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HomeMy WebLinkAbout215-094MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2H-14A KUPARUK RIV UNIT 2H-14A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 2H-14A 50-103-20036-01-00 215-094-0 W SPT 5914 2150940 3000 1580 1580 1580 1580 46 48 47 48 REQVAR P Sully Sullivan 8/18/2025 MIT-IA to MAIP 3000 psi per AIO. 2c.081 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 2H-14A Inspection Date: Tubing OA Packer Depth 980 3300 3230 3210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251021132516 BBL Pumped:2 BBL Returned:2 Wednesday, October 22, 2025 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF2 Subject:10-426 forms for 2H PAD ONLINE and SHUT IN MITIA"s 5-7-24 Date:Wednesday, May 8, 2024 10:10:38 AM Attachments:image001.png MIT KRU 2H-2,14A and 17 SI TESTS 05-07-24.xlsx MIT KRU 2H PAD 05-07-24.xlsx Good morning, Please see the attached 10-426 forms from the AOGCC witnessed MITIA’s that were performed on 5-7-24. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com KRU 2H-14A PTD 2150940 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1840730 Type Inj N Tubing 1810 1810 1810 1810 Type Test P Packer TVD 5904 BBL Pump 2.6 IA 330 3310 3250 3240 Interval V Test psi 3000 BBL Return 2.5 OA 20 20 20 20 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2150940 Type Inj N Tubing 1825 1825 1825 1825 Type Test P Packer TVD 5914 BBL Pump 2.7 IA 550 3300 3240 3220 Interval V Test psi 3000 BBL Return 2.6 OA 10 10 10 10 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2000190 Type Inj N Tubing 2300 2300 2300 2300 Type Test P Packer TVD 5978 BBL Pump 1.0 IA 650 3000 2960 2940 Interval 4 Test psi 1500 BBL Return 1.0 OA 140 150 150 150 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to MAIP per AIO 2C.071 Notes: 2H-02 2H-14A Notes:MITIA to MAIP per AIO 2C.081 2H-17 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2H Pad Casey / Hills 05/07/24 Form 10-426 (Revised 01/2017)2024-0507_MIT_KRU_2H-pad_3wells         J. Regg; 5/17/2024 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2H-14A KUPARUK RIV UNIT 2H-14A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 2H-14A 50-103-20036-01-00 215-094-0 W SPT 5914 2150940 3000 2050 2050 2050 2050 30 30 30 30 REQVAR P Lou Laubenstein 6/26/2022 MIT-IA to maximum anticipated injection pressure per AIO 2C.081 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 2H-14A Inspection Date: Tubing OA Packer Depth 1090 3320 3260 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220626140340 BBL Pumped:3.3 BBL Returned:3.3 Thursday, July 21, 2022 Page 1 of 1         CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Well Integrity Specialist CPF2 To:Regg, James B (OGC);Wallace, Chris D (OGC);Brooks, Phoebe L (OGC);DOA AOGCC Prudhoe Bay Subject:CPAI 10-426 forms for shut-in MIT-IAs Date:Tuesday, May 3, 2022 2:40:42 PM Attachments:image001.png MIT KRU 2H-014A SI TEST 05-02-22.xlsx MIT KRU 1J-170 SI TEST 05-01-22.xlsx All- Attached are the 10-426 forms for the MIT-IAs that were non-witnessed due to the wells being shut in. Please let me know if you have any questions or concerns. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 .58+$ 37' Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2150940 Type Inj N Tubing 2075 2075 2075 2075 Type Test P Packer TVD 5914 BBL Pump 2.8 IA 230 3300 3230 3210 Interval V Test psi 3000 BBL Return 2.8 OA 20 20 20 20 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al In t eg r ity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 2C.081 Notes: 2H-14A Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2H Pad waived Miller 05/02/22 Form 10-426 (Revised 01/2017)2022-0502_MIT_KRU_2H-14A 9 9 9 9 9 9 9 -5HJJ Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, November 27, 2020 7:42 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: 21-1-14A (PTD 215-094) Report of Failed MITOA Attachments: 2H-14A.pdf, 21-1-14 90 day TIO trend 11.27.20.pdf Chris, 2H -14A (PTD 215-094) Failed a diagnostic MITOA today, but the well passed a diagnostic MITIA proving the tubing and production casing as barriers. CPAI plans to leave the well online to continue diagnostics tomorrow including a Surface Casing Leak Detect after which the well will be shut in and freeze protected. The proper paperwork for continued injection or corrective action will be submitted once a plan forward has been developed. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 MEMORANDUM To: Jim Regg P.1. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 21-1-14A Insp Num: mitBDB200506060503 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 7, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2H -14A KUPARUKRIV UNIT2H-14A Src: Inspector Reviewed By: P.I. Supry J`13C- Comm API Well Number 50-103-20036-01-00 Inspector Name: Brian Bixby Permit Number: 215-094-0 Inspection Date: 5/3/2020 ✓ Packer Well 2H -14A Type Inj w I I TVD - _ -_- a Test] Type SPT Test psi BBPumped940, L 2T_ 11143L Returned: Intervall 4YRTST P/Ii Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5914 Tubing 2290 1 2290 2290- I 22904—" 1500 IA 450 3000 - 2940 2920 ' —I - - 2.3 OA 50 50 j 50 50 P ✓ -- -- Thursday, May 7, 2020 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 11,2016 TO: Jim Regg 6125((co t P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2H-14A FROM: Lou Grimaldi KUPARUK RIV UNIT 2H-14A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, :/- - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2H-14A API Well Number 50-103-20036-01-00 Inspector Name: Lou Grimaldi Permit Number: 215-094-0 Inspection Date: 5/10/2016 Insp Num: mitLG160510152116 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2H-14A - Type Inj W-TVD 5914 - Tubing 2500 - 2500 , 2500 - 2500 - PTD 2150940 - Type Test SPT Test psi 1500 IA 155 1820 - 1770 - 1760 - Interval 4YRTST P/F P tr OA 70 - 75 75 75- Notes: Pumped 1.6 bbl's diesel, 1.9 bbl's returned.All required paperwork available on location.Good test. - SCANNED SEP 2 128 6 Wednesday,May 1 I,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r"? DATE: Friday,August 21,2015 P.I.Supervisor ���/�i �� 11 5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2H-14A FROM: John Crisp KUPARUK RIV UNIT 2H-14A Petroleum Inspector Src: Inspector Reviewed By:: P.I.Supry.J&--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2H-14AAPI Well Number 50-103-20036-01-00 Inspector Name: John Crisp Permit Number: 215-094-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821095721 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2H-14A - Type Inj "-1TVD 1 5914 - Tubing 2350 . 2375 - 2375 - 2360 - PTD 2150940 Type Test SPT Test psi 1500 IA 1580 3200 - 3150 - 3130 Interval INITAL - P/F P ,/ OA 125 125 125 125 - Notes: 1.9 bbls pumped for test. SCANNED : . , : Friday,August 21,2015 Page 1 of 1 • • 9 ! o r 1 a . , [J G N 2E O • N ) ❑ O Q a p N } Q a) • O 0 J -o m > V o ct p U a) co >, >, O O (a "O -o (O T >, U = TP: a) a) .- .- J J a a LL a) a) >. 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W 0 H N IIS d N Ta. of 1 a' p C ` E 6 > E E Z aai N Y W c Er 0 0 O aa) Z Q o g Q o 0 0 c U U U U U U U p a3 m a y w a as E 0 rn V O E o O I g E a3 " E E co 4 a 2 OW W OW WW W .° z 0 a C0 0 0 a C 0 0 • • Brooks, Phoebe L (DOA) Mit -v w-I From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, September 08, 2015 9:44 AM To: Brooks, Phoebe L(DOA) Subject: RE: Recent KRU SW MIT-IAs Attachments: 2H-14A.pdf Phoebe, 2H-14A schematic is attached. Regards, Jan From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooksOalaska.gov] Sent: Tuesday, September 08, 2015 9:29 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Recent KRU SW MIT-IAs Jan/Dusty, Will you send me the schematic for 2H-14A? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, August 16, 2015 4:24 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: Recent KRU SW MIT-IAs Jim, Attached are recently performed SW MIT-lAs for 2H and 3G pads. Regards, 1 .> KUP INJ 2H-14A ConocoPhillipsn ;,:.!.„4,:',44 Well Attributes III Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(fIKO) Act Sim(ttKB) � yg1 501032003601 KUPARUK RIVER UNIT INJ J 101.46 8,875.49 11,478.0 ••• u, Comment H25(ppm) Date Annotation End Date KB•Grd(ft) Rlg Release Date 2H-14A 8/72015 2.03:40 PM SSSV:LOCKED OUT 63 12/30/2012 Last WO: 34.51 7/18/1984 Vertical schematic(actual) `Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD SIDETRACK.ADD LATERAL smsmith 8/6/2015 HANGER:23.7- R, /,', I (off sidetrack A) Casing Strings Casing Descrlptlon OD(In) ID(In) lop(NKR) Set Depth(5KB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 (5.062 30.0 110.0 110.0 62.50(440 WELDED Casing Descrlptlon OD(In) ID(in) Top MKS) Sri Depth(ftK8) Set Depth(ND)...WULen(I...Grade Top Thread SURFACE 95/8 8.921 30.0 2,838.9 2,497.2 36.00 J-55 BTC Casing Descrlptlon OD(in) ID(in) Top(ftK8) Del Depth(ftK8) Set Depth ITVDF.,WBLen p...Grade Top Thread ` PRODUCTION 7 6.276 28.6 8,842.4 6,176.4 26.00 J-55 BTC e a 811Or Casing Descrlptlon OD(In) ID(in) Top(HKB) Set Depth(ftK6) Set Depth(TVD)..WULen(I...Grade Top Thread LINER-RWO 2015 41/2 4.000 8.316.9 8.716.0 6,182.9 11.60 L-80 BTCM Liner Details li G Nominal ID Top(ftK8) Top(ND)(ftK8) Top Incl(°) Sem Das Com (In) M7CONDUCTOR:300-itO.OdI4M1 ter.,, 8,316.9 5,969.9 44.72 PACKER BAKER ZXP LINER TOP PACKER 4.330 8,336.5 5,983.8 44.64 HANGER BAKER FLEX LOCK LINER HANGER 4.240 8,352.4 5,995.1 44.58 SBE 8040 SBE 4.000 Casing Description 100(In) IID(In) Top(ttKB) I8e1 Depth(ftK8) I Set Depth(TVD)...I WULen(I...I Grade Top Thread A LINER 2 3/8 1.920 9.217 3 11.478.0 4.60 L-80 STL SURFACE:90.1-2,838,9-a • Liner Details - - - - Nominal ID Top(ttKB) Top(ND)(11KB) Top I eel(°) Item Des Com (in) 9.217.3 6,135.9 93.06 BILLET BAKER OPEN HOLE ANCHORED ALUMINUM 0.000 DEPLOY VLV;3.505.8 • LINER TOP BILLET 4 9,259.4' 6.134.3 90.49 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 4 Tubing Strings Tubing Deeorlptlon String Ma...ID(In) ITop MKS) Set Depth(ft..J Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection ,... TUBING-UPPER- 31/2 2.992 23.7 8,232.41 5,910.1 9.30 L-80 EUE BRd GAS LIFT,8,154.0 R W O 2015 Completion Details Nominal ID Top(ftK8) Top(TVD)(ttKB) Top Incl(°) Item Dea Com (In) 11 23.7 23.7 0.00 HANGER FMC GEN V HANGER 2.992 LOCATOR;8.209.7iii 3,505.6 2,891.7 52.77 DEPLOY VLV BAKER ORBIT DEPLOYMENT VALVE 2.910 8,209.7 5,894.1 45.40 LOCATOR BAKER GBH-22 LOCATOR SUB 2.992 SEAL ASSY;8,210 7.-, 8,210.7 5,894.8 45.40 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.992 PBR.8.215.5 - - I Tubing Description String Ma...ID(In) Top(NKB) Set Depth(It..JSet Depth(TVD)(...Wt(Ib/R) Grade Top Connection l�ri_,..yaIQ4 TUBING-LOWER 31/2 2.992 8,215.5 8,367.01 6,005.5 9.30 L-80 EUE Eird Mod PACKER.8.238.6 RWO 2015 Completion Details at a. Nominal ID Top MKS) Top(TVD)(ftK8) Top Incl(°) Item Des Com (In) 11 8,215.5 5,898.2 45.36 PBR 80-40 PBR(20) 4.000 am NIPPLE;8,284.0 ee 8,238.6 5,914.4 45.20 PACKER BAKER 4782 FHL PACKER 2.950 ame 8,284.0 5,946.5 44.89 NIPPLE HSE 2.813"'X'NIPPLE 2.813 8,324.3 5,975.1 44.69 LOCATOR 80-40 GBH-22 LOCATOR SUB 2.980 8,325.5 5,975.9 44.68 SEAL ASSY 80-40 001-1-22 SEAL ASSEMBLY 2.992 l' F Perforations&Slots LOCATOR:8.324.7 --- Shot y Dena a '°- Top(ND) Bim(TVD) (shots!( r M.A Top(ttKB) Btm(ttKB) (HKB) (508) Zone Date 1) Type Com SEAL ASSY;9,323< 9.229.1 9,259.0 8,135.3 6,134.3 A-3,2H-14 7/16/2015 SLOTS Slotted Liner a:ii �. 9,260.2 11,477.6 6,134.3 6,094.0 A-3,2H-14 7/16/2015 SLOTS Slotted Liner Mandrel Inserts s rpt al Top(TVD) Valve Latch Pon Size TRO Run �+� -1.11.' Top(ttKB) (ftK8) Make Model 00 (In) Solo Type Type (In) (psi) Run Date Com IPERF'.8,450.0-8,476.0- � 1 8,154.0 5,855.1 CAMCO MMG 1)l2 GAS LIFT DMY RKP 0.000 0.0 5/18/2015 DCR- 4. ♦• 1 :.`q �e Notes:General&Safety _y, I` IPERF.8.508.0-8519.0- �4ry .r End Date Annotation -..ti' 't R4 NOTE: E e e.' i '_ LINER-RWO 2015:8,316,O.__..'-'� 8,716.0 ^+ PRODUCTION;20.6-8.842.4 t- SLOTS;6,517.4-10,648 6 ALI LINER;8,516.6-10.650.0 1�1 "-- SLOTS'9229 1-9.259 0 1 g SLOTS,9,200.2-11.477.8 I I A LINER,9,217.3-11,408.0 1 2 • 72 5 9 4 t15p96 _ 6 3 26 164 �~ BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ DATA LOGGED (mandatory) 795 East 94th Avenue g/31/2015 WELL NAME 2H-14A; 14AL1 Anchorage,Alaska 99515 K BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: July 18,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 3trick.rider(@.bakerhuohes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I'KIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. I Attn:Ricky Elgaricio EC E Ivrth ATO 3-344 700 G Street F 1 i;L 7 2 6 Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. . Anchorage,Alaska 99508 Attn:Dodie Stinson ... 3 Chevron/KRU Rep I 1 1 1 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 AUG 2 6 Z li 4%State of Alaska -AOGCC 1 j; 1I 2O PCF, d lin,, Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 I 1 Attn:Sean Clifton i 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 SI*Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 O • j p � o = aaC� F -1; T. ;4v2 2 M 0 N = CD N x x 0 M o � -S c N 0 0 = w = C' I a) U O n ,:m z- -iA V+ rt .• z- a m _ m Z v, tn '< H - CD 0 0 0 0) P. 0 IX C N Xi g 71 w I . IIIII In Ut III IQ di cri CD • S iv ca c r » 0 £ CD CD J £ f o) a o F £ @ ƒ 2 10 CO 2 a K 3 § _ - - - _ _ - - _ * 3 O o In \ k \ % $ ' ( ( . = E f E .. a c _ k E. A .. 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A J 0 O J J CD O OD m N JT0ONC rn 0 0 , N J O (T O. o "" 0 N N N it N N N It Ib E N i M to 0 9•4* o3 m m aD o3 m au"' 7 a Q § g N N N (Nn o (Cn o w m D 9 c 2 . (00 Co N CO r CO V (Cn ITl 3 O A A N I 3 3 0 s ' ' N C N N A r Z N 0 J (T =1 V CO CO N 8 O 0 O II fDNg. (n U, 0 N N (T 0 M • A 4 } o 003 J W CO• OW co N = N a 0 (io 0T -1 - CO (00 A N ". 0 N) CO N) N N N) N) '< 0 °o_ os z o 3 t O = o n m 0 o' cT o W 0 to OM "s1 H� RECEIVE,' • STATE OF ALASKA • AUG 18 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG3CC la.Well Status: Oil Li Gas❑ SPLUG ❑ Other ❑ Abandoned [_ Suspended lb.Well Class: 20AAC 25.105 2oAAc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE• WDSPL❑ No. of Completions: Service ❑✓ • Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: '7/19/2015 215-094 ,, 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360 Anchorage,AK 99510 •7/10/2015 50-103-20036-01 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 110'FSL, 654'FEL,Sec.26,T11N, R8E, UM •7/15/2015 KRU 2H-14A • Top of Productive Interval: 9. KB(ft above MSL): .125' 17. Field/Pool(s): 1480'FSL, 541'FWL, Sec.35,T11N, R8E, UM GL(ft above MSL): .30' Kupuruk River Field/Kuparuk River Oil Poo • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1809'FNL,249'FEL, Sec. 34,T11N, R8E, UM 11478'MD/6094'TVD ADL 25587 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 497745 y- 5948973 Zone- 4 ' 11478'MD/6094'TVD ALK 2673 TPI: x- 493663 y- 5945065 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 492872 y- 5947057 Zone- 4 no SSSV 2754'MD/2445'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) • 8529'MD/6122'TVD • 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 CASINGGRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 30" 110' 30" 110' 24" 172 sx Cold Set II 9.625" 36# J-55 30" 2839' 30" 2497' 12.25" 980 sx AS III,440 sx Class G 7" 26# J-55 29' 8843' 29" 6354' 8.5" 400 sx Class G,250 sx AS 4.5" 11.6# L-80 8317' 8716' 5970' 6259' 6.125" 23 bbls Class G 2.375" 4.6# L-80 9217' 11478' 6135' 6094' 3" slotted liner 24.Open to production or injection? Yes ❑ No Li 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" 8232' 8317'MD/5970'TVD, slotted liner from 9229'-9259'MD/6135'-6134'TVD and 9260'-11478'MD/ 8239'MD/5914'TVD 6134'-6094'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Li "NT Per 20 AAC 25.283(i)(2)attach electronic and printed information f �rsr DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ,,---7I',.r , . none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 8/7/2015 water injector Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 5/2015 LCL 4/Z///c CONTINUED ON PAGE 2 I' t 1311\ Submit ORIGINIAL only . G ZG • 28.CORE DATA Conventional Core Yes ❑ No ❑'. Sidewall Cores: • ❑ 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, li 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 E • Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 2754' 2445' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk A4 8529' 6122' Kuparuk A3 8603' 6162' Kuparuk A3 8875' 6171' Kuparuk A3 10347' 6084' Kuparuk A3 11130' 6078' 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: Jason Burke @ 265-6097 Email: Jason.Burke@_cop.corf or Printed Name: Dan Venhaus Title: CTD Supervising Engineer - , Signature: av Phone: 263-4372 Date: 7- I /-7 - 1 5 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 1 a: 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 ' r KUP INJ • 2H-14A ConoccPhiiIips Well Attributes •Max Angle&MD TD Alaska Inc d Wellbore API/UWI Field Borne Weilbore Status Incl(°) MD(fIKB) Act Etre(ftKB) C- prolimk. 501032003601 KUPAR UK RIVER UNIT INJ 101.46 8,875.49 11;478.0 J ••• Comment H25(ppm) Dale Annotation End Date KB-Grd(ft) Rig Rolm.Date 24-14A.8/7/2015 203 00 PM SSSV:LOCKED OUT 63 12/30/2012 Last WO: 34.51 7/18/1984 Or tical echona o(Bat iaI) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason ADD SIDETRACK ADD LATERAL smsmith 8/6/2015 HANGER,23.7- :WW1 (off Sidetrack A) Casing Strings Casing Deserlptlon OD(In) ID(In) Top(ftKB) Set Depth(ftKE) Set Depth(TVD)... Wt/Len p...Grade Top Thread CONDUCTOR I 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.0 2,838.9 2,497.2 36.00 J-55 BTC. ;). Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread t 111; PRODUCTION 7 6.276 28.6 8,842.4 6,176.4 26.00 3-55: BTC:. ' ' "' ' ` K"" 'Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I..Grade Top Thread LINER-RWO 2015 41/2 4.000 8316.9 8,716.0 6,182.9 11.60 L-80 BTCM Liner Details11411 l;ID Nominal ID I Top(ftKB) Top(TVD)(ftKB( Top Incl('I Item Des Com (In) 8,316.9 5,969.9 44.72 PACKER BAKER ZXP LINER TOP PACKER 4.330 -4,544 CONDUCTOR.300-110.0- v. 8,336.5 5,983.8 44.64 HANGER BAKER FLEX LOCK LINER HANGER 4.240 I8,3524 5,995.1 44.58 SBE 80-40 SBE 4.000 Casing Description I OD(In) IID(in) Top(ftKB) 'Set Depth(ftKB) ISet Depth(TVD)...I WI/Len(I...I Grade I Top Thread A LINER 23/5 1.920 9,217.3 11,478.0 4.6011 L 80 STL SURFACE;30.1-2,838.9--• - Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (in) 9,217.3 6.135.9- 93.06 BILLET BAKER OPEN HOLE ANCHORED ALUMINUM 0.000 CEPLOYVLV:3.505.6 Ll LINER TOP BILLET 1. 9,2504. 61313 9049 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 I 1 Tubing StringsfI4 �1�9 y.xiRid. , Tubing Description Siring Ma...ID(In) Top(ftKB) Set Depth(ft..J Set Depth(TVD)(...Wt(Ib/R) Grade Top CohneCUoh TUBING-UPPER- 31/2 2.992 23.7 8.232.41 5,910.1 9.30 L-80 EUE8Rd GAS LIFT.8,154.0111 RW0 2015 Completion Details Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) II 23.7 23.7 0.00 HANGER FMC GEN V HANGER 2,992 LOCATOR,8,209.7 IIE 3,505.6 2,891;7 52.77 DEPLOY VLV BAKER ORBIT DEPLOYMENT VALVE 2.910 8,209.7 5,894.1 45.40 LOCATOR BAKER GBH-22 LOCATOR SUB 2.992 SEALASSY;8,2107-, f -1 8,210.71 5,894.8 45.40ISEAL ASSY BAKER 80-0O SEAL ASSEMBLY 2.992 PBR.8,215.5 -I Tubing Description String Me...IID(In) Top(ftKB) !Set Depth(ft...lSet Depth(ND)(...Wt(lb/ft) Grade Top Conneetion TUBING-LOWER- 31/2 2.992 8,2155 8,367.01 6,005.5 9.30 L-80 EUE 8rd Mod PACKER.8,238.6 R WO 2015 i completion Details Nominal ID Top(ftKB) Top(TVD){ftKB) Top Incl(°) Item Des Com (in) 8,215.5 5,898.2 45.36 PBR 80-40 PBR(20) 4,000 NIPPLE;8284 0 8,238.6 5,914.4 45.20 PACKER BAKER 4782 FHL PACKER 2.950 8,284.0 5,946.5 44.89 NIPPLE HSE 2.813"'X'NIPPLE 2.813 8,324.3 5,975.1 44.69 LOCATOR 80-40 GBH-22 LOCATOR SUB 2.980 8,325.5 1 5,975.9 44.68 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.992 Perforations&Slots LOCATOR:8,324.3 Shot €i Dena Top(TVD) Elm(TVD) (shotslf ,6_I 1iI Top(ftKB) Btm(ftKB) (ftKB) ((tKB) Zone Date t) Type Com SEAL ASSY;8,325.4 ):I 9:229.1 9,259.0 .6,135.3 6,134.3 A-3,2H-14 7/16/2015 SLOTS Slotted Liner P.a i 9.2602 11,477.6 6,134.3 6,094.0 A-3,2H-14 7/16/2015 SLOTS Slotted Liner . Mandrel Inserts :711' 7 St �H R'',, all 'ii on Top(TVDI Valve Latch Pad Size TRO Run � _N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com 1 8,154.0 5,855.1 CAMCO MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 5/18/2015 DCR- IPERF;8,460.0-8,4762- I, a I21 olo ` Notes:General&Safety IPERF.8.508.0-8,519.0- It; End DateIii :41 Annotation NOTE: 1 54 I - --- LINER-RWO 2015,8,316.9- 8,710.0 I i 1 PRC DUCTION:28.6-8.842.4, c SLOTS;9.517.4-10.649 6- -- ALO LINER,8.516.5-10.650.0 SLOTS'9 229 1-9,259.0 SLOTS;9,260.2-11.477.6 _ I I A LINER;9,217.3-11,478.0 • • :, 1 o I1 r 11 a 0 2 11 @r,--- 0 r 2U) �'U I-C) W J O o_ 11 _ Q^ 0 1 Nm. N ,i 0 0 0 coN 0 J '1 2 2 0 N 1 1 11 0 n II U O '2 M a, SG 000 C CO M C 11 o N i6 N E (0 th a {1 02 .t] tH MIl (21'a Tu N .— \ co no E HNy o0 V Nc,C \�{ _ CO au �p� cp CU D a) C = N�0 c0 D CNO (N 0 y w 0 " E m 2fYa w/�� i m2 0 1{ 9 6 J G y X CO o co OM o 0a_co it a'? ‘2..) 0031- J ;1 A mN 1- �Ym g n vo.i� 11 c X x rn mail U coo3aiX a�oNin 1 N N Z N N N N &N N N N fV 1 0 c0 N 0 0 N 'EE '/ M M M m m m AA m m m 7 // // iii if CrS11 ism I III /111 I ♦—' ." i FE 1 73 in _I1I ) , � ., 'ti... ... ....o .. I lut,w 111 I 1111 I 11 U I m a o v am w m ,11 o EN N N y N0 /Wp��` y- Nt N2 J im 8o rnr' 0.0 U aT mo 't ao N b co 3 Ul ccoo -a V McM d� 1�a0 cp 00 W 07 1" C O y O Q'a0 'O N (fl ) M U N N fO0 no On Q° y co eo v.', Cfi N 1�'a0 U ado ~ Q Lc) • 2H-14 PRE-RIG WELL WORK • DATE SUMMARY 5/18/2015 SET& PULLED 2.79" CATCHER @ 8284' RKB. PULLED SOV, SET DV @ 8154' RKB. MIT IA 2500 PSI, GOOD. DRIFTED TBG TO 8497' SLM w/2.63"x 17'WHIPSTOCK DUMMY. TAGGED FILL @ 8505'SLM. READY FOR FCO. 6/7/2015 Perform FCO with 3.80" undereamer in the 4.5" liner down to the Landing Collar @ 8,601'CTMD. Made several up and down passes throughout liner until returns cleaned up. Wellbore filled with seawater and freeze protect diesel. Well now ready for SLB E-Line (whipstock). ***Job in progress*** 6/8/2015 TAGGED TD @ 8605' SLM; DRIFTED DOWN TO 8619' RKB WITH 2 5/8" DUMMY WHIPSTOCK. IN PROGRESS (READY FOR E-LINE WHIPSTOCK). 6/12/2015 SET WHIPSTOCK TOP OF TRAY AT 8530'. WHIPSTOCK ORIENTATION 4.5 DEGREES RIGHT OF HIGH SIDE. 2 RA TAGS LOCATED AT 8537'. BOTTOM OF WS AT 8543'. CORRELATED TO K1 MARKER AT 8351'AND SLB CBL LOG DATED 7/30/84. JEWELRY LOG RUN FROM TD TO 8000'. JOB COMPLETE 6/16/2015 (PRE-CTD) : DDT SV, MV, SSV(PASSED), PT SV, MV,SSV(PASSED). onocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2H-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/9/2015 12:00:00 AM Rig Release: 7/20/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 37/08/2015 24 hr Summary Finished reel swap. Moved rig&shop from 2F-18 to 2H-14. Move over well, rig up equipment. 06:00 10:30 4.50 0 0 MIRU MOVE RURD P MIRU CDR2,trucks on location, rig down subs,move off well, install jeeps, pre-move meeting with personnel 10:30 15:30 5.00 0 MIRU MOVE MOB P Mobilize off 3F-pad. Travel to 2H-14 15:30 20:30 5.00 MIRU MOVE MOB P Arrive on 2H-pad. Pad really soft. Spot up&move over the well. Have to utilize cat to pull out of soft gravel. Have tool house bring out grader to work pad. 20:30 00:00 3.50 MIRU MOVE RURD P Rig spotted in&sat down. Begin rigging up equip. 37/09/2015 Complete initial BOPE test,state witnessed by Chuck Shieve. PT inner reel valve, hardline to tiger tank& PDL's. Install coil connector. 00:00 01:00 1.00 0 0 MIRU WHDBO NUND P Nipple up Stack **Note: Rig accepted at 0:00 hours 01:00 01:30 0.50 0 0 MIRU WHDBO RURD P Continue fill reel with water, prep to start BOP test. Call State for witness. 01:30 13:30 12.00 0 0 MIRU WHDBO BOPE P BOPE test,witnessed by Chuck Sheive. Low test 250 psi, high test 3,500 psi, annular test 2,500 psi. 13:30 14:30 1.00 0 0 MIRU WHDBO RGRP T Change out B4 HCR valve. 14:30 20:30 6.00 0 0 MIRU WHDBO PRTS P Fill coil with seawater,test inner reel iron and packoff, PDL, and tiger tank line. 20:30 22:30 2.00 0 0 MIRU WHDBO MPSP P Cocduct TGSM. RU BPV luicator, pull TWC. Lay down equip. 22:30 00:00 1.50 0 SLOT WELLPF CTOP P Conduct PJSM. Cut a couple feet of coil, pull out eline. MWD test E-line, install coil connector. Pull test&PT. 37/10/2015 Tagged TOWS @ 8530'. Milled window&TD rathole @ 8555'. Back reamed window&dry drifted clean. POOH &lay down BHA#1. 00:00 01:00 1.00 0 0 SLOT WELLPF CTOP P Continue installing CTC&Eline _ termination. 01:00 01:30 0.50 0 0 SLOT WELLPF SFTY P Conduct pre-spud with all on the rig. 01:30 02:00 0.50 0 0 SLOT WELLPF CTOP P Pump 1 coil volume foward. 02:00 03:45 1.75 0 76 PROD1 WHPST PULD P Shut the ordit valve.watch for no flow, good to go. Conduct TGSM for picking up BHA#1. Pick up BHA#1 Stab on. Re-open orbit valve. Page I of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 06:00 2.25 76 8,365 PROD1 WHPST TRIP P RIH W/window milling BHA. Inspected saddle clamps and pillow blocks and inner reel iron on newly installed reel at 300'and 1000'. At 1,100' LOTO reel and checked torque on bolts and repositioned chain guard. 06:00 06:15 0.25 8,365 8,398 PROD1 WHPST DLOG P Log K1 for+1.0 ft correction 06:15 07:00 0.75 8,398 8,502 SLOT WHPST CIRC P Displace well over to 9.4 ppg FloPro milling fluid, PUW 28k 07:00 07:15 0.25 8,502 8,532 PROD1 WHPST TRIP P RIH, dry tag TOWS at 8,530', PUW 32k 07:15 11:00 3.75 8,532 8,535 PROD1 WHPST WPST P Mill window, 1.55 bpm @ 3,367 psi FS, BHP 3650 psi,WHP 0, IA 925, OA 40 11:00 16:30 5.50 8,535 8,541 PROD1 WHPST WPST P Continue milling window, at midpoint, bled IA from 1500 psi to 263 psi. 1.55 bpm @ 3,367 psi FS, BHP 3650 psi,WHP 0, IA 779, OA 18 16:30 18:00 1.50 8,541 8,555 PROD1 WHPST WPST P Drill rate hole 1.55 bpm @ 3,367 psi FS, BHP 3665,WHP 0, IA 833, OA 20 18:00 20:00 2.00 8,555 8,555 PROD1 WHPST WPST P Back ream window several times. Dry drifted good, pump 5X5. 20:00 22:00 2.00 8,555 100 PROD1 WHPST TRIP P POOH 22:00 00:00 2.00 100 0 PROD1 WHPST PULD P OOH. Close orbit valve. Bleed well to 0. monitor while conducting pre-job. Lay down window milling BHA. 07/11/2015 Drill build section from 8555'to 8675'. POOH due to BHI tool failure to change BHA. RIH w/new BHA& continue drilling build section from 8675'. Trouble time: BHI 6 hours for tool failure. Nabors 5.75 hours for shaker motor failure. 00:00 01:00 1.00 0 0 PROD1 WHPST RURD P Change out bails.The set needs to be sent to tubo-scope. 01:00 02:45 1.75 0 72 PROD1 DRILL PULD P Conduct PJSM. Pick-up build BHA. 02:45 04:30 1.75 72 8,360 PROD1 DRILL TRIP P RIH W/build BHA 04:30 05:00 0.50 8,360 8,400 PROD1 DRILL DLOG P Tie into K-1. Counter was 40'off. Clean up counter wheel&re-try.Tie in for a-12.5'coreection. 05:00 05:15 0.25 8,400 8,555 PROD1 DRILL TRIP P RIH, PUW 30k 05:15 08:00 2.75 8,555 8,670 PROD1 DRILL DRLG P Drill build section as per plan. 1.50 bpm @ 3,505 psi FS, BHP 3,847, WHP 100, IA 740, OA 20. 08:00 08:15 0.25 8,670 8,360 PROD1 DRILL TRIP P PUH to log K1 and RA marker 08:15 08:30 0.25 8,360 8,570 PROD1 DRILL DLOG P Log K1 for no correction and log RA marker. RA marker at 8,536.5' 08:30 08:45 0.25 8,570 8,670 PROD1 DRILL TRIP P RIH 08:45 09:00 0.25 8,670 8,675 PROD1 DRILL DRLG P Drill build section as per plan. 1.50 bpm @ 3485 psi FS, BHP 3838, WHP 100, IA 720, OA 20 _._ Page 2 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:00 2.00 8,675 72 PROD1 DRILL TRIP T POOH due to tool failure/failed DGS -magnetic section of directional package. Close Baker orbit valve, and conduct no flow check. 11:00 11:45 0.75 72 0 PROD1 DRILL PULD T L/D BHA#2 11:45 12:45 1.00 0 72 PROD1 DRILL PULD T MU BHA#3, surface test,and open Baker orbit valve. 12:45 14:45 2.00 72 8,360 PROD1 DRILL TRIP T RIH with BHA#3 14:45 15:00 0.25 8,360 8,383 PROD1 DRILL DLOG T Log K1 and tie in for a-7.5 ft correction **Note: BHI downtime ended,total downtime 6 hours 15:00 20:45 5.75 8,383 8,383 PROD1 DRILL TRIP T Shale shaker motor failure. Motor coming from Prudhoe **Note: Nabors downtime total of 5.75 hours 20:45 21:00 0.25 8,383 8,675 PROD1 DRILL TRIP P Shaker fixed. Pumps up. RIH 21:00 00:00 3.00 8,675 8,768 PROD1 DRILL DRLG P 1.41 BPM @ 3325 psi FS. Drill ahead 1.41 BPM @ 3446 psi, BHP 3831, ROP 40. ECD 12.13 07/12/2015 TD build section @ 8815'. Drilled ahead from 8815'to 9576'. 00:00 01:30 1.50 8,768 8,815 PROD1 DRILL DRLG P @ 8768', continue drilling ahead 1.40 BPM @ 3396 psi, ROP of 37. TD build @ 8815'. 01:30 03:00 1.50 8,815 72 PROD1 DRILL TRIP P POOH to surface. 03:00 05:00 2.00 72 0 PROD1 DRILL PULD P Tag up, pumps off. 560 psi on well head&falling. Close orbit valve. Bleed off well head from 297 psi to 0 psi. Conduct pre-job. Lay down build BHA. 05:00 05:30 0.50 0 72 PROD1 DRILL PULD P Conduct PJSM. Pick-up BHA#4 05:30 07:30 2.00 72 8,360 PROD1 DRILL TRIP P RIH,with Lateral Drilling BHA, open EDC, pumping min rate. 07:30 07:45 0.25 8,360 8,360 PROD1 DRILL DLOG P Tie into the K1 correction of minus 7.0'. 07:45 08:00 0.25 8,360 8,815 PROD1 DRILL TRIP P Continue RIH to bottom. 08:00 13:30 5.50 8,815 9,111 PROD1 DRILL DRLG P BOBD 1.46 bpm at 3606 psi, BHP 3867,WHP 64, IA 684, OA 14 13:30 13:45 0.25 9,111 8,581 PROD1 DRILL WPRT P Wiper trip, PUW34k 13:45 14:00 0.25 8,581 9,111 PROD1 DRILL WPRT P RBIH 14:00 18:30 4.50 9,111 9,266 PROD1 DRILL DRLG P BOBD 1.38 bpm at 3480 psi, BHP 3808,WHP 25, IA 880, OA 20 18:30 20:30 2.00 9,266 9,415 PROD1 DRILL DRLG P Start mud swap 9.1 ppg, Continue drilling ahead. Get mud all around, 1.50 bpm @ 3339 psi/3834 BHP. Holding choke pressure now, 350 WHP. 20:30 21:15 0.75 9,415 9,415 PROD1 DRILL WPRT P Wiper,30k off btm. Page 3 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 9,415 9,576 PROD1 DRILL DRLG P @ 9415, Drill ahead 1.50 BPM @ 3358 psi, 3854 BHP X7/13/2015 Drill ahead in A lateral from 9676'to 10372' 00:00 02:15 2.25 9,576 9,715 PROD1 DRILL DRLG P Continue drilling ahead to 9715' 02:15 03:15 1.00 9,715 9,715 PROD1 DRILL WPRT P Tie in wiper, 28k off btm.Tie in for a +4.5 correction. RIH to bottom. 03:15 10:00 6.75 9,715 9,997 PROD1 DRILL DRLG P Drill ahead 1.50 BPM @ 3550 psi 3873 BHP 10:00 10:15 0.25 9,997 8,900 PROD1 DRILL WPRT P Wiper trip PUW 29.5k 10:15 10:45 0.50 8,900 9,997 PROD1 DRILL WPRT P RIH,wiper trip clean 10:45 16:15 5.50 9,997 10,162 PROD1 DRILL DRLG P BOBD 1.60 bpm @ 3800 psi FS, BHP 3910 psi,WHP 180, IA 933, OA 22. Bled IA to 540 psi 16:15 16:45 0.50 10,162 9,200 PROD1 DRILL WPRT P Wiper trip PUW 30k, early wiper trip due to low ROP and surface weight 16:45 17:15 0.50 9,200 10,162 PROD1 DRILL WPRT P RIH,wiper trip clean. Pump 10 x10 sweep 17:15 22:00 4.75 10,162 10,360 PROD1 DRILL DRLG P BOBD 1.55 bpm 3,700 psi FS, BHP 3875,WHP 200, IA 520, OA 22 22:00 23:40 1.67 10,360 10,360 PROD1 DRILL WPRT P Decision made to do a 200'wiper. Wiper trip(tie in),26k off BTM, Tie in for a+2.5'correction. RBIH 23:40 23:59 0.33 10,360 10,372 PROD1 DRILL DRLG P Back on BTM, drill ahead 1.45 BPM @ 3522 psi, 3906 BHP 37 ROP, 12.25 ECD 07/14/2015 Drill Ahead A Lateral 10372 to 11052 00:00 04:00 4.00 10,372 10,560 PROD1 DRILL DRLG P Continue drilling ahead. 1.43 BPM @ 3619 psi, ROP 42,3921 BHP 04:00 05:00 1.00 10,560 10,560 PROD1 DRILL WPRT P Wiper,26k off btm 05:00 09:15 4.25 10,560 10,805 PROD1 DRILL DRLG P BOBD 1.50 bpm 3400 psi FS, BHP 3935 psi,WHP 225 09:15 09:45 0.50 10,805 9,529 PROD1 DRILL WPRT P Wiper trip, PUW 27k 09:45 10:15 0.50 9,529 10,805 PROD1 DRILL WPRT P RBIH, perform mud swap, new mud at bit 10,805' 10:15 16:21 6.10 10,805 10,908 PROD1 DRILL DRLG P BOBD 1.47 bpm 3350 psi FS, BHP 3915,WHP 315, IA 550, OA 22 16:21 16:39 0.30 10,908 10,908 PROD1 DRILL WPRT P Stacking, Hard to get drilling, Pull wiper to 10695, PUW=31.5k 16:39 18:15 1.60 10,908 10,912 PROD1 DRILL DRLG P 10908', Drill, 1.4 BPM @ 3315 PSI FS, BHP=4000 18:15 20:09 1.90 10,912 10,912 PROD1 DRILL WPRT P 10912', Drill,Wiper to window with tie in. +3.5'correction, PUW=27K 20:09 23:27 3.30 10,912 11,052 PROD1 DRILL DRLG P 10912', Drill, 1.4 BPM @ 3315 PSI FS, BHP=3950 23:27 00:00 0.55 11,052 10,226 PROD1 DRILL WPRT P 11052', Running low on push,-8K, Pull wiper to 9500', PUW=27K 07/15/2015 Drilled A lateral to TD @ 11478. Pumped sweeps.Tie in for+2.5'. RIH and confirm TD @ 11478. Pump beaded liner pill.Trip out for liner 00:00 00:18 0.30 10,226 11,052 PROD1 DRILL WPRT P Continue wiper from 11052 00:18 03:36 3.30 11,052 11,164 PROD1 DRILL DRLG P 11052', Driull, 1.41 BPM @ 3425 PSI FS, BHP=3970 Pag9 4of8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:36 03:54 0.30 11,164 11,164 PROD1 DRILL WPRT P 11164 Wiper to 10730. Low surface weight, PUW=36K 03:54 15:45 11.85 11,164 11,306 PROD1 DRILL DRLG P 11164', Drill, 1.39 BPM @ 3425PS1 FS, BHP=3945, Low surface weight with poor transfer to bit. Problems getting it to drill, RIW=6K 15:45 16:51 1.10 11,306 8,555 PROD1 DRILL WPRT P Wiper trip, PUW28K 16:51 17:00 0.15 8,555 8,575 PROD1 DRILL DLOG P Tie in at RA tag fora+2.0 ft correction 17:00 17:54 0.90 8,575 11,306 PROD1 DRILL WPRT P RIH 17:54 18:54 1.00 11,306 11,375 PROD1 DRILL DRLG P 11306', Drill, 1.42 BPM @ 3490 PSI FS, BHP=4005, RIW=-2K with 2.1K DHWOB 18:54 19:06 0.20 11,375 11,375 PROD1 DRILL WPRT P BHA wiper, stacked out, PUW=30K 19:06 21:24 2.30 11,375 11,478 PROD1 DRILL DRLG P 11375', Drill, 1.39 BPM @ 3450 PSI FS, BHP=4025 21:24 22:12 0.80 11,478 11,478 PROD1 DRILL WPRT P BHA Wiper,work pipe cann't make hole. Pump sweeps while attempting to drill, Call TD 11478'when sweeps reach BHA 22:12 00:00 1.80 11,478 10,328 PROD1 DRILL WPRT P 11478', Call TD, Chase sweeps to window and tie in for+2.5'correction, RBIH 07/16/2015 M/U and run A Liner, 11478 to 9218'with anchored liner top billet 00:00 00:30 0.50 10,328 11,478 PROD1 DRILL WPRT P Tag TD @ 11478 00:30 04:42 4.20 11,478 86 PROD1 DRILL TRIP P Trip out laying in beaded liner running pill, Paint EOP flags at 9100', & 6100'. Reduce speed pulling out due to hot pillow block bearing on reel, >200°. 04:42 06:24 1.70 86 0 PROD1 DRILL PULD P At surface, Close Orbit valve and flow check well for 5 Min. PJSM, Unstab and lay down BHA#4 06:24 09:45 3.35 0 2,263 COMPZ CASING PUTB P PJSM, Pick up A lateral liner assembly, 73 joints of 2 3/8'slotted liner with shorty deployment sleeve 09:45 10:45 1.00 2,263 2,263 COMPZ CASING PULD P MU BHA#5 to A lateral liner, surface test, and open orbit valve 10:45 13:30 2.75 2,263 11,478 COMPZ CASING RUNL P RIH with A lateral liner assembly to EOP flag at 6,100', -12.87 ft. correction, continue to RIH PUW 28.5K 13:30 14:00 0.50 11,478 8,335 COMPZ CASING TRIP P Release from liner, reset counters, and POOH, PUW prior to liner release 32.2K, PUW post liner release 25.6K, 14:00 14:15 0.25 8,335 8,363 COMPZ CASING DLOG P Log GR tie-in for a+7.5 ft.correction 14:15 15:30 1.25 8,363 44 COMPZ CASING TRIP P POOH, paint EOP flag at 8,300' 15:30 16:18 0.80 44 44 COMPZ CASING OWFF T Function orbit valve closed with WHP 706 psi. Monitor well for no flow, Flow check doesn't look good, Function valve open WHP 606 psi. 16:18 17:06 0.80 44 3,483 COMPZ CASING TRIP T RBIH to flush orbit valve Page 5 of 8 S • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/16/2015 24 hr Summary M/U and run A Liner, 11478 to 9218'with anchored liner top billet 17:06 17:36 0.50 3,483 3,529 COMPZ CASING CIRC T Circ flush accross orbit valve Pick up above valve 17:36 18:18 0.70 3,529 3,447 COMPZ CASING OWFF T Close orbit valve and monitor-looks good 18:18 19:06 0.80 3,447 55 COMPZ CASING TRIP T Trip out keeping hole full 19:06 19:42 0.60 55 55 COMPZ CASING OWFF P At surface, PJSM, Flow check well 19:42 20:00 0.30 55 0 COMPZ CASING PULD P Break off injector and lay down BHA #5 20:00 20:24 0.40 0 0 COMPZ CASING BOPE P Perform Bi weekly BOPE function test 20:24 21:36 1.20 0 103 COMPZ CASING PULD P Make up BHA#6, Ported bullnose, 1 Jt slotted liner, OH anchor, aluminum billet. M/U to coiltrack and surface test tool. EDC Open, Pressure up well and open Orbit valve 21:36 23:24 1.80 103 8,400 COMPZ CASING TRIP P RIH, EDC open, Pumping min rate 23:24 23:42 0.30 8,400 8,424 COMPZ CASING DLOG P Tie into K1 for-9.5'correction, PUW=27K, Close EDC 23:42 00:00 0.30 8,424 8,651 COMPZ CASING TRIP P Continue in hole, No pumping.verify depth running past RA marker. No correction X7/17/2015 Set anchored billet @ 9258,TOB=9217, Kick off and drill build/turn to 9475, Drill lateral to 9775' 00:00 00:18 0.30 8,651 9,258 COMPZ CASING TRIP P Continue in hole, set down on liner lower segment @ 9258 00:18 02:06 1.80 9,258 65 COMPZ CASING TRIP P Orient to 150R pumps on see tool shift @ 4800 PSI, Set down 3K.Trip out of hole, Slow down accross orbit valve to flush. TOLTB @ 9217' 02:06 02:36 0.50 65 65 COMPZ CASING OWFF P At surface, Close orbit valve. monitor for flow, PJSM 02:36 03:06 0.50 65 0 COMPZ CASING PULD P Unstab injector, Lay down BHA#6 03:06 04:00 0.90 0 72 PROD2 STK PULD P P/U BHA#7, Build section BHA with 1.2°motor and RR HYC Bi-center, Make up injector and surface test. Pressure up well and open orbit valve. 04:00 05:30 1.50 72 8,370 PROD2 STK TRIP P RIH, EDC closed 05:30 05:45 0.25 8,370 8,389 PROD2 STK DLOG P Tie in to K1 for a-10.0'correction 05:45 06:30 0.75 8,389 9,217 PROD2 STK TRIP P RIH and dry tag billet at 9,217' 06:30 08:15 1.75 9,217 9,218 PROD2 STK KOST P Time drill off billet, 1.45 bpm 3440 psi FS, BHP 3805,WHP 150, IA 220, OA 14 08:15 09:30 1.25 9,218 9,260 PROD2 DRILL DRLG P Drilling formation, 1.45 bpm 3440 psi FS, BHP 3810,WHP 150, IA 225, OA 14 09:30 09:45 0.25 9,260 9,260 PROD2 DRILL TRIP P Dry drift billet, dry drift clean, PUW 27.5K 09:45 13:00 3.25 9,260 9,475 PROD2 DRILL DRLG P BOBD 1.45 bpm 3450 psi FS, BHP 3860,WHP 170, IA 280, OA 15 13:00 13:30 0.50 9,475 8,494 PROD2 DRILL TRIP P 9475 ft, land build section, POOH • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:00 1.50 8,494 700 PROD2 DRILL TRIP P Open EDC, Continue POOH, flush orbit valve with jog. 15:00 16:00 1.00 700 72 PROD2 DRILL TRIP P At 700'a slug of aluminum plug choked,the orbit valve was cycled closed, blew down choke. Jog in hole to 1,000',to clean hole and choke of aluminum, POOH to surface. 16:00 16:15 0.25 72 72 PROD2 DRILL TRIP P PJSM and monitor well for no flow check 16:15 17:15 1.00 72 0 PROD2 DRILL PULD P LD build section BHA 17:15 17:45 0.50 0 72 PROD2 DRILL PULD P M/U BHA#8 with .6°motor and new Hycalog bit, M/U to coil and surface test. Pressure up well and open orbit valve 17:45 19:21 1.60 72 8,370 PROD2 DRILL TRIP P Trip in hole 19:21 19:27 0.10 8,370 8,392 PROD2 DRILL DLOG P Log K1 for-8.5'correction, PUW=24K 19:27 20:09 0.70 8,392 9,476 PROD2 DRILL TRIP P Continue in hole, Clean pass through window and billet 20:09 23:51 3.70 9,476 9,775 PROD2 DRILL DRLG P 9476, Drill, 1.47 BPM @ 3570 PSI FS, BHP=3830 23:51 00:00 0.15 9,775 9,775 PROD2 DRILL WPRT P 9775',Wiper trip to 8770', PUW=29K 07/18/2015 TD AL1 lateral, Condition hole. M/U completion, Non ported bullnose,69 Jts slotted liner 00:00 00:54 0.90 9,775 9,775 PROD2 DRILL WPRT P Continue wiper trip from 9775 to 8770' 00:54 04:30 3.60 9,775 10,075 PROD2 DRILL DRLG P 9775', Drill, 1.44 BPM @ 3450 PSI FS, BHP=3850 04:30 05:15 0.75 10,075 10,075 PROD2 DRILL WPRT P Wiper trip to 9,225', PUW=27K 05:15 08:30 3.25 10,075 10,375 PROD2 DRILL DRLG P BOBD, 1.45 bpm @ 3500 PSI FS, BHP 3880 08:30 09:15 0.75 10,375 8,560 PROD2 DRILL WPRT P Wiper trip, PUW 30K 09:15 09:30 0.25 8,560 8,575 PROD2 DRILL DLOG P Log RA for a+4.0'correction 09:30 10:00 0.50 8,575 10,375 PROD2 DRILL WPRT P RIH 10:00 13:15 3.25 10,375 10,650 PROD2 DRILL DRLG P BOBD, 1.50 @ 3550 psi FS, BHP 3830,WHP 160, IA 550, OA 20 Perform mud swap, new mud at the bit© 10,403' "*Note: System 2 1,832' Drilled, 0.85%DS, 33K LSRV 13:15 14:30 1.25 10,650 8,555 PROD2 DRILL WPRT P Pumped 10 x 10 sweeps and chase to the window 14:30 14:45 0.25 8,555 8,575 PROD2 DRILL DLOG P Log RA for+ 1.0 ft. correction 14:45 15:30 0.75 8,575 10,650 PROD2 DRILL WPRT P RIH to confirm TD© 10,650' 15:30 20:00 4.50 10,650 63 PROD2 DRILL TRIP P Lay in beaded liner running pill while POOH, Paint EOP flag @ 6300' 20:00 20:24 0.40 63 0 PROD2 DRILL PULD P At surface,close orbit valve, Good flow check lay down BHA#8 20:24 20:48 0.40 0 0 COMPZ CASING PUTB P PJSM, R/U floor to run liner, PJSM to run liner ray 7 o ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:48 23:36 2.80 0 2,133 COMPZ CASING PUTB P P/U BHA#9 with non ported bullnose, 69 jts sloted liner,shorty deployment sleeve. Perform BOP drill at joint 11 in hole. 3:30Min. 23:36 00:00 0.40 2,133 2,178 COMPZ CASING PULD P PJSM, P/U Coil track, M/U to liner and stab on injector 07/19/2015 Run AL1 completion 10650 to 8516, Roll well to seawater. Freeze protect to 2500'. Set BPV. Leave orbit valve open, RDMO 00:00 00:30 0.50 2,178 2,177 COMPZ CASING PULD P Surface test tool, Open deployment rams, Pressure up well, open orbit valve 00:30 02:18 1.80 2,177 8,492 COMPZ CASING TRIP P RIH BHA#9, EDC closed 02:18 02:24 0.10 8,492 8,477 COMPZ CASING DLOG P Correct and 6300'EOP flag for-14.5', PUW=26K 02:24 03:00 0.60 8,477 10,470 COMPZ CASING TRIP P Continue in hole,clean trip past window and billet 03:00 03:06 0.10 10,470 10,488 COMPZ CASING DLOG P Log K1 for+4.5'correction 03:06 03:18 0.20 10,488 8,516 COMPZ CASING TRIP P Continue in hole,Tag bottom at 10650'. PUW=29K, Pumps on 1.5 BPM @ 3720, PUW=24K, Liner released, BOL=10650, TOL=8516, PUH and reset counters. 03:18 06:27 3.15 8,516 32 COMPZ CASING DISP P POOH while displacing well to seawater, function close orbit valve, flow check and freeze protect from 2,500' 06:27 06:57 0.50 32 0 COMPZ CASING PULD P LD liner running assebly BHA#9 06:57 11:15 4.30 0 0 DEMOB WHDBO RURD P Flush and blow down coil, pin injector, chain CT reel, and follow rig move check list. 11:15 13:00 1.75 0 0 DEMOB WHDBO MPSP P RU FMC lubricator, pressure test, set BPV, and RD FMC lubricator 13:00 14:00 1.00 0 0 DEMOB WHDBO RURD P Blow down surface lines, bleed koomey, and disconnect putz 14:00 15:00 1.00 0 0 DEMOB WHDBO NUND P Nipple down BOPE and check tree bolts. Did not find any loose tree bolts. FTP=863 psi 15:00 00:00 9.00 0 0 DEMOB WHDBO RURD P Continue RDMO CDR2 to 30-08 **Note: Rig released at 0:00 hours Page 8 of 8 1 • • ip 2i. z mai.„ ,,mi —go oltZNI N a Z I C ... i cS O as 0 w W D a I- ,, 0 U MMI e aE .E a � � o O > a r _ > I . O v E N2 C ~ r C O N .c N 0 V0 c a Rio � y- O a r (o 0 N ,`”) 03 0 N • • W z N a mix' v o [p 'S �W� n o E L m .7 7 , c v i 10,11; ii i'` m 'p Oo i F `° P M N l0 O a N ` Q N In 7 0 N O �i(I a vJ H !i i i��lll�� - N W n LL 0 a U 9 9 U o I r � � � IC' •a- , N Q 0 O N Z N N Q 7 N O N N )I . _ 1N> I 1 1 vd J N -S' di D .0 C 1,i ; , €COgJ J U - co. •:,,. roO s v .:7- Q l N N 1 N ') 1` ~ E 14 >> jV Ua "O O 0In '4 (f) a @ @ d a W *•+� O C9 (N i .Q .£ J UN V V UN tN _ Q N N N - O U Lj p a W — ce, ill 4O ONN N rn ` O 0W O' N c c fro C u^ Oa 't m N�d o m 6i V 'C O Loc.. Z L G S 1W Nd y Q O. ..7 d N n d C RC C pja O d V cw Q cy o Z H0` m U 0 Z O O L U O aG1 U aL >N ~d + i2 (5 Q = wCCQuQm JrZfAQ mc LQ et rz 32 w z W > C/iT cn N d � 14, l'-3-• (a(n Q a d N G. 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N = = C QOt aa)) M V V O 6 N 66 ti N N F 0 a C 0 N co co co co m 0 m a V 0) c 0) C) C) Ni 0) CI 2 5 V V V V V V V V a t lif Q ai Q) 4) -C U) 0 N N 0) (6 N- ZZ Ct C O U) V 0 0 (0 U) V L CI M (6 00) N N LU N N N w m c 0 0] W C) C) 6) 0 0 N a L CO V V CO CO CO V V -C 7 0 c 0 rn rn rn m m rn al m CI ',3; C Z 66- 6- vi to' 1.6 viui U) ° u) C `L 3i0 O v I > a c 2 m c7i (w C O w y d U N V 00) CO N Uco LU O co CO CO. (0 a R a' L N a • .Y-' o) W 0) W ro m m Ss- 03 m O O 7tea W V 1 v V v v v v -r- 3 F 2 Z u) 0 + M UcocoO) N-N 0 •- N _ U6 (6 (6 r 0 N V r 9 .y.'' el OO O O O Si_ C)) 6) Z 7 N N N N N } 06 N M 0, 0)) O C))01 ON 60) 0 .-. Ni 6 e' O O (6 , to,...0 0 N- rn 0 0 0)) 00) C) 00) .2.:U) 6 6- U) Ui 6 L N COMN CO) CO N- CO ON CO GIp Q § 0 v m 6 rn 6 m rn m rn > 0 0000 0000 O 7 t0 0 0 t0 UO U0 t0 (O C 1 N (0 w 3epep Q .� r r W r OM CO N N t a 0 0 n 0) m O 6 6 Q` _ L ix N N O 7 = V V V , N 0 O O 0 NN- il!• C it O. U .-. V V O N O N CO CO U Y Y N N N C m co m O O m m CL a a O O0 U U N U) O O O^ U V U) U) V N V 0 0 O U) N U) U) U) O W Ni O C it; UaNN - M0V7 CC') V m 4j YO 0 .0,-. w d a 0 0 r V U d in 0 co MECEIVED • JUL 27 2615 Letter of Transmittal Eau AOGCC BAKER Date: DATA LOGGED July 24, 2015 7'2.9/2o15 HUGHES M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): I 3F-18APB1 1 5 6 9 2 6 0 7 3 3F-18A 21 5009 26 07 3F-18AL1 21 5090 26 07' 4 3F-18AL2 21 5091 26 075 21 5094 26 076 /1211-14AL1 21 5096 26 077 r- 2H-14A (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.corn Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@pakerHughes.com IA © tom. 1111 W LO CD MI Z KIIcv N `Wo gX Li N %;.i I. ` 4 0 C Sm CU O low Oin as 0 CD WW a I— >% III Z a) a . a. — (13 s.IMMI MOM � 0 .0 E �' a = � r 0 o O to _ > N }+ M •- 43 r O O 7 7 N U- N V col' O 4= >, �� Q Q MM� A V Y Y N UL) W 0 N • • 0 ill 112 -- killi m 4, d -r ayin Oo y,_N coo v)�iuur� � I sF� a 0C3, N rO N.... 0 d p ov� • C O d is '` + o vv 0 n � r _ ao Y > Z 3 %a 3 EHi� � ? (N Cs1 I 0 • dr_ r � 0mitt O • c';111/g'''4111"; --- ' O Lc ui a U) N 0 ' ,,.p„%,1,,,q,,,,,",1": . .0 t ) ta aW r 1191;4, o4N N d CUJ— C Q U n_ 0 _N N H N oO O O 6 O) �p lVy tn O) O) O _ �iiiy111 o CLM ii NW CC ��iiIi�hr{ Q L mi11' '�5' dZ LN d �o r CU d N i'1,; =c ❑3 m = du_ > o as O p _ !° C7dD' d � dn I.N v C .2 ,E, v r �$ ir c m 0 r•,-0. -cs❑ W d E o R d Z W E "s s co ry h •� 'idd - i 10aiam m _o ,11",'," J • ❑ 3 d CO Q H oY . 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OO ro (O N N N O 0 O ^ O ui ui 0 tri O6 Ni O I.I.00 y N N c') A M 7 4 V € {() a Q. i) O C d - - - - - ON 0 EO O gN d y 0 • 0 tiOFTy • I%,�� THE STATE Alaska Oil and Gas ,� ►; ofLAsKA. Conservati®n Commission 333 West Seventh Avenue "z GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®� \Th. �, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2H-14A ConocoPhillips Alaska, Inc. Permit No: 215-094 Surface Location: 110' FSL, 654' FEL, SEC. 26, T11N, RO8E, UM Bottomhole Location: 1779' FNL, 32' FWL, SEC. 35, Ti 1N, RO8E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 1 day of June, 2015. • • : VD STATE OF ALASKA ���� 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION �� 10\1/40 PERMI20 T TOAC oDRILLAOGCC 05 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Win) ❑ Single Zone Q 1c.Specify if well,is proposed for: Drill ❑ Lateral I Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas El Gas Hydrates❑ Redrill 0' Reentry C Exploratory ❑ Service-WAG Q s Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: • L.,..j Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180, KRU 2H-14A 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11400'4 TVD: 6005', Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 110'FSL,654'FEL,Sec.26,T11N, RO8E, UM ' ADL 25587 * Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1269'FSL,716'FWL,Sec.35,T11N,RO8E, UM 2673 7/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 1779'FNL,32'FWL, Sec.35,T11N, RO8E, UM 2560. Nearest Property: 17394 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 125 feet 15.Distance to Nearest Well Open Surface:x- 497745 y- 5948973 Zone- 4 - GL Elevation above MSL: 30 feet to Same Pool: 2H-13,960 16.Deviated wells: Kickoff depth: . 8530 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: ,101° deg Downhole:3835 psig , Surface:3219 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) 3" 2.375" 4.7# L-80 ST-L 2450' 8950' 6027' 11400' 6005' 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) 8873 6377 none 8716 6354 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 172 sx CS II 110' 110' Surface 2809' 9.625" 980 sx AS III,440 sx CI G 2839 2497' Production 8814' 7" 400 sx CI G,250 sx AS I 8842' 6354' Scab Liner 340' 4.5" none 8716' 6259' Perforation Depth MD(ft): Perforation Depth TVD(ft): perfs cemented off perfs cemented off 20.Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot El Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact s n Burke @ 265-6097 Email Jason.Burke@cop.com Printed Name D. Ve haus Title CTD Engineering Supervisor Signature Phone:263-4372 Date _ 5-/S Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: a fs-- 094 50-IO -,203 342-.01-ty: Date: CO(1.911,� for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: id Other:3O p fie5-1 fo 35-00 p s m l s req'd: Yes 5 No ❑J Mud log req'd: Yes❑ No R" ! r rcvevifrr71 5v-foZ�FT2 fJ v2 n v p measures: Yes No ,❑/ Directional svy req'd: Yes 21. No Eil Spacing exception req'd: Yes ❑ No IA Inclination-only svy req'd: Yes❑ No V APPROVED BY THE / 1 , Approved by./((2/r"-- COMMISSIONER COMMISSION Date: LLL ` (S Form 10-4Q1R // /z0 ) 0 Ril iGliil 1\11rrntom theeroval(20 AAC 25.005(g)) I • RECEIVED *--- ConocoPhillips JUN 05 2 015 Alaska P.O.BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 June 4,2015,2015 . . Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk well 2H-14 using the coiled tubing drilling rig, Nabors CDR2-AC. / CTD operations are scheduled to begin in July 2015. The objective will be to drill laterals KRU 2H-14A and 2H-14AL1 targeting the Kuparuk A-sand. The original perforations have been cemented off and the wells • current status is listed as suspended(as per sundry#314-604). An application to abandon the KRU 2H-14 will be included. Attached to this application are the following documents: - 10-401 Applications for 2H-14A&2H-14AL1 — Detailed Summary of Operations — Directional Plans for 2H-14A&21-1-14AL1 — Proposed CTD Schematic — 10-403 Sundry Application to Abandon KRU 2H-14(184-195) If you have any questions or require additional information please contact me at 907-265-6097. . . I Sincerely, 10.11." 40010, 10111110L-011111P---- ' 411111111r E Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer E i t [ 4 11 '. i • • Kuparuk CTD Laterals4;4 �agnaka 2H-14A & AL1 Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 2H-14A&AL1 7 Attachment 2: Current Well Schematic for 2H-14 7 Attachment 3: Proposed Well Schematic for 2H-14A&AL1 7 Page 1 of 7 6/3/2015 • • PTD Application: 2H-14A &AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document 2H-14A &AL1. Laterals will be classified as "Service— WAG Injection"well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the A3&A4 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2H-14A&AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Using the maximum formation pressure in the area of 3835 psi in the 2H-13, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3219 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. . / rytX P 3 5 3 1 )>s,/.+ G ILa `Tv-D 4. Drilling Hazards Information and Reservoir Pressure r .� l 1.9 n (Requirements of 20 AAC 25.005(c)(4)) / S 3 S!� / p •` t, 0 4,o )tels D52 Mve Reservoir Pressure and Maximum Downhole Pressure (Requirements o 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 2H-14 in December 2014 indicated a reservoir pressure of 3715 psi or 11.6 ppg equivalent mud weight. The maximum down hole pressure in the 2H-14 pattern is at 2H-13 with 3835 psi. It is not expected that reservoir pressure as high as 2H-13 will be encountered while drilling the 2H-14A & AL1 because we are staying 960 ft from the well. Using the 2H-13 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3219 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 2H pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2H-14 laterals will be the possibility of a high pressure differential when we cross a N-S fault, drilling from an 11.6 ppg block into possibly a 8.3 ppg block. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 6/3/2015 • i PTD Application: 2H-14A & AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2H-14A 8950' 11400' 6027' 6005' 2%", 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 2H-14AL1 8525' 10300' 5998' 6060' 2%", 4.7#, L-80, ST-L slotted liner, with a shorty deployment sleeve. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (POMD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 30' 110' 0' 110' 1640 630 Surface 9-5/8" 36 J-55 BTC 30' 2839' 0' 2497' 3520 2020 Casing 7" 26 L-80 TCII 29' 8842' 0' 6354' 7240 5410 Liner 4 %" 11.6 L-80 BTCM 8317' 8716' 5970' 6259' 7780 6360 Tubing 3'h" 9.3 L-80 EUE 8Rd 24' 8232' 0' 5910' 6990 7400 7. Diverter System Information (Requirements of 20 AA C 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Flo-Pro mud (9.1 ppg) — Drilling operations: Chloride-based Flo-Pro mud (9.1 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure. — Completion operations: 2H-14 contains a new style deployment valve. This valve will allow the deployment of tool strings and liner without pumping kill weight fluid. However, in the case the valve will not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. — Emergency Kill Weight fluid: Two wellbore volumes of 12.9 ppg kill weight fluid will be stored at / drillsite 18 in the Kuparuk field, and is accessible for trucking to the rig during CTD operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP Page 3 of 7 6/3/2015 • PTD Application: 2H-14A & AL1 promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 11.8 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the fault blocks being drilled into. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 2H-14 Window(8530' MD, 6123' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(11.6 ppg) 3693 psi 3693 psi Mud Hydrostatic(9.1 ppg) 2897 psi 2897 psi Annular friction (i.e. ECD, 0.090 psi/ft) 768 psi 0 psi Mud + ECD Combined 3665 psi 2897 psi (no choke pressure) (underbalanced (underbalanced —28 psi) —796 psi) Target BHP at Window(11.8 ppg) 3757 psi 3757 psi Choke Pressure Required to Maintain 92 psi 860 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU 2H-14 is a dual lateral well that is being converted from a producer to an injector. A recent RWO was performed to swap tubing, cement a 4-1/2" scab liner in place and install a down hole deployment valve. Page 4 of 7 6/3/2015 S i PTD Application: 2H-14A & AL1 The objective of this well is to drill 2 laterals on either side of a N-S fault to provide support to the 2H-10, 2M-22 and the 2M-24. 2H-14A will kick off in the A4 sand at 8530'MD via a 2 string cemented window exit,then land in the A3 sand. From there the plan is to turn north and invert into the A4 pay,cross fault#1 into the lower A3 and geo-steer in the A3 pay until a TD of 11,400'MD. The lateral will be completed with 2-3/8" slotted liner with an aluminum billet to a depth of 8950'MD. 2H-14AL1 will kick off the billet at 8950'MD in the A4 pay on the east side of fault#1. The plan is to drop inot the A3 pay and geo-steer to the north drilling to a TD of 10,300'MD. The lateral will be completed with 2-3/8" slotted liner ran back into the parent well bore to a depth of 8525'MD. Pre-CTD Work • Coil: Perform FCO of old mud left over from RWO • E-line: Set a 4Y2"thru-tubing whip-stock at 8530' MD and 0°HS Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coil tubing. NU 7-1/16"BOPE,test. 2. 2H-14A Lateral(A4 sand-Northwest) i. Mill 2.80"window at 8530' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 11300' MD iii. Run 2%"slotted liner with an aluminum billet from TD up to 8950' MD 3. 2H-14AL1 Lateral(A3 sand-North) i. Kick off the billet at 8950' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10300' MD iii. Run 2%"slotted liner with shorty deployment sleeve from TD up to 8325' MD 4. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Flow back(less than 30 days) /- 4. Perform AOGCC witnessed MIT-IA 5. Put back on injection Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double Page 5 of 7 6/3/2015 • S PTD Application: 2H-14A & AL1 ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running 24-0 — The 2.614 has a new down hole deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalancing fluid (12.0 ppg NaBr) prior to running liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. ✓ — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 2H-14A 17394' 2H-14AL1 17394' Page 6 of 7 6/3/2015 • • PTD Application: 2H-14A & AL1 — Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well 2H-14A 960' 2H-13 2H-14AL1 1360' 2H-13 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 2H-14A is within %4-mile of the 2H-13 well 2H-14(mother bore) Injector • The well is completed with 3.5" 9.3#L-80 tubing, 4.5" 11.6#L-80 liner and 7"26#J-55 casing. The last MIT-IA was completed on 5/18/15 and passed at 2500 psi. • Recently worked over and new 4 1/" liner was ran in hole and cemented in place with 23 bbl of Class"G" cement. This well will be classified as abandoned when we drill the 2H-14A. • Classified as a "Normal Well" • C-sand perforations (cemented): 8460'-8475' MD • A-sand perforations (cemented):A5: 8508'-8519',A4: 8530'—8563' &A3: 8588'—8614' MD • Packer is located at 8238' MD (222' above C-sand)variance was granted by AOGCC on 1/21/15 (attached). Packer was set high to isolate a casing leak 8297'—8319' MD. • 3 %2" Baker Orbit deployment valve at 3505' MD • The well is being converted from a producer into an injector. The CBL data shows a very good bond in the 7"casing from 8350'—8450', and appears to be adequate above that based on the CBL from 7/30/1984 2H-13(injector), —960' away from 2H-14A lateral to northeast ` • The 2H-13 is currently injecting into the Kuparuk A&C-sand intervals. • Currently a waivered well for TxIA communication and is currently a water only injector • Well head pressure is monitored daily as per waiver • Completed with 7", 26#, J-55 casing • C-sand perforations: C4: 7466'—7469' MD • A-sand perforations:A5: 7510'—7515' MD, A4: 7528'—7555' MD &A3: 7591'—7597' MD • Packer at 7387' MD, which is less than 200'from the perforations • The cement bond log shows adequate cement as per original injection order • Last state witnessed MIT-IA on 5/11/08 17. Attachments Attachment 1: Directional Plans for 2H-14A &AL1 Attachment 2: Current Well Schematic for 2H-14 Attachment 3: Proposed Well Schematic for 2H-14A &AL1 Attachment 4: 10-403 to abandon 2H-14 Page 7 of 7 6/3/2015 • • II 1I 11 co II I 1 I-I_ II 22 d II b 0 11 0oO) 0 F- Ps II 3�ao 30� <�© Zo a II om7, Io1I S o <- O 1 NI-E Co 7–tV a) I I M 20 c II 0 0 0 N F- 1 1 2 2 2 a) II 0 m 1I 8 0 N M a II (0 M U) 2 co C_ 0) M 0 I I In 7 mw v m E o' d II Tn 2 > a M .o - a) II (O Ol III EHuI E O mE NN CU(0 (OF,LU)0) a)M C Nyao.0 -0 N N© U N N v UW 1 =Yx09 U C C9 0 OU N J d a # as E 'T'tm #'C 'Td' 1 co O) 0] U) 0 aco W V4' O)X COON LLD II 1 N N Z N Y Y Y NCV Y Y s N / (0 (0 (0 'T'T (0 co )0 / A M M comm MM CD O]0 // // immieii // // Lem III // iii,400. I s W l/ I 'jI II" `,1, �.Trr... - _S:S:S:•....1%;•:,...,:•.:5:•.:•.:ti S:••:S:ti•.::e.. :S4. �_ • it • ..........."7r r.r•l.r.r•!•J•J.. L.S•S•S •S•Sri•S•S• • ��� IN I, .�� I 4•J.r•l.J.J.!J.r.. i•r.r•r•i.r•r.r•r•. L.S.S•1•S•SH•S•S•S• 1M•J.!•JYWJ•J•. S•S•4•S•S•S•h•S•S• CIO !•J•J•!•0.J.l.0.e, r•r•r•r•r•r+!•r•r• AiS.Y1. .S.S.S.S.S.S.YS.S. : ti�M.S.1+S•S.YS.S.S.•..S.S•S S.S.YS.S.S.•.;m /J\\V// �J.r..M1r.JY.J.JY.J.J.l•!.r' r_rY.J_M•J.JY.J.J•.M1J.J•l.J.JY.J�.r.JY.r.J.I.J_J.. CI 0TIT Ill I 1- I M O vI O — a M O OJ t o u-) a w O m Mt o O N N a. r LO yO N<") '� �0 N Y 0 (� O d' N U)LSO TS O OLc) a3 0 Y co •.t O) O-co z)m coIN 4 U) .) 10 `t "O o a)s- C N N 7 _ M 0 C M Op_r 0 p) -0 CO m 0M a(O r co I N,- CO 0 'y ao '0 co d ar CO l0 00 (per W o) U1r C O 0(O NO Q m C N Via' O)N n� m a` i�aOo ¢m III CO V U 00 Q CO KUP PROD • 2H-14 Conoco fillips Well Attributes Max Angle&MD TD Pr(asiSa,Inc. Wellbore API/UWI Field Name Wellbore Status Incl p) MD(ftKBI Act Btm(ftKB) Cxnaco4rhilhps ! 501032003600 KUPARUK RIVER UNIT PROD 54.38 3,000.00 8,873.0 ... .K Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-14,523/20156:12:46 PM SSSV:LOCKED OUT 63 12/30/2012 Last WO: 12/25/2015 34.51 7/18/1984 vertical achemanc(ectue0 Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,505.0 5/18/2015 Rev Reason:GLV C/O,TAG lehallf 5/23/2015 HANGER;23.7-a --.t Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth 111601 Set Depth(ND)...WELen(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I.,.Grade Top Thread SURFACE 9 5/8 8.921 30.0 2,838.9 2,497.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WS/Len(I...Grade Top Thread ii PRODUCTION 7 6.276 28.6 8,842.4 6,353.8 26.00 J-55 BTC `� ,1 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKBI Set Depth(ND)...Wf/Len(I...Grade Top Thread 44'LINER-RWO 2015 41/2 4.000 8.316.9 8,716.0 6,259.4 11.60 L-80 BTCM Liner Details Nominal ID Top(SOB) Top(ND)(ftKB) Top Incl C) Item Des Com (In) 8,316.9 5,969.9 44.72 PACKER BAKER ZXP LINER TOP PACKER 4.330 8,336.5 5,983.8 44.64 HANGER BAKER FLEX LOCK LINER HANGER 4.240 ✓..N CONDUCTOR;30.0-110.0- 8,352.4 5,995.1 44.58 SBE 80-40 SOT 4.000 Tubing Strings Tubing Description String Ma...ID(in) Topf (ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER- 1 31/21 2.9921 23.7 8,232.41 5,910.1 9.30 L-80 EUE 8Rd RWO 2015 SURFACE;30.1-2.838.5-- - Completion Details ,41:40!1'01!,L; Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 23.7 23.7 0.00 HANGER FMC GEN V HANGER 2.992 DEPLOY VLV;3,505.6 3,505.6 2,891.7 52.77 DEPLOY VLV BAKERORBITDEPLOYMENTVALVE 2.910 I 8,209.7 5,894.1 45.40 LOCATOR BAKER GBH-22 LOCATOR SUB 2.992 8,210.7 5,894.8 45.40 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.992 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-LOWER- 1 3 1/21 2.9921 8,215.51 8,367.01 6,005.5 9.30 L-80 EUE 8rd Mod GAS LIFT;8,154.0 1 R W O 2015 Completion Details Nominal ID ( Top(ftKB) Top(TVD)(ftKB) Top Incl p) Item Des Com (in) 8,215.5 5,898.2 45.36 PBR 80-40 PBR 120') 4.000 ` LOCATOR;8,209.7 iii 8,238.6 5,914.4 45.20 PACKER BAKER 4782 FHL PACKER 2.950 8,284.0 5,946.5 44.89 NIPPLE HSE 2.813"'X'NIPPLE 2.813 SEAL ASSY;8,210.7 i i 8,324.3 5,975.1 44.69 LOCATOR 80-40 GBH-22 LOCATOR SUB 2.980 PER;8,215.5 I / 8.325.51 5,975.91 44.68 SEAL ASSY 180-40 GB4-22 SEAL ASSEMBLY 1 2.992 Perforations&Slots PACKER;8,238.6 Shot Dens = Top(ND) Btm(ND) (shots/f 11 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,460.0 8,476.0 6,072.1 6,083.6 C-4,UNIT B, 4/18/1985 12.0 (PERF 120 deg.Ph;5"Baker 2H-14 Tubing Cony it NIPPLE;8.284.0 : 8,508.0' 8,519.0 6,106.6 6,114.5 A-5,2H-14 4/22/1985 4.0 IPERF 90 deg.Ph;2 1/8" EnerJet 8,530.0 8,563.0 6,122.5 6,146.5 A-4,2H-14 4/22/1985 4.0 IPERF 90 deg.Ph;2 1/8" EnerJet 8,588.0 8,614.0 6,164.7 6,183.8 A-3,2H-14 4/22/1985 4.0 IPERF 90 deg.Ph,2 1/8" ii 1 En e/Jet Cement Squeezes LOCATOR;8,3243Top(ND) Btm(ND) °'- Top(ft6B) Btm(EKE) (ftKB) (ftKB) Des Start Date Com 8,336.5 8,842.0 5,983.8 6,353.5 4 1/2"liner 1/19/2015 Pump 15 bbls of Mud Push II Followed by 23 bbls of '`"- t Class""G""15.8 lb/gal cement.Flush lines.Drop Dart SEAL ASSY;8,325.4 'I=I &pump 5 bbls fresh wtr.Displace w/53.5 bbls of mud. Total displacement=58.5 bbls. Pressure up&bump plug with 2500 psi.Plug down at 05:46 hrs.S/O w/ r 45K&set slips. I in Mandrel Inserts st ab k. kl5on Top(ND) Valve Latch Port Size TRO Run a _. N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (In) (psi) Run Date Com IPERF;E480.0-8.476.0- i.. { 8,154.0 5,855.1 CAMCO MMG 11/2 GAS LIFT DMY RKP 5/18/2015 OCR- 1 Notes:General&Safety IPERF;6508.0-8,519.0- End Date Annotation 4 41 10/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;8,530.0-8.563.0- 1 11 li 1.41 IPERF;8,588.0-8,614.0-. a 1 ii 1 III LINER-RWO 2015;8,316.9- 8.716.0 ICI PRODUCTION;28.6-8.842.4 ` • • W LW�_ io Wwo I IIO . 1 o I i j I 8 8 _._. _ - .._ - i ........- _ O tt. i 8V o 181 E 1_:i.: '1��.. O O _c.•,_ o ' �'s�•ao 8 w mees I ,- . I - " $ z . . e 3W U Z • O " n 0_ N II-^. N N O i N O e o eW �3 • . � no u FF 0 I I - " ® o ti • I Rip, EA �o c. 4. _ , roo \ p cv 1 1 1 1 8 , " , " 8 N 4� zl I,, oy o IL'v ..y it z A 0 N i m it , p• j { • • Y 1 , =,,,-.4 u • r9 G OO O O 0 O O O O O 8 O O O O OO O O O O e O O O G O c r 2 N N 1� 8 N " O N O p O 1, 'T 't V 't O N , (ai/1Jsn OSZ) +)u oN/�-)ulnosM = N • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2H Pad 2H-14 2H-14A Plan: 2H-14A wp06 Standard Planning Report 29 May, 2015 BAKER HUGHES • • - lake ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2H-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2H-14 @ 125.00usft(2H-14) Site: Kuparuk 2H Pad North Reference: True Well: 2H-14 Survey Calculation Method: Minimum Curvature Wellbore: 2H-14A Design: 2H-14A_wp06 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Site Kuparuk 2H Pad Site Position: Northing: 5,948,973.20 usft Latitude: 70°16'18.548 N From: Map Easting: 498,414.90 usft Longitude: 150°0'46.152 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ° Well 2H-14 Well Position +N/-S 0.00 usft Northing: 5,948,973.05 usft Latitude: 70°16'18.545 N +E/-W 0.00 usft Easting: 497,745.06 usft Longitude: 150°1'5.655 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2H-14A -- Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 8/1/2015 18.60 80.85 57,543 Design 2H-14A_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,500.00 Vertical Section: Depth From(TVD) +N/-S +E/-W --,------MR---- Direction (usft) (usft) (usft)' (0) 0.00 0.00 0.00 247.65 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System i +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°I100ft) (°/100ft) (°/100ft) (0) Target 8,500.00 43.90 218.93 5,975.83 -4,088.82 -3,570.42 0.00 0.00 0.00 0.00 8,530.00 43.60 218.90 5,997.50 -4,104.96 -3,583.45 1.00 -1.00 -0.10 -176.06 8,555.00 48.85 218.90 6,014.79 -4,119.01 -3,594.78 21.00 21.00 0.00 0.00 8,633.11 84.00 218.90 6,045.54 -4,173.85 -3,639.04 45.00 45.00 0.00 0.00 8,733.11 90.05 263.58 6,051.01 -4,220.57 -3,724.38 45.00 6.05 44.68 83.90 8,833.11 100.58 307.59 6,041.29 -4,194.85 -3,817.87 45.00 10.53 44.01 75.00 9,003.11 90.04 313.14 6,025.57 -4,085.36 -3,946.56 7.00 -6.20 3.27 152.00 9,453.11 91.44 344.62 6,019.60 -3,704.99 -4,176.21 7.00 0.31 6.99 87.30 9,853.11 91.27 316.61 6,009.92 -3,360.03 -4,370.49 7.00 -0.04 -7.00 270.00 10,253.11 91.17 344.62 6,001.21 -3,015.04 -4,564.78 7.00 -0.03 7.00 89.90 10,473.11 91.13 0.02 5,996.76 -2,797.71 -4,594.09 7.00 -0.02 7.00 90.00 10,723.11 91.38 342.52 5,991.25 -2,551.63 -4,631.89 7.00 0.10 -7.00 271.00 10,793.11 90.02 347.23 5,990.39 -2,484.08 -4,650.15 7.00 -1.93 6.73 106.00 11,243.11 87.83 18.66 5,999.04 -2,040.39 -4,627.39 7.00 -0.49 6.98 94.20 11,400.00 87.87 7.67 6,004.95 -1,887.97 -4,591.75 7.00 0.03 -7.00 270.00 5/29/2015 11:34.544M Page 2 COMPASS 5000.1 Build 61 . • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2H-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2H-14 @ 125.00usft(2H-14) Site: Kuparuk 2H Pad North Reference: True Well: 2H-14 Survey Calculation Method: Minimum Curvature Wellbore: 2H-14A sl Design: 2H-14A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1-S +E/-W Section Rate Azimuth Northing Easting (usft) (a) (0) (usft) (usft (usft) (usft) (°1100ft) (0) (usft) (usft) 8,500.00 43.90 218.93 5,975.83 -4,088.82 -3,570.42 4,857.07 0.00 0.00 5,944,885.71 494,173.77 TIP 8,530.00 43.60 218.90 5,997.50 -4,104.96 -3,583.45 4,875.26 1.00 -176.06 5,944,869.57 494,160.74 KOP 8,555.00 48.85 218.90 6,014.79 -4,119.01 -3,594.78 4,891.08 21.00 0.00 5,944,855.53 494,149.40 End 21 dls,Start 45 dls 8,600.00 69.10 218.90 6,037.86 -4,148.86 -3,618.87 4,924.71 45.00 0.00 5,944,825.69 494,125.30 8,633.11 84.00 218.90 6,045.54 -4,173.85 -3,639.04 4,952.87 45.00 0.00 5,944,800.70 494,105.13 4 8,700.00 87.85 248.84 6,050.40 -4,212.70 -3,692.32 5,016.92 45.00 83.90 5,944,761.87 494,051.84 8,733.11 90.05 263.58 6,051.01 -4,220.57 -3,724.38 5,049.56 45.00 81.72 5,944,754.01 494,019.78 5 8,800.00 97.50 292.83 6,046.52 -4,211.24 -3,789.69 5,106.41 45.00 75.00 5,944,763.37 493,954.49 8,833.11 100.58 307.59 6,041.29 -4,194.85 -3,817.87 5,126.25 45.00 76.97 5,944,779.76 493,926.31 End 45 dls,Start 7 dls 8,900.00 96.44 309.80 6,031.39 -4,153.50 -3,869.49 5,158.26 7.00 152.00 5,944,821.13 493,874.72 9,000.00 90.23 313.04 6,025.57 -4,087.49 -3,944.29 5,202.34 7.00 152.33 5,944,887.16 493,799.94 9,003.11 90.04 313.14 6,025.57 -4,085.36 -3,946.56 5,203.63 7.00 152.52 5,944,889.28 493,797.67 7 9,100.00 90.36 319.92 6,025.23 -4,015.08 -4,013.18 5,238.52 7.00 87.30 5,944,959.57 493,731.08 9,200.00 90.68 326.91 6,024.33 -3,934.84 -4,072.74 5,263.09 7.00 87.32 5,945,039.83 493,671.55 9,300.00 90.99 333.91 6,022.86 -3,847.94 -4,122.08 5,275.68 7.00 87.39 5,945,126.73 493,622.24 9,400.00 91.29 340.90 6,020.87 -3,755.70 -4,160.47 5,276.11 7.00 87.49 5,945,218.98 493,583.88 9,453.11 91.44 344.62 6,019.60 -3,704.99 -4,176.21 5,271.38 7.00 87.63 5,945,269.68 493,568.16 8 9,500.00 91.44 341.33 6,018.42 -3,660.18 -4,189.93 5,267.03 7.00 -90.00 5,945,314.49 493,554.45 9,600.00 91.42 334.33 6,015.92 -3,567.66 -4,227.63 5,266.71 7.00 -90.08 5,945,407.02 493,516.79 9,700.00 91.38 327.33 6,013.47 -3,480.42 -4,276.32 5,278.57 7.00 -90.26 5,945,494.26 493,468.12 9,800.00 91.32 320.33 6,011.12 -3,399.77 -4,335.29 5,302.44 7.00 -90.43 5,945,574.92 493,409.19 9,853.11 91.27 316.61 6,009.92 -3,360.03 -4,370.49 5,319.88 7.00 -90.59 5,945,614.67 493,374.00 9 9,900.00 91.28 319.89 6,008.88 -3,325.06 -4,401.70 5,335.45 7.00 89.90 5,945,649.64 493,342.81 10,000.00 91.27 326.89 6,006.65 -3,244.85 -4,461.28 5,360.05 7.00 89.97 5,945,729.86 493,283.26 10,100.00 91.25 333.90 6,004.45 -3,157.98 -4,510.64 5,372.67 7.00 90.13 5,945,816.74 493,233.93 10,200.00 91.20 340.90 6,002.31 -3,065.74 -4,549.04 5,373.11 7.00 90.28 5,945,908.98 493,195.56 10,253.11 91.17 344.62 6,001.21 -3,015.04 -4,564.78 5,368.38 7.00 90.43 5,945,959.68 493,179.84 10 10,300.00 91.17 347.90 6,000.25 -2,969.51 -4,575.91 5,361.37 7.00 90.00 5,946,005.21 493,168.72 10,400.00 91.15 354.90 5,998.22 -2,870.71 -4,590.85 5,337.62 7.00 90.07 5,946,104.00 493,153.81 10,473.11 91.13 0.02 5,996.76 -2,797.71 -4,594.09 5,312.85 7.00 90.21 5,946,176.99 493,150.59 11 10,500.00 91.16 358.14 5,996.22 -2,770.83 -4,594.52 5,303.03 7.00 -89.00 5,946,203.87 493,150.17 10,600.00 91.27 351.14 5,994.10 -2,671.36 -4,603.86 5,273.84 7.00 -89.04 5,946,303.34 493,140.86 10,700.00 91.36 344.13 5,991.80 -2,573.76 -4,625.26 5,256.52 7.00 -89.19 5,946,400.93 493,119.49 10,723.11 91.38 342.52 5,991.25 -2,551.63 -4,631.89 5,254.23 7.00 -89.35 5,946,423.06 493,112.87 12 10,793.11 90.02 347.23 5,990.39 -2,484.08 -4,650.15 5,245.43 7.00 106.00 5,946,490.61 493,094.63 13 10,800.00 89.99 347.71 5,990.39 -2,477.36 -4,651.64 5,244.26 7.00 94.20 5,946,497.34 493,093.14 10,900.00 89.48 354.69 5,990.86 -2,378.60 -4,666.94 5,220.85 7.00 94.20 5,946,596.09 493,077.88 11,000.00 88.97 1.67 5,992.21 -2,278.72 -4,670.11 5,185.80 7.00 94.17 5,946,695.96 493,074.73 11,100.00 88.49 8.66 5,994.43 -2,179.21 -4,661.12 5,139.65 7.00 94.07 5,946,795.45 493,083.75 5/29/2015 11:34:54AM Page 3 COMPASS 5000.1 Build 61 • • IF/gall ConocoPhillips Planning Report BAKER HUGHES yaw A Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2H-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2H-14 @ 125.00usft(2H-14) Site: Kuparuk 2H Pad North Reference: True Well: 2H-14 Survey Calculation Method: Minimum Curvature Wellbore: 2H-14A Design: 2H-14A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +EI-W Section Rate Azimuth Northing Easting (usft) (e) (a) (usft) (usft) (usft) (usft) (I100ft) (°) (usft) (usft) 11,200.00 88.02 15.64 5,997.48 -2,081.56 -4,640.10 5,083.07 7.00 93.92 5,946,893.09 493,104.80 11,243.11 87.83 18.66 5,999.04 -2,040.39 -4,627.39 5,055.67 7.00 93.70 5,946,934.25 493,117.52 14 11,300.00 87.83 14.67 6,001.20 -1,985.95 -4,611.10 5,019.89 7.00 -90.00 5,946,988.69 493,133.83 11,400.00• 87.87 7.67 6,004.95 -1,887.97 -4,591.75 4,964.73 7.00 -89.85 5,947,086.65 493,153.20 Planned TD at 11400.00 5/29/2015 11:34:54AM Page 4 COMPASS 5000.1 Build 61 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2H-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2H-14 @ 125.00usft(2H-14) Site: Kuparuk 2H Pad North Reference: True Well: 2H-14 Survey Calculation Method Minimum Curvature Wellbore: 2H-14A Design: 2H-14A_wp06 Targets jTarget Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2H-14A_T03 0.00 0.00 6,047.00 -4,119.021,136,356.85 5,944,514.00 1,633,987.00 70°1'40.644 N 140°54'24.059 W -plan misses target center by 1139927.28usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A_T04 0.00 0.00 6,024.00 -3,817.071,136,057.73 5,944,816.00 1,633,688.00 70°1'44.014 N 140°54'31.264 W -plan misses target center by 1139628.19usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A_T07 0.00 0.00 6,005.00 -1,796.021,135,555.08 5,946,837.00 1,633,186.00 700 2'4.377 N 140°54'36.893 W -plan misses target center by 1139127.81 usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14AL1 CTD Polygon 0.00 0.00 0.00 -2,410.981,135,915.30 5,946,222.00 1,633,546.00 70°1'57.877 N 140°54'29.290 W -plan misses target center by 1139502.62usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Polygon Point 1 0.00 0.00 0.00 5,946,222.00 1,633,546.00 Point2 0.00 -346.83 570.18 5,945,875.03 1,634,116.02 Point3 0.00 -1,082.99 338.41 5,945,139.02 1,633,884.05 Point4 0.00 -1,330.91 628.53 5,944,891.03 1,634,174.07 Points 0.00 -2,075.01 570.78 5,944,147.03 1,634,116.10 Point6 0.00 -1,331.23 -289.56 5,944,890.99 1,633,256.07 Point7 0.00 0.00 0.00 5,946,222.00 1,633,546.00 2H-14A_T06 0.00 0.00 5,989.00 -2,306.101,135,482.22 5,946,327.00 1,633,113.00 70°1'59.530 N 140°54'41.148 W -plan misses target center by 1139054.04usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A_T02 0.00 0.00 6,050.00 -4,113.981,136,467.86 5,944,519.00 1,634,098.00 70°1'40.530 N 140°54'20.884 W -plan misses target center by 1140038.29usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A CTD Polygon 0.00 0.00 0.00 -1,543.061,135,349.98 5,947,090.00 1,632,981.00 70°2'7.133 N 140°54'41.639 W -plan misses target center by 1138938.93usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Polygon Point 1 0.00 0.00 0.00 5,947,090.00 1,632,981.00 Point2 0.00 -24.75 730.08 5,947,065.03 1,633,711.00 Point3 0.00 -1,396.98 457.54 5,945,693.02 1,633,438.08 Point 4 0.00 -2,223.80 1,201.90 5,944,866.06 1,634,182.11 Point5 0.00 -2,942.90 1,136.15 5,944,147.05 1,634,116.15 Point6 0.00 -2,108.16 151.75 5,944,982.01 1,633,132.10 Point 7 0.00 0.00 0.00 5,947,090.00 1,632,981.00 2H-14A_T05 0.00 0.00 6,009.00 -3,233.11 1,135,744.53 5,945,400.00 1,633,375.00 70°1'50.143 N 140°54'37.663 W -plan misses target center by 1139315.27usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A_T01 0.00 0.00 6,049.00 -4,111.981,136,471.86 5,944,521.00 1,634,102.00 70°1'40.544 N 140°54'20.762 W -plan misses target center by 1140042.29usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Point 2H-14A_Faultl 0.00 0.00 0.00 -3,233.11 1,135,744.53 5,945,400.00 1,633,375.00 70°1'50.143 N 140°54'37.663 W -plan misses target center by 1139330.94usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Rectangle(sides W500.00 H1.00 D0.00) 2H-14A_Fault2b 0.00 0.00 0.00 -3,818.071,136,057.73 5,944,815.00 1,633,688.00 70°1'44.004 N 140°54'31.269 W -plan misses target center by 1139643.85usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Rectangle(sides W500.00 H1.00 D0.00) 2H-14A_Fault2a 0.00 0.00 0.00 -4,114.981,136,466.86 5,944,518.00 1,634,097.00 70°1'40.522 N 140°54'20.917 W -plan misses target center by 1140052.95usft at 8500.00usft MD(5975.83 TVD,-4088.82 N,-3570.42 E) -Rectangle(sides W500.00 H1.00 D0.00) 5/29/2015 11.34.54AM Page 5 COMPASS 5000.1 Build 61 E - ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2H-14 Company: " ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2H-14 @ 125.00usft(2H-14) Site: Kuparuk 2H Pad North Reference: True Well: 2H-14 Survey Calculation Method: Minimum Curvature Wellbore: 2H-14A Design: 2H-14A_wp06 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) „ Name (in) (in) aii�n'4 lei 11,400.00 6,004.95 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,500.00 5,975.83 -4,088.82 -3,570.42 TIP 8,530.00 5,997.50 -4,104.96 -3,583.45 KOP 8,555.00 6,014.79 -4,119.01 -3,594.78 End 21 dls,Start 45 dls 8,633.11 6,045.54 -4,173.85 -3,639.04 4 8,733.11 6,051.01 -4,220.57 -3,724.38 5 8,833.11 6,041.29 -4,194.85 -3,817.87 End 45 dls,Start 7 dls 9,003.11 6,025.57 -4,085.36 -3,946.56 7 9,453.11 6,019.60 -3,704.99 -4,176.21 8 9,853.11 6,009.92 -3,360.03 -4,370.49 9 10,253.11 6,001.21 -3,015.04 -4,564.78 10 10,473.11 5,996.76 -2,797.71 -4,594.09 11 10,723.11 5,991.25 -2,551.63 -4,631.89 12 10,793.11 5,990.39 -2,484.08 -4,650.15 13 11,243.11 5,999.04 -2,040.39 -4,627.39 14 11,400.00 6,004.95 -1,887.97 -4,591.75 Planned TD at 11400.00 5/29/2015 11:34:54AM Page 6 COMPASS 5000.1 Build 61 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2H Pad 2H-14 2H-14A s 2H-14A_wp06 Travelling Cylinder Report 29 May, 2015 ,iga- ..-_,..,,,$:-. , , ir 4.,111111 , °,,,,,,Ow: , ,, BAKER HUGHES Baker Hughes INTEQ rag ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2H-14 Project: Kuparuk River Unit TVD Reference: 2H-14 @ 125.00usft(2H-14) Reference Site: Kuparuk 2H Pad MD Reference: 2H-14 @ 125.00usft(2H-14) Site Error: 0.00usft North Reference: True Reference Well: 2H-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2H-14A Database: OAKEDMP2 Reference Design: 2H-14A_wp06 Offset TVD Reference: Offset Datum Reference 2H-14A_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,500.00 to 11,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,327.50usft Error Surface: Elliptical Conic Survey Tool Program Date '.5/29/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 8,500.00 2H-14(2H-14) GCT-MS Schlumberger GCT multishot 8,500.00 11,400.00 2H-14A_wp06(2H-14A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (.•) (")' 11,400.00 6,129.95 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre " Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design' (usft) (usft) (usft) (usft) Kuparuk 2H Pad 2H-14-2H-14-2H-14 8,549.96 8,550.00 0.77 2.14 -1.36 FAIL-Major Risk 2H-14-2H-14AL1-2H-14AL1_wp07 8,974.98 8,975.00 0.76 0.80 -0.04 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/29/2015 10:11:58AM Page 2 of 6 COMPASS 5000.1 Build 65 • • 110 In I i O ilia N r i o I N o M i 3 y I o 0 o � � N F i,8x N m d v N a N A, 1 I Fl o N z wt,2z 0 iQ Wz�' �' 0 �, Z � x o 7. i mo@D El 1 N Wagl664111°1".r \ vs 11111 Ile mN .. _i 'x� o C N • Z-C A-79 i10-0v o gI I k.,N , I o 1 2 ............ i ....... 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These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 1q()._ o -1'�/} PTD: 09] —6711 Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: � ►JkJ POOL: I, .1 16180,4 2,441- J 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: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • ❑❑ Ts' N , , LL. o a N N Y a) 0 y, 5 c a). Q 0' ° a >, t . . . O, . , , c ap cao , O �Z ° . . . o a N. `o. WI (� 0, a C m °. W. , of ai E O aa o' , c@ ) . a a 3 = a - ° v - . c . 0 'S oQ o, a�°i ,.T.cr 3 Y o. cn S J CO C O L, > O M �' O I- O. U $2 E �� vi. a E. M� Y' ' o � 0. -0 a, , , , ` , '> oo °a, m aorm >. , ET °, D. c. a LO, am 1 o ( � v y o, , o a. 3, 0 cca) _a, a' c a _ � w . �' � "O' , � = . . 3. o. ° N a m. d , 0, . c I o, > y _ m, 3. °' a c; 3 Z °3. y Y �� �, E �� Y. N, y. ay �I Y. �� > �� t' °. �, �, 3. c. y yu _ m. m. a) C. c. uS, c. c' . rn, �. a. d -8. o. . . 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