15.86 6,383.00 14.14 -5.06 24.03 5.96 13.85 5.04 7.82 31.83 19.67 138.29 MWD+IFR-AK-CAZ-SC(3, 12,667.42 85.00 14.80 6,388.00 14.14 -5.06 24.03 5.96 13.85 5.04 7.82 31.83 19.67 138.29 MWD(3,4) 12,682.25 85.00 14.80 6,389.29 14.17 -5.06 24.01 5.96 13.86 5.04 7.82 31.96 20.06 136.84 MWD(3,4) 12,697.42 85.00 14.80 6,390.61 14.17 -5.06 24.01 5.96 13.86 5.04 7.82 31.96 20.06 136.84 MWD(3,4) 12,884.67 91.52 14.17 6,396.29 13.86 -5.03 23.47 5.87 13.88 5.04 7.75 31.23 20.42 133.45 MWD(3,4) 14,303.01 91.52 14.17 8,358.56 14.14 -5.03 23.86 5.96 14.18 5.01 7.82 30.48 22.00 130.13 MWD+1FR-AK-CAZ-SC(4, 14,329.31 91.00 14.22 6,358.00 14.15 -5.03 23.84 5.96 14.17 5.01 7.82 30.45 22.02 129.95 MWD+IFR-AK-CAZ-SC(4, 14,373.31 90.16 14.49 6,357.55 14.21 -5.01 23.68 5.95 14.20 5.01 7.83 30.38 21.99 129.25 MWD+IFR-AK-CAZ-SC(4, 14,475.01 88.22 15.10 6,358.99 14.30 -4.98 23.48 5.94 14.23 5.01 7.84 30.30 21.97 128.51 MWD+1FR-AK-CAZ-SC(4, 15,043.58 88.22 15.10 6,376.62 14.56 -4.98 24.18 5.94 14.49 5.03 7.93 29.95 23.20 128.22 MWD+IFR-AK-CAZ-SC(4, 15,132.65 90.00 14.98 6,378.00 14.54 -5.03 24.35 5.95 14.54 5.03 7.95 29.90 23.43 125.89 MWD+IFR-AK-CAZ-SC(4, 15,153.33 90.13 14.59 6,377.98 14.57 -5.04 24.53 5.98 14.58 5.03 7.96 29.86 23.58 125.53 MWD+1FR-AK-CAZ-SC(4, 15,244.74 90.70 12.85 6,377.31 14.59 -5.05 24.63 6.00 14.60 5.03 7.97 29.82 23.63 125.23 MWD+1FR-AK-CAZ-SC(4, 15,594.79 90.70 12.85 6,373.00 14.80 -5.05 25.28 8.00 14.81 5.03 8.02 29.63 24.56 123.99 MWD+IFR-AK-CAZ-SC(4, ' 15,595.08 90.71 12.85 6,373.00 14.80 -5.05 25.28 6.00 14.81 5.03 8.02 29.63 24.56 123.99 MWD+1FR-AK-CAZ-SC(4, 15,622.39 90.43 13.32 6,372.73 14.89 -5.01 25.10 5.94 14.88 5.03 8.04 29.55 24.58 122.57 MWD+IFR-AK-CAZ-SC(4, 15,737.03 89.23 15.27 6,373.07 14.92 -5.00 25.04 5.92 14.90 5.03 8.05 29.52 24.59 122.05 MWD+IFR-AK-CAZ-SC(4, 16,827.75 89.23 15.27 6,387.74 15.75 -5.00 28.01 5.92 15.72 5.04 8.37 29.18 28.01 108.21 MWD+IFR-AK-CAZ-SC(4, 16,862.11 89.92 15.27 6,388.00 15.78 -5.04 28.14 5.92 15.76 5.04 8.38 29.18 28.14 103.85 MWD+1FR-AK-CAZSC(4, 16,866.27 90.00 15.27 6,388.00 15.78 -5.04 28.14 5.92 15.76 5.04 8.38 29.18 28.14 103.85 MWD+1FR-AK-CAZ-SC(4, 18,891.29 90.49 15.17 8,387.89 15.77 -5.07 28.22 5.93 15.78 5.04 8.39 29.19 28.22 102.01 MWD+1FR-AK-CAZSC(4, 17,460.19 90.49 15.17 6,383.03 18.28 -5.07 30.25 5.93 16.29 5.04 8.58 30.58 28,85 41.63 MWD+IFR-AK-CAZ-SC(4, 17,678.42 92.15 11.13 6,378.00 18.49 -5.15 30.63 6.17 18.50 5.03 8.64 31.17 28.75 39.94 MWD+IFR-AK-CAZ-SC(4, 18,477.45 92.15 11.12 6,348.00 17.31 -5.15 32.34 6.17 17.32 5.01 8.89 33.22 28.36 37.16 MWD+IFR-AK-CAZ-SC(4, Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ('•) (") 3,643.07 2,650.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 12,667.42 6,388.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 18,477.45 6,348.00 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) r) 11,212.00 5,998.00 HRZ(top) 12,614.33 6,383.00 A4 2/25/2015 4:30:40PM Page 3 COMPASS 5000.1 Build 65 42 • • y Schlumberger ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-02 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Plan:Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-02 North Reference: True Wellbore: Plan:2S-02 Survey Calculation Method: Minimum Curvature Design: 2S-02wp08[Thresher] Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 325.00 325.00 0.00 0.00 KOP:Start 1.5°/100'DLS, 144.25°TF,for 275.24' 600.24 600.00 -8.04 5.79 Start 2.5°/100'DLS,0°TF,for 907.6' 1,507.84 1,469.00 -203.28 146.34 Hold for 112.05' 1,619.89 1,569.00 -244.31 175.88 Start 3.5°/100'DLS,22.63°TF,for 1287.18' 2,907.07 2,402.87 -1,097.79 562.44 Hold for 4213.19' 7,120.26 3,817.53 -4,851.46 1,850.71 Start 2.5°/100'DLS,-123.06°TF,for 5547.16' 12,667.42 6,388.00 -4,412.57 5,255.79 Hold for 30' 12,697.42 6,390.61 -4,383.68 5,263.42 Start 3.5°/100'DLS,-5.52°TF,for 187.25' 12,884.67 6,396.29 -4,202.56 5,310.21 Hold for 1418.34' 14,303.01 6,358.58 -2,827.86 5,657.31 Start 2°/100'DLS, 174.59°TF,for 26.3' 14,329.31 6,358.00 -2,802.37 5,663.76 Adjust TF to 162.36°,for 145.7' 14,475.01 6,358.99 -2,661.44 5,700.63 Hold for 568.57' 15,043.58 6,376.62 -2,112.77 5,848.70 Start 2°/100'DLS,-3.97°TF,for 89.06' 15,132.65 6,378.00 -2,026.77 5,871.81 Adjust TF to-71.67°,for 112.1' 15,244.74 6,377.31 -1,917.97 5,898.77 Hold for 350.05' 15,595.06 6,373.00 -1,576.46 5,976.68 Start 2°/100'DLS,-18.81°TF,for 0.26' 15,737.03 6,373.07 -1,438.75 6,011.18 Adjust TF to 121.42°,for 141.98' 16,827.75 6,387.74 -386.65 6,298.47 Hold for 1090.72' 16,866.27 6,388.00 -349.49 6,308.61 Start 2°/100'DLS,-0.23°TF,for 38.52' 16,891.29 6,387.89 -325.35 6,315.18 Adjust TF to-11.79°,for 25.02' 17,460.19 6,383.03 223.71 6,464.02 Hold for 568.89' 17,678.42 6,378.00 436.11 6,513.65 Start 2°/100'DLS,-67.61°TF,for 218.23' 18,477.45 6,348.00 1,219.58 6,667.68 Hold for 799.03' Checked By: Approved By: Date: 2/25/2015 4:30:40PM Page 4 COMPASS 5000.1 Build 65 43 Pool Report Permit Pack • • oaa$aoso ' ' - E55,6-rcrc- O1 / % rc Q le s cs u o 3" _...._-._._ -------.__—.—.__.-____._ --__.—..____. ---- o W• 666o566060 N lr 0 qm d u 000ai'o �r"a°p°0 umin.�-llninomw E o a - CDO 1. a 't2 u r U U v mm N0-mmmmaam r aan agora t. w ,,, "ggggmyo cel hNYM.i.-., MOW OLLLL \ O N 2NNctiaNn \ '441 00 N(VN \ \ T \ kW finPk ., 9 OI i z Hall - RS O W ..— O .- (C) N L N w O L . 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CPA!Coordinate Converter -From: To: Datum: 1NAD83 _J Region: lalaska J Datum: 'NAD27 �' Region: lalaska 1rI C Latitude/Longitude 'Decimal Degrees ., C LatitudelLongitude [ ecimal Degrees .L...1 C UTM Zone: r--' E South C UTM Zone: (True— 1 South ' State Plane Zone: f4 'I Units: 'us-ft t: State Plane Zone: F.-7j, Units: us-ft C Legal Description(NAD27 only) C Legal Description(NAD27 only) _Starting Coordinates: —Ending Coordinates: X: 1621312.92 X: ( 481279.604033174 Y: 5929779.42 Y: ( 5930029.82899801 rTransform Quit I Help 2S-02wp08 Intermediate Casing a o J CPA[Coordinate Converter From: To: Datum: 'NAD83 j Region: lalaska j Datum: 'NAD27 L.11 Region: lalaska J C Latitude/Longitude 'Decimal Degrees r LatitudelLongitude 'Decimal Degrees �! C UTM Zone: ' r South C UTM Zone: (True E South C State Plane Zone: 4 Units: !us-ft �! ( State Plane Zone: 4 J Units: us-ft • C Legal Description(NAD27 only) C Legal Description(NAD27 only) f Starting Coordinates: -- r Ending Coordinates: X: (1626557 X: [486523.754183613 Y: 15925354 Y: (5925604.43163111 TransformQuit I Help i .._. 'a 50 I 0 2S-02wp08 TD , In CPAI Coordinate Converter -C3 k f , -,...., From: To: Datum: INAD83 . Region: lalaska ..zi Datum: 1NAD27 :i Region: lalaska ._i Latitude/Longitude [Decimal Degrees .2j, C Latitude/Longitude 1Decimal Degrees 2:I UT M Zone: r----- r' South r UTM Zone [frue n South 6State Plane Zone: ri---- 1 Units: lus.ft 2L 6. State Plane Zone: ri7. Units: C Legal Description(NAD27 only) C Legal Description(NAD27 only) [ ` ....._ Starting Coordinates: Ending Coordinates: X: 11627983 X: I 487949.863516069 I Y: 15930982 Y: 15931T32.28205138 Transform Quit I Help 51 • • 2S-02wp08 Surface Location C . CPA!Coordinate Converter s , From: _ ____-__._.__ _-____ To: Datum: 1NAD83 Region: lalaska . Datum: INAD27 Region: lalaska J C LatitudelLongitude 'Decimal Degrees —l a_ Latitude/Longitude Decirnal Degrees J C UTM Zone: I-- r South C UTM Zone: 'True r South 1 is State Plane Zone: 14 .J Units: us4t . ; r. State Plane Zone: 1-4 A Units: us-ft • I. r. Legal Ucscrfption(NAD 27 only) is Legal Description(NAD27 only) 4 k Starting Coordinates: Legal Description X: 11621312.92 Township: 1010 IN Range: loos 1-E ,, Y: 15929779.42 Meridian: lu j Section:117 FNL 13017.8945 FEL 11290.6491 Transform Quit I Help j '-4 [ - 2S-02wp08 Intermediate Casing In CPA!Coordinate Conve Ism , r From: _ ( To: Datum: INAD83 j JRegion: lalaska J 2 Datum: INAD27 _.J Region: lalaska .....:i 1 C Latitude/Longitude IDecimal Degrees A C Latitude/Longitude 'Decimal Degrees C UTM Zone: I (— South C UTM Zone: 'True r South I C State Plane Zone: l4 Units: lus.ft J C State Plane Zone: [4�___��� Units: lus-k C Legal Uescri tion ttI,ALii unyj ��` Le9al Description(NAD27 only) ) I --Starting Coordinates: - Legal Description X: 11626557 Thi010 IN .I Range: 1008 lE J Y: 15925354 Meridian: lU � Section: 21 IFNL -.1 2152.5680 ITEC-Dr 11328.1295 Transform Quit 1 Help I 52 II • 2S-02wp08 TD 1 . - Its I In CPAI Coordinate Converter From: __ To:- Datum: o:Datum: 'NAD83 J Region: 'alaska :::i 4 Datum: INAD27 Region: Ialaska j 1"-- Latitude/Longitude 'Decimal Degrees C Latitude/Longitude 'Decimal Degrees UTM Zone: -- r- South C UTM Zone: (True— I— South 4 State Plane Zone: 14 Units: (us-ft J C State Plane Zone: I Units: us-ft T. C c gal Descript:on(NAD27 cnly) 6 Legal Description(NAD27 only) -Starting Coordinates: Legal Description --- ----- -- ----- X: 11627983 Township: 010 IN ,' Range: 1008 1E I Y: 15930982 , Meridian: lu .) Section:115 IFNL .ri 11801.7254 IFEL 2:I 15179.1152 Transform Quit I Help , a 53 • • 2S-02 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.First well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 7 6-3/4"Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in 54 • • the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. 55 • • 2S-02 ConocoPhillips Grassroots Horizontal A-Sand Injector Proposed Wellbore Schematic (wp08) I\ f$ .il c CAMERON Last Edited: ` 4-%"tree,top joint is 4-1h"12.6#IBTM Callahan-4/14/15 fi 16"Conductor to-115' 4 13.5" Surface Hole x v. fir; Q 1 D I v''''.1 3-%"2.875"DS Landing Nipple r, n'` k 11 A: GL Surface Casing 10-3/4"45.5#L-80 Hydri1563 9-7/8" Intermediate Hole 3,643' MD/2,650'TVD GL 3-72"GLM 3-1/2" 9.3#L-80 EUE 8RD-MOD Tubing a a a d 2nd Stage TOC:8,595'MD/4,515'TVD cal , 1,1 (500'MD above C37) a "4' t U) u Ed tt 53 0 ,i ® ill Weatherford Stage Collar:9,100'MD/ 4,813'TVD(Top of C-37 formation) Growler(Iceberg):9,270'MD/4,918'ND Ise Stage TOC:10,184'MD/5,471'TVD - (Top of Bermuda/Cairn formation) s c., � ''''''''4,-,—„ '';''r ;R 7-5/8"Flex Lock Liner Hanger 6-3/4" Production Hole Kuparuk C/Kuparuk A:12,457'MD/6,364'TVD Baker 2.812"CMU Sliding Sleeve '`.�,�. � a'i"�'3�' / ®. ■ ■ 4=A'Orange Peel CD ® snoe aa. 3-1,2.75"D Nip;3';'' ''' e '+tl+ .;-, oma . u. ri 2 ci 3-''/a"HES Mirage Disappearing Plug TD:18,477'MD/6,348'TVD Intermediate Casing 7-5/8"29.7#L-80 Hyd563 Casing 6.38"x4-'/:"Swell Packer 12,667' MD/6,388'TVD (85°) NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data 56 • • 2S-02 Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 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 3143' MD. Client: CPAI Revision Date:April 7,2015 Prepared by:Jenna Houston Location:Anchorage, AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -260 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11 ppg- 1.91 ft3/sk email:jhouston2@slb.com 1.339 ft3/ft x(110')x 1.00 (no excess) = 148 ft3 < TOC at Surface 0.3637 ft3/ft x(1390-110') x 3.50 (250% excess) =ii 1630 ft3 0.3637 ft3/ft x(3143-1390)x 1.50 (50% excess)= 957 ft3 148 ft3+ 1630 ft3+957 ft3= 2735 ft3 2735 ft3/1.91 ft3/sk= 1432 sks(-1442 sks) Please have extra DeepCRETE on location for top out. Previous Csg. Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.), 106.5#casing DeepCRETE @ 12 ppg - 1.63 ft3/sk � < 20" at 110'MD 0.3637 ft3/ft x(3643-3143) x 1.50 (50% excess)= 273 ft3 0.5400 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 =76°F, Estimated BHCT=76°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at 1390'MD(-1,363'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 7.0 100.0 14.3 14.3 Pause 0.0 0.0 5.0 19.3 < Top of Tail at 11 ppg DeepCRETE 7.0 486.8 69.5 88.8 3,143'MD Surface Tail 7.0 56.3 8.0 DeepCRETE Slurry 96'8 Pause 0.0 0.0 5.0 101.8 Fresh Water 7.0 10.0 1.4 103.2 Pause 0.0 0.0 5.0 108.2 Mud 8.0 322.7 40.3 148.5 Mud 3.0 10.0 3.3 151.8 < 10-3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties: 9.5 ppg, Pv<20, Ty<20 TD at 3,643'MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, Ty 20-25 (2,650'TVD) Centralizers: As per CPAi program. *Mark of Schlumberger 57 • • 2S-02 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 1st Stage (V2) Location: Kuparuk Client: CPAI Revision Date:April 14, 2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40% excess. The topof the 1st stage tail slurryis designed to be Location:Anchorage, AKg g Phone: (907)263-4207 at-10,184 MD. Mobile: (907)223-8916 email:jhouston2@slb.com Lead Slurry Minimum pump time: -290 min. (pump time plus 120 min.) 15.8 ppg Class G + GASBLOK*adds- 1.17 ft3/sk 0.2148 ft3/ft x(11950'-10184') x 1.40 (40% excess) = 532 ft3 532 ft3+ft3 = 532 ft3 532 ft3/1.17 ft3/sk= 455 sks Round up to 465 sks Previous csg. Tail Slurry Minimum pump time: -270 min. (pump time plus 120 min.) < 10-3/4",45.5.#casing 15.8 ppg Class G +adds- 1.16 ft3/sk at 3,643'MD 0.2148 ft3/ft x(12667'-11950') x 1.40 (40% excess) = 216 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3 216 ft3+21 ft3 = 237 ft3 237 ft3/ 1.16 ft3/sk= 205 sks Round up to 215 sks BHST= 154°F, Estimated BHCT= 119°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) < Stage tool at 9100'MD PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.0 30.0 6.0 6.0 Pause 0.0 0.0 5.0 11.0 < Top of Cement at GASBLOK*Slurry 5.0 94.6 18.9 29.9 Tail Slurry 5.0 42.1 8.4 38.3 10,184 MD Pause 0.0 0.0 5.0 43.3 Fresh Water 5.0 10.0 2.0 45.3 Pause 0.0 0.0 5.0 50.3 Mud 5.0 500.0 100.0 150.3 < 7-5/8",29.7#casing Mud 4.0 34.0 8.5 158.8 in 9-7/8"OH Mud 2.0 34.0 17.0 175.8 TD at-12,667 MD MUD REMOVAL (6,388'TVD) Expected Mud Properties:-11.2 ppg, Pv<20, Yield Point<25. Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-24, Yield Point=20-30 Centralizers: As per program Mark of Schlumberger 58 0 0 2S-02 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 2nd Stage (V2) Location: Kuparuk Client: CPAI Revision Date: April 14, 2015 Volume Calculations and Cement Systems Prepared by: Jenna Houston Volumes are based on 40% excess. The top of the 2nd stage tail slurry is designed to be Location:Anchorage, AK Phone: (907)263-4207 at-8,595 MD, 500' above the C37. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -230 min. (pump time plus 120 min.) 15.8 ppg Class G +GASBLOK*+ adds- 1.17 ft3/sk 0.2148 ft3/ft x(9100'-8595')x 1.40 (40% excess) = 152 ft3 152 ft3= 152 ft3 152 ft3/1.17 ft3/sk = 130 sks Previous Csg. Round up to 185 sks < 10-3/4",45.5.#casing at 3,643'MD BHST= 118°F, Estimated BHCT= 87°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH ii 5.0 30.0 6.0 6.0 Pause 0.0 0.0 5.0 11.0 GASBLOK*Slurry 5.0 27.0 5.4 16.4 Pause 0.0 0.0 5.0 21.4 Fresh Water 5.0 10.0 2.0 23.4 Pause 0.0 0.0 5.0 28.4 Mud 5.0 377.8 75.6 104.0 Mud 3.0 15.0 5.0 109.0 Mud 2.0 15.0 7.5 116.5 < Top of Cement at 8,595 MD MUD REMOVAL Expected Mud Properties:-11.2 ppg, Pv<20, Yield Point<25. Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-24, Yield Point=20-30 < 7-5/8",29.7#casing in 9-7/8"OH Centralizers: As per program Stage tool at-9,100' MD (4,813'TVD) * Mark of Schlumberger 59 • • Bettis, Patricia K (DOA) From: Callahan, Mike S [Mike.Callahan@conocophillips.com] Sent: Thursday, April 23, 2015 10:52 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2S-02: Permit to Drill Application (215-070) Patricia, here are the predicted formation tops for the well, with the ones you requested in bold. Please let me know if you need anything else. Formation MD TVD Base Permafrost 1390 1362 Top W Sak 2173 2013 Base W Sak 3398 2576 C-80 4825 3048 / C-50 7855 4123 C-40 8552 4492 C-37 9095 4751 Growler(Iceberg) 9270 4918 Cairn 10184 5471 Bermuda 10245 5505 Base Bermuda 10427 5608 HRZ (K-2 Marker) 11415 6081 Upper Kalubik 11724 6191 Lower Kalubik (K-1 Marker) 12012 6275 Kuparuk C (C4) 12457 6364 A5 12513 6372 A4 12700 6392 Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 22, 2015 4:38 PM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2S-02: Permit to Drill Application (215-070) Good afternoon Mike, Please provide a list of the expected formation tops and geologic markers, measured depth and TVD, anticipated to be penetrated by the well. For geologic markers, I am looking for Base Permafrost, C-37, C-40, C-80, C-50. Others would be appreciated. 1 • • 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. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, April 22, 2015 4:38 PM To: 'Callahan, Mike S' Subject: KRU 2S-02: Permit to Drill Application (215-070) Good afternoon Mike, Please provide a list of the expected formation tops and geologic markers, measured depth and ND, anticipated to be penetrated by the well. For geologic markers, I am looking for Base Permafrost, C-37, C-40, C-80, C-50. Others would be appreciated. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • 4110 TRANSMITTAL LETTER CHECKLIST WELL NAME: K A(, c2S -c)2. PTD: A/S" 0• '0 Development /Service Exploratory _Stratigraphic Test Non-Conventional FIELD: h f,,,i1� ► Ar POOL: � ' ,\JL5.- 14u 7c)J C; ) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: d Well Logging Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. OW / t..41 ,-,ht. u w,`r sE 6- - -1 _ si 5Iw1E_c F N *.*A 7l.2, G(0? bk.L1-- M6_6..su.r.4-, cilr, Revised 2/2015 O o 00 m 0) Q a) m a) D o � asTo E coa N. , , , a aCN '05 ) O Z� C' w C' �' a), N - a) 0 `o. o, ° T ILI a CIS N m 2 O m °a 76 • p -: a (tea oiCO , 00m a 0, rn 3 °i: N: a Z, o' T..) , o = 76. . , a m. •� o -0 m. •(a D 2 o, .c cci E' oY, W. c Y o N d a)� C � ? ` of .N � co N 3 0' a a a a m W' as' o° . c ` ° L. ami o O moo' u Y' a as, C I- c O, C CD a- 03 �' a E. 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E = 0 •C 0 a) 0 z C, .- c, 0 o a) m' .., 0 , o c), a), o o, 0 v m ui 3. co' _ ti. •0 ° co.O. c • a 0, °� °� °: > %, m, E: .E a ° 0. a .0: m' F H �' C 0 a g. a) c a' a o - n c E E m c m ,__ U E as' v m' 0 0' v a a as .....°. 3. as' o a, 2 M M' 'a' -0 co •0 -0 = O, O; r, ° 0 a`) m m, a), o, ( i • • Well History File APPENDIX Infot illation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infom illation. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: July 17, 2015 Surface Data Logging End of Well Report 2S-02 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 141 Well: 2S-02 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20710-00-00 Sperry Job Number: AK -XX-0902499586 Job Start Date: 12 June 2015 Spud Date: 14 June 2015 Total Depth: 18410’ MD, 6329’ TVD North Reference: True Declination: 18.7142° Dip Angle: 80.87° Total Field Strength: 57491 nT Date Of Magnetic Data: 11 July 2015 Wellhead Coordinates N: North 70° 13’ 10.875” Wellhead Coordinates W : West 150° 9’ 14.84“ Drill Floor Elevation 147.5’ Ground Elevation: 120.0’ Permanent Datum: Mean Sea Level SDL Engineers: Jacob Hansen, Justin Kyle Wiseman, Hilary Garney SDL Sample Catchers: Chris Medeiros, Geoff Yenter Company Geologist: Phill B Company Representatives: Don Mickey, Bob Finkbiner , Robert Wall, Andy Lundale SSDS Unit Number: 125 DAILY SUMMARY 06/13/2015 Begin rigging up mud logging unit. Rigged up, calibrated and tested gas equipment. 06/14/2013 Set up WITS to Totco RigSense. Made up bottom hole assembly and began to run into the hole to tag up at 93’. Continued to make up the bottom hole assembly while drilling ahead to 177’ MD. Spudded well to 635’ MD and continued to drill ahead. Gas: Max g as was 6 units. Fluids: No losses/gains for 24 hour period. Geology: The samples have been predominantly light grey, soft, amorphous clay with inter- bedded sand grains. An interval of c onglomerate was observed followed by light grey to white, transparent to opaque, unconsolidated medium to coarse grains. 06/15/2013 Continued to drill ahead from 635’ MD to 2704’ MD. Gas: Max gas was 1174 units at 1869’ MD. Fluids: One barrel gain for 24 hour period. Geology: The samples have been predominantly light grey, soft, poorly compacted, amorphous clay inter -bedded with black to clear, transparent to opaque, fine to coarse grained, sub elongated to sub rounded, poorly sorted, unconsolidated sand. 6/16/2015 Continued drilling ahead from 2704’ MD to s urface TD at 3654’ MD. Circulated bottoms up then proceeded to trip out of the hole. Gas: Max gas was 1292 units at 3196’ MD. Fluids: 66 Barrel loss for 24 hour period. Geology: The s amples have been predominantly light grey, soft, poorly compacted, amorphous , inter-bedded clay with black to clear, transparent to opaque, very fine to coarse grained, sub elongated to sub rounded, poorly sorted, unconsolidated sand. 6/17/2015 Laid down bottom hole assembly then rigged up equipment to run casing to 1628’ MD. Gas: Max gas was 109 units while running into the hole. Fluids: No loss /gain in the 24 hour period. 6/18/2015 Continued to run into the hole with 10.75" casing to 1550' MD where slack off w eight was lost. Circulated bottoms up at 1575' MD where the hole unloaded. Continued pumping in hole from 1575' MD to 1735' MD until hole was cleaned. Then continued to run into the hole from 1735' MD to 3613' MD and landed casing at 3644' MD. Circulated and conditioned mud for cement job. Rigged up c ement lines and proceeded to pump cement from which the plug was bumped with rig pumps at 7 barrels per minute. Monitored well, this was static. Flushed stack and flow - line then began to rig down cementers. Diverter began to be nippled down. Gas: Max gas was 302 units. Fluids: 36 barrel gain while running into the hole with casing. 6/19/2015 Continued to nipple down diverter and began to nipple up BOPE’s. The rig crew performed rig maintenance on rig pumps and top drive. SDL crew calibrated and tested gas equipment. Gas: No gas was observed. Fluids: No loss es /gains in the 24 hour period. 6/20/2015 Continued to nipple up kill lines and choke lines then rigged up to test BOPE’s. While attempting to test the c hoke line was observed leaking. Once fixed, testing continued. Rigged down testing equipment then began to make up bottom hole as sembly as per SLB rep to 736' MD. Gas: No gas was observed. Fluids: No loss es /gains in the 24 hour period. 6/21/2015 Ran into the hole from 736' MD to 1666' MD and perform shallow pulse test. Continued to run into the hole to 3535' MD then c irculated mud to perform casing pressure test. Displaced well to 9.6 pounds per gallon LSND then pumped 24 barrel spacer, chased with 110 barrels and observed a pressure spike where the decision made to trip out of the hole. Gas: Max gas was 61 units while tripping into the hole. Fluids: 12.2 barrels gained over 24 hour period. 6/22/2015 Laid down bottom hole assembly and c hange out MWD tool. Ran into the hole to 1573' MD to perform shallow pulse test on MWD tools then continued to 3650' MD. Washed and ream ed from 3650' MD to 3674' MD then circulated bottoms up. Perform formation integrity test with an equivalent mud weight of 16.0 pounds per gallon. The well was then displaced from 9.6 pounds per gallon spud mud to 9.6 pounds per gallon LSND. Then began to drill ahead. Gas: Max gas was 571 units while tripping into the hole. Fluids: 12.5 barrels gained over 24 hour period. Geology: The samples have been predominantly light grey to black, opaque to transparent, soft to firm, fine to very fine grained, sub angular to sub rounded, poorly sorted, moderately to unconsolidated sand with occasional laminations and silty. 6/23/2015 Drilled ahead from 5027' MD to 7268' MD. Gas: Max gas was 163 units at 5403’ MD. Fluids: 0.5 barrels gained in 24 hour period. Geology: The samples have been predominantly light grey to black, opaque to transparent, soft to firm, medium to very fine grained, sub angular to sub rounded, poorly- moderately sorted, moderately to unconsolidated grained sand with occasional laminations and silty. 6/24/2015 Drilled ahead from 7268' MD to 7960’ MD where mud pump #2 had to be fixed and c irculated. Drilled from 7960’ MD to 8362’ MD then proceeded to back r eam. Monitored the well, static then continued to run into the hole from 8107’ MD to 8362’ MD. Observed pack off issues and began to circulate bottoms up and began to observe losses at 60 barrels per hour . Gas: Max gas was 269 units at 8360’ MD. Fluids: 157 barrels lost over 24 hour period with 156 barrels lost between 20:00 and 24:00. Geology: The samples have been predominantly light to dark grey, soft to firm, blocky, well sorted, predominantly unconsolidated, slightly argillaceous and calcareous siltstone. 6/25/2015 Dec ision made to pump LCM pill. Drilled ahead from 8757’ MD to 8847’ MD then m onitored well where it was determined that the well was breathing. Hook up MPD returns line and line up to circ ulate. Drilled from 8847’ MD to 9190’ MD and observed a pack off while drilling. Picked up off bottom and slowed pump rates to establish a loss rate. Ream in hole to 9190’ MD and continued to drill from 9190’ MD to 9644’ MD. Gas: Max gas 1362 units at 8848’ MD. Fluids: 382.9 BBLs loss in 24 hour period. Geology: The samples have been alternating between white, transparent to translucent, unconsolidated, fine to medium grained, sub angular to sub rounded, very well sorted sand and light to dark grey, firm, blocky, moderately sorted, predominantly unconsolidated, slightly argillaceous siltstone. 6/26/2015 Drilling ahead from 9644’ MD to 11367’ MD. Gas: Max gas was 687 units at 10481’ MD. Fluids: 161 barrels lost in 24 hour period. Geology: The samples have been alternating between light to dark grey, soft to friable, blocky to fissile, moderately sorted, slightly argillaceous siltstone with occasional laminations and light to dark grey, moderately soft to firm, blocky, flakey, splintery shale with inter-bedded siltstone, possibly inner bedded clay, trace organics and pyrite. 6/27/2015 Drilled ahead from 11367' MD to 11985' MD, 6276' TV, circulated bottoms up and pumped a sweep. Monitored Well where it was determined that the well was breathing. While tripping out of the hole, a tight spot was encountered at 9727' MD. Ream ed through tight spot from 9781' to 9700' MD then proceeded to back ream out of the hole Gas: Max gas was 1046 units at 11840’ MD. Fluids: 411 barrels lost in 24 hour period. Geology: The s amples have been predominantly light to dark grey, soft to friable, blocky to fissile, moderately sorted, slightly argillaceous siltstone with occasional laminations. 6/28/2015 Back reamed out of the hole from 9506' MD to 8107' MD. ECD 's were observed to be climbing with mud coming back at 10.6 pounds per gallon. Circ ulated hole clean till mud weight was 10.4 pounds per gallon. Began to pull out of the hole on elevators from 8107' MD to 5032' MD while working pipe through tight spots. Pumped out 3 stands from 5032' MD to 4750' MD and ECD's began to climb again with mud coming back 10.6 pounds per gallon. Circ ulated hole till mud weight was 10.4 pounds per gallon. Continued to pull out of the hole for 4750' MD to 3627' MD, circulated bottoms up and m onitored the w ell. Perform ed breathing test per Co-Man then lined up on trip tank to continue to pull out of the hole on elevators from 3615' MD to 3250' MD. Hole swabbing was observed so pumped out at 2 barrels per minute from 2973' MD to 2640'MD. Gas: Max gas was 253 units while pulling out of the hole. Fluids: 173 barrels lost in 24 hour period. 6/29/2015 Pumped out of the hole from 2640' MD to 828' MD, m onitored well: slight flow, slowing down to a dribble, then continued to pull out of the hole from 828' to 735' MD and lay down bottom hole assembly. Remove 2.875" X5" top rams and installed 7.625” rams and performed test on rams. Pick up hanger and made up landing joint. Preform ed dummy run per Cameron rep then began to run 7-5/8” casing to 3612' MD. Circulated bottoms up at 3612' MD then c ontinued torun into the hole to 4465' MD. Gas: Max gas was 37 units while running casing. Fluids: 6 barrels lost in 24 hour period. 6/30/2015 Ran into the hole with 7.625" casing from 4465' MD to 5138' MD and observed a 15,000 pound slack off. Decision was made to circulate, getting slight returns back to the pits. Broke c irc ulation at 1 barrel per minute with slight returns then the slack off string broke free and 7 barrels were pumped away during circulation. From 5761' to 8073' MD no returns were observed. Ran into the hole from 8073' MD to 11805' MD and encountered a tight spot at 11805’ MD and washed down to 11837' MD. Gas: Max gas was 163 units while running casing. Fluids: 363 barrels lost in 24 hour period. 7/01/2015 Worked pipe from 11982' MD to 11945' MD where a tight spot was encountered, could not move the pipe up or down, could not pump but was able to work pipe free and establish circ ulation with m inimal returns. Prepped for cement job by rigging up cement equipment and circulating mud then perform ed both stages of cement job per SLB reps. Rigged down and back flushed cement lines. Laid down casing tools & picked up packer where it was set and tested. Flushed and freeze protected annulus. Slip and cut the drill line. Gas: Max gas was 150 units during cement job. Fluids: 1408 barrels lost in 24 hour period. 7/02/2015 Slip and cut drill line. Laid down 5” drill pipe from derrick and prepped pipe shed to begin to pick up 4” drill pipe for production section. Gas: No gas was observed. Fluids: 0 barrels lost in 24 hour period. 7/03/2015 Continued to pick up 4” drill pipe for production hole section. Cleared and cleaned the rig floor then began to rig up and test BOP’s per AOGCC. Gas: No gas was observed. Fluids: 0 barrels lost in 24 hour period. 7/04/2015 Finished testing BOP’s per AOGCC then rigged down testing equipment and prepped rig to pick up bottom hole assembly #4 per SLB. Picked up bottom hole assembly and began to run into the hole to 7720’ MD then started to MADD Pass. Once at 7720’ MD, the depth of the cement stinger, one bottoms up was circulated and then the casing pressure test to 3000 pounds per square inch was performed. Then the cement stinger was drilled out and the MADD Pass continued. Gas: No gas was observed. Fluids: 0 barrels lost in 24 hour period. 7/05/2015 Continued with the MADD Pass down to 11892’ MD and it was determined that the cement quality was good. Began to circulate bottoms up to achieve equal mud weights in and out prior to performing the casing pressure test to 3500 pounds per square inch for 30 minutes then the drill line was slipped and cut and then the drill out of the cement began. Gas: No gas was observed. Fluids: 0 barrels lost in 24 hour period. 7/06/2015 Continued drilling out cement and 20’ of new formation, pulled back into the shoe and performed a formation integrity test to 16 pounds per gallon equivalent. Displaced mud sys tem per Mud Engineer to 10.5 pounds per gallon Flo-Thru then proceeded to monitor the well, which began to flow and was out of balance. Circ ulated and c onditioned the mud to achieve an even mud weight while clearing the bottom hole assembly of any debris . Proceeded to drill ahead in the production section. Gas: Max Gas was 187 U at 12179’ MD Fluids: 0 barrels lost in 24 hour period. Geology: Samples have been primarily dark gray to black, soft to firm blocky, well sorted shale with some unconsolidated sand with no oil shows. 7/07/2015 Continued drilling ahead in the production section, performed a pore pressure test, circulated a bottoms up and continued ahead. MPD troubleshooting took place and once those issues were fixed, drilling continued. Gas: Max Gas was 7073 U at 13033’ MD Fluids: 0 barrels lost in 24 hour period. Geology: Samples have been primar ily dark gray to black, dark to light brown, translucent to transparent, fine to very fine grained, sub-angular to sub-rounded, sub-elongated to sub- spherical, well sorted sandstone with unconsolidated grains mixed in with occasional siltstone fragments. Oil shows have been: strong odor, light brown stain, patchy to even orange-yellow fluorescence, streaming bright white-yellow cut fluorescence, bright white residual cut fluorescence. 7/08/2015 Continued drilling ahead in the production section. Gas: Max Gas was 9880 U at 14810’ MD Fluids: 0 barrels lost in 24 hour period. Geology: Samples have been primarily dark gray to black, dark to light brown, translucent to transparent, fine to very fine grained, sub-angular to sub-rounded, sub-elongated to sub- spherical, well sorted sandstone with unconsolidated grains mixed in with occasional siltstone fragments. Oil shows have been: strong odor, light brown stain, patchy to even orange-yellow fluorescence, streaming bright white-yellow cut fluorescence, bright w hite residual cut fluorescence. 7/09/2015 Continue to drill ahead in the production section. Gas: Max Gas was 9238 U at 11585’ MD Fluids: 36 barrels lost in 24 hour period. Geology: Samples have been primarily light to dark gray, dark to light brown, translucent to transparent, fine to very fine grained, sub-angular to sub-rounded, sub-elongated to sub- spherical, well sorted sandstone with unconsolidated grains mixed in with occasional siltstone fragments. Oil shows have been: strong odor, light brown s tain, patchy to even orange-yellow fluorescence, streaming bright white-yellow cut fluorescence, bright white residual cut fluorescence. 7/10/2015 Continued to drill ahead to 17266’ MD where MWD/DD troubleshoot the PowerDrive, then circulated bottoms up to try and get the tool to work, then continued to drill in the production section. Gas: Max Gas was 9104 U at 17284’ MD Fluids: 0 barrels lost in 24 hour period. Geology: Samples have been primarily light to dark gray, dark to light brown, translucent to transparent, fine to very fine grained, sub-angular to sub-rounded, sub-elongated to sub- spherical, moderately well sorted sandstone with unconsolidated grains, trace pyrite, mixed in with occasional siltstone fragments. Oil shows have been: moderate odor, no stain, patchy to even orange fluorescence, streaming bright white-yellow cut fluorescence, bright white residual cut fluorescence. 7/11/2015 Continued to drill ahead to 18275’ MD and circulated bottoms up before changing out the MPD bearing then continued to drill ahead to a TD of 18410’ MD. Circulated bottoms up until the shakers came back clean and no gas was present, then began to back ream out of the hole. Gas: Max Gas was 7894 U at 18061’ MD Fluids: 0 barrels lost in 24 hour period. Geology: Samples have been primarily light to dark gray, dark to light brown, translucent to transparent, fine to very fine grained, sub-angular to sub-rounded, sub-elongated to sub- spherical, moderately well sorted sandstone with unconsolidated grains, trace pyrite, mixed in with occasional siltstone. Oil shows have been: moderate odor, no stain, patchy to even orange fluorescence, streaming bright white-yellow cut fluorescence, bright white residual cut fluorescence. 7/12/2015 Continued to back ream out of the hole to 12100' MD when the hole packed off, lost circulation and rotation so the decision was made to run back into the hole to 12125' MD to try and get circulation back. Worked pipe and got circulation back. Continue to back ream out of the hole. Gas: Max Gas was 1594 U while circulating bottoms up. Fluids: 250 barrels lost in 24 hour period. 7/13/2015 Continued to back ream out of the hole to 12018’ MD when the hole packed off, so the pipe was worked until was freed and then continued to back ream out of the hole to 11979’ MD where 2 bottoms up were circulated. Ran back into the hole to 12736’ MD where a hi-vis pill was spotted per mud engineer. Gas: Max Gas was 1588 U while circulating bottoms up. Fluids: 197 barrels lost in 24 hour period. 7/14/2015 Continued to back ream out of the hole and laid down viscous pill from 12727’ MD to the shoe. Began to pump out of the hole where a 30 barrel of kill weight brine was pumped followed by a displacement spacer from which the well was displaced to 11.6 pounds per gallon sodium bromide brine. The well was observed to be breathing during a flow check, but after the BOP stack was drained, the well was monitored again and was static. Rigged down the RCD head and installed the trip nipple, slip and cut the drill line and began to pump out of the hole. Gas: Max Gas was 57 U while circulating bottoms up. Fluids: 0 barrels lost in 24 hour period. 7/15/2015 Continued to pump out of the hole from 4034’ MD to 440’ MD where the well was monitored for flow, static. Began laying down the bottom hole assembly and pulled the wear bushing. Rigged up and pressure tested the annular per AOGCC. Rigged up and began to run slotted liner to 6501’ MD then the Baker seal bore assembly was made up then changed out the elevators and began to pick up 4 inch drill pipe. Gas: Max Gas was 10 U while circulating bottoms up. Fluids: 19 barrels lost in 24 hour period. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 0 5 10 15 20 25 30 35 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-02 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-0902499568 Days vs. Depth 13 June 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 14-Jun-2015 TD: 11-Jul-2015 Commenced 13.5" Surface Hole Section On Bot: 13:58 14 June 2015 TD Surface Hole Section 3654' MD, 2656' TVD Off Bot: 11:57 16 June 2015 Landed 10.75" Casing 3644' MD, 2653' TVD 18 June 2015 Commenced 9.875" Intermediate Hole Section On Bot: 17:33 21 June 2015 Drill 9.875" Hole to 3674' MD POOH due to Pack Off 21 June 2015 TD Intermediate Hole Section 11985' MD, 6433' TVD Off Bot: 12:07 27 June 2015 Landed 7.625" Casing 11982' MD, 6275' TVD 30 June 2015 Commenced 6.75" Production Hole Section On Bot: 03:45 06 July 2015 TD Production Hole Section 18410' MD, 6329' TVD Off Bot: 13:30 11 July 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We got called out last minute so it was a race to get everything we needed out here and systems all working correctly before we spudded the well. We had issues with Totco when we got started that made it difficult to start logging the well. During the rig up we had issues getting internet and communications out here so it made it even harder to rig up on time but we made it. Recommendations: Things might go smoother in the future if we get a call out a little earlier. It allows us to get internet and communications set up and makes the rig up a lot easier especially if it’s a new job on a new pad. Innovations and/or cost savings: N/A Doyon 141 Jacob Hansen Surface 16-Jun-2015 What went as, or better than, planned: We logged the section with out a hitch. We had a rough start but we worked out all the kinks so the future wells should go a lot smoother 2S-02 Kuparuk River unit ConocoPhillips North Slope Borough 902499586 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We had some issues working along side of pit watchers, but they came around and eventually worked with us. Recommendations: Explain to the pit watcher the importance of tracking volumes and calling out transfers so we know what is happening on the rig. Communication is key. Innovations and/or cost savings: N/A Doyon 141 Jacob Hansen Intermediate 30-Jun-2015 What went as, or better than, planned: Everything ran well and we were able to log a good hole. We monitored losses closely and the mud engineers and pit watchers helped out. Everyone worked as a team. 2S-02 Kuparuk River unit ConocoPhillips North Slope Borough 902499586 Alaska Surface Data Logging After Action Review Surface Data Logging 2S-02 ConocoPhillips Alaska, Inc. MI Swaco Doyon 141 AK-XX-0902499586 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 13-Jun 0 8.70 69 21 26 11/20/23 NC 68/47/38/28/10/10 NC 1.0 /99 -0.08 9.4 20.0 .07/.60 420 680 Rigging Up SDL Unit 14-Jun 641 9.20 355 32 56 31/50/63 NC 120/88/74/55/29/26 NC 1.0 /99 -0.06 9.7 25.0 .25/.85 490 240 Spud 15-Jun 2686 9.60 258 60 80 33/53/64 6.0 200/140/115/84/34/30 2 6.0 0.0 0.05 0.55 9.8 27.5 .22/.75 350 252 Drilling Ahead in Surface Section 16-Jun 3654 9.80 223 38 50 20/54/77 6.2 126/88/72/51/20/17 2 9.0 0.0 0.25 0.41 9.5 35.0 .26/.65 420 300 TD Surface Section 17-Jun 3654 9.70 260 32 62 35/48/59 6.0 126/94/80/64/36/32 2 8.8 0.0 TR 0.34 9.2 30.0 .17/.53 400 220 Running 10.75" Surface Casing 18-Jun 3654 9.80 52 25 17 3/4/7 6.4 67/42/32/19/4/3 2 9.0 /91 TR 0.44 9.6 27.5 .19/.57 380 142 Cement Surface Casing 19-Jun 3654 9.80 45 17 12 3/4/8 6.5 46/29/21/14/4/3 2 9.0 /91 TR 0.38 9.2 27.5 .19/.57 380 120 BOP Test 20-Jun 3654 9.60 47 16 17 4/5/9 6.5 49/33/23/15/5/4 2 9.0 /91 TR 0.39 9.1 27.5 .19/.57 420 120 Finish BOP Test, M/U BHA #2 21-Jun 3674 9.70 50 19 19 6/20/31 6.6 57/38/29/18/5/4 2 9.0 /91 TR 0.47 9.3 27.5 .19/.85 380 180 Packed Off 22-Jun 5029 9.60 52 12 30 12/18/23 5.8 54/42/36/28/12/11 2 6.5 *2/91 TR 0.62 9.9 4.0 .45/2.00 8000 120 Drilling Ahead in Intermediate Section 23-Jun 7243 9.60 45 12 23 11/34/43 5.5 47/35/30/23/10/9 2 7.0 *3/91 TR 0.59 9.8 15.0 .38/1.38 5600 120 Drilling Ahead in Intermediate Section 24-Jun 8755 9.90 53 14 28 11/23/32 4.2 56/42/35/27/12/10 2 8.8 *3/89 TR 0.55 9.8 22.5 .28/1.30 2400 110 Drilling Ahead in Intermediate Section 25-Jun 9630 10.00 50 15 25 10/14/17 4.2 55/40/33/25/11/10 2 10.3 *3/87 TR 0.45 9.4 26.3 .15/1.15 1500 70 Drilling Ahead in Intermediate Section 26-Jun 11365 10.30 49 14 24 10/15/20 4.3 52/38/32/25/11/10 2 11.0 *3/86 TR 0.65 9.6 13.8 .25/1.30 800 60 Drilling Ahead in Intermediate Section 27-Jun 11985 10.40 47 13 23 9/13/19 3.4 49/36/30/22/10/9 1/2*11.0 *3/86 TR 0.60 9.9 18.5 .20/1.25 700 60 TD Intermediate Section 28-Jun 11985 10.40 48 14 27 10/16/22 3.4 55/41/34/25/11/10 1 11.0 3/86*TR 0.60 9.9 18.8 .20/1.30 600 60 TOOH 29-Jun 11985 10.40 47 14 27 10/16/22 3.4 55/41/34/25/11/10 1 11.0 3/86*TR 0.60 9.9 18.8 .20/1.30 600 60 TOOH 30-Jun 11985 10.40 49 14 19 9/11/12 3.4 47/33/28/22/10/9 1/2*11.0 3/86*TR 0.60 9.7 18.8 .20/1.20 600 80 Running 7.625" Intermediate Casing 1-Jul 11985 10.50 50 13 24 8/10/11 5.1 50/37/31/23/9/7 1 9.0 2/90*TR 1.10 9.9 3.0 .80/3.10 2300 160 Cement Intermediate Casing 2-Jul 11985 10.50 51 13 23 9/10/11 5.1 49/36/30/22/9/8 1 9.0 2/90 -1.10 9.9 9.9 0.80/3.10 2200 160 P/U 4" DP 3-Jul 11985 10.50 51 13 25 9/10/11 5.1 51/38/32/23/9/6 1 9.0 2/90 -1.10 9.9 3.0 0.80/3.10 2300 160 BOP Test 4-Jul 11985 10.50 49 11 23 7/10/11 4.6 45/34/28/21/8/7 1 10.0 2/89 -2.00 10.7 3.0 1.10/4.50 2300 340 MADD Pass 5-Jul 11985 10.40 48 11 25 9/11/12 4.5 47/36/30/22/9/8 1 10.0 2/88 -1.10 10.2 3.0 0.70/3.30 2000 400 Drill Out Cmt 6-Jul 12263 10.50 54 17 21 6/6/6 2.7 55/38/31/22/7/6 1/2 14.8 2/83 0.25 6.90 9.8 1.3 5.10/9.60 145000 10 Drilling Ahead 7-Jul 13079 10.80 56 20 22 5/6/6 2.0 62/42/33/22/6/5 1/2 16.5 3/81 Tr 4.90 9.8 2.5 4.50/5.20 138000 20 Drilling Ahead 8-Jul 14733 10.70 59 21 23 5/6/7 1.9 65/44/35/24/6/5 1/1 17.0 3/80 Tr 3.60 9.7 2.0 2.60/9.40 126000 20 Drilling Ahead 9-Jul 16383 10.80 64 23 27 6/10/14 2.4 73/50/41/28/7/5 1/1 16.8 3/80 Tr 3.40 9.2 2.5 3.10/10.40 146000 40 Drilling Ahead 10-Jul 17638 10.70 60 22 24 6/9/14 2.4 68/46/37/24/6/5 1/1 17.0 3/80 Tr 5.20 9.8 4.10/13.40 148000 20 Drilling Ahead 11-Jul 18410 10.80 94 27 34 9/17/21 2.3 88/61/50/34/10/7 1/1 16.8 3/80 Tr 6.50 9.7 3.0 6.30/16.00 152000 40 BROOH 12-Jul 18410 10.80 88 26 31 10/16/21 1.8 83/57/46/32/9/8 1/NA 14.5 3/83 Tr 4.90 9.6 2.5 4.40/13.20 152000 40 BROOH 13-Jul 18410 10.70 79 23 34 11/16/20 2.4 80/57/46/32/11/9 1/NA 16.0 2/82 Tr 4.20 9.6 2.0 3.20/9.70 1100000 40 Spot Pill 14-Jul 18410 11.70 --------------179000 -POOH 15-Jul 18410 11.60 --------------285000 -RIH w/ Liner Casing Record Alaska RIG:SPUD:14-Jun-2015 SPERRY JOB:TD:11-Jul-2015 Remarks 16" Conductor @ 120' MD, 120'TVD 10.75" Casing @ 3644' MD, 2653'TVD 7.625" Casing @ 11982' MD, 6275'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE: W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Milled Tooth Bit 13.50 93 3654 3561 61.05 0.994 112.0 22 70 2250 750 1-1-WT-A-E-1-NO-TD Surface TD 2 400 2 PDC 9.88 3654 11985 8331 121.33 0.560 113.6 45 140 3200 730 0-0-NO-A-X-I-NOTD Intermediate TD 3 500 3 PDC 6.75 11985 18410 6425 75.75 0.499 84.2 45 140 3727 260 1-1-CT-G-X-IN-NO -TD Production TD WELL NAME:2S-02 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902499586 TD:11-Jul-2015 MI Swaco STATE:Alaska RIG:Doyon 141 SPUD:14-Jun-2015 B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 145054 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 0 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 13480 0 744 176 Units* Casing Summary Lithology (%) 4 MBT 2069' pH 499 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 27.5258 C-5n 1869' 99.0 C-2 1174 in 3 1505'Minimum Depth Time: 88 635' 2704' 2069' Max @ ft Current 1663'78.5 Date: Avg to93' Yesterday's Depth: Current Depth: 24 Hour Progress: 520.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Don Mickey/Bob Finkbiner ShClyst TuffGvlCoal cP 60 1976' Footage 39.20 90 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - D/A PV 24 hr Max Weight 4 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 001 31.0 WBM 6.02686'80 Depth in / out Mud Type Lst 10 Type Average -90Background (max)Trip 10.6210.40 Avg Min Comments RPM ECD (ppg) ml/30min Tools arcVison,MWD API FL Chromatograph (ppm) 19.093'2069' WOB Conductor 100% Gas In Air=10,000 Units-Connection 0 109' Condition - Bit # 1 6.0 13.5 9.60 13 1/2" VM-3 Milled Tooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.84 Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Jun-2015 12:00 AM Current Pump & Flow Data: 157 Max 1 Chlorides mg/l 350.00 Drilled Ahead from 635' MD to 2704' MD. Max Gas 1174 Units.1 barrel gain for 24 hour period. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled ahead from 2704' MD to 3654' MD. Circulate B/U. TOOH. Max Gas 1292u. 66 Barrel loss for 24 hour period. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 420.00 18 17-Jun-2015 12:00 AM Current Pump & Flow Data: 8 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.85 Doyon 141 Report For: Condition - Bit # 1 9.0 13.5 9.80 13 1/2" VM-3 Milled Tooth 9.80 Size 109' 100% Gas In Air=10,000 Units-Connection 79 Tools arcVison,MWD API FL Chromatograph (ppm) 32.493'3653' WOB Conductor 9.9610.50 Avg Min Comments RPM ECD (ppg) ml/30min 25Background (max)Trip Average 834 Mud Type Lst 30 Type 38.0 WBM 6.23654'50 Depth in / out YP (lb/100ft2) 9.50 3790 00 CementChtSilt C-4i C-4n 24 hr Max Weight 119 Hours C-3 70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Pump OOH PV 3544' Footage 47.70 Don Mickey/Bob Finkbiner ShClyst TuffGvlCoal cP 38 Gas Summary 0 30 274 (current) Avg to109' Yesterday's Depth: Current Depth: 24 Hour Progress: 280.0 Flow In (gpm) Flow In (spm) 2704' 3654' 950' Max @ ft Current 3159'117.8 Date: Time: 219 in 3 2841'Minimum Depth C-5n 3196' - C-2 1292 SPP (psi) Gallons/stroke TFABit Type Depth 35.0223 MBT 3654' pH 499 0 786 0 Siltst 0 0 Units* Casing Summary Lithology (%) 18831610 435 907-670-4906Unit Phone: 10 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) 702 0 Cly 163854 . . * 24 hr Recap: (max)(current) 19 0 Cly 8871 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 0 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 2356 15 0 0 Units* Casing Summary Lithology (%) 24 MBT 3654' pH 499 0 59 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 30.0260 C-5n - - C-2 109 in 2 -Minimum Depth Time: 20 3654' 3654' 0' Max @ ft Current -- Date: Avg to109' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 57 (current) Don Mickey/Bob Finkbiner ShClyst TuffGvlCoal cP 32 3544' Footage 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - RIH Casing PV 24 hr Max Weight 5 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 0027 38.0 WBM 6.03654'62 Depth in / out Mud Type Lst Type Average 10910Background (max)Trip 9.9610.50 Avg Min Comments RPM ECD (ppg) ml/30min Tools arcVison,MWD API FL Chromatograph (ppm) 32.493'3653' WOB Conductor 100% Gas In Air=10,000 Units-Connection 5 109' Condition - Bit # 1 8.8 13.5 9.70 13 1/2" VM-3 Milled Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.85 Doyon 141 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Jun-2015 12:00 AM Current Pump & Flow Data: 19 Max 0 Chlorides mg/l 400.00 L/D BHA. RIH with casing to 1628'MD. Max Gas 109 U. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 45.5# Hydril 563 60 0 Cly 30240 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 0 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 3634 33 10.75'' 0 0 Units* Casing Summary Lithology (%) 22 L-80 MBT 3654' pH 499 0 101 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 27.552 C-5n - - C-2 302 in 2 -Minimum Depth Time: F/1575' MD T/1735' MD. RIH F/1735' MD T/3613' MD. M/U hanger/Landing JT. Land Casing @ 3644' MD. Circ and condition mud. 27 3654' 3654' 0' Max @ ft Current -- Date: Avg to109' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 5 74 (current) Don Mickey/Bob Finkbiner ShClyst TuffGvlCoal cP 25 3544' Footage 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Nipple Down Diverter PV 24 hr Max Weight 5 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 0021 38.0 WBM 6.43654'17 Depth in / out Mud Type Lst Type Average --Background (max)Trip 9.9610.50 Avg Min Comments RPM ECD (ppg) ml/30min Tools arcVison,MWD API FL Chromatograph (ppm) 32.493'3653' WOB Conductor 100% Gas In Air=10,000 Units-Connection 9 Monitor Well: Static. R/D Landing JT and Volant tool. Flush stack and flow-line. L/D Rig tongs and Volant tool. N/D Diverter. R/U Cement Lines and Valves T/Volant tool. Pump Cement. Bump Plug with rig pumps @ 7 BPM. Bumped plug w/3302 Strokes. 2641' 109' Condition - Bit # 1 9.0 13.5 9.80 13 1/2" VM-3 Milled Tooth 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.85 Doyon 141 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Jun-2015 12:00 AM Current Pump & Flow Data: 19 Max 1 Chlorides mg/l 380.00 Cont. RIH w/10.75" CSG T/1550' MD. Lost Slack off Weight. CBU @ 1575' MD. Hole unloaded. Cont Pumping in hole Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Hydril 563 - - Cly - Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: - J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman - - 10.75'' 0 0 Units* Casing Summary Lithology (%) - L-80 MBT 3654' pH 499 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 27.545 C-5n - - C-2 - in --Minimum Depth Time: T/blind rams, Blind rams T/Mud Cross and lower rams. Install Koomey Lines. Install MPD air valve, M/U Adapter Flange. Install - 3654' 3654' 0' Max @ ft Current -- Date: Avg to109' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary - -- (current) Larry Hill/Bob Finkbiner ShClyst TuffGvlCoal cP 17 3544' Footage 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Nipple up BOPE PV 24 hr Max 45.5 Weight - Hours C-3 -- CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 --- 38.0 WBM 6.53654'12 Depth in / out Mud Type Lst Type Average --Background (max)Trip 9.9610.50 Avg Min Comments RPM ECD (ppg) ml/30min Tools arcVison,MWD API FL Chromatograph (ppm) 32.493'3653' WOB Conductor 100% Gas In Air=10,000 Units-Connection - Kill line. Take on LSND. Inspect pumps and Top Drive. Calibrate gas equipment. 3640' 109' Condition - Bit # 1 9.0 13.5 9.80 13 1/2" VM-3 Milled Tooth 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.85 Doyon 141 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Jun-2015 12:00 AM Current Pump & Flow Data: 19 Max - Chlorides mg/l 380.00 Cont. N/D Diverter. N/U well head. Test. N/U BOPE. Cont N/U BOPE. M/U New choke line flanges, M/U upper rams Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont N/U kill lines/Choke lines. Remove MPD valve, change out with another. R/U scaffolding around stack. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 420.00 - 21-Jun-2015 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.85 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 9.0 13.5 9.60 13 1/2" VM-3 Milled Tooth 9.60 Size M/U BHA. Set wear ring. R/U and Test RCD per Safekick rep. Service Rig. R/D test cap install riser adapters. Mobilize BHA to Rig floor. 3640' 109' 100% Gas In Air=10,000 Units-Connection - Tools arcVison,MWD API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 9.9610.50 Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average - Mud Type Lst Type 38.0 9 7/8 PDC WBM 6.53654'17 Depth in / out YP (lb/100ft2) 9.10 --- -- CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - M/U BHA RIH PV 3544' 9.875 Footage 47.70 Larry Hill/Bob Finkbiner ShClyst TuffGvlCoal cP 16 Gas Summary - -- (current) Avg to109' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 3654' 3654' 0' Max @ ft Current -- Date: Time: Hammer up MPD Valve. R/U T/test BOPE. Attempt to test. Choke line leaking, Mud Cross Leaking. Test BOPE. R/D Test equip. - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 27.547 L-80 MBT 3654' pH 0.499 - - - Siltst 10.75'' 0 0 Units* Casing Summary Lithology (%) -- - 907-670-4906Unit Phone: - J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) Hydril 563 - - Cly - . . * 24 hr Recap: (max)(current) Hydril 563 181 0 Cly 7513 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 28 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 312 0 10.75'' 0 0 Units* Casing Summary Lithology (%) 3 L-80 MBT 3674' pH 0.499 0 52 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 27.550 C-5n 3674' - C-2 61 in 0 -Minimum Depth Time: equip. Install MPD bearing. Test MPD. Install Catch can on stack. Install new flow paddle on flow line. Drill Float Equip to 3654' MD. 8 3654' 3674' 20' Max @ ft Current 3672'25.7 Date: Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 150.6 Flow In (gpm) Flow In (spm) Gas Summary 0 52 47 (current) Larry Hill/Bob Finkbiner ShClyst TuffGvlCoal cP 19 3544' 9.875 Footage 20' 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - L/D BHA PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.30 005 39 38.0 9 7/8 PDC LSND 6.6 3654' 3654'19 3674' Depth in / out Mud Type Lst Type Average 372Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools EcoScope,MWD API FL Chromatograph (ppm) 22 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 44 110 BBLs. Observed pressure spike. Decision made to TOOH. Drill 20' to 3674' MD. Rack back stand. CBU. Mud aired up. Displace well to 9.6 ppg LSND. Pumped 24 BBL spacer, chased with 3640' 109' Condition 1,1,WT,A,E,1,NOTD Bit # 1 9.0 13.5 9.70 13 1/2" VM-3 Milled Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Jun-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 380.00 RIH F/736' MD T/1666' MD. Perform shallow pulse test. RIH to 3535'. Circulate. R/U and test casing. R/U safekick Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Hydril 563 148 0 Cly 48721 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 60 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 10 8340 0 10.75'' 711 168 Units* Casing Summary Lithology (%) 4 L-80 MBT 5027' pH 0.499 0 51 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 4.052 C-5n 3674' 251.0 C-2 571 in 2 -Minimum Depth Time: RIH w/5 stands HWDP F/276' MD T/735' MD. RIH T/1573' MD. Shallow Pulse test MWD. RIH T/3650' MD. Wash and Ream F/3650' 59 3674' 5027' 1353' Max @ ft Current 4445'85.0 Date: Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 339.6 Flow In (gpm) Flow In (spm) Gas Summary 0 13 70 (current) Larry Hill/Bob Finkbiner ShClyst TuffGvlCoal cP 12 3544' 9.875 Footage 8.80 - 47.70 20 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - D/A PV 24 hr Max 45.5 Weight 12 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 708 85 38.0 9 7/8 PDC LSND 5.8 3654' 3654'30 - Depth in / out Mud Type Lst 70 Type Average -100Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools EcoScope,MWD API FL Chromatograph (ppm) 11 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 47 LSND. Drilling Ahead MD T/3674' MD. CBU. POOH F/3674' MD T/3625' MD. Perform FIT (EMW: 16.0ppg) Displace well F/9.6 ppg Spud Mud. T/ 9.6 ppg 3640' 109' Condition 1,1,WT,A,E,1,NOTD Bit # 1 120.0 13.5 9.60 13 1/2" VM-3 Milled Tooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jun-2015 12:00 AM Current Pump & Flow Data: 2124 Max 0 Chlorides mg/l 8000.00 L/D BHA. Change MWD, M/U Bit, install sources, RIH w/1 Stand HWDP. Clean under shakers, pit 5, and Trip Tank. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled ahead F/5027' MD T/7268' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 5600.00 2 24-Jun-2015 12:00 AM Current Pump & Flow Data: 339 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.02 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 120.0 13.5 9.60 13 1/2" VM-3 Milled Tooth 9.60 Size 3640' 109' 100% Gas In Air=10,000 Units-Connection 16 Tools EcoScope,MWD API FL Chromatograph (ppm) 22 32.493'3654' WOB Conductor 10.2211.66 Avg Min Comments RPM ECD (ppg) ml/30min 70Background (max)Trip Average - Mud Type Lst 70 Type 128 38.0 9 7/8 PDC LSND 5.5 3654' 7243'23 - Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 37 Hours C-3 10 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Drilling Ahead PV 3544' 9.875 0.710 Footage 23.30 - 47.70 Larry Hill/Bob Finkbiner ShClyst TuffGvlCoal cP 12 Gas Summary 0 46 16 (current) Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 309.0 Flow In (gpm) Flow In (spm) 5027' 7268' 2241' Max @ ft Current 5585'95.0 Date: Time: 56 in 2 7217'Minimum Depth C-5n 5403' 125.0 C-2 163 SPP (psi) Gallons/stroke TFABit Type Depth 15.045 L-80 MBT 7268' pH 0.499 0 12 0 Siltst 10.75'' 719 170 Units* Casing Summary Lithology (%) 0 20 8423 13 907-670-4906Unit Phone: 18 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) Hydril 563 88 0 Cly 22487 . . * 24 hr Recap: Drilled ahead F/7268' MD T/7960’ MD. Troubleshoot #2 mud pump, washed out seat, Circulate. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 13 25-Jun-2015 12:00 AM Current Pump & Flow Data: 288 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.02 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 110.0 13.5 9.90 13 1/2" VM-3 Milled Tooth 9.90 Size 157.7 BBLs loss. 156.2 BBLs loss F/20:00-24:00 Back ream STD due to ECD’s, on the DN STK, observed pack off issues. CBU. Observed losses @ 60 BHP. Monitor Well (Static). C/O SCR breaker, Monitor Well Visually(Static). RIH F/ 8107’ MD T/8362’MD. D/A T/ 8757’MD. 3640' 109' 100% Gas In Air=10,000 Units-Connection 59 Tools EcoScope,MWD API FL Chromatograph (ppm) 19 32.493'3654' WOB Conductor 10.2211.75 Avg Min Comments RPM ECD (ppg) ml/30min 22Background (max)Trip Average - Mud Type Lst 40 Type 97 38.0 9 7/8 PDC LSND 4.2 3654' 8755'28 - Depth in / out YP (lb/100ft2) 4.20 010 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 74 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Circ. Pump Pill PV 3544' 9.875 0.710 Footage 34.00 - 47.70 Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 14 Gas Summary 0 12 20 (current) Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 177.0 Flow In (gpm) Flow In (spm) 7268' 8757' 1489' Max @ ft Current 8200'63.0 Date: Time: Drill F/7960’ MD T/8362’ MD. SCR breaker #2 tripped & could not be Reset, Decision made to Change out, Back Ream. 52 in 2 8714'Minimum Depth C-5n 8360' - C-2 269 SPP (psi) Gallons/stroke TFABit Type Depth 22.553 L-80 MBT 8757' pH 0.499 0 18 0 Siltst 10.75'' 495 117 Units* Casing Summary Lithology (%) 3 40 8120 31 907-670-4906Unit Phone: 12 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) Hydril 563 334 0 Cly 36127 . . * 24 hr Recap:Decision made to pump LCM pill Circ. Drill from 8757’ MD to 8847’MD. Circ. Monitor Well (well Breathing). Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1500.00 133 26-Jun-2015 12:00 AM Current Pump & Flow Data: 2419 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.02 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 70.0 13.5 10.00 13 1/2" VM-3 Milled Tooth 10.00 Size packing off while drilling. P/U slow pumps. Establish loss rate. Ream in hole to 9190’MD. Drill from 9190’MD to 9644’MD. 3640' 109' 100% Gas In Air=10,000 Units1362Connection 2079 Tools EcoScope,MWD API FL Chromatograph (ppm) 17 32.493'3654' WOB Conductor 10.2211.75 Avg Min Comments RPM ECD (ppg) ml/30min 68Background (max)Trip Average - Mud Type Lst 70 Type 93 38.0 9 7/8 PDC LSND 4.2 3654' 9630'25 - Depth in / out YP (lb/100ft2) 9.40 5298 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 388 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Drilling Ahead PV 3544' 9.875 0.710 Footage 45.00 - 47.70 Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 15 Gas Summary 0 537 133 (current) Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 165.3 Flow In (gpm) Flow In (spm) 8757' 9644' 887' Max @ ft Current 9129'36.7 Date: Time: Monitor through annulus. Hook up MPD return line and line up to circ. Circ through MPD. Drill from 8847’MD to 9190’MD observed 102 382.9 BBLs loss in 24 hour period. in 2 9441'Minimum Depth C-5n 8848' 76.0 C-2 1362 SPP (psi) Gallons/stroke TFABit Type Depth 26.050 L-80 MBT 9644' pH 0.499 0 249 0 Siltst 10.75'' 592 140 Units* Casing Summary Lithology (%) 22 30 12073 0 907-670-4906Unit Phone: 123 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) Hydril 563 4877 0 Cly 165179 . . * 24 hr Recap: (max)(current) Hydril 563 4081 0 Cly 70736 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 120 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 40 17389 80 10.75'' 567 134 Units* Casing Summary Lithology (%) 58 L-80 MBT 11367' pH 0.499 0 192 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 13.849 C-5n 10481' 60.0 C-2 687 in 2 11138'Minimum Depth Time: 158 161 BBLs loss in 24 hour period. 9644' 11367' 1723' Max @ ft Current 9716'72.0 Date: Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 150.0 Flow In (gpm) Flow In (spm) Gas Summary 0 618 114 (current) Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 14 3544' 9.875 0.710 Footage 65.00 - 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Drilling Ahead PV 24 hr Max 45.5 Weight 1004 Hours C-3 50 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 4118337 96 38.0 9 7/8 PDC LSND 4.3 3654' 11365'24 - Depth in / out Mud Type Lst 10 Type Average -201Background (max)Trip 10.2211.75 Avg Min Comments RPM ECD (ppg) ml/30min Tools EcoScope,MWD API FL Chromatograph (ppm) 18 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units687Connection 2044 3640' 109' Condition 1,1,WT,A,E,1,NOTD Bit # 1 60.0 13.5 10.30 13 1/2" VM-3 Milled Tooth 10.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.02 Doyon 141 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Jun-2015 12:00 AM Current Pump & Flow Data: 2422 Max 533 Chlorides mg/l 800.00 Drilling ahead from 9644'MD to 11367'MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilling from 11367' MD to 11985' MD. 6276' TVD. CBU. Pump Sweep, Circulate out. Pump Sweep, CBU x3. Monitor Well Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 700.00 556 28-Jun-2015 12:00 AM Current Pump & Flow Data: 58 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.45 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 11.0 13.5 10.40 13 1/2" VM-3 Milled Tooth 10.40 Size 3640' 109' 100% Gas In Air=10,000 Units470Connection 2352 Tools EcoScope,MWD API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor 10.2211.59 Avg Min Comments RPM ECD (ppg) ml/30min 61Background (max)Trip Average 529 Mud Type Lst 10 Type 96 38.0 9 7/8 PDC LSND 3.4 3654' 11985'23 11985' Depth in / out YP (lb/100ft2) 9.90 6825155 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 968 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - BROOH PV 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 13 Gas Summary 0 778 162 (current) Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: 121.0 Flow In (gpm) Flow In (spm) 11367' 11985' 618' Max @ ft Current 11922'26.0 Date: Time: (Well Breathing) TOOH. Encountered Tight spot @ 9727'MD. Ream through tight spot from 9781' to 9700' MD. BROOH. 146 411 BBLs loss in 24 hour period. in 2 11766'Minimum Depth C-5n 11840' - C-2 1046 SPP (psi) Gallons/stroke TFABit Type Depth 18.547 L-80 MBT 11985' pH 0.499 0 241 0 Siltst 10.75'' 9 2 Units* Casing Summary Lithology (%) 6014574 0 907-670-4906Unit Phone: 182 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade 16" (max)(current) Hydril 563 5671 0 Cly 101619 70 . . * 24 hr Recap: (max)(current) Hydril 563 1671 0 Cly 26401 Set AtSize 62.5 lbs/ft R3 Grade 16" 907-670-4906Unit Phone: 82 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 1401 0 10.75'' 97 23 Units* Casing Summary Lithology (%) 6 L-80 MBT 11985' pH 0.499 0 109 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.848 C-5n - - C-2 253 in 2 -Minimum Depth Time: POOH on elevators from 8107' to 5032' MD. Work pipe through tight spots. Pump out 3 STDs from 5032' to 4750'MD. ECD's Climbing, 16 173 BBLs loss in 24 hour period. 11985' 11985' 0' Max @ ft Current -- Date: Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 298 87 (current) Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 14 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - TOOH PV 24 hr Max 45.5 Weight 57 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 9227 96 38.0 9 7/8 PDC LSND 3.4 3654' 11985'27 11985' Depth in / out Mud Type Lst Type Average 2534Background (max)Trip 10.2211.59 Avg Min Comments RPM ECD (ppg) ml/30min Tools EcoScope,MWD API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 850 Co-Man. Line up on Trip Tank. POOH on elevators from 3615' to 3250' MD. Hole swabbing. Pump out 2 bpm from 2973' to 2640'MD. mud coming back 10.6 ppg. Circ hole till MW is 10.4 ppg. POOH for 4750' to 3627' MD. CBU. Monitor Well. Perform Breathing test per 3640' 109' Condition 1,1,WT,A,E,1,NOTD Bit # 1 600.0 13.5 10.40 13 1/2" VM-3 Milled Tooth 10.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.45 Doyon 141 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Jun-2015 12:00 AM Current Pump & Flow Data: 83 Max 37 Chlorides mg/l 600.00 BROOH from 9506' MD to 8107' MD. ECD's Climbing, mud coming back 10.6 ppg. Circ hole clean till MW is 10.4 ppg. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Pump OOH, from 2640' to 828'MD. Monitor Well (Slight Flow, slowing down to a dribble confirm breathing) POOH Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 8 30-Jun-2015 12:00 AM Current Pump & Flow Data: 31 Max 0,0,NO,A,X,I,NOTD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.45 Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 11.0 13.5 10.40 13 1/2" VM-3 Milled Tooth 10.40 Size per Cameron rep. Run 7-5/8 CSG to 3612' MD. CBU at 3612' MD. Cont. RIH to 4465' MD. washer and flush. Remove 2.875" X5" top rams. Install 7.625 rams. Test rams. P/U Hanger and M/U landing JT. Preform dummy run 3640' 109' 100% Gas In Air=10,000 Units-Connection 22 Tools EcoScope,MWD API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor 10.2211.59 Avg Min Comments RPM ECD (ppg) ml/30min 5Background (max)Trip Average 37 Mud Type Lst Hydril 563 Type 96 38.0 9 7/8 PDC LSND 3.4 3654' 11985'27 11985' Depth in / out YP (lb/100ft2) 9.90 291 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 5 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - RIH CSG PV 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Larry Hill/ Andy Lundale ShClyst TuffGvlCoal cP 14 29.7 Gas Summary 0 20 16 (current) Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 11985' 11985' 0' Max @ ft Current -- Date: Time: from 828' to 735' MD. Rack Back 3 STDS HWDP. Unload sources. POOH 3 STDS HWDP and L/D BHA per SLB rep. M/U stack 9 6 BBLs loss in 24 hour period. in 2 -Minimum Depth C-5n - - C-2 37 SPP (psi) Gallons/stroke TFABit Type Depth 18.847 L-80 MBT 11985' pH 0.499 0 8 0 Siltst 10.75'' 0 0 Units* Casing Summary Lithology (%) 0676 0 907-670-4906Unit Phone: 13 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade L-80 16" 7.63'' (max)(current) Hydril 563 32 0 Cly 5478 . . * 24 hr Recap: (max)(current) Hydril 563 98 0 Cly 22953 Set AtSize 62.5 lbs/ft R3 Grade L-80 16" 7.63'' 907-670-4906Unit Phone: 37 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman 10419 127 10.75'' 21 5 Units* Casing Summary Lithology (%) 7 L-80 MBT 11985' pH 0.499 0 33 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.849 C-5n - - C-2 163 in 3 -Minimum Depth Time: at 1 BPM, no returns to slight returns. Slack off string broke free, pumped away 7 bbls during circulation. RIH from 5138' to 5152' 73 363 BBLs loss in 24 hour period. 11985' 11985' 0' Max @ ft Current -- Date: Avg to3654' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 37 31 (current) Don Mickey/Andy Lundale ShClyst TuffGvlCoal cP 14 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - RIH CSG PV 24 hr Max 45.5 Weight 47 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 9227 96 38.0 9 7/8 PDC LSND 3.4 3654' 11985'19 11985' Depth in / out Mud Type Lst Hydril 563 Type Average 2626Background (max)Trip 10.2211.59 Avg Min Comments RPM ECD (ppg) ml/30min Tools EcoScope,MWD API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 64 Observed no returns. RIH from 8073' to 11805' MD. Tight spot at 11805. Wash Down to 11837' MD. MD. Decision made to Continue RIH. RIH from 5152' to 5761' MD. Slight returns. Break Circ at 1 BPM. RIH from 5761' to 8073' MD. 3640' 109' Condition 1,1,WT,A,E,1,NOTD Bit # 1 80.0 13.5 14.00 13 1/2" VM-3 Milled Tooth 14.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.45 Doyon 141 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska 0,0,NO,A,X,I,NOTD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Jul-2015 12:00 AM Current Pump & Flow Data: 31 Max 27 Chlorides mg/l 600.00 RIH 7.625" CSG. From 4465' to 5138' MD. Observed 15K slack off. Decision made to Circ. (slight returns). Break Circ. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Work Pipe from 11982' to 11945' MD. Tight hole, could not go up or down, could not pump, work pipe free, establish Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2300.00 17 2-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 0,0,NO,A,X,I,NOTD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1,1,WT,A,E,1,NOTD Bit # 1 160.0 13.5 10.50 13 1/2" VM-3 Milled Tooth 10.50 Size P/U packoff. Set packoff and test. Flush and freeze protect annulus. Slip and cut drill line. Perform both stages of Cement job. Per SLB reps. R/D & B/D lines. R/D Scaffolding and break stack. N/U stack, L/D CSG tools & 3640' 109' 100% Gas In Air=10,000 Units-Connection 70 Tools - API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor -- Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average 150 Mud Type Lst Hydril 563 Type 96 38.0 9 7/8 PDC LSND 5.1 3654' 11985'24 11985' Depth in / out YP (lb/100ft2) 9.90 5134 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 29 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 - - Slip & Cut PV 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Don Mickey/Andy Lundale ShClyst TuffGvlCoal cP 13 29.7 Gas Summary 0 53 44 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 11985' 11985' 0' Max @ ft Current -- Date: Time: Circ. Minimal returns. Work pipe from from 11960' to 11980' MD. Prep for cement job. R/U cement equipment, establish Circ. 40 1408 BBLs loss in 24 hour period. in 2 -Minimum Depth C-5n - - C-2 150 SPP (psi) Gallons/stroke TFABit Type Depth 3.050 L-80 MBT - pH 0.499 0 25 0 Siltst 10.75'' 0 0 Units* Casing Summary Lithology (%) 45549 0 907-670-4906Unit Phone: 34 J. Kyle Wiseman Maximum Report By:Logging Engineers:Jacob Hansen, J. Kyle Wiseman Set AtSize 62.5 lbs/ft R3 Grade L-8011980' 16" 7.63'' (max)(current) Hydril 563 101 0 Cly 21293 . . * 24 hr Recap: (max)(current) Hydril 563 0 0 Cly 0 Set AtSize 62.5 lbs/ft R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 0 0 10.75'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT - pH 0.499 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.051 C-5n - - C-2 0 in 0 -Minimum Depth Time: 0 0 BBLs loss in 24 hour period. 11985' 11985' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) Don Mickey/Andy Lundale ShClyst TuffGvlCoal cP 13 3544' 9.875 0.710 Footage 73.20 8331' 47.70 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 P/U 4" DP PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 000 96 38.0 9 7/8 PDC LSND 5.1 3654' 11985'23 11985' Depth in / out Mud Type Lst Hydril 563 Type Average 00Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 20 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 0 2 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 160.0 13.5 10.50 13 1/2" VM-3 Milled Tooth 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska 0-0-NO-A-X-I-NO-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 2-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 2200.00 Slip and Cur drill line. L/D 5" DP from derrick. C/O top rams. Prepped pipe shed for 4" DP, then began P/U. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Hydril 563 0 0 Cly 0 Set AtSize 62.5 lbs/ft R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 0 0 10.75'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT - pH 0.499 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.051 C-5n - - C-2 0 in 0 -Minimum Depth Time: 0 0 BBLs loss in 24 hour period. 11985' 11985' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) Robert Wall/Andy Lundale ShClyst TuffGvlCoal cP 13 3544' 6.75 0.383 Footage 0' 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 BOP Test PV 24 hr Max 45.5 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 000 38.0 6.75" PDC LSND 5.1 11985' 11985'25 11985' Depth in / out Mud Type Lst Hydril 563 Type Average 00BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 0 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 160.0 13.5 10.50 13 1/2" VM-3 Milled Tooth 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 2300.00 Continued to P/U 4" DP. BOP Test. SDL crew calibrated and tested gas equipment. Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: Hydril 563 0 0 Cly 0 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 0 0 10.75'' 215 51 Units* Casing Summary Lithology (%) 0 L-80 MBT - pH 0.499 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.049 C-5n - - C-2 0 in 0 -Minimum Depth Time: Pass to cmt stinger @ 9050' MD @ 220 GPM, CBU. Performed casing pressure test to 3000PSI for 10 mins. Drilled out cmt collar 0 0 BBLs loss in 24 hour period. 11985' 11985' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) Robert Wall/Andy Lundale ShClyst TuffGvlCoal cP 11 3544' 6.75 0.383 Footage 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 MADD Pass PV 24 hr Max 45.5 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 10.70 000 38.0 6.75" PDC LSND 4.6 11985' 11985'23 Depth in / out Mud Type Lst Hydril 563 Type Average 00BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 0 3 then continued MADD Pass. 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 340.0 13.5 10.50 13 1/2" VM-3 Milled Tooth 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Jul-2015 12:00 AM Current Pump & Flow Data: 1580 Max 0 Chlorides mg/l 2300.00 Performed BOP Test per AOGCC. R/D testing equipment. M/U BHA #4 per SLB, RIH to 7720' MD and began MADD Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' Finished MADD Pass to 11892' MD, cmt quality good. CBU and performed casing pressure test to 3500 PSI for Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 5-Jul-2015 12:00 AM Current Pump & Flow Data: 1731 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-A-E-1-NO-TD Bit # 1 400.0 13.5 10.40 13 1/2" VM-3 Milled Tooth 10.40 Size 3 3640' 109' 100% Gas In Air=10,000 Units-Connection 0 Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor -- Avg Min Comments Surface RPM ECD (ppg) ml/30min 0Background Trip Average 0 Mud Type Lst Hydril 563 Type 38.0 6.75" PDC LSND 4.5 11985' 11985'25 Depth in / out YP (lb/100ft2) 10.20 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drill Out Cmt PV 3544' 6.75 0.383 Footage 47.70 11985' 8331' Robert Wall/Andy Lundale ShClyst TuffGvlCoal cP 11 29.7 Gas Summary 0 0 0 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 11985' 11985' 0' Max @ ft Current -- Date: Time: 30 mins. Slip & cut drill line. Drilling out cmt. 0 0 BBLs loss in 24 hour period. in 0 -Minimum Depth C-5n - - C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 3.048 L-80 MBT - pH 0.499 0 0 0 Siltst 10.75'' 199 47 Units* Casing Summary Lithology (%) 00 0 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' Hydril 563 0 0 Cly 0 . . * 24 hr Recap: Hydril 563 1351 0 Cly 20385 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 52 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 10 4760 0 10.75'' 233 55 Units* Casing Summary Lithology (%) 17 L-80 MBT - pH 0.499 0 48 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.354 C-5n 12179' - C-2 187 in 0 11986'Minimum Depth Time: Displaced mud system per Mud Engineer to 10.5 ppg Flo-Thru then monitored well, out of balance. Circ and Cond while clearing 33 0 BBLs loss in 24 hour period. 11985' 12263' 278' Max @ ft Current 12259'47.4 Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 123.3 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 100 18 (current) Robert Wall/Andy Lundale ShClyst TuffGvlCoal cP 17 3544' 6.75 0.383 Footage 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drilling Ahead PV 24 hr Max 45.5 Weight 645 Hours C-3 90 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 25486 38.0 6.75" PDC Flo-Thru 2.7 11985' 12165'21 Depth in / out Mud Type Lst Hydril 563 Type Average 064BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 488 3 BHA. Continued to drill ahead. 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 14.8 13.5 10.50 13 1/2" VM-3 Milled Tooth 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Jul-2015 12:00 AM Current Pump & Flow Data: 2684 Max 217 Chlorides mg/l 145000.00 Continued drilling out cmt and 20' of new formation. Pulled back into the show and performed FIT test to 16 ppg. Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: Hydril 563 46365 26 Cly 428109 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 964 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 40 234499 159 10.75'' 241 57 Units* Casing Summary Lithology (%) 973 L-80 MBT - pH 0.499 38 2249 4 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.556 C-5n 13033' 86.0 C-2 7073 in 276 12263'Minimum Depth Time: 3569 0 BBLs loss in 24 hour period. 12263' 13208' 945' Max @ ft Current 12923'87.0 Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 216.0 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 2 4881 969 (current) Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 20 3544' 6.75 0.383 Footage 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drilling Ahead PV 24 hr Max 45.5 Weight 21456 Hours C-3 216 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 4302113434 38.0 6.75" PDC Flo-Thru 2.0 11985' 10379'22 Depth in / out Mud Type Lst 60 Hydril 563 Type Average 02650BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units4164Connection 22186 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 16.5 13.5 10.80 13 1/2" VM-3 Milled Tooth 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Jul-2015 12:00 AM Current Pump & Flow Data: 2975 Max 9681 Chlorides mg/l 138000.00 Continue to drill ahead to 12639' MD, performed pore pressure test, CBU. Troubleshoot MPD , continue to drill ahead. Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' Continue to drill ahead in production section. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2.60 5824 8-Jul-2015 12:00 AM Current Pump & Flow Data: 3355 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-A-E-1-NO-TD Bit # 1 17.0 13.5 10.70 13 1/2" VM-3 Milled Tooth 10.70 Size 3 3640' 109' 100% Gas In Air=10,000 Units8571Connection 35406 Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor -- Avg Min Comments Surface RPM ECD (ppg) ml/30min 6500Background Trip Average 0 Mud Type Lst 100 Hydril 563 Type 38.0 6.75" PDC Flo-Thru 7.0 11985' 14733'23 Depth in / out YP (lb/100ft2) 9.70 116051281112 048 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 45280 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drilling Ahead PV 3544' 6.75 0.383 Footage 47.70 11985' 8331' Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 21 29.7 Gas Summary 0 7990 1639 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 190.2 Flow In (gpm) Flow In (spm) 13208' 14951' 1743' Max @ ft Current 14904'101.4 Date: Time: 7191 0 BBLs loss in 24 hour period. in 19 13208'Minimum Depth C-5n 14810' 100.0 C-2 9880 SPP (psi) Gallons/stroke TFABit Type Depth 2.059 L-80 MBT - pH 0.499 104 3655 0 Siltst 10.75'' 258 61 Units* Casing Summary Lithology (%) 2322463553 1616 907-670-4906Unit Phone: 1371 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' Hydril 563 75148 213 Cly 714999 . . * 24 hr Recap: Hydril 563 266517 0 Cly 607083 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 1416 Hilary Garney Maximum Report By:Logging Engineers:Jacob Hansen, Hilary Garney 304301 0 10.75'' 245 58 Units* Casing Summary Lithology (%) 1509 L-80 MBT - pH 0.499 0 3324 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.564 C-5n 15885' 104.0 C-2 9238 in 100 14847'Minimum Depth Time: 3738 36 BBLs loss in 24 hour period. 14951' 16575' 1624' Max @ ft Current 15987'68.0 Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 207.0 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 41290 1440 (current) Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 23 3544' 6.75 0.383 Footage 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drilling Ahead PV 24 hr Max 45.5 Weight 29857 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 7183255734 38.0 6.75" PDC Flo-Thru 2.4 11985' 16383'27 Depth in / out Mud Type Lst 100 Hydril 563 Type Average 01325BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units6342Connection 66147 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 16.8 13.5 10.80 13 1/2" VM-3 Milled Tooth 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Jul-2015 12:00 AM Current Pump & Flow Data: 3332 Max 15313 Chlorides mg/l 146000.00 Continuing to drill ahead in production section. Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' Continued to drill ahead to 17266' MD. Troubleshoot Power Drive. CBU. Continued to drill ahead. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 148000.00 10247 10-Jul-2015 12:00 AM Current Pump & Flow Data: 39 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-A-E-1-NO-TD Bit # 1 17.0 13.5 10.70 13 1/2" VM-3 Milled Tooth 10.70 Size 3 3640' 109' 100% Gas In Air=10,000 Units2161Connection 28888 Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor -- Avg Min Comments Surface RPM ECD (ppg) ml/30min 600Background Trip Average 0 Mud Type Lst 100 Hydril 563 Type 38.0 6.75" PDC Flo-Thru 2.4 11985' 17638'24 Depth in / out YP (lb/100ft2) 9.80 5692488581 037 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 23409 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Drilling Ahead PV 3544' 6.75 0.383 Footage 47.70 11985' 8331' Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 22 29.7 Gas Summary 0 6481 1406 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 331.0 Flow In (gpm) Flow In (spm) 16575' 17837' 1262' Max @ ft Current 17369'52.7 Date: Time: 3963 0 BBLs loss in 24 hour period. in 246 17466'Minimum Depth C-5n 17284' 0.0 C-2 9104 SPP (psi) Gallons/stroke TFABit Type Depth 2.560 L-80 MBT - pH 0.499 85 3175 0 Siltst 10.75'' 0 0 Units* Casing Summary Lithology (%) 1143255694 1316 907-670-4906Unit Phone: 1301 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' Hydril 563 61368 142 Cly 595799 . . * 24 hr Recap: Hydril 563 51877 20 Cly 511495 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 1228 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams 30 241054 97 10.75'' 0 0 Units* Casing Summary Lithology (%) 1245 L-80 MBT - pH 0.499 20 2720 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.094 C-5n 18061' 0.0 C-2 7849 in 21 18277'Minimum Depth Time: came back clean. BROOH. 3683 0 BBLs loss in 24 hour period. 17837' 18410' 573' Max @ ft Current 18404'91.3 Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 140.0 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 5531 1237 (current) Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 27 3544' 6.75 0.383 Footage 6425' 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 BROOH PV 24 hr Max 45.5 Weight 22799 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 6142631632 38.0 6.75" PDC Flo-Thru 2.3 11985' 18410'34 18410' Depth in / out Mud Type Lst 70 Hydril 563 Type Average 413100BackgroundTrip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units2766Connection 45527 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 16.8 13.5 10.80 13 1/2" VM-3 Milled Tooth 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 10534 Chlorides mg/l 152000.00 Drilled ahead to 18275' MD, CBU and C/O MPD bearing. Continued drilling to TD of 18410' MD. CBU until shakers Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' Continued to BROOH to 12100' MD when hole packed off. Lost circulation and rototation. RIH to 12125' MD to try Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 152000.00 640 12-Jul-2015 12:00 AM Current Pump & Flow Data: 1776 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-A-E-1-NO-TD Bit # 1 14.5 13.5 10.80 13 1/2" VM-3 Milled Tooth 10.80 Size 3 3640' 109' 100% Gas In Air=10,000 Units-Connection 2313 Tools PeriScope, MicroScope, ImPulse, SonicScope, adnVISION API FL Chromatograph (ppm) 32.493'3654' WOB Conductor -- Avg Min Comments Surface RPM ECD (ppg) ml/30min 25Background Trip Average - Mud Type Lst 70 Hydril 563 Type 38.0 6.75" PDC Flo-Thru 1.8 11985' 18410'31 18410' Depth in / out YP (lb/100ft2) 9.60 158375146 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 787 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 BROOH PV 3544' 6.75 0.383 Footage 6425' 47.70 11985' 8331' Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 26 29.7 Gas Summary 0 661 218 (current) Avg to11895' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 18410' 18410' 0' Max @ ft Current -- Date: Time: and get circulation back. Worked pipe and got circulation back. Continue to BROOH. 144 250 BBLs loss in 24 hour period. in 5 -Minimum Depth C-5n - 0.0 C-2 1594 SPP (psi) Gallons/stroke TFABit Type Depth 2.588 L-80 MBT 18410' pH 0.499 0 281 0 Siltst 10.75'' 148 35 Units* Casing Summary Lithology (%) 133 30 6963 0 907-670-4906Unit Phone: 253 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' Hydril 563 6984 0 Cly 147981 . . * 24 hr Recap: Hydril 563 9195 33 Cly 141017 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 150 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams 30 9268 199 10.75'' 127 30 Units* Casing Summary Lithology (%) 36 L-80 MBT 18410' pH 0.499 21 268 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.079 C-5n - 0.0 C-2 1588 in 11 -Minimum Depth Time: 11979' MD to 12736' MD to spot hi-vis pill per mud engineer. 110 197 BBLs loss in 24 hour period. 18410' 18410' 0' Max @ ft Current -- Date: Avg to11895' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 595 150 (current) Robert Wall/Bob Finkbiner ShClyst TuffGvlCoal cP 23 3544' 6.75 0.383 Footage 6425' 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 Spot Pill PV 24 hr Max 45.5 Weight 683 Hours C-3 012 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 4810342 38.0 6.75" PDC Flo-Thru 2.4 11985' 18410'34 18410' Depth in / out Mud Type Lst 70 Hydril 563 Type Average -35Background Trip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools PeriScope, MicroScope, ImPulse, SonicScope, adnVISION API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 2927 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 16.0 13.5 10.70 13 1/2" VM-3 Milled Tooth 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Jul-2015 12:00 AM Current Pump & Flow Data: 1685 Max 261 Chlorides mg/l 110000.00 Continued BROOH, packed off at 120185' MD. Worked pipe free and BROOH to 11979' MD and CBUx2. RIH from Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' . . * 24 hr Recap: 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' Continued to BROOH. Pumped viscous pill. Pumped OOH then spotted 30bbl brine and displacement spacer. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 179000.00 45 14-Jul-2015 12:00 AM Current Pump & Flow Data: - Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 30 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-A-E-1-NO-TD Bit # 1 - 13.5 11.70 13 1/2" VM-3 Milled Tooth 11.70 Size 3 nipple. Slip and cut drill line. POOH. 3640' 109' 100% Gas In Air=10,000 Units-Connection 263 Tools PeriScope, MicroScope, ImPulse, SonicScope, adnVISION API FL Chromatograph (ppm) 32.493'3654' WOB Conductor -- Avg Min Comments Surface RPM ECD (ppg) ml/30min -Background Trip Average - Mud Type Lst 70 Hydril 563 Type 38.0 6.75" PDC Brine - 11985' 18410'- 18410' Depth in / out YP (lb/100ft2) - 7165 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 94 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902499586 POOH PV 3544' 6.75 0.383 Footage 6425' 47.70 11985' 8331' Dave Coates/Bob Finkbiner ShClyst TuffGvlCoal cP - 29.7 Gas Summary 0 82 30 (current) Avg to11895' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 18410' 18410' 0' Max @ ft Current -- Date: Time: Displaced well to 11.6ppg NaBr brine. Monitored well, breathing. Drained the stack. Monitored well, static. R/D RCD and R/U trip 12 0 BBLs loss in 24 hour period. in 0 -Minimum Depth C-5n - 0.0 C-2 57 SPP (psi) Gallons/stroke TFABit Type Depth -- L-80 MBT 18410' pH 0.499 0 29 0 Siltst 10.75'' - - Units* Casing Summary Lithology (%) 5 30 670 0 907-670-4906Unit Phone: 39 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' Hydril 563 585 0 Cly 4058 . . * 24 hr Recap: Hydril 563 0 0 Cly 17 Set AtSize 62.5 R3 Grade L-8011980' 16" 7.63'' 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers: Hilary Garney, Macy Williams 30 9 0 10.75'' - - Units* Casing Summary Lithology (%) 0 L-80 MBT 18410' pH 0.499 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -- C-5n - 0.0 C-2 10 in 0 -Minimum Depth Time: slotted liner to 6501' MD, M/U baker seal bore assembly. C/O elevators P/U 4"DP and continue TIH. 4 19 BBLs loss in 24 hour period. 18410' 18410' 0' Max @ ft Current -- Date: Avg to11895' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) Dave Coates/Bob Finkbiner ShClyst TuffGvlCoal cP - 3544' 6.75 0.383 Footage 6425' 47.70 11985' 8331' Ss (ppb Eq) C-1 C-5i AK-AM-902499586 TIH w/ Liner PV 24 hr Max 45.5 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) - 000 38.0 6.75" PDC Brine - 11985' 18410'- 18410' Depth in / out Mud Type Lst 70 Hydril 563 Type Average --Background Trip -- Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools PeriScope, MicroScope, ImPulse, SonicScope, adnVISION API FL Chromatograph (ppm) 32.493'3654' WOB Conductor 100% Gas In Air=10,000 Units-Connection 0 3 3640' 109' Condition 1-1-WT-A-E-1-NO-TD Bit # 1 - 13.5 11.60 13 1/2" VM-3 Milled Tooth 11.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 31 Customer: Well: Area: Location: Rig: 2S-02 Conoco Phillips Kuparuk Alaska Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Jul-2015 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l 285000.00 Continued to POOH from 4043' MD to 440' MD. Monitored well, static. L/D BHA per SLB. Test Annular. R/U to run Density (ppg) out (sec/qt) Viscosity Cor Solids % 20 96 0-0-NO-A-X-I-NO-TD29 7/8 PDC 9.875 0.710 73.20 3654' WELL INFORMATION Created On : Jul 30 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-02 Job Number :AK-XX-0902499586 Rig Name :Doyon 141 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 79.33 0.22 264.90 79.33 0.01 S 0.10 W -0.03 0.42 104.97 0.18 264.90 104.97 0.02 S 0.19 W -0.05 0.16 201.82 0.28 264.90 201.82 0.05 S 0.58 W -0.16 0.10 293.09 1.07 157.53 293.08 0.86 S 0.47 W -0.93 1.30 384.26 3.66 146.85 384.17 4.08 S 1.45 E -3.73 2.87 476.47 6.34 145.93 476.02 10.76 S 5.91 E -9.44 2.91 567.55 5.97 145.89 566.57 18.85 S 11.38 E -16.33 0.41 659.98 7.27 139.59 658.39 27.29 S 17.87 E -23.37 1.61 752.38 8.71 141.01 749.89 37.18 S 26.06 E -31.52 1.57 845.09 9.73 140.31 841.40 48.66 S 35.48 E -41.00 1.11 938.89 10.68 143.21 933.71 61.72 S 45.75 E -51.86 1.15 1031.83 12.50 143.30 1,024.76 76.68 S 56.92 E -64.41 1.96 1127.07 16.06 144.48 1,117.04 95.68 S 70.74 E -80.42 3.75 1218.14 17.24 144.24 1,204.29 116.88 S 85.94 E -98.33 1.30 1311.27 22.51 148.58 1,291.85 143.31 S 103.31 E -120.97 5.87 1404.33 25.25 148.70 1,376.93 175.48 S 122.91 E -148.80 2.94 1496.94 25.18 149.30 1,460.72 209.30 S 143.23 E -178.12 0.29 1590.92 26.52 150.42 1,545.29 244.74 S 163.80 E -208.99 1.52 1683.02 28.77 149.69 1,626.87 281.76 S 185.14 E -241.25 2.47 1776.78 30.32 149.47 1,708.44 321.62 S 208.55 E -275.92 1.66 1870.07 32.51 148.39 1,788.05 363.26 S 233.65 E -312.00 2.42 1917.29 34.22 149.35 1,827.48 385.49 S 247.07 E -331.27 3.79 1963.14 38.74 150.89 1,864.34 409.13 S 260.63 E -351.88 10.06 2008.07 40.31 150.65 1,899.00 434.08 S 274.60 E -373.71 3.51 2055.84 39.97 150.56 1,935.52 460.91 S 289.71 E -397.17 0.72 2150.11 41.79 151.87 2,006.79 514.99 S 319.41 E -444.58 2.13 2242.85 46.57 154.41 2,073.29 572.65 S 348.54 E -495.62 5.50 2286.63 48.32 156.29 2,102.89 601.96 S 361.98 E -521.83 5.10 INSITE V8.3.0 Page 1Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2335.33 49.78 156.21 2,134.81 635.63 S 376.80 E -552.05 3.00 2428.08 53.30 158.80 2,192.50 702.72 S 404.54 E -612.62 4.38 2521.26 57.96 160.39 2,245.09 774.79 S 431.32 E -678.26 5.20 2569.60 59.50 161.11 2,270.18 813.80 S 444.94 E -713.95 3.43 2613.01 61.40 161.94 2,291.59 849.62 S 456.90 E -746.83 4.68 2705.53 62.56 161.79 2,335.05 927.23 S 482.32 E -818.17 1.26 2798.27 65.76 161.39 2,375.47 1,006.42 S 508.68 E -890.86 3.47 2891.22 67.27 161.00 2,412.51 1,087.11 S 536.16 E -964.84 1.67 2984.44 69.93 162.04 2,446.52 1,169.42 S 563.67 E -1040.39 3.04 3078.50 71.80 159.42 2,477.35 1,253.29 S 593.00 E -1117.12 3.30 3172.25 70.97 160.32 2,507.28 1,336.71 S 623.58 E -1193.17 1.27 3264.83 72.52 159.74 2,536.28 1,419.34 S 653.60 E -1268.55 1.78 3358.77 72.44 159.49 2,564.56 1,503.31 S 684.81 E -1345.02 0.27 3451.37 72.53 160.02 2,592.43 1,586.16 S 715.36 E -1420.52 0.55 3546.33 71.19 159.61 2,621.99 1,670.86 S 746.50 E -1497.72 1.47 3578.11 71.31 159.61 2,632.21 1,699.07 S 756.99 E -1523.41 0.38 3648.89 71.09 159.61 2,655.02 1,761.87 S 780.33 E -1580.61 0.31 3742.01 71.53 159.61 2,684.86 1,844.55 S 811.06 E -1655.91 0.47 3834.63 71.74 159.89 2,714.04 1,927.02 S 841.49 E -1731.06 0.37 3928.68 70.66 158.64 2,744.35 2,010.29 S 873.00 E -1806.77 1.70 4021.82 70.21 157.67 2,775.54 2,091.75 S 905.66 E -1880.51 1.09 4116.49 70.22 157.64 2,807.59 2,174.14 S 939.53 E -1954.92 0.03 4208.85 70.08 157.94 2,838.95 2,254.57 S 972.36 E -2027.61 0.34 4301.47 70.19 158.12 2,870.42 2,335.35 S 1,004.95 E -2100.69 0.22 4395.70 70.15 158.11 2,902.39 2,417.60 S 1,038.00 E -2175.13 0.04 4490.64 67.56 160.37 2,936.63 2,500.38 S 1,069.39 E -2250.39 3.52 4582.81 62.88 164.08 2,975.27 2,580.01 S 1,094.97 E -2323.68 6.25 4630.09 60.60 165.42 2,997.65 2,620.19 S 1,105.93 E -2361.02 5.43 4676.10 58.54 167.88 3,020.96 2,658.78 S 1,115.10 E -2397.16 6.43 4725.53 59.59 166.29 3,046.37 2,700.10 S 1,124.58 E -2435.91 3.48 4772.57 61.65 164.84 3,069.45 2,739.79 S 1,134.80 E -2472.92 5.14 4864.70 65.99 161.23 3,110.09 2,818.82 S 1,158.96 E -2545.89 5.88 4900.29 66.83 160.26 3,124.34 2,849.61 S 1,169.72 E -2574.06 3.44 4958.75 68.93 159.28 3,146.35 2,900.42 S 1,188.44 E -2620.37 3.91 5053.27 71.58 158.24 3,178.28 2,983.33 S 1,220.68 E -2695.60 2.99 5145.24 73.20 158.71 3,206.10 3,064.88 S 1,252.84 E -2769.51 1.83 5239.23 73.24 158.10 3,233.24 3,148.55 S 1,285.96 E -2845.33 0.62 5333.60 72.65 158.08 3,260.92 3,232.25 S 1,319.62 E -2921.07 0.63 5426.03 72.23 157.84 3,288.80 3,313.93 S 1,352.69 E -2994.94 0.52 5518.53 71.93 157.99 3,317.26 3,395.49 S 1,385.78 E -3068.68 0.36 5612.19 72.30 159.66 3,346.03 3,478.60 S 1,417.97 E -3144.13 1.74 5705.92 72.76 160.94 3,374.17 3,562.77 S 1,448.11 E -3221.00 1.39 5797.08 72.74 161.57 3,401.20 3,645.21 S 1,476.09 E -3296.59 0.66 5891.34 72.85 161.49 3,429.08 3,730.62 S 1,504.61 E -3374.98 0.14 5984.46 72.80 161.75 3,456.58 3,815.05 S 1,532.67 E -3452.51 0.27 INSITE V8.3.0 Page 2Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6079.38 73.01 161.81 3,484.48 3,901.22 S 1,561.03 E -3531.69 0.23 6171.92 73.48 161.79 3,511.16 3,985.40 S 1,588.71 E -3609.04 0.51 6264.70 73.23 163.38 3,537.74 4,070.22 S 1,615.32 E -3687.22 1.66 6357.62 72.81 164.24 3,564.87 4,155.56 S 1,640.09 E -3766.26 0.99 6452.00 71.09 165.34 3,594.12 4,242.14 S 1,663.64 E -3846.77 2.13 6546.56 70.82 164.30 3,624.97 4,328.41 S 1,687.04 E -3926.98 1.08 6639.39 71.21 163.09 3,655.17 4,412.66 S 1,711.69 E -4004.98 1.30 6733.34 71.59 162.16 3,685.14 4,497.63 S 1,738.28 E -4083.32 1.02 6825.99 71.56 160.77 3,714.42 4,580.97 S 1,766.22 E -4159.80 1.42 6919.67 71.13 160.08 3,744.39 4,664.60 S 1,795.96 E -4236.21 0.84 7012.84 70.59 159.36 3,774.94 4,747.16 S 1,826.47 E -4311.44 0.93 7106.80 69.91 158.28 3,806.69 4,829.62 S 1,858.41 E -4386.29 1.30 7199.18 69.17 156.41 3,838.98 4,909.49 S 1,891.75 E -4458.33 2.06 7244.76 69.03 154.84 3,855.25 4,948.28 S 1,909.32 E -4493.05 3.23 7291.38 68.76 153.04 3,872.03 4,987.35 S 1,928.42 E -4527.75 3.65 7383.77 68.23 150.58 3,905.91 5,063.10 S 1,969.02 E -4594.37 2.54 7432.28 67.46 150.46 3,924.20 5,102.21 S 1,991.13 E -4628.54 1.60 7476.60 66.79 148.64 3,941.43 5,137.41 S 2,011.83 E -4659.15 4.07 7523.30 65.95 148.04 3,960.15 5,173.83 S 2,034.28 E -4690.61 2.15 7569.49 64.77 146.66 3,979.41 5,209.18 S 2,056.93 E -4720.99 3.73 7661.87 62.68 144.63 4,020.30 5,277.56 S 2,103.66 E -4779.20 3.00 7708.63 61.42 143.44 4,042.22 5,311.00 S 2,127.91 E -4807.39 3.51 7754.64 60.43 143.18 4,064.58 5,343.24 S 2,151.94 E -4834.46 2.21 7847.12 58.64 141.38 4,111.47 5,406.29 S 2,200.69 E -4887.05 2.56 7941.74 57.14 140.05 4,161.76 5,468.33 S 2,251.43 E -4938.27 1.98 8033.51 55.79 138.38 4,212.46 5,526.25 S 2,301.39 E -4985.59 2.11 8126.93 54.30 137.04 4,265.98 5,582.89 S 2,352.90 E -5031.36 1.98 8219.65 54.14 135.68 4,320.20 5,637.33 S 2,404.81 E -5074.89 1.20 8311.71 53.98 133.46 4,374.23 5,689.63 S 2,457.90 E -5116.10 1.96 8405.19 54.41 131.05 4,428.93 5,740.60 S 2,514.01 E -5155.43 2.14 8498.51 55.01 129.12 4,482.84 5,789.64 S 2,572.29 E -5192.45 1.81 8589.66 55.80 126.01 4,534.60 5,835.37 S 2,631.75 E -5225.99 2.94 8683.20 56.08 124.26 4,587.00 5,879.96 S 2,695.13 E -5257.67 1.58 8776.27 55.77 122.48 4,639.14 5,922.36 S 2,759.50 E -5287.01 1.62 8871.20 55.23 119.36 4,692.92 5,962.56 S 2,826.60 E -5313.67 2.77 8964.80 55.26 115.26 4,746.29 5,997.83 S 2,894.91 E -5335.26 3.60 9058.92 54.33 110.96 4,800.57 6,028.02 S 2,965.60 E -5351.40 3.86 9151.26 53.08 107.55 4,855.24 6,052.57 S 3,035.84 E -5362.10 3.27 9244.59 51.90 103.86 4,912.08 6,072.62 S 3,107.08 E -5368.19 3.38 9339.64 51.68 101.01 4,970.88 6,088.70 S 3,180.00 E -5370.06 2.37 9433.65 52.18 96.95 5,028.87 6,100.24 S 3,253.08 E -5367.45 3.44 9527.85 52.70 93.07 5,086.30 6,106.75 S 3,327.44 E -5359.65 3.31 9622.63 53.06 89.50 5,143.51 6,108.44 S 3,402.98 E -5346.89 3.03 9714.35 53.01 86.72 5,198.67 6,106.03 S 3,476.21 E -5330.55 2.42 9807.43 52.81 82.83 5,254.82 6,099.27 S 3,550.13 E -5309.81 3.34 INSITE V8.3.0 Page 3Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 9900.31 52.10 79.93 5,311.43 6,088.24 S 3,622.92 E -5285.10 2.59 9993.05 51.94 77.10 5,368.51 6,073.69 S 3,694.55 E -5257.15 2.41 10084.97 52.38 74.60 5,424.90 6,055.94 S 3,764.93 E -5226.30 2.20 10177.14 52.85 71.05 5,480.87 6,034.32 S 3,834.87 E -5191.72 3.10 10270.67 53.68 68.96 5,536.82 6,008.68 S 3,905.30 E -5153.12 2.00 10363.78 54.22 67.13 5,591.62 5,980.54 S 3,975.12 E -5112.17 1.69 10458.74 55.60 65.62 5,646.21 5,949.39 S 4,046.30 E -5068.02 1.95 10552.81 57.15 64.24 5,698.30 5,916.20 S 4,117.24 E -5021.89 2.05 10645.30 59.32 63.18 5,746.99 5,881.36 S 4,187.73 E -4974.25 2.54 10738.02 60.40 61.18 5,793.54 5,843.94 S 4,258.64 E -4923.98 2.20 10829.90 61.81 59.02 5,837.94 5,803.83 S 4,328.36 E -4871.31 2.57 10922.36 63.14 56.63 5,880.68 5,760.17 S 4,397.75 E -4815.21 2.71 11015.52 64.31 54.14 5,921.92 5,712.71 S 4,466.48 E -4755.51 2.71 11108.81 65.52 51.16 5,961.48 5,661.45 S 4,533.63 E -4692.38 3.17 11200.77 65.87 48.49 5,999.34 5,607.39 S 4,597.66 E -4627.09 2.67 11294.57 66.41 45.46 6,037.29 5,548.87 S 4,660.36 E -4557.68 3.01 11392.75 67.00 43.08 6,076.12 5,484.30 S 4,723.29 E -4482.29 2.31 11480.49 66.94 40.75 6,110.45 5,424.22 S 4,777.23 E -4413.02 2.44 11573.13 67.76 38.17 6,146.13 5,358.21 S 4,831.55 E -4337.86 2.72 11666.15 69.27 36.07 6,180.20 5,289.20 S 4,883.78 E -4260.15 2.65 11760.11 71.22 34.01 6,211.96 5,216.80 S 4,934.54 E -4179.40 2.93 11853.07 73.37 32.41 6,240.23 5,142.71 S 4,983.03 E -4097.42 2.83 11912.22 74.51 31.42 6,256.59 5,094.46 S 5,013.08 E -4044.32 2.51 11985.00 76.00 30.00 6,275.12 5,033.95 S 5,049.02 E -3978.06 2.78 12041.60 76.56 29.07 6,288.54 4,986.11 S 5,076.12 E -3925.93 1.88 12085.66 77.20 27.48 6,298.54 4,948.32 S 5,096.45 E -3884.96 3.80 12180.07 78.74 25.19 6,318.22 4,865.57 S 5,137.40 E -3795.92 2.88 12273.61 80.14 25.31 6,335.36 4,782.41 S 5,176.62 E -3706.79 1.50 12366.85 81.43 24.30 6,350.30 4,698.86 S 5,215.23 E -3617.42 1.75 12462.43 82.98 21.76 6,363.26 4,611.72 S 5,252.27 E -3524.81 3.09 12558.53 86.12 17.25 6,372.39 4,521.58 S 5,284.19 E -3430.23 5.70 12652.45 89.07 15.22 6,376.33 4,431.50 S 5,310.42 E -3336.80 3.81 12748.08 91.40 14.84 6,375.94 4,339.14 S 5,335.22 E -3241.42 2.47 12840.91 90.82 13.15 6,374.14 4,249.09 S 5,357.66 E -3148.73 1.92 12936.69 90.24 11.46 6,373.26 4,155.52 S 5,378.07 E -3052.99 1.87 13031.39 91.02 10.68 6,372.22 4,062.59 S 5,396.25 E -2958.29 1.16 13125.78 89.79 10.35 6,371.55 3,969.79 S 5,413.48 E -2863.91 1.35 13217.62 91.23 9.38 6,370.73 3,879.31 S 5,429.21 E -2772.10 1.89 13313.95 90.51 9.19 6,369.27 3,784.26 S 5,444.75 E -2675.82 0.77 13408.13 91.40 8.21 6,367.70 3,691.17 S 5,459.00 E -2581.73 1.41 13501.25 91.16 8.76 6,365.62 3,599.10 S 5,472.73 E -2488.73 0.64 13597.30 90.78 8.55 6,363.99 3,504.15 S 5,487.19 E -2392.77 0.45 13692.32 91.13 9.24 6,362.41 3,410.29 S 5,501.88 E -2297.83 0.81 13787.60 90.13 9.77 6,361.36 3,316.33 S 5,517.61 E -2202.59 1.19 13881.69 90.72 9.56 6,360.66 3,223.58 S 5,533.40 E -2108.53 0.67 INSITE V8.3.0 Page 4Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13975.95 91.64 9.63 6,358.72 3,130.65 S 5,549.11 E -2014.32 0.98 14070.90 92.19 9.53 6,355.55 3,037.08 S 5,564.91 E -1919.45 0.59 14165.40 92.19 9.91 6,351.94 2,944.01 S 5,580.85 E -1825.04 0.40 14260.57 91.85 10.72 6,348.58 2,850.43 S 5,597.88 E -1729.94 0.92 14355.12 90.85 12.42 6,346.36 2,757.83 S 5,616.84 E -1635.42 2.09 14450.54 91.47 12.88 6,344.42 2,664.75 S 5,637.73 E -1540.06 0.81 14542.74 91.33 13.52 6,342.17 2,575.01 S 5,658.78 E -1447.96 0.71 14637.09 91.71 13.26 6,339.67 2,483.26 S 5,680.62 E -1353.72 0.49 14729.99 90.51 13.64 6,337.87 2,392.93 S 5,702.22 E -1260.93 1.35 14825.07 90.27 14.86 6,337.22 2,300.78 S 5,725.62 E -1166.01 1.31 14918.24 89.52 14.90 6,337.39 2,210.73 S 5,749.55 E -1073.05 0.81 15012.99 91.03 16.78 6,336.94 2,119.59 S 5,775.41 E -978.65 2.54 15109.46 88.90 21.76 6,337.00 2,028.56 S 5,807.24 E -883.21 5.61 15155.64 88.11 24.18 6,338.20 1,986.06 S 5,825.25 E -838.06 5.51 15203.05 87.35 26.97 6,340.08 1,943.33 S 5,845.70 E -792.21 6.09 15266.54 86.87 26.23 6,343.28 1,886.63 S 5,874.09 E -731.14 1.39 15296.93 87.70 25.20 6,344.72 1,859.28 S 5,887.26 E -701.78 4.35 15390.37 90.48 24.86 6,346.20 1,774.64 S 5,926.78 E -611.15 3.00 15485.53 89.69 24.10 6,346.06 1,688.03 S 5,966.22 E -518.61 1.15 15580.57 88.86 23.30 6,347.27 1,601.02 S 6,004.41 E -425.91 1.21 15675.57 88.07 21.88 6,349.81 1,513.34 S 6,040.89 E -332.88 1.71 15724.65 88.90 21.05 6,351.11 1,467.68 S 6,058.85 E -284.63 2.39 15767.01 87.77 20.51 6,352.34 1,428.10 S 6,073.87 E -242.91 2.96 15864.87 87.80 19.71 6,356.12 1,336.27 S 6,107.49 E -146.36 0.82 15959.89 87.63 18.46 6,359.91 1,246.55 S 6,138.53 E -52.36 1.33 16052.49 86.53 17.03 6,364.63 1,158.47 S 6,166.72 E 39.48 1.95 16146.49 87.73 16.09 6,369.33 1,068.49 S 6,193.47 E 132.92 1.62 16240.28 85.26 13.37 6,375.07 977.96 S 6,217.28 E 226.32 3.91 16334.34 85.81 9.20 6,382.39 886.02 S 6,235.62 E 320.07 4.46 16430.14 90.27 6.73 6,385.67 791.23 S 6,248.88 E 415.65 5.32 16476.84 91.40 7.43 6,384.99 744.90 S 6,254.64 E 462.23 2.85 16524.03 91.85 8.11 6,383.65 698.16 S 6,261.01 E 509.33 1.73 16619.23 91.23 12.13 6,381.09 604.49 S 6,277.73 E 604.46 4.27 16714.90 90.92 13.86 6,379.30 511.29 S 6,299.24 E 700.05 1.84 16807.93 89.24 16.12 6,379.17 421.44 S 6,323.30 E 792.85 3.03 16903.20 91.23 16.28 6,378.78 329.96 S 6,349.88 E 887.72 2.10 16997.43 91.57 15.16 6,376.47 239.28 S 6,375.40 E 981.60 1.24 17090.93 92.88 13.95 6,372.84 148.85 S 6,398.88 E 1074.85 1.91 17185.76 93.47 14.55 6,367.59 57.08 S 6,422.19 E 1169.38 0.89 17281.26 92.89 13.76 6,362.29 35.38 N 6,445.50 E 1264.59 1.03 17376.53 90.30 13.48 6,359.64 127.92 N 6,467.93 E 1359.71 2.73 17470.54 88.45 14.53 6,360.67 219.13 N 6,490.68 E 1453.58 2.26 17566.45 87.79 10.85 6,363.82 312.63 N 6,511.73 E 1549.38 3.90 17659.47 92.74 9.04 6,363.39 404.22 N 6,527.79 E 1642.35 5.67 17754.57 92.40 9.19 6,359.12 498.02 N 6,542.84 E 1737.30 0.39 INSITE V8.3.0 Page 5Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 17849.50 92.77 8.66 6,354.84 591.71 N 6,557.55 E 1832.07 0.68 17942.67 92.88 8.82 6,350.25 683.68 N 6,571.69 E 1925.06 0.21 18038.13 92.09 10.28 6,346.11 777.73 N 6,587.52 E 2020.39 1.74 18131.74 91.78 9.35 6,342.95 869.91 N 6,603.46 E 2113.93 1.05 18226.54 92.19 9.48 6,339.67 963.38 N 6,618.96 E 2208.64 0.45 18322.24 93.50 8.80 6,334.92 1,057.75 N 6,634.14 E 2304.17 1.54 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 11.00 degrees (Grid) - A total correction of 18.77 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 18,322.24 feet is 6,717.94 feet along 80.94 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 6Job No:AK-XX-0902499586 Well Name:2S-02 Survey Report
